40 CFR PARTS 72 AND 75
Unofficial Version
(Volume I)
U.S. Environmental Protection Agency
Clean Air Markets Division
January 3, 2008
(Reposted with Corrections January 24, 2008)
-------
-------
January 3, 2008
40 CFR Parts 72 and 75
NOTICE
This unofficial version of 40 CFR Part 75 (and 40 CFR 72.1 - 72.3) has been produced to assist
interested parties in understanding changes that the U.S. Environmental Protection Agency has made to
Parts 72 and 75. This unofficial version contains the final rule revisions published on September 7,
2007, and also reflects revisions to be published in a notice of final rulemaking. While all reasonable
steps have been taken to produce this unofficial version in an accurate manner, the version published by
the Office of the Federal Register remains the official version of the applicable rules.
For ease of electronic access, the material is split into two volumes: Volume I contains §§ 72.1 -
72.3, and the regulatory sections of Part 75; Volume II contains the appendices to Part 75.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page i
-------
[This page intentionally left blank.]
Unofficial Version - Parts 72 and 75 (01/03/08) — Page ii
-------
40 CFR Parts 72 and 75
Table of Contents
Page
40 CFR Part 72:
Subpart A — Acid Rain Program General Provisions 1
§ 72.1 Purpose and scope 1
§72.2 Definitions 1
§ 72.3 Measurements, abbreviations, and acronyms 28
40 CFR Part 75:
Subpart A ~ General 31
§75.1 Purpose and scope 31
§75.2 Applicability 31
§ 75.3 General Acid Rain Program provisions 32
§ 75.4 Compliance dates 32
§ 75.5 Prohibitions 35
§75.6 Incorporation by reference 36
§ 75.7 [Removed and Reserved] 40
§75.8 [Removed and Reserved] 40
Subpart B - Monitoring Provisions 40
§ 75.10 General operating requirements 40
§ 75.11 Specific provisions for monitoring S02 emissions 43
§ 75.12 Specific provisions for monitoring NOx emission rate 45
§ 75.13 Specific provisions for monitoring C02 emissions 46
§ 75.14 Specific provisions for monitoring opacity 47
§ 75.15 Special provisions for measuring Hg mass emissions using the excepted sorbent
trap monitoring methodology 47
§ 75.16 Special provisions for monitoring emissions from common, bypass, and multiple
stacks for S02 emissions and heat input determinations 49
§ 75.17 Specific provisions for monitoring emissions from common, bypass, and multiple
stacks for NOx emission rate 51
§ 75.18 Specific provisions for monitoring emissions from common and by-pass stacks
for opacity 53
§ 75.19 Optional S02, NOx, and C02 emissions calculation for low mass emissions units 54
Subpart C - Operation and Maintenance Requirements 72
§ 75.20 Initial certification and recertification procedures 72
§ 75.21 Quality assurance and quality control requirements 85
§75.22 Reference test methods 87
§ 75.23 Alternatives to standards incorporated by reference 89
§ 75.24 Out-of-control periods and adjustment for system bias 89
Subpart D - Missing Data Substitution Procedures 90
§ 75.30 General provisions 90
§75.31 Initial missing data procedures 91
Unofficial Version - Parts 72 and 75 (01/03/08) — Page iii
-------
40 CFR Parts 72 and 75
Table of Contents (cont.)
Page
§ 75.32 Determination of monitor data availability for standard missing data procedures 93
§ 75.33 Standard missing data procedures for S02, NOx, Hg and flow rate 94
§ 75.34 Units with add-on emission controls 102
§ 75.35 Missing data procedures for C02 104
§ 75.36 Missing data procedures for heat input rate determinations 105
§ 75.37 Missing data procedures for moisture 105
§ 75.38 Standard missing data procedures for Hg CEMS 106
§ 75.39 Missing data procedures for sorbent trap monitoring systems 107
Subpart E - Alternative Monitoring Systems 108
§ 75.40 General demonstration requirements 108
§ 75.41 Precision criteria 108
§ 75.42 Reliability criteria 114
§ 75.43 Accessibility criteria 114
§ 75.44 Timeliness criteria 114
§ 75.45 Daily quality assurance criteria 114
§ 75.46 Missing data substitution criteria 114
§ 75.47 Criteria for a class of affected units 114
§ 75.48 Petition for an alternative monitoring system 115
Subpart F - Recordkeeping Requirements 116
§ 75.50 -75.52 [Reserved] 116
§ 75.53 Monitoring plan 116
§75.54 [Reserved] 126
§75.55 [Reserved] 126
§75.56 [Reserved] 126
§ 75.57 General recordkeeping provisions 126
§ 75.58 General recordkeeping provisions for specific situations 134
§ 75.59 Certification, quality assurance, and quality control record provisions 139
Subpart G - Reporting Requirements 152
§ 75.60 General provisions 152
§ 75.61 Notifications 153
§75.62 Monitoring plan submittals 156
§ 75.63 Initial certification or recertification application 157
§ 75.64 Quarterly reports 158
§ 75.65 Opacity reports 161
§ 75.66 Petitions to the Administrator 161
§75.67 Retired units petitions 163
Subpart H - NOx Mass Emissions Provisions 163
§75.70 NOx mass emissions provisions 163
§ 75.71 Specific provisions for monitoring NOx and heat input for the purpose of
calculating NOx mass emissions 167
§ 75.72 Determination of NOx mass emissions for common stack and multiple stack configurations 168
§ 75.73 Recordkeeping and reporting 171
§ 75.74 Annual and ozone season monitoring and reporting requirements 176
§ 75.75 Additional ozone season calculation procedures for special circumstances 183
Unofficial Version - Parts 72 and 75 (01/03/08) — Page iv
-------
40 CFR Parts 72 and 75
Table of Contents (cont.)
Page
Subpart I - Hg Mass Emission Provisions 183
§ 75.80 General provisions 183
§ 75.81 Monitoring of Hg mass emissions and heat input at the unit level 186
§ 75.82 Monitoring of Hg mass emissions and heat input at common and multiple stacks 190
§ 75.83 Calculation of Hg mass emissions and heat input rate 192
§ 75.84 Recordkeeping and reporting 192
Unofficial Version - Parts 72 and 75 (01/03/08) — Page v
-------
[This page intentionally left blank.]
Unofficial Version - Parts 72 and 75 (01/03/08) — Page vi
-------
PART 72-PERMITS REGULATION
Authority: 42 U.S.C. 7601 and 7651, etseq.
Subpart A—Acid Rain Program General Provisions
§ 72.1 § 72.1 Purpose and scope.
§ 72.1(a) (a) Purpose. The purpose of this part is to establish certain general provisions and the
operating permit program requirements for affected sources and affected units under the
Acid Rain Program, pursuant to title IV of the Clean Air Act, 42 U.S.C. 7401, et seq., as
amended by Public Law 101-549 (November 15, 1990).
§ 72.1(b) (b) Scope. The regulations under this part set forth certain generally applicable
provisions under the Acid Rain Program. The regulations also set forth requirements for
obtaining three types of Acid Rain permits, during Phases I and II, for which an affected
source may apply: Acid Rain permits issued by the United States Environmental Protection
Agency during Phase I; the Acid Rain portion of an operating permit issued by a State
permitting authority during Phase II; and the Acid Rain portion of an operating permit
issued by EPA when it is the permitting authority during Phase II. The requirements under
this part supplement, and in some cases modify, the requirements under parts 70 and 71 of
this chapter and other regulations implementing title V for approving and implementing
State operating permit programs and for Federal issuance of operating permits under title V,
as such requirements apply to affected sources under the Acid Rain Program.
§ 72.2 § 72.2 Definitions.
The terms used in this part, in parts 73, 74, 75, 76, 77 and 78 of this chapter shall have
the meanings set forth in the Act, including sections 302 and 402 of the Act, and in this
section as follows:
Account number means the identification number given by the Administrator to each
Allowance Tracking System account pursuant to §73.31(d) of this chapter.
Acid Rain compliance option means one of the methods of compliance used by an affected
unit under the Acid Rain Program as described in a compliance plan submitted and
approved in accordance with subpart D of this part, part 74 of this chapter or part 76 of this
chapter.
Acid Rain emissions limitation means:
(1) For purposes of sulfur dioxide emissions:
(i) The tonnage equivalent of the allowances authorized to be allocated to an affected
unit for use in a calendar year under section 404(a)(1), (a)(3), and (h) of the Act, or the
basic Phase II allowance allocations authorized to be allocated to an affected unit for use in
a calendar year, or the allowances authorized to be allocated to an opt-in source under
section 410 of the Act for use in a calendar year;
(ii) As adjusted:
(A) By allowances allocated by the Administrator pursuant to section 403, section 405
(a)(2), (a)(3), (b)(2), (c)(4), (d)(3), and (h)(2), and section 406 of the Act;
(B) By allowances allocated by the Administrator pursuant to subpart D of this part;
and thereafter
(C) By allowance transfers to or from the compliance subaccount for that unit that were
recorded or properly submitted for recordation by the allowance transfer deadline as
provided in §73.35 of this chapter, after deductions and other adjustments are made
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 1
-------
pursuant to §73.34(c) of this chapter; and
(2) For purposes of nitrogen oxides emissions, the applicable limitation under part 76
of this chapter.
Acid Rain emissions reduction requirement means a requirement under the Acid Rain
Program to reduce the emissions of sulfur dioxide or nitrogen oxides from a unit to a
specified level or by a specified percentage.
Acid Rain permit or permit means the legally binding written document or portion of such
document, including any permit revisions, that is issued by a permitting authority under this
part and specifies the Acid Rain Program requirements applicable to an affected source and
to the owners and operators and the designated representative of the affected source or the
affected unit.
Acid Rain Program means the national sulfur dioxide and nitrogen oxides air pollution
control and emissions reduction program established in accordance with title IV of the Act,
this part, and parts 73, 74, 75, 76, 77, and 78 of this chapter.
Act means the Clean Air Act, 42 U.S.C. 7401, el seq. as amended by Public Law No.
101-549 (November 15, 1990).
Actual S02 emissions rate means the annual average sulfur dioxide emissions rate for the
unit (expressed in lb/mmBtu), for the specified calendar year; provided that, if the unit is
listed in the NADB, the "1985 actual S02 emissions rate" for the unit shall be the rate
specified by the Administrator in the NADB under the data field "S02RTE."
Add-on control means a pollution reduction control technology that operates independent of
the combustion process.
Additional advance auction means the auction of advance allowances that were offered the
previous year for sale in an advance sale.
Administrator means the Administrator of the United States Environmental Protection
Agency or the Administrator's duly authorized representative.
Advance allowance means an allowance that may be used for purposes of compliance with
a unit's Acid Rain sulfur dioxide emissions limitation requirements beginning no earlier
than seven years following the year in which the allowance is first offered for sale.
Advance auction means an auction of advance allowances.
Advance sale means a sale of advance allowances.
Affected source means a source that includes one or more affected units.
Affected States means any affected States as defined in part 71 of this chapter.
Affected unit means a unit that is subject to any Acid Rain emissions reduction requirement
or Acid Rain emissions limitation under §72.6 or part 74 of this chapter.
Affiliate shall have the meaning set forth in section 2(a)(l 1) of the Public Utility Holding
Company Act of 1935, 15 U.S.C. 79b(a)(ll), as of November 15, 1990.
Allocate or allocation means the initial crediting of an allowance by the Administrator to an
Allowance Tracking System unit account or general account.
Air Emission Testing Body (AETB) means a company or other entity that conducts Air
Emissions Testing as described in ASTM D7036-04 (incorporated by referenced under
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 2
-------
§75.6 of this part).
Allowable S02 emissions rate means the most stringent federally enforceable emissions
limitation for sulfur dioxide (in lb/mmBtu) applicable to the unit or combustion source for
the specified calendar year, or for such subsequent year as determined by the Administrator
where such a limitation does not exist for the specified year; provided that, if a Phase I or
Phase II unit is listed in the NADB, the "1985 allowable S02 emissions rate" for the Phase I
or Phase II unit shall be the rate specified by the Administrator in the NADB under the data
field "1985 annualized boiler S02 emission limit."
Allowance means an authorization by the Administrator under the Acid Rain Program to
emit up to one ton of sulfur dioxide during or after a specified calendar year.
Allowance deduction, or deduct when referring to allowances, means the permanent
withdrawal of allowances by the Administrator from an Allowance Tracking System
compliance subaccount, or future year subaccount, to account for the number of tons of S02
emissions from an affected unit for the calendar year, for tonnage emissions estimates
calculated for periods of missing data as provided in part 75 of this chapter, or for any other
allowance surrender obligations of the Acid Rain Program.
Allowances held or hold allowances means the allowances recorded by the Administrator,
or submitted to the Administrator for recordation in accordance with §73.50 of this chapter,
in an Allowance Tracking System account.
Allowance reserve means any bank of allowances established by the Administrator in the
Allowance Tracking System pursuant to sections 404(a)(2) (Phase I extension reserve),
404(g) (energy conservation and renewable energy reserve), or 416(b) (special allowance
reserve) of the Act, and implemented in accordance with part 73, subpart B of this chapter.
Allowance Tracking System or A TS means the Acid Rain Program system by which the
Administrator allocates, records, deducts, and tracks allowances.
Allowance Tracking System account means an account in the Allowance Tracking System
established by the Administrator for purposes of allocating, holding, transferring, and using
allowances.
Allowance transfer deadline means midnight of March 1 (or February 29 in any leap year)
or, if such day is not a business day, midnight of the first business day thereafter and is the
deadline by which allowances may be submitted for recordation in an affected unit's
compliance subaccount for the purposes of meeting the unit's Acid Rain emissions
limitation requirements for sulfur dioxide for the previous calendar year.
Alternative monitoring system means a system or a component of a system designed to
provide direct or indirect data of mass emissions per time period, pollutant concentrations,
or volumetric flow, that is demonstrated to the Administrator as having the same precision,
reliability, accessibility, and timeliness as the data provided by a certified CEMS or
certified CEMS component in accordance with part 75 of this chapter.
As-fired means the taking of a fuel sample just prior to its introduction into the unit for
combustion.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 3
-------
Auction subaccount means a subaccount in the Special Allowance Reserve, as specified in
section 416(b) of the Act, which contains allowances to be sold at auction in the amount of
150,000 per year from calendar year 1995 through 1999, inclusive, and 200,000 per year
for each year beginning in calendar year 2000, subject to the adjustments noted in the
regulations in part 73, subpart E of this chapter.
Authorized account representative means a responsible natural person who is authorized, in
accordance with part 73 of this chapter, to transfer and otherwise dispose of allowances
held in an Allowance Tracking System general account; or, in the case of a unit account, the
designated representative of the owners and operators of the affected unit.
Automated data acquisition and handling system means that component of the CEMS,
COMS, or other emissions monitoring system approved by the Administrator for use in the
Acid Rain Program, designed to interpret and convert individual output signals from
pollutant concentration monitors, flow monitors, diluent gas monitors, moisture monitors,
opacity monitors, and other component parts of the monitoring system to produce a
continuous record of the measured parameters in the measurement units required by part 75
of this chapter.
Award means the conditional set-aside by the Administrator, based on the submission of an
early ranking application pursuant to subpart D of this part, of an allowance from the Phase
I extension reserve, for possible future allocation to a Phase I extension applicant's
Allowance Tracking System unit account.
Backup fuel means a fuel for a unit where:
(1) For purposes of the requirements of the monitoring exception of appendix E of part
75 of this chapter, the fuel provides less than 10.0 percent of the heat input to a unit during
the three calendar years prior to certification testing for the primary fuel and the fuel
provides less than 15.0 percent of the heat input to a unit in each of those three calendar
years; or the Administrator approves the fuel as a backup fuel; and
(2) For all other purposes under the Acid Rain Program, a fuel that is not the primary
fuel (expressed in mmBtu) consumed by an affected unit for the applicable calendar year.
Baseline means the annual average quantity of fossil fuel consumed by a unit, measured in
millions of British Thermal Units (expressed in mmBtu) for calendar years 1985 through
1987; provided that in the event that a unit is listed in the NADB, the baseline will be
calculated for each unit-generator pair that includes the unit, and the unit's baseline will be
the sum of such unit-generator baselines. The unit-generator baseline will be as provided in
the NADB under the data field "BASE8587", as adjusted by the outage hours listed in the
NADB under the data field "OUTAGEHR" in accordance with the following equation:
Baseline = BASE8587 x {26280 / (26280 - - OUTAGEHR)} x {36 / (36 - - months not on
line)} x 106
"Months not on line" is the number of months during January 1985 through December 1987
prior to the commencement of firing for units that commenced firing in that period, i.e., the
number of months, in that period, prior to the on-line month listed under the data field
"BLRMNONL" and the on-line year listed in the data field "BLRYRONL" in the NADB.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 4
-------
Basic Phase II allowance allocations means:
(1) For calendar years 2000 through 2009 inclusive, allocations of allowances made by
the Administrator pursuant to section 403 and section 405 (b)(1), (3), and (4); (c)(1), (2),
(3), and (5); (d)(1), (2), (4), and (5); (e); (f); (g)(1), (2), (3), (4), and (5); (h)(1); (i); and (j).
(2) For each calendar year beginning in 2010, allocations of allowances made by the
Administrator pursuant to section 403 and section 405 (b)(1), (3), and (4); (c)(1), (2), (3),
and (5); (d)(1), (2), (4), and (5); (e); (f); (g)(1), (2), (3), (4), and (5); (h)(1) and (3); (i); and
CD-
Bias means systematic error, resulting in measurements that will be either consistently low
or high relative to the reference value.
Boiler means an enclosed fossil or other fuel-fired combustion device used to produce heat
and to transfer heat to recirculating water, steam, or any other medium.
Bypass operating quarter means a calendar quarter during which emissions pass through a
stack, duct or flue that bypasses add-on emission controls.
Bypass stack means any duct, stack, or conduit through which emissions from an affected
unit may or do pass to the atmosphere, which either augments or substitutes for the
principal stack exhaust system or ductwork during any portion of the unit's operation.
Calibration error means the difference between:
(1) The response of a gaseous monitor to a calibration gas and the known
concentration of the calibration gas;
(2) The response of a flow monitor to a reference signal and the known value of the
reference signal; or
(3) The response of a continuous opacity monitoring system to an attenuation filter and
the known value of the filter after a stated period of operation during which no unscheduled
maintenance, repair, or adjustment took place.
Calibration gas means:
(1) A standard reference material;
(2) A standard reference material-equivalent compressed gas primary reference
material;
(3) A NIST traceable reference material;
(4) NIST/EPA-approved certified reference materials;
(5) A gas manufacturer's intermediate standard;
(6) An EPA protocol gas;
(7) Zero air material; or
(8) A research gas mixture.
Capacity factor means either: (1) the ratio of a unit's actual annual electric output
(expressed inMWe-hr) to the unit's nameplate capacity (or maximum observed hourly gross
load (in MWe/hr) if greater than the nameplate capacity) times 8760 hours, or (2) the ratio
of a unit's annual heat input (in million British thermal units or equivalent units of measure)
to the unit's maximum rated hourly heat input rate (in million British thermal units per hour
or equivalent units of measure) times 8,760 hours.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 5
-------
CEMSprecision or precision as applied to the monitoring requirements of part 75 of this
chapter, means the closeness of a measurement to the actual measured value expressed as
the uncertainty associated with repeated measurements of the same sample or of different
samples from the same process (e.g., the random error associated with simultaneous
measurements of a process made by more than one instrument). A measurement technique
is determined to have increasing "precision" as the variation among the repeated
measurements decreases.
Centroidal area means a representational concentric area that is geometrically similar to the
stack or duct cross section, and is not greater than 1 percent of the stack or duct cross-
sectional area.
Certificate of representation means the completed and signed submission required by
§72.20, for certifying the appointment of a designated representative for an affected source
or a group of identified affected sources authorized to represent the owners and operators of
such source(s) and of the affected units at such source(s) with regard to matters under the
Acid Rain Program.
Certifying official, for purposes of part 73 of this chapter, means:
(1) For a corporation, a president, secretary, treasurer, or vice-president of the
corporation in charge of a principal business function, or any other person who performs
similar policy or decision-making functions for the corporation;
(2) For partnership or sole proprietorship, a general partner or the proprietor,
respectively; and
(3) For a local government entity or State, Federal, or other public agency, either a
principal executive officer or ranking elected official.
Coal means all solid fuels classified as anthracite, bituminous, subbituminous, or lignite by
the American Society for Testing and Materials Designation ASTM D388-92 "Standard
Classification of Coals by Rank" (as incorporated by reference in §72.13).
Coal-derived fuel means any fuel, whether in a solid, liquid, or gaseous state, produced b y
the mechanical, thermal, or chemical processing of coal (e.g., pulverized coal, coal refuse,
liquified or gasified coal, washed coal, chemically cleaned coal, coal-oil mixtures, and
coke).
Coal-fired means the combustion of fuel consisting of coal or any coal-derived fuel (except
a coal-derived gaseous fuel that meets the definition of "very low sulfur fuel" in this
section), alone or in combination with any other fuel, where:
(1) For purposes of the requirements of part 75 of this chapter, a unit is "coal-fired"
independent of the percentage of coal or coal-derived fuel consumed in any calendar year
(expressed in mmBtu); and
(2) For all other purposes under the Acid Rain Program, except for purposes of
applying part 76 of this chapter, a unit is "coal-fired" if it uses coal or coal-derived fuel as
its primary fuel (expressed in mmBtu); provided that, if the unit is listed in the NADB, the
primary fuel is the fuel listed in the NADB under the data field "PRIMEFUEL".
Cogeneration unit means a unit that produces electric energy and useful thermal energy for
industrial, commercial, or heating or cooling purposes, through the sequential use of the
original fuel energy.
Combustion source means a stationary fossil fuel fired boiler, turbine, or internal
combustion engine that has submitted or intends to submit an opt-in permit application
under §74.14 of this chapter to enter the Opt-in Program.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 6
-------
Commence commercial operation means to have begun to generate electricity for sale,
including the sale of test generation.
Commence construction means that an owner or operator has either undertaken a
continuous program of construction or has entered into a contractual obligation to
undertake and complete, within a reasonable time, a continuous program of construction.
Commence operation means to have begun any mechanical, chemical, or electronic process,
including start-up of an emissions control technology or emissions monitor or of a unit's
combustion chamber.
Common pipe means an oil or gas supply line through which the same type of fuel is
distributed to two or more affected units.
Common pipe operating time means the portion of a clock hour during which fuel flows
through a common pipe. The common pipe operating time, in hours, is expressed as a
decimal fraction, with valid values ranging from 0.00 to 1.00.
Common stack means the exhaust of emissions from two or more units through a single
flue.
Compensating unit means an affected unit that is not otherwise subject to Acid Rain
emissions limitation or Acid Rain emissions reduction requirements during Phase I and that
is designated as a Phase I unit in a reduced utilization plan under §72.43; provided that an
opt-in source shall not be a compensating unit.
Compliance certification means a submission to the Administrator or permitting authority,
as appropriate, that is required by this part, by part 73, 74, 75, 76, 77, or 78 of this chapter,
to report an affected source or an affected unit's compliance or non-compliance with a
provision of the Acid Rain Program and that is signed and verified by the designated
representative in accordance with subparts B and I of this part and the Acid Rain Program
regulations generally.
Compliance plan, for the purposes of the Acid Rain Program, means the document
submitted for an affected source in accordance with subpart C of this part or subpart E of
part 74 of this chapter, or part 76 of this chapter, specifying the method(s) (including one or
more Acid Rain compliance options as provided under subpart D of this part or subpart E of
part 74 of this chapter, or part 76 of this chapter) by which each affected unit at the source
will meet the applicable Acid Rain emissions limitation and Acid Rain emissions reduction
requirements.
Compliance subaccount means the subaccount in an affected unit's Allowance Tracking
System account, established pursuant to §73.31 (a) or (b) of this chapter, in which are held,
from the date that allowances for the current calendar year are recorded under §73.34(a)
until December 31, allowances available for use in the current calendar year and, after
December 31 until the date that deductions are made under §73.35(b), allowances available
for use by the unit in the preceding calendar year, for the purpose of meeting the Acid Rain
emissions limitation for sulfur dioxide.
Compliance use date means the first calendar year for which an allowance may be used for
purposes of meeting a unit's Acid Rain emissions limitation for sulfur dioxide.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 7
-------
Conditionally valid data means data from a continuous monitoring system that are not
quality-assured, but which may become quality-assured if certain conditions are met.
Examples of data that may qualify as conditionally valid are: data recorded by an
uncertified monitoring system prior to its initial certification; or data recorded by a certified
monitoring system following a significant change to the system that may affect its ability to
accurately measure and record emissions. A monitoring system must pass a probationary
calibration error test, in accordance with section 2.1.1 of appendix B to part 75 of this
chapter, to initiate the conditionally valid data status. In order for conditionally valid
emission data to become quality-assured, one or more quality assurance tests or diagnostic
tests must be passed within a specified time period in accordance with §75.20(b)(3).
Conservation Verification Protocol means a methodology developed by the Administrator
for calculating the kilowatt hour savings from energy conservation measures and improved
unit efficiency measures for the purposes of title IV of the Act.
Construction means fabrication, erection, or installation of a unit or any portion of a unit.
Consumer Price Index or CPI means, for purposes of the Acid Rain Program, the U.S.
Department of Labor, Bureau of Labor Statistics unadjusted Consumer Price Index for All
Urban Consumers for the U.S. city average, for All Items on the latest reference base, or if
such index is no longer published, such other index as the Administrator in his or her
discretion determines meets the requirements of the Clean Air Act Amendments of 1990.
(1) CPI (1990) means the CPI for all urban consumers for the month of August 1989.
The "CPI (1990)" is 124.6 (with 1982-1984=100). Beginning in the month for which a
new reference base is established, "CPI (1990)" will be the CPI value for August 1989 on
the new reference base.
(2) CPI (year) means the CPI for all urban consumers for the month of August of the
previous year.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 8
-------
Continuous emission monitoring system or CEMS means the equipment required by part 75
of this chapter used to sample, analyze, measure, and provide, by means of readings
recorded at least once every 15 minutes (using an automated data acquisition and handling
system (DAHS)), a permanent record of S02, NOx, Hg, or C02 emissions or stack gas
volumetric flow rate. The following are the principal types of continuous emission
monitoring systems required under part 75 of this chapter. Sections 75.10 through 75.18,
§75.71(a) and 75.81 of this chapter indicate which type(s) of CEMS is required for specific
applications:
(1) A sulfur dioxide monitoring system, consisting of an S02 pollutant concentration
monitor and an automated DAHS. An S02 monitoring system provides a permanent,
continuous record of S02 emissions in units of parts per million (ppm);
(2) A flow monitoring system, consisting of a stack flow rate monitor and an automated
DAHS. A flow monitoring system provides a permanent, continuous record of stack gas
volumetric flow rate, in units of standard cubic feet per hour (scfh);
(3) A nitrogen oxides (NOx) emission rate (or NOx-diluent) monitoring system,
consisting of a NOx pollutant concentration monitor, a diluent gas (C02 or 02) monitor, and
an automated DAHS. A NOx-diluent monitoring system provides a permanent, continuous
record of: NOx concentration in units of parts per million (ppm), diluent gas concentration
in units of percent 02 or C02 (% 02 or C02), and NOx emission rate in units of pounds per
million British thermal units (lb/mmBtu);
(4) A nitrogen oxides concentration monitoring system, consisting of a NOx pollutant
concentration monitor and an automated DAHS. A NOx concentration monitoring system
provides a permanent, continuous record of NOx emissions in units of parts per million
(ppm). This type of CEMS is used only in conjunction with a flow monitoring system to
determine NOx mass emissions (in lb/hr) under subpart H of part 75 of this chapter;
(5) A carbon dioxide monitoring system, consisting of a C02 pollutant concentration
monitor (or an oxygen monitor plus suitable mathematical equations from which the C02
concentration is derived) and the automated DAHS. A carbon dioxide monitoring system
provides a permanent, continuous record of C02 emissions in units of percent C02 (%
C02); and
(6) A moisture monitoring system, as defined in §75.11(b)(2) of this chapter. A
moisture monitoring system provides a permanent, continuous record of the stack gas
moisture content, in units of percent H20 (% H20)
(7) A Hg concentration monitoring system, consisting of a Hg pollutant concentration
monitor and an automated DAHS. A Hg concentration monitoring system provides a
permanent, continuous record of Hg emissions in units of micrograms per standard cubic
meter (|ig/scm).
Continuous opacity monitoring system or COMS means the equipment required by part 75
of this chapter to sample, measure, analyze, and provide, with readings taken at least once
every 6 minutes, a permanent record of opacity or transmittance. The following
components are included in a continuous opacity monitoring system:
(1) Opacity monitor; and
(2) An automated data acquisition and handling system.
Control unit means a unit employing a qualifying Phase I technology in accordance with a
Phase I extension plan under §72.42.
Current year subaccount means the subaccount in an Allowance Tracking System general
account, established pursuant to §73.31(c) of this chapter, in which are held allowances that
may be transferred to a unit's compliance subaccount for use for the purpose of meeting the
Acid Rain sulfur dioxide emissions limitation.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 9
-------
Customer means a purchaser of electricity not for the purposes of retransmission or resale.
For generating rural electrical cooperatives, the customers of the distribution cooperatives
served by the generating cooperative will be considered customers of the generating
cooperative.
Decisional body means any EPA employee who is or may reasonably be expected to act in
a decision-making role in a proceeding under part 78 of this chapter, including the
Administrator, a member of the Environmental Appeals Board, and a Presiding Officer, and
any staff of any such person who are participating in the decisional process.
Demand-side measure means a measure:
(1) To improve the efficiency of consumption of electricity from a utility by customers
of the utility; or
(2) To reduce the amount of consumption of electricity from a utility by customers of
the utility without increasing the use by the customer of fuel other than: Biomass (i.e.,
combustible energy-producing materials from biological sources, which include wood, plant
residues, biological wastes, landfill gas, energy crops, and eligible components of municipal
solid waste), solar, geothermal, or wind resources; or industrial waste gases where the party
making the submission involved certifies that there is no net increase in sulfur dioxide
emissions from the use of such gases. "Demand-side measure" includes the measures listed
in part 73, appendix A, section 1 of this chapter.
Designated representative means a responsible natural person authorized by the owners and
operators of an affected source and of all affected units at the source or by the owners and
operators of a combustion source or process source, as evidenced by a certificate of
representation submitted in accordance with subpart B of this part, to represent and legally
bind each owner and operator, as a matter of Federal law, in matters pertaining to the Acid
Rain Program. Whenever the term "responsible official" is used in part 70 of this chapter,
in any other regulations implementing title V of the Act, or in a State operating permit
program, it shall be deemed to refer to the "designated representative" with regard to all
matters under the Acid Rain Program.
Desulfurization refers to various procedures whereby sulfur is removed from petroleum
during or apart from the refining process. "Desulfurization" does not include such
processes as dilution or blending of low sulfur content diesel fuel with high sulfur content
diesel fuel from a diesel refinery not eligible under 40 CFR part 73, subpart G.
Diesel-fired unit means, for the purposes of part 75 of this chapter, an oil-fired unit that
combusts diesel fuel as its fuel oil, where the supplementary fuel, if any, shall be limited to
natural gas or gaseous fuels containing no more sulfur than natural gas.
Diesel fuel means a low sulfur fuel oil of grades 1 -D or 2-D, as defined by the American
Society for Testing and Materials standard ASTM D975-91, "Standard Specification for
Diesel Fuel Oils," grades 1-GT or 2-GT, as defined by ASTM D2880-90a, "Standard
Specification for Gas Turbine Fuel Oils," or grades 1 or 2, as defined by ASTM D396-90a,
"Standard Specification for Fuel Oils" (incorporated by reference in §72.13).
Diesel reciprocating engine unit means an internal combustion engine that combusts only
diesel fuel and that thereby generates electricity through the operation of pistons, rather
than by heating steam or water.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 10
-------
Diluent cap value means a default value of percent C02 or 02 which may be used to
calculate the hourly NOx emission rate when the measured hourly average percent C02 is
below the default value or when the measured hourly average percent 02 is above the
default value. The diluent cap values for boilers are 5.0 percent C02 and 14.0 percent 02.
For combustion turbines, the diluent cap values are 1.0 percent C02 and 19.0 percent 02.
Diluent gas means a major gaseous constituent in a gaseous pollutant mixture, which in the
case of emissions from fossil fuel-fired units are carbon dioxide and oxygen.
Diluent gas monitor means that component of the continuous emission monitoring system
that measures the diluent gas concentration in a unit's flue gas.
Direct public utility ownership means direct ownership of equipment and facilities by one
or more corporations, the principal business of which is sale of electricity to the public at
retail. Percentage ownership of such equipment and facilities shall be measured on the
basis of book value.
Direct Sale Subaccount means a subaccount in the Special Allowance Reserve, as specified
in section 416(b) of the Act, which contains Phase II allowances to be sold in the amount of
25,000 per year, from calendar year 1993 to 1999, inclusive, and of 50,000 per year for
each year beginning in calendar year 2000, subject to the adjustments noted in the
regulations at part 73, subpart E of this chapter.
Dispatch means the assignment within a dispatch system of generating levels to specific
units and generators to affect the reliable and economical supply of electricity, as customer
demand rises or falls, and includes:
(1) The operation of high-voltage lines, substations, and related equipment; and
(2) The scheduling of generation for the purpose of supplying electricity to other
utilities over interconnecting transmission lines.
Draft Acid Rain permit or draft permit means the version of the Acid Rain permit, or the
Acid Rain portion of an operating permit, that a permitting authority offers for public
comment.
Dual-fuel reciprocating engine unit means an internal combustion engine that combusts any
combination of natural gas and diesel fuel and that thereby generates electricity through the
operation of pistons, rather than by heating steam or water.
Eligible Indian tribe means any eligible Indian tribe as defined in part 71 of this chapter.
Emergency fuel means either:
(1) For purposes of the requirements for a fuel flowmeter used in an excepted
monitoring system under appendix D or E of part 75 of this chapter, the fuel identified by
the designated representative in the unit's monitoring plan as the fuel which is combusted
only during emergencies where the primary fuel is not available; or
(2) For purposes of the requirement for stack testing for an excepted monitoring system
under appendix E of part 75 of this chapter, the fuel identified in a federally-enforceable
permit for a plant and identified by the designated representative in the unit's monitoring
plan as the fuel which is combusted only during emergencies where the primary fuel is not
available.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 11
-------
Emissions means air pollutants exhausted from a unit or source into the atmosphere, as
measured, recorded, and reported to the Administrator by the designated representative and
as determined by the Administrator, in accordance with the emissions monitoring
requirements of part 75 of this chapter.
Environmental Appeals Board means the three-member board established pursuant to
§1.25(e) of this chapter and authorized to hear appeals pursuant to part 78 of this chapter.
EPA means the United States Environmental Protection Agency.
EPA protocol gas means a calibration gas mixture prepared and analyzed according to
section 2 of the "EPA Traceability Protocol for Assay and Certification of Gaseous
Calibration Standards," September 1997, EPA-600/R-97/121 or such revised procedure as
approved by the Administrator. On and after January 1, 2009, vendors advertising
certification with the EPA Traceability Protocol or distributing gases as "EPA Protocol
Gas" must participate in the EPA Protocol Gas Verification Program. Non-participating
vendors may not use "EPA" in any form of advertising for these products, unless approved
by the Administrator.
EPA Protocol Gas Verification Program means the EPA Protocol Gas audit program
described in Section 2.1.10 of the "EPA Traceability Protocol for Assay and Certification
of Gaseous Calibration Standards," September 1997, EPA-600/R-97/121 (EPA Protocol
Procedure) or such revised procedure as approved by the Administrator.
EPA trial staff means an employee of EPA, whether temporary or permanent, who has been
designated by the Administrator to investigate, litigate, and present evidence, arguments,
and positions of EPA in any evidentiary hearing under part 78 of this chapter. Any EPA or
permitting authority employee, consultant, or contractor who is called as a witness in the
evidentiary hearing by EPA trial staff shall be deemed to be "EPA trial staff'.
Equivalent diameter means a value, calculated using the Equation 1 -1 in section 12.2 of
Method 1 in part 60, appendix A of this chapter, and used to determine the upstream and
downstream distances for locating CEMS or CEMS components in flues or stacks with
rectangular cross sections.
Ex parte communication means any communication, written or oral, relating to the merits of
an adjudicatory proceeding under part 78 of this chapter, that was not originally included or
stated in the administrative record, in a pleading, or in an evidentiary hearing or oral
argument under part 78 of this chapter, between the decisional body and any interested
person outside EPA or any EPA trial staff. Ex parte communication shall not include:
(1) Communication between EPA employees other than between EPA trial staff and a
member of the decisional body; or
(2) Communication between the decisional body and interested persons outside the
Agency, or EPA trial staff, where all parties to the proceeding have received prior written
notice of the proposed communication and are given an opportunity to be present and to
participate therein.
Excepted monitoring system means a monitoring system that follows the procedures and
requirements of §75.15 of this chapter, §75.19 of this chapter, §75.81(b) of this chapter or
of appendix D, or E to part 75 for approved exceptions to the use of continuous emission
monitoring systems.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 12
-------
Excess emissions means:
(1) Any tonnage of sulfur dioxide emitted by an affected unit during a calendar year
that exceeds the Acid Rain emissions limitation for sulfur dioxide for the unit; and
(2) Any tonnage of nitrogen oxide emitted by an affected unit during a calendar year
that exceeds the annual tonnage equivalent of the Acid Rain emissions limitation for
nitrogen oxides applicable to the affected unit taking into account the unit's heat input for
the year.
Existing unit means a unit (including a unit subject to section 111 of the Act) that
commenced commercial operation before November 15, 1990 and that on or after
November 15, 1990 served a generator with nameplate capacity of greater than 25 MWe.
"Existing unit" does not include simple combustion turbines or any unit that on or after
November 15, 1990 served only generators with a nameplate capacity of 25 MWe or less.
Any "existing unit" that is modified, reconstructed, or repowered after November 15, 1990
shall continue to be an "existing unit."
Facility means any institutional, commercial, or industrial structure, installation, plant,
source, or building.
File means to send or transmit a document, information, or correspondence to the official
custody of the person specified to take possession in accordance with the applicable
regulation. Compliance with any "filing" deadline shall be determined by the date that
person receives the document, information, or correspondence.
Flow meter accuracy means the closeness of the measurement made by a flow meter to the
reference value of the fuel flow being measured, expressed as the difference between the
measurement and the reference value.
Flow monitor means a component of the continuous emission monitoring system that
measures the volumetric flow of exhaust gas.
Flue means a conduit or duct through which gases or other matter are exhausted to the
atmosphere.
Flue gas desulfurization system means a type of add-on emission control used to remove
sulfur dioxide from flue gas, commonly referred to as a "scrubber."
Forced outage means the removal of a unit from service due to an unplanned component
failure or other unplanned condition that requires such removal immediately or within 7
days from the onset of the unplanned component failure or condition. For purposes of
§§72.43, 72.91, and 72.92, "forced outage" also includes a partial reduction in the heat
input or electrical output due to an unplanned component failure or other unplanned
condition that requires such reduction immediately or within 7 days from the onset of the
unplanned component failure or condition.
Fossil fuel means natural gas, petroleum, coal, or any form of solid, liquid, or gaseous fuel
derived from such material.
Fossil fuel-fired means the combustion of fossil fuel or any derivative of fossil fuel, alone
or in combination with any other fuel, independent of the percentage of fossil fuel
consumed in any calendar year (expressed in mmBtu).
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 13
-------
Fuel flowmeter QA operating quarter means a unit operating quarter in which the unit
combusts the fuel measured by the fuel flowmeter for at least 168 unit operating hours (as
defined in this section).
Fuel flowmeter system means an excepted monitoring system (as defined in this section)
which provides a continuous record of the flow rate of fuel oil or gaseous fuel, in
accordance with appendix D to part 75 of this chapter. A fuel flowmeter system consists of
one or more fuel flowmeter components, all necessary auxiliary components (e.g.,
transmitters, transducers, etc.), and a data acquisition and handling system (DAHS).
Fuel oil means any petroleum-based fuel (including diesel fuel or petroleum derivatives
such as oil tar) as defined by the American Society for Testing and Materials in ASTM
D396-90a, "Standard Specification for Fuel Oils" (incorporated by reference in §72.13),
and any recycled or blended petroleum products or petroleum by-products used as a fuel
whether in a liquid, solid or gaseous state; provided that for purposes of the monitoring
requirements of part 75 of this chapter, "fuel oil" shall be limited to the petroleum-based
fuels for which applicable ASTM methods are specified in Appendices D, E, or F of part 75
of this chapter.
Fuel supply agreement means a legally binding agreement between a new IPP or a firm
associated with a new IPP and a fuel supplier that establishes the terms and conditions
under which the fuel supplier commits to provide fuel to be delivered to the new IPP.
Fuel usage time means the portion of a clock hour during which a unit combusts a
particular type of fuel. The fuel usage time, in hours, is expressed as a decimal fraction,
with valid values ranging from 0.00 to 1.00.
Future year subaccount means a subaccount in an Allowance Tracking System account,
established by the Administrator pursuant to §73.31 of this chapter, in which allowances are
held for one of the 30 years following the later of 1995 or a current calendar year following
1995.
Gas-fired means:
(1) For all purposes under the Acid Rain Program, except for part 75 of this chapter,
the combustion of:
(1) Natural gas or other gaseous fuel (including coal-derived gaseous fuel), for at least
90.0 percent of the unit's average annual heat input during the previous three calendar years
and for at least 85.0 percent of the annual heat input in each of those calendar years; and
(ii) Any fuel, except coal or solid or liquid coal-derived fuel, for the remaining heat
input, if any.
(2) For purposes of part 75 of this chapter, the combustion of:
(i) Natural gas or other gaseous fuel (including coal-derived gaseous fuel) for at least
90.0 percent of the unit's average annual heat input during the previous three calendar years
and for at least 85.0 percent of the annual heat input in each of those calendar years; and
(ii) Fuel oil, for the remaining heat input, if any.
(3) For purposes of part 75 of this chapter, a unit may initially qualify as gas-fired if the
designated representative demonstrates to the satisfaction of the Administrator that the
requirements of paragraph (2) of this definition are met, or will in the future be met, through
one of the following submissions:
(i) For a unit for which a monitoring plan has not been submitted under §75.62 of this
chapter, the designated representative submits either:
(A) Fuel usage data for the unit for the three calendar years immediately preceding the
date of initial submission of the monitoring plan for the unit under §75.62; or
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 14
-------
(B) If a unit does not have fuel usage data for one or more of the three calendar years
immediately preceding the date of initial submission of the monitoring plan for the unit
under §75.62, the unit's designated fuel usage; all available fuel usage data (including the
percentage of the unit's heat input derived from the combustion of gaseous fuels), beginning
with the date on which the unit commenced commercial operation; and the unit's projected
fuel usage.
(ii) For a unit for which a monitoring plan has already been submitted under §75.62,
that has not qualified as gas-fired under paragraph (3)(i) of this definition, and whose fuel
usage changes, the designated representative submits either:
(A) Three calendar years of data following the change in the unit's fuel usage, showing
that no less than 90.0 percent of the unit's average annual heat input during the previous
three calendar years, and no less than 85.0 percent of the unit's annual heat input during any
one of the previous three calendar years, is from the combustion of gaseous fuels and the
remaining heat input is from the combustion of fuel oil; or
(B) A minimum of 720 hours of unit operating data following the change in the unit's
fuel usage, showing that no less than 90.0 percent of the unit's heat input is from the
combustion of gaseous fuels and the remaining heat input is from the combustion of fuel oil,
and a statement that this changed pattern of fuel usage is considered permanent and is
projected to continue for the foreseeable future.
(iii) If a unit qualifies as gas-fired under paragraph (3)(i) or (ii) of this definition, the
unit is classified as gas-fired as of the date of the submission under such paragraph.
(4) For purposes of part 75 of this chapter, a unit that initially qualifies as gas-fired
under paragraph (3)(i) or (ii) of this definition must meet the criteria in paragraph (2) of this
definition each year in order to continue to qualify as gas-fired. If such a unit combusts
only gaseous fuel and fuel oil but fails to meet such criteria for a given year, the unit no
longer qualifies as gas-fired starting January 1 of the year after the first year for which the
criteria are not met. If such a unit combusts fuel other than gaseous fuel or fuel oil and fails
to meet such criteria in a given year, the unit no longer qualifies as gas-fired starting the day
after the first day for which the criteria are not met. If a unit failing to meet the criteria in
paragraph (2) of this definition initially qualified as a gas-fired unit under paragraph (3) of
this definition, the unit may qualify as a gas-fired unit for a subsequent year only if the
designated representative submits the data specified in paragraph (3)(ii)(A) of this
definition.
Gas manufacturer's intermediate standard (GMIS) means a compressed gas calibration
standard that has been assayed and certified by direct comparison to a standard reference
material (SRM), an SRM-equivalent PRM, a NIST/EPA-approved certified reference
material (CRM), or a NIST traceable reference material (NTRM), in accordance with
section 2.1.2.1 of the "EPA Traceability Protocol for Assay and Certification of Gaseous
Calibration Standards," September 1997, EPA-600/R-97/121.
Gaseous fuel means a material that is in the gaseous state at standard atmospheric
temperature and pressure conditions and that is combusted to produce heat.
General account means an Allowance Tracking System account that is not a unit account.
Generator means a device that produces electricity and was or would have been required to
be reported as a generating unit pursuant to the United States Department of Energy Form
860 (1990 edition).
Generator Output capacity means the full-load continuous rating of a generator under
specific conditions as designed by the manufacturer.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 15
-------
Hearing clerk means an EPA employee designated by the Administrator to establish a
repository for all books, records, documents, and other materials relating to proceedings
under part 78 of this chapter.
Heat input rate means the product (expressed in mmBtu/hr) of the gross calorific value of
the fuel (expressed in mmBtu/mass of fuel) and the fuel feed rate into the combustion
device (expressed in mass of fuel/hr) and does not include the heat derived from preheated
combustion air, recirculated flue gases, or exhaust from other sources.
Hour before and hour after means, for purposes of the missing data substitution procedures
of part 75 of this chapter, the quality-assured hourly S02 or C02 concentration, hourly flow
rate, hourly NOx concentration, hourly moisture, hourly 02 concentration, or hourly NOx
emission rate (as applicable) recorded by a certified monitor during the unit or stack
operating hour immediately before and the unit or stack operating hour immediately after a
missing data period.
Hybrid generation facility means a plant that generates electrical energy derived from a
combination of qualified renewable energy (wind, solar, biomass, or geothermal) and one or
more other energy resources.
Independent auditor means a professional engineer who is not an employee or agent of the
source being audited.
Independent Power Production Facility (IPP) means a source that:
(1) Is nonrecourse project financed, as defined by the Secretary of Energy at 10 CFR
part 715;
(2) Is used for the generation of electricity, eighty percent or more of which is sold at
wholesale; and
(3) Is a new unit required to hold allowances under Title IV of the Clean Air Act; but
only if direct public utility ownership of the equipment comprising the facility does not
exceed 50 percent.
Interested person means any person who submitted written comments or testified at a public
hearing on the draft permit or other matter subject to notice and comment under the Acid
Rain Program or any person who submitted his or her name to the Administrator or the
permitting authority, as appropriate, to be placed on a list of persons interested in such
matter. The Administrator or the permitting authority may update the list of interested
persons from time to time by requesting additional written indication of continued interest
from the persons listed and may delete from the list the name of any person failing to
respond as requested.
Investor-owned utility means a utility that is organized as a tax-paying for-profit business.
Kilowatthour saved or savings means the net savings in electricity use (expressed in Kwh)
that result directly from a utility's energy conservation measures or programs.
Least-cost plan or least-cost planning process means an energy conservation and electric
power planning methodology meeting the requirements of §73.82(a)(4) of this chapter.
Life-of-the-unit, firm power contractual arrangement means a unit participation power
sales agreement under which a utility or industrial customer reserves, or is entitled to
receive, a specified amount or percentage of nameplate capacity and associated energy
generated by any specified generating unit and pays its proportional amount of such unit's
total costs, pursuant to a contract:
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 16
-------
(1) For the life of the unit;
(2) For a cumulative term of no less than 30 years, including contracts that permit an
election for early termination; or
(3) For a period equal to or greater than 25 years or 70 percent of the economic useful
life of the unit determined as of the time the unit was built, with option rights to purchase or
release some portion of the nameplate capacity and associated energy generated by the unit
at the end of the period.
Long-term cold storage means the complete shutdown of a unit intended to last for an
extended period of time (at least two calendar years) where notice for long-term cold
storage is provided under §75.61(a)(7).
Low mass emissions unit means an affected unit that is "gas-fired" or "oil-fired" (as defined
in this section), and that qualifies to use the low mass emissions excepted methodology in
§75.19 of this chapter.
Mail or serve by mail means to submit or serve by means other than personal service.
Maximum potential hourly heat input means an hourly heat input used for reporting
purposes when a unit lacks certified monitors to report heat input. If the unit intends to use
appendix D of part 75 of this chapter to report heat input, this value should be calculated, in
accordance with part 75 of this chapter, using the maximum fuel flow rate and the
maximum gross calorific value. If the unit intends to use a flow monitor and a diluent gas
monitor, this value should be reported, in accordance with part 75 of this chapter, using the
maximum potential flow rate and either the maximum carbon dioxide concentration (in
percent C02) or the minimum oxygen concentration (in percent 02).
Maximum potential NOx emission rate or MER means the emission rate of nitrogen oxides
(in lb/mmBtu) calculated in accordance with section 3 of appendix F to part 75 of this
chapter, using the maximum potential nitrogen oxides concentration (MPC), as defined in
section 2.1.2.1 of appendix A to part 75 of this chapter, and either the maximum oxygen
concentration (in percent 02) or the minimum carbon dioxide concentration (in percent
C02) under all operating conditions of the unit except for unit start-up, shutdown, and
upsets. The diluent cap value, as defined in this section, may be used in lieu of the
maximum 02 or minimum C02 concentration to calculate the MER. As a second
alternative, when the NOx MPC is determined from emission test results or from historical
CEM data, as described in section 2.1.2.1 of appendix A to part 75 of this chapter, quality-
assured diluent gas (i.e., 02 or C02) data recorded concurrently with the MPC may be used
to calculate the MER. For the purposes of §§75.4(f), 75.19(b)(3), and 75.33(c)(7) in part
75 of this chapter and section 2.5 in appendix E to part 75 of this chapter, the MER is
specific to the type of fuel combusted in the unit.
Maximum rated hourly heat input rate means a unit-specific maximum hourly heat input
rate (mmBtu/hr) which is the higher of the manufacturer's maximum rated hourly heat input
rate or the highest observed hourly heat input rate.
Missing data period means the total number of consecutive hours during which any
certified CEMS or approved alternative monitoring system is not providing quality-assured
data, regardless of the reason.
Monitor accuracy means the closeness of the measurement made by a CEMS to the
reference value of the emissions or volumetric flow being measured, expressed as the
difference between the measurement and the reference value.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 17
-------
Monitor operating hour means any unit operating hour or portion thereof over which a
CEMS, or other monitoring system approved by the Administrator under part 75 of this
chapter is operating, regardless of the number of measurements (i.e., data points) collected
during the hour or portion of an hour.
Most stringent federally enforceable emissions limitation means the most stringent
emissions limitation for a given pollutant applicable to the unit, which has been approved
by the Administrator under the Act, whether in a State implementation plan approved
pursuant to title I of the Act, a new source performance standard, or otherwise. To
determine the most stringent emissions limitation for sulfur dioxide, each limitation shall be
converted to lbs/mmBtu, using the appropriate conversion factors in appendix B of this
part; provided that for determining the most stringent emissions limitation for sulfur dioxide
for 1985, each limitation shall also be annualized, using the appropriate annualization
factors in appendix A of this part.
Multi-header generator means a generator served by ductwork from more than one unit.
Multi-header unit means a unit with ductwork serving more than one generator.
Multiple stack configuration refers to an exhaust configuration in which the flue gases from
a particular unit discharge to the atmosphere through two or more stacks. The term also
refers to a unit for which emissions are monitored in two or more ducts leading to the
exhaust stack, in lieu of monitoring at the stack.
Nameplate capacity means the maximum electrical generating output (expressed in MWe)
that a generator can sustain over a specified period of time when not restricted by seasonal
or other deratings, as listed in the NADB under the data field "NAMECAP" if the generator
is listed in the NADB or as measured in accordance with the United States Department of
Energy standards if the generator is not listed in the NADB.
National Allowance Data Base or NADB means the data base established by the
Administrator under section 402(4)(C) of the Act.
Natural gas means a naturally occurring fluid mixture of hydrocarbons (e.g., methane,
ethane, or propane) produced in geological formations beneath the Earth's surface that
maintains a gaseous state at standard atmospheric temperature and pressure under ordinary
conditions. Natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic
feet. Additionally, natural gas must either be composed of at least 70 percent methane by
volume or have a gross calorific value between 950 and 1100 Btu per standard cubic foot.
Natural gas does not include the following gaseous fuels: landfill gas, digester gas, refinery
gas, sour gas, blast furnace gas, coal-derived gas, producer gas, coke oven gas, or any
gaseous fuel produced in a process which might result in highly variable sulfur content or
heating value.
NERC region means the North American Electric Reliability Council region or, if any,
subregion.
Net income neutrality means, in the case of energy conservation measures undertaken by an
investor-owned utility whose rates are regulated by a State utility regulatory authority, rates
and charges established by the State utility regulatory authority that ensure that the net
income earned by the utility on its State-jurisdictional equity investment will be no lower as
a consequence of its expenditures on cost-effective qualified energy conservation measures
and any associated lost sales than it would have been had the utility not made such
expenditures, or that the State utility regulatory authority has implemented a ratemaking
approach designed to meet this objective.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 18
-------
New independent power production facility or new IPP means a unit that:
(1) Commences commercial operation on or after November 15, 1990;
(2) Is nonrecourse project-financed, as defined in 10 CFR part 715;
(3) Sells 80% of electricity generated at wholesale; and
(4) Does not sell electricity to any affiliate or, if it does, demonstrates it cannot obtain
the required allowances from such an affiliate.
New unit means a unit that commences commercial operation on or after November 15,
1990, including any such unit that serves a generator with a nameplate capacity of 25 MWe
or less or that is a simple combustion turbine.
Ninetieth (90th) percentile means a value that would divide an ordered set of increasing
values so that at least 90 percent are less than or equal to the value and at least 10 percent
are greater than or equal to the value.
Ninety-fifth (95th) percentile means a value that would divide an ordered set of increasing
values so that at least 95 percent of the set are less than or equal to the value and at least 5
percent are greater than or equal to the value.
NIST/EPA-approved certified reference material or NIST/EPA-approved CRM means a
calibration gas mixture that has been approved by EPA and the National Institutes of
Standards and Technologies (NIST) as having specific known chemical or physical
property values certified by a technically valid procedure as evidenced by a certificate or
other documentation issued by a certifying standard-setting body.
NIST traceable elemental Hg standards means either:
(1) Compressed gas cylinders having known concentrations of elemental Hg, which
have been prepared according to the "EPA Traceability Protocol for Assay and
Certification of Gaseous Calibration Standards"; or
(2) Calibration gases having known concentrations of elemental Hg, produced by a
generator that fully meets the performance requirements of the "EPA Traceability Protocol
for Qualification and Certification of Elemental Mercury Gas Generators."
NIST traceable reference material (NTRM) means a calibration gas mixture tested by and
certified by the National Institutes of Standards and Technologies (NIST) to have a certain
specified concentration of gases. NTRMs may have different concentrations from those of
standard reference materials.
NIST traceable source of oxidized Hg means a generator that: is capable of providing
known concentrations of vapor phase mercuric chloride (HgCl2), and that fully meets the
performance requirements of the "EPA Traceability Protocol for Qualification and
Certification of Oxidized Mercury Gas Generators."
Offset plan means a plan pursuant to part 77 of this chapter for offsetting excess emissions
of sulfur dioxide that have occurred at an affected unit in any calendar year.
Oil-fired means:
(1) For all purposes under the Acid Rain Program, except part 75 of this chapter, the
combustion of:
(i) Fuel oil for more than 10.0 percent of the average annual heat input during the
previous three calendar years or for more than 15.0 percent of the annual heat input during
any one of those calendar years; and
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 19
-------
(ii) Any solid, liquid or gaseous fuel (including coal-derived gaseous fuel), other than
coal or any other coal-derived solid or liquid fuel, for the remaining heat input, if any.
(2) For purposes of part 75 of this chapter, combustion of only fuel oil and gaseous
fuels, provided that the unit involved does not meet the definition of gas-fired.
Opacity means the degree to which emissions reduce the transmission of light and obscure
the view of an object in the background.
Operating when referring to a combustion or process source seeking entry into the Opt-in
Program, means that the source had documented consumption of fuel input for more than
876 hours in the 6 months immediately preceding the submission of a combustion source's
opt-in application under §74.16(a) of this chapter.
Operating permit means a permit issued under part 70 of this chapter and any other
regulations implementing title V of the Act.
Opt in or opt into means to elect to become an affected unit under the Acid Rain Program
through the issuance of the final effective opt-in permit under §74.14 of this chapter.
Opt-in permit means the legally binding written document that is contained within the Acid
Rain permit and sets forth the requirements under part 74 of this chapter for a combustion
source or a process source that opts into the Acid Rain Program.
Opt-in source means a combustion source or process source that has elected to become an
affected unit under the Acid Rain Program and whose opt-in permit has been issued and is
in effect.
Out-of-control period means any period:
(1) Beginning with the hour corresponding to the completion of a daily calibration
error, linearity check, or quality assurance audit that indicates that the instrument is not
measuring and recording within the applicable performance specifications; and
(2) Ending with the hour corresponding to the completion of an additional calibration
error, linearity check, or quality assurance audit following corrective action that
demonstrates that the instrument is measuring and recording within the applicable
performance specifications.
Oversubscription payment deadline means 30 calendar days prior to the allowance transfer
deadline.
Owner means any of the following persons:
(1) Any holder of any portion of the legal or equitable title in an affected unit or in a
combustion source or process source; or
(2) Any holder of a leasehold interest in an affected unit or in a combustion source or
process source; or
(3) Any purchaser of power from an affected unit or from a combustion source or
process source under a life-of-the-unit, firm power contractual arrangement as the term is
defined herein and used in section 408(i) of the Act. However, unless expressly provided
for in a leasehold agreement, owner shall not include a passive lessor, or a person who has
an equitable interest through such lessor, whose rental payments are not based, either
directly or indirectly, upon the revenues or income from the affected unit; or
(4) With respect to any Allowance Tracking System general account, any person
identified in the submission required by §73.31(c) of this chapter that is subject to the
binding agreement for the authorized account representative to represent that person's
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 20
-------
ownership interest with respect to allowances.
Owner or operator means any person who is an owner or who operates, controls, or
supervises an affected unit, affected source, combustion source, or process source and shall
include, but not be limited to, any holding company, utility system, or plant manager of an
affected unit, affected source, combustion source, or process source.
Ozone nonattainment area means an area designated as a nonattainment area for ozone
under subpart C of part 81 of this chapter.
Ozone season means the period of time beginning May 1 of a year and ending on
September 30 of the same year, inclusive.
Ozone transport region means the ozone transport region designated under Section 184 of
the Act.
Peaking unit means:
(1) A unit that has:
(1) An average capacity factor of no more than 10.0 percent during the previous three
calendar years and
(ii) A capacity factor of no more than 20.0 percent in each of those calendar years.
(2) For purposes of part 75 of this chapter, a unit may initially qualify as a peaking unit
if the designated representative demonstrates to the satisfaction of the Administrator that the
requirements of paragraph (1) of this definition are met, or will in the future be met, through
one of the following submissions:
(i) For a unit for which a monitoring plan has not been submitted under §75.62, the
designated representative submits either:
(A) Capacity factor data for the unit for the three calendar years immediately preceding
the date of initial submission of the monitoring plan for the unit under §75.62; or
(B) If a unit does not have capacity factor data for one or more of the three calendar
years immediately preceding the date of initial submission of the monitoring plan for the
unit under §75.62, all available capacity factor data, beginning with the date on which the
unit commenced commercial operation; and projected capacity factor data.
(ii) For a unit for which a monitoring plan has already been submitted under §75.62,
that has not qualified as a peaking unit under paragraph (2)(i) of this definition, and where
capacity factor changes, the designated representative submits either:
(A) Three calendar years of data following the change in the unit's capacity factor
showing an average capacity factor of no more than 10.0 percent during the three previous
calendar years and a capacity factor of no more than 20.0 percent in each of those calendar
years; or
(B) One calendar year of data following the change in the unit's capacity factor
showing a capacity factor of no more than 10.0 percent and a statement that this changed
pattern of operation resulting in a capacity factor less than 10.0 percent is considered
permanent and is projected to continue for the foreseeable future.
(3) For purposes of part 75 of this chapter, a unit that initially qualifies as a peaking
unit must meet the criteria in paragraph (1) of this definition each year in order to continue
to qualify as a peaking unit. If such a unit fails to meet such criteria for a given year, the
unit no longer qualifies as a peaking unit starting January 1 of the year after the year for
which the criteria are not met. If a unit failing to meet the criteria in paragraph (1) of this
definition initially qualified as a peaking unit under paragraph (2) of this definition, the unit
may qualify as a peaking unit for a subsequent year only if the designated representative
submits the data specified in paragraph (2)(ii)(A) of this definition.
(4) A unit required to comply with the provisions of subpart H of part 75 of this
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 21
-------
chapter, under a State or Federal NOx mass emissions reduction program, may, pursuant to
§75.74(c)(l 1) in part 75 of this chapter, qualify as a peaking unit on an ozone season basis
rather than an annual basis, if the owner or operator reports NOx mass emissions and heat
input data only during the ozone season.
Permit revision means a permit modification, fast track modification, administrative permit
amendment, or automatic permit amendment, as provided in subpart H of this part.
Permitting authority means either:
(1) When the Administrator is responsible for administering Acid Rain permits under
subpart G of this part, the Administrator or a delegatee agency authorized by the
Administrator; or
(2) The State air pollution control agency, local agency, other State agency, or other
agency authorized by the Administrator to administer Acid Rain permits under subpart G of
this part and part 70 of this chapter.
Person includes an individual, corporation, partnership, association, State, municipality,
political subdivision of a State, any agency, department, or instrumentality of the United
States, and any officer, agent, or employee thereof.
Phase I means the Acid Rain Program period beginning January 1, 1995 and ending
December 31, 1999.
Phase I unit means any affected unit, except an affected unit under part 74 of this chapter,
that is subject to an Acid Rain emissions reduction requirement or Acid Rain emissions
limitation beginning in Phase I; or any unit exempt under §72.8 that, but for such
exemption, would be subject to an Acid Rain emissions reduction requirement or Acid Rain
emissions limitation beginning in Phase I.
Phase II means the Acid Rain Program period beginning January 1, 2000, and continuing
into the future thereafter.
Phase II unit means any affected unit, except an affected unit under part 74 of this chapter,
that is subject to an Acid Rain emissions reduction requirement or Acid Rain emissions
limitation during Phase II only.
Pipeline natural gas means a naturally occurring fluid mixture of hydrocarbons (e.g.,
methane, ethane, or propane) produced in geological formations beneath the Earth's surface
that maintains a gaseous state at standard atmospheric temperature and pressure under
ordinary conditions, and which is provided by a supplier through a pipeline. Pipeline
natural gas contains 0.5 grains or less of total sulfur per 100 standard cubic feet.
Additionally, pipeline natural gas must either be composed of at least 70 percent methane
by volume or have a gross calorific value between 950 and 1100 Btu per standard cubic
foot.
Pollutant concentration monitor means that component of the continuous emission
monitoring system that measures the concentration of a pollutant in a unit's flue gas.
Potential electrical output capacity means the MWe capacity rating for the units which
shall be equal to 33 percent of the maximum design heat input capacity of the steam
generating unit, as calculated according to appendix D of part 72.
Power distribution system means the portion of an electricity grid owned or operated by a
utility that is dedicated to delivering electric energy to customers.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 22
-------
Power purchase commitment means a commitment or obligation of a utility to purchase
electric power from a facility pursuant to:
(1) A power sales agreement;
(2) A State regulatory authority order requiring a utility to:
(i) Enter into a power sales agreement with the facility;
(ii) Purchase from the facility; or
(iii) Enter into arbitration concerning the facility for the purpose of establishing terms
and conditions of the utility's purchase of power;
(3) A letter of intent or similar instrument committing to purchase power (actual
electrical output or generator output capacity) from the source at a previously offered or
lower price and a power sales agreement applicable to the source is executed within the
time frame established by the terms of the letter of intent but no later than November 15,
1993 or, where the letter of intent does not specify a time frame, a power sale agreement
applicable to the source is executed on or before November 15, 1993; or
(4) A utility competitive bid solicitation that has resulted in the selection of the
qualifying facility or independent power production facility as the winning bidder.
Power sales agreement is a legally binding agreement between a QF, IPP, new IPP, or firm
associated with such facility and a regulated electric utility that establishes the terms and
conditions for the sale of power from the facility to the utility.
Presiding Officer means an Administrative Law Judge appointed under 5 U.S.C. 3105 and
designated to preside at a hearing in an appeal under part 78 of this chapter or an EPA
lawyer designated to preside at any such hearing under §78.6(b)(3)(ii) of this chapter.
Primary fuel or primary fuel supply means the main fuel type (expressed in mmBtu)
consumed by an affected unit for the applicable calendar year.
Probationary calibration error test means an on-line calibration error test performed in
accordance with section 2.1.1 of appendix B to part 75 of this chapter that is used to initiate
a conditionally valid data period.
Proposed Acid Rain permit or proposed permit means, in the case of a State operating
permit program, the version of an Acid Rain permit that the permitting authority submits to
the Administrator after the public comment period, but prior to completion of the EPA
permit review period, as provided for in part 70 of this chapter.
QA operating quarter means a calendar quarter in which there are at least 168 unit
operating hours (as defined in this section) or, for a common stack or bypass stack, a
calendar quarter in which there are at least 168 stack operating hours (as defined in this
section).
Qualified Individual means an individual who meets the requirements as described in
ASTM D7036-04 "Standard Practice for Competence of Air Emission Testing Bodies"
(incorporated by reference under §75.6 of this part).
Qualifying facility (QF) means a "qualifying small power production facility" within the
meaning of section 3(17)(C) of the Federal Power Act or a "qualifying cogeneration
facility" within the meaning of section 3(18)(B) of the Federal Power Act.
Qualifying Phase I technology means a technological system of continuous emission
reduction that is demonstrated to achieve a ninety (90) percent (or greater) reduction in
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 23
-------
emissions of sulfur dioxide from the emissions that would have resulted from the use of
fossil fuels that were not subject to treatment prior to combustion, as provided in §72.42.
Qualifying power purchase commitment means a power purchase commitment in effect as
of November 15, 1990 without regard to changes to that commitment so long as:
(1) The identity of the electric output purchaser; or
(2) The identity of the steam purchaser and the location of the facility, remain
unchanged as of the date the facility commences commercial operation; and
(3) The terms and conditions of the power purchase commitment are not changed in
such a way as to allow the costs of compliance with the Acid Rain Program to be shifted to
the purchaser.
Qualifying repowering technology means:
(1) Replacement of an existing coal-fired boiler with one of the following clean coal
technologies: Atmospheric or pressurized fluidized bed combustion, integrated gasification
combined cycle, magnetohydrodynamics, direct and indirect coal-fired turbines, integrated
gasification fuel cells, or as determined by the Administrator, in consultation with the
Secretary of Energy, a derivative of one or more of these technologies, and any other
technology capable of controlling multiple combustion emissions simultaneously with
improved boiler or generation efficiency and with significantly greater waste reduction
relative to the performance of technology in widespread commercial use as of the date of
enactment of the Clean Air Act Amendments of 1990; or
(2) Any oil- or gas-fired unit that has been awarded clean coal technology
demonstration funding as of January 1, 1991, by the Department of Energy.
Quality-assured monitor operating hour means any unit operating hour or portion thereof
over which a certified CEMS, or other monitoring system approved by the Administrator
under part 75 of this chapter, is operating:
(1) Within the performance specifications set forth in part 75, appendix A of this
chapter and the quality assurance/quality control procedures set forth in part 75, appendix B
of this chapter, without unscheduled maintenance, repair, or adjustment; and
(2) In accordance with §75.10(d), (e), and (f) of this chapter.
Receive or receipt of means the date the Administrator or a permitting authority comes into
possession of information or correspondence (whether sent in writing or by authorized
electronic transmission), as indicated in an official correspondence log, or by a notation
made on the information or correspondence, by the Administrator or the permitting
authority in the regular course of business.
Recordation, record, or recorded means, with regard to allowances, the transfer of
allowances by the Administrator from one Allowance Tracking System account or
subaccount to another.
Reduced utilization means a reduction, during any calendar year in Phase I, in the heat input
(expressed in mmBtu for the calendar year) at a Phase I unit below the unit's baseline,
where such reduction subjects the unit to the requirement to submit a reduced utilization
plan under §72.43; or, in the case of an opt-in source, means a reduction in the average
utilization, as specified in §74.44 of this chapter, of an opt-in source below the opt-in
source's baseline.
Reference method means any direct test method of sampling and analyzing for an air
pollutant as specified in part 60, appendix A of this chapter.
Reference value or reference signal means the known concentration of a calibration gas, the
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 24
-------
known value of an electronic calibration signal, or the known value of any other
measurement standard approved by the Administrator, assumed to be the true value for the
pollutant or diluent concentration or volumetric flow being measured.
Relative accuracy means a statistic designed to provide a measure of the systematic and
random errors associated with data from continuous emission monitoring systems, and is
expressed as the absolute mean difference between the pollutant or moisture concentration
or volumetric flow measured by the pollutant concentration or flow monitor or moisture
monitor and the value determined by the applicable reference method(s) plus the 2.5
percent error confidence coefficient of a series of tests divided by the mean of the reference
method tests in accordance with part 75 of this chapter.
Replacement unit means an affected unit replacing the thermal energy provided by an opt-in
source, where both the affected unit and the opt-in source are governed by a thermal energy
plan.
Research gas mixture (RGM) means a calibration gas mixture developed by agreement of a
requestor and NIST that NIST analyzes and certifies as "NIST traceable." RGMs may have
concentrations different from those of standard reference materials.
Schedule of compliance means an enforceable sequence of actions, measures, or operations
designed to achieve or maintain compliance, or correct non-compliance, with an applicable
requirement of the Acid Rain Program, including any applicable Acid Rain permit
requirement.
Secretary of Energy means the Secretary of the United States Department of Energy or the
Secretary's duly authorized representative.
Serial number means, when referring to allowances, the unique identification number
assigned to each allowance by the Administrator, pursuant to §73.34(d) of this chapter.
Simple combustion turbine means a unit that is a rotary engine driven by a gas under
pressure that is created by the combustion of any fuel. This term includes combined cycle
units without auxiliary firing. This term excludes combined cycle units with auxiliary
firing, unless the unit did not use the auxiliary firing from 1985 through 1987 and does not
use auxiliary firing at any time after November 15, 1990.
Site lease, as used in part 73, subpart E of this chapter, means a legally-binding agreement
signed between a new IPP or a firm associated with a new IPP and a site owner that
establishes the terms and conditions under which the new IPP or the firm associated with
the new IPP has the binding right to utilize a specific site for the purposes of operating or
constructing the new IPP.
Small diesel refinery means a domestic motor diesel fuel refinery or portion of a refinery
that, as an annual average of calendar years 1988 through 1990 and as reported to the
Department of Energy on Form 810, had bona fide crude oil throughput less than
18,250,000 barrels per year, and the refinery or portion of a refinery is owned or controlled
by a refiner with a total combined bona fide crude oil throughput of less than 50,187,500
barrels per year.
Solid waste incinerator means a source as defined in section 129(g)(1) of the Act.
Sorbent trap monitoring system means the equipment required by part 75 of this chapter for
the continuous monitoring of Hg emissions, using paired sorbent traps containing iodated
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 25
-------
charcoal (IC) or other suitable reagents. This excepted monitoring system consists of a
probe, the paired sorbent traps, an umbilical line, moisture removal components, an air tight
sample pump, a gas flow meter, and an automated data acquisition and handling system.
The monitoring system samples the stack gas at a rate proportional to the stack gas
volumetric flowrate. The sampling is a batch process. Using the sample volume measured
by the gas flow meter and the results of the analyses of the sorbent traps, the average Hg
concentration in the stack gas for the sampling period is determined, in units of micrograms
per dry standard cubic meter (|ig/dscm). Mercury mass emissions for each hour in the
sampling period are calculated using the average Hg concentration for that period, in
conjunction with contemporaneous hourly measurements of the stack gas flow rate,
corrected for the stack gas moisture content.
Source means any governmental, institutional, commercial, or industrial structure,
installation, plant, building, or facility that emits or has the potential to emit any regulated
air pollutant under the Act. For purposes of section 502(c) of the Act, a "source", including
a "source" with multiple units, shall be considered a single "facility."
Span means the highest pollutant or diluent concentration or flow rate that a monitor
component is required to be capable of measuring under part 75 of this chapter.
Specialty gas producer means an organization that prepares and analyzes compressed gas
mixtures for use as calibration gases and that offers the mixtures for sale to end users or to
third-party vendors for resale to end users.
Spot allowance means an allowance that may be used for purposes of compliance with a
unit's Acid Rain sulfur dioxide emissions limitation requirements beginning in the year in
which the allowance is offered for sale.
Spot auction means an auction of a spot allowance.
Spot sale means a sale of a spot allowance.
Stack means a structure that includes one or more flues and the housing for the flues.
Stack operating hour means a clock hour during which flue gases flow through a particular
stack or duct (either for the entire hour or for part of the hour) while the associated unit(s)
are combusting fuel.
Stack operating time means the portion of a clock hour during which flue gases flow
through a particular stack or duct while the associated unit(s) are combusting fuel. The
stack operating time, in hours, is expressed as a decimal fraction, with valid values ranging
from 0.00 to 1.00.
Standard conditions means 68 °F at 1 atm (29.92 in. of mercury).
Standard reference material or SRM means a calibration gas mixture issued and certified by
NIST as having specific known chemical or physical property values.
Standard reference material-equivalent compressed gas primary reference material (SRM-
equivalent PRM) means those gas mixtures listed in a declaration of equivalence in
accordance with section 2.1.2 of the "EPA Traceability Protocol for Assay and Certification
of Gaseous Calibration Standards," September 1997, EPA-600/R-97/121.
State means one of the 48 contiguous States and the District of Columbia, any non-federal
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 26
-------
authorities in or including such States or the District of Columbia (including local agencies,
interstate associations, and State-wide agencies), and any eligible Indian tribe in an area in
such State or the District of Columbia. The term "State" shall have its conventional
meaning where such meaning is clear from the context.
State operating permit program means an operating permit program that the Administrator
has approved under part 70 of this chapter.
Stationary gas turbine means a turbine that is not self-propelled and that combusts natural
gas, other gaseous fuel with a total sulfur content no greater than the total sulfur content of
natural gas, or fuel oil in order to heat inlet combustion air and thereby turn a turbine in
addition to or instead of producing steam or heating water.
Steam sales agreement is a legally binding agreement between a QF, IPP, new IPP, or firm
associated with such facility and an industrial or commercial establishment requiring steam
that establishes the terms and conditions under which the facility will supply steam to the
establishment.
Submit or serve means to send or transmit a document, information, or correspondence to
the person specified in accordance with the applicable regulation:
(1) In person;
(2) By United States Postal Service; or
(3) By other equivalent means of dispatch, or transmission, and delivery. Compliance
with any "submission", "service", or "mailing" deadline shall be determined by the date of
dispatch, transmission, or mailing and not the date of receipt.
Substitute data means emissions or volumetric flow data provided to assure 100 percent
recording and reporting of emissions when all or part of the continuous emission
monitoring system is not functional or is operating outside applicable performance
specifications.
Substitution unit means an affected unit, other than a unit under section 410 of the Act, that
is designated as a Phase I unit in a substitution plan under §72.41.
Sulfur-free generation means the generation of electricity by a process that does not have
any emissions of sulfur dioxide, including hydroelectric, nuclear, solar, or wind generation.
A "sulfur-free generator" is a generator that is located in one of the 48 contiguous States or
the District of Columbia and produces "sulfur-free generation."
Supply-side measure means a measure to improve the efficiency of the generation,
transmission, or distribution of electricity, implemented by a utility in connection with its
operations or facilities to provide electricity to its customers, and includes the measures set
forth in part 73, appendix A, section 2 of this chapter.
Thermal energy means the thermal output produced by a combustion source used directly
as part of a manufacturing process but not used to produce electricity.
Ton or tonnage means any "short ton" (i.e., 2,000 pounds). For the purpose of determining
compliance with the Acid Rain emissions limitations and reduction requirements, total tons
for a year shall be calculated as the sum of all recorded hourly emissions (or the tonnage
equivalent of the recorded hourly emissions rates) in accordance with part 75 of this
chapter, with any remaining fraction of a ton equal to or greater than 0.50 ton deemed to
equal one ton and any fraction of a ton less than 0.50 ton deemed not to equal any ton.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 27
-------
Total planned net output capacity means the planned generator output capacity, excluding
that portion of the electrical power which is designed to be used at the power production
facility, as specified under one or more qualifying power purchase commitments or
contemporaneous documents as of November 15, 1990; "Total installed net output
capacity" shall be the generator output capacity, excluding that portion of the electrical
power actually used at the power production facility, as installed.
Transfer unit means a Phase I unit that transfers all or part of its Phase I emission reduction
obligations to a control unit designated pursuant to a Phase I extension plan under §72.42.
Underutilization means a reduction, during any calendar year in Phase I, of the heat input
(expressed in mmBtu for the calendar year) at a Phase I unit below the unit's baseline.
Unit means a fossil fuel-fired combustion device.
Unit account means an Allowance Tracking System account, established by the
Administrator for an affected unit pursuant to §73.31 (a) or (b) of this chapter.
Unit load means the total (i.e., gross) output of a unit or source in any calendar year (or
other specified time period) produced by combusting a given heat input of fuel, expressed
in terms of:
(1) The total electrical generation (MWe) for use within the plant and for sale; or
(2) In the case of a unit or source that uses part of its heat input for purposes other than
electrical generation, the total steam pressure (psia) produced by the unit or source.
Unit operating day means a calendar day in which a unit combusts any fuel.
Unit operating hour means a clock hour during which a unit combusts any fuel, either for
part of the hour or for the entire hour.
Unit operating quarter means a calendar quarter in which a unit combusts any fuel.
Unit operating time means the portion of a clock hour during which a unit combusts any
fuel. The unit operating time, in hours, is expressed as a decimal fraction, with valid values
ranging from 0.00 to 1.00.
Utility means any person that sells electricity.
Utility competitive bid solicitation is a public request from a regulated utility for offers to
the utility for meeting future generating needs. A qualifying facility, independent power
production facility, or new IPP may be regarded as having been "selected" in such
solicitation if the utility has named the facility as a project with which the utility intends to
negotiate a power sales agreement.
Utility regulatory authority means an authority, board, commission, or other entity (limited
to the local-, State-, or federal-level, whenever so specified) responsible for overseeing the
business operations of utilities located within its jurisdiction, including, but not limited to,
utility rates and charges to customers.
Utility system means all interconnected units and generators operated by the same utility
operating company.
Utility unit means a unit owned or operated by a utility:
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 28
-------
(1) That serves a generator in any State that produces electricity for sale, or
(2) That during 1985, served a generator in any State that produced electricity for sale.
(3) Notwithstanding paragraphs (1) and (2) of this definition, a unit that was in
operation during 1985, but did not serve a generator that produced electricity for sale
during 1985, and did not commence commercial operation on or after November 15, 1990
is not a utility unit for purposes of the Acid Rain Program.
(4) Notwithstanding paragraphs (1) and (2) of this definition, a unit that cogenerates
steam and electricity is not a utility unit for purposes of the Acid Rain Program, unless the
unit is constructed for the purpose of supplying, or commences construction after
November 15, 1990 and supplies, more than one-third of its potential electrical output
capacity and more than 25 MWe output to any power distribution system for sale.
Utilization means the heat input (expressed in mmBtu/time) for a unit.
Very low sulfur fuel means either:
(1) A fuel with a total sulfur content no greater than 0.05 percent sulfur by weight;
(2) Natural gas or pipeline natural gas, as defined in this section; or
(3) Any gaseous fuel with a total sulfur content no greater than 20 grains of sulfur per
100 standard cubic feet.
Volumetric flow means the rate of movement of a specified volume of gas past a cross-
sectional area (e.g., cubic feet per hour).
Zero air material means either:
(1) A calibration gas certified by the gas vendor not to contain concentrations of S02,
NOx, or total hydrocarbons above 0.1 parts per million (ppm), a concentration of CO above
1 ppm, or a concentration of C02 above 400 ppm;
(2) Ambient air conditioned and purified by a CEMS for which the CEMS
manufacturer or vendor certifies that the particular CEMS model produces conditioned gas
that does not contain concentrations of S02, NOx, or total hydrocarbons above 0.1 ppm, a
concentration of CO above 1 ppm, or a concentration of C02 above 400 ppm;
(3) For dilution-type CEMS, conditioned and purified ambient air provided by a
conditioning system concurrently supplying dilution air to the CEMS; or
(4) A multicomponent mixture certified by the supplier of the mixture that the
concentration of the component being zeroed is less than or equal to the applicable
concentration specified in paragraph (1) of this definition, and that the mixture's other
components do not interfere with the CEM readings.
§ 72.3 § 72.3 Measurements, abbreviations, and acronyms.
Measurements, abbreviations, and acronyms used in this part are defined as follows:
acfh - actual cubic feet per hour,
atm - atmosphere,
bbl - barrel.
Btu - British thermal unit.
°C - degree Celsius (centigrade).
CEMS - continuous emission monitoring system.
cfm - cubic feet per minute.
cm - centimeter.
dcf - dry cubic feet.
DOE - Department of Energy.
dscf - dry cubic feet at standard conditions.
dscfh - dry cubic feet per hour at standard conditions.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 29
-------
EIA - Energy Information Administration.
eq - equivalent.
°F - degree Fahrenheit.
fps - feet per second.
gal - gallon.
hr - hour.
in - inch.
°K - degree Kelvin.
kacfm - thousands of cubic feet per minute at actual conditions,
kscfh - thousands of cubic feet per hour at standard conditions.
Kwh - kilowatt hour,
lb - pounds,
m - meter.
mmBtu - million Btu.
min - minute.
mol. wt. - molecular weight.
MWe - megawatt electrical.
MWge - gross megawatt electrical.
NIST-National Institute of Standards and Technology
ppm - parts per million.
psi - pounds per square inch.
°R - degree Rankine.
RATA - relative accuracy test audit.
scf - cubic feet at standard conditions.
scfh - cubic feet per hour at standard conditions.
sec - second.
std - at standard conditions.
C02 - carbon dioxide.
NOx - nitrogen oxides.
02 - oxygen.
THC - total hydrocarbon content.
S02 - sulfur dioxide.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 30
-------
PART 75-CONTINUOUS EMISSION MONITORING
Authority: 42 U.S.C. 7601, 7651k, and 7651k note.
Subpart A — General
§ 75.1 § 75.1 Purpose and scope.
§ 75.1(a) (a) Purpose. The purpose of this part is to establish requirements for the monitoring,
recordkeeping, and reporting of sulfur dioxide (S02), nitrogen oxides (NOx), and carbon
dioxide (C02) emissions, volumetric flow, and opacity data from affected units under the Acid
Rain Program pursuant to Sections 412 and 821 of the CAA, 42 U.S.C. 7401-7671q as
amended by Public Law 101-549 (November 15, 1990) [the Act]. In addition, this part sets
forth provisions for the monitoring, recordkeeping, and reporting of NOx mass emissions with
which EPA, individual States, or groups of States may require sources to comply in order to
demonstrate compliance with a NOx mass emission reduction program, to the extent these
provisions are adopted as requirements under such a program.
§75.1(b) do) Scope.
(1) The regulations established under this part include general requirements for the
installation, certification, operation, and maintenance of continuous emission or opacity
monitoring systems and specific requirements for the monitoring of S02 emissions, volumetric
flow, NOx emissions, opacity, C02 emissions and S02 emissions removal by qualifying Phase I
technologies. Specifications for the installation and performance of continuous emission
monitoring systems, certification tests and procedures, and quality assurance tests and
procedures are included in appendices A and B to this part. Criteria for alternative monitoring
systems and provisions to account for missing data from certified continuous emission
monitoring systems or approved alternative monitoring systems are also included in the
regulation.
(2) Statistical estimation procedures for missing data are included in appendix C to this
part. Optional protocols for estimating S02 mass emissions from gas-fired or oil-fired units
and NOx emissions from gas-fired peaking or oil-fired peaking units are included in appendices
D and E, respectively, to this part. Requirements for recording and recordkeeping of
monitoring data and for quarterly electronic reporting also are specified. Procedures for
conversion of monitoring data into units of the standard are included in appendix F to this part.
Procedures for the monitoring and calculation of C02 emissions are included in appendix G of
this part.
§ 75.2 § 75.2 Applicability.
§ 75.2(a) (a) Except as provided in paragraphs (b) and (c) of this section, the provisions of this part
apply to each affected unit subject to Acid Rain emission limitations or reduction requirements
for S02 or NOx.
§ 75.2(b) (b) The provisions of this part do not apply to:
(1) A new unit for which a written exemption has been issued under § 72.7 of this chapter
(any new unit that serves one or more generators with total nameplate capacity of 25 MWe or
less and burns only fuels with a sulfur content of 0.05 percent or less by weight may apply to
the Administrator for an exemption); or
(2) Any unit not subject to the requirements of the Acid Rain Program due to operation of
any paragraph of § 72.6(b) of this chapter; or
(3) An affected unit for which a written exemption has been issued under § 72.8 of this
chapter and an exception granted under § 75.67 of this part.
§ 75.2(c) (c) The provisions of this part apply to sources subject to a State or federal NOx mass
emission reduction program, to the extent these provisions are adopted as requirements under
such a program.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 31
-------
(d) The provisions of this part apply to sources subject to a State or Federal mercury (Hg)
mass emission reduction program, to the extent that these provisions are adopted as
requirements under such a program.
§75.3
§ 75.3 General Acid Rain Program provisions.
The provisions of part 72, including the following, shall apply to this part:
(a) § 72.2 (Definitions);
(b) § 72.3 (Measurements, Abbreviations, and Acronyms);
(c) § 72.4 (Federal Authority);
(d) § 72.5 (State Authority);
(e) § 72.6 (Applicability);
(f) § 72.7 (New Unit Exemption);
(g) § 72.8 (Retired Units Exemption);
(h) § 72.9 (Standard Requirements);
(i) § 72.10 (Availability of Information); and
(j) § 72.11 (Computation of Time).
In addition, the procedures for appeals of decisions of the Administrator under this part
are contained in part 78 of this chapter.
§75.4
§ 75.4(a)
§ 75.4 Compliance dates.
(a) The provisions of this part apply to each existing Phase I and Phase II unit on February
10, 1993. For substitution or compensating units that are so designated under the Acid Rain
permit which governs that unit and contains the approved substitution or reduced utilization
plan, pursuant to § 72.41 or § 72.43 of this chapter, the provisions of this part become
applicable upon the issuance date of the Acid Rain permit. For combustion sources seeking to
enter the Opt-in Program in accordance with part 74 of this chapter, the provisions of this part
become applicable upon the submission of an opt-in permit application in accordance with
§ 74.14 of this chapter. The provisions of this part for the monitoring, recording, and reporting
of NOx mass emissions become applicable on the deadlines specified in the applicable State or
federal NOx mass emission reduction program, to the extent these provisions are adopted as
requirements under such a program. In accordance with § 75.20, the owner or operator of each
existing affected unit shall ensure that all monitoring systems required by this part for
monitoring S02, NOx, C02, opacity, moisture and volumetric flow are installed and that all
certification tests are completed no later than the following dates (except as provided in
paragraphs (d) through (i) of this section):
§ 75.4(a)(1)
§ 75.4(a)(2)
(1) For a unit listed in table 1 of § 73.10(a) of this chapter, November 15, 1993.
(2) For a substitution or a compensating unit that is designated under an approved
substitution plan or reduced utilization plan pursuant to § 72.41 or § 72.43 of this chapter, or
for a unit that is designated an early election unit under an approved NOx compliance plan
pursuant to part 76 of this chapter, that is not conditionally approved and that is effective for
1995, the earlier of the following dates:
(i) January 1, 1995; or
(ii) 90 days after the issuance date of the Acid Rain permit (or date of approval of permit
revision) that governs the unit and contains the approved substitution plan, reduced utilization
plan, or NOx compliance plan.
§ 75.4(a)(3)
(3) For either a Phase II unit, other than a gas-fired unit or an oil-fired unit, or a
substitution or compensating unit that is not a substitution or compensating unit under
paragraph (a)(2) of this section: January 1, 1995.
§ 75.4(a)(4)
(4) For a gas-fired Phase II unit or an oil-fired Phase II unit, January 1, 1995, except that
installation and certification tests for continuous emission monitoring systems for NOx and
C02 or excepted monitoring systems for NOx under appendix E or C02 estimation under
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 32
-------
appendix G of this part shall be completed as follows:
(i) For an oil-fired Phase II unit or a gas-fired Phase II unit located in an ozone
nonattainment area or the ozone transport region, not later than July 1, 1995; or
(ii) For an oil-fired Phase II unit or a gas-fired Phase II unit not located in an ozone
nonattainment area or the ozone transport region, not later than January 1, 1996.
§ 75.4(a)(5) (5) For combustion sources seeking to enter the Opt-in Program in accordance with part
74 of this chapter, the expiration date of a combustion source's opt-in permit under § 74.14(e)
of this chapter.
§ 75.4(b) (b) In accordance with § 75.20, the owner or operator of each new affected unit shall
ensure that all monitoring systems required under this part for monitoring of S02, NOx, C02,
opacity, and volumetric flow are installed and all certification tests are completed on or before
the later of the following dates:
(1) January 1, 1995, except that for a gas-fired unit or oil-fired unit located in an ozone
nonattainment area or the ozone transport region, the date for installation and completion of
all certification tests for NOx and C02 monitoring systems shall be July 1, 1995 and for a gas-
fired unit or an oil-fired unit not located in an ozone nonattainment area or the ozone transport
region, the date for installation and completion of all certification tests for NOx and C02
monitoring systems shall be January 1, 1996; or
(2) The earlier of 90 unit operating days or 180 calendar days after the date the unit
commences commercial operation, notice of which date shall be provided under subpart G of
this part.
§ 75.4(c) (c) In accordance with § 75.20, the owner or operator of any unit affected under any
paragraph of § 72.6(a)(3) (ii) through (vii) of this chapter shall ensure that all monitoring
systems required under this part for monitoring of S02, NOx, C02, opacity, and volumetric
flow are installed and all certification tests are completed on or before the later of the
following dates:
(1) January 1, 1995, except that for a gas-fired unit or oil-fired unit located in an ozone
nonattainment area or the ozone transport region, the date for installation and completion of
all certification tests for NOx and C02 monitoring systems shall be July 1, 1995 and for a gas-
fired unit or an oil-fired unit not located in an ozone nonattainment area or the ozone transport
region, the date for installation and completion of all certification tests for NOx and C02
monitoring systems shall be January 1, 1996; or
(2) The earlier of 90 unit operating days or 180 calendar days after the date the unit first
operates after becoming subject to the requirements of the Acid Rain Program, notice of
which date shall be provided under subpart G of this part.
§ 75.4(d) (d) This paragraph, applies to affected units under the Acid Rain Program and to units
subject to a State or Federal pollutant mass emissions reduction program that adopts the
emission monitoring and reporting provisions of this part. In accordance with § 75.20, for an
affected unit which, on the applicable compliance date, is either in long-term cold storage (as
defined in §72.2 of this chapter) or is shut down as the result of a planned outage or a forced
outage, thereby preventing the required continuous monitoring system certification tests from
being completed by the compliance date, the owner or operator shall provide notice of such
unit storage or outage in accordance with §75.61(a)(3) or §75.61(a)(7), as applicable. For the
planned and unplanned unit outages described in this paragraph, the owner or operator shall
ensure that all of the continuous monitoring systems for S02, NOx, C02, Hg, opacity, and
volumetric flow rate required under this part (or under the applicable State or Federal mass
emissions reduction program) are installed and that all required certification tests are
completed no later than 90 unit operating days or 180 calendar days (whichever occurs first)
after the date that the unit recommences commercial operation, notice of which date shall be
provided under §75.61(a)(3) or §75.61(a)(7), as applicable. The owner or operator shall
determine and report S02 concentration, NOx emission rate, C02 concentration, Hg
concentration, and flow rate data (as applicable) for all unit operating hours after the
applicable compliance date until all of the required certification tests are successfully
completed, using either:
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 33
-------
(1) The maximum potential concentration of S02 (as defined in section 2.1.1.1 of
appendix A to this part), the maximum potential NOx emission rate, as defined in § 72.2 of
this chapter, the maximum potential flow rate, as defined in section 2.1.4.1 of appendix A to
this part, the maximum potential Hg concentration, as defined in section 2.1.7.1 of appendix A
to this part, or the maximum potential C02 concentration, as defined in section 2.1.3.1 of
appendix A to this part; or
(2) The conditional data validation provisions of §75.20(b)(3); or
(3) Reference methods under § 75.22(b); or
(4) Another procedure approved by the Administrator pursuant to a petition under §75.66.
§ 75.4(e) (e) In accordance with § 75.20, if the owner or operator of an existing unit completes
construction of a new stack, flue, flue gas desulfurization system or add-on NOx emission
controls after the applicable deadline in paragraph (a) of this section, then the owner or
operator shall ensure that all monitoring systems required under this part for monitoring S02,
NOx, C02, opacity, and volumetric flow are installed on the new stack or duct and all
certification tests are completed not later than 90 unit operating days or 180 calendar days
(whichever occurs first) after the date that emissions first exit to the atmosphere through the
new stack, flue, flue gas desulfurization system or add-on NOx emission controls, notice of
which date shall be provided under subpart G of this part. Until emissions first pass through
the new stack, flue, flue gas desulfurization system or add-on NOx emission controls, the unit
is subject to the appropriate deadline in paragraph (a) of this section. The owner or operator
shall determine and report S02 concentration, NOx emission rate, C02 concentration, and flow
data for all unit operating hours after emissions first pass through the new stack, flue, flue gas
desulfurization system or add-on NOx emission controls until all required certification tests are
successfully completed using either:
(1) The appropriate value for substitution of missing data upon recertification pursuant to
§ 75.20(b)(3); or
(2) Reference methods under § 75.22(b) of this part; or
(3) Another procedure approved by the Administrator pursuant to a petition under
§75.66.
§ 75.4(f) (f) In accordance with § 75.20, the owner or operator of an affected gas-fired or oil-fired
peaking unit, if planning to use appendix E of this part, shall ensure that the required
certification tests for excepted monitoring systems under appendix E are completed for
backup fuel, as defined in § 72.2 of this chapter, no later than 90 unit operating days or 180
calendar days (whichever occurs first) after the date that the unit first combusts the backup
fuel following the certification testing with the primary fuel. If the required testing is
completed by this deadline, the appendix E correlation curve derived from the test results may
be used for reporting data under this part beginning with the first date and hour that the
backup fuel is combusted, provided that the fuel flowmeter for the backup fuel was certified as
of that date and hour. If the required appendix E testing has not been successfully completed
by the compliance date in this paragraph, then, until the testing is completed, the owner or
operator shall report NOx emission rate data for all unit operating hours that the backup fuel is
combusted using either:
(1) The fuel-specific maximum potential NOx emission rate, as defined in § 72.2 of this
chapter; or
(2) Reference methods under § 75.22(b) of this part; or
(3) Another procedure approved by the Administrator pursuant to a petition under
§75.66.
§ 75.4(g) (g) The provisions of this paragraph shall apply unless an owner or operator is exempt
from certifying a fuel flowmeter for use during combustion of emergency fuel under section
2.1.4.3 of appendix D to this part, in which circumstance the provisions of section 2.1.4.3 of
appendix D shall apply. In accordance with § 75.20, whenever the owner or operator of a gas-
fired or oil-fired unit uses an excepted monitoring system under appendix D or E of this part
and combusts emergency fuel as defined in § 72.2 of this chapter, then the owner or operator
shall ensure that a fuel flowmeter measuring emergency fuel is installed and the required
certification tests for excepted monitoring systems are completed by no later than 30 unit
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 34
-------
operating days after the first date after January 1, 1995 that the unit combusts emergency fuel.
For all unit operating hours that the unit combusts emergency fuel after January 1, 1995 until
the owner or operator installs a flowmeter for emergency fuel and successfully completes all
required certification tests, the owner or operator shall determine and report S02 mass
emission data using either:
(1) The maximum potential fuel flow rate, as described in appendix D of this part, and the
maximum sulfur content of the fuel, as described in section 2.1.1.1 of appendix A of this part;
(2) Reference methods under § 75.22(b) of this part; or
(3) Another procedure approved by the Administrator pursuant to a petition under
§75.66.
§ 75.4(h) (h)[Reserved]
§ 75.4(i) (i) In accordance with § 75.20, the owner or operator of each affected unit at which S02
concentration is measured on a dry basis or at which moisture corrections are required to
account for C02 emissions, NOx emission rate in lb/mmBtu, heat input, or NOx mass
emissions for units in a NOx mass reduction program, shall ensure that the continuous
moisture monitoring system required by this part is installed and that all applicable initial
certification tests required under § 75.20(c)(5), (c)(6), or (c)(7) for the continuous moisture
monitoring system are completed no later than the following dates:
(1) April 1, 2000, for a unit that is existing and has commenced commercial operation by
January 2, 2000;
(2) For a new affected unit which has not commenced commercial operation by January 2,
2000, 90 unit operating days or 180 calendar days (whichever occurs first) after the date the
unit commences commercial operation; or
(3) For an existing unit that is shutdown and is not yet operating by April 1, 2000, 90 unit
operating days or 180 calendar days (whichever occurs first) after the date that the unit
recommences commercial operation.
(j) If the certification tests required under paragraph (b) or (c) of this section have not
been completed by the applicable compliance date, the owner or operator shall determine and
report S02 concentration, NOx emission rate, C02 concentration, and flow rate data for all unit
operating hours after the applicable compliance date in this paragraph until all required
certification tests are successfully completed using either:
(1) The maximum potential concentration of S02, as defined in section 2.1.1.1 of
appendix A to this part, the maximum potential NOx emission rate, as defined in § 72.2 of this
chapter, the maximum potential flow rate, as defined in section 2.1.4.1 of appendix A to this
part, or the maximum potential C02 concentration, as defined in section 2.1.3.1 of appendix A
to this part;
(2) Reference methods under § 75.22(b); or
(3) Another procedure approved by the Administrator pursuant to a petition under
§75.66.
§ 75.5 § 75.5 Prohibitions.
§ 75.5(a) (a) A violation of any applicable regulation in this part by the owners or operators or the
designated representative of an affected source or an affected unit is a violation of the Act.
§ 75.5(b) (b) No owner or operator of an affected unit shall operate the unit without complying with
the requirements of §§ 75.2 through 75.75 and appendices A through G to this part.
§ 75.5(c) (c) No owner or operator of an affected unit shall use any alternative monitoring system,
alternative reference method, or any other alternative for the required continuous emission
monitoring system without having obtained the Administrator's prior written approval in
accordance with §§ 75.23, 75.48 and 75.66.
§ 75.5(d) (d) No owner or operator of an affected unit shall operate the unit so as to discharge, or
allow to be discharged, emissions of S02, NOx or C02 to the atmosphere without accounting
for all such emissions in accordance with the provisions of §§ 75.10 through 75.19.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 35
-------
§ 75.5(e)
§ 75.5(f)
§75.6
§ 75.6(a)
§ 75.6(a)(1)
§ 75.6(a)(2)
§ 75.6(a)(3)
§ 75.6(a)(4)
§ 75.6(a)(5)
§ 75.6(a)(6)
§ 75.6(a)(7)
(e) No owner or operator of an affected unit shall disrupt the continuous emission
monitoring system, any portion thereof, or any other approved emission monitoring method,
and thereby avoid monitoring and recording S02, NOx, or C02 emissions discharged to the
atmosphere, except for periods of recertification, or periods when calibration, quality
assurance, or maintenance is performed pursuant to § 75.21 and appendix B of this part.
(f) No owner or operator of an affected unit shall retire or permanently discontinue use of
the continuous emission monitoring system, any component thereof, the continuous opacity
monitoring system, or any other approved emission monitoring system under this part, except
under any one of the following circumstances:
(1) During the period that the unit is covered by an approved retired unit exemption under
§ 72.8 of this chapter that is in effect; or
(2) The owner or operator is monitoring emissions from the unit with another certified
monitoring system or an excepted methodology approved by the Administrator for use at that
unit that provides emissions data for the same pollutant or parameter as the retired or
discontinued monitoring system; or
(3) The designated representative submits notification of the date of recertification testing
of a replacement monitoring system in accordance with §§ 75.20 and 75.61, and the owner or
operator recertifies thereafter a replacement monitoring system in accordance with § 75.20.
§ 75.6 Incorporation by reference.
The materials listed in this section are incorporated by reference in the corresponding
sections noted. These incorporations by reference were approved by the Director of the
Federal Register in accordance with 5 U.S.C. 552(a) and 1 CFR part 51. These materials are
incorporated as they existed on the date of approval, and a notice of any change in these
materials will be published in the FEDERAL REGISTER. The materials are available for
purchase at the corresponding address noted below and are available for inspection at the
Office of the Federal Register, 800 North Capitol Street, NW, Suite 700, Washington, DC, at
the Public Information Reference Unit of the U.S. EPA, 401 M Street, SW, Washington, DC
and at the Library (MD-35), U.S. EPA, Research Triangle Park, North Carolina.
(a) The following materials are available for purchase from the following addresses:
American Society for Testing and Material (ASTM), 100 Barr harbor Drive, P.O. Box C-700,
West Conshohocken, Pennsylvania 19428-2959; and the University Microfilms International
300 North Zeeb Road, Ann Arbor, Michigan 48106.
(1) ASTM D129-00, Standard Test Method for Sulfur in Petroleum Products (General
Bomb Method), for appendices A and D of this part.
(2) ASTM D240-00, (Reapproved 1991), Standard Test Method for Heat of Combustion
of Liquid Hydrocarbon Fuels by Bomb Calorimeter, for appendices A, D and F of this part.
(3) ASTM D287-92 (Reapproved 2000), Standard Test Method for API Gravity of Crude
Petroleum and Petroleum Products (Hydrometer Method), for appendix D of this part.
(4) ASTM D3 88-99, Standard Classification of Coals by Rank, incorporation by
reference for appendix F of this part.
(5) [Reserved]
(6) ASTM D1072-06, Standard Test Method for Total Sulfur in Fuel Gases by
Combustion and Barium Chloride Titration, for appendix D of this part.
(7) ASTM D1217-93 (Reapprovedl998), Standard Test Method for Density and Relative
Density (Specific Gravity) of Liquids by Bingham Pycnometer, for appendix D of this part.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 36
-------
§ 75.6(a)(8)
§ 75.6(a)(9)
§ 75.6(a)(10)
§ 75.6(a)(ll)
§ 75.6(a)(12)
§ 75.6(a)(13)
§ 75.6(a)(14)
§ 75.6(a)(15)
§ 75.6(a)(16)
§ 75.6(a)(17)
§ 75.6(a)(18)
§ 75.6(a)(19)
§ 75.6(a)(20)
§ 75.6(a)(21)
§ 75.6(a)(22)
§ 75.6(a)(23)
§ 75.6(a)(24)
§ 75.6(a)(25)
(8) ASTM D1250-07, Standard Guide for Use of the Petroleum Measurement Tables, for
appendix D of this part.
(9) ASTM D1298-99, Standard Test Method for Density, Relative Density (Specific
Gravity), or API Gravity of Crude Petroleum and Liquid Petroleum Products by Hydrometer
Method, for appendix D of this part.
(10) ASTM D1480-93 (Reapproved 1997), Standard Test Method for Density and
Relative Density (Specific Gravity) of Viscous Materials by Bingham Pycnometer, for
appendix D of this part.
(11) ASTM D1481-93 (Reapproved 1997), Standard Test Method for Density and
Relative Density (Specific Gravity) of Viscous Materials by Lipkin Bicapillary Pycnometer,
for appendix D of this part.
(12) ASTM D1552-01, Standard Test Method for Sulfur in Petroleum Products (High
Temperature Method), for appendices A and D of this part.
(13) ASTM D1826-94 (Reapproved 1998), Standard Test Method for Calorific (Heating)
Value of Gases in Natural Gas Range by Continuous Recording Calorimeter, for appendices D
and F to this part.
(14) ASTM D1945-96 (Reapproved 2001), Standard Test Method for Analysis of
Natural Gas by Gas Chromatography, for appendices F and G of this part.
(15) ASTM D1946-90 (Reapproved 2006), Standard Practice for Analysis of Reformed
Gas by Gas Chromatography, for appendices F and G of this part.
(16) [Reserved]
(17) ASTM D2013-01, Standard Practice of Preparing Coal Samples for Analysis, for
appendix F of this part.
(18) [Reserved]
(19) ASTM D2234-00, Standard Practice for Collection of a Gross Sample of Coal, for
appendix F of this part.
(20) [Reserved]
(21) ASTM D2502-92 (Reapproved 1996), Standard Test Method for Estimation of
Molecular Weight (Relative Molecular Mass) of Petroleum Oils from Viscosity
Measurements, for appendix G of this part.
(22) ASTM D2503-92 (Reapproved 1997), Standard Test Method for Relative Molecular
Mass (Relative Molecular Weight) of Hydrocarbons by Thermoelectric Measurement of
Vapor Pressure, for appendix G of this part.
(23) ASTM D2622-98, Standard Test Method for Sulfur in Petroleum Products by
Wavelength Dispersive X-ray Fluorescence Spectrometry, for appendices A and D of this
part.
(24) ASTM D3174-00, Standard Test Method for Ash in the Analysis Sample of Coal
and Coke from Coal, for appendix G of this part.
(25) ASTM D3176-89 (Reapproved 2002), Standard Practice for Ultimate Analysis of
Coal and Coke, for appendices A and F of this part.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 37
-------
§ 75.6(a)(26)
§ 75.6(a)(27)
§ 75.6(a)(28)
§ 75.6(a)(29)
§ 75.6(a)(30)
§ 75.6(a)(31)
§ 75.6(a)(32)
§ 75.6(a)(33)
§ 75.6(a)(34)
§ 75.6(a)(35)
§ 75.6(a)(36)
§ 75.6(a)(37)
§ 75.6(a)(38)
§ 75.6(a)(39)
§ 75.6(a)(40)
§ 75.6(a)(41)
§ 75.6(a)(42)
(26) ASTM D3177-02 (Reapproved 2007), Standard Test Methods for Total Sulfur in
the Analysis Sample of Coal and Coke, for appendix A of this part.
(27) ASTM D5373-02 (Reapproved 2007) Standard Test Methods for Instrumental
Determination of Carbon, Hydrogen, and Nitrogen in Laboratory Samples of Coal and Coke,
for appendix G of this part.
(28) ASTM D3238-95 (Reapproved 2000), Standard Test Method for Calculation of
Carbon Distribution and Structural Group Analysis of Petroleum Oils by the n-d-M Method,
for appendix G of this part.
(29) ASTM D3246-96, Standard Test Method for Sulfur in Petroleum Gas by Oxidative
Microcoulometry, for appendix D of this part.
(30) [Reserved]
(31) ASTM D3588-98, Standard Practice for Calculating Heat Value, Compressibility
Factor, and Relative Density of Gaseous Fuels, for appendices D and F to this part.
(32) ASTM D4052-96 (Reapproved 2002), Standard Test Method for Density and
Relative Density of Liquids by Digital Density Meter, for appendix D of this part.
(33) ASTM D4057-95 (Reapproved 2000), Standard Practice for Manual Sampling of
Petroleum and Petroleum Products, for appendix D of this part.
(34) ASTM D4177-95 (Reapproved 2000), Standard Practice for Automatic Sampling of
Petroleum and Petroleum Products, for appendix D of this part.
(35) ASTM D4239-02, Standard Test Methods for Sulfur in the Analysis Sample of Coal
and Coke Using High-Temperature Tube Furnace Combustion Methods, for appendix A of
this part.
(36) ASTM D4294-98, Standard Test Method for Sulfur in Petroleum and Petroleum
(37) ASTM D4468-85 (Reapproved 2006), Standard Test Method for Total Sulfur in
Gaseous Fuels by Hydrogenolysis and Rateometric Colorimetry, for appendix D of this part.
(38) ASTMD4840-99 (Reapproved 2004), "Standard Guide for Sample Chain-of-
Custody Procedures," for appendix K of this part, section 7.2.9
(39) ASTM D4891-89 (Reapproved 2006), Standard Test Method for Heating Value of
Gases in Natural Gas Range by Stoichiometric Combustion, for appendices D and F to this
part.
(40) ASTM D5291-02, Standard Test Methods for Instrumental Determination of
Carbon, Hydrogen, and Nitrogen in Petroleum Products and Lubricants, for appendices F and
G to this part.
(41) ASTM D5373-02 (Reapproved 2007), Standard Test Methods for Instrumental
Determination of Carbon, Hydrogen, and Nitrogen in Laboratory Samples of Coal and Coke,"
for appendix G to this part.
(42) ASTM D5504-01, Standard Test Method for Determination of Sulfur Compounds in
Natural Gas and Gaseous Fuels by Gas Chromatography and Chemiluminescence, for
appendix D of this part.
§ 75.6(a)(43)
(43) ASTM D6784-02, "Standard Test Method for Elemental, Oxidized, Particle-Bound
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 38
-------
and Total Mercury in Flue Gas Generated from Coal-fired Stationary Sources (Ontario Hydro
Method)," for § 75.22(a)(7) and (b)(5).
§ 75.6(a)(44)
§ 75.6(a)(45)
§ 75.6(a)(46)
§ 75.6(a)(47)
§ 75.6(a)(48)
§ 75.6(a)(49)
§ 75.6(b)
§ 75.6(c)
§ 75.6(d)
§ 75.6(e)
(44) ASTM D6911-03, "Guide for Packaging and Shipping Environmental Samples for
Laboratory Analysis," for appendix K of this part, section 7.2.8.
(45) ASTM D6667-04, Standard Test Method for Determination of Total Volatile Sulfur
in Gaseous Hydrocarbons and Liquefied Petroleum Gases by Ultraviolet Fluorescence, for
appendix D of this part.
(46) ASTM D4809-00, Standard Test Method for Heat of Combustion of Liquid
Hydrocarbon Fuels by Bomb Calorimeter (Precision Method), for appendices D, and F of this
part.
(47) ASTM D5865-01a, Standard Test Method for Gross Calorific Value of Coal and
Coke, for appendices A, D, and F of this part.
(48) ASTM D7036-04, Standard Practice for Competence of Air Emission Testing
Bodies, for appendices A, B, and E of this part.
(49) ASTM D5453-06, Standard Test Method for Determination of Total Sulfur in Light
Hydrocarbons, Spark Ignition Engine Fuel, Diesel Engine Fuel, and Engine Oil by Ultraviolet
Fluorescence, for appendix D of this part.
(b) The following materials are available for purchase from the American Society of
Mechanical Engineers (ASME), 22 Law Drive, P.O. Box 2900, Fairfield, NJ 07007-2900.
(1) ASME MFC-3M-1989 (Reaffirmed 1995), Measurement of Fluid Flow in Pipes
Using Orifice, Nozzle, and Venturi, for appendix D of this part.
(2) ASME MFC-4M-1986 (Reaffirmed 1997), Measurement of Gas Flow by Turbine
Meters, for appendix D of this part.
(3) ASME-MFC-5M-1985, (Reaffirmed 1994), Measurement of Liquid Flow in Closed
Conduits Using Transit-Time Ultrasonic Flowmeters, for appendix D of this part.
(4) ASME MFC-6M-1998, Measurement of Fluid Flow in Pipes Using Vortex
Flowmeters, for appendix D of this part.
(5) ASME MFC-7M-1987 (Reaffirmed 1992), Measurement of Gas Flow by Means of
Critical Flow Venturi Nozzles, for appendix D of this part.
(6) ASME MFC-9M-1988 (Reaffirmed 2001), Measurement of Liquid Flow in Closed
Conduits by Weighing Method, for appendix D of this part.
(c) The following materials are available for purchase from the American National
Standards Institute (ANSI), 25 West 43rd Street, Fourth Floor, New York, New York 10036:
(1) ISO 8316: 1987(E) Measurement of Liquid Flow in Closed Conduits-Method by
Collection of the Liquid in a Volumetric Tank, for appendices D and E of this part.
(2) [Reserved]
(d) The following materials are available for purchase from the following address: Gas
Processors Association (GPA), 6526 East 60th Street, Tulsa, Oklahoma 74143:
(1) GPA Standard 2172-96, Calculation of Gross Heating Value, Relative Density and
Compressibility Factor for Natural Gas Mixtures from Compositional Analysis, for appendices
D, E, and F of this part.
(2) GPA Standard 2261-00, Analysis for Natural Gas and Similar Gaseous Mixtures by
Gas Chromatography, for appendices D, F, and G of this part.
(e) The following American Gas Association materials are available for purchase from the
following address: ILI Infodisk, 610 Winters Avenue, Paramus, New Jersey 07652:
(1) American Gas Association Report No. 3: Orifice Metering of Natural Gas and Other
Related Hydrocarbon Fluids, Part 1: General Equations and Uncertainty Guidelines (October
1990 Edition), Part 2: Specification and Installation Requirements (February 1991 Edition)
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 39
-------
and Part 3: Natural Gas Applications (August 1992 Edition), for appendices D and E of this
part.
(2) American Gas Association Transmission Measurement Committee Report No. 7:
Measurement of Gas by Turbine Meters (Second Revision, April 1996), for appendix D to this
part.
§ 75.6(f) (f) The following materials are available for purchase from the following address:
American Petroleum Institute, Publications Department, 1220 L Street NW, Washington, DC
20005-4070:
(1) American Petroleum Institute (API) Manual of Petroleum Measurement Standards,
Chapter 3- Tank Gauging, Section 1A, Standard Practice for the Manual Gauging of
Petroleum and Petroleum Products, Second Edition, August 2005; Section IB-Standard
Practice for Level Measurement of Liquid Hydrocarbons in Stationary Tanks by Automatic
Tank Gauging, Second Edition June 2001; Section 2-Standard Practice for Gauging Petroleum
and Petroleum Products in Tank Cars, First Edition, August 1995 (Reaffirmed March 2006);
Section 3-Standard Practice for Level Measurement of Liquid Hydrocarbons in Stationary
Pressurized Storage Tanks by Automatic Tank Gauging, First Edition June 1996 (Reaffirmed,
March 2001); Section 4- Standard Practice for Level Measurement of Liquid Hydrocarbons
on Marine Vessels by Automatic Tank Gauging, First Edition April 1995 (Reaffirmed,
September 2000); and Section 5-Standard Practice for Level Measurement of Light
Hydrocarbon Liquids Onboard Marine Vessels by Automatic Tank Gauging, First Edition
March 1997 (Reaffirmed, March 2003); for § 75.19.
(2) Shop Testing of Automatic Liquid Level Gages, Bulletin 2509 B, December 1961
(Reaffirmed August 1987, October 1992), for § 75.19.
(3) American Petroleum Institute (API) Manual of Petroleum Measurement Standards,
Chapter 4-Proving Systems, Section 2-Pipe Provers (Provers Accumulating at Least 10,000
Pulses), Second Edition, March 2001, Section 3-Small Volume Provers (First Edition), and
Section 5-Master-Meter Provers, Second Edition, May 2000, for appendix D to this part.
(4) American Petroleum Institute (API) Manual of Petroleum Measurement Standards,
Chapter 22-Testing Protocol, Section 2-Differential Pressure Flow Measurement Devices,
First Edition, August 2005, for appendix D to this part.
§ 75.7 § 75.7 [Removed and Reserved]
§ 75.8 § 75.8 [Removed and Reserved]
Subpart B — Monitoring Provisions
§ 75.10 § 75.10 General operating requirements.
§ 75.10(a) (a) Primary Measurement Requirement. The owner or operator shall measure opacity,
and all S02, NOx, and C02 emissions for each affected unit as follows:
§ 75.10(a)(1) (1) To determine S02 emissions, the owner or operator shall install, certify, operate, and
maintain, in accordance with all the requirements of this part, a S02 continuous emission
monitoring system and a flow monitoring system with an automated data acquisition and
handling system for measuring and recording S02 concentration (in ppm), volumetric gas flow
(in scfh), and S02 mass emissions (in lb/hr) discharged to the atmosphere, except as provided
in §§ 75.11 and 75.16 and subpart E of this part;
§ 75.10(a)(2) (2) To determine NOx emissions, the owner or operator shall install, certify, operate, and
maintain, in accordance with all the requirements of this part, a NOx-diluent continuous
emission monitoring system (consisting of a NOx pollutant concentration monitor and an 02 or
C02 diluent gas monitor) with an automated data acquisition and handling system for
measuring and recording NOx concentration (in ppm), 02 or C02 concentration (in percent 02
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 40
-------
or C02) and NOx emission rate (in lb/mmBtu) discharged to the atmosphere, except as
provided in §§ 75.12 and 75.17 and subpart E of this part. The owner or operator shall
account for total NOx emissions, both NO and N02, either by monitoring for both NO and
N02 or by monitoring for NO only and adjusting the emissions data to account for N02;
§ 75.10(a)(3)
(3) The owner or operator shall determine C02 emissions by using one of the following
options, except as provided in § 75.13 and subpart E of this part:
(i) The owner or operator shall install, certify, operate, and maintain, in accordance with
all the requirements of this part, a C02 continuous emission monitoring system and a flow
monitoring system with an automated data acquisition and handling system for measuring and
recording C02 concentration (in ppm or percent), volumetric gas flow (in scfh), and C02 mass
emissions (in tons/hr) discharged to the atmosphere;
(ii) The owner or operator shall determine C02 emissions based on the measured carbon
content of the fuel and the procedures in appendix G of this part to estimate C02 emissions (in
ton/day) discharged to the atmosphere; or
(iii) The owner or operator shall install, certify, operate, and maintain, in accordance with
all the requirements of this part, a flow monitoring system and a C02 continuous emission
monitoring system that uses an 02 concentration monitor to determine C02 emissions
(according to the procedures in appendix F of this part) with an automated data acquisition
and handling system for measuring and recording 02 concentration (in percent), C02
concentration (in percent), volumetric gas flow (in scfh), and C02 mass emissions (in tons/hr)
discharged to the atmosphere;
§ 75.10(a)(4)
(4) The owner or operator shall install, certify, operate, and maintain, in accordance with
all the requirements in this part, a continuous opacity monitoring system with the automated
data acquisition and handling system for measuring and recording the opacity of emissions (in
percent opacity) discharged to the atmosphere, except as provided in §§ 75.14 and 75.18; and
§ 75.10(a)(5)
(5) A single certified flow monitoring system may be used to meet the requirements of
paragraphs (a)(1) and (a)(3) of this section. A single certified diluent monitor may be used to
meet the requirements of paragraphs (a)(2) and (a)(3) of this section. A single automated data
acquisition and handling system may be used to meet the requirements of paragraphs (a)(1)
through (a)(4) of this section.
§ 75.10(b)
(b) Primary Equipment Performance Requirements. The owner or operator shall ensure
that each continuous emission monitoring system required by this part meets the equipment,
installation, and performance specifications in appendix A to this part; and is maintained
according to the quality assurance and quality control procedures in appendix B to this part;
and shall record S02 and NOx emissions in the appropriate units of measurement (i.e., lb/hr
for S02 and lb/mmBtu for NOx).
§ 75.10(c)
(c) Heat Input Rate Measurement Requirement. The owner or operator shall determine
and record the heat input rate, in units of mmBtu/hr, to each affected unit for every hour or
part of an hour any fuel is combusted following the procedures in appendix F to this part.
§ 75.10(d)
(d) Primary equipment hourly operating requirements. The owner or operator shall
ensure that all continuous emission and opacity monitoring systems required by this part are in
operation and monitoring unit emissions or opacity at all times that the affected unit combusts
any fuel except as provided in § 75.11(e) and during periods of calibration, quality assurance,
or preventive maintenance, performed pursuant to § 75.21 and appendix B of this part, periods
of repair, periods of backups of data from the data acquisition and handling system, or
recertification performed pursuant to § 75.20. The owner or operator shall also ensure, subject
to the exceptions above in this paragraph, that all continuous opacity monitoring systems
required by this part are in operation and monitoring opacity during the time following
combustion when fans are still operating, unless fan operation is not required to be included
under any other applicable Federal, State, or local regulation, or permit. The owner or
operator shall ensure that the following requirements are met:
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 41
-------
§ 75.10(d)(1)
(1) The owner or operator shall ensure that each continuous emission monitoring system
is capable of completing a minimum of one cycle of operation (sampling, analyzing, and data
recording) for each successive 15-min interval. The owner or operator shall reduce all S02
concentrations, volumetric flow, S02 mass emissions, C02 concentration, 02 concentration,
C02 mass emissions (if applicable), NOx concentration, NOx emission rate, and Hg
concentration data collected by the monitors to hourly averages. Hourly averages shall be
computed using at least one data point in each fifteen minute quadrant of an hour, where the
unit combusted fuel during that quadrant of an hour. Notwithstanding this requirement, an
hourly average may be computed from at least two data points separated by a minimum of 15
minutes (where the unit operates for more than one quadrant of an hour) if data are
unavailable as a result of the performance of calibration, quality assurance, or preventive
maintenance activities pursuant to § 75.21 and appendix B of this part, or backups of data
from the data acquisition and handling system, or recertification, pursuant to § 75.20. The
owner or operator shall use all valid measurements or data points collected during an hour to
calculate the hourly averages. All data points collected during an hour shall be, to the extent
practicable, evenly spaced over the hour.
§ 75.10(d)(2)
(2) The owner or operator shall ensure that each continuous opacity monitoring system is
capable of completing a minimum of one cycle of sampling and analyzing for each successive
10-sec period and one cycle of data recording for each successive 6-min period. The owner or
operator shall reduce all opacity data to 6-min averages calculated in accordance with the
provisions of part 51, appendix M of this chapter, except where the applicable State
implementation plan or operating permit requires a different averaging period, in which case
the State requirement shall satisfy this Acid Rain Program requirement.
§ 75.10(d)(3)
(3) Failure of an S02, C02, or 02 emissions concentration monitor, NOx concentration
monitor, Hg concentration monitor, flow monitor, moisture monitor, or NOx-diluent
continuous emission monitoring system to acquire the minimum number of data points for
calculation of an hourly average in paragraph (d)(1) of this section shall result in the failure to
obtain a valid hour of data and the loss of such component data for the entire hour. For a
NOx-diluent monitoring system, an hourly average NOx emission rate in lb/mmBtu is valid
only if the minimum number of data points is acquired by both the NOx pollutant
concentration monitor and the diluent monitor (C02 or 02). For a moisture monitoring system
consisting of one or more oxygen analyzers capable of measuring 02 on a wet-basis and a dry-
basis, an hourly average percent moisture value is valid only if the minimum number of data
points is acquired for both the wet- and dry-basis measurements. If a valid hour of data is not
obtained, the owner or operator shall estimate and record emissions, moisture, or flow data for
the missing hour by means of the automated data acquisition and handling system, in
accordance with the applicable procedure for missing data substitution in subpart D of this
part.
§ 75.10(e)
(e) Optional backup monitor requirements. If the owner or operator chooses to use two
or more continuous emission monitoring systems, each of which is capable of monitoring the
same stack or duct at a specific affected unit, or group of units using a common stack, then the
owner or operator shall designate one monitoring system as the primary monitoring system,
and shall record this information in the monitoring plan, as provided for in § 75.53. The
owner or operator shall designate the other monitoring system(s) as backup monitoring
system(s) in the monitoring plan. The backup monitoring system(s) shall be designated as
redundant backup monitoring system(s), non-redundant backup monitoring system(s), or
reference method backup system(s), as described in § 75.20(d). When the certified primary
monitoring system is operating and not out-of-control as defined in § 75.24, only data from the
certified primary monitoring system shall be reported as valid, quality-assured data. Thus,
data from the backup monitoring system may be reported as valid, quality-assured data only
when the backup is operating and not out-of-control as defined in § 75.24 (or in the applicable
reference method in appendix A of part 60 of this chapter) and when the certified primary
monitoring system is not operating (or is operating but out-of-control). A particular monitor
may be designated both as a certified primary monitor for one unit and as a certified redundant
backup monitor for another unit.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 42
-------
§ 75.10(f) (f) Minimum measurement capability requirement. The owner or operator shall ensure
that each continuous emission monitoring system is capable of accurately measuring,
recording, and reporting data, and shall not incur an exceedance of the full scale range, except
as provided in sections 2.1.1.5, 2.1.2.5, and 2.1.4.3 of appendix A to this part.
§ 75.10(g) (g) Minimum recording and reporting requirements. The owner or operator shall record
and the designated representative shall report the hourly, daily, quarterly, and annual
information collected under the requirements of this part as specified in subparts F and G of
this part.
§75.11 §75.11 Specific provisions for monitoring S02 emissions.
§ 75.11(a) (a) Coal-fired units. The owner or operator shall meet the general operating requirements
in § 75.10 for an S02 continuous emission monitoring system and a flow monitoring system
for each affected coal-fired unit while the unit is combusting coal and/or any other fuel, except
as provided in paragraph (e) of this section, in § 75.16, and in subpart E of this part. During
hours in which only gaseous fuel is combusted in the unit, the owner or operator shall comply
with the applicable provisions of paragraph (e)(1), (e)(2), or (e)(3) of this section.
§ 75.11(b) (b) Moisture correction. Where S02 concentration is measured on a dry basis, the owner
or operator shall either:
(1) Report the appropriate fuel-specific default moisture value for each unit operating
hour, selected from among the following: 3.0%, for anthracite coal; 6.0% for bituminous coal;
8.0% for sub-bituminous coal; 11.0% for lignite coal; 13.0% for wood; and 14.0% for natural
gas (boilers, only); or
(2) Install, operate, maintain, and quality assure a continuous moisture monitoring system
for measuring and recording the moisture content of the flue gases, in order to correct the
measured hourly volumetric flow rates for moisture when calculating S02 mass emissions (in
lb/hr) using the procedures in appendix F to this part. The following continuous moisture
monitoring systems are acceptable: a continuous moisture sensor; an oxygen analyzer (or
analyzers) capable of measuring 02 both on a wet basis and on a dry basis; or a stack
temperature sensor and a moisture look-up table, i.e., a psychrometric chart (for saturated gas
streams following wet scrubbers or other demonstrably saturated gas streams, only). The
moisture monitoring system shall include as a component the automated data acquisition and
handling system (DAHS) for recording and reporting both the raw data (e.g., hourly average
wet- and dry-basis 02 values) and the hourly average values of the stack gas moisture content
derived from those data. When a moisture look-up table is used, the moisture monitoring
system shall be represented as a single component, the certified DAHS, in the monitoring plan
for the unit or common stack.
§ 75.11(c) (c) Unit with no location for a flow monitor meeting siting requirements. Where no
location exists that satisfies the minimum physical siting criteria in appendix A to this part for
installation of a flow monitor in either the stack or the ducts serving an affected unit or
installation of a flow monitor in either the stack or ducts is demonstrated to the satisfaction of
the Administrator to be technically infeasible, either:
(1) The designated representative shall petition the Administrator for an alternative
method for monitoring volumetric flow in accordance with § 75.66; or
(2) The owner or operator shall construct a new stack or modify existing ductwork to
accommodate the installation of a flow monitor, and the designated representative shall
petition the Administrator for an extension of the required certification date given in § 75.4
and approval of an interim alternative flow monitoring methodology in accordance with
§ 75.66. The Administrator may grant existing Phase I affected units an extension to
January 1, 1995, and existing Phase II affected units an extension to January 1, 1996 for
the submission of the certification application for the purpose of constructing a new stack or
making substantial modifications to ductwork for installation of a flow monitor; or
(3) The owner or operator shall install a flow monitor in any existing location in the stack
or ducts serving the affected unit at which the monitor can achieve the performance
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 43
-------
specifications of this part.
§ 75.11(d)
(d) Gas-fired and oil-fired units. The owner or operator of an affected unit that qualifies
as a gas-fired or oil-fired unit, as defined in § 72.2 of this chapter, based on information
submitted by the designated representative in the monitoring plan, shall measure and record
S02 emissions:
(1) By meeting the general operating requirements in § 75.10 for an S02 continuous
emission monitoring system and flow monitoring system. If this option is selected, the owner
or operator shall comply with the applicable provisions in paragraph (e)(1), (e)(2), or (e)(3) of
this section during hours in which the unit combusts only gaseous fuel;
(2) By providing other information satisfactory to the Administrator using the applicable
procedures specified in appendix D to this part for estimating hourly S02 mass emissions; or
(3) By using the low mass emissions excepted methodology in § 75.19(c) for estimating
hourly S02 mass emissions if the affected unit qualifies as a low mass emissions unit under
§ 75.19(a) and (b). If this option is selected for S02, the LME methodology must also be used
for NOx and C02 when these parameters are required to be monitored by applicable
program(s).
§ 75.11(e)
(e) Special considerations during the combustion of gaseous fuels. The owner or
operator of an affected unit that uses a certified flow monitor and a certified diluent gas (02 or
C02) monitor to measure the unit heat input rate shall, during any hours in which the unit
combusts only gaseous fuel, determine S02 emissions in accordance with paragraph (e)(1) or
(e)(3) of this section, as applicable.
§ 75.11(e)(1)
(1) If the gaseous fuel qualifies for a default S02 emission rate under Section 2.3.1.1,
2.3.2.1.1, or 2.3.6(b) of appendix D to this part, the owner or operator may determine S02
emissions by using Equation F-23 in appendix F to this part. Substitute into Equation F-23 the
hourly heat input, calculated using the certified flow monitoring system and the certified
diluent monitor (according to the applicable equation in section 5.2 of appendix F to this part),
in conjunction with the appropriate default S02 emission rate from section 2.3.1.1, 2.3.2.1.1,
or 2.3.6(b) of appendix D to this part. When this option is chosen, the owner or operator shall
perform the necessary data acquisition and handling system tests under § 75.20(c), and shall
meet all quality control and quality assurance requirements in appendix B to this part for the
flow monitor and the diluent monitor; or
§ 75.11(e)(2)
§ 75.11(e)(3)
(2) [Reserved]
(3) The owner or operator may determine S02 mass emissions by using a certified S02
continuous monitoring system, in conjunction with the certified flow rate monitoring system.
However, if the gaseous fuel is very low sulfur fuel (as defined in § 72.2 of this chapter), the
S02 monitoring system shall meet the following quality assurance provisions when the very
low sulfur fuel is combusted:
(i) When conducting the daily calibration error tests of the S02 monitoring system, as
required by section 2.1.1 in appendix B of this part, the zero-level calibration gas shall have
an S02 concentration of 0.0 percent of span. This restriction does not apply if gaseous fuel is
burned in the affected unit only during unit startup.
(ii) EPA recommends that the calibration response of the S02 monitoring system be
adjusted, either automatically or manually, in accordance with the procedures for routine
calibration adjustments in section 2.1.3 of appendix B to this part, whenever the zero-level
calibration response during a required daily calibration error test exceeds the applicable
performance specification of the instrument in section 3.1 of appendix A to this part (i.e.,
+ 2.5 percent of the span value or + 5 ppm, whichever is less restrictive).
(iii) Any bias-adjusted hourly average S02 concentration of less than 2.0 ppm recorded by
the S02 monitoring system shall be adjusted to a default value of 2.0 ppm, for reporting
purposes. Such adjusted hourly averages shall be considered to be quality-assured data,
provided that the monitoring system is operating and is not out-of-control with respect to any
of the quality assurance tests required by appendix B of this part (i.e., daily calibration error,
linearity and relative accuracy test audit).
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 44
-------
(iv) In accordance with the requirements of section 2.1.1.2 of appendix A to this part, for
units that sometimes burn gaseous fuel that is very low sulfur fuel (as defined in § 72.2 of this
chapter) and at other times burn higher sulfur fuel(s) such as coal or oil, a second low-scale
S02 measurement range is not required when the very low sulfur gaseous fuel is combusted.
For units that burn only gaseous fuel that is very low sulfur fuel and burn no other type(s) of
fuel(s), the owner or operator shall set the span of the S02 monitoring system to a value no
greater than 200 ppm.
(4) The provisions in paragraph (e)(1) of this section, may also be used for the
combustion of a solid or liquid fuel that meets the definition of very low sulfur fuel in §72.2 of
this chapter, mixtures of such fuels, or combinations of such fuels with gaseous fuel, if the
owner or operator submits a petition under §75.66 for a default S02 emission rate for each
fuel, mixture or combination, and if the Administrator approves the petition.
§ 75.11(f) (f) Other units. The owner or operator of an affected unit that combusts wood, refuse, or
other material in addition to oil or gas shall comply with the monitoring provisions for coal-
fired units specified in paragraph (a) of this section except where the owner or operator has an
approved petition to use the provisions of paragraph (e)(1) of this section.
§75.12 §75.12 Specific provisions for monitoring NOx emission rate
§ 75.12(a) (a) Coal-fired units, gas-fired nonpeaking units or oil-fired nonpeaking units. The owner
or operator shall meet the general operating requirements in § 75.10 of this part for a NOx
continuous emission monitoring system (CEMS) for each affected coal-fired unit, gas-fired
nonpeaking unit, or oil-fired nonpeaking unit, except as provided in paragraph (d) of this
section, § 75.17, and subpart E of this part. The diluent gas monitor in the NOx-diluent CEMS
may measure either 02 or C02 concentration in the flue gases.
§ 75.12(b) (b) Moisture correction. If a correction for the stack gas moisture content is needed to
properly calculate the NOx emission rate in lb/mmBtu, e.g., if the NOx pollutant concentration
monitor measures on a different moisture basis from the diluent monitor, the owner or
operator shall either report a fuel-specific default moisture value for each unit operating hour,
as provided in § 75.11(b)(1), or shall install, operate, maintain, and quality assure a
continuous moisture monitoring system, as defined in § 75.11(b)(2). Notwithstanding this
requirement, if Equation 19-3, 19-4 or 19-8 in Method 19 in appendix A to part 60 of this
chapter is used to measure NOx emission rate, the following fuel-specific default moisture
percentages shall be used in lieu of the default values specified in § 75.11(b)(1): 5.0%, for
anthracite coal; 8.0% for bituminous coal; 12.0% for sub-bituminous coal; 13.0% for lignite
coal; 15.0% for wood; and 18.0% for natural gas (boilers, only).
§ 75.12(c) (c) Determination ofiNOx emission rate. The owner or operator shall calculate hourly,
quarterly, and annual NOx emission rates (in lb/mmBtu) by combining the NOx concentration
(in ppm), diluent concentration (in percent 02 or C02), and percent moisture (if applicable)
measurements according to the procedures in appendix F to this part.
§ 75.12(d) (d) Gas-fired peaking units or oil-fired peaking units. The owner or operator of an
affected unit that qualifies as a gas-fired peaking unit or oil-fired peaking unit, as defined in
§ 72.2 of this chapter, based on information submitted by the designated representative in the
monitoring plan shall comply with one of the following:
(1) Meet the general operating requirements in § 75.10 for a NOx continuous emission
monitoring system; or
(2) Provide information satisfactory to the Administrator using the procedure specified in
appendix E of this part for estimating hourly NOx emission rate. However, if in the years after
certification of an excepted monitoring system under appendix E of this part, a unit's
operations exceed a capacity factor of 20 percent in any calendar year or exceed a capacity
factor of 10.0 percent averaged over three years, the owner or operator shall install, certify,
and operate a NOx-diluent continuous emission monitoring system no later than December 31
of the following calendar year. If the required CEMS has not been installed and certified by
that date, the owner or operator shall report the maximum potential NOx emission rate (MER)
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 45
-------
(as defined in § 72.2 of this chapter) for each unit operating hour, starting with the first unit
operating hour after the deadline and continuing until the CEMS has been provisionally
certified.
§ 75.12(e) (e) Low mass emissions units. Notwithstanding the requirements of paragraphs (a) and
(d) of this section, the owner or operator of an affected unit that qualifies as a low mass
emissions unit under § 75.19(a) and (b) shall comply with one of the following:
(1) Meet the general operating requirements in § 75.10 for a NOx continuous emission
monitoring system;
(2) Meet the requirements specified in paragraph (d)(2) of this section for using the
excepted monitoring procedures in appendix E to this part, if applicable; or
(3) Use the low mass emissions excepted methodology in § 75.19(c) for estimating hourly
NOx emission rate and hourly NOx mass emissions, if applicable under § 75.19(a) and (b)._If
this option is selected for NOx, the LME methodology must also be used for S02 and C02
when these parameters are required to be monitored by applicable program(s).
§ 75.12(f) (f) Other units. The owner or operator of an affected unit that combusts wood, refuse, or
other material in addition to oil or gas shall comply with the monitoring provisions specified
in paragraph (a) of this section.
§75.13 §75.13 Specific provisions for monitoring C02 emissions.
§ 75.13(a) (a) C02 continuous emission monitoring system. If the owner or operator chooses to use
the continuous emission monitoring method, then the owner or operator shall meet the general
operating requirements in § 75.10 for a C02 continuous emission monitoring system and flow
monitoring system for each affected unit. The owner or operator shall comply with the
applicable provisions specified in §§ 75.11 (a) through (e) or § 75.16, except that the phrase
"C02 continuous emission monitoring system" shall apply rather than "S02 continuous
emission monitoring system," the phrase "C02 concentration" shall apply rather than "S02
concentration," the term "maximum potential concentration of C02" shall apply rather than
"maximum potential concentration of S02," and the phrase "C02 mass emissions" shall apply
rather than "S02 mass emissions."
§ 75.13(b) (b) Determination of C02 emissions using appendix G to this part. If the owner or
operator chooses to use the appendix G method, then the owner or operator shall follow the
procedures in appendix G to this part for estimating daily C02 mass emissions based on the
measured carbon content of the fuel and the amount of fuel combusted. For units with wet
flue gas desulfurization systems or other add-on emissions controls generating C02, the owner
or operator shall use the procedures in appendix G to this part to estimate both
combustion-related emissions based on the measured carbon content of the fuel and the
amount of fuel combusted and sorbent-related emissions based on the amount of sorbent
injected. The owner or operator shall calculate daily, quarterly, and annual C02 mass
emissions (in tons) in accordance with the procedures in appendix G to this part.
§ 75.13(c) (c) Determination of C02 mass emissions using an 02 monitor according to appendix F
to this part. If the owner or operator chooses to use the appendix F method, then the owner or
operator shall determine hourly C02 concentration and mass emissions with a flow monitoring
system; a continuous 02 concentration monitor; fuel F and Fc factors; and, where 02
concentration is measured on a dry basis (or where Equation F-14b in appendix F to this part
is used to determine C02 concentration), either a continuous moisture monitoring system, as
specified in § 75.11(b)(2), or a fuel-specific default moisture percentage (if applicable), as
defined in § 75.11(b)(1); and by using the methods and procedures specified in appendix F to
this part. For units using a common stack, multiple stack, or bypass stack, the owner or
operator may use the provisions of § 75.16, except that the phrase "C02 continuous emission
monitoring system" shall apply rather than "S02 continuous emission monitoring system," the
term "maximum potential concentration of C02" shall apply rather than "maximum potential
concentration of S02," and the phrase "C02 mass emissions" shall apply rather than "S02
mass emissions."
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 46
-------
§ 75.13(d) (d) Determination of C02 mass emissions from low mass emissions units. The owner or
operator of a unit that qualifies as a low mass emissions unit under § 75.19(a) and (b) shall
comply with one of the following:
(1) Meet the general operating requirements in § 75.10 for a C02 continuous emission
monitoring system and flow monitoring system;
(2) Meet the requirements specified in paragraph (b) or (c) of this section for use of the
methods in appendix G or F to this part, respectively; or
(3) Use the low mass emissions excepted methodology in § 75.19(c) for estimating hourly
C02 mass emissions, if applicable under § 75.19(a) and (b). If this option is selected for C02,
the LME methodology must also be used for NOx and S02 when these parameters are required
to be monitored by applicable program(s).
§75.14 §75.14 Specific provisions for monitoring opacity.
§ 75.14(a) (a) Coal-fired units and oil-fired units. The owner or operator shall meet the general
operating provisions in § 75.10 of this part for a continuous opacity monitoring system for
each affected coal-fired or oil-fired unit, except as provided in paragraphs (b), (c), and (d) of
this section and in § 75.18. Each continuous opacity monitoring system shall meet the design,
installation, equipment, and performance specifications in Performance Specification 1 in
appendix B to part 60 of this chapter. Any continuous opacity monitoring system previously
certified to meet Performance Specification 1 shall be deemed certified for the purposes of
this part.
§ 75.14(b) (b) Unit with wet flue gas pollution control system. If the owner or operator can
demonstrate that condensed water is present in the exhaust flue gas stream and would impede
the accuracy of opacity measurements, then the owner or operator of an affected unit equipped
with a wet flue gas pollution control system for S02 emissions or particulates is exempt from
the opacity monitoring requirements of this part.
§ 75.14(c) (c) Gas-fired units. The owner or operator of an affected unit that qualifies as gas-fired,
as defined in § 72.2 of this chapter, based on information submitted by the designated
representative in the monitoring plan is exempt from the opacity monitoring requirements of
this part. Whenever a unit previously categorized as a gas-fired unit is recategorized as
another type of unit by changing its fuel mix, the owner or operator shall install, operate, and
certify a continuous opacity monitoring system as required by paragraph (a) of this section by
December 31 of the following calendar year.
§ 75.14(d) (d) Diesel-fired units and dual-fuel reciprocating engine units. The owner or operator of
an affected diesel-fired unit or a dual-fuel reciprocating engine unit is exempt from the opacity
monitoring requirements of this part.
§ 75.14(e) (e) Unit with a certified particulate matter (PM) monitoring system. If, for a particular
affected unit, the owner or operator installs, certifies, operates, maintains, and quality-assures
a continuous particulate matter (PM) monitoring system in accordance with Procedure 2 in
appendix F to part 60 of this chapter, the unit shall be exempt from the opacity monitoring
requirement of this part.
§ 75.15 § 75.15 Special provisions for measuring Hg mass emissions using the excepted sorbent
trap monitoring methodology.
For an affected coal-fired unit under a State or Federal Hg mass emission reduction
program that adopts the provisions of subpart I of this part, if the owner or operator elects to
use sorbent trap monitoring systems (as defined in § 72.2 of this chapter) to quantify Hg mass
emissions, the guidelines in paragraphs (a) through (1) of this section shall be followed for this
excepted monitoring methodology:
§ 75.15(a) (a) For each sorbent trap monitoring system (whether primary or redundant backup), the
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 47
-------
use of paired sorbent traps, as described in appendix K to this part, is required;
§ 75.15(b) (b) Each sorbent trap shall have both a main section, a backup section, and a third section
to allow spiking with a calibration gas of known Hg concentration, as described in appendix K
to this part;
§ 75.15(c) (c) A certified flow monitoring system is required;
§ 75.15(d) (d) Correction for stack gas moisture content is required, and in some cases, a certified 02
or C02 monitoring system is required (see § 75.81(a)(4));
§ 75.15(e) (e) Each sorbent trap monitoring system shall be installed and operated in accordance
with appendix K to this part. The automated data acquisition and handling system shall ensure
that the sampling rate is proportional to the stack gas volumetric flow rate.
§ 75.15(f) (f) At the beginning and end of each sample collection period, and at least once in each
unit operating hour during the collection period, the gas flow meter reading shall be recorded.
§ 75.15(g) (g) After each sample collection period, the mass of Hg adsorbed in each sorbent trap (in
all three sections) shall be determined according to the applicable procedures in appendix K to
this part.
§ 75.15(h) (h) The hourly Hg mass emissions for each collection period are determined using the
results of the analyses in conjunction with contemporaneous hourly data recorded by a
certified stack flow monitor, corrected for the stack gas moisture content. For each pair of
sorbent traps analyzed, the average of the two Hg concentrations shall be used for reporting
purposes under § 75.84(f). Notwithstanding this requirement, if, due to circumstances beyond
the control of the owner or operator, one of the paired traps is accidentally lost, damaged, or
broken and cannot be analyzed, the results of the analysis of the other trap may be used for
reporting purposes, provided that:
(1) The other trap has met all of the applicable quality-assurance requirements of this
part; and
(2) The Hg concentration measured by the other trap is multiplied by a factor of 1.111.
§ 75.15(i) (i) All unit operating hours for which valid Hg concentration data are obtained with the
primary sorbent trap monitoring system (as verified using the quality assurance procedures in
appendix K to this part) shall be reported in the electronic quarterly report under § 75.84(f).
For hours in which data from the primary monitoring system are invalid, the owner or operator
may, in accordance with § 75.20(d), report valid Hg concentration data from: A certified
redundant backup CEMS or sorbent trap monitoring system; a certified non-redundant backup
CEMS or sorbent trap monitoring system; or from an applicable reference method under
§ 75.22. If no quality-assured Hg concentration are available for a particular hour, the owner
or operator shall report the appropriate substitute data value in accordance with § 75.39.
§ 75.15(j) (j) Initial certification requirements and additional quality-assurance requirements for the
sorbent trap monitoring systems are found in § 75.20(c)(9), in section 6.5.7 of appendix A to
this part, in sections 1.5 and 2.3 of appendix B to this part, and in appendix K to this part.
§ 75.15(k) (k) During each RATA of a sorbent trap monitoring system, the type of sorbent material
used by the traps shall be the same as for daily operation of the monitoring system. A new
pair of traps shall be used for each RATA run. However, the size of the traps used for the
RATA may be smaller than the traps used for daily operation of the system.
§75.15(1) (1) Whenever the type of sorbent material used by the traps is changed, the owner or
operator shall conduct a diagnostic RATA of the modified sorbent trap monitoring system
within 720 unit or stack operating hours after the date and hour when the new sorbent material
is first used. If the diagnostic RATA is passed, data from the modified system may be
reported as quality-assured, back to the date and hour when the new sorbent material was first
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 48
-------
used. If the RATA is failed, all data from the modified system shall be invalidated, back to
the date and hour when the new sorbent material was first used, and data from the system shall
remain invalid until a subsequent RATA is passed. If the required RATA is not completed
within 720 unit or stack operating hours, but is passed on the first attempt, data from the
modified system shall be invalidated beginning with the first operating hour after the 720 unit
or stack operating hour window expires and data from the system shall remain invalid until the
date and hour of completion of the successful RATA.
§ 75.16 § 75.16 Special provisions for monitoring emissions from common, bypass, and multiple
stacks for S02 emissions and heat input determinations.
§ 75.16(a) (a) [Reserved]
§ 75.16(b) (b) Common stack procedures. The following procedures shall be used when more than
one unit uses a common stack:
§ 75.16(b)(1) (1) Unit utilizing common stack with other affected unit(s). When a Phase I or Phase II
affected unit utilizes a common stack with one or more other Phase I or Phase II affected
units, but no nonaffected units, the owner or operator shall either:
(i) Install, certify, operate, and maintain an S02 continuous emission monitoring system
and flow monitoring system in the duct to the common stack from each affected unit; or
(ii) Install, certify, operate, and maintain an S02 continuous emission monitoring system
and flow monitoring system in the common stack and combine emissions for the affected units
for recordkeeping and compliance purposes.
§ 75.16(b)(2)
(2) Unit utilizing common stack with nonaffected unit(s). When one or more Phase I or
Phase II affected units utilizes a common stack with one or more nonaffected units, the owner
or operator shall either:
§75.16(b)(2)(i)
(i) Install, certify, operate, and maintain an S02 continuous emission monitoring system
and flow monitoring system in the duct to the common stack from each Phase I and Phase II
unit; or
§ 75.16(b)(2)(ii)
(ii) Install, certify, operate, and maintain an S02 continuous emission monitoring system
and flow monitoring system in the common stack; and
(A) Designate the nonaffected units as opt-in units in accordance with part 74 of this
chapter and combine emissions for recordkeeping and compliance purposes; or
(B) Install, certify, operate, and maintain an S02 continuous emission monitoring system
and flow monitoring system in the duct from each nonaffected unit; determine S02 mass
emissions from the affected units as the difference between S02 mass emissions measured in
the common stack and S02 mass emissions measured in the ducts of the nonaffected units, not
to be reported as an hourly average value less than zero; combine emissions for the Phase I
and Phase II affected units for recordkeeping and compliance purposes; and calculate and
report S02 mass emissions from the Phase I and Phase II affected units, pursuant to an
approach approved by the Administrator, such that these emissions are not underestimated; or
(C) Record the combined emissions from all units as the combined S02 mass emissions
for the Phase I and Phase II affected units for recordkeeping and compliance purposes; or
(D) Petition through the designated representative and provide information satisfactory to
the Administrator on methods for apportioning S02 mass emissions measured in the common
stack to each of the units using the common stack and on reporting the S02 mass emissions.
The Administrator may approve such demonstrated substitute methods for apportioning and
reporting S02 mass emissions measured in a common stack whenever the demonstration
ensures that there is a complete and accurate accounting of all emissions regulated under this
part and, in particular, that the emissions from any affected unit are not underestimated.
§ 75.16(c)
(c) Unit with bypass stack Whenever any portion of the flue gases from an affected unit
can be routed through a bypass stack so as to avoid the installed S02 continuous emission
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 49
-------
monitoring system and flow monitoring system, the owner or operator shall either:
§ 75.16(c)(1)
(1) Install, certify, operate, and maintain separate S02 continuous emission monitoring
systems and flow monitoring systems on the main stack and the bypass stack and calculate
S02 mass emissions for the unit as the sum of the S02 mass emissions measured at the two
stacks; or
§ 75.16(c)(2)
(2) Monitor S02 mass emissions at the main stack using S02 and flow rate monitoring
systems and measure S02 mass emissions at the bypass stack using the reference methods in
§ 75.22(b) for S02 and flow rate and calculate S02 mass emissions for the unit as the sum of
the emissions recorded by the installed monitoring systems on the main stack and the
emissions measured by the reference method monitoring systems; or
§ 75.16(c)(3)
(3) Install, certify, operate, and maintain S02 and flow rate monitoring systems only on
the main stack. If this option is chosen, report the following values for each hour during
which emissions pass through the bypass stack: the maximum potential concentration of S02
as determined under section 2.1.1.1 of appendix A to this part (or, if available, the S02
concentration measured by a certified monitor located at the control device inlet may be
reported instead), and the hourly volumetric flow rate value that would be substituted for the
flow monitor installed on the main stack or flue under the missing data procedures in subpart
D of this part if data from the flow monitor installed on the main stack or flue were missing for
the hour. The maximum potential S02 concentration may be specific to the type of fuel
combusted in the unit during the bypass (see § 75.33(b)(5)). The option in this paragraph,
(c)(3), may only be used if use of the bypass stack is limited to unit startup, emergency
situations (e.g., malfunction of a flue gas desulfurization system), and periods of routine
maintenance of the flue gas desulfurization system or maintenance on the main stack. If this
option is chosen, it is not necessary to designate the exhaust configuration as a multiple stack
configuration in the monitoring plan required under § 75.53, with respect to S02 or any other
parameter that is monitored only at the main stack. Calculate S02 mass emissions for the unit
as the sum of the emissions calculated with the substitute values and the emissions recorded by
the S02 and flow monitoring systems installed on the main stack.
§ 75.16(d)
(d) Unit with multiple stacks or ducts. When the flue gases from an affected unit utilize
two or more ducts feeding into two or more stacks (that may include flue gases from other
affected or nonaffected units), or when the flue gases utilize two or more ducts feeding into a
single stack and the owner or operator chooses to monitor in the ducts rather than the stack,
the owner or operator shall either:
(1) Install, certify, operate, and maintain an S02 continuous emission monitoring system
and flow monitoring system in each duct feeding into the stack or stacks and determine S02
mass emissions from each affected unit as the sum of the S02 mass emissions recorded for
each duct; or
(2) Install, certify, operate, and maintain an S02 continuous emission monitoring system
and flow monitoring system in each stack. Determine S02 mass emissions from each affected
unit as the sum of the S02 mass emissions recorded for each stack. Notwithstanding the prior
sentence, if another unit also exhausts flue gases to one or more of the stacks, the owner or
operator shall also comply with the applicable common stack requirements of this section to
determine and record S02 mass emissions from the units using that stack and shall calculate
and report S02 mass emissions from the affected units and stacks, pursuant to an approach
approved by the Administrator, such that these emissions are not underestimated.
§ 75.16(e)
§ 75.16(e)(1)
(e) Heat input rate. The owner or operator of an affected unit using a common stack,
bypass stack, or multiple stacks shall account for heat input rate according to the following:
(1) The owner or operator of an affected unit using a common stack, bypass stack, or
multiple stack with a diluent monitor and a flow monitor on each stack may use the flow rate
and diluent monitors to determine the heat input rate for the affected unit, using the procedures
specified in paragraphs (b) through (d) of this section, except that the term "heat input rate"
shall apply rather than "S02 mass emissions" or "emissions" and the phrase "a diluent monitor
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 50
-------
and a flow monitor" shall apply rather than "S02 continuous emission monitoring system and
flow monitoring system." The applicable equation in appendix F to this part shall be used to
calculate the heat input rate from the hourly flow rate, diluent monitor measurements, and (if
the equation in appendix F requires a correction for the stack gas moisture content) hourly
moisture measurements. Notwithstanding the options for combining heat input rate in
paragraphs (b)(l)(ii) and (b)(2)(ii) of this section, the owner or operator of an affected unit
with a diluent monitor and a flow monitor installed on a common stack to determine the
combined heat input rate at the common stack shall also determine and report heat input rate
to each individual unit, according to paragraph (e)(3) of this section.
§ 75.16(e)(2) (2) In the event that an owner or operator of a unit with a bypass stack does not install and
certify a diluent monitor and flow monitoring system in a bypass stack, the owner or operator
shall determine total heat input rate to the unit for each unit operating hour during which the
bypass stack is used according to the missing data provisions for heat input rate under § 75.36
or the procedures for calculating heat input rate from fuel sampling and analysis in section 5.5
of appendix F to this part.
§ 75.16(e)(3) (3) The owner or operator of an affected unit with a diluent monitor and a flow monitor
installed on a common stack to determine heat input rate at the common stack may choose to
apportion the heat input rate from the common stack to each affected unit utilizing the
common stack by using either of the following two methods, provided that all of the units
utilizing the common stack are combusting fuel with the same F-factor found in section 3 of
appendix F of this part. The heat input rate may be apportioned either by using the ratio of
load (in MWe) for each individual unit to the total load for all units utilizing the common
stack or by using the ratio of steam load (in 1000 lb/hr or mmBtu/hr thermal output) for each
individual unit to the total steam load for all units utilizing the common stack, in conjunction
with the appropriate unit and stack operating times. If using either of these apportionment
methods, the owner or operator shall apportion according to section 5.6 of appendix F to this
part.
§ 75.16(e)(4) (4) Notwithstanding paragraph (e)(1) of this section, any affected unit that is using the
procedures in this part to meet the monitoring and reporting requirements of a State or federal
NOx mass emission reduction program must also meet the requirements for monitoring heat
input rate in §§ 75.71, 75.72 and 75.75.
§ 75.17 § 75.17 Specific provisions for monitoring emissions from common, bypass, and multiple
stacks for NOx emission rate.
Notwithstanding the provisions of paragraphs (a), (b), (c), and (d) of this section, the
owner or operator of an affected unit that is using the procedures in this part to meet the
monitoring and reporting requirements of a State or federal NOx mass emission reduction
program must also meet the provisions for monitoring NOx emission rate in §§ 75.71 and
75.72.
§ 75.17(a)
§ 75.17(a)(1)
§ 75.17(a)(2)
(a) Unit utilizing common stack with other affected unit(s). When an affected unit utilizes
a common stack with one or more affected units, but no nonaffected units, the owner or
operator shall either:
(1) Install, certify, operate, and maintain a NOx continuous emission monitoring system in
the duct to the common stack from each affected unit; or
(2) Install, certify, operate, and maintain a NOx continuous emission monitoring system in
the common stack and follow the appropriate procedure in paragraphs (a)(2) (i) through (iii)
of this section, depending on whether or not the units are required to comply with a NOx
emission limitation (in lb/mmBtu, annual average basis) pursuant to section 407(b) of the Act
(referred to hereafter as "NOx emission limitation").
§ 75.17(a)(2)®
(i) When each of the affected units has a NOx emission limitation, the designated
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 51
-------
representative shall submit a compliance plan to the Administrator that indicates:
(A) Each unit will comply with the most stringent NOx emission limitation of any unit
utilizing the common stack; or
(B) Each unit will comply with the applicable NOx emission limitation by averaging its
emissions with the other unit(s) utilizing the common stack, pursuant to the emissions
averaging plan submitted under part 76 of this chapter; or
(C) Each unit's compliance with the applicable NOx emission limit will be determined by
a method satisfactory to the Administrator for apportioning to each of the units the combined
NOx emission rate (in lb/mmBtu) measured in the common stack and for reporting the NOx
emission rate, as provided in a petition submitted by the designated representative. The
Administrator may approve such demonstrated substitute methods for apportioning and
reporting NOx emission rate measured in a common stack whenever the demonstration ensures
that there is a complete and accurate estimation of all emissions regulated under this part and,
in particular, that the emissions from any unit with a NOx emission limitation are not
underestimated.
§ 75.17(a)(2)(ii) (ii) When none of the affected units has a NOx emission limitation, the owner or operator
and the designated representative have no additional obligations pursuant to section 407 of the
Act and may record and report a combined NOx emission rate (in lb/mmBtu) for the affected
units utilizing the common stack.
§ 75.17(a)(2)(iii) (iii) When at least one of the affected units has a NOx emission limitation and at least one
of the affected units does not have a NOx emission limitation, the owner or operator shall
either:
(A) Install, certify, operate, and maintain NOx and diluent monitors in the ducts from the
affected units; or
(B) Develop, demonstrate, and provide information satisfactory to the Administrator on
methods for apportioning the combined NOx emission rate (in lb/mmBtu) measured in the
common stack on each of the units. The Administrator may approve such demonstrated
substitute methods for apportioning the combined NOx emission rate measured in a common
stack whenever the demonstration ensures complete and accurate estimation of all emissions
regulated under this part.
(b) Unit utilizing common stack with nonaffected unit(s). When one or more affected
units utilizes a common stack with one or more nonaffected units, the owner or operator shall
either:
(1) Install, certify, operate, and maintain a NOx-diluent continuous emission monitoring
system in the duct from each affected unit; or
(2) Develop, demonstrate, and provide information satisfactory to the Administrator on
methods for apportioning the combined NOx emission rate (in lb/mmBtu) measured in the
common stack for each of the units. The Administrator may approve such demonstrated
substitute methods for apportioning the combined NOx emission rate measured in a common
stack whenever the demonstration ensures complete and accurate estimation of all emissions
regulated under this part.
(c) Unit with multiple stacks or ducts. When the flue gases from an affected unit
discharge to the atmosphere through two or more stacks or when flue gases from an affected
unit utilize two or more ducts feeding into a single stack and the owner or operator chooses to
monitor in the ducts rather than the stack, the owner or operator shall monitor the NOx
emission rate in a way that is representative of each affected unit. Where another unit also
exhausts flue gases to one or more of the stacks where monitoring systems are installed, the
owner or operator shall also comply with the applicable common stack monitoring
requirements of this section. The owner or operator shall either:
(1) Install, certify, operate, and maintain a NOx-diluent continuous emission monitoring
system and a flow monitoring system in each stack or duct and determine the NOx emission
rate for the unit as the Btu-weighted average of the NOx emission rates measured in the stacks
or ducts using the heat input estimation procedures in appendix F to this part. Alternatively,
§ 75.17(b)
§ 75.17(c)
§ 75.17(c)(1)
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 52
-------
for units that are eligible to use the procedures of appendix D to this part, the owner or
operator may monitor heat input and NOx emission rate at the unit level, in lieu of installing
flow monitors on each stack or duct. If this alternative unit-level monitoring is performed,
report, for each unit operating hour, the highest emission rate measured by any of the NOx-
diluent monitoring systems installed on the individual stacks or ducts as the hourly NOx
emission rate for the unit, and report the hourly unit heat input as determined under appendix
D to this part. Also, when this alternative unit-level monitoring is performed, the applicable
NOx missing data procedures in §§ 75.31 or 75.33 shall be used for each unit operating hour
in which a quality-assured NOx emission rate is not obtained for one or more of the individual
stacks or ducts; or
§ 75.17(c)(2) (2) Provided that the products of combustion are well-mixed, install, certify, operate, and
maintain a NOx continuous emission monitoring system in one stack or duct from the affected
unit and record the monitored value as the NOx emission rate for the unit. The owner or
operator shall account for NOx emissions from the unit during all times when the unit
combusts fuel. Therefore, this option shall not be used if the monitored stack or duct can be
bypassed (e.g., by using dampers). Follow the procedure in § 75.17(d) for units with bypass
stacks. Further, this option shall not be used unless the monitored NOx emission rate truly
represents the NOx emissions discharged to the atmosphere (e.g., the option is disallowed if
there are any additional NOx emission controls downstream of the monitored location).
§ 75.17(d) (d) Unit with amain stack and bypass stack con figuration. For an affected unit with a
discharge configuration consisting of a main stack and a bypass stack, the owner or operator
shall either:
(1) Follow the procedures in paragraph (c)(1) of this section; or
(2) Install, certify, operate, and maintain a NOx-diluent CEMS only on the main stack. If
this option is chosen, it is not necessary to designate the exhaust configuration as a multiple
stack configuration in the monitoring plan required under § 75.53, with respect to NOx or any
other parameter that is monitored only at the main stack. For each unit operating hour in
which the bypass stack is used and the emissions are either uncontrolled (or the add-on
controls are not documented to be operating properly), report the maximum potential NOx
emission rate (as defined in § 72.2 of this chapter). The maximum potential NOx emission
rate may be specific to the type of fuel combusted in the unit during the bypass (see
§ 75.33(c)(8)). Alternatively, for a unit with NOx add-on emission controls, for each unit
operating hour in which the bypass stack is used and the add-on NOx emission controls are not
bypassed, the owner or operator may report the maximum controlled NOx emission rate
(MCR) instead of the maximum potential NOx emission rate provided that the add-on controls
are documented to be operating properly, as described in the quality assurance/quality control
program for the unit, required by section 1 in appendix B of this part. To provide the
necessary documentation, the owner or operator shall record parametric data to verify the
proper operation of the NOx add-on emission controls as described in § 75.34(d).
Furthermore, the owner or operator shall calculate the MCR using the procedure described in
§ 2.1.2.1(b) of appendix A to this part where the words "maximum potential NOx emission
rate (MER)" shall apply instead of the words "maximum controlled NOx emission rate
(MCR)" and by using the NOx MEC in the calculations instead of the NOx MPC.
§ 75.18 § 75.18 Specific provisions for monitoring emissions from common and by-pass stacks
for opacity.
§ 75.18(a) (a) Unit using common stack When an affected unit utilizes a common stack with other
affected units or nonaffected units, the owner or operator shall comply with the applicable
monitoring provision in this paragraph, as determined by existing Federal, State, or local
opacity regulations.
(1) Where another regulation requires the installation of a continuous opacity monitoring
system upon each affected unit, the owner or operator shall install, certify, operate, and
maintain a continuous opacity monitoring system meeting Performance Specification 1 in
appendix B to part 60 of this chapter (referred to hereafter as a "certified continuous opacity
monitoring system") upon each unit.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 53
-------
(2) Where another regulation does not require the installation of a continuous opacity
monitoring system upon each affected unit, and where the affected source is not subject to any
existing Federal, State, or local opacity regulations, the owner or operator shall install, certify,
operate, and maintain a certified continuous opacity monitoring system upon each common
stack for the combined effluent.
(b) Unit using bypass stack. Where any portion of the flue gases from an affected unit
can be routed so as to bypass the installed continuous opacity monitoring system, the owner or
operator shall install, certify, operate, and maintain a certified continuous opacity monitoring
system on each bypass stack flue, duct, or stack gas stream unless either:
(1) An applicable Federal, State, or local opacity regulation or permit exempts the unit
from a requirement to install a continuous opacity monitoring system in the bypass stack; or
(2) A continuous opacity monitoring system is already installed and certified at the inlet
of the add-on emissions controls.
(3) The owner or operator monitors opacity using method 9 of appendix A of part 60 of
this chapter whenever emissions pass through the bypass stack. Method 9 shall be used in
accordance with the applicable State regulations.
§ 75.19 Optional S02, NOx, and C02 emissions calculation for low mass emissions units.
(a) Applicability and qualification
(1) For units that meet the requirements of this paragraph (a)(1) and paragraphs (a)(2) and
(b) of this section, the low mass emissions (LME) excepted methodology in paragraph (c) of
this section may be used in lieu of continuous emission monitoring systems or, if applicable, in
lieu of excepted methods under appendices D, E, and G to this part, for the purpose of
determining unit heat input, NOx, S02, and C02 mass emissions, and NOx emission rate under
this part. If the owner or operator of a qualifying unit elects to use the LME methodology, it
must be used for all parameters that are required to be monitored by the applicable
program(s). For example, for an Acid Rain Program LME unit, the methodology must be
used to estimate S02, NOx, and C02 mass emissions, NOx emission rate, and unit heat input.
§ 75.19(a)(l)(i) (i) A low mass emissions unit is an affected unit that is gas-fired, or oil-fired (as defined
in § 72.2 of this chapter), and for which:
(A) An initial demonstration is provided, in accordance with paragraph (a)(2) of this
section, which shows that the unit emits :
(1) No more than 25 tons of S02 annually and less than 100 tons of NOx annually, for
Acid Rain Program affected units. If the unit is also subject to the provisions of subpart H of
this part, no more than 50 of the allowable annual tons of NOx may be emitted during the
ozone season; or
(2) Less than 100 tons of NOx annually and no more than 50 tons of NOx during the
ozone season, for non-Acid Rain Program units subject to the provisions of subpart H of this
part, for which the owner or operator reports emissions data on a year-round basis, in
accordance with § 75.74(a) or § 75.74(b); or
(3) No more than 50 tons of NOx per ozone season, for non-Acid Rain Program units
subject to the provisions of subpart H of this part, for which the owner or operator reports
emissions data only during the ozone season, in accordance with § 75.74(b); and
§ 75.18(b)
§ 75.19
§ 75.19(a)
§ 75.19(a)(1)
(B) An annual demonstration is provided thereafter, using one of the allowable
methodologies in paragraph (c) of this section, showing that the low mass emissions unit
continues to emit no more than the applicable number of tons of S02 and/or NOx specified in
paragraph (a)(l)(i)(A) of this section.
(C) This paragraph, (a)(l)(i)(C), applies only to a unit that is subject to an S02 emission
limitation under the Acid Rain Program, and that combusts a gaseous fuel other than pipeline
natural gas or natural gas (as defined in § 72.2 of this chapter). The owner or operator of such
a unit must quantify the sulfur content and variability of the gaseous fuel by performing the
demonstration described in section 2.3.6 of appendix D to this part, in order for the unit to
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 54
-------
qualify for LME status. If the results of that demonstration show that the gaseous fuel
qualifies under paragraph (b) of section 2.3.6 to use a default S02 emission rate to report S02
mass emissions under this part, the unit is eligible for LME status.
§ 75.19(a)(l)(ii) (ii) Each qualifying LME unit must start using the low mass emissions excepted
methodology as follows:
(A) For a unit that reports emission data on a year-round basis, begin using the
methodology in the first unit operating hour in the calendar year designated in the certification
application as the first year that the methodology will be used; or
(B) For a unit that is subject to Subpart H of this part and that reports only during the
ozone season according to § 75.74(c), begin using the methodology in the first unit operating
hour in the ozone season designated in the certification application as the first ozone season
that the methodology will be used.
(C) For a new or newly-affected unit, see paragraph (b)(4) of this section for additional
guidance.
§ 75.19(a)(2)
(2) A unit may initially qualify as a low mass emissions unit if the designated
representative submits a certification application to use the LME methodology (as described
in § 75.63 (a)(l)(ii) and in this paragraph, (a)(2)) and the Administrator (or permitting
authority, as applicable) certifies the use of such methodology. The certification application
shall be submitted no later than 45 days prior to the date on which use of the low mass
emissions methodology is expected to commence, and the application must contain:
§ 75.19(a)(2)®
(i) A statement identifying the projected date on which the LME methodology will first
be used. The projected commencement date shall be consistent with paragraphs (a)(l)(ii) and
(b)(4) of this section, as applicable; and
§ 75.19(a)(2)(h)
§75.19(a)(2)(ii)(A)
(ii) Either:
(A) Actual S02 and /or NOx mass emissions data (as applicable) for each of the three
calendar years (or ozone seasons) prior to the calendar year in which the certification
application is submitted demonstrating to the satisfaction of the Administrator or (if
applicable) the permitting authority, that the unit emitted less than the applicable number of
tons of S02 and/or NOx specified in paragraph (a)(l)(i)(A) of this section. For the purposes of
this paragraph, (a)(2)(ii)(A), the required actual S02 or NOx mass emissions for each
qualifying year or ozone season shall be determined using the S02, NOx and heat input data
reported to the Administrator in the electronic quarterly reports required under § 75.64 or
under the Ozone Transport Commission (OTC) NOx Budget Trading Program.
Notwithstanding this requirement, in the absence of such electronic reports, an estimate of the
actual emissions for each of the previous three years (or ozone seasons) shall be provided,
using either the maximum rated heat input methodology described in paragraph (c)(3)(i) of
this section or procedures consistent with the long term fuel flow heat input methodology
described in paragraph (c)(3)(ii) of this section, in conjunction with the appropriate S02 or
NOx emission rate from paragraph (c)(l)(i) of this section for S02, and paragraph (c)(l)(ii) or
(c)(l)(iv) of this section for NOx. Alternatively, the initial estimate of the NOx emission rate
may be based on historical emission test data that is representative of operation at normal load
or historical data from a CEMS certified under part 60 of this chapter or under a State CEM
program; or
§ 75.19(a)(2)(ii)(B) (B) When the three full years (or ozone seasons) of actual S02 and NOx mass emissions
data (or reliable estimates thereof) described under paragraph (a)(2)(ii)(A) of this section do
not exist, the designated representative may submit an application to use the low mass
emissions excepted methodology based upon a combination of actual historical S02 and NOx
mass emissions data and projected S02 and NOx mass emissions, totaling three years (or
ozone seasons). Except as provided in paragraph (a)(3) of this section, actual data must be
used for any years (or ozone seasons) in which such data exists and projected data should be
used for any remaining future years (or ozone seasons) needed to provide emissions data for
three consecutive calendar years (or ozone seasons). For example, if a unit commenced
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 55
-------
operation two years ago, the designated representative may submit actual, historical data for
the previous two years and one year of projected emissions for the current calendar year or,
for a new unit, the designated representative may submit three years of projected emissions,
beginning with the current calendar year. Any actual or projected annual emissions must
demonstrate to the satisfaction of the Administrator that the unit will emit less than the
applicable number of tons of S02 and/or NOx specified in paragraph (a)(l)(i)(A) of this
section. Projected emissions shall be calculated using either the appropriate default emission
rates from paragraphs (c)(l)(i) and (c)(l)(ii) of this section (or, alternatively for NO x, a
conservative estimate of the NOx emission rate, as described in paragraph (a)(4) of this
section), in conjunction with projections of unit operating hours or fuel type and fuel usage,
according to one of the allowable calculation methodologies in paragraph (c) of this section;
and
§ 75.19(a)(2)(iii) (iii) A description of the methodology from paragraph (c) of this section that will be used
to demonstrate on-going compliance under paragraph (b) of this section; and
§ 75.19(a)(2)(iv) (iv) Appropriate documentation demonstrating that the unit is eligible to use projected
emissions to qualify for LME status under paragraph (a)(3) of this section (if applicable).
(3) In the following circumstances, projected emissions for a future year (or years) may
be used in lieu of the actual emissions data from one (or more) of the three years (or ozone
seasons) preceding the year of the certification application:
(i) If the owner or operator takes an enforceable permit restriction on the number of
annual or ozone season unit operating hours for the future year (or years), such that the unit
will emit no more than the applicable number of tons of S02 and/or NOx specified in
paragraph (a)(l)(i)(A) of this section; or
(ii) If the actual emissions for one (or more) of the three years (or ozone seasons) prior to
the year of the certification application is not representative of the present and expected future
emissions from the unit, because the owner or operator has recently installed emission controls
on the unit.
(4) When the owner or operator elects to demonstrate initial LME qualification and on-
going compliance using a fuel-and-unit-specific NOx emission rate in accordance with
paragraph (c)(l)(iv) of this section, there will be instances (e.g., for a new or newly-affected
unit) where it is not possible to determine that NOx emission rate prior to submitting the
certification application. In such cases, if the generic default NOx emission rates in Table
LM-2 of this section are inappropriately high for the unit, the owner or operator may use a
more representative, but conservatively high estimate of the expected NOx emission rate, for
the purposes of the initial monitoring plan submittal and to calculate the unit's projected
annual or ozone season emissions under paragraph (a)(2)(ii)(B) of this section. For example,
the NOx emission rate could, as described in paragraph (a)(2)(ii)(A) of this section, be
estimated using historical CEM data or historical emission test data that is representative of
operation at normal load. The NOx emission limit specified in the operating permit for the
unit could also be used to estimate the NOx emission rate (except for units equipped with SCR
or SNCR), or, consistent with paragraph (c)( I )(i\')(€')(-/) of this section, for a unit that uses
SCR or SNCR to control NOx emissions, an estimated default NOx emission rate of 0.15
lb/mmBtu could be used. However, these estimated NOx emission rates may not be used for
reporting purposes in the time period extending from the first hour in which the LME
methodology is used to the date and hour on which the fuel-and-unit-specific NOx emission
rate testing is completed. Rather, in that interval, the owner or operator shall either report the
appropriate default NOx emission rate from Table LM-2, or shall report the maximum
potential NOx emission rate, calculated in accordance with § 72.2 of this chapter and section
2.1.2.1 of appendix A to this part. Then, beginning with the first unit operating hour after
completion of the tests, the appropriate default NOx emission rate(s) obtained from the fuel-
and-unit-specific testing shall be used for emissions reporting.
§ 75.19(b) (b) On-going qualification and disqualification.
§ 75.19(a)(3)
§ 75.19(a)(3)®
§ 75.19(a)(3)(h)
§ 75.19(a)(4)
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 56
-------
§ 75.19(b)(1) (1) Once a low mass emissions unit has qualified for and has started using the low mass
emissions excepted methodology, an annual demonstration is required, showing that the unit
continues to emit no more than the applicable number of tons of S02 and/or NOx specified in
paragraph (a)(l)(i)(A) of this section. The calculation methodology used for the annual
demonstration shall be the methodology described in the certification application under
paragraph (a)(2)(iii) of this section.
§ 75.19(b)(2) (2) If any low mass emissions unit fails to provide the required annual demonstration
under paragraph (b)(1) of this section, such that the calculated cumulative emissions for the
unit exceed the applicable number of tons of S02 and/or NOx specified in paragraph
(a)(l)(i)(A) of this section at the end of any calendar year or ozone season, then:
(i) The low mass emissions unit shall be disqualified from using the low mass emissions
excepted methodology; and
(ii) The owner or operator of the low mass emissions unit shall install and certify
monitoring systems that meet the requirements of §§ 75.11, 75.12, and 75.13, and shall report
S02 (Acid Rain Program units, only), NOx, and C02 (Acid Rain Program units, only)
emissions data and heat input data from such monitoring systems by December 31 of the
calendar year following the year in which the unit exceeded the number of tons of S02 and/or
NOx specified in paragraph (a)(l)(i)(A) of this section; and
(iii) If the required monitoring systems have not been installed and certified by the
applicable deadline in paragraph (b)(2)(ii) of this section, the owner or operator shall report
the following values for each unit operating hour, beginning with the first operating hour after
the deadline and continuing until the monitoring systems have been provisionally certified: the
maximum potential hourly heat input for the unit, as defined in § 72.2 of this chapter; the S02
emissions, in lb/hr, calculated using the applicable default S02 emission rate from paragraph
(c)(l)(i) of this section and the maximum potential hourly unit heat input; the C02 emissions,
in tons/hr, calculated using the applicable default C02 emission rate from paragraph (c)(l)(iii)
of this section and the maximum potential hourly unit heat input; and the maximum potential
NOx emission rate, as defined in § 72.2 of this chapter.
§ 75.19(b)(3) (3) If a low mass emissions unit that initially qualifies to use the low mass emissions
excepted methodology under this section changes fuels, such that a fuel other than those
allowed for use in the low mass emissions methodology is combusted in the unit, the unit shall
be disqualified from using the low mass emissions excepted methodology as of the first hour
that the new fuel is combusted in the unit. The owner or operator shall install and certify S02
(Acid Rain Program units, only), NOx, and C02 (Acid Rain Program units, only) and flow (if
necessary) monitoring systems that meet the requirements of §§ 75.11, 75.12, and 75.13 prior
to a change to such fuel, and shall report emissions data from such monitoring systems
beginning with the date and hour on which the new fuel is first combusted in the unit. If the
required monitoring systems are not installed and certified prior to the fuel switch, the owner
or operator shall report (as applicable) the maximum potential concentration of S02, C02 and
NOx, the maximum potential NOx emission rate, the maximum potential flowrate, the
maximum potential hourly heat input and the maximum (or minimum, if appropriate) potential
moisture percentage, from the date and hour of the fuel switch until the monitoring systems
are certified or until probationary calibration error tests of the monitors are passed and the
conditional data validation procedures in § 75.20(b)(3) begin to be used. All maximum and
minimum potential values shall be specific to the new fuel and shall be determined in a
manner consistent with section 2 of appendix A to this part and § 72.2 of this chapter. The
owner or operator must notify the Administrator (or the permitting authority) in the case where
a unit switches fuels without previously having installed and certified a S02, NOx and C02
monitoring system meeting the requirements of §§ 75.11, 75.12, and 75.13.
§ 75.19(b)(4) (4) If a new or newly-affected unit initially qualifies to use the low mass emissions
excepted methodology under this section and the owner or operator wants to use the low mass
emissions methodology for the unit, he or she must:
(i) Keep the records specified in paragraph (c)(2) of this section, beginning with the date
and hour of commencement of commercial operation, for a new unit subject to an Acid Rain
emission limitation, and beginning with the date and hour of the commencement of operation,
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 57
-------
for a new unit subject to a NOx mass reduction program under subpart H of this part. For
newly-affected units, the records in paragraph (c)(2) of this section shall be kept as follows:
(A) For Acid Rain Program units, begin keeping the records as of the first hour of
commercial operation of the unit following the date on which the unit becomes affected; or
(B) For units subject to a NOx mass reduction program under subpart H of this part,
begin keeping the records as of the first hour of unit operation following the date on which the
unit becomes an affected unit;
(ii) Use these records to determine the cumulative heat input and S02, C02, and/or NOx
mass emissions in order to continue to qualify as a low mass emissions unit; and
(iii) Determine the cumulative S02 and/or NOx mass emissions according to paragraph (c)
of this section using the same procedures used after the certification deadline for the unit, for
purposes of demonstrating eligibility to use the excepted methodology set forth in this section.
For example, use the default emission rates in tables LM-1, LM-2, and LM-3 of this section or
use the fuel-and-unit-specific NOx emission rate determined according to paragraph (c)(l)(iv)
of this section. For Acid Rain Program LME units, the Administrator will not count S02 mass
emissions calculated for the period between commencement of commercial operation and the
certification deadline for the unit under § 75.4 against S02 allowances to be held in the unit
account.
§ 75.19(b)(5) (5) A low mass emissions unit that has been disqualified from using the low mass
emissions excepted methodology may subsequently submit an application to qualify again to
use the low mass emissions methodology under paragraph (a)(2) of this section only if,
following the non-compliant year (or ozone season), at least three full years (or ozone
seasons) of actual, monitored emissions data is obtained showing that the unit emitted no more
than the applicable number of tons of S02 and/or NOx specified in paragraph (a)(l)(i)(A) of
this section. Further, the designated representative or authorized account representative must
certify in the application that the unit operation for the years or ozone seasons for which the
emissions were monitored are representative of the projected future operation of the unit.
§ 75.19(c)(l)(i) (c) Low mass emissions excepted methodology, calculations, and values.
(1) Determination ofS02, NOx, and C02 emission rates.
(i) If the unit combusts only natural gas and/or fuel oil, use Table LM-1 of this section to
determine the appropriate S02 emission rate for use in calculating hourly S02 mass emissions
under this section. Alternatively, for fuel oil combustion, a lower, fuel-specific S02 emission
factor may be used in lieu of the applicable emission factor from Table LM-1, if a federally
enforceable permit condition is in place that limits the sulfur content of the oil. If this
alternative is chosen, the fuel-specific S02 emission rate in lb/mmBtu shall be calculated by
multiplying the fuel sulfur content limit (weight percent sulfur) by 1.01. In addition, the
owner or operator shall periodically determine the sulfur content of the oil combusted in the
unit, using one of the oil sampling and analysis options described in section 2.2 of appendix D
to this part, and shall keep records of these fuel sampling results in a format suitable for
inspection and auditing. Alternatively, the required oil sampling and associated recordkeeping
may be performed using a consensus standard (e.g., ASTM, API, etc.) that is prescribed in the
unit's Federally-enforceable operating permit, in an applicable State regulation, or in another
applicable Federal regulation. If the unit combusts gaseous fuel(s) other than natural gas, the
owner or operator shall use the procedures in section 2.3.6 of appendix D to this part to
document the total sulfur content of each such fuel and to determine the appropriate default
S02 emission rate for each such fuel.
§ 75.19(c)(l)(ii) (ii) If the unit combusts only natural gas and/or fuel oil, use either the appropriate NOx
emission factor from Table LM-2 of this section, or a fuel-and-unit-specific NOx emission rate
determined according to paragraph (c)(l)(iv) of this section, to calculate hourly NOx mass
emissions under this section. If the unit combusts a gaseous fuel other than pipeline natural
gas or natural gas, the owner or operator shall determine a fuel-and-unit-specific NOx
emission rate according to paragraph (c)(l)(iv) of this section.
§ 75.19(c)(l)(iii) (iii) If the unit combusts only natural gas and/or fuel oil, use Table LM-3 of this section to
determine the appropriate C02 emission rate for use in calculating hourly C02 mass emissions
under this section (Acid Rain Program units, only). If the unit combusts a gaseous fuel other
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 58
-------
§ 75.19(c)(l)(iii)(A)
§ 75.19(c)(l)(iii)(B)
than pipeline natural gas or natural gas, the owner or operator shall determine a fuel-and-unit-
specific C02 emission rate for the fuel, as follows:
(A) Derive a carbon-based F-factor for the fuel, using fuel sampling and analysis, as
described in section 3.3.6 of appendix F to this part; and
(B) Use Equation G-4 in appendix G to this part to derive the default C02 emission rate.
Rearrange the equation, solving it for the ratio of WCo2 /H (this ratio will yield an emission
rate, in units of tons/mmBtu). Then, substitute the carbon-based F-factor determined in
paragraph (c)(l)(iii)(A) of this section into the rearranged equation to determine the default
C02 emission rate for the unit.
§75.19(c)(l)(iv)
(iv) In lieu of using the default NOx emission rate from Table LM-2 of this section, the
owner or operator may, for each fuel combusted by a low mass emissions unit, determine a
fuel-and-unit-specific NOx emission rate for the purpose of calculating NOx mass emissions
under this section. This option may be used by any unit which qualifies to use the low mass
emissions excepted methodology under paragraph (a) of this section, and also by groups of
units which combust fuel from a common source of supply and which use the long term fuel
flow methodology under paragraph (c)(3)(ii) of this section to determine heat input. The
testing must be completed in a timely manner, such that the test results are reported
electronically no later than the end of the calendar year or ozone season in which the LME
methodology is first used. If this option is chosen, the following procedures shall be used.
§75.19(c)(l)(iv)(A)
(A) Except as otherwise provided in paragraphs (c)(l)(iv)(F), (c)(l)(iv)(G), and
(c)(l)(iv)(I) of this section, determine a fuel-and-unit-specific NOx emission rate by
conducting a four load NOx emission rate test procedure as specified in section 2.1 of
appendix E to this part, for each type of fuel combusted in the unit. For a group of units
sharing a common fuel supply, the appendix E testing must be performed on each individual
unit in the group, unless some or all of the units in the group belong to an identical group of
units, as defined in paragraph (c)(l)(iv)(B) of this section, in which case, representative
testing may be conducted on units in the identical group of units, as described in paragraph
(c)(l)(iv)(B) of this section. For the purposes of this section, make the following
modifications to the appendix E test procedures:
(/) Do not measure the heat input as required under 2.1.3 of appendix E to this part.
(2) Do not plot the test results as specified under 2.1.6 of appendix E to this part.
(3) Do not correct the NOx concentration to 15% 02.
(4) If the testing is performed on an uncontrolled diffusion flame turbine, a correction to
the observed average NOx concentration from each run of the test must be applied using the
following Equation LM-la.
NOx — AlOx
iyKJXcorr iyKJXobs
V-
{ \ 1-53
(Eq. LM-la)
Where:
NOxcorr = Corrected NOx concentration (ppm).
NOxobs = Average measured NOx concentration for each run of the test (ppm).
Pr = Average annual atmospheric pressure (or average ozone season atmospheric
pressure for a Subpart H unit that reports data only during the ozone season) at the
nearest weather station (e.g., a standardized NOAA weather station located at the
airport) for the year (or ozone season) prior to the year of the test (mm Hg).
PQ = Observed atmospheric pressure during the test run (mm Hg).
Hr = Average annual atmospheric humidity ratio (or average ozone season humidity
ratio for a Subpart H unit that reports data only during the ozone season) at the
nearest weather station, for the year (or ozone season) prior to the year of the test
(g H20/g air).
H0 = Observed humidity ratio during the test run (g H20/g air).
Tr = Average annual atmospheric temperature (or average ozone season atmospheric
temperature for a Subpart H unit that reports data only during the ozone season) at
the nearest weather station, for the year (or ozone season) prior to the year of the
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 59
-------
§ 75.19(c)(l)(iv)(B)
§ 75.19(c)(l)(iv)(B)(7j
§75.19(c)(l)(iv)(B)f2;
§75.19(c)(l)(iv)(B)f3;
§75.19(c)(l)(iv)(B)^
§75.19(c)(l)(iv)(B)fj;
§ 75.19(c)(l)(iv)(C)
§75.19(c)(l)(iv)(C)W
§ 75.19(c)(l)(iv)(C)f2j
§75.19(c)(l)(iv)(C)f3;
§ 75.19(c)(l)(iv)(C)(¥/)
§75.19(c)(l)(iv)(C)fj;
§75.19(c)(l)(iv)(C)f6j
test (° K).
Ta = Observed atmospheric temperature during the test run (° K).
(B) Representative appendix E testing may be done on low mass emissions units in a
group of identical units. All of the units in a group of identical units must combust the same
fuel type but do not have to share a common fuel supply.
(1) To be considered identical, all low mass emissions units must be of the same size
(based on maximum rated hourly heat input), manufacturer and model, and must have the
same history of modifications (e.g., have the same controls installed, the same types of burners
and have undergone major overhauls at the same frequency (based on hours of operation)).
Also, under similar operating conditions, the stack or turbine outlet temperature of each unit
must be within + 50 degrees Fahrenheit of the average stack or turbine outlet temperature for
all of the units.
(2) If all of the low mass emissions units in the group qualify as identical, then
representative testing of the units in the group may be performed according to Table LM-4 of
this section.
(3) [Reserved]
(4) If the acceptance criteria in paragraph (c)( 1 )(iv)(B)( /) of this section are not met then
the group of low mass emissions units is not considered an identical group of units and
individual appendix E testing of each unit is required.
(5) Fuel and unit specific NOx emission rates determined according to paragraphs
(c)(l)(iv)(F) and (c)(l)(iv)(G) of this section may be used in lieu of appendix E testing for one
or more low mass emissions units in a group of identical units.
(C) Based on the results of the part 75 appendix E testing, determine the fuel-and-unit-
specific NOx emission rate as follows:
(/) Except for LME units that use selective catalytic reduction (SCR) or selective non-
catalytic reduction (SNCR) to control NOx emissions, the highest three-run average NOx
emission rate obtained at any load in the appendix E test for a particular type of fuel shall be
the fuel-and-unit-specific NOx emission rate, for that type of fuel.
(2) [Reserved]
(3) For a group of identical low mass emissions units (except for units that use SCR or
SNCR to control NOx emissions), the fuel-and-unit-specific NOx emission rate for all units in
the group, for a particular type of fuel, shall be the highest three-run average NOx emission
rate obtained at any tested load from any unit tested in the group, for that type of fuel.
(4) Except as provided in paragraphs (c)(l)(iv)(C)( 7) and (c)(l)(iv)(C)(8) of this section,
for an individual low mass emissions unit which uses SCR or SNCR to control NOx emissions,
the fuel-and-unit-specific NOx emission rate for each type of fuel combusted in the unit shall
be the higher of:
(/') The highest three-run average emission rate from any load of the appendix E test for
that type of fuel; or (/'/') 0.15 lb/mmBtu.
(5) [Reserved]
(6) Except as provided in paragraphs (c)(l)(iv)(C)( 7) and (c)(l)(iv)(C)(8) of this section,
for a group of identical low mass emissions units that are all equipped with SCR or SNCR to
control NOx emissions, the fuel-and-unit-specific NOx emission rate for each unit in the group
of units, for a particular type of fuel, shall be the higher of:
(/') The highest three-run average NOx emission rate at any load from all appendix E tests
of all tested units in the group, for that type of fuel; or
(/'/') 0.15 lb/mmBtu.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 60
-------
§75.19(c)(l)(iv)(C)f7;
(7) Notwithstanding the requirements of paragraphs (c)(l)(iv)(C)(4) and (c)(l)(iv)(C)(6)
of this section, for a unit (or group of identical units) equipped with SCR (or SNCR) and
water (or steam) injection to control NOx emissions:
(/') If the appendix E testing is performed when the water (or steam) injection is in use
and either upstream of the SCR or SNCR or during a time period when the SCR or SNCR is
out of service; then
(/'/') The highest three-run average emission rate from the appendix E testing may be used
as the fuel-and-unit-specific NOx emission rate for the unit (or, if applicable, for each unit in
the group), for each unit operating hour in which the water-to-fuel ratio is within the
acceptable range established during the appendix E testing.
§ 75.19(c)(l)(iv)(C)fSj
§75.19(c)(l)(iv)(C)fP;
§75.19(c)(l)(iv)(D)
(H) Notwithstanding the requirements of paragraphs (c)(l)(iv)(C)(4) and (c)(l)(iv)(C)(6)
of this section, for a unit (or group of identical units) equipped with SCR (or SNCR) and uses
dry low-NOx technology to control NOx emissions:
(/') If the appendix E testing is performed during a time period when the dry low-NOx
controls are in use, but the SCR or SNCR is out of service; then
(/'/') The highest three-run average emission rate from the appendix E testing may be used
as the fuel-and-unit-specific NOx emission rate for the unit (or, if applicable, for each unit in
the group), for each unit operating hour in which the parametric data described in paragraph
(c)(l)(iv)(H)(2) of this section demonstrate that the dry low-NOx controls are operating in the
premixed or low-NOx mode.
(9) For an individual combustion turbine (or a group of identical turbines) that operate
principally at base load (or at a set point temperature), but are capable of operating at a higher
peak load (or higher internal operating temperature), the fuel-and-unit-specific NOx emission
rate for the unit (or for each unit in the group) shall be as follows:
(i) If the testing is done only at base load, use the three-run average NOx emission rate
for base load operating hours and 1.15 times that emission rate for peak load operating hours;
or
(/'/') If the testing is done at both base load and peak load, use the three-run average NOx
emission rate from the base load testing for base load operating hours and the three-run
average NOx emission rate from the peak load testing for peak load operating hours.
(D) For each low mass emissions unit or group of identical units for which the provisions
of paragraph (c)(l)(iv) of this section are used to account for NOx emission rate, the owner or
operator shall determine a new fuel-and-unit-specific NOx emission rate every five years (20
calendar quarters), unless changes in the fuel supply, physical changes to the unit, changes in
the manner of unit operation, or changes to the emission controls occur which may cause a
significant increase in the unit's actual NOx emission rate. If such changes occur, the fuel-and-
unit-specific NOx emission rate(s) shall be re-determined according to paragraph (c)(l)(iv) of
this section. Testing shall be done at the number of loads specified in paragraph (c)(l)(iv)(A)
or (c)(l)(iv)(I) of this section, as applicable. If a low mass emissions unit belongs to a group
of identical units and it is required to retest to determine a new fuel-and-unit-specific NOx
emission rate because of changes in the fuel supply, physical changes to the unit, changes in
the manner of unit operation or changes to the emission controls occur which may cause a
significant increase in the unit's actual NOx emission rate, any other unit in that group of
identical units is not required to re-determine the fuel-and-unit-specific NOx emission rate
unless such unit also undergoes changes in the fuel supply, physical changes to the unit,
changes in the manner of unit operation or changes to the emission controls occur which may
cause a significant increase in the unit's actual NOx emission rates.
§75.19(c)(l)(iv)(E)
(E) Each low mass emissions unit or each low mass emissions unit in a group of identical
units for which a fuel-and-unit-specific NOx emission rate(s) are determined shall meet the
quality assurance and quality control provisions of paragraph (e) of this section.
§75.19(c)(l)(iv)(F)
(F) Low mass emissions units may use the results of appendix E testing, if such test
results are available from a test conducted no more than five years prior to the time of initial
certification, to determine the appropriate fuel-and unit-specific NOx emission rate(s).
However, fuel-and-unit-specific NOx emission rates from historical testing may not be used
longer than five years after the appendix E testing was conducted.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 61
-------
§ 75.19(c)(l)(iv)(G) (G) Low mass emissions units for which at least three years of quality-assured NOx
emission rate data from a NOx-diluent CEMS that meets the quality assurance requirements of
either: this part, or appendix F to part 60 of this chapter, or a comparable State CEM
program, and corresponding fuel usage data are available may determine fuel-and-unit-
specific NOx emission rates from the actual data using the following procedure. Separate the
actual NOx emission rate data into groups, according to the type of fuel combusted. Discard
data from periods when multiple fuels were combusted. Each fuel-specific data set must
contain at least 168 hours of data and must represent all normal operating ranges of the unit
when combusting the fuel. Sort the data in each fuel-specific data set in ascending order
according to NOx emission rate. Determine the 95th percentile NOx emission rate for each
data set as defined in § 72.2 of this chapter. Use the 95th percentile value for each data set as
the fuel-and-unit-specific NOx emission rate, except that for a unit that uses SCR or SNCR for
NOx emission control, if the 95th percentile value is less than 0.15 lb/mmBtu, a value of 0.15
lb/mmBtu shall be used as the fuel-and-unit-specific NOx emission rate.
§ 75.19(c)(l)(iv)(H) (H) For low mass emissions units with add-on NOx emission controls, and for units that
use dry low-NOx technology, the owner or operator shall, during every hour of unit operation
during the test period, monitor and record parameters, as required under paragraph (e)(5) of
this section, which indicate that the NOx emission controls are operating properly. After the
test period, these same parameters shall be monitored and recorded and kept for all operating
hours in order to determine whether the NOx controls are operating properly and to allow the
determination of the correct NOx emission rate as required under paragraph (c)(l)(iv) of this
section.
(/) For low mass emissions units with steam or water injection, the steam-to-fuel or
water-to-fuel ratio used during the testing must be documented. The water-to-fuel or steam-
to-fuel ratio must be maintained during unit operations for a unit to use the fuel and unit
specific NOx emission rate determined during the test. Owners or operators must include in
the monitoring plan the acceptable range of the water-to-fuel or steam-to-fuel ratio, which will
be used to indicate hourly, proper operation of the NOx controls for each unit. The water-to-
fuel or steam-to-fuel ratio shall be monitored and recorded during each hour of unit operation.
If the water-to-fuel or steam-to-fuel ratio is not within the acceptable range in a given hour the
fuel and unit specific NOx emission rate may not be used for that hour, and the appropriate
default NOx emission rate from Table LM-2 shall be reported instead.
(2) For a low mass emissions unit that uses dry low-NOx premix technology to control
NOx emissions, proper operation of the emission controls means that the unit is in the low-
NOx or premixed combustion mode, and fired with natural gas. Evidence of operation in the
low-NOx or premixed mode shall be provided by monitoring the appropriate turbine operating
parameters. These parameters may include percentage of full load, turbine exhaust
temperature, combustion reference temperature, compressor discharge pressure, fuel and air
valve positions, dynamic pressure pulsations, internal guide vane (IGV) position, and flame
detection or flame scanner condition. The acceptable values and ranges for all parameters
monitored shall be specified in the monitoring plan for the unit, and the parameters shall be
monitored during each subsequent operating hour. If one or more of these parameters is not
within the acceptable range or at an acceptable value in a given operating hour, the fuel-and-
unit-specific NOx emission rate may not be used for that hour, and the appropriate default NOx
emission rate from Table LM-2 shall be reported instead. When the unit is fired with oil the
appropriate default value from Table LM-2 shall be reported.
(3) For low mass emissions units with other types of add-on NOx controls, appropriate
parameters and the acceptable range of the parameters which indicate hourly proper operation
of the NOx controls must be specified in the monitoring plan. These parameters shall be
monitored during each subsequent operating hour. If any of these parameters are not within
the acceptable range in a given operating hour, the fuel-and-unit specific NOx emission rates
may not be used in that hour, and the appropriate default NOx emission rate from Table LM-2
shall be reported instead.
§ 75.19 (c)(l)(iv)(I) (I) Notwithstanding the requirements in paragraph (c)(l)(iv)(A) of this section, the
appendix E testing to determine (or re-determine) the fuel-specific, unit-specific NOx emission
rate for a unit (or for each unit in a group of identical units) may be performed at fewer than
four loads, under the following circumstances:
(/) Testing may be done at one load level if the data analysis described in paragraph
(c)(l)(iv)(J) of this section is performed and the results show that the unit has operated (or all
units in the group of identical units have operated) at a single load level for at least 85.0
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 62
-------
percent of all operating hours in the previous three years (12 calendar quarters) prior to the
calendar quarter of the appendix E testing. For combustion turbines that are operated to
produce approximately constant output (in MW) but which use internal operating and exhaust
temperatures and not the actual output in MW to control the operation of the turbine, the
internal operating temperature set point may be used as a surrogate for load in demonstrating
that the unit qualifies for single-load testing. If the data analysis shows that the unit does not
qualify for single-load testing, testing may be done at two (or three) load levels if the unit has
operated (or if all units in the group of identical units have operated) cumulatively at two (or
three) load levels for at least 85.0 percent of all operating hours in the previous three years; or
(2) If a multiple-load appendix E test was initially performed for a unit (or group of
identical units) to determine the fuel-and-unit specific NOx emission rate, then the periodic
retests required under paragraph (c)(l)(iv)(D) of this section may be single-load tests,
performed at the load level for which the highest average NOx emission rate was obtained in
the initial test.
(3) The initial appendix E testing may be performed at a single load, between 75 and 100
percent of the maximum sustainable load defined in the monitoring plan for the unit, if the
average annual capacity factor of the LME unit, when calculated according to the definition of
"capacity factor" in §72.2 of this chapter, is 2.5 percent or less for the three calendar years
immediately preceding the year of the testing, and that the annual capacity factor does not
exceed 4.0 percent in any of those three years. Similarly, for a LME unit that reports
emissions data on an ozone season-only basis, the initial appendix E testing may be performed
at a single load between 75 and 100 percent of the maximum sustainable load if the 2.5 and
4.0 percent capacity factor requirements are met for the three ozone seasons immediately
preceding the date of the emission testing (see §75.74(c)(l 1)). For a group of identical LME
units, any unit(s) in the group that meet the 2.5 and 4.0 percent capacity factor requirements
may perform the initial appendix E testing at a single load between 75 and 100 percent of the
maximum sustainable load.
(4) The retest of any LME unit may be performed at a single load between 75 and 100
percent of the maximum sustainable load if, for the three calendar years immediately
preceding the year of the retest (or, if applicable, the three ozone seasons immediately
preceding the date of the retest), the applicable capacity factor requirements described in
paragraph (c)(l)(iv)(I)(3) of this section are met.
(5) Alternatively, for combustion turbines, the single-load testing described in paragraphs
(c)(l)(iv)(I)(3) and (c)(l)(iv)(I)(4) of this section may be performed at the highest attainable
load level corresponding to the season of the year in which the testing is conducted.
(6) In all cases where the alternative single-load testing option described in paragraphs
(c)(l)(iv)(I)(3) and (c)(l)(iv)(I)(5)of this section is used, the owner or operator shall keep
records documenting that the required capacity factor requirements were met.
§ 75.19 (c)(l)(iv)(J) (J) To determine whether a unit qualifies for testing at fewer than four loads under
paragraph (c)(l)(iv)(I) of this section, follow the procedures in paragraph (c)(l)(iv)(J)( /') or
(c)(l)(iv)(J)(//) of this section, as applicable.
(/') Determine the range of operation of the unit, according to section 6.5.2.1 of appendix
A to this part. Divide the range of operation into four equal load bands. For example, if the
range of operation extends from 20 MW to 100 MW, the four equal load bands would be:
band # 1: from 20 MW to 40 MW; band #2: from 41 MW to 60 MW; band #3: from 61 MW
to 80 MW; and band # 4: from 81 to 100 MW. Then, perform a historical load analysis for all
unit operating hours in the 12 calendar quarters preceding the quarter of the test.
Alternatively, for sources that report emissions data only during the ozone season, the
historical load analysis may be based on unit operation in the previous three ozone seasons,
rather than unit operation in the previous 12 calendar quarters. Determine the percentage of
the data that fall into each load band. For a unit that is not part of a group of identical units, if
85.0% or more of the data fall into one load band, single-load testing may be performed at any
point within that load band. For a group of identical units, if each unit in the group meets the
85.0% criterion, then representative single-load testing within the load band may be
performed. If the 85.0% criterion cannot be met to qualify for single-load testing but this
criterion can be met cumulatively for two (or three) load levels, then testing may be performed
at two (or three) loads instead of four.
(/'/') For a combustion turbine that uses exhaust temperature and not the actual output in
megawatts to control the operation of the turbine (or for a group of identical units of this
type), the owner or operator must document that the unit (or each unit in the group) has
operated within + 10% of the set point temperature for 85.0% of the operating hours in the
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 63
-------
§ 75.19(c)(2)
§ 75.19(c)(2)®
§ 7 5.19(c)(2)(ii)
§ 7 5.19(c)(2)(iii)
§75.19(c)(2)(iv)
§ 75.19(c)(3)
previous 12 calendar quarters to qualify for single-load testing. Alternatively, for sources that
report emissions data only during the ozone season, the historical set point temperature
analysis may be based on unit operation in the previous three ozone seasons, rather than unit
operation in the previous 12 calendar quarters. When the set point temperature is used rather
than unit load to justify single-load testing, the designated representative shall certify in the
monitoring plan for the unit that this is the normal manner of unit operation and shall
document the setpoint temperature.
(2) Records of operating time, fuel usage, unit output and NOx emission control
operating status. The owner or operator shall keep the following records on-site, for three
years, in a form suitable for inspection, except that for unmanned facilities, the records may be
kept at a central location, rather than on-site:
(i) For each low mass emissions unit, the owner or operator shall keep hourly records
which indicate whether or not the unit operated during each clock hour of each calendar year.
The owner or operator may report partial operating hours or may assume that for each hour
the unit operated the operating time is a whole hour. Units using partial operating hours and
the maximum rated hourly heat input to calculate heat input for each hour must report partial
operating hours.
(ii) For each low mass emissions unit, the owner or operator shall keep hourly records
indicating the type(s) of fuel(s) combusted in the unit during each hour of unit operation.
(iii) For each low mass emissions unit using the long term fuel flow methodology under
paragraph (c)(3)(ii) of this section to determine hourly heat input, the owner or operator shall
keep hourly records of unit load (in megawatts or thousands of pounds of steam per hour), for
the purpose of apportioning heat input to the individual unit operating hours.
(iv) For each low mass emissions unit with add-on NOx emission controls of any kind and
each unit that uses dry low-NOx technology, the owner or operator shall keep hourly records
of the hourly value of the parameter(s) specified in (c)(l)(iv)(H) of this section used to
indicate proper operation of the unit's NOx controls.
(3) Heat input. Hourly, quarterly and annual heat input for a low mass emissions unit
shall be determined using either the maximum rated hourly heat input method under paragraph
(c)(3)(i) of this section or the long term fuel flow method under paragraph (c)(3)(ii) of this
section.
§75.19(c)(3)®
(i) Maximum rated hourly heat input method.
(A) For the purposes of the mass emission calculation methodology of paragraph (c)(3) of
this section, HIhr. the hourly heat input (mmBtu) to a low mass emissions unit shall be deemed
to equal the maximum rated hourly heat input, as defined in § 72.2 of this chapter, multiplied
by the operating time of the unit for each hour. The owner or operator may choose to record
and report partial operating hours or may assume that a unit operated for a whole hour for
each hour the unit operated. However, the owner or operator of a unit may petition the
Administrator under § 75.66 for a lower value for maximum rated hourly heat input than that
defined in § 72.2 of this chapter. The Administrator may approve such lower value if the
owner or operator demonstrates that either the maximum hourly heat input specified by the
manufacturer or the highest observed hourly heat input, or both, are not representative, and
such a lower value is representative, of the unit's current capabilities because modifications
have been made to the unit, limiting its capacity permanently.
(B) The quarterly heat input, HIqtr, in mmBtu, shall be determined using Equation LM-1:
HI,,, = I HIir
(Eq. LM-1)
Where:
n = Number of unit operating hours in the quarter.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 64
-------
HIhr = Hourly heat input under paragraph (c)(3)(i)(A) of this section (mmBtu).
(C) The year-to-date cumulative heat input (mmBtu) shall be the sum of the quarterly heat
input values for all of the calendar quarters in the year to date.
(D) For a unit subject to the provisions of subpart H of this part, which is not required to
report emission data on a year-round basis and elects to report only during the ozone season,
the quarterly heat input for the second calendar quarter of the year shall, for compliance
purposes, include only the heat input for the months of May and June, and the cumulative
ozone season heat input shall be the sum of the heat input values for May, June and the third
calendar quarter of the year.
§ 75.19(c)(3)(ii) (ii) Long term fuel flow heat input method. The owner or operator may, for the purpose
of demonstrating that a low mass emissions unit or group of low mass emissions units sharing
a common fuel supply meets the requirements of this section, use records of long-term fuel
flow, to calculate hourly heat input to a low mass emissions unit.
§75.19(c)(3)(ii)(A)
(A) This option may be used for a group of low mass emissions units only if:
(1) The low mass emissions units combust fuel from a common source of supply; and
(2) Records are kept of the total amount of fuel combusted by the group of low mass
emissions units and the hourly output (in megawatts or pounds of steam) from each unit in the
group; and
(3) All of the units in the group are low mass emissions units.
§ 75.19(c)(3)(ii)(B)
(B) For each fuel used during the quarter, the volume in standard cubic feet (for gas) or
gallons (for oil) may be determined using any of the following methods;
(1) Fuel billing records (for low mass emissions units, or groups of low mass emissions
units, which purchase fuel from non-affiliated sources);
(2) American Petroleum Institute (API) Manual of Petroleum Measurement Standards,
Chapter 3- Tank Gauging, Section 1A, Standard Practice for the Manual Gauging of
Petroleum and Petroleum Products, Second Edition, August 2005; Section IB-Standard
Practice for Level Measurement of Liquid Hydrocarbons in Stationary Tanks by Automatic
Tank Gauging, Second Edition June 2001; Section 2-Standard Practice for Gauging Petroleum
and Petroleum Products in Tank Cars, First Edition, August 1995 (Reaffirmed March 2006);
Section 3-Standard Practice for Level Measurement of Liquid Hydrocarbons in Stationary
Pressurized Storage Tanks by Automatic Tank Gauging, First Edition June 1996 (Reaffirmed,
March 2001); Section 4-Standard Practice for Level Measurement of Liquid Hydrocarbons on
Marine Vessels by Automatic Tank Gauging, First Edition April 1995 (Reaffirmed,
September 2000); and Section 5-Standard Practice for Level Measurement of Light
Hydrocarbon Liquids Onboard Marine Vessels by Automatic Tank Gauging, First Edition
March 1997 (Reaffirmed, March 2003); for § 75.19; Shop Testing of Automatic Liquid Level
Gages, Bulletin 2509 B, December 1961 (Reaffirmed August 1987, October 1992) (all
incorporated by reference under § 75.6 of this part); or;
(3) A fuel flow meter certified and maintained according to appendix D to this part.
§75.19(c)(3)(ii)(C)
(C) Except as provided in paragraph (c)(3)(ii)(C)(3) of this section, for each fuel
combusted during a quarter, the gross calorific value of the fuel shall be determined by either:
(1) Using the applicable procedures for gas and oil analysis in sections 2.2 and 2.3 of
appendix D to this part. If this option is chosen the highest gross calorific value recorded
during the previous calendar year shall be used (or, for a new or newly-affected unit, if there
are no sample results from the previous year, use the highest GCVfrom the samples taken in
the current year); or
(2) Using the appropriate default gross calorific value listed in Table LM-5 of this
section.
(3) For gaseous fuels other than pipeline natural gas or natural gas, the GCV sampling
frequency shall be daily unless the results of a demonstration under section 2.3.5 of appendix
D to this part show that the fuel has a low GCV variability and qualifies for monthly sampling.
If daily GCV sampling is required, use the highest GCV obtained in the calendar quarter as
GCVmax in Equation LM-3 of this section.
§75.19(c)(3)(ii)(D)
(D) If Eq. LM-2 is used for heat input determination, the specific gravity of each type of
fuel oil combusted during the quarter shall be determined either by:
(I) Using the procedures in section 2.2.6 of appendix D to this part. If this option is
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 65
-------
chosen, use the highest specific gravity value recorded during the previous calendar year (or,
for a new or newly-affected unit, if there are no sample results from the previous year, use the
highest specific gravity from the samples taken in the current year); or
(2) Using the appropriate default specific gravity value in Table LM-6 of this section.
§ 75.19(c)(3)(ii)(E) (E) The quarterly heat input from each type of fuel combusted during the quarter by a low
mass emissions unit or group of low mass emissions units sharing a common fuel supply shall
be determined using either Equation LM-2 or Equation LM-3 for oil (as applicable to the
method used to quantify oil usage) and Equation LM-3 for gaseous fuels. For a unit subject to
the provisions of subpart H of this part, which is not required to report emission data on a
year-round basis and elects to report only during the ozone season, the quarterly heat input for
the second calendar quarter of the year shall include only the heat input for the months of May
and June.
HI
fuel-qtr
M
qtr
GCK
106
Eq. LM-2 (for fuel oil)
Where:
Hlfuel-qtr
M,
-qtr
GCVmax -
106 =
Quarterly total heat input from oil (mmBtu).
Mass of oil consumed during the quarter, determined as the product of the volume
of oil under paragraph (c)(3)(ii)(B) of this section and the specific gravity under
paragraph (c)(3)(ii)(D) of this section (lb).
Gross calorific value of oil, as determined under paragraph (c)(3)(ii)(C) of this
section (Btu/lb)
Conversion of Btu to mmBtu.
HI
fuel-qtr
= a
GCF
qtr
106
Eq. LM-3 (for gaseous fuel or fuel oil)
Where:
HI fuel-qtr '
Qqtr =
GCV max =
106 =
Quarterly heat input from gaseous fuel or fuel oil (mmBtu).
Volume of gaseous fuel or fuel oil combusted during the quarter, as
determined under paragraph (c)(3)(ii)(B) of this section standard cubic feet
(scf) or (gal), as applicable.
Gross calorific value of the gaseous fuel or fuel oil combusted during the
quarter, as determined under paragraph (c)(3)(ii)(C) of this section (Btu/scf)
or (Btu/gal), as applicable.
Conversion of Btu to mmBtu.
§ 75.19(c)(3)(ii)(F) (F) Use Eq. LM-4 to calculate HIqtr.total, the quarterly heat input (mmBtu) for all fuels.
Hlqtr-totai, shall be the sum of the HIfaei_qtr values determined using Equations LM-2 and LM-3.
HI qtr-total ~ m fuel-qtr
all- fuels
(Eq. LM-4)
§ 75.19(c)(3)(ii)(G) (G) The year-to-date cumulative heat input (mmBtu) for all fuels shall be the sum of all
quarterly total heat input (HIqtr.total) values for all calendar quarters in the year to date. For a
unit subject to the provisions of subpart H of this part, which is not required to report emission
data on a year-round basis and elects to report only during the ozone season, the cumulative
ozone season heat input shall be the sum of the quarterly heat input values for the second and
third calendar quarters of the year.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 66
-------
§ 75.19(c)(3)(ii)(H)
(H) For each low mass emissions unit or each low mass emissions unit in a group of
identical units, the owner or operator shall determine the cumulative quarterly unit load in
megawatt hours or thousands of pounds of steam. The quarterly cumulative unit load shall be
the sum of the hourly unit load values recorded under paragraph (c)(2) of this section and shall
be determined using Equations LM-5 or LM-6. For a unit subject to the provisions of subpart
H of this part, which is not required to report emission data on a year-round basis and elects to
report only during the ozone season, the quarterly cumulative load for the second calendar
quarter of the year shall include only the unit loads for the months of May and June.
all-hours
Eq. LM-5 (for MW output)
ST
qtr
1st
all-hours
Eq. LM-6 (for steam output)
Where:
MWqtr =
^Tfuel-qtr '
MW =
ST
Sum of all unit operating loads recorded during the quarter by the unit
(MWh).
Sum of all hourly steam loads recorded during the quarter by the unit (klb of
steam/hr).
Unit operating load for a particular unit operating hour (MWh).
Unit steam load for a particular unit operating hour (klb of steam).
§ 75.19(c)(3)(ii)(I)
(I) For a low mass emissions unit that is not included in a group of low mass emissions
units sharing a common fuel supply, apportion the total heat input for the quarter, HIqtr.totai to
each hour of unit operation using either Equation LM- 7 or LM-8:
(Eq LM-7 for MW output)
MWkr
TTJ _ TTJ ?1L_
hr qtr— total * /fTJf
qtr
ST
ZTJ _ ZTJ ° hr
hr qtr-total '
(Eq LM-8 for steam output)
Where:
HIhl = Hourly heat input to the unit (mmBtu).
MW|, = Hourly operating load for the unit (MW).
SThr= Hourly steam load for the unit (klb of steam/hr).
§ 75.19(c)(3)(ii)(J) (J) For each low mass emissions unit that is included in a group of units sharing a
common fuel supply, apportion the total heat input for the quarter, ff!qlr-,olai to each hour of
operation using either Equation LM-7a or LM-8a:
hr qtr- total
MWhl.
I MWq,r
all-units
(Eq LM-7a for MW output)
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 67
-------
hr HI qtr-total
ST,
hr
1st
all-units
qtr
(Eq LM-8a for steam output)
Where:
HIhl = Hourly heat input to the individual unit (mmBtu).
MWhr = Hourly operating load for the individual unit (MW).
SThl = Hourly steam load for the individual unit (klb of steam/hr).
V.\= Sum of the quarterly operating loads (from Eq. LM-5) for all units in
all-units the group (MW).
X STqtr = Sum of the quarterly steam loads (from Eq. LM-6) for all units in the
all-units group (klb of steam/hr).
§ 75.19(c)(4) (4) Calculation ofS02, NOx and C02 mass emissions. The owner or operator shall, for
the purpose of demonstrating that a low mass emissions unit meets the requirements of this
section, calculate S02, NOx and C02 mass emissions in accordance with the following.
§ 75.19(c)(4)(i) (i) S02 Mass Emissions.
(A) The hourly S02 mass emissions (lbs) for a low mass emissions unit (Acid Rain
Program units, only) shall be determined using Equation LM-9 and the appropriate fuel-based
S02 emission factor for the fuels combusted in that hour. If more than one fuel is combusted
in the hour, use the highest emission factor for all of the fuels combusted in the hour. If
records are missing as to which fuel was combusted in the hour, use the highest emission
factor for all of the fuels capable of being combusted in the unit.
^S02 ~ EFs02 X HIhr
(Eq. LM-9)
Where:
11'so: = Hourly S02 mass emissions (lbs).
EFS02 = Either the S02 emission factor from Table LM-1 of this section or the fuel-and-unit-
specific S02 emission rate from paragraph (c)(l)(i) of this section (lb/mmBtu).
HIhl = Either the maximum rated hourly heat input under paragraph (c)(3)(i)(A) of this
section or the hourly heat input under paragraph (c)(3)(ii) of this section (mmBtu).
(B) The quarterly S02 mass emissions (tons) for the low mass emissions unit shall be the
sum of all the hourly S02 mass emissions in the quarter, as determined under paragraph
(c)(4)(i)(A) of this section, divided by 2000 lb/ton.
(C) The year-to-date cumulative S02 mass emissions (tons) for the low mass emissions
unit shall be the sum of the quarterly S02 mass emissions, as determined under paragraph
(c)(4)(i)(B) of this section, for all of the calendar quarters in the year to date.
§ 75.19(c)(4)(ii) (ii) NOx mass emissions and NOx emission rate.
(A) The hourly NOx mass emissions for the low mass emissions unit (lbs) shall be
determined using Equation LM-10. If more than one fuel is combusted in the hour, use the
highest emission rate for all of the fuels combusted in the hour. If records are missing as to
which fuel was combusted in the hour, use the highest emission factor for all of the fuels
capable of being combusted in the unit. For low mass emissions units with NOx emission
controls of any kind and for which a fuel-and-unit-specific NOx emission rate is determined
under paragraph (c)(l)(iv) of this section, for any hour in which the parameters under
paragraph (c)(l)(iv)(A) of this section do not show that the NOx emission controls are
operating properly, use the NOx emission rate from Table LM-2 of this section for the fuel
combusted during the hour with the highest NOx emission rate.
WNOx = EFNOx X HI hr
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 68
-------
(Eq. LM-10)
Where:
Il'xo, = Hourly NOx mass emissions (lbs).
EFNOx = Either the NOx emission factor from Table LM-2 of this section or the fuel-and
unit-specific NOx emission rate determined under paragraph (c)(l)(iv) of this
section (lb/mmBtu).
HIhr = Either the maximum rated hourly heat input from paragraph (c)(3)(i)(A) of this
section or the hourly heat input as determined under paragraph (c)(3)(ii) of this
section (mmBtu).
(B) The quarterly NOx mass emissions (tons) for the low mass emissions unit shall be the
sum of all of the hourly NOx mass emissions in the quarter, as determined under paragraph
(c)(4)(ii)(A) of this section, divided by 2000 lb/ton.
(C) The year-to-date cumulative NOx mass emissions (tons) for the low mass emissions
unit shall be the sum of the quarterly NOx mass emissions, as determined under paragraph
(c)(4)(ii)(B) of this section, for all of the calendar quarters in the year to date. For a unit
subject to the provisions of subpart H of this part, which is not required to report emission
data on a year-round basis and elects to report only during the ozone season, the ozone season
NOx mass emissions for the unit shall be the sum of the quarterly NOx mass emissions, as
determined under paragraph (c)(4)(ii)(B) of this section, for the second and third calendar
quarters of the year, and the second quarter report shall include emissions data only for May
and June.
(D) The quarterly and cumulative NOx emission rate in lb/mmBtu (if required by the
applicable program(s)) shall be determined as follows. Calculate the quarterly NOx emission
rate by taking the arithmetic average of all of the hourly EFNOx values. Calculate the
cumulative (year-to-date) NOx emission rate by taking the arithmetic average of the quarterly
NOx emission rates.
§ 75.19(c)(4)(iii) (iii) C02 Mass Emissions.
(A) The hourly C02 mass emissions (tons) for the affected low mass emissions unit (Acid
Rain Program units, only) shall be determined using Equation LM-11 and the appropriate fuel-
based C02 emission factor from Table LM-3 of this section for the fuel being combusted in
that hour. If more than one fuel is combusted in the hour, use the highest emission factor for
all of the fuels combusted in the hour. If records are missing as to which fuel was combusted
in the hour, use the highest emission factor for all of the fuels capable of being combusted in
the unit.
WC02 = EFC02 X HIhr
(Eq.LM-11)
Where:
WCo2 = Hourly C02 mass emissions (tons).
EFC02 = Either the fuel-based C02 emission factor from Table LM-3 of this section or the
fuel-and-unit-specific C02 emission rate from paragraph (c)(l)(iii) of this section
(tons /mmBtu).
HIhr = Either the maximum rated hourly heat input from paragraph (c)(3)(i)(A) of this
section or the hourly heat input as determined under paragraph (c)(3)(ii) of this
section (mmBtu).
(B) The quarterly C02 mass emissions (tons) for the low mass emissions unit shall be the
sum of all of the hourly C02 mass emissions in the quarter, as determined under paragraph
(c)(4)(iii)(A) of this section.
(C) The year-to-date cumulative C02 mass emissions (tons) for the low mass emissions
unit shall be the sum of all of the quarterly C02 mass emissions, as determined under
paragraph (c)(4)(iii)(B) of this section, for all of the calendar quarters in the year to date.
§ 75.19(d) (d) Each unit that qualifies under this section to use the low mass emissions methodology
must follow the recordkeeping and reporting requirements pertaining to low mass emissions
units in subparts F and G of this part.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 69
-------
§ 75.19(e)
§ 75.19(e)(1)
§ 75.19(e)(2)
§ 75.19(e)(3)
§ 75.19(e)(4)
(e) The quality control and quality assurance requirements in § 75.21 are not applicable to
a low mass emissions unit for which the low mass emissions excepted methodology under
paragraph (c) of this section is being used in lieu of a continuous emission monitoring system
or an excepted monitoring system under appendix D or E to this part, except for fuel
flowmeters used to meet the provisions in paragraph (c)(3)(ii) of this section. However, the
owner or operator of a low mass emissions unit shall implement the following quality
assurance and quality control provisions:
(1) For low mass emissions units or groups of units which use the long term fuel flow
methodology under paragraph (c)(3)(ii) of this section and which use fuel billing records to
determine fuel usage, the owner or operator shall keep, at the facility, for three years, the
records of the fuel billing statements used for long term fuel flow determinations.
(2) For low mass emissions units or groups of units which use the long term fuel flow
methodology under paragraph (c)(3)(ii) of this section and which use one of the methods
specified in paragraph (c)(3)(ii)(B)(2) of this section to determine fuel usage, the owner or
operator shall keep, at the facility, a copy of the standard used and shall keep records, for
three years, of all measurements obtained for each quarter using the methodology.
(3) For low mass emissions units or groups of units which use the long term fuel flow
methodology under paragraph (c)(3)(ii) of this section and which use a certified fuel flow
meter to determine fuel usage, the owner or operator shall comply with the quality control
quality assurance requirements for a fuel flow meter under section 2.1.6 of appendix D of this
part.
(4) For each low mass emissions unit for which fuel-and-unit-specific NOx emission rates
are determined in accordance with paragraph (c)(l)(iv) of this section, the owner or operator
shall keep, at the facility, records which document the results of all NOx emission rate tests
conducted according to appendix E to this part. If CEMS data are used to determine the fuel-
and-unit-specific NOx emission rates under paragraph (c)(l)(iv)(G) of this section, the owner
or operator shall keep, at the facility, records of the CEMS data and the data analysis
performed to determine a fuel-and-unit-specific NOx emission rate. The appendix E test
records and historical CEMS data records shall be kept until the fuel and unit specific NOx
emission rates are re-determined.
§ 75.19(e)(5)
§ 75.19(e)(6)
(5) For each low mass emissions unit for which fuel-and-unit-specific NOx emission rates
are determined in accordance with paragraph (c)(l)(iv) of this section and which has add-on
NOx emission controls of any kind or uses dry low-NOx technology, the owner or operator
shall develop and keep on-site a quality assurance plan which explains the procedures used to
document proper operation of the NOx emission controls. The plan shall include the
parameters monitored (e.g., water-to-fuel ratio) and the acceptable ranges for each parameter
used to determine proper operation of the unit's NOx controls.
(6) For unmanned facilities, the records required by paragraphs (e)(1), (e)(2) and (e)(4) of
this section may be kept at a central location, rather than at the facility.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 70
-------
Table LM-1: S02 Emission Factors (lb/mmBtu) for Various Fuel Types
Fuel type
S02 emission factors
Pipeline Natural Gas
0.0006 lb/mmBtu.
Other Natural Gas
0.06 lb/mmBtu.
Residual Oil
2.1 lb/mmBtu.
Diesel Fuel
0.5 lb/mmBtu.
Table LM-2: NOx Emission Rates (lb/mmBtu) for Various Boiler/Fuel Types
Unit type
Fuel type
NOx emission rate
Turbine
Gas
0.7
Turbine
Oil
1.2
Boiler
Gas
1.5
Boiler
Oil
2
Table LM-3: C02 Emission Factors (ton/mmBtu) for Gas and Oil
Fuel type
C02 emission factors
Pipeline (or other) Natural Gas
0.059 ton/mmBtu
Oil
0.081 ton/mmBtu
Table LM-4: Identical Unit Testing Requirements
Number of identical units
in the group
Number of appendix E tests
required
2
1
3 to 6
2
7
3
>7
n tests; where n = number of units
divided by 3 and rounded to nearest
integer.
Table LM-5: Default Gross Calorific Values (GCVs) for Various Fuels
Fuel
GCV for use in equation LM-2 or LM-3
Pipeline Natural Gas
1050 Btu/scf.
Other Natural Gas
1100 Btu/scf.
Residual Oil
19,700 Btu/lb or 167,500 Btu/gallon.
Diesel Fuel
20,500 Btu/lb or 151,700 Btu/gallon.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 71
-------
Table LM-6: Default Specific Gravity Values for Fuel Oil
Fuel
Specific gravity (lb/gal)
Residual Oil
8.5
Diesel Fuel
7.4
Subpart C — Operation and Maintenance Requirements
§ 75.20
§ 75.20(a)
§ 75.20(a)(1)
§ 75.20(a)(2)
§ 75.20(a)(3)
§ 75.20(a)(4)
§ 75.20 Initial certification and recertification procedures.
(a) Initial certification approval process. The owner or operator shall ensure that each
continuous emission or opacity monitoring system required by this part meets the initial
certification requirements of this section and shall ensure that all applicable initial certification
tests under paragraph (c) of this section are completed by the deadlines specified in § 75.4 and
prior to use in the Acid Rain Program. In addition, whenever the owner or operator installs a
continuous emission or opacity monitoring system in order to meet the requirements of
§§ 75.11 through 75.18, where no continuous emission or opacity monitoring system was
previously installed, initial certification is required.
(1) Notification of initial certification test dates. The owner or operator or designated
representative shall submit a written notice of the dates of initial certification testing at the unit
as specified in § 75.61(a)(1).
(2) Certification application. The owner or operator shall apply for certification of each
continuous emission or opacity monitoring system used under the Acid Rain Program. The
owner or operator shall submit the certification application in accordance with § 75.60 and
each complete certification application shall include the information specified in § 75.63.
(3) Provisional approval of certification (or recertification) applications. Upon the
successful completion of the required certification (or recertification) procedures of this
section, each continuous emission or opacity monitoring system shall be deemed provisionally
certified (or recertified) for use under the Acid Rain Program for a period not to exceed 120
days following receipt by the Administrator of the complete certification (or recertification)
application under paragraph (a)(4) of this section. Notwithstanding this paragraph, no
continuous emission or opacity monitor systems for a combustion source seeking to enter the
Opt-in Program in accordance with part 74 of this chapter shall be deemed provisionally
certified (or recertified) for use under the Acid Rain Program. Data measured and recorded
by a provisionally certified (or recertified) continuous emission or opacity monitoring system,
operated in accordance with the requirements of appendix B to this part, will be considered
valid quality-assured data (retroactive to the date and time of provisional certification or
recertification), provided that the Administrator does not invalidate the provisional
certification (or recertification) by issuing a notice of disapproval within 120 days of receipt
by the Administrator of the complete certification (or recertification) application. Note that
when the conditional data validation procedures of paragraph (b)(3) of this section are used
for the initial certification (or recertification) of a continuous emissions monitoring system, the
date and time of provisional certification (or recertification) of the CEMS may be earlier than
the date and time of completion of the required certification (or recertification) tests.
(4) Certification (or recertification) application formal approval process. The
Administrator will issue a notice of approval or disapproval of the certification (or
recertification) application to the owner or operator within 120 days of receipt of the complete
certification (or recertification) application. In the event the Administrator does not issue such
a notice within 120 days of receipt, each continuous emission or opacity monitoring system
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 72
-------
which meets the performance requirements of this part and is included in the certification (or
recertification) application will be deemed certified (or recertified) for use under the Acid
Rain Program.
§ 75.20(a)(4)(i) (i) Approval notice. If the certification (or recertification) application is complete and
shows that each continuous emission or opacity monitoring system meets the performance
requirements of this part, then the Administrator will issue a notice of approval of the
certification (or recertification) application within 120 days of receipt.
§ 75.20(a)(4)(ii) (ii) Incomplete application notice. A certification (or recertification) application will be
considered complete when all of the applicable information required to be submitted in
§ 75.63 has been received by the Administrator, the EPA Regional Office, and the appropriate
State and/or local air pollution control agency. If the certification (or recertification)
application is not complete, then the Administrator will issue a notice of incompleteness that
provides a reasonable timeframe for the designated representative to submit the additional
information required to complete the certification (or recertification) application. If the
designated representative has not complied with the notice of incompleteness by a specified
due date, then the Administrator may issue a notice of disapproval specified under paragraph
(a)(4)(iii) of this section. The 120-day review period shall not begin prior to receipt of a
complete application.
§ 75.20(a)(4)(iii) (iii) Disapproval notice. If the certification (or recertification) application shows that any
continuous emission or opacity monitoring system does not meet the performance
requirements of this part, or if the certification (or recertification) application is incomplete
and the requirement for disapproval under paragraph (a)(4)(ii) of this section has been met,
the Administrator shall issue a written notice of disapproval of the certification (or
recertification) application within 120 days of receipt. By issuing the notice of disapproval,
the provisional certification (or recertification) is invalidated by the Administrator, and the
data measured and recorded by each uncertified continuous emission or opacity monitoring
system shall not be considered valid quality-assured data as follows: from the hour of the
probationary calibration error test that began the initial certification (or recertification) test
period (if the conditional data validation procedures of paragraph (b)(3) of this section were
used to retrospectively validate data); or from the date and time of completion of the invalid
certification or recertification tests (if the conditional data validation procedures of paragraph
(b)(3) of this section were not used). The owner or operator shall follow the procedures for
loss of initial certification in paragraph (a)(5) of this section for each continuous emission or
opacity monitoring system which is disapproved for initial certification. For each disapproved
recertification, the owner or operator shall follow the procedures of paragraph (b)(5) of this
section.
§ 75.20(a)(4)(iv)
(iv) Audit decertification. The Administrator may issue a notice of disapproval of the
certification status of a continuous emission or opacity monitoring system in accordance with
§75.21.
§ 75.20(a)(5)
(5) Procedures for loss of certification. When the Administrator issues a notice of
disapproval of a certification application or a notice of disapproval of certification status (as
specified in paragraph (a)(4) of this section), then:
§ 75.20(a)(5)®
(i) Until such time, date, and hour as the continuous emission monitoring system can be
adjusted, repaired, or replaced and certification tests successfully completed (or, if the
conditional data validation procedures in paragraphs (b)(3)(ii) through (b)(3)(ix) of this
section are used, until a probationary calibration error test is passed following corrective
actions in accordance with paragraph (b)(3)(ii) of this section), the owner or operator shall
substitute the following values, as applicable, for each hour of unit operation during the period
of invalid data specified in paragraph (a)(4)(iii) of this section or in § 75.21: the maximum
potential concentration of S02, as defined in section 2.1.1.1 of appendix A to this part, to
report S02 concentration; the maximum potential NOx emission rate, as defined in § 72.2 of
this chapter, to report NOx emissions in lb/mmBtu; the maximum potential concentration of
NOx, as defined in section 2.1.2.1 of appendix A to this part, to report NOx emissions in ppm
(when a NOx concentration monitoring system is used to determine NOx mass emissions, as
defined under § 75.71(a)(2)); the maximum potential concentration of Hg, as defined in
section 2.1.7 of appendix A to this part, to report Hg emissions in (ig/scm (when a Hg
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 73
-------
concentration monitoring system or a sorbent trap monitoring system is used to determine Hg
mass emissions, as defined under § 75.81(b)); the maximum potential flow rate, as defined in
section 2.1.4.1 of appendix A to this part, to report volumetric flow; the maximum potential
concentration of C02, as defined in section 2.1.3.1 of appendix A to this part, to report C02
concentration data; and either the minimum potential moisture percentage, as defined in
section 2.1.5 of appendix A to this part or, if Equation 19-3, 19-4 or 19-8 in Method 19 in
appendix A to part 60 of this chapter is used to determine NOx emission rate, the maximum
potential moisture percentage, as defined in section 2.1.6 of appendix A to this part; and
§ 75.20(a)(5)(ii) (ii) The designated representative shall submit a notification of certification retest dates as
specified in § 75.6l(a)(l)(ii) and a new certification application according to the procedures in
paragraph (a)(2) of this section; and
§ 75.20(a)(5)(iii) (iii) The owner or operator shall repeat all certification tests or other requirements that
were failed by the continuous emission or opacity monitoring system, as indicated in the
Administrator's notice of disapproval, no later than 30 unit operating days after the date of
issuance of the notice of disapproval.
§ 75.20(b) (b) Recertification approval process. Whenever the owner or operator makes a
replacement, modification, or change in a certified continuous emission monitoring system or
continuous opacity monitoring system that may significantly affect the ability of the system to
accurately measure or record the S02 or C02 concentration, stack gas volumetric flow rate,
NOx emission rate, NOx concentration, Hg concentration, percent moisture, or opacity, or to
meet the requirements of § 75.21 or appendix B to this part, the owner or operator shall
recertify the continuous emission monitoring system or continuous opacity monitoring system,
according to the procedures in this paragraph. Furthermore, whenever the owner or operator
makes a replacement, modification, or change to the flue gas handling system or the unit
operation that may significantly change the flow or concentration profile, the owner or
operator shall recertify the monitoring system according to the procedures in this paragraph.
Examples of changes which require recertification include: replacement of the analyzer;
change in location or orientation of the sampling probe or site; and complete replacement of
an existing continuous emission monitoring system or continuous opacity monitoring system.
The owner or operator shall also recertify the continuous emission monitoring systems for a
unit that has recommenced commercial operation following a period of long-term cold storage
as defined in § 72.2 of this chapter. The owner or operator shall recertify a continuous opacity
monitoring system whenever the monitor path length changes or as required by an applicable
State or local regulation or permit. Any change to a flow monitor or gas monitoring system
for which a RATA is not necessary shall not be considered a recertification event. In addition,
changing the polynomial coefficients or K factor(s) of a flow monitor shall require a 3-load
RATA, but is not considered to be a recertification event; however, records of the polynomial
coefficients or K factor(s) currently in use shall be maintained on-site in a format suitable for
inspection. Changing the coefficient or K factor(s) of a moisture monitoring system shall
require a RATA, but is not considered to be a recertification event; however, records of the
coefficient or K factor(s) currently in use by the moisture monitoring system shall be
maintained on-site in a format suitable for inspection. In such cases, any other tests that are
necessary to ensure continued proper operation of the monitoring system (e.g., 3-load flow
RAT As following changes to flow monitor polynomial coefficients, linearity checks,
calibration error tests, DAHS verifications, etc.) shall be performed as diagnostic tests, rather
than as recertification tests. The data validation procedures in paragraph (b)(3) of this section
shall be applied to RAT As associated with changes to flow or moisture monitor coefficients,
and to linearity checks, 7-day calibration error tests, and cycle time tests, when these are
required as diagnostic tests. When the data validation procedures of paragraph (b)(3) of this
section are applied in this manner, replace the word "recertification" with the word
"diagnostic."
§ 75.20(b)(1) (1) Tests required. For all recertification testing, the owner or operator shall complete all
initial certification tests in paragraph (c) of this section that are applicable to the monitoring
system, except as otherwise approved by the Administrator. For diagnostic testing after
changing the flow rate monitor polynomial coefficients, the owner or operator shall complete
a 3-level RATA. For diagnostic testing after changing the K factor or mathematical algorithm
of a moisture monitoring system, the owner or operator shall complete a RATA.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 74
-------
§ 75.20(b)(2)
§ 75.20(b)(3)
§ 75.20(b)(3)(i)
§ 75.20(b)(3)(ii)
(2) Notification of recertification test dates. The owner, operator, or designated
representative shall submit notice of testing dates for recertification under this paragraph as
specified in § 75.6 l(a)(l)(ii), unless all of the tests in paragraph (c) of this section are required
for recertification, in which case the owner or operator shall provide notice in accordance with
the notice provisions for initial certification testing in § 75.61(a)(l)(i).
(3) Recertification test period requirements and data validation. The data validation
provisions in paragraphs (b)(3)(i) through (b)(3)(ix) of this section shall apply to all CEMS
recertifications and diagnostic testing. The provisions in paragraphs (b)(3)(ii) through
(b)(3)(ix) of this section may also be applied to initial certifications (see sections 6.2(a),
6.3.1(a), 6.3.2(a), 6.4(a) and 6.5(f) of appendix A to this part) and may be used to supplement
the linearity check and RATA data validation procedures in sections 2.2.3(b) and 2.3.2(b) of
appendix B to this part.
(i) The owner or operator shall use substitute data, according to the standard missing data
procedures in §§ 75.33 through 75.37 (or shall report emission data using a reference method
or another monitoring system that has been certified or approved for use under this part), in
the period extending from the hour of the replacement, modification or change made to a
monitoring system that triggers the need to perform recertification testing, until either: the
hour of successful completion of all of the required recertification tests; or the hour in which a
probationary calibration error test (according to paragraph (b)(3)(ii) of this section) is
performed and passed, following all necessary repairs, adjustments or reprogramming of the
monitoring system. The first hour of quality-assured data for the recertified monitoring
system shall either be the hour after all recertification tests have been completed or, if
conditional data validation is used, the first quality-assured hour shall be determined in
accordance with paragraphs (b)(3)(ii) through (b)(3)(ix) of this section. Notwithstanding
these requirements, if the replacement, modification, or change requiring recertification of the
CEMS is such that the historical data stream is no longer representative (e.g., where the S02
concentration and stack flow rate change significantly after installation of a wet scrubber), the
owner or operator shall substitute for missing data as follows, in lieu of using the standard
missing data procedures in §§ 75.33 through 75.37: for a change that results in a significantly
higher concentration or flow rate, substitute maximum potential values according to the
procedures in paragraph (a)(5) of this section; or for a change that results in a significantly
lower concentration or flow rate, substitute data using the standard missing data procedures.
The owner or operator shall then use the initial missing data procedures in § 75.31, beginning
with the first hour of quality assured data obtained with the recertified monitoring system,
unless otherwise provided by § 75.34 for units with add-on emission controls.
(ii) Once the modification or change to the CEMS has been completed and all of the
associated repairs, component replacements, adjustments, linearization, and reprogramming of
the CEMS have been completed, a probationary calibration error test is required to establish
the beginning point of the recertification test period. In this instance, the first successful
calibration error test of the monitoring system following completion of all necessary repairs,
component replacements, adjustments, linearization and reprogramming shall be the
probationary calibration error test. The probationary calibration error test must be passed
before any of the required recertification tests are commenced.
§ 75.20(b)(3)(iii)
(iii) Beginning with the hour of commencement of a recertification test period, emission
data recorded by the CEMS are considered to be conditionally valid, contingent upon the
results of the subsequent recertification tests.
§ 75.20(b)(3)(iv)
(iv) Each required recertification test shall be completed no later than the following
number of unit operating hours (or unit operating days) after the probationary calibration error
test that initiates the test period:
(A) For a linearity check and/or cycle time test, 168 consecutive unit operating hours, as
defined in § 72.2 of this chapter or, for CEMS installed on common stacks or bypass stacks,
168 consecutive stack operating hours, as defined in § 72.2 of this chapter;
(B) For a RATA (whether normal-load or multiple-load), 720 consecutive unit operating
hours, as defined in § 72.2 of this chapter or, for CEMS installed on common stacks or bypass
stacks, 720 consecutive stack operating hours, as defined in § 72.2 of this chapter; and
(C) For a 7-day calibration error test, 21 consecutive unit operating days, as defined in
§ 72.2 of this chapter.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 75
-------
§ 75.20(b)(3)(v)
§ 75.20(b)(3)(vi)
(v) All recertification tests shall be performed hands-off. No adjustments to the
calibration of the CEMS, other than the routine calibration adjustments following daily
calibration error tests as described in section 2.1.3 of appendix B to this part, are permitted
during the recertification test period. Routine daily calibration error tests shall be performed
throughout the recertification test period, in accordance with section 2.1.1 of appendix B to
this part. The additional calibration error test requirements in section 2.1.3 of appendix B to
this part shall also apply during the recertification test period.
(vi) If all of the required recertification tests and required daily calibration error tests are
successfully completed in succession with no failures, and if each recertification test is
completed within the time period specified in paragraph (b)(3)(iv)(A), (B), or (C) of this
section, then all of the conditionally valid emission data recorded by the CEMS shall be
considered quality assured, from the hour of commencement of the recertification test period
until the hour of completion of the required test(s).
§ 75.20(b)(3)(vii)
(vii) If a required recertification test is failed or aborted due to a problem with the CEMS,
or if a daily calibration error test is failed during a recertification test period, data validation
shall be done as follows:
§ 75.20(b)(3)(vii)(A)
(A) If any required recertification test is failed, it shall be repeated. If any recertification
test other than a 7-day calibration error test is failed or aborted due to a problem with the
CEMS, the original recertification test period is ended, and a new recertification test period
must be commenced with a probationary calibration error test. The tests that are required in
the new recertification test period will include any tests that were required for the initial
recertification event which were not successfully completed and any recertification or
diagnostic tests that are required as a result of changes made to the monitoring system to
correct the problems that caused the failure of the recertification test. For a 2- or 3-load flow
RATA, if the relative accuracy test is passed at one or more load levels, but is failed at a
subsequent load level, provided that the problem that caused the RATA failure is corrected
without re-linearizing the instrument, the length of the new recertification test period shall be
equal to the number of unit operating hours remaining in the original recertification test
period, as of the hour of failure of the RATA. However, if re-linearization of the flow monitor
is required after a flow RATA is failed at a particular load level, then a subsequent 3-load
RATA is required, and the new recertification test period shall be 720 consecutive unit (or
stack) operating hours. The new recertification test sequence shall not be commenced until all
necessary maintenance activities, adjustments, linearizations, and reprogramming of the
CEMS have been completed;
§ 75.20(b)(3)(vii)(B)
(B) If a linearity check, RATA, or cycle time test is failed or aborted due to a problem
with the CEMS, all conditionally valid emission data recorded by the CEMS are invalidated,
from the hour of commencement of the recertification test period to the hour in which the test
is failed or aborted, except for the case in which a multiple-load flow RATA is passed at one
or more load levels, failed at a subsequent load level, and the problem that caused the RATA
failure is corrected without re-linearizing the instrument. In that case, data invalidation shall
be prospective, from the hour of failure of the RATA until the commencement of the new
recertification test period. Data from the CEMS remain invalid until the hour in which a new
recertification test period is commenced, following corrective action, and a probationary
calibration error test is passed, at which time the conditionally valid status of emission data
from the CEMS begins again;
§ 75.20(b)(3)(vii)(C)
§ 75.20(b)(3)(vii)(D)
(C) If a 7-day calibration error test is failed within the recertification test period,
previously-recorded conditionally valid emission data from the CEMS are not invalidated.
The conditionally valid data status is unaffected, unless the calibration error on the day of the
failed 7-day calibration error test exceeds twice the performance specification in section 3 of
appendix A to this part, as described in paragraph (b)(3)(vii)(D) of this section; and
(D) If a daily calibration error test is failed during a recertification test period (i.e., the
results of the test exceed twice the performance specification in section 3 of appendix A to this
part), the CEMS is out-of-control as of the hour in which the calibration error test is failed.
Emission data from the CEMS shall be invalidated prospectively from the hour of the failed
calibration error test until the hour of completion of a subsequent successful calibration error
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 76
-------
test following corrective action, at which time the conditionally valid status of data from the
monitoring system resumes. Failure to perform a required daily calibration error test during a
recertification test period shall also cause data from the CEMS to be invalidated
prospectively, from the hour in which the calibration error test was due until the hour of
completion of a subsequent successful calibration error test. Whenever a calibration error test
is failed or missed during a recertification test period, no further recertification tests shall be
performed until the required subsequent calibration error has been passed, re-establishing the
conditionally valid status of data from the monitoring system. If a calibration error test failure
occurs while a linearity check or RATA is still in progress, the linearity check or RATA must
be re-started.
§ 75.20(b)(3)(vii)(E) (E) Trial gas injections and trial RATA runs are permissible during the recertification test
period, prior to commencing a linearity check or RATA, for the purpose of optimizing the
performance of the CEMS. The results of such gas injections and trial runs shall not affect the
status of previously-recorded conditionally valid data or result in termination of the
recertification test period, provided that the following specifications and conditions are met:
(/) For gas injections, the stable, ending monitor response is within +5 percent or within 5
ppm of the tag value of the reference gas;
(2) For RATA trial runs, the average reference method reading and the average CEMS
reading for the run differ by no more than +10% of the average reference method value or +15
ppm, or +1.5% H20, or +0.02 lb/mmBtu from the average reference method value, as
applicable;
(3) No adjustments to the calibration of the CEMS are made following the trial
injection(s) or run(s), other than the adjustments permitted under section 2.1.3 of appendix B
to this part; and
(4) The CEMS is not repaired, re-linearized or reprogrammed (e.g., changing flow
monitor polynomial coefficients, linearity constants, or K-factors) after the trial injections(s)
or run(s).
§ 75.20(b)(3)(vii)(F) (F) If the results of any trial gas injection(s) or RATA run(s) are outside the limits in
paragraphs (b)(3)(vii)(E)(/) or (2) of this section or if the CEMS is repaired, re-linearized or
reprogrammed after the trial injection(s) or run(s), the trial injection(s) or run(s) shall be
counted as a failed linearity check or RATA attempt. If this occurs, follow the procedures
pertaining to failed and aborted recertification tests in paragraphs (b)(3)(vii)(A) and
(b)(3)(vii)(B) of this section.
§ 75.20(b)(3)(viii) (viii) If any required recertification test is not completed within its allotted time period,
data validation shall be done as follows. For a late linearity test, RATA, or cycle time test that
is passed on the first attempt, data from the monitoring system shall be invalidated from the
hour of expiration of the recertification test period until the hour of completion of the late test.
For a late 7-day calibration error test, whether or not it is passed on the first attempt, data from
the monitoring system shall also be invalidated from the hour of expiration of the
recertification test period until the hour of completion of the late test. For a late linearity test,
RATA, or cycle time test that is failed on the first attempt or aborted on the first attempt due
to a problem with the monitor, all conditionally valid data from the monitoring system shall be
considered invalid back to the hour of the first probationary calibration error test which
initiated the recertification test period. Data from the monitoring system shall remain invalid
until the hour of successful completion of the late recertification test and any additional
recertification or diagnostic tests that are required as a result of changes made to the
monitoring system to correct problems that caused failure of the late recertification test.
§ 75.20(b)(3)(ix) (ix) If any required recertification test of a monitoring system has not been completed by
the end of a calendar quarter and if data contained in the quarterly report are conditionally
valid pending the results of test(s) to be completed in a subsequent quarter, the owner or
operator shall indicate this by means of a suitable conditionally valid data flag in the
electronic quarterly report for that quarter. The owner or operator shall resubmit the report for
that quarter if the required recertification test is subsequently failed. In the resubmitted report,
the owner or operator shall use the appropriate missing data routine in§75.31or§75.33 to
replace with substitute data each hour of conditionally valid data that was invalidated by the
failed recertification test. Alternatively, if any required recertification test is not completed by
the end of a particular calendar quarter but is completed no later than 30 days after the end of
that quarter (i.e., prior to the deadline for submitting the quarterly report under § 75.64), the
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 77
-------
test data and results may be submitted with the earlier quarterly report even though the test
date(s) are from the next calendar quarter. In such instances, if the recertification test(s) are
passed in accordance with the provisions of paragraph (b)(3) of this section, conditionally
valid data may be reported as quality-assured, in lieu of reporting a conditional data flag. If
the recertification test(s) is failed and if conditionally valid data are replaced, as appropriate,
with substitute data, then neither the reporting of a conditional data flag nor resubmission is
required. In addition, if the owner or operator uses a conditionally valid data flag in any of the
four quarterly reports for a given year, the owner or operator shall indicate the final status of
the conditionally valid data (i.e., resolved or unresolved) in the annual compliance
certification report required under § 72.90 of this chapter for that year. The Administrator
may invalidate any conditionally valid data that remains unresolved at the end of a particular
calendar year and may require the owner or operator to resubmit one or more of the quarterly
reports for that calendar year, replacing the unresolved conditionally valid data with substitute
data values determined in accordance with § 75.31 or § 75.33, as appropriate.
§ 75.20(b)(4) (4) Recertification application. The designated representative shall apply for
recertification of each continuous emission or opacity monitoring system used under the Acid
Rain Program. The owner or operator shall submit the recertification application in
accordance with § 75.60, and each complete recertification application shall include the
information specified in § 75.63.
§ 75.20(b)(5) (5) Approval or disapproval of request for recertification. The procedures for
provisional certification in paragraph (a)(3) of this section shall apply to recertification
applications. The Administrator will issue a notice of approval, disapproval, or
incompleteness according to the procedures in paragraph (a)(4) of this section. In the event
that a recertification application is disapproved, data from the monitoring system are
invalidated and the applicable missing data procedures in §§ 75.31 or 75.33 shall be used
from the date and hour of receipt of the disapproval notice back to the hour of the adjustment
or change to the CEMS that triggered the need for recertification testing or, if the conditional
data validation procedures in paragraphs (b)(3)(ii) through (b)(3)(ix) of this section were used,
back to the hour of the probationary calibration error test that began the recertification test
period. Data from the monitoring system remain invalid until all required recertification tests
have been passed or until a subsequent probationary calibration error test is passed, beginning
a new recertification test period. The owner or operator shall repeat all recertification tests or
other requirements, as indicated in the Administrator's notice of disapproval, no later than 30
unit operating days after the date of issuance of the notice of disapproval. The designated
representative shall submit a notification of the recertification retest dates, as specified in
§ 75.6l(a)(l)(ii), and shall submit a new recertification application according to the
procedures in paragraph (b)(4) of this section.
§ 75.20(c) (c) Initial certification and recertification procedures. Prior to the deadline in § 75.4, the
owner or operator shall conduct initial certification tests and in accordance with § 75.63, the
designated representative shall submit an application to demonstrate that the continuous
emission or opacity monitoring system and components thereof meet the specifications in
appendix A to this part. The owner or operator shall compare reference method values with
output from the automated data acquisition and handling system that is part of the continuous
emission monitoring system being tested. Except as otherwise specified in paragraphs (b)(1),
(d), and (e) of this section, and in sections 6.3.1 and 6.3.2 of appendix A to this part, the
owner or operator shall perform the following tests for initial certification or recertification of
continuous emission or opacity monitoring systems or components according to the
requirements of appendix A to this part:
§ 75.20(c)(1) (1) For each S02 pollutant concentration monitor, each NOx concentration monitoring
system used to determine NOx mass emissions, as defined under § 75.71(a)(2), each Hg
concentration monitoring system, and for each NOx-diluent continuous emission monitoring
system:
(i) A 7-day calibration error test, where, for the NOx-diluent continuous emission
monitoring system, the test is performed separately on the NOx pollutant concentration
monitor and the diluent gas monitor;
(ii) A linearity check, where, for the NOx-diluent continuous emission monitoring system,
the test is performed separately on the NOx pollutant concentration monitor and the diluent gas
monitor. For Hg monitors, perform this check with elemental Hg standards;
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 78
-------
(iii) A relative accuracy test audit. For the NOx-diluent continuous emission monitoring
system, the RATA shall be done on a system basis, in units of lb/mmBtu. For the NOx
concentration monitoring system, the RATA shall be done on a ppm basis. For the Hg
concentration monitoring system, the RATA shall be done on a (ig/scm basis;
(iv) A bias test;
(v) A cycle time test, (where, for the NOx-diluent continuous emission monitoring system,
the test is performed separately on the NOx pollutant concentration monitor and the diluent gas
monitor); and
(vi) For Hg monitors only, a 3-level system integrity check, using a NIST-traceable
source of oxidized Hg, as described in section 6.2 of appendix A to this part. This test is not
required for an Hg monitor that does not have a converter.
§ 75.20(c)(2)
(2) For each flow monitor:
(i) A 7-day calibration error test;
(ii) Relative accuracy test audits, as follows:
(A) A single-load (or single-level) RATA at the normal load (or level), as defined in
section 6.5.2.1(d) of appendix A to this part, for a flow monitor installed on a peaking unit or
bypass stack, or for a flow monitor exempted from multiple-level RATA testing under section
6.5.2 (e) of appendix A to this part;
(B) For all other flow monitors, a RATA at each of the three load levels (or operating
levels) corresponding to the three flue gas velocities described in section 6.5.2(a) of appendix
A to this part;
(iii) A bias test for the single-load (or single-level) flow RATA described in paragraph
(c)(2)(ii)(A) of this section; and
(iv) A bias test (or bias tests) for the 3-level flow RATA described in paragraph
(c)(2)(ii)(B) of this section, at the following load or operational level(s):
(A) At each load level designated as normal under section 6.5.2.1(d) of appendix A to this
part, for units that produce electrical or thermal output, or
(B) At the operational level identified as normal in section 6.5.2.1(d) of appendix A to
this part, for units that do not produce electrical or thermal output.
§ 75.20(c)(3)
(3) The initial certification test data from an 02 or a C02 diluent gas monitor certified for
use in a NOx continuous emission monitoring system may be submitted to meet the
requirements of paragraph (c)(4) of this section. Also, for a diluent monitor that is used both
as a C02 monitoring system and to determine heat input, only one set of diluent monitor
certification data need be submitted (under the component and system identification numbers
of the C02 monitoring system).
§ 75.20(c)(4)
(4) For each C02 pollutant concentration monitor, each C02 monitoring system that uses
an 02 monitor to determine C02 concentration, and each diluent gas monitor used only to
monitor heat input rate:
(i) A 7-day calibration error test;
(ii) A linearity check;
(iii) A relative accuracy test audit, where, for an 02 monitor used to determine C02
concentration, the C02 reference method shall be used for the RATA; and
(iv) A cycle-time test.
§ 75.20(c)(5)
(5) For each continuous moisture monitoring system consisting of wet- and dry-basis 02
analyzers:
(i) A 7-day calibration error test of each 02 analyzer;
(ii) A cycle time test of each 02 analyzer;
(iii) A linearity test of each 02 analyzer; and
(iv) A RATA, directly comparing the percent moisture measured by the monitoring
system to a reference method.
§ 75.20(c)(6)
§ 75.20(c)(7)
(6) For each continuous moisture sensor: A RATA, directly comparing the percent
moisture measured by the monitor sensor to a reference method.
(7) For a continuous moisture monitoring system consisting of a temperature sensor and a
data acquisition and handling system (DAHS) software component programmed with a
moisture lookup table:
(i) A demonstration that the correct moisture value for each hour is being taken from the
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 79
-------
moisture lookup tables and applied to the emission calculations. At a minimum, the
demonstration shall be made at three different temperatures covering the normal range of stack
temperatures from low to high.
(ii) [Reserved]
§ 75.20(c)(8) (8) The owner or operator shall ensure that initial certification or recertification of a
continuous opacity monitor for use under the Acid Rain Program is conducted according to
one of the following procedures:
(i) Performance of the tests for initial certification or recertification, according to the
requirements of Performance Specification 1 in appendix B to part 60 of this chapter; or
(ii) A continuous opacity monitoring system tested and certified previously under State or
other Federal requirements to meet the requirements of Performance Specification 1 shall be
deemed certified for the purposes of this part.
§ 75.20(c)(9) (9) For each sorbent trap monitoring system, perform a RATA, on a (ig/dscm basis, and a
bias test.
§ 75.20(c)(10)
§ 75.20(c)(ll)
§ 75.20(d)
§ 75.20(d)(1)
§ 75.20(d)(2)
§ 75.20(d)(2)(i)
(10) For the automated data acquisition and handling system, tests designed to verify:
(i) Proper computation of hourly averages for pollutant concentrations, flow rate,
pollutant emission rates, and pollutant mass emissions; and
(11) Proper computation and application of the missing data substitution procedures in
subpart D of this part and the bias adjustment factors in section 7 of appendix A to this part.
(11) The owner or operator shall provide adequate facilities for initial certification or
recertification testing that include:
(i) Sampling ports adequate for test methods applicable to such facility, such that: (A)
Volumetric flow rate, pollutant concentration, and pollutant emission rates can be accurately
determined by applicable test methods and procedures; and
(B) A stack or duct free of cyclonic flow during performance tests is available, as
demonstrated by applicable test methods and procedures.
(ii) Basic facilities (e.g., electricity) for sampling and testing equipment.
(d) Initial certification and recertification and quality assurance procedures for optional
backup continuous emission monitoring systems.
(1) Redundant backups. The owner or operator of an optional redundant backup CEMS
shall comply with all the requirements for initial certification and recertification according to
the procedures specified in paragraphs (a), (b), and (c) of this section. The owner or operator
shall operate the redundant backup CEMS during all periods of unit operation, except for
periods of calibration, quality assurance, maintenance, or repair. The owner or operator shall
perform upon the redundant backup CEMS all quality assurance and quality control
procedures specified in appendix B to this part, except that the daily assessments in section
2.1 of appendix B to this part are optional for days on which the redundant backup CEMS is
not used to report emission data under this part. For any day in which a redundant backup
CEMS is used to report emission data, the system must meet all of the applicable daily
assessment criteria in appendix B to this part.
(2) Non-redundant backups. The owner or operator of an optional non-redundant backup
CEMS or like-kind replacement analyzer shall comply with all of the following requirements
for initial certification, quality assurance, recertification, and data reporting:
(i) Except as provided in paragraph (d)(2)(v) of this section, for a regular non-redundant
backup CEMS (i.e., a non-redundant backup CEMS that has its own separate probe, sample
interface, and analyzer) or a non-redundant backup flow monitor, all of the tests in paragraph
(c) of this section are required for initial certification of the system, except for the 7-day
calibration error test.
§ 75.20(d)(2)(ii)
(ii) For a like-kind replacement non-redundant backup analyzer (i.e., a non-redundant
backup analyzer that uses the same probe and sample interface as a primary monitoring
system), no initial certification of the analyzer is required. A non-redundant backup analyzer,
connected to the same probe and interface as a primary CEMS in order to satisfy the dual span
requirements of section 2.1.1.4 or 2.1.2.4 of appendix A to this part, shall be treated in the
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 80
-------
same manner as a like-kind replacement analyzer.
§ 75.20(d)(2)(iii) (iii) Each non-redundant backup CEMS or like-kind replacement analyzer shall comply
with the daily and quarterly quality assurance and quality control requirements in appendix B
to this part for each day and quarter that the non-redundant backup CEMS or like-kind
replacement analyzer is used to report data, and shall meet the additional linearity and
calibration error test requirements specified in this paragraph. The owner or operator shall
ensure that each non-redundant backup CEMS or like-kind replacement analyzer passes a
linearity check (for pollutant concentration and diluent gas monitors) or a calibration error test
(for flow monitors) prior to each use for recording and reporting emissions. For a primary
NOx-diluent CEMS consisting of the primary pollutant analyzer and a like-kind replacement
diluent analyzer (or vice-versa), provided that the primary pollutant or diluent analyzer (as
applicable) is operating and is not out-of-control with respect to any of its quality assurance
requirements, only the like-kind replacement analyzer must pass a linearity check before the
system is used for data reporting. When a non-redundant backup CEMS or like-kind
replacement analyzer is brought into service, prior to conducting the linearity test, a
probationary calibration error test (as described in paragraph (b)(3)(ii) of this section), which
will begin a period of conditionally valid data, may be performed in order to allow the
validation of data retrospectively, as follows. Conditionally valid data from the CEMS or like-
kind replacement analyzer are validated back to the hour of completion of the probationary
calibration error test if the following conditions are met: if no adjustments are made to the
CEMS or like-kind replacement analyzer other than the allowable calibration adjustments
specified in section 2.1.3 of appendix B to this part between the probationary calibration error
test and the successful completion of the linearity test; and if the linearity test is passed within
168 unit (or stack) operating hours of the probationary calibration error test. However, if the
linearity test is performed within 168 unit or stack operating hours but is either failed or
aborted due to a problem with the CEMS or like-kind replacement analyzer, then all of the
conditionally valid data are invalidated back to the hour of the probationary calibration error
test, and data from the non-redundant backup CEMS or from the primary monitoring system of
which the like-kind replacement analyzer is a part remain invalid until the hour of completion
of a successful linearity test. Notwithstanding this requirement, the conditionally valid data
status may be re-established after a failed or aborted linearity check, if corrective action is
taken and a calibration error test is subsequently passed. However, in no case shall the use of
conditional data validation extend for more than 168 unit or stack operating hours beyond the
date and time of the original probationary calibration error test when the analyzer was brought
into service.
§ 75.20(d)(2)(iv) (iv) When data are reported from a non-redundant backup CEMS or like-kind replacement
analyzer, the appropriate bias adjustment factor shall be determined as follows:
(A) For a regular non-redundant backup CEMS, as described in paragraph (d)(2)(i) of this
section, apply the bias adjustment factor from the most recent RATA of the non-redundant
backup system (even if that RATA was done more than 12 months previously); or
(B) When a like-kind replacement non-redundant backup analyzer is used as a component
of a primary CEMS (as described in paragraph (d)(2)(ii) of this section), apply the primary
monitoring system bias adjustment factor.
§ 75.20(d)(2)(v) (v) For each parameter monitored (i.e., S02, C02, NOx, Hg or flow rate) at each unit or
stack, a regular non-redundant backup CEMS may not be used to report data at that affected
unit or common stack for more than 720 hours in any one calendar year (or 720 hours in any
ozone season, for sources that report emission data only during the ozone season, in
accordance with § 75.74(c)), unless the CEMS passes a RATA at that unit or stack. For each
parameter monitored (S02, C02 or NOx) at each unit or stack, the use of a like-kind
replacement non-redundant backup analyzer (or analyzers) is restricted to 720 cumulative
hours per calendar year (or ozone season, as applicable), unless the owner or operator
redesignates the like-kind replacement analyzer(s) as component(s) of regular non-redundant
backup CEMS and each redesignated CEMS passes a RATA at that unit or stack.
§ 75.20(d)(2)(vi) (vi) For each regular non-redundant backup CEMS, no more than eight successive
calendar quarters shall elapse following the quarter in which the last RATA of the CEMS was
done at a particular unit or stack, without performing a subsequent RATA. Otherwise, the
CEMS may not be used to report data from that unit or stack until the hour of completion of a
passing RATA at that location.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 81
-------
§ 75.20(d)(2)(vii) (vii) Each regular non-redundant backup CEMS shall be represented in the monitoring
plan required under § 75.53 as a separate monitoring system, with unique system and
component identification numbers. When like-kind replacement non-redundant backup
analyzers are used, the owner or operator shall represent each like-kind replacement analyzer
used during a particular calendar quarter in the monitoring plan required under § 75.53 as a
component of a primary monitoring system. The owner or operator shall also assign a unique
component identification number to each like-kind replacement analyzer, beginning with the
letters "LK" (e.g., "LK1," "LK2," etc.) and shall specify the manufacturer, model, and serial
number of the like-kind replacement analyzer. This information may be added, deleted or
updated as necessary, from quarter to quarter. The owner or operator shall also report data
from the like-kind replacement analyzer using the system identification number of the primary
monitoring system and the assigned component identification number of the like-kind
replacement analyzer. For the purposes of the electronic quarterly report required under
§ 75.64, the owner or operator may manually enter the appropriate component identification
number(s) of any like-kind replacement analyzer(s) used for data reporting during the quarter.
§ 75.20(d)(2)(viii) (viii) When reporting data from a certified regular non-redundant backup CEMS, use a
method of determination (MODC) code of "02." When reporting data from a like-kind
replacement non-redundant backup analyzer, use a MODC of "17" (see Table 4a under
§ 75.57). For the purposes of the electronic quarterly report required under § 75.64, the owner
or operator may manually enter the required MODC of" 17" for a like-kind replacement
analyzer.
§ 75.20(d)(2)(ix) (ix) For non-redundant backup Hg CEMS and sorbent trap monitoring systems, and for
like-kind replacement Hg analyzers, the following provisions apply in addition to, or, in some
cases, in lieu of, the general requirements in paragraphs (d)(2)(i) through (d)(2)(viii) of this
section:
(A) When a certified sorbent trap monitoring system is brought into service as a regular
non-redundant backup monitoring system, the system shall be operated according to the
procedures in § 75.15 and appendix K of this part;
(B) When a regular non-redundant backup Hg CEMS or a like-kind replacement Hg
analyzer is brought into service, a linearity check with elemental Hg standards, as described in
paragraph (c)(l)(ii) of this section and section 6.2 of appendix A of this part, and a single-
point system integrity check, as described in section 2.6 of appendix B of this part, shall be
performed. Alternatively, a 3-level system integrity check, as described in paragraph (c)(l)(vi)
of this section and paragraph (g) of 6.2 in appendix A of this part, may be performed in lieu of
these two tests.
(C) The weekly single-point system integrity checks described in section 2.6 of appendix
B of this part are required as long as a non-redundant backup Hg CEMS or like-kind
replacement Hg analyzer remains in service, unless the daily calibrations of the Hg analyzer
are done using a NIST-traceable source of oxidized Hg.
§ 75.20(d)(3) (3) Reference method backups. A monitoring system that is operated as a reference
method backup system pursuant to the reference method requirements of methods 2, 6C, 7E, or
3 A in appendix A of part 60 of this chapter need not perform and pass the certification tests
required by paragraph (c) of this section prior to its use pursuant to this paragraph.
§ 75.20(e) (e) Certification/recertification procedures for either peaking unit or by-pass stack/duct
continuous emission monitoring systems. The owner or operator of either a peaking unit or
by-pass stack/duct continuous emission monitoring system shall comply with all the
requirements for certification or recertification according to the procedures specified in
paragraphs (a), (b), and (c) of this section, except as follows: the owner or operator need only
perform one nine-run relative accuracy test audit for certification or recertification of a flow
monitor installed on the by-pass stack/duct or on the stack/duct used only by affected peaking
unit(s). The relative accuracy test audit shall be performed during normal operation of the
peaking unit(s) or the by-pass stack/duct.
§ 75.20(f) (f) Certification/recertification procedures for alternative monitoring systems. The
designated representative representing the owner or operator of each alternative monitoring
system approved by the Administrator as equivalent to or better than a continuous emission
monitoring system according to the criteria in subpart E of this part shall apply for certification
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 82
-------
to the Administrator prior to use of the system under the Acid Rain Program, and shall apply
for recertification to the Administrator following a replacement, modification, or change
according to the procedures in paragraph (c) of this section. The owner or operator of an
alternative monitoring system shall comply with the notification and application requirements
for certification or recertification according to the procedures specified in paragraphs (a) and
(b) of this section.
§ 75.20(g)
§ 75.20(g)(1)
§ 75.20(g)(l)(i)
§ 75.20(g)(l)(ii)
§ 75.20(g)(l)(iii)
§ 75.20(g)(2)
§ 75.20(g)(3)
§ 75.20(g)(4)
(g) Initial certification and recertification procedures for excepted monitoring systems
under appendices D and E. The owner or operator of a gas-fired unit, oil-fired unit, or
diesel-fired unit using the optional protocol under appendix D or E to this part shall ensure that
an excepted monitoring system under appendix D or E to this part meets the applicable general
operating requirements of § 75.10, the applicable requirements of appendices D and E to this
part, and the initial certification or recertification requirements of this paragraph.
(1) Initial certification and recertification testing. The owner or operator shall use the
following procedures for initial certification and recertification of an excepted monitoring
system under appendix D or E to this part.
(1) When the optional S02 mass emissions estimation procedure in appendix D to this part
or the optional NOx emissions estimation protocol in appendix E to this part is used, the owner
or operator shall provide data from a flowmeter accuracy test (or shall provide a statement of
calibration if the flowmeter meets the accuracy standard by design) for each fuel flowmeter,
according to section 2.1.5.1 of appendix D to this part. For orifice, nozzle, and venturi-type
flowmeters, the results of primary element visual inspections and/or calibrations of the
transmitters or transducers shall also be provided.
(ii) For the automated data acquisition and handling system used under either the optional
S02 mass emissions estimation procedure in appendix D of this part or the optional NOx
emissions estimation protocol in appendix E of this part, the owner or operator shall perform
tests designed to verify:
(A) The proper computation of hourly averages for pollutant concentrations, fuel flow
rates, emission rates, heat input, and pollutant mass emissions; and
(B) Proper computation and application of the missing data substitution procedures in
appendix D or E of this part.
(iii) When the optional NOx emissions protocol in appendix E is used, the owner or
operator shall complete all initial performance testing under section 2.1 of appendix E.
(2) Initial certification, recertification, and QA testing notification. The designated
representative shall provide initial certification testing notification, recertification testing
notification, and routine periodic quality-assurance testing, as specified in § 75.61. Initial
certification testing notification, recertification testing notification, or periodic quality
assurance testing notification is not required for an excepted monitoring system under
appendix D to this part.
(3) Monitoring plan. The designated representative shall submit an initial monitoring plan
in accordance with § 75.62(a).
(4) Initial certification or recertification application. The designated representative shall
submit an initial certification or recertification application in accordance with §§75.60 and
75.63.
§ 75.20(g)(5) (5) Provisional approval of initial certification and recertification applications. Upon the
successful completion of the required initial certification or recertification procedures for each
excepted monitoring system under appendix D or E to this part, each excepted monitoring
system under appendix D or E to this part shall be deemed provisionally certified (or
recertified) for use under the Acid Rain Program during the period for the Administrator's
review. The provisions for the initial certification or recertification application formal
approval process in paragraph (a)(4) of this section shall apply, except that the term "excepted
monitoring system" shall apply rather than "continuous emission or opacity monitoring
system" and except that the procedures for loss of certification or for disapproval of a
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 83
-------
recertification request in paragraph (g)(7) of this section shall apply rather than the procedures
for loss of certification or denial of a recertification request in paragraph (a)(5) or (b)(5) of this
section. Data measured and recorded by a provisionally certified (or recertified) excepted
monitoring system under appendix D or E to this part will be considered quality assured data
from the date and time of completion of the last initial certification or recertification test,
provided that the Administrator does not revoke the provisional certification or recertification
by issuing a notice of disapproval in accordance with the provisions in paragraph (a)(4) or
(b)(5) of this section.
§ 75.20(g)(6) (6) Recertification requirements. Recertification of an excepted monitoring system under
appendix D or E to this part is required for any modification to the system or change in
operation that could significantly affect the ability of the system to accurately account for
emissions and for which the Administrator determines that an accuracy test of the fuel
flowmeter or a retest under appendix E to this part to re-establish the NOx correlation curve is
required. Examples of such changes or modifications include fuel flowmeter replacement,
changes in unit configuration, or exceedance of operating parameters.
§ 75.20(g)(7) (7) Procedures for loss of certification or recertification for excepted monitoring systems
under appendices D and E to this part. In the event that a certification or recertification
application is disapproved for an excepted monitoring system, data from the monitoring system
are invalidated, and the applicable missing data procedures in section 2.4 of appendix D or
section 2.5 of appendix E to this part shall be used from the date and hour of receipt of such
notice back to the hour of the provisional certification. Data from the excepted monitoring
system remain invalid until all required tests are repeated and the excepted monitoring system
is again provisionally certified. The owner or operator shall repeat all certification or
recertification tests or other requirements, as indicated in the Administrator's notice of
disapproval, no later than 30 unit operating days after the date of issuance of the notice of
disapproval. The designated representative shall submit a notification of the certification or
recertification retest dates if required under paragraph (g)(2) of this section and shall submit a
new certification or recertification application according to the procedures in paragraph (g)(4)
of this section.
§ 75.20(h)
§ 75.20(h)(1)
§ 75.20(h)(2)
§ 75.20(h)(3)
§ 75.20(h)(4)
(h) Initial certification and recertification procedures for low mass emissions units using
the excepted methodologies under § 75.19. The owner or operator of a gas-fired or oil-fired
unit using the low mass emissions excepted methodology under § 75.19 shall meet the
applicable general operating requirements of § 75.10, the applicable requirements of § 75.19,
and the applicable certification requirements of this paragraph.
(1) Monitoring plan. The designated representative shall submit a monitoring plan in
accordance with §§75.53 and 75.62.
(2) Certification application. The designated representative shall submit a certification
application in accordance with § 75.63(a)(l)(ii).
(3) Approval of certification applications. The provisions for the certification application
formal approval process in the introductory text of paragraph (a)(4) and in paragraphs
(a)(4)(i), (ii), and (iv) of this section shall apply, except that "continuous emission or opacity
monitoring system" shall be replaced with "low mass emissions excepted methodology."
Provisional certification status for the low mass emissions methodology begins on the date of
submittal (consistent with the definition of "submit" in § 72.2 of this chapter) of a complete
certification application, and the methodology is considered to be certified either upon receipt
of a written approval notice from the Administrator or, if such notice is not provided, at the
end of the Administrator's 120 day review period. However, in contrast to CEM systems or
appendix D and E monitoring systems, a provisionally certified or certified low mass
emissions excepted methodology may not be used to report data under the Acid Rain Program
or in a NOx mass emissions reduction program under subpart H of this part prior to the
applicable commencement date specified in § 75.19(a)(2)(i).
(4) Disapproval of low mass emissions unit certification applications. If the
Administrator determines that the certification application for a low mass emissions unit does
not demonstrate that the unit meets the requirements of §§ 75.19(a) and (b), the Administrator
shall issue a written notice of disapproval of the certification application within 120 days of
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 84
-------
§ 75.20(h)(4)®
§ 75.20(h)(4)(h)
§ 75.20(h)(5)
§ 75.21
§ 75.21(a)
§ 75.21(a)(1)
§ 75.21(a)(2)
§ 75.21(a)(3)
§ 75.21(a)(4)
receipt. By issuing the notice of disapproval, the provisional certification is invalidated by the
Administrator, and any emission data reported using the excepted methodology during the
Administrator's 120-day review period shall be considered invalid. The owner or operator
shall use the following procedures when a certification application is disapproved:
(i) The owner or operator shall substitute the following values, as applicable, for each
hour of unit operation in which data were reported using the low mass emissions methodology
until such time, date, and hour as continuous emission monitoring systems or excepted
monitoring systems, where applicable, are installed and provisionally certified: the maximum
potential concentration of S02, as defined in section 2.1.1.1 of appendix A to this part; the
maximum potential fuel flowrate, as defined in section 2.4.2 of appendix D to this part; the
maximum potential values of fuel sulfur content, GCV, and density (if applicable) in Table D-
6 of appendix D to this part; the maximum potential NOx emission rate, as defined in § 72.2 of
this chapter; the maximum potential flow rate, as defined in section 2.1.4.1 of appendix A to
this part; or the maximum potential C02 concentration as defined in section 2.1.3.1 of
appendix A to this part. For a unit subject to a State or federal NOx mass reduction program
where the owner or operator intends to monitor NOx mass emissions with a NOx pollutant
concentration monitor and a flow monitoring system, substitute for NOx concentration using
the maximum potential concentration of NOx, as defined in section 2.1.2.1 of appendix A to
this part, and substitute for volumetric flow using the maximum potential flow rate, as defined
in section 2.1.4.1 of appendix A to this part; and
(ii) The designated representative shall submit a notification of certification test dates for
the required monitoring systems, as specified in § 75.61(a)(l)(i), and shall submit a
certification application according to the procedures in paragraph (a)(2) of this section.
(5) Recertification. Recertification of an approved low mass emissions excepted
methodology is not required. Once the Administrator has approved the methodology for use,
the owner or operator is subject to the on-going qualification and disqualification procedures
in § 75.19(b), on an annual or ozone season basis, as applicable.
§ 75.21 Quality assurance and quality control requirements.
(a) Continuous emission monitoring systems. The owner or operator of an affected unit
shall operate, calibrate and maintain each continuous emission monitoring system used to
report emission data under the Acid Rain Program as follows:
(1) The owner or operator shall operate, calibrate and maintain each primary and
redundant backup continuous emission monitoring system according to the quality assurance
and quality control procedures in appendix B of this part.
(2) The owner or operator shall ensure that each non-redundant backup CEMS meets the
quality assurance requirements of § 75.20(d) for each day and quarter that the system is used to
report data.
(3) The owner or operator shall perform quality assurance upon a reference method
backup monitoring system according to the requirements of method 2, 6C, 7E, or 3 A in
appendix A of part 60 of this chapter (supplemented, as necessary, by guidance from the
Administrator), or one of the Hg reference methods in § 75.22, as applicable, instead of the
procedures specified in appendix B of this part.
(4) The owner or operator of a unit with an S02 continuous emission monitoring system is
not required to perform the daily or quarterly assessments of the S02 monitoring system under
appendix B to this part on any day or in any calendar quarter in which only gaseous fuel is
combusted in the unit if, during those days and calendar quarters, S02 emissions are
determined in accordance with § 75.11(e)(1). However, such assessments are permissible, and
if any daily calibration error test or linearity test of the S02 monitoring system is failed while
the unit is combusting only gaseous fuel, the S02 monitoring system shall be considered
out-of-control. The length of the out-of-control period shall be determined in accordance with
the applicable procedures in section 2.1.4 or 2.2.3 of appendix B to this part.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 85
-------
§ 75.21(a)(5)
§ 75.21(a)(6)
§ 75.21(a)(7)
§ 75.21(a)(8)
§ 75.21(a)(10)
(5) For a unit with an S02 continuous monitoring system, in which gaseous fuel that is
very low sulfur fuel (as defined in § 72.2 of this chapter) is sometimes burned as a primary or
backup fuel and in which higher-sulfur fuel(s) such as oil or coal are, at other times, burned as
primary or backup fuel(s), the owner shall perform the relative accuracy test audits of the S02
monitoring system (as required by section 6.5 of appendix A to this part and section 2.3.1 of
appendix B to this part) only when the higher-sulfur fuel is combusted in the unit and shall not
perform S02 relative accuracy test audits when the very low sulfur gaseous fuel is the only fuel
being combusted.
(6) If the designated representative certifies that a unit with an S02 monitoring system
burns only very low sulfur fuel (as defined in § 72.2 of this chapter), the S02 monitoring
system is exempted from the relative accuracy test audit requirements in appendices A and B
to this part.
(7) If the designated representative certifies that a particular unit with an S02 monitoring
system combusts primarily fuel(s) that are very low sulfur fuel(s) (as defined in § 72.2 of this
chapter) and combusts higher sulfur fuel(s) only for infrequent, non-routine operations (e.g.,
only as emergency backup fuel(s) or for short-term testing), the S02 monitoring system shall
be exempted from the RATA requirements of appendices A and B to this part in any calendar
year that the unit combusts the higher-sulfur fuel(s) for no more than 480 hours. If, in a
particular calendar year, the higher-sulfur fuel usage exceeds 480 hours, the owner or operator
shall perform a RATA of the S02 monitor (while combusting the higher-sulfur fuel) either by
the end of the calendar quarter in which the exceedance occurs or by the end of a 720 unit (or
stack) operating hour grace period (under section 2.3.3 of appendix B to this part) following
the quarter in which the exceedance occurs.
(8) The quality assurance provisions of §§ 75.1 l(e)(3)(i) through 75.1 l(e)(3)(iv) shall
apply to all units with S02 monitoring systems during hours in which only very low sulfur fuel
(as defined in § 72.2 of this chapter) is combusted in the unit. § 75.21(a)(9)
(9) Provided that a unit with an S02 monitoring system is not exempted from the S02
RATA requirements of this part under paragraphs (a)(6) or (a)(7) of this section, any calendar
quarter during which a unit combusts only very low sulfur fuel (as defined in § 72.2 of this
chapter) shall be excluded in determining the quarter in which the next relative accuracy test
audit must be performed for the S02 monitoring system. However, no more than eight
successive calendar quarters shall elapse after a relative accuracy test audit of an S02
monitoring system, without a subsequent relative accuracy test audit having been performed.
The owner or operator shall ensure that a relative accuracy test audit is performed, in
accordance with paragraph (a)(5) of this section, either by the end of the eighth successive
elapsed calendar quarter since the last RATA or by the end of a 720 unit (or stack) operating
hour grace period, as provided in section 2.3.3 of appendix B to this part.
(10) The owner or operator who, in accordance with § 75.11(e)(1), uses a certified flow
monitor and a certified diluent monitor and Equation F-23 in appendix F to this part to
calculate S02 emissions during hours in which a unit combusts only natural gas or pipeline
natural gas (as defined in § 72.2 of this chapter) shall meet all quality control and quality
assurance requirements in appendix B to this part for the flow monitor and the diluent monitor.
§ 75.21(b)
§ 75.21(c)
§ 75.21(d)
(b) Continuous opacity monitoring systems. The owner or operator of an affected unit
shall operate, calibrate, and maintain each continuous opacity monitoring system used under
the Acid Rain Program according to the procedures specified for State Implementation Plans,
pursuant to part 51, appendix M of this chapter.
(c) Calibration gases. The owner or operator shall ensure that all calibration gases used
to quality assure the operation of the instrumentation required by this part shall meet the
definition in § 72.2 of this chapter.
(d) Notification for periodic relative accuracy test audits. The owner or operator or the
designated representative shall submit a written notice of the dates of relative accuracy testing
as specified in § 75.61.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 86
-------
§ 75.21(e)
§ 75.21(e)(1)
§ 75.21(e)(2)
§ 75.22
§ 75.22(a)
(e) Consequences of audits. The owner or operator shall invalidate data from a
continuous emission monitoring system or continuous opacity monitoring system upon failure
of an audit under appendix B to this part or any other audit, beginning with the unit operating
hour of completion of a failed audit as determined by the Administrator. The owner or
operator shall not use invalidated data for reporting either emissions or heat input, nor for
calculating monitor data availability.
(1) Audit decertification. Whenever both an audit of a continuous emission or opacity
monitoring system (or component thereof, including the data acquisition and handling system),
of any excepted monitoring system under appendix D or E to this part, or of any alternative
monitoring system under subpart E of this part, and a review of the initial certification
application or of a recertification application, reveal that any system or component should not
have been certified or recertified because it did not meet a particular performance specification
or other requirement of this part, both at the time of the initial certification or recertification
application submission and at the time of the audit, the Administrator will issue a notice of
disapproval of the certification status of such system or component. For the purposes of this
paragraph, an audit shall be either a field audit of the facility or an audit of any information
submitted to EPA or the State agency regarding the facility. By issuing the notice of
disapproval, the certification status is revoked prospectively by the Administrator. The data
measured and recorded by each system shall not be considered valid quality-assured data from
the date of issuance of the notification of the revoked certification status until the date and time
that the owner or operator completes subsequently approved initial certification or
recertification tests. The owner or operator shall follow the procedures in § 75.20(a)(5) for
initial certification or § 75.20(b)(5) for recertification to replace, prospectively, all of the
invalid, non-quality-assured data for each disapproved system.
(2) Out-of-control period. Whenever a continuous emission monitoring system or
continuous opacity monitoring system fails a quality assurance audit, or any other audit, the
system is out-of-control. The owner or operator shall follow the procedures for out-of-control
periods in § 75.24.
§ 75.22 Reference test methods.
(a) The owner or operator shall use the following methods, which are found in appendix
A-4 to part 60 of this chapter or have been published by ASTM, to conduct the following tests:
monitoring system tests for certification or recertification of continuous emission monitoring
systems and excepted monitoring systems under appendix E to this part; the emission tests
required under §75.81(c) and (d); and required quality assurance and quality control tests:
(1) Methods 1 or 1A are the reference methods for selection of sampling site and sample
traverses.
(2) Method 2 or its allowable alternatives, as provided in appendix A to part 60 of this
chapter, except for Methods 2B and 2E, are the reference methods for determination of
volumetric flow.
(3) Methods 3, 3A, or 3B are the reference methods for the determination of the dry
molecular weight 02 and C02 concentrations in the emissions.
(4) Method 4 (either the standard procedure described in section 8.1 of the method or the
moisture approximation procedure described in section 8.2 of the method) shall be used to
correct pollutant concentrations from a dry basis to a wet basis (or from a wet basis to a dry
basis) and shall be used when relative accuracy test audits of continuous moisture monitoring
systems are conducted. For the purpose of determining the stack gas molecular weight,
however, the alternative wet bulb-dry bulb technique for approximating the stack gas moisture
content described in section 2.2 of Method 4 may be used in lieu of the procedures in sections
8.1 and 8.2 of the method.
(5) Methods 6, 6A, 6B or 6C, and 7, 7A, 7C, 7D or 7E in appendix A-4 to part 60 of this
chapter, as applicable, are the reference methods for determining S02 and NOx pollutant
concentrations. (Methods 6A and 6B in appendix A-4 to part 60 of this chapter may also be
used to determine S02 emission rate in lb/mmBtu.) Methods 7, 7A, 7C, 7D, or 7E in appendix
A-4 to part 60 of this chapter must be used to measure total NOx emissions, both NO and N02,
for purposes of this part. The owner or operator shall not use the following sections,
exceptions, and options of method 7E in appendix A-4 to part 60 of this chapter:
(i) Section 7.1 of the method allowing for use of prepared calibration gas mixtures that
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 87
-------
are produced in accordance with method 205 in Appendix M of 40 CFR Part 51;
(ii) The sampling point selection procedures in section 8.1 of the method, for the emission
testing of boilers and combustion turbines under appendix E to this part. The number and
location of the sampling points for those applications shall be as specified in sections 2.1.2.1
and 2.1.2.2 of appendix E to this part;
(iii) Paragraph (3) in section 8.4 of the method allowing for the use of a multi-hole probe
to satisfy the multipoint traverse requirement of the method;
(iv) Section 8.6 of the method allowing for the use of "Dynamic Spiking" as an
alternative to the interference and system bias checks of the method. Dynamic spiking may be
conducted (optionally) as an additional quality assurance check.
(6) Method 3 A in appendix A-2 and method 7E in appendix A-4 to part 60 of this chapter
are the reference methods for determining NOx and diluent emissions from stationary gas
turbines for testing under appendix E to this part.
(7) ASTM D6784-02, Standard Test Method for Elemental, Oxidized, Particle-Bound
and Total Mercury in Flue Gas Generated from Coal-Fired Stationary Sources (Ontario Hydro
Method) (incorporated by reference under §75.6 of this part) is the reference method for
determining Hg concentration.
(i) Alternatively, Method 29 in appendix A-8 to part 60 of this chapter may be used, with
these caveats: the procedures for preparation of Hg standards and sample analysis in sections
13.4.1.1 through 13.4.1.3 ASTM D6784-02 (incorporated by reference under § 75.6 of this
part) shall be followed instead of the procedures in sections 7.5.33 and 11.1.3 of Method 29 in
appendix A-8 to part 60 of this chapter, and the QA/QC procedures in section 13.4.2 of ASTM
D6784-02 (incorporated by reference under § 75.6 of this part) shall be performed instead of
the procedures in section 9.2.3 of Method 29 in appendix A-8 to part 60 of this chapter. The
tester may also opt to use the sample recovery and preparation procedures in ASTM D6784-02
(incorporated by reference under § 75.6 of this part) instead of the Method 29 in appendix A-8
to part 60 of this chapter procedures, as follows: sections 8.2.8 and 8.2.9.1 of Method 29 in
appendix A-8 to part 60 of this chapter may be replaced with sections 13.2.9.1 through
13.2.9.3 of ASTM D6784-02 (incorporated by reference under § 75.6 of this part); sections
8.2.9.2 and 8.2.9.3 of Method 29 in appendix A-8 to part 60 of this chapter may be replaced
with sections 13.2.10.1 through 13.2.10.4 of ASTM D6784-02 (incorporated by reference
under § 75.6 of this part); section 8.3.4 of Method 29 in appendix A-8 to part 60 of this
chapter may be replaced with section 13.3.4 or 13.3.6 of ASTM D6784-02 (as appropriate)
(incorporated by reference under § 75.6 of this part); and section 8.3.5 of Method 29 in
appendix A-8 to part 60 of this chapter may be replaced with section 13.3.5 or 13.3.6 of
ASTM D6784-02 (as appropriate) (incorporated by reference under § 75.6 of this part).
(ii) Whenever ASTM D6784-02 (incorporated by reference under § 75.6 of this part) or
Method 29 in appendix A-8 to part 60 of this chapter is used, paired sampling trains are
required. To validate a RATA run or an emission test run, the relative deviation (RD),
calculated according to section 11.7 of appendix K to this part, must not exceed 10 percent,
when the average concentration is greater than 1.0 |ig/m\ If the average concentration is < 1.0
|ig/m3. the RD must not exceed 20 percent. The RD results are also acceptable if the absolute
difference between the Hg concentrations measured by the paired trains does not exceed 0.03
|ig/m3. If the RD criterion is met, the run is valid. For each valid run, average the Hg
concentrations measured by the two trains (vapor phase, only).
(iii) Two additional reference methods that may be used to measure Hg concentration are:
Method 30A, "Determination of Total Vapor Phase Mercury Emissions from Stationary
Sources (Instrumental Analyzer Procedure)" and Method 30B, "Determination of Total Vapor
Phase Mercury Emissions from Coal-Fired Combustion Sources Using Carbon Sorbent Traps."
(iv) When Method 29 in appendix A-8 to part 60 of this chapter or ASTM D6784-02
(incorporated by reference under § 75.6 of this part) is used for the Hg emission testing
required under §§75.81(c) and (d), locate the reference method test points according to section
8.1 of Method 3OA, and if Hg stratification testing is part of the test protocol, follow the
procedures in sections 8.1.3 through 8.1.3.5 of Method 3 OA.
§ 75.22(b) (b) The owner or operator may use any of the following methods, which are found in
appendix A to part 60 of this chapter or have been published by ASTM, as a reference method
backup monitoring system to provide quality-assured monitor data:
(1) Method 3A for determining 02 or C02 concentration;
(2) Method 6C for determining S02 concentration;
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 88
-------
(3) Method 7E for determining total NOx concentration (both NO and N02); (4) Method
2, or its allowable alternatives, as provided in appendix A to part 60 of this chapter, except for
Methods 2B and 2E, for determining volumetric flow. The sample point(s) for reference
methods shall be located according to the provisions of section 6.5.5 of appendix A to this
part;
(5) ASTM D6784-02, Standard Test Method for Elemental, Oxidized, Particle-Bound
and Total Mercury in Flue Gas Generated from Coal-Fired Stationary Sources (Ontario Hydro
Method) (incorporated by reference under § 75.6 of this part) for determining Hg
concentration;
(6) Method 29 in appendix A-8 to part 60 of this chapter for determining Hg
concentration;
(7) Method 30A for determining Hg concentration; and
(8) Method 3 OB for determining Hg concentration.
§ 75.22(c)(1)
(c)(1) Instrumental EPA Reference Methods 3 A, 6C, and 7E in appendices A-2 and A-4
of part 60 of this chapter shall be conducted using calibration gases as defined in section 5 of
appendix A to this part. Otherwise, performance tests shall be conducted and data reduced in
accordance with the test methods and procedures of this part unless the Administrator:
(i) Specifies or approves, in specific cases, the use of a reference method with minor
changes in methodology;
(ii) Approves the use of an equivalent method; or
(iii) Approves shorter sampling times and smaller sample volumes when necessitated by
process variables or other factors.
§ 75.22(c)(2)
§ 75.23
(2) Nothing in this paragraph shall be construed to abrogate the Administrator's authority
to require testing under Section 114 of the Act.
§ 75.23 Alternatives to standards incorporated by reference.
(a) The designated representative of a unit may petition the Administrator for an
alternative to any standard incorporated by reference and prescribed in this part in accordance
with § 75.66(c).
(b) [Reserved]
§ 75.24
§ 75.24(a)
§ 75.24 Out-of-control periods and adjustment for system bias.
(a) If an out-of-control period occurs to a monitor or continuous emission monitoring
system, the owner or operator shall take corrective action and repeat the tests applicable to the
"out-of-control parameter" as described in appendix B of this part.
(1) For daily calibration error tests, an out-of-control period occurs when the calibration
error of a pollutant concentration monitor exceeds the applicable specification in section 2.1.4
of appendix B to this part.
(2) For quarterly linearity checks, an out-of-control period occurs when the error in
linearity at any of three gas concentrations (low, mid-range, and high) exceeds the applicable
specification in appendix A to this part.
(3) For relative accuracy test audits, an out-of-control period occurs when the relative
accuracy exceeds the applicable specification in appendix A to this part.
§ 75.24(b)
(b) When a monitor or continuous emission monitoring system is out-of-control, any data
recorded by the monitor or monitoring system are not quality-assured and shall not be used in
calculating monitor data availabilities pursuant to § 75.32 of this part.
§ 75.24(c)
(c) When a monitor or continuous emission monitoring system is out-of-control, the owner
or operator shall take one of the following actions until the monitor or monitoring system has
successfully met the relevant criteria in appendices A and B of this part as demonstrated by
subsequent tests:
(1) Apply the procedures for missing data substitution to emissions from affected unit(s);
or
(2) Use a certified backup monitoring system or a reference method for measuring and
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 89
-------
recording emissions from the affected unit(s); or
(3) Adjust the gas discharge paths from the affected unit(s) with emissions normally
observed by the out-of-control monitor or monitoring system so that all exhaust gases are
monitored by a certified monitor or monitoring system meeting the requirements of appendices
A and B of this part.
§ 75.24(d) (d) When the bias test indicates that an S02 monitor, a flow monitor, a NOx-diluent
continuous emission monitoring system, or a NOx concentration monitoring system used to
determine NOx mass emissions, as defined in § 75.71(a)(2), a Hg concentration monitoring
system or a sorbent trap monitoring system is biased low (i.e., the arithmetic mean of the
differences between the reference method value and the monitor or monitoring system
measurements in a relative accuracy test audit exceed the bias statistic in section 7 of appendix
A to this part), the owner or operator shall adjust the monitor or continuous emission
monitoring system to eliminate the cause of bias such that it passes the bias test or calculate
and use the bias adjustment factor as specified in section 2.3.4 of appendix B to this part.
§ 75.24(e) (e) The owner or operator shall determine if a continuous opacity monitoring system is
out-of-control and shall take appropriate corrective actions according to the procedures
specified for State Implementation Plans, pursuant to appendix M of part 51 of this chapter.
The owner or operator shall comply with the monitor data availability requirements of the
State. If the State has no monitor data availability requirements for continuous opacity
monitoring systems, then the owner or operator shall comply with the monitor data availability
requirements as stated in the data capture provisions of appendix M, part 51 of this chapter.
Subpart D — Missing Data Substitution Procedures
§ 75.30 § 75.30 General provisions.
§ 75.30(a) (a) Except as provided in § 75.34, the owner or operator shall provide substitute data for
each affected unit using a continuous emission monitoring system according to the missing
data procedures in this subpart whenever the unit combusts any fuel and:
(1) A valid, quality-assured hour of S02 concentration data (in ppm) has not been
measured and recorded for an affected unit by a certified S02 pollutant concentration monitor,
or by an approved alternative monitoring method under subpart E of this part, except as
provided in paragraph (d) of this section; or
(2) A valid, quality-assured hour of flow data (in scfh) has not been measured and
recorded for an affected unit from a certified flow monitor, or by an approved alternative
monitoring system under subpart E of this part; or
(3) A valid, quality-assured hour of NOx emission rate data (in lb/mmBtu) has not been
measured or recorded for an affected unit, either by a certified NOx-diluent continuous
emission monitoring system, or by an approved alternative monitoring system under subpart E
of this part; or
(4) A valid, quality-assured hour of C02 concentration data (in percent C02, or percent 02
converted to percent C02 using the procedures in appendix F to this part) has not been
measured and recorded for an affected unit, either by a certified C02 continuous emission
monitoring system or by an approved alternative monitoring method under subpart E of this
part; or
(5) A valid, quality-assured hour of NOx concentration data (in ppm) has not been
measured or recorded for an affected unit, either by a certified NOx concentration monitoring
system used to determine NOx mass emissions, as defined in § 75.71(a)(2), or by an approved
alternative monitoring system under subpart E of this part; or
(6) A valid, quality-assured hour of C02 or 02 concentration data (in percent C02, or
percent 02) used for the determination of heat input has not been measured and recorded for an
affected unit, either by a certified C02 or 02 diluent monitor, or by an approved alternative
monitoring method under subpart E of this part; or
(7) A valid, quality-assured hour of moisture data (in percent H20) has not been
measured or recorded for an affected unit, either by a certified moisture monitoring system or
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 90
-------
an approved alternative monitoring method under subpart E of this part. This requirement
does not apply when a default percent moisture value, as provided in §§ 75.11(b) or 75.12(b),
is used to account for the hourly moisture content of the stack gas; or
(8) A valid, quality-assured hour of heat input rate data (in mmBtu/hr) has not been
measured and recorded for a unit from a certified flow monitor and a certified diluent (C02 or
02) monitor or by an approved alternative monitoring system under subpart E of this part.
§ 75.30(b) (b) However, the owner or operator shall have no need to provide substitute data
according to the missing data procedures in this subpart if the owner or operator uses S02,
C02, NOx, or 02 concentration, flow rate, percent moisture, or NOx emission rate data
recorded from either a certified redundant or regular non-redundant backup CEMS, a like-kind
replacement non-redundant backup analyzer, or a backup reference method monitoring system
when the certified primary monitor is not operating or is out-of-control. A redundant or
non-redundant backup continuous emission monitoring system must have been certified
according to the procedures in § 75.20 prior to the missing data period. Non-redundant
backup continuous emission monitoring system must pass a linearity check (for pollutant
concentration monitors) or a calibration error test (for flow monitors) prior to each period of
use of the certified backup monitor for recording and reporting emissions. Use of a certified
backup monitoring system or backup reference method monitoring system is optional and at
the discretion of the owner or operator.
§ 75.30(c) (c) When the certified primary monitor is not operating or out-of-control, then data
recorded for an affected unit from a certified backup continuous emission monitor or backup
reference method monitoring system are used, as if such data were from the certified primary
monitor, to calculate monitor data availability in § 75.32, and to provide the quality-assured
data used in the missing data procedures in §§ 75.31 and 75.33, such as the "hour after" value.
§ 75.30(d) (d) The owner or operator shall comply with the applicable provisions of this paragraph
during hours in which a unit with an S02 continuous emission monitoring system combusts
only gaseous fuel.
(1) Whenever a unit with an S02 CEMS combusts only natural gas or pipeline natural gas
(as defined in § 72.2 of this chapter) and the owner or operator is using the procedures in
section 7 of appendix F to this part to determine S02 mass emissions pursuant to § 75.11(e)(1),
the owner or operator shall, for purposes of reporting heat input data under § 75.57(b)(5), and
for the calculation of S02 mass emissions using Equation F-23 in section 7 of appendix F to
this part, substitute for missing data from a flow monitoring system, C02 diluent monitor or 02
diluent monitor using the missing data substitution procedures in § 75.36.
(2) Whenever a unit with an S02 CEMS combusts gaseous fuel and the owner or operator
uses the gas sampling and analysis and fuel flow procedures in appendix D to this part to
determine S02 mass emissions pursuant to § 75.11(e)(2), the owner or operator shall substitute
for missing total sulfur content, gross calorific value, and fuel flowmeter data using the missing
data procedures in appendix D to this part and shall also, for purposes of reporting heat input
data under § 75.57(b)(5), substitute for missing data from a flow monitoring system, C02
diluent monitor or 02 diluent monitor using the missing data substitution procedures in
§75.36.
(3) The owner or operator of a unit with an S02 monitoring system shall not include hours
when the unit combusts only gaseous fuel in the S02 data availability calculations in § 75.32 or
in the calculations of substitute S02 data using the procedures of either § 75.31 or § 75.33, for
hours when S02 emissions are determined in accordance with § 75.11(e)(1) or (e)(2). For the
purpose of the missing data and availability procedures for S02 pollutant concentration
monitors in §§ 75.31 and 75.33 only, all hours during which the unit combusts only gaseous
fuel shall be excluded from the definition of "monitor operating hour," "quality assured
monitor operating hour," "unit operating hour," and "unit operating day," when S02 emissions
are determined in accordance with § 75.11(e)(1) or (e)(2).
(4) During all hours in which a unit with an S02 continuous emission monitoring system
combusts only gaseous fuel and the owner or operator uses the S02 monitoring system to
determine S02 mass emissions pursuant to § 75.11(e)(3), the owner or operator shall determine
the percent monitor data availability for S02 in accordance with § 75.32 and shall use the
standard S02 missing data procedures of § 75.33.
§ 75.31 § 75.31 Initial missing data procedures.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 91
-------
§ 75.31(a) (a) During the first 720 quality-assured monitor operating hours following initial
certification of the required S02, C02, 02, Hg concentration or moisture monitoring system(s)
at a particular unit or stack location (i.e., the date and time at which quality assured data begins
to be recorded by CEMS(s) installed at that location), and during the first 2,160 quality-
assured monitor operating hours following initial certification of the required NOx-diluent,
NOx concentration, or flow monitoring system(s) at the unit or stack location, the owner or
operator shall provide substitute data required under this subpart according to the procedures
in paragraphs (b) and (c) of this section. The owner or operator of a unit shall use these
procedures for no longer than three years (26,280 clock hours) following initial certification.
§ 75.31(b) (b) SO2, CO2, or 02 concentration data, Hg concentration data and moisture data. For
each hour of missing S02, Hg, or C02 emissions concentration data (including C02 data
converted from 02 data using the procedures in appendix F of this part), or missing 02 or C02
diluent concentration data used to calculate heat input, or missing moisture data, the owner or
operator shall calculate the substitute data as follows:
(1) Whenever prior quality-assured data exist, the owner or operator shall substitute, by
means of the data acquisition and handling system, for each hour of missing data, the average
of the hourly S02, C02, Hg, or 02 concentrations or moisture percentages recorded by a
certified monitor for the unit operating hour immediately before and the unit operating hour
immediately after the missing data period.
(2) Whenever no prior quality assured S02, C02, Hg, or 02 concentration data or moisture
data exist, the owner or operator shall substitute, as applicable, for each hour of missing data,
the maximum potential S02 concentration or the maximum potential C02 concentration or the
minimum potential 02 concentration or (unless Equation 19-3, 19-4 or 19-8 in Method 19 in
appendix A to part 60 of this chapter is used to determine NOx emission rate) the minimum
potential moisture percentage, or the maximum potential Hg concentration, as specified,
respectively, in sections 2.1.1.1, 2.1.3.1, 2.1.3.2 and 2.1.5 of appendix A to this part. If
Equation 19-3, 19-4 or 19-8 in Method 19 in appendix A to part 60 of this chapter is used to
determine NOx emission rate, substitute the maximum potential moisture percentage, as
specified in section 2.1.6 of appendix A to this part.
§ 75.31(c) (c) Volumetric flow and NOx emission rate or NOx concentration data (load ranges or
operational bins used). The procedures in this paragraph apply to affected units for which
load-based ranges or non-load-based operational bins, as defined, respectively, in sections 2
and 3 of appendix C to this part are used to provide substitute NOx and flow rate data. For
each hour of missing volumetric flow rate data, NOx emission rate data, or NOx concentration
data used to determine NOx mass emissions:
(1) Whenever prior quality-assured data exist in the load range (or operational bin)
corresponding to the operating load (or operating conditions) at the time of the missing data
period, the owner or operator shall substitute, by means of the automated data acquisition and
handling system, for each hour of missing data, the arithmetic average of all of the prior
quality-assured hourly flow rates, NOx emission rates, or NOx concentrations in the
corresponding load range (or operational bin) as determined using the procedure in appendix C
to this part. When non-load-based operational bins are used, if essential operating or
parametric data are unavailable for any hour in the missing data period, such that the
operational bin cannot be determined, the owner or operator shall, for that hour, substitute (as
applicable) the maximum potential flow rate as specified in section 2.1.4.1 of appendix A to
this part or the maximum potential NOx emission rate or the maximum potential NOx
concentration as specified in section 2.1.2.1 of appendix A to this part.
(2) This paragraph (c)(2) does not apply to non-load-based units using operational bins.
Whenever no prior quality-assured flow or NOx emission rate or NOx concentration data exist
for the corresponding load range, the owner or operator shall substitute, for each hour of
missing data, the average hourly flow rate or the average hourly NOx emission rate or NOx
concentration at the next higher level load range for which quality-assured data are available.
(3) Whenever no prior quality assured flow rate or NOx emission rate or NOx
concentration data exist for the corresponding load range, or any higher load range (or for non-
load-based units using operational bins, when no prior quality-assured data exist in the
corresponding operational bin), the owner or operator shall, as applicable, substitute, for each
hour of missing data, the maximum potential flow rate as specified in section 2.1.4.1 of
appendix A to this part or shall substitute the maximum potential NOx emission rate or the
maximum potential NOx concentration, as specified in section 2.1.2.1 of appendix A to this
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 92
-------
part. Alternatively, where a unit with add-on NOx emission controls can demonstrate that the
controls are operating properly during the hour, as provided in §75.34(d), the owner or
operator may substitute, as applicable, the maximum controlled NOx emission rate (MCR) or
the maximum expected NOx concentration (MEC).
§ 75.31(d) (d) Non-load-based volumetric flow and NOx emission rate or NOx concentration data
(operational bins not used). The procedures in this paragraph, (d), apply only to affected units
that do not produce electrical output (in megawatts) or thermal output (in klb/hr of steam) and
for which operational bins are not used. For each hour of missing volumetric flow rate data,
NOx emission rate data, or NOx concentration data used to determine NOx mass emissions:
(1) Whenever prior quality-assured data exist at the time of the missing data period, the
owner or operator shall substitute, by means of the automated data acquisition and handling
system, for each hour of missing data, the arithmetic average of all of the prior quality-assured
hourly average flow rates or NOx emission rates or NOx concentrations.
(2) Whenever no prior quality-assured flow rate, NOx emission rate, or NOx concentration
data exist, the owner or operator shall, as applicable, substitute for each hour of missing data,
the maximum potential flow rate as specified in section 2.1.4.1 of appendix A to this part or
the maximum potential NOx emission rate or the maximum potential NOx concentration as
specified in section 2.1.2.1 of appendix A to this part.
§ 75.32 § 75.32 Determination of monitor data availability for standard missing data
procedures.
§ 75.32(a) (a) Following initial certification of the required S02, C02, 02, or Hg concentration, or
moisture monitoring system(s) at a particular unit or stack location (i.e., the date and time at
which quality assured data begins to be recorded by CEMS(s) at that location), the owner or
operator shall begin calculating the percent monitor data availability as described in paragraph
(a)(1) of this section, and shall, upon completion of the first 720 quality-assured monitor
operating hours, record, by means of the automated data acquisition and handling system, the
percent monitor data availability for each monitored parameter. Similarly, following initial
certification of the required NOx-diluent, NOx concentration, or flow monitoring system(s) at a
unit or stack location, the owner or operator shall begin calculating the percent monitor data
availability as described in paragraph (a)(1) of this section, and shall, upon completion of the
first 2,160 quality-assured monitor operating hours, record, by means of the automated data
acquisition and handling system, the percent monitor data availability for each monitored
parameter. Notwithstanding these requirements, if three years (26,280 clock hours) have
elapsed since the date and hour of initial certification and fewer than 720 (or 2,160, as
applicable) quality-assured monitor operating hours have been recorded, the owner or operator
shall begin recording the percent monitor data availability. The percent monitor data
availability shall be calculated for each monitored parameter at each unit or stack location, as
follows:
§ 75.32(a)(1)
(1) Prior to completion of 8,760 unit (or stack) operating hours following initial
certification, the owner or operator shall, for the purpose of applying the standard missing data
procedures of § 75.33, use Equation 8 to calculate, hourly, percent monitor data availability.
Percent
monitor data =
availability
Total unit operating
hours for which
quality - assured
data were recorded
since certification
Total unit operating
hours since certificaiton
-x 100
(Eq. 8)
§ 75.32(a)(2) (2) Upon completion of 8,760 unit (or stack) operating hours following initial
certification and thereafter, the owner or operator shall, for the purpose of applying the
standard missing data procedures of § 75.33, use Equation 9 to calculate, hourly, percent
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 93
-------
monitor data availability. Notwithstanding this requirement, if three years (26,280 clock
hours) have elapsed since initial certification and fewer than 8,760 unit or stack operating
hours have been accumulated, the owner or operator shall begin using a modified version of
Equation 9, as described in paragraph (a)(3) of this section.
Total unit operating hours
for which quality - assured data
were recorded during previous
Percent
, 8,760 unit operating hours
monitor data = x 100
8,760
availability
(Eq. 9)
§ 75.32(a)(3) (3) When calculating percent monitor data availability using Equation 8 or 9, the owner
or operator shall include all unit operating hours, and all monitor operating hours for which
quality-assured data were recorded by a certified primary monitor; a certified redundant or
non-redundant backup monitor or a reference method for that unit; or by an approved
alternative monitoring system under subpart E of this part. No hours from more than three
years (26,280 clock hours) earlier shall be used in Equation 9. For a unit that has accumulated
fewer than 8,760 unit operating hours in the previous three years (26,280 clock hours), replace
the words "during previous 8,760 unit operating hours" in the numerator of Equation 9 with "in
the previous three years" and replace "8,760" in the denominator of Equation 9 with "total unit
operating hours in the previous three years" The owner or operator of a unit with an S02
monitoring system shall, when S02 emissions are determined in accordance with § 75.11(e)(1)
or (e)(2), exclude hours in which a unit combusts only gaseous fuel from calculations of
percent monitor data availability for S02 pollutant concentration monitors, as provided in
§ 75.30(d).
§ 75.32(b) (b) The monitor data availability shall be calculated for each hour during each missing
data period. The owner or operator shall record the percent monitor data availability for each
hour of each missing data period to implement the missing data substitution procedures.
§ 75.33 § 75.33 Standard missing data procedures for S02, NOx,, Hg and flow rate.
§ 75.33(a) (a) Following initial certification of the required S02, NOx, and flow rate monitoring
system(s) at a particular unit or stack location (i.e., the date and time at which quality assured
data begins to be recorded by CEMS(s) at that location) and upon completion of the first 720
quality-assured monitor operating hours (for S02) or the first 2,160 quality assured monitor
operating hours (for flow, NOx emission rate, or NOx concentration), the owner or operator
shall provide substitute data required under this subpart according to the procedures in
paragraphs (b) and (c) of this section and depicted in Table 1 (S02) and Table 2 of this section
(NOx, flow). The owner or operator may either implement the provisions of paragraphs (b)
and (c) of this section on a non-fuel-specific basis, or may, as described in paragraphs (b)(5),
(b)(6), (c)(7) and (c)(8) of this section, provide fuel-specific substitute data values.
Notwithstanding these requirements, if three years (26,280 clock hours) have elapsed since the
date and hour of initial certification, and fewer than 720 (or 2,160, as applicable) quality
assured monitor operating hours have been recorded, the owner or operator shall begin using
the missing data procedures of this section. The owner or operator of a unit shall substitute for
missing data using quality-assured monitor operating hours of data from no earlier than three
years (26,280 clock hours) prior to the date and time of the missing data period.
§ 75.33(b) (b) S02 concentration data. For each hour of missing S02 concentration data,
§ 75.33(b)(1) (1) If the monitor data availability is equal to or greater than 95.0 percent, the owner or
operator shall calculate substitute data by means of the automated data acquisition and
handling system for that hour of the missing data period according to the following procedures:
(i) For a missing data period less than or equal to 24 hours, substitute the average of the
hourly S02 concentrations recorded by an S02 pollutant concentration monitor for the hour
before and the hour after the missing data period.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 94
-------
§ 75.33(b)(2)
§ 75.33(b)(3)
§ 75.33(b)(4)
§ 75.33(b)(5)
§ 75.33(b)(6)
(ii) For a missing data period greater than 24 hours, substitute the greater of:
(A) The 90th percentile hourly S02 concentration recorded by an S02 pollutant
concentration monitor during the previous 720 quality-assured monitor operating hours; or
(B) The average of the hourly S02 concentrations recorded by an S02 pollutant
concentration monitor for the hour before and the hour after the missing data period.
(2) If the monitor data availability is at least 90.0 percent but less than 95.0 percent, the
owner or operator shall calculate substitute data by means of the automated data acquisition
and handling system for that hour of the missing data period according to the following
procedures:
(i) For a missing data period of less than or equal to 8 hours, substitute the average of the
hourly S02 concentrations recorded by an S02 pollutant concentration monitor for the hour
before and the hour after the missing data period.
(ii) For a missing data period of more than 8 hours, substitute the greater of:
(A) the 95th percentile hourly S02 concentration recorded by an S02 pollutant
concentration monitor during the previous 720 quality-assured monitor operating hours; or
(B) The average of the hourly S02 concentrations recorded by an S02 pollutant
concentration monitor for the hour before and the hour after the missing data period.
(3) If the monitor data availability is at least 80.0 percent but less than 90.0 percent, the
owner or operator shall substitute for that hour of the missing data period the maximum hourly
S02 concentration recorded by an S02 pollutant concentration monitor during the previous 720
quality-assured monitor operating hours.
(4) If the monitor data availability is less than 80.0 percent, the owner or operator shall
substitute for that hour of the missing data period the maximum potential S02 concentration, as
defined in section 2.1.1.1 of appendix A to this part.
(5) For units that combust more than one type of fuel, the owner or operator may opt to
implement the missing data routines in paragraphs (b)(1) through (b)(4) of this section on a
fuel-specific basis. If this option is selected, the owner or operator shall document this in the
monitoring plan required under § 75.53.
(6) Use the following guidelines to implement paragraphs (b)(1) through (b)(4) of this
section on a fuel-specific basis:
(i) Separate the historical, quality-assured S02 concentration data according to the type of
fuel combusted;
(ii) For units that co-fire different types of fuel, either group the co-fired hours with the
historical data for the fuel with the highest S02 emission rate (e.g., if diesel oil and pipeline
natural gas are co-fired, count co-fired hours as oil-burning hours), or separate the co-fired
hours from the single-fuel hours;
(iii) For the purposes of providing substitute data under paragraph (b)(4) of this section,
determine a separate, fuel-specific maximum potential S02 concentration (MPC) value for
each type of fuel combusted in the unit, in a manner consistent with section 2.1.1.1 of appendix
A to this part. For fuel that qualifies as pipeline natural gas or natural gas (as defined in § 72.2
of this chapter), the owner or operator shall, for the purposes of determining the MPC, either
determine the maximum total sulfur content and minimum gross calorific value (GCV) of the
gas by fuel sampling and analysis or shall use a default total sulfur content of 0.05 percent by
weight (dry basis) and a default GCV value of 950 Btu/scf. For co-firing, the MPC value shall
be based on the fuel with the highest S02 emission rate. The exact methodology used to
determine each fuel-specific MPC value shall be documented in the monitoring plan for the
unit or stack; and
(iv) For missing data periods that require 720-hour (or, if applicable, 3-year) lookbacks,
use historical data for the type of fuel combusted during each hour of the missing data period
to determine the appropriate substitute data value for that hour. For co-fired missing data
hours, if the historical data are separated into single-fuel and co-fired hours, use co-fired data
to provide the substitute data values. Otherwise, use data for the fuel with the highest S02
emission rate to provide substitute data values for co-fired missing data hours.
§ 75.33(b)(7)
(7) Table 1 summarizes the provisions of paragraphs (b)(1) through (b)(6) of this section.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 95
-------
§ 75.33(c) (c) Volumetric flow rate, N0X emission rate and N0X concentration data. Use the
procedures in this paragraph to provide substitute NOx and flow rate data for all affected units
for which load-based ranges have been defined in accordance with section 2 of appendix C to
this part. For units that do not produce electrical or thermal output (i.e., non-load-based units),
use the procedures in this paragraph only to provide substitute data for volumetric flow rate,
and only if operational bins have been defined for the unit, as described in section 3 of
appendix C to this part. Otherwise, use the applicable missing data procedures in paragraph
(d) or (e) of this section for non-load-based units. For each hour of missing volumetric flow
rate data, NOx emission rate data, or NOx concentration data used to determine NOx mass
emissions:
§ 75.33(c)(1)
(1) If the monitor data availability is equal to or greater than 95.0 percent, the owner or
operator shall calculate substitute data by means of the automated data acquisition and
handling system for that hour of the missing data period according to the following procedures:
(i) For a missing data period less than or equal to 24 hours, substitute, as applicable, for
each missing hour, the arithmetic average of the flow rates or NOx emission rates or NOx
concentrations recorded by a monitoring system during the previous 2,160 quality assured
monitor operating hours at the corresponding unit load range or operational bin, as determined
using the procedure in appendix C to this part.
(ii) For a missing data period greater than 24 hours, substitute, as applicable, for each
missing hour, the greater of:
(A) The 90th percentile hourly flow rate or the 90th percentile NOx emission rate or the
90th percentile NOx concentration recorded by a monitoring system during the previous 2,160
quality-assured monitor operating hours at the corresponding unit load range or operational
bin, as determined using the procedure in appendix C to this part; or
(B) The average of the recorded hourly flow rates, NOx emission rates or NOx
concentrations recorded by a monitoring system for the hour before and the hour after the
missing data period.
§ 75.33(c)(2)
(2) If the monitor data availability is at least 90.0 percent but less than 95.0 percent, the
owner or operator shall calculate substitute data by means of the automated data acquisition
and handling system for that hour of the missing data period according to the following
procedures:
(i) For a missing data period of less than or equal to 8 hours, substitute, as applicable, the
arithmetic average hourly flow rate or NOx emission rate or NOx concentration recorded by a
monitoring system during the previous 2,160 quality-assured monitor operating hours at the
corresponding unit load range or operational bin, as determined using the procedure in
appendix C to this part.
(ii) For a missing data period greater than 8 hours, substitute, as applicable, for each
missing hour, the greater of:
(A) The 95th percentile hourly flow rate or the 95th percentile NOx emission rate or the
95th percentile NOx concentration recorded by a monitoring system during the previous 2,160
quality-assured monitor operating hours at the corresponding unit load range or operational
bin, as determined using the procedure in appendix C to this part; or
(B) The average of the hourly flow rates, NOx emission rates or NOx concentrations
recorded by a monitoring system for the hour before and the hour after the missing data period.
§ 75.33(c)(3)
(3) If the monitor data availability is at least 80.0 percent but less than 90.0 percent, the
owner or operator shall, by means of the automated data acquisition and handling system,
substitute, as applicable, for that hour of the missing data period, the maximum hourly flow
rate or the maximum hourly NOx emission rate or the maximum hourly NOx concentration
recorded during the previous 2,160 quality-assured monitor operating hours at the
corresponding unit load range or operational bin, as determined using the procedure in
appendix C to this part.
§ 75.33(c)(4)
(4) If the monitor data availability is less than 80.0 percent, the owner or operator shall
substitute, as applicable, for that hour of the missing data period, the maximum potential flow
rate, as defined in section 2.1.4.1 of appendix A to this part, or the maximum NOx emission
rate, as defined in section 2.1.2.1 of appendix A to this part, or the maximum potential NOx
concentration, as defined in section 2.1.2.1 of appendix A to this part. In addition, when non-
load-based operational bins are used, the owner or operator shall substitute the maximum
potential flow rate for any hour in the missing data period in which essential operating or
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 96
-------
parametric data are unavailable and the operational bin cannot be determined.
§ 75.33(c)(5)
§ 75.33(c)(6)
§ 75.33(c)(7)
§ 75.33(c)(8)
(5) This paragraph, (c)(5), does not apply to non-load-based affected units using
operational bins. Whenever no prior quality-assured flow rate data, NOx concentration data or
NOx emission rate data exist for the corresponding load range, the owner or operator shall
substitute, as applicable, for each hour of missing data, the maximum hourly flow rate or the
maximum hourly NOx concentration or maximum hourly NOx emission rate at the next higher
level load range for which quality-assured data are available.
(6) Whenever no prior quality-assured flow rate data, NOx concentration data or NOx
emission rate data exist at either the corresponding load range (or a higher load range) or at the
corresponding operational bin, the owner or operator shall substitute, as applicable, either the
maximum potential NOx emission rate or the maximum potential NOx concentration, as
defined in section 2.1.2.1 of appendix A to this part or the maximum potential flow rate, as
defined in section 2.1.4.1 of appendix A to this part.
(7) This paragraph (c)(7) does not apply to affected units using non-load-based
operational bins. For units that combust more than one type of fuel, the owner or operator may
opt to implement the missing data routines in paragraphs (c)(1) through (c)(6) of this section
on a fuel-specific basis. If this option is selected, the owner or operator shall document this in
the monitoring plan required under § 75.53.
(8) This paragraph, (c)(8), does not apply to affected units using non-load-based
operational bins. Use the following guidelines to implement paragraphs (c)(1) through (c)(6)
of this section on a fuel-specific basis:
(i) Separate the historical, quality-assured NOx emission rate, NOx concentration, or flow
rate data according to the type of fuel combusted;
(ii) For units that co-fire different types of fuel, either group the co-fired hours with the
historical data for the fuel with the highest NOx emission rate, NOx concentration or flow rate,
or separate the co-fired hours from the single-fuel hours;
(iii) For the purposes of providing substitute data under paragraph (c)(4) of this section, a
separate, fuel-specific maximum potential concentration (MPC), maximum potential NOx
emission rate (MER), or maximum potential flow rate (MPF) value (as applicable) shall be
determined for each type of fuel combusted in the unit, in a manner consistent with § 72.2 of
this chapter and with section 2.1.2.1 or 2.1.4.1 of appendix A to this part. For co-firing, the
MPC, MER or MPF value shall be based on the fuel with the highest emission rate or flow rate
(as applicable). Furthermore, for a unit with add-on NOx emission controls, a separate fuel-
specific maximum controlled NOx emission rate (MCR) or maximum expected NOx
concentration (MEC) value (as applicable) shall be determined for each type of fuel combusted
in the unit. The exact methodology used to determine each fuel-specific MPC, MER, MEC,
MCR or MPF value shall be documented in the monitoring plan for the unit or stack.
(iv) For missing data periods that require 2,160-hour (or, if applicable, 3-year) lookbacks,
use historical data for the type of fuel combusted during each hour of the missing data period
to determine the appropriate substitute data value for that hour. For co-fired missing data
hours, if the historical data are separated into single-fuel and co-fired hours, use co-fired data
to provide the substitute data values. Otherwise, use data for the fuel with the highest NOx
emission rate, NOx concentration or flow rate (as applicable) to provide substitute data values
for co-fired missing data hours. Tables 1 and 2 follow.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 97
-------
Table 1. ~ Missing Data Procedure for S02 CEMS, C02 CEMS, Moisture CEMS, Hg CEMS, and Diluent
(C02 or 02) Monitors for Heat Input Determination
Trigger conditions
Calculation routines
Monitor data availability (percent)
Duration (N) of CEMS
outage (hours)2
Method
Lookback
period
95 or more (90 or more for Hg)..
N < 24
Average
HB/HA
N> 24
For S02, C02, Hg, and H20**, the greater of:
Average
90th percentile
For 02 and H2Ox, the lesser of:
10th percentile
HB/HA
720 hours*
HB/HA.
720 hours*
90 or more, but below 95 (> 80
but < 90 for Hg)
N < 8
Average
HB/HA
N> 8
For S02, C02, Hg, and H20**, the greater of:
Average
95th percentile
For 02 and H2Ox, the lesser of:
Average
5th Percentile
HB/HA
720 hours*
HB/HA
720 hours*
80 or more, but below 90 (> 70
but < 80 for Hg)
N> 0
For S02, C02, Hg, and H20**,
Maximum value1
720 hours*
For 02 and H2Ox:
Minimum value1
720 hours*
Below 80 (Below 70 for Hg)
N > 0
Maximum potential concentration3 or % (for S02,
C02, Hg, and H20**) or
Minimum potential concentration or % (for 02 and
ll-O'i
None
HB/HA = hour before and hour after the CEMS outage.
* Quality-assured, monitor operating hours, during unit operation. May be either fuel-specific or non-fuel-specific. For units that report data only for the ozone
season, include only quality assured monitor operating hours within the ozone season in the lookback period. Use data from no earlier than 3 years prior to the
missing data period.
1 Where a unit with add-on SO2 or Hg emission controls can demonstrate that the controls are operating properly during the missing data period, as provided in
§ 75.34, the unit may use the maximum controlled concentration from the previous 720 quality-assured monitor operating hours.
2
During unit operating hours.
3
Alternatively, where a unit with add-on SO2 or Hg emission controls can demonstrate that the controls are operating properly during the missing data period,
as provided in § 75.34, the unit may report the greater of: (a) the maximum expected SO2 or Hg concentration or (b) 1.25 times the maximum controlled value
from the previous 720 quality-assured monitor operating hours.
x Use this algorithm for moisture except when Equation 19-3, 19-4 or 19-8 in Method 19 in appendix A to part 60 of this chapter is used for NQ< emission rate.
** Use this algorithm for moisture only when Equation 19-3, 19-4 or 19-8 in Method 19 in appendix A to part 60 of this chapter is used for NO< emission
rate.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 98
-------
Table 2. ~ Load-Based Missing Data Procedure for NOx-Diluent CEMS, NOx Concentration
CEMS and Flow Rate CEMS
Trigger conditions
Calculation routines
Monitor data availability
(percent)
95 or more
90 or more, but below 95.
80 or more, but below 90.
Below 80
Duration (N) of CEMS
outage (hours)
N < 24
N > 24
N < 8
N> 8
N> 0
N > 0
Method
Average.
The greater of:
Average
90th percentile..
Average
The greater of:
Average
95th percentile
Maximum value1.
Maximum potential NOx
emission rate3; or maximum
potential NOx concentration3;
or maximum potential flow
rate.
Lookback
period
2160 hours*.
HB/HA
2160 hours*.
2160 hours*.
HB/HA
2160 hours*.
2160 hours*.
None
HB/HA = hour before and hour after the CEMS outage.
* Quality-assured, monitor operating hours, using data at the corresponding load range ("load bin") for each hour of the missing data period. May be either
fuel-specific or non-fuel-specific. For units that report data only for the ozone season, include only quality assured monitor operating hours within the ozone
season in the lookback period. Use data from no earlier than three years prior to the missing data period.
Where a unit with add-on NOx emission controls can demonstrate that the controls are operating properly during the missing data period, as provided in
§ 75.34, the unit may use the maximum controlled \() concentration or emission rate from the previous 2160 quality-assured monitor operating hours. Units
with add-on controls that report NOx mass emissions on a year-round basis under subpart H of this part may use separate ozone season and non-ozone season
data pools to provide substitute data values, as described in § 75.34 (a)(2).
2 During unit operating hours.
3 Alternatively, where a unit with add-on \() emission controls can demonstrate that the controls are operating properly during the missing data period, as
provided in § 75.34, the unit may report the greater of: (a) the maximum expected \() concentration (or maximum controlled \() emission rate, as
applicable); or (b) 1.25 times the maximum controlled value at the corresponding load bin, from the previous 2160 quality-assured monitor operating hours.
§ 75.33(c)(9)
(9) The load-based provisions of paragraphs (c)(1) through (c)(8) of this section are
summarized in Table 2 of this section. The non-load-based provisions for volumetric flow rate,
found in paragraphs (c)(1) through (c)(4), and (c)(6) of this section, are presented in Table 4 of
this section.
§ 75.33(d)
(d) Non-load-based NOx emission rate and NOx concentration data. Use the procedures
in this paragraph to provide substitute NOx data for affected units that do not produce electrical
output (in megawatts) or thermal output (in klb/hr of steam). For each hour of missing NOx
emission rate data, or NOx concentration data used to determine NOx mass emissions:
§ 75.33(d)(1)
(1) If the monitor data availability is equal to or greater than 95.0 percent, the owner or
operator shall calculate substitute data by means of the automated data acquisition and handling
system for that hour of the missing data period according to the following procedures:
(i) For a missing data period less than or equal to 24 hours, substitute, as applicable, for
each missing hour, the arithmetic average of the NOx emission rates or NOx concentrations
recorded by a monitoring system in a 2,160 hour lookback period. The lookback period may
be comprised of either:
(A) The previous 2,160 quality assured monitor operating hours, or
(B) The previous 2,160 quality-assured monitor operating hours at the corresponding
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 99
-------
operational bin, if operational bins, as defined in section 3 of appendix C to this part, are used.
(ii) For a missing data period greater than 24 hours, substitute, for each missing hour, the
90th percentile NOx emission rate or the 90th percentile NOx concentration recorded by a
monitoring system during the previous 2,160 quality assured monitor operating hours (or
during the previous 2,160 quality-assured monitor operating hours at the corresponding
operational bin, if operational bins are used).
§ 75.33(d)(2)
(2) If the monitor data availability is at least 90.0 percent but less than 95.0 percent, the
owner or operator shall calculate substitute data by means of the automated data acquisition
and handling system for that hour of the missing data period according to the following
procedures:
(i) For a missing data period of less than or equal to eight hours, substitute, as applicable,
the arithmetic average of the hourly NOx emission rates or NOx concentrations recorded by a
monitoring system during the previous 2,160 quality-assured monitor operating hours (or
during the previous 2,160 quality-assured monitor operating hours at the corresponding
operational bin, if operational bins are used).
(ii) For a missing data period greater than eight hours, substitute, for each missing hour,
the 95th percentile hourly flow rate or the 95th percentile NOx emission rate or the 95th
percentile NOx concentration recorded by a monitoring system during the previous 2,160
quality-assured monitor operating hours (or during the previous 2,160 quality-assured monitor
operating hours at the corresponding operational bin, if operational bins are used).
§ 75.33(d)(3)
(3) If the monitor data availability is at least 80.0 percent but less than 90.0 percent, the
owner or operator shall, by means of the automated data acquisition and handling system,
substitute, as applicable, for that hour of the missing data period, the maximum hourly NOx
emission rate or the maximum hourly NOx concentration recorded during the previous 2,160
quality-assured monitor operating hours (or during the previous 2,160 quality-assured monitor
operating hours at the corresponding operational bin, if operational bins are used).
§ 75.33(d)(4)
(4) If the monitor data availability is less than 80.0 percent, the owner or operator shall
substitute, as applicable, for that hour of the missing data period, the maximum NOx emission
rate, as defined in § 72.2 of this chapter, or the maximum potential NOx concentration, as
defined in section 2.1.2.1 of appendix A to this part. In addition, when operational bins are
used, the owner or operator shall substitute (as applicable) the maximum potential NOx
emission rate or the maximum potential NOx concentration for any hour in the missing data
period in which essential operating or parametric data are unavailable and the operational bin
cannot be determined.
§ 75.33(d)(5)
(5) If operational bins are used and no prior quality-assured NOx concentration data or
NOx emission rate data exist for the corresponding operational bin, the owner or operator shall
substitute, as applicable, either the maximum potential NOx emission rate, as defined in § 72.2
of this chapter, or the maximum potential NOx concentration, as defined in section 2.1.2.1 of
appendix A to this part.
§ 75.33(d)(6)
(6) Table 3 of this section summarizes the provisions of paragraphs (d)(1) through (d)(5)
of this section.
§ 75.33(e) (e) Non-load-based volumetric flow rate data.
(1) If operational bins, as defined in section 3 of appendix C to this part, are used for a unit
that does not produce electrical or thermal output, use the missing data procedures in paragraph
(c) of this section to provide substitute volumetric flow rate data for the unit.
(2) If operational bins are not used, modify the procedures in paragraph (c) of this section
as follows:
(i) In paragraphs (c)(1) through (c)(3), the words "previous 2,160 quality-assured monitor
operating hours" shall apply rather than "previous 2,160 quality-assured monitor operating
hours at the corresponding unit load range or operational bin, as determined using the
procedure in appendix C to this part;"
(ii) The last sentence in paragraph (c)(4) does not apply;
(iii) Paragraphs (c)(5), (c)(7), and (c)(8) are not applicable; and
(iv) In paragraph (c)(6), the words, "for either the corresponding load range (or a higher
load range) or at the corresponding operational bin" do not apply.
(3) Table 4 of this section summarizes the provisions of paragraphs (e)(1) and (e)(2) of
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 100
-------
this section. Tables 3 and 4 follow:
Table 3. ~ Non-load-based Missing Data Procedure for NOx-Diluent
CEMS and NOx Concentration CEMS
Trigger conditions
Calculation routines
Monitor data availability
(percent)
Duration (N) of CEMS
outage (hours)1
Method
Lookback period
95 or more
N < 24
N > 24
N < 8
N> 8
N> 0
N> 0
Average
2160 hours*
2160 hours*
2160 hours*
2160 hours*
2160 hours*
None
90 or more, but below 95
80 or more, but below 90
Below 80, or operational bin
indeterminable
90th percentile
Average
95th percentile
Maximum value3
Maximum potential NOx emission
rate2 or maximum potential NOx
concentration2
* If operational bins are used, the lookback period is 2,160 quality-assured, monitor operating hours, and data at the corresponding operational bin are used to
provide substitute data values. If operational bins are not used, the lookback period is the previous 2,160 quality-assured monitor operating hours. For units that
report data only for the ozone season, include only quality-assured monitor operating hours within the ozone season in the lookback period. Use data from no
earlier than three years prior to the missing data period.
^ During unit operation.
Alternatively, where a unit with add-on NOx emission controls can demonstrate that the controls are operating properly, as provided in§ 75.34, the unit may
report the greater of: (a) the maximum expected NO< concentration, (or maximum controlled NOx emission rate, as applicable); or (b) 1.25 times the maximum
controlled value at the corresponding operational bin (if applicable), from the previous 2160 quality-assured monitor operating hours.
3
Where a unit with add-on NOx emission controls can demonstrate that the controls are operating properly during the missing data period, as provided in
§ 75.34, the unit may use the maximum controlled NOx concentration or emission rate from the previous 2160 quality-assured monitor operating hours. Units
with add-on controls that report NOx mass emissions on a year-round basis under subpart H of this part may use separate ozone season and non-ozone season
data pools to provide substitute data values, as described in § 75.34 (a)(2).
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 101
-------
Table 4. ~ Non-load-based Missing Data Procedure
for Flow Rate CEMS
Trigger conditions
Calculation routines
Monitor data availability
(percent)
95 or more
90 or more, but below 95
80 or more, but below 90
Below 80, or operational bin
indeterminable
Duration (N) of
CEMS outage
(hours)1
N < 24
N> 24
N < 8
N> 8
N> 0
N> 0
Method
Average
The greater of:
Average
90th percentile
Average
The greater of:
Average
95th percentile
Maximum value
Maximum potential flow rate
Lookback
period
2160 hours*
HB/HA
2160 hours*
2160 hours*
HB/HA
2160 hours*
2160 hours*
None
* If operational bins are used, the lookback period is the previous 2,160 quality-assured, monitor operating hours and data at the corresponding operational bin
are used to provide substitute data values. If operational bins are not used, the lookback period is the previous 2,160 quality-assured, monitor operating hours.
For units that report data only for the ozone season, include only quality assured monitor operating hours within the ozone season in the lookback period. Use
data from no earlier than three years prior to the missing data period.
1 During unit operation.
§ 75.34
§ 75.34(a)
§ 75.34(a)(1)
§ 75.34 Units with add-on emission controls.
(a) The owner or operator of an affected unit equipped with add-on S02 and/or NOx
emission controls shall provide substitute data in accordance with paragraphs (a)(1) through
(a)(5) of this section for each hour in which quality-assured data from the outlet S02 and/or
NOx monitoring system(s) are not obtained.
(1) The owner or operator may use the missing data substitution procedures specified in
§§ 75.31 through 75.33 to provide substitute data for any missing data hour(s) in which the
add-on emission controls are documented to be operating properly, as described in the quality
assurance/quality control program for the unit, required by section 1 in appendix B of this part.
To provide the necessary documentation, the owner or operator shall, for each missing data
period, record parametric data to verify the proper operation of the S02 or NOx add-on
emission controls during each hour, as described in paragraph (d) of this section. For any
missing data hour(s) in which such parametric data are either not provided or, if provided, do
not demonstrate that proper operation of the S02 or NOx add-on emission controls has been
maintained, the owner or operator shall substitute (as applicable) the maximum potential NOx
concentration (MPC) as defined in section 2.1.2.1 of appendix A to this part, the maximum
potential NOx emission rate, as defined in § 72.2 of this chapter, or the maximum potential
concentration for S02, as defined by section 2.1.1.1. Alternatively, for S02 or NOx, the owner
or operator may substitute, if available, the hourly S02 or NOx concentration recorded by a
certified inlet monitor, in lieu of the MPC. For each hour in which data from an inlet monitor
are reported, the owner or operator shall use a method of determination code (MODC) of "22"
(see Table 4a in § 75.57). In addition, under § 75.64(c), the designated representative shall
submit as part of each electronic quarterly report, a certification statement, verifying the proper
operation of the S02 or NOx add-on emission control for each missing data period in which the
missing data procedures of §§ 75.31 through 75.33 were applied; or
§ 75.34(a)(2)
(2) This paragraph, (a)(2), applies only to a unit which, as provided in § 75.74 (a) or §
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 102
-------
75.74 (b)(1), reports NOx mass emissions on a year-round basis under a State or Federal NOx
mass emissions reduction program that adopts the emissions monitoring provisions of this part.
If the add-on NOx emission controls installed on such a unit are operated only during the ozone
season or are operated in a more efficient manner during the ozone season than outside the
ozone season, the owner or operator may implement the missing data provisions of paragraph
(a)(1) of this section in the following alternative manner:
(i) The historical, quality-assured NOx emission rate or NOx concentration data may be
separated into two categories, i.e., data recorded inside the ozone season and data recorded
outside the ozone season;
(ii) For the purposes of the missing data lookback periods described under §§75.33 (c)(1),
(c)(2), (c)(3) and (c)(5) of this section, and §75.38(c), the substitute data values shall be taken
from the appropriate database, depending on the date(s) and hour(s) of the missing data period.
That is, if the missing data period occurs inside the ozone season, the ozone season data shall
be used to provide substitute data. If the missing data period occurs outside the ozone season,
data from outside the ozone season shall be used to provide substitute data.
(iii) A missing data period that begins outside the ozone season and continues into the
ozone season shall be considered to be two separate missing data periods, one ending on April
30, hour 23, and the other beginning on May 1, hour 00;
(iv) For missing data hours outside the ozone season, the procedures of § 75.33 may be
applied unconditionally, i.e., documentation of the operational status of the emission controls is
not required in order to apply the standard missing data routines.
§ 75.34(a)(3) (3) For each missing data hour in which the percent monitor data availability for S02 or
NOx, calculated in accordance with §75.32, is less than 90.0 percent and is greater than or equal
to 80.0 percent; and parametric data establishes that the add-on emission controls were
operating properly (i.e., within the range of operating parameters provided in the quality
assurance/quality control program) during the hour, the owner or operator may:
(i) Replace the maximum S02 concentration recorded in the 720 quality-assured monitor
operating hours immediately preceding the missing data period, with the maximum controlled
S02 concentration recorded in the previous 720 quality-assured monitor operating hours; or
(ii) Replace the maximum NOx concentrations) or NOx emission rate(s) from the
appropriate load bin(s) (based on a lookback through the 2,160 quality-assured monitor
operating hours immediately preceding the missing data period), with the maximum controlled
NOx concentrations) or emission rate(s) from the appropriate load bin(s) in the same 2,160
quality-assured monitor operating hour lookback period.
§ 75.34(a)(4) (4) The designated representative may petition the Administrator under § 75.66 for
approval of site-specific parametric monitoring procedure(s) for calculating substitute data for
missing S02 pollutant concentration, NOx pollutant concentration, and NOx emission rate data
in accordance with the requirements of paragraphs (b) and (c) of this section and appendix C to
this part. The owner or operator shall record the data required in appendix C to this part,
pursuant to § 75.58(b).
§ 75.34(a)(5) (5) For each missing data hour in which the percent monitor data availability for S02 or
NOx, calculated in accordance with §75.32, is below 80.0 percent and parametric data establish
that the add-on emission controls were operating properly (i.e., within the range of operating
parameters provided in the quality assurance/quality control program),in lieu of reporting the
maximum potential value, the owner or operator may substitute, as applicable, the greater of:
(i) The maximum expected S02 concentration or 1.25 times the maximum hourly
controlled S02 concentration recorded in the previous 720 quality-assured monitor operating
hours;
(ii) The maximum expected NOx concentration or 1.25 times the maximum hourly
controlled NOx concentration recorded in the previous 2,160 quality-assured monitor operating
hours at the corresponding unit load range or operational bin;
(iii) The maximum controlled hourly NOx emission rate (MCR) or 1.25 times the
maximum hourly controlled NOx emission rate recorded in the previous 2,160 quality-assured
monitor operating hours at the corresponding unit load range or operational bin;
(iv) For the purposes of implementing the missing data options in paragraphs (a)(5)(i)
through (a)(5)(iii) of this section, the maximum expected S02 and NOx concentrations shall be
determined, respectively, according to sections 2.1.1.2 and 2.1.2.2 of appendix A to this part.
The MCR shall be calculated according to the basic procedure described in section 2.1.2.1(b)
of appendix A to this part, except that the words "maximum potential NOx emission rate
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 103
-------
(MER)" shall be replaced with the words "maximum controlled NOx emission rate (MCR)" and
the NOx MEC shall be used instead of the NOx MPC.
§ 75.34(b) (b) For an affected unit equipped with add-on S02 emission controls, the designated
representative may petition the Administrator to approve a parametric monitoring procedure, as
described in appendix C of this part, for calculating substitute S02 concentration data for
missing data periods. The owner or operator shall use the procedures in §§ 75.31, 75.33, or
75.34(a) for providing substitute data for missing S02 concentration data unless a parametric
monitoring procedure has been approved by the Administrator.
(1) Where the monitor data availability is 90.0 percent or more for an outlet S02 pollutant
concentration monitor, the owner or operator may calculate substitute data using an approved
parametric monitoring procedure.
(2) Where the monitor data availability for an outlet S02 pollutant concentration monitor
is less than 90.0 percent, the owner or operator shall calculate substitute data using the
procedures in § 75.34(a) (1) or (2), even if the Administrator has approved a parametric
monitoring procedure.
§ 75.34(c) (c) For an affected unit with NOx add-on emission controls, the designated representative
may petition the Administrator to approve a parametric monitoring procedure, as described in
appendix C of this part, in order to calculate substitute NOx emission rate data for missing data
periods. The owner or operator shall use the procedures in § 75.31 or 75.33 for providing
substitute data for missing NOx emission rate data prior to receiving the Administrator's
approval for a parametric monitoring procedure.
(1) Where monitor data availability for a NOx continuous emission monitoring system is
90.0 percent or more, the owner or operator may calculate substitute data using an approved
parametric monitoring procedure.
(2) Where monitor data availability for a NOx continuous emission monitoring system is
less than 90.0 percent, the owner or operator shall calculate substitute data using the procedure
in § 75.34(a) (1) or (2), even if the Administrator has approved a parametric monitoring
procedure.
§ 75.34(d) (d) In order to implement the options in paragraphs (a)(1), (a)(3) and (a)(5) of this section;
and §§ 75.31(c)(3), 75.38(c), and 75.72(c)(3), the owner or operator shall keep records of
information as described in § 75.58(b)(3) to verify the proper operation of all add-on S02 or
NOx emission controls, during all periods of S02 or NOx emission missing data. If the owner
or operator elects to implement the missing data option in paragraph (a)(2) of this section, the
records in § 75.58 (b)(3) are required to be kept only for the ozone season. The owner or
operator shall document in the quality assurance/quality control (QA/QC) program required by
section 1 of appendix B to this part, the parameters monitored and (as applicable) the ranges
and combinations of parameters that indicate proper operation of the controls. The owner or
operator shall provide the information recorded under § 75.58(b)(3) and the related QA/QC
program information to the Administrator, to the EPA Regional Office, or to the appropriate
State or local agency, upon request.
§ 75.35 § 75.35 Missing data procedures for C02.
§ 75.35(a) (a) The owner or operator of a unit with a C02 continuous emission monitoring system for
determining C02 mass emissions in accordance with § 75.10 (or an 02 monitor that is used to
determine C02 concentration in accordance with appendix F to this part) shall substitute for
missing C02 pollutant concentration data using the procedures of paragraphs (b) and (d) of this
section.
§ 75.35(b) (b) During the first 720 quality assured monitor operating hours following initial
certification at a particular unit or stack location (i.e., the date and time at which quality assured
data begins to be recorded by a CEMS at that location), or (when implementing these
procedures for a previously certified C02 monitoring system) during the 720 quality assured
monitor operating hours preceding implementation of the standard missing data procedures in
paragraph (d) of this section, the owner or operator shall provide substitute C02 pollutant
concentration data or substitute C02 data for heat input determination, as applicable, according
to the procedures in § 75.31(b).
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 104
-------
§ 75.35(c) (c) [Reserved]
§ 75.35(d) (d) Upon completion of 720 quality assured monitor operating hours using the initial
missing data procedures of § 75.31(b), the owner or operator shall provide substitute data for
C02 concentration or substitute C02 data for heat input determination, as applicable, in
accordance with the procedures in § 75.33(b) except that the term "C02 concentration" shall
apply rather than "S02 concentration," the term "C02 pollutant concentration monitor" or "C02
diluent monitor" shall apply rather than "S02 pollutant concentration monitor," and the term
"maximum potential C02 concentration, as defined in section 2.1.3.1 of appendix A to this
part" shall apply, rather than "maximum potential S02 concentration."
§ 75.36 § 75.36 Missing data procedures for heat input rate determinations.
§ 75.36(a) (a) When hourly heat input rate is determined using a flow monitoring system and a
diluent gas (02 or C02) monitor, substitute data must be provided to calculate the heat input
whenever quality assured data are unavailable from the flow monitor, the diluent gas monitor,
or both. When flow rate data are unavailable, substitute flow rate data for the heat input rate
calculation shall be provided according to §75.31 or §75.33, as applicable. When diluent gas
data are unavailable, the owner or operator shall provide substitute 02 or C02 data for the heat
input rate calculations in accordance with paragraphs (b) and (d) of this section.
§ 75.36(b) (b) During the first 720 quality assured monitor operating hours following initial
certification at a particular unit or stack location (i.e., the date and time at which quality assured
data begins to be recorded by a CEMS at that location), or (when implementing these
procedures for a previously certified C02 or 02 monitor) during the 720 quality assured
monitor operating hours preceding implementation of the standard missing data procedures in
paragraph (d) of this section, the owner or operator shall provide substitute C02 or 02 data, as
applicable, for the calculation of heat input (under section 5.2 of appendix F to this part)
according to § 75.31(b).
§ 75.36(c) (c) [Reserved]
§ 75.36(d) (d) Upon completion of 720 quality-assured monitor operating hours using the initial
missing data procedures of § 75.31(b), the owner or operator shall provide substitute data for
C02 or 02 concentration to calculate heat input rate, as follows. Substitute C02 data for heat
input rate determinations shall be provided according to § 75.35(d). Substitute 02 data for the
heat input rate determinations shall be provided in accordance with the procedures in
§ 75.33(b), except that the term "02 concentration" shall apply rather than the term "S02
concentration" and the term "02 diluent monitor" shall apply rather than the term "S02
pollutant concentration monitor." In addition, the term "substitute the lesser of' shall apply
rather than "substitute the greater of;" the terms "minimum hourly 02 concentration" and
"minimum potential 02 concentration, as determined under section 2.1.3.2 of appendix A to
this part" shall apply rather than, respectively, the terms "maximum hourly S02 concentration"
and "maximum potential S02 concentration, as determined under section 2.1.1.1 of appendix A
to this part;" and the terms " 10th percentile" and "5th percentile" shall apply rather than,
respectively, the terms "90th percentile" and "95th percentile" (see Table 1 of § 75.33).
§ 75.37 § 75.37 Missing data procedures for moisture.
§ 75.37(a) (a) The owner or operator of a unit with a continuous moisture monitoring system shall
substitute for missing moisture data using the procedures of this section.
§ 75.37(b) (b) Where no prior quality assured moisture data exist, substitute the minimum potential
moisture percentage, from section 2.1.5 of appendix A to this part, except when Equation 19-3,
19-4 or 19-8 in Method 19 in appendix A to part 60 of this chapter is used to determine NOx
emission rate. If Equation 19-3, 19-4 or 19-8 in Method 19 in appendix A to part 60 of this
chapter is used to determine NOx emission rate, substitute the maximum potential moisture
percentage, as specified in section 2.1.6 of appendix A to this part.
§ 75.37(c) (c) During the first 720 quality assured monitor operating hours following initial
certification at a particular unit or stack location (i.e., the date and time at which quality assured
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 105
-------
data begins to be recorded by a moisture monitoring system at that location), the owner or
operator shall provide substitute data for moisture according to § 75.31(b).
§ 75.37(d) (d) Upon completion of the first 720 quality-assured monitor operating hours following
initial certification, the owner or operator shall provide substitute data for moisture as follows:
(1) Unless Equation 19-3, 19-4 or 19-8 in Method 19 in appendix A to part 60 of this
chapter is used to determine NOx emission rate, follow the missing data procedures in
§ 75.33(b), except that the term, "moisture percentage" shall apply rather than "S02
concentration;" the term "moisture monitoring system" shall apply rather than the term "S02
pollutant concentration monitor;" the term "substitute the lesser of' shall apply rather than
"substitute the greater of;" the terms "minimum hourly moisture percentage" and "minimum
potential moisture percentage, as determined under section 2.1.5 of appendix A to this part"
shall apply rather than, respectively, the terms "maximum hourly S02 concentration" and
"maximum potential S02 concentration, as determined under section 2.1.1.1 of appendix A to
this part;" and the terms " 10th percentile" and "5th percentile" shall apply rather than,
respectively, the terms "90th percentile" and "95th percentile" (see Table 1 of § 75.33). (2)
When Equation 19-3, 19-4 or 19-8 in Method 19 in appendix A to part 60 of this chapter is
used to determine NOx emission rate:
(i) Provided that none of the following equations is used to determine S02 emissions, C02
emissions or heat input: Equation F-2, F-14b, F-16, F-17, or F-18 in appendix F to this part, or
Equation 19-5 or 19-9 in Method 19 in appendix A to part 60 of this chapter, use the missing
data procedures in § 75.33(b), except that the term "moisture percentage" shall apply rather
than "S02 concentration," the term "moisture monitoring system" shall apply rather than "S02
pollutant concentration monitor," and the term "maximum potential moisture percentage, as
defined in section 2.1.6 of appendix A to this part" shall apply, rather than "maximum potential
S02 concentration;" or
(ii) If any of the following equations is used to determine S02 emissions, C02 emissions or
heat input: Equation F-2, F-14b, F-16, F-17, or F-18 in appendix F to this part, or Equation 19-
5 or 19-9 in Method 19 in appendix A to part 60 of this chapter, the owner or operator shall
petition the Administrator under § 75.66(1) for permission to use an alternative moisture
missing data procedure.
§ 75.38 § 75.38 Standard missing data procedures for Hg CEMS.
§ 75.38(a) (a) Once 720 quality assured monitor operating hours of Hg concentration data have been
obtained following initial certification, the owner or operator shall provide substitute data for
Hg concentration in accordance with the procedures in §§ 75.33(b)(1) through (b)(4), except
that the term "Hg concentration" shall apply rather than "S02 concentration," the term "Hg
concentration monitoring system" shall apply rather than "S02 pollutant concentration
monitor," the term "maximum potential Hg concentration, as defined in section 2.1.7 of
appendix A to this part" shall apply, rather than "maximum potential S02 concentration", and
the percent monitor data availability trigger conditions prescribed for Hg in Table 1 of §75.33
shall apply rather than the trigger conditions prescribed for S02.
§ 75.38(b) (b) For a unit equipped with a flue gas desulfurization (FGD) system that significantly
reduces the concentration of Hg emitted to the atmosphere (including circulating fluidized bed
units that use limestone injection), or for a unit equipped with add-on Hg emission controls
(e.g., carbon injection), the standard missing data procedures in paragraph (a) of this section
may only be used for hours in which the S02 or Hg emission controls are documented to be
operating properly, as described in § 75.58(b)(3). For any hour(s) in the missing data period for
which this documentation is unavailable, the owner or operator shall report, as applicable, the
maximum potential Hg concentration, as defined in section 2.1.7 of appendix A to this part. In
addition, under § 75.64(c), the designated representative shall submit as part of each electronic
quarterly report, a certification statement, verifying the proper operation of the S02 or Hg
emission controls for each missing data period in which the procedures in paragraph (a) of this
section are applied.
§ 75.38(c) (c) For units with FGD systems or add-on Hg controls, when the percent monitor data
availability is less than 80.0 percent and is greater than or equal to 70.0 percent, and a missing
data period occurs, consistent with §75.34(a)(3), for each missing data hour in which the FGD
or Hg emission controls are documented to be operating properly, the owner or operator may
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 106
-------
report the maximum controlled Hg concentration in the previous 720 quality-assured monitor
operating hours. In addition, when the percent monitor data availability is less than 70.0
percent and a missing data period occurs, consistent with §75.34(a)(5), for each missing data
hour in which the FGD or Hg emission controls are documented to be operating properly, the
owner or operator may report the greater of the maximum expected Hg concentration (MEC) or
1.25 times the maximum controlled Hg concentration recorded in the previous 720 quality-
assured monitor operating hours. The MEC shall be determined in accordance with section
2.1.7.1 of appendix A to this part.
§ 75.39 § 75.39 Missing data procedures for sorbent trap monitoring systems.
§ 75.39(a) (a) If a primary sorbent trap monitoring system has not been certified by the applicable
compliance date specified under a State or Federal Hg mass emission reduction program that
adopts the requirements of subpart I of this part, and if quality-assured Hg concentration data
from a certified backup Hg monitoring system, reference method, or approved alternative
monitoring system are unavailable, the owner or operator shall report the maximum potential
Hg concentration, as defined in section 2.1.7 of appendix A to this part, until the primary
system is certified.
§ 75.39(b) (b) For a certified sorbent trap system, a missing data period will occur in the following
circumstances, unless quality-assured Hg concentration data from a certified backup Hg CEMS,
sorbent trap system, reference method, or approved alternative monitoring system are available:
(1) A gas sample is not extracted from the stack during unit operation (e.g., during a
monitoring system malfunction or when the system undergoes maintenance); or
(2) The results of the Hg analysis for the paired sorbent traps are missing or invalid (as
determined using the quality assurance procedures in appendix K to this part). The missing
data period begins with the hour in which the paired sorbent traps for which the Hg analysis is
missing or invalid were put into service. The missing data period ends at the first hour in which
valid Hg concentration data are obtained with another pair of sorbent traps (i.e., the hour at
which this pair of traps was placed in service), or with a certified backup Hg CEMS, reference
method, or approved alternative monitoring system.
§ 75.39(c) (c) Initial missing data procedures. Use the missing data procedures in §75.31(b) until
720 hours of quality-assured Hg concentration data have been collected with the sorbent trap
monitoring system(s), following initial certification.
§ 75.39(d) (d) Standard missing data procedures. Once 720 quality-assured hours of data have been
obtained with the sorbent trap system(s), begin reporting the percent monitor data availability
in accordance with § 75.32 and switch from the initial missing data procedures in paragraph (c)
of this section to the standard missing data procedures in §75.38.
§ 75.39(e) (e) Notwithstanding the requirements of paragraphs (c) and (d) of this section, if the unit
has add-on Hg emission controls or is equipped with a flue gas desulfurization system that
significantly reduces Hg emissions, the owner or operator shall report the maximum potential
Hg concentration, as defined in section 2.1.7 of appendix A to this part, for any hour(s) in the
missing data period for which proper operation of the Hg emission controls or FGD system is
not documented according to § 75.58(b)(3).
§75.39(f) (f) In cases where the owner or operator elects to use a primary Hg CEMS and a certified
redundant (or non-redundant) backup sorbent trap monitoring system (or vice-versa), when
both the primary and backup monitoring systems are out-of-service and quality-assured Hg
concentration data from a temporary like-kind replacement analyzer, reference method, or
approved alternative monitoring system are unavailable, the previous 720 quality-assured
monitor operating hours reported in the electronic quarterly report under §75.64 shall be used
for the required missing data lookback, irrespective of whether these data were recorded by the
Hg CEMS, the sorbent trap system, a temporary like-kind replacement analyzer, a reference
method, or an approved alternative monitoring system.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 107
-------
Subpart E — Alternative Monitoring Systems
§ 75.40
§ 75.40(a)
§ 75.40(b)
§ 75.41
§ 75.41(a)
§ 75.41(a)(1)
§ 75.41(a)(2)
§ 75.41(a)(3)
§ 75.41(a)(4)
§ 75.41(a)(5)
§ 75.41(a)(6)
§ 75.40 General demonstration requirements.
(a) The owner or operator of an affected unit, or the owner or operator of an affected unit
and representing a class of affected units which meet the criteria specified in § 75.47, required
to install a continuous emission monitoring system may apply to the Administrator for approval
of an alternative monitoring system (or system component) to determine average hourly
emission data for S02, NOx, and/or volumetric flow by demonstrating that the alternative
monitoring system has the same or better precision, reliability, accessibility, and timeliness as
that provided by the continuous emission monitoring system.
(b) The requirements of this subpart shall be met by the alternative monitoring system
when compared to a contemporaneously operating, fully certified continuous emission
monitoring system or a contemporaneously operating reference method, where the appropriate
reference methods are listed in § 75.22.
§ 75.41 Precision criteria.
(~) Data collection and analysis. To demonstrate precision equal to or better than the
continuous emission monitoring system, the owner or operator shall conduct an F-test, a
correlation analysis, and a t-test for bias as described in this section. The t-test shall be
performed only on sample data at the normal operating level and primary fuel supply, whereas
the F-test and the correlation analysis must be performed on each of the data sets required
under paragraphs (a)(4) and (a)(5) of this section. The owner or operator shall collect and
analyze data according to the following requirements:
(1) Data from the alternative monitoring system and the continuous emission monitoring
system shall be collected and paired in a manner that ensures each pair of values applies to
hourly average emissions during the same hour.
(2) An alternative monitoring system that directly measures emissions shall have probes or
other measuring devices in locations that are in proximity to the continuous emission
monitoring system and shall provide data on the same parameters as those measured by the
continuous emission monitoring system. Data from the alternative monitoring system shall
meet the statistical tests for precision in paragraph (c) of this section and the t-test for bias in
appendix A of this part.
(3) An alternative monitoring system that indirectly quantifies emission values by
measuring inputs, operating characteristics, or outputs and then applying a regression or
another quantitative technique to estimate emissions, shall meet the statistical tests for precision
in paragraph (c) of this section and the t-test for bias in appendix A of this part.
(4) For flow monitor alternatives, the alternative monitoring system must provide sample
data for each of three different exhaust gas velocities while the unit or units, if more than one
unit exhausts into the stack or duct, is burning its primary fuel at:
(i) A frequently used low operating level, selected within the range between the minimum
safe and stable operating level and 50 percent of the maximum operating level,
(ii) A frequently used high operating level, selected within the range between 80 percent of
the maximum operating level and the maximum operating level, and
(iii) The normal operating level, or an evenly spaced intermediary level between low and
high levels used if the normal operating level is within a specified range (10.0 percent of the
maximum operating level), of either paragraphs (a)(4) (i) or (ii) of this section.
(5) For pollutant concentration monitor alternatives, the alternative monitoring system shall
provide sample data for the primary fuel supply and for all alternative fuel supplies that have
significantly different sulfur content.
(~) For the normal unit operating level and primary fuel supply, paired hourly sample data
shall be provided for at least 90.0 percent of the hours during 720 unit operating hours. For
each of the remaining two operating levels for flow monitor alternatives, and for each
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 108
-------
§ 75.41(a)(7)
§ 75.41(a)(8)
§ 75.41(a)(9)
alternative fuel supply for pollutant concentration monitor alternatives, paired hourly sample
data shall be provided for at least 24 successive unit operating hours.
(7) The owner or operator shall not use missing data substitution procedures to provide
sample data.
(8) If the collected data meet the requirements of the F-test, the correlation test, and the
t-test at one or more, but not all, of the operating levels or fuel supplies, the owner or operator
may elect to continue collecting the paired data for up to 1,440 additional operating hours and
repeat the statistical tests using the data for the entire 30- to 90-day period.
(9) The owner or operator shall provide two separate time series data plots for the data at
each operating level or fuel supply described in paragraphs (a)(4) and (a)(5) of this section.
Each data plot shall have a horizontal axis that represents the clock hour and calendar date of
the readings and shall contain a separate data point for every hour for the duration of the
performance evaluation. The data plots shall show the following:
(i) Percentage difference versus time where the vertical axis represents the percentage
difference between each paired hourly reading generated by the continuous emission
monitoring system (or reference method) and the alternative emission monitoring system as
calculated using the following equation:
Ae = ——— x 100 %
(Eq. 10)where,
Ae =Percentage difference between the readings generated by the alternative monitoring
system and the continuous emission monitoring system.
ep =Measured value from the alternative monitoring system.
ev =Measured value from the continuous emission monitoring system.
(ii) Alternative monitoring system readings and continuous emission monitoring system (or
reference method) readings versus time where the vertical axis represents hourly pollutant
concentrations or volumetric flow, as appropriate, and two different symbols are used to
represent the readings from the alternative monitoring system and the continuous emission
monitoring system (or reference method), respectively.
§ 75.41(b) (b) Data screening and calculation adjustments. In preparation for conducting the
statistical tests described in paragraph (c) of this section, the owner or operator may screen the
data for lognormality and time dependency autocorrelation. If either is detected, the owner or
operator shall make the following calculation adjustments:
§ 75.41(b)(1) (1) Lognormality. The owner or operator shall conduct any screening and adjustment for
lognormality according to the following procedures.
§ 75.4 l(b)(l)(i) (i) Apply the log transformation to each measured value of either the certified continuous
emissions monitoring system or certified flow monitor, using the following equation:
lv = In ev
(Eq. 11)
where,
ev =Hourly value generated by the certified continuous emissions monitoring system or
certified flow monitoring system
lv =Hourly lognormalized data values for the certified monitoring system,
and to each measured value, eP, of the proposed alternative monitoring system, using the
following equation to obtain the lognormalized data values,
1P<
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 109
-------
lp = In eP
§ 75.41(b)(l)(ii)
§ 75.41(b)(l)(iii)
§ 75.41(b)(l)(iv)
§ 75.41(b)(l)(v)
§ 75.41(b)(2)
§ 75.41(b)(2)(i)
(Eq. 12)
where,
eP =Hourly value generated by the proposed alternative monitoring system.
1P =Hourly lognormalized data values for the proposed alternative monitoring system.
(ii) Separately test each set of transformed data, lv and for normality, using the
following:
(A) Shapiro-Wilk test;
(B) Histogram of the transformed data; and
(C) Quantile-Quantile plot of the transformed data.
(iii) The transformed data in a data set will be considered normally distributed if all of the
following conditions are satisfied:
(A) The Shapiro-Wilk test statistic, W, is greater than or equal to 0.75 or is not statistically
significant at a=0.05.
(B) The histogram of the data is unimodal and symmetric.
(C) The Quantile-Quantile plot is a diagonal straight line.
(iv) If both of the transformed data sets, lv and meet the conditions for normality,
specified in paragraphs (b)(l)(iii) (A) through (C) of this section, the owner or operator may
use the transformed data, lv and in place of the original measured data values in the statistical
tests for alternative monitoring systems as described in paragraph (c) of this section and in
appendix A of this part.
(v) If the transformed data are used in the statistical tests in paragraph (c) of this section
and in appendix A of this part, the owner or operator shall provide the following:
(A) Copy of the original measured values and the corresponding transformed data in
printed and electronic format.
(B) Printed copy of the test results and plots described in paragraphs (b)(1) (i) through (iii)
of this section.
(2) Time dependency (autocorrelation). The screening and adjustment for time
dependency are conducted according to the following procedures:
(i) Calculate the degree of autocorrelation of the data on their LAG1 values, where the
degree of autocorrelation is represented by the Pearson autocorrelation coefficient, p, computed
from an AR(1) autoregression model, such that:
COV(xl,x:)
Sx'Sx"
(Eq. 13)
where,
x,'
Xi"
The original data value at hour i.
The LAG1 data value at hour i.
COV(x1', Xi") = The autocovariance of x,' and defined by
xr~x')( xr~x~)
COV(xr, xt) = —
(n-1)
(Eq. 14)
where,
n =The total number of observations in which both the original value, xand the lagged
value, Xi", are available in the data set.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 110
-------
S'vl =The standard deviation of the original data values, x,' defined by
sx
1
t \2
Xi'-x')
n-1
(Eq. 15)
where,
SX1" =The standard deviation of the LAGldata values, defined by
sx
1
xr-x f
i=l
n-1
(Eq. 16)where,
x' =The mean of the original data values, defined by
n ,
x' = ^—
n
(Eq. 17)
where,
X" =The mean of the LAG1 data values, x". defined by
n
_ 2 Xf
x" = ^—
n
(Eq. 18)
where,
§ 75.4 l(b)(2)(ii) (ii) The data in a data set will be considered autocorrelated if the autocorrelation
coefficient, p, is significant at the 5 percent significance level. To determine if this condition is
satisfied, calculate Z using the following equation:
Z = 0.5
In
^1 +
\l~Pj
yfn-3
(Eq. 19)
If Z > 1.96, then the autocorrelation coefficient, p, is significant at the 5 percent significance
level (a = 0.05).
§ 75.41 (b)(2)(iii)
(iii) If the data in a data set satisfy the conditions for autocorrelation, specified in
paragraph (b)(2)(ii) of this section, the variance of the data, S2, may be adjusted using the
following equation:
S2adj =vif x s2
(Eq. 20)
where,
S2 =The original, unadjusted variance of the data set.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 111
-------
VIF =The variance inflation factor, defined by
VIF =
1 —
2 p
2p(l-p")
(n-\)(\-p) n(n-\)(\-pf
(Eq. 21)S
The autocorrelation-adjusted variance for the data set.
§ 75.41(b)(2)(iv)
(iv) The procedures described in paragraphs (b)(2)(i)-(iii) of this section may be separately
applied to the following data sets in order to derive distinct autocorrelation coefficients and
variance inflation factors for each data set:
(A) The set of measured hourly values, ev, generated by the certified continuous emissions
monitoring system or certified flow monitoring system.
(B) The set of hourly values, ep, generated by the proposed alternative monitoring system,
(C) The set of hourly differences, ev-eP, between the hourly values, ev, generated by the
certified continuous emissions monitoring system or certified flow monitoring system and the
hourly values, ep, generated by the proposed alternative monitoring system.
§ 75.41(b)(2)(v)
(v) For any data set, listed in paragraph (b)(2)(iv) of this section, that satisfies the
conditions for autocorrelation specified in paragraph (b)(2)(ii) of this section, the owner or
operator may adjust the variance of that data set, using equation 20 of this section.
(A) The adjusted variance may be used in place of the corresponding original variance, as
calculated using equation 23 of this section, in the F-test (Equation 24) of this section.
(B) In place of the standard error of the mean,
Sji_
yfn
in the bias test Equation A-9 of Appendix A of this part the following adjusted standard error of
the mean may be used:
rv
adj
'^1 + p^ f 2p(l-p")
}~P.
\
n(\-pf
:JviF
rv
(Eq. 22)
where,
$d The autocorrelation - adjusted
-Jn ) standard error of the mean.
§ 75.41(b)(2)(vi)
(vi) For each data set in which a variance adjustment is used, the owner or operator shall
provide the following:
(A) All values in the data set in printed and electronic format.
(B) Values of the autocorrelation coefficient, its level of significance, the variance inflation
factor, and the unadjusted original and adjusted values found in equations 20 and 22 of this
section.
(C) Equation and related statistics of the AR(1) autoregression model of the data set.
(D) Printed documentation of the intermediate calculations used to derive the
autocorrelation coefficient and the Variance Inflation Factor.
§ 75.41(c)
(c) Statistical Tests. The owner or operator shall perform the F-test and correlation
analysis as described in this paragraph and the t-test for bias described in appendix A of this
part to demonstrate the precision of the alternative monitoring system.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 112
-------
§ 75.41(c)(1) (1) F-test. The owner or operator shall conduct the F-test according to the following
procedures.
(i) Calculate the variance of the certified continuous emission monitoring system or
certified flow monitor as applicable, Sv2, and the proposed method, Sp2, using the following
equation.
(@i ~ @m )
s
2 _ i=l
n-1
(Eq. 23)
where,
c, =Measured values of either the certified continuous emission monitoring system or
certified flow monitor, as applicable, or proposed method.
em =Mean of either the certified continuous emission monitoring system or certified flow
monitor, as applicable, or proposed method values,
n =Total number of paired samples.
(ii) Determine if the variance of the proposed method is significantly different from that of
the certified continuous emission monitoring system or certified flow monitor, as applicable, by
calculating the F-value using the following equation.
F
St
_ ° V
Sv
(Eq. 24)
Compare the experimental F-value with the critical value of F at the 95-percent confidence
level with n-1 degrees of freedom. The critical value is obtained from a table for F-distribution.
If the calculated F-value is greater than the critical value, the proposed method is unacceptable.
§ 75.41(c)(2) (2) Correlation analysis. The owner or operator shall conduct the correlation analysis
according to the following procedures.
§ 75.41(c)(2)(i) (i) Plot each of the paired emissions readings as a separate point on a graph where the
vertical axis represents the value (pollutant concentration or volumetric flow, as appropriate)
generated by the alternative monitoring system and the horizontal axis represents the value
(pollutant concentration or volumetric flow, as appropriate) generated by the continuous
emission monitoring system (or reference method). On the graph, draw a horizontal line
representing the mean value, ep, for the alternative monitoring system and a vertical line
representing the mean value, ev, for the continuous emission monitoring system where,
— _Hep
eP
n
(Eq. 25)
— _Hev
ev
n
(Eq. 26)
where,
ep =Hourly value generated by the alternative monitoring system.
ev =Hourly value generated by the continuous emission monitoring system,
n = Total number of hours for which data were generated for the tests.
A separate graph shall be produced for the data generated at each of the operating levels or fuel
supplies described in paragraphs (a)(4) and (a)(5) of this section.
§ 75.4 l(c)(2)(ii) (ii) Use the following equation to calculate the coefficient of correlation, r, between the
emissions data from the alternative monitoring system and the continuous emission monitoring
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 113
-------
system using all hourly data for which paired values were available from both monitoring
systems.
2V,
Hepev ~
(Eq. 27)
§ 75.4 l(c)(2)(iii) (iii) If the calculated r-value is less than 0.8, the proposed method is unacceptable.
§ 75.42 § 75.42 Reliability criteria.
To demonstrate reliability equal to or better than the continuous emission monitoring
system, the owner or operator shall demonstrate that the alternative monitoring system is
capable of providing valid 1-hr averages for 95.0 percent or more of unit operating hours over a
1-yr period and that the system meets the applicable requirements of appendix B of this part.
§ 75.43 § 75.43 Accessibility criteria.
To demonstrate accessibility equal to or better than the continuous emission monitoring
system, the owner or operator shall provide reports and onsite records of emission data to
demonstrate that the alternative monitoring system provides data meeting the requirements of
subparts F and G of this part.
§ 75.44 § 75.44 Timeliness criteria.
To demonstrate timeliness equal to or better than the continuous emission monitoring
system, the owner or operator shall demonstrate that the alternative monitoring system can meet
the requirements of subparts F and G of this part; can provide a continuous, quality-assured,
permanent record of certified emissions data on an hourly basis; and can issue a record of data
for the previous day within 24 hours.
§ 75.45 § 75.45 Daily quality assurance criteria.
The owner or operator shall either demonstrate that daily tests equivalent to those specified
in appendix B of this part can be performed on the alternative monitoring system or
demonstrate and document that such tests are unnecessary for providing quality-assured data.
§ 75.46 § 75.46 Missing data substitution criteria.
The owner or operator shall demonstrate that all missing data can be accounted for in a
manner consistent with the applicable missing data procedures in subpart D of this part.
§ 75.47 § 75.47 Criteria for a class of affected units.
§ 75.47(a) (a) The owner or operator of an affected unit may represent a class of affected units for the
purpose of applying to the Administrator for a class-approved alternative monitoring system.
§ 75.47(b) (b) The owner or operator of an affected unit representing a class of affected units shall
provide the following information:
(1) A description of the affected unit and how it appropriately represents the class of
affected units;
(2) A description of the class of affected units, including data describing all the affected
units which will comprise the class; and
(3) A demonstration that the magnitude of emissions of all units which will comprise the
class of affected units are de minimis.
§ 75.47(c) (c) If the Administrator determines that the emissions from all affected units which will
comprise the class of units are de minimis, then the Administrator shall publish notice in the
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 114
-------
Federal Register, providing a 30-day period for public comment, prior to granting a
class-approved alternative monitoring system.
§ 75.48 § 75.48 Petition for an alternative monitoring system.
§ 75.48(a) (a) The designated representative shall submit the following information in the application
for certification or recertification of an alternative monitoring system.
§ 75.48(a)(1) (1) Source identification information.
§ 75.48(a)(2) (2) A description of the alternative monitoring system.
§ 75.48(a)(3) (3) Data, calculations, and results of the statistical tests, specified in § 75.41(c) of this part,
including:
(i) Date and hour.
(ii) Hourly test data for the alternative monitoring system at each required operating level
and fuel type. The fuel type, operating level and gross unit load shall be recorded.
(iii) Hourly test data for the continuous emissions monitoring system at each required
operating level and fuel type. The fuel type, operating level and gross unit load shall be
recorded.
(iv) Arithmetic mean of the alternative monitoring system measurement values, as
specified in Equation 25 in § 75.41(c) of this part, of the continuous emission monitoring
system values, as specified onEquation 26 in§75.41(c) of this part, and of their differences.
(v) Standard deviation of the difference, as specified in equation A-8 in appendix A of this
part.
(vi) Confidence coefficient, as specified in equation A-9 in appendix A of this part.
(vii) The bias test results as specified in § 7.6.4 in appendix A of this part.
(viii) Variance of the measured values for the alternative monitoring system and of the
measured values for the continuous emission monitoring system, as specified in Equation 23 in
§ 75.41(c) of this part.
(ix) F-statistic, as specified in Equation 24 in § 75.41(c) of this part.
(x) Critical value of F at the 95-percent confidence level with n-1 degrees of freedom.
(xi) Coefficient of correlation, r, as specified in Equation 27 in § 75.41(c) of this part.
§ 75.48(a)(4) (4) Data plots, specified in §§ 75.41(a)(9) and 75.41(c)(2)(i) of this part.
§ 75.48(a)(5) (5) Results of monitor reliability analysis.
§ 75.48(a)(6) (6) Results of monitor accessibility analysis.
§ 75.48(a)(7) (7) Results of monitor timeliness analysis.
§ 75.48(a)(8) (8) A detailed description of the process used to collect data, including location and
method of ensuring an accurate assessment of operating hourly conditions on a real-time basis.
§ 75.48(a)(9) (9) A detailed description of the operation, maintenance, and quality assurance procedures
for the alternative monitoring system as required in appendix B of this part.
§ 75.48(a)(10) (10) A description of methods used to calculate heat input or diluent gas concentration, if
applicable.
§ 75.48(a)(l 1) (11) Results of tests and measurements (including the results of all reference method field
test sheets, charts, laboratory analyses, example calculations, or other data as appropriate)
necessary to substantiate that the alternative monitoring system is equivalent in performance to
an appropriate, certified operating continuous emission monitoring system.
§ 75.48(b) (b) [Reserved]
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 115
-------
Subpart F — Recordkeeping Requirements
§ 75.50-§ 75.52 § 75.50-75.52 [Reserved]
§ 75.53 § 75.53 Monitoring plan.
§ 75.53(a) (a) General provisions.
(1) The provisions of paragraphs (e) and (f) of this section shall remain in effect through
December 31, 2008. The owner or operator shall meet the requirements of paragraphs (a), (b),
(e), and (f) of this section through December 31, 2008, except as otherwise provided in
paragraph (g) of this section. On and after January 1, 2009, the owner or operator shall meet
the requirements of paragraphs (a), (b), (g), and (h) of this section only. In addition, the
provisions in paragraphs (g) and (h) of this section that support a regulatory option provided in
another section of this part must be followed if the regulatory option is used prior to January 1,
2009.
(2) The owner or operator of an affected unit shall prepare and maintain a monitoring
plan. Except as provided in paragraphs (f) or (h) of this section (as applicable), a monitoring
plan shall contain sufficient information on the continuous emission or opacity monitoring
systems, excepted methodology under § 75.19, or excepted monitoring systems under appendix
D or E to this part and the use of data derived from these systems to demonstrate that all unit
S02 emissions, NOx emissions, C02 emissions, and opacity are monitored and reported.
§ 75.53(b) (b) Whenever the owner or operator makes a replacement, modification, or change in the
certified CEMS, continuous opacity monitoring system, excepted methodology under § 75.19,
excepted monitoring system under appendix D or E to this part, or alternative monitoring
system under subpart E of this part, including a change in the automated data acquisition and
handling system or in the flue gas handling system, that affects information reported in the
monitoring plan (e.g., a change to a serial number for a component of a monitoring system),
then the owner or operator shall update the monitoring plan, by the applicable deadline
specified in § 75.62 or elsewhere in this part.
§ 75.53(c) (c) [Reserved]
§ 75.53(d) (d) [Reserved]
§ 75.53(e) (e) Contents of the monitoring plan. Each monitoring plan shall contain the information in
paragraph (e)(1) of this section in electronic format and the information in paragraph (e)(2) of
this section in hardcopy format. Electronic storage of all monitoring plan information,
including the hardcopy portions, is permissible provided that a paper copy of the information
can be furnished upon request for audit purposes.
§ 75.53(e)(1) (1) Electronic.
§ 75.53(e)(l)(i) (i) ORISPL numbers developed by the Department of Energy and used in the National
Allowance Data Base (or equivalent facility ID number assigned by EPA, if the facility does
not have an ORISPL number), for all affected units involved in the monitoring plan, with the
following information for each unit:
(A) Short name;
(B) Classification of the unit as one of the following: Phase I (including substitution or
compensating units), Phase II, new, or nonaffected;
(C) Type of boiler (or boilers for a group of units using a common stack);
(D) Type of fuel(s) fired by boiler, fuel type start and end dates,
primary/secondary/emergency/startup fuel indicator, and, if more than one fuel, the fuel
classification of the boiler;
(E) Type(s) of emission controls for S02, NOx, Hg, and particulates installed or to be
installed, including specifications of whether such controls are pre-combustion, post-
combustion, or integral to the combustion process; control equipment code, installation date,
and optimization date; control equipment retirement date (if applicable); primary/secondary
controls indicator; and an indicator for whether the controls are an original installation;
(F) Maximum hourly heat input capacity;
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 116
-------
§ 75.53(e)(l)(ii)
§ 75.53(e)(l)(iii)
§ 75.53(e)(l)(iv)
§ 75.53(e)(l)(v)
§ 75.53(e)(l)(vi)
(G) Date of first commercial operation;
(H) Unit retirement date (if applicable);
(I) Maximum hourly gross load (in MW, rounded to the nearest MW, or steam load in
1000 lb/hr, rounded to the nearest 100 lb/hr);
(J) Identification of all units using a common stack;
(K) Activation date for the stack/pipe;
(L) Retirement date of the stack/pipe (if applicable); and
(M) Indicator of whether the stack is a bypass stack.
(ii) For each unit and parameter required to be monitored, identification of monitoring
methodology information, consisting of monitoring methodology, type of fuel associated with
the methodology, primary/secondary methodology indicator, missing data approach for the
methodology, methodology start date, and methodology end date (if applicable).
(iii) The following information:
(A) Program(s) for which the EDR is submitted;
(B) Unit classification;
(C) Reporting frequency;
(D) Program participation date;
(E) State regulation code (if applicable); and
(F) State or local regulatory agency code.
(iv) Identification and description of each monitoring component (including each monitor
and its identifiable components, such as analyzer and/or probe) in the CEMS (e.g., S02
pollutant concentration monitor, flow monitor, moisture monitor; NOx pollutant concentration
monitor, Hg monitor, and diluent gas monitor), the sorbent trap monitoring system, the
continuous opacity monitoring system, or the excepted monitoring system (e.g., fuel flowmeter,
data acquisition and handling system), including:
(A) Manufacturer, model number and serial number;
(B) Component/system identification code assigned by the utility to each identifiable
monitoring component (such as the analyzer and/or probe). Each code shall use a three-digit
format, unique to each monitoring component and unique to each monitoring system;
(C) Designation of the component type and method of sample acquisition or operation,
(e.g., in situ pollutant concentration monitor or thermal flow monitor);
(D) Designation of the system as a primary, redundant backup, non-redundant backup, data
backup, or reference method backup system, as provided in § 75.10(e);
(E) First and last dates the system reported data;
(F) Status of the monitoring component; and
(G) Parameter monitored.
(v) Identification and description of all major hardware and software components of the
automated data acquisition and handling system, including:
(A) Hardware components that perform emission calculations or store data for quarterly
reporting purposes (provide the manufacturer and model number); and
(B) Software components (provide the identification of the provider and model/version
number).
(vi) Explicit formulas for each measured emission parameter, using component/system
identification codes for the primary system used to measure the parameter that links CEMS or
excepted monitoring system observations with reported concentrations, mass emissions, or
emission rates, according to the conversions listed in appendix D or E to this part. Formulas
for backup monitoring systems are required only if different formulas for the same parameter
are used for the primary and backup monitoring systems (e.g., if the primary system measures
pollutant concentration on a different moisture basis from the backup system). The formulas
must contain all constants and factors required to derive mass emissions or emission rates from
component/system code observations and an indication of whether the formula is being added,
corrected, deleted, or is unchanged. Each emissions formula is identified with a unique three
digit code. The owner or operator of a low mass emissions unit for which the owner or
operator is using the optional low mass emissions excepted methodology in § 75.19(c) is not
required to report such formulas.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 117
-------
§ 75.53(e)(l)(vii)
(vii) Inside cross-sectional area (ft2) at flue exit (for all units) and at flow monitoring
location (for units with flow monitors, only).
§ 75.53(e)(l)(viii) (viii) Stack exit height (ft) above ground level and ground level elevation above sea level.
§ 75.53(e)(l)(ix) (ix) Monitoring location identification, facility identification code as assigned by the
Administrator for use under the Acid Rain Program or this part, and the following information,
as reported to the Energy Information Administration (EIA): facility identification number,
flue identification number, boiler identification number, ARP/Subpart H facility ID number or
ORISPL number (as applicable), reporting year, and 767 reporting indicator (or equivalent).
§ 75.53(e)(l)(x) (x) For each parameter monitored: Scale, maximum potential concentration (and method
of calculation), maximum expected concentration (if applicable) (and method of calculation),
maximum potential flow rate (and method of calculation), maximum potential NOx emission
rate, span value, full-scale range, daily calibration units of measure, span effective date/hour,
span inactivation date/hour, indication of whether dual spans are required, default high range
value, flow rate span, and flow rate span value and full scale value (in scfh) for each unit or
stack using S02, NOx, C02, Hg, 02, or flow component monitors.
§ 75.53(e)(l)(xi) (xi) If the monitoring system or excepted methodology provides for the use of a constant,
assumed, or default value for a parameter under specific circumstances, then include the
following information for each such value for each parameter:
(A) Identification of the parameter;
(B) Default, maximum, minimum, or constant value, and units of measure for the value;
(C) Purpose of the value;
(D) Indicator of use during controlled/uncontrolled hours;
(E) Type of fuel;
(F) Source of the value;
(G) Value effective date and hour;
(H) Date and hour value is no longer effective (if applicable); and
(I) For units using the excepted methodology under § 75.19, the applicable S02 emission
factor.
§ 75.53(e)(l)(xii) (xii) Unless otherwise specified in section 6.5.2.1 of appendix A to this part, for each unit
or common stack on which hardware CEMS are installed:
(A) The upper and lower boundaries of the range of operation (as defined in section 6.5.2.1
of appendix A to this part), expressed in megawatts, or thousands of lb/hr of steam, or ft/sec (as
applicable);
(B) The load (or operating) level(s) designated as normal in section 6.5.2.1 of appendix A
to this part, expressed in megawatts, or thousands of lb/hr of steam, or ft/sec (as applicable);
(C) The two load (or operating) levels (i.e., low, mid, or high) identified in section 6.5.2.1
of appendix A to this part as the most frequently used;
(D) The date of the data analysis used to determine the normal load (or operating) level(s)
and the two most frequently-used load (or operating) levels; and
(E) Activation and deactivation dates, when the normal load (or operating) level(s) or two
most frequently-used load (or operating) levels change and are updated.
§ 75.53(e)(l)(xiii) (xiii) For each unit for which the optional fuel flow-to-load test in section 2.1.7 of
appendix D to this part is used:
(A) The upper and lower boundaries of the range of operation (as defined in section 6.5.2.1
of appendix A to this part), expressed in megawatts or thousands of lb/hr of steam;
(B) The load level designated as normal, pursuant to section 6.5.2.1 of appendix A to this
part, expressed in megawatts or thousands of lb/hr of steam; and
(C) The date of the load analysis used to determine the normal load level.
§ 75.53(e)(l)(xiv) (xiv) For each unit with a flow monitor installed on a rectangular stack or duct, if a wall
effects adjustment factor (WAF) is determined and applied to the hourly flow rate data:
(A) Stack or duct width at the test location, ft;
(B) Stack or duct depth at the test location, ft;
(C) Wall effects adjustment factor (WAF), to the nearest 0.0001;
(D) Method of determining the WAF;
(E) WAF Effective date and hour;
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 118
-------
§ 75.53(e)(2)
§ 75.53(e)(2)®
§ 75.53(e)(2)(ii)
§ 75.53 (e)(2)(iii)
§ 75.53(e)(2)(iv)
§ 75.53(e)(2)(v)
§ 75.53(f)
§ 75.53(f)(1)
§ 75.53(f)(1)®
§75.53(f)(l)(ii)
(F) WAF no longer effective date and hour (if applicable);
(G) WAF determination date;
(H) Number of WAF test runs;
(I) Number of Method 1 traverse points in the WAF test;
(J) Number of test ports in the WAF test; and
(K) Number of Method 1 traverse points in the reference flow RATA.
(2) Hardcopy.
(i) Information, including (as applicable): identification of the test strategy; protocol for
the relative accuracy test audit; other relevant test information; calibration gas levels (percent of
span) for the calibration error test and linearity check; calculations for determining maximum
potential concentration, maximum expected concentration (if applicable), maximum potential
flow rate, maximum potential NOx emission rate, and span; and apportionment strategies under
§§75.10 through 75.18.
(ii) Description of site locations for each monitoring component in the continuous emission
or opacity monitoring systems, including schematic diagrams and engineering drawings
specified in paragraphs (e)(2)(iv) and (e)(2)(v) of this section and any other documentation that
demonstrates each monitor location meets the appropriate siting criteria.
(iii) A data flow diagram denoting the complete information handling path from output
signals of CEMS components to final reports.
(iv) For units monitored by a continuous emission or opacity monitoring system, a
schematic diagram identifying entire gas handling system from boiler to stack for all affected
units, using identification numbers for units, monitor components, and stacks corresponding to
the identification numbers provided in paragraphs (e)(1)®, (e)(l)(iv), (e)(l)(vi), and (e)(l)(ix)
of this section. The schematic diagram must depict stack height and the height of any monitor
locations. Comprehensive and/or separate schematic diagrams shall be used to describe groups
of units using a common stack.
(v) For units monitored by a continuous emission or opacity monitoring system, stack and
duct engineering diagrams showing the dimensions and location of fans, turning vanes, air
preheaters, monitor components, probes, reference method sampling ports, and other equipment
that affects the monitoring system location, performance, or quality control checks.
(f) Contents of monitoring plan for specific situations. The following additional
information shall be included in the monitoring plan for the specific situations described:
(1) For each gas-fired unit or oil-fired unit for which the owner or operator uses the
optional protocol in appendix D to this part for estimating heat input and/or S02 mass
emissions, or for each gas-fired or oil-fired peaking unit for which the owner/operator uses the
optional protocol in appendix E to this part for estimating NOx emission rate (using a fuel
flowmeter), the designated representative shall include the following additional information in
the monitoring plan:
(i) Electronic.
(A) Parameter monitored;
(B) Type of fuel measured, maximum fuel flow rate, units of measure, and basis of
maximum fuel flow rate (i.e., upper range value or unit maximum) for each fuel flowmeter;
(C) Test method used to check the accuracy of each fuel flowmeter;
(D) Submission status of the data;
(E) Monitoring system identification code; and
(F) The method used to demonstrate that the unit qualifies for monthly GCV sampling or
for daily or annual fuel sampling for sulfur content, as applicable.
(ii) Hardcopy.
(A) A schematic diagram identifying the relationship between the unit, all fuel supply lines,
the fuel flowmeter(s), and the stack(s). The schematic diagram must depict the installation
location of each fuel flowmeter and the fuel sampling location(s). Comprehensive and/or
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 119
-------
separate schematic diagrams shall be used to describe groups of units using a common pipe;
(B) For units using the optional default S02 emission rate for "pipeline natural gas" or
"natural gas" in appendix D to this part, the information on the sulfur content of the gaseous
fuel used to demonstrate compliance with either section 2.3.1.4 or 2.3.2.4 of appendix D to this
part; (C) For units using the 720 hour test under 2.3.6 of Appendix D of this part to determine
the required sulfur sampling requirements, report the procedures and results of the test; and
(D) For units using the 720 hour test under 2.3.5 of Appendix D of this part to determine
the appropriate fuel GCV sampling frequency, report the procedures used and the results of the
test;
§ 75.53(f)(2) (2) For each gas-fired peaking unit and oil-fired peaking unit for which the owner or
operator uses the optional procedures in appendix E to this part for estimating NOx emission
rate, the designated representative shall include in the monitoring plan:
§ 75.53(f)(2)(i) (i) Electronic. Unit operating and capacity factor information demonstrating that the unit
qualifies as a peaking unit or gas-fired unit, as defined in § 72.2 of this chapter, and NOx
correlation test information, including:
(A) Test date;
(B) Test number;
(C) Operating level;
(D) Segment ID of the NOx correlation curve;
(E) NOx monitoring system identification;
(F) Low and high heat input rate values and corresponding NOx emission rates;
(G) Type of fuel; and
(H) To document the unit qualifies as a peaking unit, current calendar year or ozone
season, capacity factor data as specified in the definition of peaking unit in § 72.2 of this
chapter, and an indication of whether the data are actual or projected data.
§ 75.53 (f)(2)(ii) (ii) Hardcopy.
(A) A protocol containing methods used to perform the baseline or periodic NOx emission
test; and
(B) Unit operating parameters related to NOx formation by the unit.
§ 75.53(f)(3)
(3) For each gas-fired unit and diesel-fired unit or unit with a wet flue gas pollution control
system for which the designated representative claims an opacity monitoring exemption under
§ 75.14, the designated representative shall include in the hardcopy monitoring plan the
information specified under § 75.14(b), (c), or (d), demonstrating that the unit qualifies for the
exemption.
§ 75.53(f)(4)
§ 75.53(f)(5)
§ 75.53(f)(5)®
(4) For each monitoring system recertification, maintenance, or other event, the designated
representative shall include the following additional information in electronic format in the
monitoring plan:
(i) Component/system identification code;
(ii) Event code or code for required test;
(iii) Event begin date and hour;
(iv) Conditionally valid data period begin date and hour (if applicable);
(v) Date and hour that last test is successfully completed; and
(vi) Indicator of whether conditionally valid data were reported at the end of the quarter.
(5) For each unit using the low mass emissions excepted methodology under § 75.19 the
designated representative shall include the following additional information in the monitoring
plan that accompanies the initial certification application:
(i) Electronic. For each low mass emissions unit, report the results of the analysis
performed to qualify as a low mass emissions unit under § 75.19(c). This report will include
either the previous three years actual or projected emissions. The following items should be
included:
(A) Current calendar year of application;
(B) Type of qualification;
(C) Years one, two, and three;
(D) Annual or ozone season measured, estimated or projected NOx mass emissions for
years one, two, and three;
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 120
-------
§ 75.53(f)(5)(ii)
§ 75.53(f)(6)
75.53(g)
§ 75.53(g)(1)
§ 75.53(g)(l)(i)
(E) Annual measured, estimated or projected S02 mass emissions for years one, two, and
three; and
(F) Annual or ozone season operating hours for years one, two, and three.
(ii) Hardcopy.
(A) A schematic diagram identifying the relationship between the unit, all fuel supply lines
and tanks, any fuel flowmeter(s), and the stack(s). Comprehensive and/or separate schematic
diagrams shall be used to describe groups of units using a common pipe;
(B) For units which use the long term fuel flow methodology under § 75.19(c)(3), the
designated representative must provide a diagram of the fuel flow to each affected unit or group
of units and describe in detail the procedures used to determine the long term fuel flow for a
unit or group of units for each fuel combusted by the unit or group of units;
(C) A statement that the unit burns only gaseous fuel(s) and/or fuel oil and a list of the
fuels that are burned or a statement that the unit is projected to burn only gaseous fuel(s) and/or
fuel oil and a list of the fuels that are projected to be burned;
(D) A statement that the unit meets the applicability requirements in §§ 75.19(a) and (b);
and
(E) Any unit historical actual, estimated and projected emissions data and calculated
emissions data demonstrating that the affected unit qualifies as a low mass emissions unit under
§§ 75.19(a) and 75.19(b).
(6) For each gas-fired unit the designated representative shall include in the monitoring
plan, in electronic format, the following: current calendar year, fuel usage data as specified in
the definition of gas-fired in § 72.2 of this part, and an indication of whether the data are actual
or projected data.
(g) Contents of the monitoring plan. The requirements of paragraphs (g) and (h) of this
section shall be met on and after January 1, 2009. Notwithstanding this requirement, the
provisions of paragraphs (g) and (h) of this section may be implemented prior to January 1,
2009, as follows. In 2008, the owner or operator may opt to record and report the monitoring
plan information in paragraphs (g) and (h) of this section, in lieu of recording and reporting the
information in paragraphs (e) and (f) of this section. Each monitoring plan shall contain the
information in paragraph (g)(1) of this section in electronic format and the information in
paragraph (g)(2) of this section in hardcopy format. Electronic storage of all monitoring plan
information, including the hardcopy portions, is permissible provided that a paper copy of the
information can be furnished upon request for audit purposes.
(1) Electronic.
(i) The facility ORISPL number developed by the Department of Energy and used in the
National Allowance Data Base (or equivalent facility ID number assigned by EPA, if the
facility does not have an ORISPL number). Also provide the following information for each
unit and (as applicable) for each common stack and/or pipe, and each multiple stack and/or
pipe involved in the monitoring plan:
(A) A representation of the exhaust configuration for the units in the monitoring plan.
Provide the ID number of each unit and assign a unique ID number to each common stack,
common pipe multiple stack and/or multiple pipe associated with the unit(s) represented in the
monitoring plan. For common and multiple stacks and/or pipes, provide the activation date and
deactivation date (if applicable) of each stack and/or pipe;
(B) Identification of the monitoring system location(s) (e.g., at the unit-level, on the
common stack, at each multiple stack, etc.). Provide an indicator ("flag") if the monitoring
location is at a bypass stack or in the ductwork (breeching);
(C) The stack exit height (ft) above ground level and ground level elevation above sea
level, and the inside cross-sectional area (ft2) at the flue exit and at the flow monitoring location
(for units with flow monitors, only). Also use appropriate codes to indicate the material(s) of
construction and the shape(s) of the stack or duct cross-section(s) at the flue exit and (if
applicable) at the flow monitor location;
(D) The type(s) of fuel(s) fired by each unit. Indicate the start and (if applicable) end date
of combustion for each type of fuel, and whether the fuel is the primary, secondary, emergency,
or startup fuel;
(E) The type(s) of emission controls that are used to reduce S02, NOx, Hg, and particulate
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 121
-------
emissions from each unit. Also provide the installation date, optimization date, and retirement
date (if applicable) of the emission controls, and indicate whether the controls are an original
installation;
(F) Maximum hourly heat input capacity of each unit; and
(G) A non-load based unit indicator (if applicable) for units that do not produce electrical
or thermal output.
§ 75.53(g)(l)(ii) (ii) For each monitored parameter (e.g., S02, NOx, flow, etc.) at each monitoring location,
specify the monitoring methodology and the missing data approach for the parameter. If the
unmonitored bypass stack approach is used for a particular parameter, indicate this by means of
an appropriate code. Provide the activation date/hour, and deactivation date/hour (if
applicable) for each monitoring methodology and each missing data approach.
§ 75.53(g)(l)(iii) (iii) For each required continuous emission monitoring system, each fuel flowmeter
system, each continuous opacity monitoring system, and each sorbent trap monitoring system
(as defined in §72.2 of this chapter), identify and describe the major monitoring components in
the monitoring system (e.g., gas analyzer, flow monitor, opacity monitor, moisture sensor, fuel
flowmeter, DAHS software, etc.). Other important components in the system (e.g., sample
probe, PLC, data logger, etc.) may also be represented in the monitoring plan, if necessary.
Provide the following specific information about each component and monitoring system:
(A) For each required monitoring system:
(/) Assign a unique, 3-character alphanumeric identification code to the system;
(2) Indicate the parameter monitored by the system;
(3) Designate the system as a primary, redundant backup, non-redundant backup, data
backup, or reference method backup system, as provided in § 75.10(e); and
(4) Indicate the system activation date/hour and deactivation date/hour (as applicable).
(B) For each component of each monitoring system represented in the monitoring plan:
(/) Assign a unique, 3-character alphanumeric identification code to the component;
(2) Indicate the manufacturer, model and serial number;
(3) Designate the component type;
(4) For dual-span applications, indicate whether the analyzer component ID represents a
high measurement scale, a low scale, or a dual range;
(5) For gas analyzers, indicate the moisture basis of measurement;
(6) Indicate the method of sample acquisition or operation, (e.g., extractive pollutant
concentration monitor or thermal flow monitor); and
(7) Indicate the component activation date/hour and deactivation date/hour (as applicable).
§ 75.53(g)(l)(iv) (iv) Explicit formulas, using the component and system identification codes for the primary
monitoring system, and containing all constants and factors required to derive the required mass
emissions, emission rates, heat input rates, etc. from the hourly data recorded by the monitoring
systems. Formulas using the system and component ID codes for backup monitoring systems
are required only if different formulas for the same parameter are used for the primary and
backup monitoring systems (e.g., if the primary system measures pollutant concentration on a
different moisture basis from the backup system). Provide the equation number or other
appropriate code for each emissions formula (e.g., use code F-l if EquationF-1 in appendix F
to this part is used to calculate S02 mass emissions). Also identify each emissions formula with
a unique three character alphanumeric code. The formula effective start date/hour and
inactivation date/hour (as applicable) shall be included for each formula. The owner or
operator of a unit for which the optional low mass emissions excepted methodology in § 75.19
is being used is not required to report such formulas.
§ 75.53(g)(l)(v) (v) For each parameter monitored with CEMS, provide the following information:
(A) Measurement scale (high or low);
(B) Maximum potential value (and method of calculation). If NOx emission rate in
lb/mmBtu is monitored, calculate and provide the maximum potential NOx emission rate in
addition to the maximum potential NOx concentration;
(C) Maximum expected value (if applicable) and method of calculation;
(D) Span value(s) and full-scale measurement range(s);
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 122
-------
(E) Daily calibration units of measure;
(F) Effective date/hour, and (if applicable) inactivation date/hour of each span value;
(G) An indication of whether dual spans are required; and
(H) The default high range value (if applicable) and the maximum allowable low-range
value for this option;
§ 75.53(g)(l)(vi) (vi) If the monitoring system or excepted methodology provides for the use of a constant,
assumed, or default value for a parameter under specific circumstances, then include the
following information for each such value for each parameter:
(A) Identification of the parameter;
(B) Default, maximum, minimum, or constant value, and units of measure for the value;
(C) Purpose of the value;
(D) Indicator of use, i.e., during controlled hours, uncontrolled hours, or all operating
hours;
(E) Type of fuel;
(F) Source of the value;
(G) Value effective date and hour;
(H) Date and hour value is no longer effective (if applicable); and
(I) For units using the excepted methodology under § 75.19, the applicable S02 emission
factor.
§ 75.53(g)(l)(vii) (vii) Unless otherwise specified in section 6.5.2.1 of appendix A to this part, for each unit
or common stack on which hardware CEMS are installed:
(A) Maximum hourly gross load (in MW, rounded to the nearest MW, or steam load in
1000 lb/hr (i.e., klb/hr), rounded to the nearest klb/hr, or thermal output in mmBtu/hr, rounded
to the nearest mmBtu/hr), for units that produce electrical or thermal output;
(B) The upper and lower boundaries of the range of operation (as defined in section 6.5.2.1
of appendix A to this part), expressed in megawatts, thousands of lb/hr of steam, mmBtu/hr of
thermal output, or ft/sec (as applicable);
(C) Except for peaking units, identify the most frequently and second most frequently used
load (or operating) levels (i.e., low, mid, or high) in accordance with section 6.5.2.1 of
appendix A to this part, expressed in megawatts, thousands of lb/hr of steam, mmBtu/hr of
thermal output, or ft/sec (as applicable);
(D) Except for peaking units, an indicator of whether the second most frequently used load
(or operating) level is designated as normal in section 6.5.2.1 of appendix A to this part;
(E) The date of the data analysis used to determine the normal load (or operating) level(s)
and the two most frequently-used load (or operating) levels (as applicable); and
(F) Activation and deactivation dates and hours, when the maximum hourly gross load,
boundaries of the range of operation, normal load (or operating) level(s) or two most
frequently-used load (or operating) levels change and are updated.
§ 75.53(g)(l)(viii) (viii) For each unit for which CEMS are not installed:
(A) Maximum hourly gross load (in MW, rounded to the nearest MW, or steam load in
klb/hr, rounded to the nearest klb/hr, or steam load in mmBtu/hr, rounded to the nearest
mmBtu/hr);
(B) The upper and lower boundaries of the range of operation (as defined in section 6.5.2.1
of appendix A to this part), expressed in megawatts, mmBtu/hr of thermal output, or thousands
of lb/hr of steam;
(C) Except for peaking units and units using the low mass emissions excepted methodology
under § 75.19, identify the load level designated as normal, pursuant to section 6.5.2.1 of
appendix A to this part, expressed in megawatts, mmBtu/hr of thermal output, or thousands of
lb/hr of steam;
(D) The date of the load analysis used to determine the normal load level (as applicable);
and
(E) Activation and deactivation dates and hours, when the maximum hourly gross load,
boundaries of the range of operation, or normal load level change and are updated.
§ 75.53(g)(l)(ix) (ix) For each unit with a flow monitor installed on a rectangular stack or duct, if a wall
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 123
-------
effects adjustment factor (WAF) is determined and applied to the hourly flow rate data:
(A) Stack or duct width at the test location, ft;
(B) Stack or duct depth at the test location, ft;
(C) Wall effects adjustment factor (WAF), to the nearest 0.0001;
(D) Method of determining the WAF;
(E) WAF Effective date and hour;
(F) WAF no longer effective date and hour (if applicable);
(G) WAF determination date;
(H) Number of WAF test runs;
(I) Number of Method 1 traverse points in the WAF test;
(J) Number of test ports in the WAF test; and
(K) Number of Method 1 traverse points in the reference flow RATA.
§ 75.53(g)(2) (2) Hardcopy.
§ 75.53(g)(2)(i) (i) Information, including (as applicable): identification of the test strategy; protocol for
the relative accuracy test audit; other relevant test information; calibration gas levels (percent of
span) for the calibration error test and linearity check; calculations for determining maximum
potential concentration, maximum expected concentration (if applicable), maximum potential
flow rate, maximum potential NOx emission rate, and span; and apportionment strategies under
§§75.10 through 75.18.
§ 75.53(g)(2)(ii) (ii) Description of site locations for each monitoring component in the continuous emission
or opacity monitoring systems, including schematic diagrams and engineering drawings
specified in paragraphs (e)(2)(iv) and (e)(2)(v) of this section and any other documentation that
demonstrates each monitor location meets the appropriate siting criteria.
§ 75.53(g)(2)(iii) (iii) A data flow diagram denoting the complete information handling path from output
signals of CEMS components to final reports.
§ 75.53(g)(2)(iv) (iv) For units monitored by a continuous emission or opacity monitoring system, a
schematic diagram identifying entire gas handling system from boiler to stack for all affected
units, using identification numbers for units, monitoring systems and components, and stacks
corresponding to the identification numbers provided in paragraphs (g)(l)(i) and (g)(l)(iii) of
this section. The schematic diagram must depict stack height and the height of any monitor
locations. Comprehensive and/or separate schematic diagrams shall be used to describe groups
of units using a common stack.
§ 75.53(g)(2)(v) (v) For units monitored by a continuous emission or opacity monitoring system, stack and
duct engineering diagrams showing the dimensions and location of fans, turning vanes, air
preheaters, monitor components, probes, reference method sampling ports, and other equipment
that affects the monitoring system location, performance, or quality control checks.
§ 75.53(h) (h) Contents of monitoring plan for specific situations. The following additional
information shall be included in the monitoring plan for the specific situations described:
§ 75.53(h)(1) (1) For each gas-fired unit or oil-fired unit for which the owner or operator uses the
optional protocol in appendix D to this part for estimating heat input and/or S02 mass
emissions, or for each gas-fired or oil-fired peaking unit for which the owner/operator uses the
optional protocol in appendix E to this part for estimating NOx emission rate (using a fuel
flowmeter), the designated representative shall include the following additional information for
each fuel flowmeter system in the monitoring plan:
§ 75.53(h)(l)(i) (i) Electronic.
(A) Parameter monitored;
(B) Type of fuel measured, maximum fuel flow rate, units of measure, and basis of
maximum fuel flow rate (i.e., upper range value or unit maximum) for each fuel flowmeter;
(C) Test method used to check the accuracy of each fuel flowmeter;
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 124
-------
(D) Monitoring system identification code;
(E) The method used to demonstrate that the unit qualifies for monthly GCV sampling or
for daily or annual fuel sampling for sulfur content, as applicable; and
(F) Activation date/hour and (if applicable) inactivation date/hour for the fuel flowmeter
system;
§ 75.53(h)(l)(ii)
(ii) Hardcopy.
(A) A schematic diagram identifying the relationship between the unit, all fuel supply lines,
the fuel flowmeter(s), and the stack(s). The schematic diagram must depict the installation
location of each fuel flowmeter and the fuel sampling location(s). Comprehensive and/or
separate schematic diagrams shall be used to describe groups of units using a common pipe;
(B) For units using the optional default S02 emission rate for "pipeline natural gas" or
"natural gas" in appendix D to this part, the information on the sulfur content of the gaseous
fuel used to demonstrate compliance with either section 2.3.1.4 or 2.3.2.4 of appendix D to this
part;
(C) For units using the 720 hour test under 2.3.6 of Appendix D of this part to determine
the required sulfur sampling requirements, report the procedures and results of the test; and
(D) For units using the 720 hour test under 2.3.5 of Appendix D of this part to determine
the appropriate fuel GCV sampling frequency, report the procedures used and the results of the
test.
§ 75.53(h)(2)
(2) For each gas-fired peaking unit and oil-fired peaking unit for which the owner or
operator uses the optional procedures in appendix E to this part for estimating NOx emission
rate, the designated representative shall include in the monitoring plan:
§ 75.53(h)(2)(i)
(i) Electronic. Unit operating and capacity factor information demonstrating that the unit
qualifies as a peaking unit, as defined in § 72.2 of this chapter for the current calendar year or
ozone season, including: capacity factor data for three calendar years (or ozone seasons) as
specified in the definition of peaking unit in § 72.2 of this chapter; the method of qualification
used; and an indication of whether the data are actual or projected data.
§ 75.53(h)(2)(ii)
(ii) Hardcopy.
(A) A protocol containing methods used to perform the baseline or periodic NOx emission
test; and
(B) Unit operating parameters related to NOx formation by the unit.
§ 75.53(h)(3)
(3) For each gas-fired unit and diesel-fired unit or unit with a wet flue gas pollution control
system for which the designated representative claims an opacity monitoring exemption under
§ 75.14, the designated representative shall include in the hardcopy monitoring plan the
information specified under § 75.14(b), (c), or (d), demonstrating that the unit qualifies for the
exemption.
§ 75.53(h)(4)
(4) For each unit using the low mass emissions excepted methodology under § 75.19 the
designated representative shall include the following additional information in the monitoring
plan that accompanies the initial certification application:
§ 75.53(h)(4)(i)
(i) Electronic. For each low mass emissions unit, report the results of the analysis
performed to qualify as a low mass emissions unit under § 75.19(c). This report will include
either the previous three years actual or projected emissions. The following items should be
included:
(A) Current calendar year of application;
(B) Type of qualification;
(C) Years one, two, and three;
(D) Annual and/or ozone season measured, estimated or projected NOx mass emissions for
years one, two, and three;
(E) Annual measured, estimated or projected S02 mass emissions (if applicable) for years
one, two, and three; and
(F) Annual or ozone season operating hours for years one, two, and three.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 125
-------
§ 75.53(h)(4)(ii) (ii) Hardcopy.
(A) A schematic diagram identifying the relationship between the unit, all fuel supply lines
and tanks, any fuel flowmeter(s), and the stack(s). Comprehensive and/or separate schematic
diagrams shall be used to describe groups of units using a common pipe;
(B) For units which use the long term fuel flow methodology under § 75.19(c)(3), the
designated representative must provide a diagram of the fuel flow to each affected unit or group
of units and describe in detail the procedures used to determine the long term fuel flow for a
unit or group of units for each fuel combusted by the unit or group of units;
(C) A statement that the unit burns only gaseous fuel(s) and/or fuel oil and a list of the
fuels that are burned or a statement that the unit is projected to burn only gaseous fuel(s) and/or
fuel oil and a list of the fuels that are projected to be burned;
(D) A statement that the unit meets the applicability requirements in §§ 75.19(a) and (b);
and
(E) Any unit historical actual, estimated and projected emissions data and calculated
emissions data demonstrating that the affected unit qualifies as a low mass emissions unit under
§§ 75.19(a) and 75.19(b).
§ 75.53(h)(5) (5) For qualification as a gas-fired unit, as defined in § 72.2 of this part, the designated
representative shall include in the monitoring plan, in electronic format, the following: current
calendar year, fuel usage data for three calendar years (or ozone seasons) as specified in the
definition of gas-fired in § 72.2 of this part, the method of qualification used, and an indication
of whether the data are actual or projected data.
§ 75.53(h)(6)
§ 75.54
§ 75.55
§ 75.56
§ 75.57
§ 75.57(a)
§ 75.57(a)(1)
§ 75.57(a)(2)
(6) For each monitoring location with a stack flow monitor that is exempt from performing
3-load flow RAT As (peaking units, bypass stacks, or by petition) the designated representative
shall include in the monitoring plan an indicator of exemption from 3-load flow RATA using
the appropriate exemption code.
§ 75.54 [Reserved]
§ 75.55 [Reserved]
§ 75.56 [Reserved]
§ 75.57 General recordkeeping provisions.
The owner or operator shall meet all of the applicable recordkeeping requirements of this
section.
(a) Recordkeeping requirements for affected sources. The owner or operator of any
affected source subject to the requirements of this part shall maintain for each affected unit a
file of all measurements, data, reports, and other information required by this part at the source
in a form suitable for inspection for at least three (3) years from the date of each record.
Unless otherwise provided, throughout this subpart the phrase "for each affected unit" also
applies to each group of affected or nonaffected units utilizing a common stack and common
monitoring systems, pursuant to §§ 75.16 through 75.18, or utilizing a common pipe header
and common fuel flowmeter, pursuant to section 2.1.2 of appendix D to this part. The file shall
contain the following information:
(1) The data and information required in paragraphs (b) through (h) of this section,
beginning with the earlier of the date of provisional certification or the deadline in § 75.4(a),
(b), or (c);
(2) The supporting data and information used to calculate values required in paragraphs
(b) through (g) of this section, excluding the subhourly data points used to compute hourly
averages under § 75.10(d), beginning with the earlier of the date of provisional certification or
the deadline in § 75.4(a), (b), or (c);
§ 75.57(a)(3)
(3) The data and information required in § 75.58 for specific situations, beginning with the
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 126
-------
earlier of the date of provisional certification or the deadline in § 75.4(a), (b), or (c);
§ 75.57(a)(4)
§ 75.57(a)(5)
§ 75.57(a)(6)
§ 75.57(b)
§ 75.57(b)(1)
§ 75.57(b)(2)
§ 75.57(b)(3)
§ 75.57(b)(4)
§ 75.57(b)(5)
§ 75.57(b)(6)
§ 75.57(b)(7)
§ 75.57(c)
§ 75.57(c)(1)
(4) The certification test data and information required in § 75.59 for tests required under
§ 75.20, beginning with the date of the first certification test performed, the quality assurance
and quality control data and information required in § 75.59 for tests, and the quality
assurance/quality control plan required under § 75.21 and appendix B to this part, beginning
with the date of provisional certification;
(5) The current monitoring plan as specified in § 75.53, beginning with the initial
submission required by § 75.62; and
(6) The quality control plan as described in section 1 of appendix B to this part, beginning
with the date of provisional certification.
(b) Operating parameter record provisions. The owner or operator shall record for each
hour the following information on unit operating time, heat input rate, and load, separately for
each affected unit and also for each group of units utilizing a common stack and a common
monitoring system or utilizing a common pipe header and common fuel flowmeter:
(1) Date and hour;
(2) Unit operating time (rounded up to the nearest fraction of an hour (in equal increments
that can range from one hundredth to one quarter of an hour, at the option of the owner or
operator));
(3) Hourly gross unit load (rounded to nearest MWge) (or steam load in 1000 lb/hr at
stated temperature and pressure, rounded to the nearest 1000 lb/hr, or mmBtu/hr of thermal
output, rounded to the nearest mmBtu/hr, if elected in the monitoring plan);
(4) Operating load range corresponding to hourly gross load of 1 to 10, except for units
using a common stack or common pipe header, which may use up to 20 load ranges for stack
or fuel flow, as specified in the monitoring plan;
(5) Hourly heat input rate (mmBtu/hr, rounded to the nearest tenth);
(6) Identification code for formula used for heat input, as provided in § 75.53; and
(7) For CEMS units only, F-factor for heat input calculation and indication of whether the
diluent cap was used for heat input calculations for the hour.
(c) SO 2 emission record provisions. The owner or operator shall record for each hour the
information required by this paragraph for each affected unit or group of units using a common
stack and common monitoring systems, except as provided under § 75.11(e) or for a gas-fired
or oil-fired unit for which the owner or operator is using the optional protocol in appendix D to
this part or for a low mass emissions unit for which the owner or operator is using the optional
low mass emissions methodology in § 75.19(c) for estimating S02 mass emissions:
(1) For S02 concentration during unit operation, as measured and reported from each
certified primary monitor, certified back-up monitor, or other approved method of emissions
determination:
(i) Component-system identification code, as provided in § 75.53;
(ii) Date and hour;
(iii) Hourly average S02 concentration (ppm, rounded to the nearest tenth);
(iv) Hourly average S02 concentration (ppm, rounded to the nearest tenth), adjusted for
bias if bias adjustment factor is required, as provided in § 75.24(d);
(v) Percent monitor data availability (recorded to the nearest tenth of a percent), calculated
pursuant to § 75.32; and
(vi) Method of determination for hourly average S02 concentration using Codes 1-55 in
Table 4a of this section.
§ 75.57(c)(2)
(2) For flow rate during unit operation, as measured and reported from each certified
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 127
-------
primary monitor, certified back-up monitor, or other approved method of emissions
determination:
(i) Component-system identification code, as provided in § 75.53; (ii) Date and hour;
(iii) Hourly average volumetric flow rate (in scfh, rounded to the nearest thousand);
(iv) Hourly average volumetric flow rate (in scfh, rounded to the nearest thousand),
adjusted for bias if bias adjustment factor required, as provided in § 75.24(d);
(v) Percent monitor data availability (recorded to the nearest tenth of a percent) for the
flow monitor, calculated pursuant to § 75.32; and
(vi) Method of determination for hourly average flow rate using Codes 1-5 5 in Table 4a of
this section.
§ 75.57(c)(3) (3) For flue gas moisture content during unit operation (where S02 concentration is
measured on a dry basis), as measured and reported from each certified primary monitor,
certified back-up monitor, or other approved method of emissions determination:
(i) Component-system identification code, as provided in § 75.53;
(ii) Date and hour;
(iii) Hourly average moisture content of flue gas (percent, rounded to the nearest tenth). If
the continuous moisture monitoring system consists of wet- and dry-basis oxygen analyzers,
also record both the wet- and dry-basis oxygen hourly averages (in percent 02, rounded to the
nearest tenth);
(iv) Percent monitor data availability (recorded to the nearest tenth of a percent) for the
moisture monitoring system, calculated pursuant to § 75.32; and
(v) Method of determination for hourly average moisture percentage, using Codes 1-55 in
Table 4a of this section.
§ 75.57(c)(4) (4) For S02 mass emission rate during unit operation, as measured and reported from the
certified primary monitoring system(s), certified redundant or non-redundant back-up
monitoring system(s), or other approved method(s) of emissions determination:
(i) Date and hour;
(ii) Hourly S02 mass emission rate (lb/hr, rounded to the nearest tenth);
(iii) Hourly S02 mass emission rate (lb/hr, rounded to the nearest tenth), adjusted for bias
if bias adjustment factor required, as provided in § 75.24(d); and
(iv) Identification code for emissions formula used to derive hourly S02 mass emission
rate from S02 concentration and flow and (if applicable) moisture data in paragraphs (c)(1),
(c)(2), and (c)(3) of this section, as provided in § 75.53.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 128
-------
Table 4a. ~ Codes for Method of Emissions and Flow Determination
Code
Hourly emissions/flow measurement or estimation method
1
Certified primary emission/flow monitoring system.
2
Certified backup emission/flow monitoring system.
3
Approved alternative monitoring system.
4
Reference method:
S02: Method 6C.
Flow: Method 2 or its allowable alternatives under appendix A to part 60 of this chapter.
NOx: Method 7E.
C02 or 02: Method 3A.
5
For units with add-on S02 and/or NOx emission controls: S02 concentration or NOx emission rate estimate from
Agency preapproved parametric monitoring method.
6
Average of the hourly S02 concentrations, C02 concentrations, 02 concentrations, NOx concentrations, flow rates,
moisture percentages or NOx emission rates for the hour before and the hour following a missing data period.
7
Initial missing data procedures used. Either: (a) the average of the hourly S02 concentration, C02 concentration,
02 concentration, or moisture percentage for the hour before and the hour following a missing data period; or (b)
the arithmetic average of all NOx concentration, NOx emission rate, or flow rate values at the corresponding load
range (or a higher load range), or at the corresponding operational bin (non-load-based units, only); or (c) the
arithmetic average of all previous NOx concentration, NOx emission rate, or flow rate values (non-load-based units,
only).
8
90th percentile hourly S02 concentration, C02 concentration, NOx concentration, flow rate, moisture percentage, or
NOx emission rate or 10th percentile hourly 02 concentration or moisture percentage in the applicable lookback
period (moisture missing data algorithm depends on which equations are used for emissions and heat input).
9
95th percentile hourly S02 concentration, C02 concentration, NOx concentration, flow rate, moisture percentage, or
NOx emission rate or 5th percentile hourly 02 concentration or moisture percentage in the applicable lookback
period (moisture missing data algorithm depends on which equations are used for emissions and heat input).
10
Maximum hourly S02 concentration, C02 concentration, NOx concentration, flow rate, moisture percentage, or
NOx emission rate or minimum hourly 02 concentration or moisture percentage in the applicable lookback period
(moisture missing data algorithm depends on which equations are used for emissions and heat input).
11
Average of hourly flow rates, NOx concentrations or NOx emission rates in corresponding load range, for the
applicable lookback period. For non-load-based units, report either the average flow rate, NOx concentration or
NOx emission rate in the applicable lookback period, or the average flow rate or NOx value at the corresponding
operational bin (if operational bins are used).
12
Maximum potential concentration of S02, maximum potential concentration of C02, maximum potential
concentration of NOx maximum potential flow rate, maximum potential NOx emission rate, maximum potential
moisture percentage, minimum potential 02 concentration or minimum potential moisture percentage, as
determined using § 72.2 of this chapter and section 2.1 of appendix A to this part (moisture missing data algorithm
depends on which equations are used for emissions and heat input).
13
Maximum expected concentration of S02, maximum expected concentration of NOx, maximum expected Hg
concentration, or maximum controlled NOx emission rate. (See §75.34(a)(5)).
14
Diluent cap value (if the cap is replacing a C02 measurement, use 5.0 percent for boilers and 1.0 percent for
turbines; if it is replacing an 02 measurement, use 14.0 percent for boilers and 19.0 percent for turbines).
15
1.25 times the maximum hourly controlled S02 concentration, Hg concentration, NOx concentration at the
corresponding load or operational bin, or NOx emission rate at the corresponding load or operational bin, in the
applicable lookback period (See §75.34(a)(5)).
16
S02 concentration value of 2.0 ppm during hours when only "very low sulfur fuel", as defined in
§ 72.2 of this chapter, is combusted.
17
Like-kind replacement non-redundant backup analyzer.
19
200 percent of the MPC; default high range value.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 129
-------
20
200 percent of the full-scale range setting (full-scale exceedance of high range).
21
Negative hourly C02 concentration, S02 concentration, NOx concentration, percent moisture, or NOx emission rate
replaced with zero.
22
Hourly average S02 or NOx concentration, measured by a certified monitor at the control device inlet (units with
add-on emission controls only).
23
Maximum potential S02 concentration, NOx concentration, C02 concentration, NOx emission rate or flow rate, or
minimum potential 02 concentration or moisture percentage, for an hour in which flue gases are discharged through
an unmonitored bypass stack.
24
Maximum expected NOx concentration, or maximum controlled NOx emission rate for an hour in which flue gases
are discharged downstream of the NOx emission controls through an unmonitored bypass stack, and the add-on
NOx emission controls are confirmed to be operating properly.
25
Maximum potential NOx emission rate (MER). (Use only when a NOx concentration full-scale exceedance occurs
and the diluent monitor is unavailable.)
26
1.0 mmBtu/hr substituted for Heat Input Rate for an operating hour in which the calculated Heat Input
Rate is zero or negative.
32
Hourly Hg concentration determined from analysis of a single trap multiplied by a factor of 1.111 when
one of the paired traps is invalidated or damaged (See Appendix K, section 8).
33
Hourly Hg concentration determined from the trap resulting in the higher Hg concentration when the
relative deviation criterion for the paired traps is not met (See Appendix K, section 8).
40
Fuel specific default value (or prorated default value) used for the hour.
54
Other quality assured methodologies approved through petition. These hours are included in missing
data lookback and are treated as unavailable hours for percent monitor availability calculations.
55
Other substitute data approved through petition. These hours are not included in missing data lookback
and are treated as unavailable hours for percent monitor availability calculations.
§ 75.57(d)
(d) N0X emission record provisions. The owner or operator shall record the applicable
information required by this paragraph for each affected unit for each hour or partial hour
during which the unit operates, except for a gas-fired peaking unit or oil-fired peaking unit for
which the owner or operator is using the optional protocol in appendix E to this part or a low
mass emissions unit for which the owner or operator is using the optional low mass emissions
excepted methodology in § 75.19(c) for estimating NOx emission rate. For each NOx emission
rate (in lb/mmBtu) measured by a NOx-diluent monitoring system, or, if applicable, for each
NOx concentration (in ppm) measured by a NOx concentration monitoring system used to
calculate NOx mass emissions under § 75.71(a)(2), record the following data as measured and
reported from the certified primary monitor, certified back-up monitor, or other approved
method of emissions determination:
§ 75.57(d)(1)
(1) Component-system identification code, as provided in § 75.53 (including identification
code for the moisture monitoring system, if applicable);
§ 75.57(d)(2)
§ 75.57(d)(3)
(2) Date and hour;
(3) Hourly average NOx concentration (ppm, rounded to the nearest tenth) and hourly
average NOx concentration (ppm, rounded to the nearest tenth) adjusted for bias if bias
adjustment factor required, as provided in § 75.24(d);
§ 75.57(d)(4)
§ 75.57(d)(5)
(4) Hourly average diluent gas concentration (for NOx-diluent monitoring systems, only, in
units of percent 02 or percent C02, rounded to the nearest tenth);
(5) If applicable, the hourly average moisture content of the stack gas (percent H20,
rounded to the nearest tenth). If the continuous moisture monitoring system consists of wet-
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 130
-------
and dry-basis oxygen analyzers, also record both the hourly wet- and dry-basis oxygen readings
(in percent 02, rounded to the nearest tenth);
§ 75.57(d)(6) (6) Hourly average NOx emission rate (for NOx-diluent monitoring systems only, in units
of lb/mmBtu, rounded to the nearest thousandth);
§ 75.57(d)(7)
(7) Hourly average NOx emission rate (for NOx-diluent monitoring systems only, in units
of lb/mmBtu, rounded to the nearest thousandth), adjusted for bias if bias adjustment factor is
required, as provided in § 75.24(d). The requirement to report hourly NOx emission rates to
the nearest thousandth shall not affect NOx compliance determinations under part 76 of this
chapter; compliance with each applicable emission limit under part 76 shall be determined to
the nearest hundredth pound per million Btu;
§ 75.57(d)(8)
(8) Percent monitoring system data availability (recorded to the nearest tenth of a percent),
for the NOx-diluent or NOx concentration monitoring system, and, if applicable, for the
moisture monitoring system, calculated pursuant to § 75.32;
§ 75.57(d)(9)
(9) Method of determination for hourly average NOx emission rate or NOx concentration
and (if applicable) for the hourly average moisture percentage, using Codes 1-55 in Table 4a of
this section; and
§ 75.57(d)(10)
(10) Identification codes for emissions formulas used to derive hourly average NOx
emission rate and total NOx mass emissions, as provided in § 75.53, and (if applicable) the F-
factor used to convert NOx concentrations into emission rates.
§ 75.57(e)
(e) CO 2 emission record provisions. Except for a low mass emissions unit for which the
owner or operator is using the optional low mass emissions excepted methodology in
§ 75.19(c) for estimating C02 mass emissions, the owner or operator shall record or calculate
C02 emissions for each affected unit using one of the following methods specified in this
section:
§ 75.57(e)(1) (1) If the owner or operator chooses to use a C02 CEMS (including an 02 monitor and
flow monitor, as specified in appendix F to this part), then the owner or operator shall record
for each hour or partial hour during which the unit operates the following information for C02
mass emissions, as measured and reported from the certified primary monitor, certified back-up
monitor, or other approved method of emissions determination:
(i) Component-system identification code, as provided in § 75.53 (including identification
code for the moisture monitoring system, if applicable);
(ii) Date and hour;
(iii) Hourly average C02 concentration (in percent, rounded to the nearest tenth);
(iv) Hourly average volumetric flow rate (scfh, rounded to the nearest thousand scfh);
(v) Hourly average moisture content of flue gas (percent, rounded to the nearest tenth),
where C02 concentration is measured on a dry basis. If the continuous moisture monitoring
system consists of wet- and dry-basis oxygen analyzers, also record both the hourly wet- and
dry-basis oxygen readings (in percent 02, rounded to the nearest tenth);
(vi) Hourly average C02 mass emission rate (tons/hr, rounded to the nearest tenth);
(vii) Percent monitor data availability for both the C02 monitoring system and, if
applicable, the moisture monitoring system (recorded to the nearest tenth of a percent),
calculated pursuant to § 75.32;
(viii) Method of determination for hourly average C02 mass emission rate and hourly
average C02 concentration, and, if applicable, for the hourly average moisture percentage,
using Codes 1-55 in Table 4a of this section;
(ix) Identification code for emissions formula used to derive hourly average C02 mass
emission rate, as provided in § 75.53; and
(x) Indication of whether the diluent cap was used for C02 calculation for the hour.
§ 75.57(e)(2) (2) As an alternative to paragraph (e)(1) of this section, the owner or operator may use the
procedures in § 75.13 and in appendix G to this part, and shall record daily the following
information for C02 mass emissions:
(i) Date;
(ii) Daily combustion-formed C02 mass emissions (tons/day, rounded to the nearest tenth);
(iii) For coal-fired units, flag indicating whether optional procedure to adjust combustion-
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 131
-------
formed C02 mass emissions for carbon retained in flyash has been used and, if so, the
adjustment;
(iv) For a unit with a wet flue gas desulfurization system or other controls generating C02,
daily sorbent-related C02 mass emissions (tons/day, rounded to the nearest tenth); and
(v) For a unit with a wet flue gas desulfurization system or other controls generating C02,
total daily C02 mass emissions (tons/day, rounded to the nearest tenth) as the sum of
combustion-formed emissions and sorbent-related emissions.
§ 75.57(f) (f) Opacity records. The owner or operator shall record opacity data as specified by the
State or local air pollution control agency. If the State or local air pollution control agency
does not specify recordkeeping requirements for opacity, then record the information required
by paragraphs (f) (1) through (5) of this section for each affected unit, except as provided in
§§ 75.14(b), (c), and (d). The owner or operator shall also keep records of all incidents of
opacity monitor downtime during unit operation, including reason(s) for the monitor outage(s)
and any corrective action(s) taken for opacity, as measured and reported by the continuous
opacity monitoring system:
(1) Component/system identification code;
(2) Date, hour, and minute;
(3) Average opacity of emissions for each six minute averaging period (in percent
opacity);
(4) If the average opacity of emissions exceeds the applicable standard, then a code
indicating such an exceedance has occurred; and
(5) Percent monitor data availability (recorded to the nearest tenth of a percent), calculated
according to the requirements of the procedure recommended for State Implementation Plans
in appendix M to part 51 of this chapter.
§ 75.57(g) (g) Diluent record provisions. The owner or operator of a unit using a flow monitor and
an 02 diluent monitor to determine heat input, in accordance with Equation F-17 or F-18 of
appendix F to this part, or a unit that accounts for heat input using a flow monitor and a C02
diluent monitor (which is used only for heat input determination and is not used as a C02
pollutant concentration monitor) shall keep the following records for the 02 or C02 diluent
monitor:
(1) Component-system identification code, as provided in § 75.53;
(2) Date and hour;
(3) Hourly average diluent gas (02 or C02) concentration (in percent, rounded to the
nearest tenth);
(4) Percent monitor data availability for the diluent monitor (recorded to the nearest tenth
of a percent), calculated pursuant to § 75.32; and
(5) Method of determination code for diluent gas (02 or C02) concentration data using
Codes 1-55, in Table 4a of this section.
§ 75.57(h) (h) Missing data records. The owner or operator shall record the causes of any missing
data periods and the actions taken by the owner or operator to correct such causes.
§ 75.57(i) (i) Hg emission record provisions (CEMS). The owner or operator shall record for each
hour the information required by this paragraph for each affected unit using Hg CEMS in
combination with flow rate, and (in certain cases) moisture, and diluent gas monitors, to
determine Hg mass emissions and (if applicable) unit heat input under a State or Federal Hg
mass emissions reduction program that adopts the requirements of subpart I of this part.
§ 75.57(i)(l) (1) For Hg concentration during unit operation, as measured and reported from each
certified primary monitor, certified back-up monitor, or other approved method of emissions
determination:
(i) Component-system identification code, as provided in § 75.53;
(ii) Date and hour;
(iii) Hourly Hg concentration (|ig/scm. rounded to the nearest tenth). For a particular pair
of sorbent traps, this will be the flow-proportional average concentration for the data
collection period;
(iv) The bias-adjusted hourly average Hg concentration (|ig/scm. rounded to the nearest
tenth) if a bias adjustment factor is required, as provided in § 75.24(d);
(v) Method of determination for hourly Hg concentration using Codes 1 -55 in Table 4a of
this section; and
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 132
-------
(vi) The percent monitor data availability (to the nearest tenth of a percent), calculated
pursuant to § 75.32.
§ 75.57(i)(2) (2) For flue gas moisture content during unit operation (if required), as measured and
reported from each certified primary monitor, certified back-up monitor, or other approved
method of emissions determination (except where a default moisture value is used in
accordance with § 75.11(b) or approved under § 75.66):
(i) Component-system identification code, as provided in § 75.53;
(ii) Date and hour;
(iii) Hourly average moisture content of flue gas (percent, rounded to the nearest tenth). If
the continuous moisture monitoring system consists of wet- and dry-basis oxygen analyzers,
also record both the wet- and dry-basis oxygen hourly averages (in percent 02, rounded to the
nearest tenth);
(iv) Percent monitor data availability (recorded to the nearest tenth of a percent) for the
moisture monitoring system, calculated pursuant to § 75.32; and
(v) Method of determination for hourly average moisture percentage, using Codes 1 -55 in
Table 4a of this section.
§ 75.57(i)(3) (3) For diluent gas (02 or C02) concentration during unit operation (if required), as
measured and reported from each certified primary monitor, certified back-up monitor, or other
approved method of emissions determination:
(i) Component-system identification code, as provided in § 75.53;
(ii) Date and hour;
(iii) Hourly average diluent gas (02 or C02) concentration (in percent, rounded to the
nearest tenth);
(iv) Method of determination code for diluent gas (02 or C02) concentration data using
Codes 1-55, in Table 4a of this section; and
(v) The percent monitor data availability (to the nearest tenth of a percent) for the 02 or
C02 monitoring system (if a separate 02 or C02 monitoring system is used for heat input
determination), calculated pursuant to § 75.32.
§ 75.57(i)(4) (4) For stack gas volumetric flow rate during unit operation, as measured and reported
from each certified primary monitor, certified back-up monitor, or other approved method of
emissions determination, record the information required under paragraphs (c)(2)(i) through
(c)(2)(vi) of this section.
§ 75.57(i)(5) (5) For Hg mass emissions during unit operation, as measured and reported from the
certified primary monitoring system(s), certified redundant or nonredundant back-up
monitoring system(s), or other approved method(s) of emissions determination:
(i) Date and hour;
(ii) Hourly Hg mass emissions (ounces, rounded to three decimal places);
(iii) Hourly Hg mass emissions (ounces, rounded to three decimal places), adjusted for
bias if a bias adjustment factor is required, as provided in § 75.24(d); and
(iv) Identification code for emissions formula used to derive hourly Hg mass emissions
from Hg concentration, flow rate and moisture data, as provided in § 75.53.
§ 75.57(j) (j) Hg emission record provisions (sorbent trap systems). The owner or operator shall
record for each hour the information required by this paragraph, for each affected unit using
sorbent trap monitoring systems in combination with flow rate, moisture, and (in certain cases)
diluent gas monitors, to determine Hg mass emissions and (if required) unit heat input under a
State or Federal Hg mass emissions reduction program that adopts the requirements of subpart
I of this part.
§ 75.57(j)(l) (1) For Hg concentration during unit operation, as measured and reported from each
certified primary monitor, certified back-up monitor, or other approved method of emissions
determination:
(i) Component-system identification code, as provided in § 75.53;
(ii) Date and hour;
(iii) Hourly Hg concentration (|ig/dscm. rounded to the nearest tenth). For a particular pair
of sorbent traps, this will be the flow-proportional average concentration for the data collection
period;
(iv) The bias-adjusted hourly average Hg concentration (|ig/dscm. rounded to the nearest
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 133
-------
§75.57(j)(2)
§75.57(j)(3)
§75.570X4)
§75.570X5)
§75.570X6)
§75.570X7)
§75.570X8)
§ 75.58
tenth) if a bias adjustment factor is required, as provided in § 75.24(d);
(v) Method of determination for hourly average Hg concentration using Codes 1 -55 in
Table 4a of this section; and
(vi) Percent monitor data availability (recorded to the nearest tenth of a percent),
calculated pursuant to § 75.32;
(2) For flue gas moisture content during unit operation, as measured and reported from
each certified primary monitor, certified back-up monitor, or other approved method of
emissions determination (except where a default moisture value is used in accordance with §
75.11(b) or approved under § 75.66), record the information required under paragraphs
(i)(2)(i) through (i)(2)(v) of this section;
(3) For diluent gas (02 or C02) concentration during unit operation (if required for heat
input determination), record the information required under paragraphs (i)(3)(i) through
(i)(3)(v) of this section.
(4) For stack gas volumetric flow rate during unit operation, as measured and reported
from each certified primary monitor, certified back-up monitor, or other approved method of
emissions determination, record the information required under paragraphs (c)(2)(i) through
(c)(2)(vi) of this section.
(5) For Hg mass emissions during unit operation, as measured and reported from the
certified primary monitoring system(s), certified redundant or nonredundant back-up
monitoring system(s), or other approved method(s) of emissions determination, record the
information required under paragraph (i)(5) of this section.
(6) Record the average flow rate of stack gas through each sorbent trap (in appropriate
units, e.g., liters/min, cc/ min, dscm/min).
(7) Record the gas flow meter reading (in dscm, rounded to the nearest hundredth) at the
beginning and end of the collection period and at least once in each unit operating hour during
the collection period.
(8) Calculate and record the ratio of the bias-adjusted stack gas flow rate to the sample
flow rate, as described in section 11.2 of appendix K to this part.
§ 75.58 General recordkeeping provisions for specific situations.
The owner or operator shall meet all of the applicable recordkeeping requirements of this
section.
§ 75.58(a)
§ 75.58(b)
§ 75.58(b)(1)
(a) [Reserved]
(b) Specific parametric data record provisions for calculating substitute emissions data
for units with add-on emission controls. In accordance with § 75.34, the owner or operator of
an affected unit with add-on emission controls shall either record the applicable information in
paragraph (b)(3) of this section for each hour of missing S02 concentration data or NOx
emission rate (in addition to other information), or shall record the information in paragraph
(b)(1) of this section for S02 or paragraph (b)(2) of this section for NOx through an automated
data acquisition and handling system, as appropriate to the type of add-on emission controls:
(1) For units with add-on S02 emission controls using the optional parametric monitoring
procedures in appendix C to this part, for each hour of missing S02 concentration or volumetric
flow data:
(i) The information required in § 75.57(c) for S02 concentration and volumetric flow, if
either one of these monitors is still operating;
(ii) Date and hour;
(iii) Number of operating scrubber modules;
(iv) Total feedrate of slurry to each operating scrubber module (gal/min);
(v) Pressure differential across each operating scrubber module (inches of water column);
(vi) For a unit with a wet flue gas desulfurization system, an in-line measure of absorber
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 134
-------
pH for each operating scrubber module;
(vii) For a unit with a dry flue gas desulfurization system, the inlet and outlet temperatures
across each operating scrubber module;
(viii) For a unit with a wet flue gas desulfurization system, the percent solids in slurry for
each scrubber module;
(ix) For a unit with a dry flue gas desulfurization system, the slurry feed rate (gal/min) to
the atomizer nozzle;
(x) For a unit with S02 add-on emission controls other than wet or dry limestone,
corresponding parameters approved by the Administrator;
(xi) Method of determination of S02 concentration and volumetric flow using Codes 1-55
in Table 4a of § 75.57; and
(xii) Inlet and outlet S02 concentration values, recorded by an S02 continuous emission
monitoring system, and the removal efficiency of the add-on emission controls.
§ 75.58(b)(2) (2) For units with add-on NOx emission controls using the optional parametric monitoring
procedures in appendix C to this part, for each hour of missing NOx emission rate data:
(i) Date and hour;
(ii) Inlet air flow rate (scfh, rounded to the nearest thousand);
(iii) Excess 02 concentration of flue gas at stack outlet (percent, rounded to the nearest
tenth of a percent);
(iv) Carbon monoxide concentration of flue gas at stack outlet (ppm, rounded to the
nearest tenth);
(v) Temperature of flue gas at furnace exit or economizer outlet duct (°F);
(vi) Other parameters specific to NOx emission controls (e.g., average hourly reagent
feedrate);
(vii) Method of determination of NOx emission rate using Codes 1-55 in Table 4a of
§ 75.57; and
(viii) Inlet and outlet NOx emission rate values recorded by a NOx continuous emission
monitoring system and the removal efficiency of the add-on emission controls.
§ 75.58(b)(3) (3) Except as otherwise provided in §75.34 (d), for units with add-on S02 or NOx emission
controls following the provisions of §75.34(a)(1), (a)(2), (a)(3) or (a)(5), and for units with
add-on Hg emission controls, the owner or operator shall record:
(i) Parametric data which demonstrate, for each hour of missing S02, Hg, or NOx emission
data, the proper operation of the add-on emission controls, as described in the quality
assurance/quality control program for the unit. The parametric data shall be maintained on site
and shall be submitted, upon request, to the Administrator, EPA Regional office, State, or local
agency. Alternatively, for units equipped with flue gas desulfurization (FGD) systems, the
owner or operator may use quality-assured data from a certified S02 monitor to demonstrate
proper operation of the emission controls during periods of missing Hg data;
(ii) A flag indicating, for each hour of missing S02, Hg, or NOx emission data, either that
the add-on emission controls are operating properly, as evidenced by all parameters being
within the ranges specified in the quality assurance/quality control program, or that the add-on
emission controls are not operating properly;
§ 75.58(c) (c) Specific S02 emission record provisions for gas-fired or oil-fired units using optional
protocol in appendix D to this part. In lieu of recording the information in § 75.57(c), the
owner or operator shall record the applicable information in this paragraph for each affected
gas-fired or oil-fired unit for which the owner or operator is using the optional protocol in
appendix D to this part for estimating S02 mass emissions:
§ 75.58(c)(1) (1) For each hour when the unit is combusting oil:
(i) Date and hour;
(ii) Hourly average volumetric flow rate of oil, while the unit combusts oil, with the units
in which oil flow is recorded (gal/hr, scf/hr, m3/hr, or bbl/hr, rounded to the nearest tenth) (flag
value if derived from missing data procedures);
(iii) Sulfur content of oil sample used to determine S02 mass emission rate (rounded to
nearest hundredth for diesel fuel or to the nearest tenth of a percent for other fuel oil) (flag
value if derived from missing data procedures);
(iv) [Reserved];
(v) Mass flow rate of oil combusted each hour and method of determination (lb/hr,
rounded to the nearest tenth) (flag value if derived from missing data procedures);
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 135
-------
(vi) S02 mass emission rate from oil (lb/hr, rounded to the nearest tenth);
(vii) For units using volumetric oil flowmeters, density of oil with the units in which oil
density is recorded and method of determination (flag value if derived from missing data
procedures);
(viii) Gross calorific value of oil used to determine heat input and method of determination
(Btu/lb) (flag value if derived from missing data procedures);
(ix) Hourly heat input rate from oil, according to procedures in appendix D to this part
(mmBtu/hr, to the nearest tenth);
(x) Fuel usage time for combustion of oil during the hour (rounded up to the nearest
fraction of an hour (in equal increments that can range from one hundredth to one quarter of an
hour, at the option of the owner or operator)) (flag to indicate multiple/single fuel types
combusted);
(xi) Monitoring system identification code;
(xii) Operating load range corresponding to gross unit load (01-20);
(xiii) Type of oil combusted; and
(xiv) Heat input formula ID and S02 Formula ID (required beginning January 1, 2009).
§ 75.58(c)(2) (2) For gas-fired units or oil-fired units using the optional protocol in appendix D to this
part for daily manual oil sampling, when the unit is combusting oil, the highest sulfur content
recorded from the most recent 30 daily oil samples (rounded to the nearest tenth of a percent).
§ 75.58(c)(3)
(3) For gas-fired units or oil-fired units using the optional protocol in appendix D to this
part, when either an assumed oil sulfur content or density value is used, or when as-delivered
oil sampling is performed:
(i) Record the measured sulfur content, gross calorific value, and, if applicable, density
from each fuel sample; and
(ii) Record and report the assumed sulfur content, gross calorific value, and, if applicable,
density used to calculate S02 mass emission rate or heat input rate.
§ 75.58(c)(4)
(4) For each hour when the unit is combusting gaseous fuel:
(i) Date and hour.
(ii) Hourly heat input rate from gaseous fuel, according to procedures in appendix F to this
part (mmBtu/hr, rounded to the nearest tenth).
(iii) Sulfur content or S02 emission rate, in one of the following formats, in accordance
with the appropriate procedure from appendix D to this part:
(A) Sulfur content of gas sample and method of determination (rounded to the nearest 0.1
grains/100 scf) (flag value if derived from missing data procedures); or
(B) Default S02 emission rate of 0.0006 lb/mmBtu for pipeline natural gas, or calculated
S02 emission rate for natural gas from section 2.3.2.1.1 of appendix D to this part.
(iv) Hourly flow rate of gaseous fuel, while the unit combusts gas (100 scfh) and source of
data code for gas flow rate.
(v) Gross calorific value of gaseous fuel used to determine heat input rate (Btu/100 scf)
(flag value if derived from missing data procedures).
(vi) S02 mass emission rate due to the combustion of gaseous fuels (lb/hr).
(vii) Fuel usage time for combustion of gaseous fuel during the hour (rounded up to the
nearest fraction of an hour (in equal increments that can range from one hundredth to one
quarter of an hour, at the option of the owner or operator)) (flag to indicate multiple/single fuel
types combusted).
(viii) Monitoring system identification code.
(ix) Operating load range corresponding to gross unit load (01-20).
(x) Type of gas combusted; and
(xi) Heat input formula ID and S02 Formula ID (required beginning January 1, 2009).
§ 75.58(c)(5)
(5) For each oil sample or sample of diesel fuel:
(i) Date of sampling;
(ii) Sulfur content (percent, rounded to either the nearest hundredth, or nearest ten-
thousandth for diesel fuels and to the nearest tenth for other fuel oil);
(iii) Gross calorific value (Btu/lb); and
(iv) Density or specific gravity, if required to convert volume to mass.
§ 75.58(c)(6)
(6) For each sample of gaseous fuel for sulfur content:
(i) Date of sampling; and
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 136
-------
(ii) Sulfur content (grains/100 scf, rounded to the nearest tenth).
§ 75.58(c)(7)
§ 75.58(c)(8)
§ 75.58(d)
§ 75.58(d)(1)
§ 75.58(d)(2)
(7) For each sample of gaseous fuel for gross calorific value:
(i) Date of sampling; and
(ii) Gross calorific value (Btu/100 scf).
(8) For each oil sample or sample of gaseous fuel:
(i) Type of oil or gas; and
(ii) Type of sulfur sampling (using codes in tables D-4 and D-5 of appendix D to this part)
and value used in calculations, and type of GCV or density sampling (using codes in tables D-4
and D-5 of appendix D to this part).
(d) Specific NOx emission record provisions for gas-fired peaking units or oil-fired
peaking units using optional protocol in appendix E to this part. In lieu of recording the
information in § 75.57(d), the owner or operator shall record the applicable information in this
paragraph for each affected gas-fired peaking unit or oil-fired peaking unit for which the owner
or operator is using the optional protocol in appendix E to this part for estimating NOx
emission rate. The owner or operator shall meet the requirements of this section, except that
the requirements under paragraphs (d)(l)(vii) and (d)(2)(vii) of this section shall become
applicable on the date on which the owner or operator is required to monitor, record, and report
NOx mass emissions under an applicable State or federal NOx mass emission reduction
program, if the provisions of subpart H of this part are adopted as requirements under such a
program.
(1) For each hour when the unit is combusting oil:
(1) Date and hour;
(ii) Hourly average mass flow rate of oil while the unit combusts oil with the units in which
oil flow is recorded (lb/hr);
(iii) Gross calorific value of oil used to determine heat input (Btu/lb);
(iv) Hourly average NOx emission rate from combustion of oil (lb/mmBtu, rounded to the
nearest hundredth);
(v) Heat input rate of oil (mmBtu/hr, rounded to the nearest tenth);
(vi) Fuel usage time for combustion of oil during the hour (rounded up to the nearest
fraction of an hour, in equal increments that can range from one hundredth to one quarter of an
hour, at the option of the owner or operator);
(vii) NOx mass emissions, calculated in accordance with section 8.1 of appendix F to this
part;
(viii) NOx monitoring system identification code;
(ix) Fuel flow monitoring system identification code;
(x) Segment identification of the correlation curve; and
(xi) Heat input rate formula ID (required beginning January 1, 2009).
(2) For each hour when the unit is combusting gaseous fuel:
(i) Date and hour;
(ii) Hourly average fuel flow rate of gaseous fuel, while the unit combusts gas (100 scfh);
(iii) Gross calorific value of gaseous fuel used to determine heat input (Btu/100 scf) (flag
value if derived from missing data procedures);
(iv) Hourly average NOx emission rate from combustion of gaseous fuel (lb/mmBtu,
rounded to nearest hundredth);
(v) Heat input rate from gaseous fuel, while the unit combusts gas (mmBtu/hr, rounded to
the nearest tenth);
(vi) Fuel usage time for combustion of gaseous fuel during the hour (rounded up to the
nearest fraction of an hour, in equal increments that can range from one hundredth to one
quarter of an hour, at the option of the owner or operator);
(vii) NOx mass emissions, calculated in accordance with section 8.1 of appendix F to this
part;
(viii) NOx monitoring system identification code;
(ix) Fuel flow monitoring system identification code;
(x) Segment identification of the correlation curve; and
(xi) Heat input rate formula ID (required beginning January 1, 2009).
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 137
-------
§ 75.58(d)(3)
§ 75.58(d)(4)
§ 75.58(d)(5)
§ 75.58(d)(6)
§ 75.58(e)
§ 75.58(e)(1)
§ 75.58(e)(2)
§ 75.58(f)
§ 75.58(f)(1)
(3) For each hour when the unit combusts multiple fuels:
(i) Date and hour;
(ii) Hourly average heat input rate from all fuels (mmBtu/hr, rounded to the nearest tenth);
and
(iii) Hourly average NOx emission rate for the unit for all fuels (lb/mmBtu, rounded to the
nearest hundredth).
(4) For each hour when the unit combusts any fuel(s):
(i) For stationary gas turbines and diesel or dual-fuel reciprocating engines, hourly
averages of operating parameters under section 2.3 of appendix E to this part (flag if value is
outside of manufacturer's recommended range); and
(ii) For boilers, hourly average boiler 02 reading (percent, rounded to the nearest tenth)
(flag if value exceeds by more than 2 percentage points the 02 level recorded at the same heat
input during the previous NOx emission rate test).
(5) For each fuel sample:
(i) Date of sampling;
(ii) Gross calorific value (Btu/lb for oil, Btu/100 scf for gaseous fuel); and
(iii) Density or specific gravity, if required to convert volume to mass.
(6) Flag to indicate multiple or single fuels combusted.
(e) Specific S02 emission record provisions during the combustion of gaseous fuel.
(1) If S02 emissions are determined in accordance with the provisions in § 75.11(e)(2)
during hours in which only gaseous fuel is combusted in a unit with an S02 CEMS, the owner
or operator shall record the information in paragraph (c)(3) of this section in lieu of the
information in §§ 75.57(c)(1), (c)(3), and (c)(4), for those hours.
(2) The provisions of this paragraph apply to a unit which, in accordance with the
provisions of § 75.11(e)(3), uses an S02 CEMS to determine S02 emissions during hours in
which only gaseous fuel is combusted in the unit. If the unit sometimes burns only gaseous fuel
that is very low sulfur fuel (as defined in § 72.2 of this chapter) as a primary and/or backup fuel
and at other times combusts higher sulfur fuels, such as coal or oil, as primary and/or backup
fuel(s), then the owner or operator shall keep records on-site, in a form suitable for inspection,
of the type(s) of fuel(s) burned during each period of missing S02 data and the number of hours
that each type of fuel was combusted in the unit during each missing data period. This
recordkeeping requirement does not apply to an affected unit that burns very low sulfur fuel
exclusively, nor does it apply to a unit that burns such gaseous fuel(s) only during unit startup.
(f) Specific SO 2, NOx, and C02 record provisions for gas-fired or oil-fired units using the
optional low mass emissions excepted methodology in § 75.19. In lieu of recording the
information in §§ 75.57(b) through (e), the owner or operator shall record the following
information for each affected low mass emissions unit for which the owner or operator is using
the optional low mass emissions excepted methodology in § 75.19(c):
(1) All low mass emissions units shall report for each hour:
(i) Date and hour;
(ii) Unit operating time (units using the long term fuel flow methodology report operating
time to be 1);
(iii) Fuel type (pipeline natural gas, natural gas, other gaseous fuel, residual oil, or diesel
fuel). If more than one type of fuel is combusted in the hour, either:
(A) Indicate the fuel type which results in the highest emission factors for NOx (this option
is in effect through December 31, 2008); or(B) Indicate the fuel type resulting in the highest
emission factor for each parameter (S02, NOx emission rate, and C02) separately (this option is
required on and after January 1, 2009);
(iv) Average hourly NOx emission rate (lb/mmBtu, rounded to the nearest thousandth);
(v) Hourly NOx mass emissions (lbs, rounded to the nearest tenth);
(vi) Hourly S02 mass emissions (lbs, rounded to the nearest tenth);
(vii) Hourly C02 mass emissions (tons, rounded to the nearest tenth);
(viii) Hourly calculated unit heat input in mmBtu;
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 138
-------
(ix) Hourly unit output in gross load or steam load;
(x) The method of determining hourly heat input: unit maximum rated heat input, unit
long term fuel flow or group long term fuel flow;
(xi) The method of determining NOx emission rate used for the hour: default based on fuel
combusted, unit specific default based on testing or historical data, group default based on
representative testing of identical units, unit specific based on testing of a unit with NOx
controls operating, or missing data value;
(xii) Control status of the unit;
(xiii) Base or peak load indicator (as applicable); and
(xiv) Multiple fuel flag.
§ 75.58(f)(2)
(2) low mass emissions units using the optional long term fuel flow methodology to
determine unit heat input shall report for each quarter:
(i) Type of fuel;
(ii) Beginning date and hour of long term fuel flow measurement period;
(iii) End date and hour of long term fuel flow period;
(iv) Quantity of fuel measured; (v) Units of measure;
(vi) Fuel GCV value used to calculate heat input;
(vii) Units of GCV;
(viii) Method of determining fuel GCV used;
(ix) Method of determining fuel flow over period;
(x) Monitoring system identification code;
(xi) Quarter and year;
(xii) Total heat input (mmBtu); and
(xiii) Operating hours in period.
§ 75.59
§ 75.59 Certification, quality assurance, and quality control record provisions.
The owner or operator shall meet all of the applicable recordkeeping requirements of this
section.
§ 75.59(a)
(a) Continuous emission or opacity monitoring systems. The owner or operator shall
record the applicable information in this section for each certified monitor or certified
monitoring system (including certified backup monitors) measuring and recording emissions or
flow from an affected unit.
§ 75.59(a)(1)
(1) For each S02 or NOx pollutant concentration monitor, flow monitor, C02 emissions
concentration monitor (including 02 monitors used to determine C02 emissions), Hg monitor,
or diluent gas monitor (including wet- and dry-basis 02 monitors used to determine percent
moisture), the owner or operator shall record the following for all daily and 7-day calibration
error tests, all daily system integrity checks (Hg monitors only), and all off-line calibration
demonstrations, including any follow-up tests after corrective action:
(i) Component-system identification code (on and after January 1, 2009, only the
component identification code is required);
(ii) Instrument span and span scale;
(iii) Date and hour;
(iv) Reference value (i.e., calibration gas concentration or reference signal value, in ppm
or other appropriate units);
(v) Observed value (monitor response during calibration, in ppm or other appropriate
units);
(vi) Percent calibration error (rounded to the nearest tenth of a percent) (flag if using
alternative performance specification for low emitters or differential pressure flow monitors);
(vii) Reference signal or calibration gas level;
(viii) For 7-day calibration error tests, a test number and reason for test;
(ix) For 7-day calibration tests for certification or recertification, a certification from the
cylinder gas vendor or CEMS vendor that calibration gas, as defined in § 72.2 of this chapter
and appendix A to this part, was used to conduct calibration error testing;
(x) Description of any adjustments, corrective actions, or maintenance prior to a passed
test or following a failed test; and
(xi) Indication of whether the unit is off-line or on-line.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 139
-------
§ 75.59(a)(2) (2) For each flow monitor, the owner or operator shall record the following for all daily
interference checks, including any follow-up tests after corrective action:
(i) Component-system identification code (after January 1, 2009, only the component
identification is required);
(ii) Date and hour;
(iii) Code indicating whether monitor passes or fails the interference check; and
(iv) Description of any adjustments, corrective actions, or maintenance prior to a passed
test or following a failed test.
§ 75.59(a)(3) (3) For each S02 or NOx pollutant concentration monitor, C02 emissions concentration
monitor (including 02 monitors used to determine C02 emissions), Hg concentration monitor,
or diluent gas monitor (including wet- and dry-basis 02 monitors used to determine percent
moisture), the owner or operator shall record the following for the initial and all subsequent
linearity check(s) and 3-level system integrity checks (Hg monitors with converters, only),
including any follow-up tests after corrective action.
(i) Component-system identification code (on and after January 1, 2009, only the
component identification code is required);
(ii) Instrument span and span scale (only span scale is required on and after January 1,
2009);
(iii) Calibration gas level;
(iv) Date and time (hour and minute) of each gas injection at each calibration gas level;
(v) Reference value (i.e., reference gas concentration for each gas injection at each
calibration gas level, in ppm or other appropriate units);
(vi) Observed value (monitor response to each reference gas injection at each calibration
gas level, in ppm or other appropriate units);
(vii) Mean of reference values and mean of measured values at each calibration gas level;
(viii) Linearity error at each of the reference gas concentrations (rounded to nearest tenth
of a percent) (flag if using alternative performance specification);
(ix) Test number and reason for test (flag if aborted test); and
(x) Description of any adjustments, corrective action, or maintenance prior to a passed test
or following a failed test.
§ 75.59(a)(4) (4) For each differential pressure type flow monitor, the owner or operator shall record
items in paragraphs (a)(4)(i) through (v) of this section, for all quarterly leak checks, including
any follow-up tests after corrective action. For each flow monitor, the owner or operator shall
record items in paragraphs (a)(4)(vi) and (vii) for all flow-to-load ratio and gross heat rate
tests:
§ 75.59(a)(4)(i) (i) Component-system identification code (on and after January 1, 2009, only the system
identification code is required).
§ 75.59(a)(4)(ii) (ii) Date and hour.
§ 75.59(a)(4)(iii) (iii) Reason for test.
§ 75.59(a)(4)(iv) (iv) Code indicating whether monitor passes or fails the quarterly leak check.
§ 75.59(a)(4)(v) (v) Description of any adjustments, corrective actions, or maintenance prior to a passed
test or following a failed test.
§ 75.59(a)(4)(vi) (vi) Test data from the flow-to-load ratio or gross heat rate (GHR) evaluation, including:
(A) Monitoring system identification code;
(B) Calendar year and quarter;
(C) Indication of whether the test is a flow-to-load ratio or gross heat rate evaluation;
(D) Indication of whether bias adjusted flow rates were used;
(E) Average absolute percent difference between reference ratio (or GHR) and hourly
ratios (or GHR values);
(F) Test result;
(G) Number of hours used in final quarterly average;
(H) Number of hours exempted for use of a different fuel type;
(I) Number of hours exempted for load ramping up or down;
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 140
-------
(J) Number of hours exempted for scrubber bypass;
(K) Number of hours exempted for hours preceding a normal-load flow RATA;
(L) Number of hours exempted for hours preceding a successful diagnostic test, following
a documented monitor repair or major component replacement;
(M) Number of hours excluded for flue gases discharging simultaneously thorough a main
stack and a bypass stack; and
(N) Test number.
§ 75.59(a)(4)(vii) (vii) Reference data for the flow-to-load ratio or gross heat rate evaluation, including (as
applicable):
(A) Reference flow RATA end date and time;
(B) Test number of the reference RATA;
(C) Reference RATA load and load level;
(D) Average reference method flow rate during reference flow RATA;
(E) Reference flow/load ratio;
(F) Average reference method diluent gas concentration during flow RATA and diluent
gas units of measure;
(G) Fuel specific Fd- or Fc-factor during flow RATA and F-factor units of measure; (H)
Reference gross heat rate value;
(I) Monitoring system identification code;
(J) Average hourly heat input rate during RATA;
(K) Average gross unit load;
(L) Operating load level; and
(M) An indicator ("flag") if separate reference ratios are calculated for each multiple stack.
§ 75.59(a)(5) (5) For each S02 pollutant concentration monitor, flow monitor, each C02 emissions
concentration monitor (including any 02 concentration monitor used to determine C02 mass
emissions or heat input), each NOx-diluent continuous emission monitoring system, each S02-
diluent continuous emission monitoring system, each NOx concentration monitoring system,
each diluent gas (02 or C02) monitor used to determine heat input, each moisture monitoring
system, each Hg concentration monitoring system, each sorbent trap monitoring system, and
each approved alternative monitoring system, the owner or operator shall record the following
information for the initial and all subsequent relative accuracy test audits:
§ 75.59(a)(5)(i) (i) Reference method(s) used.
§ 75.59(a)(5)(ii) (ii) Individual test run data from the relative accuracy test audit for the S02 concentration
monitor, flow monitor, C02 emissions concentration monitor, NOx-diluent continuous emission
monitoring system, S02-diluent continuous emission monitoring system, diluent gas (02 or
C02) monitor used to determine heat input, NOx concentration monitoring system, moisture
monitoring system, Hg concentration monitoring system, sorbent trap monitoring system, or
approved alternative monitoring system, including:
(A) Date, hour, and minute of beginning of test run;
(B) Date, hour, and minute of end of test run;
(C) Monitoring system identification code;
(D) Test number and reason for test;
(E) Operating level (low, mid, high, or normal, as appropriate) and number of operating
levels comprising test;
(F) Normal load (or operating level) indicator for flow RAT As (except for peaking units);
(G) Units of measure;
(H) Run number;
(I) Run value from CEMS being tested, in the appropriate units of measure;
(J) Run value from reference method, in the appropriate units of measure;
(K) Flag value (0, 1, or 9, as appropriate) indicating whether run has been used in
calculating relative accuracy and bias values or whether the test was aborted prior to
completion;
(L) Average gross unit load, expressed as a total gross unit load, rounded to the nearest
MWe, or as steam load, rounded to the nearest thousand lb/hr), except for units that do not
produce electrical or thermal output; and
(M) Flag to indicate whether an alternative performance specification has been used.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 141
-------
§ 75.59(a)(5)(iii) (iii) Calculations and tabulated results, as follows:
(A) Arithmetic mean of the monitoring system measurement values, of the reference
method values, and of their differences, as specified in Equation A-7 in appendix A to this part;
(B) Standard deviation, as specified in Equation A-8 in appendix A to this part;
(C) Confidence coefficient, as specified in Equation A-9 in appendix A to this part;
(D) Statistical "t" value used in calculations;
(E) Relative accuracy test results, as specified in Equation A-10 in appendix A to this part.
For multi-level flow monitor tests the relative accuracy test results shall be recorded at each
load (or operating) level tested. Each load (or operating) level shall be expressed as a total
gross unit load, rounded to the nearest MWe, or as steam load, rounded to the nearest thousand
lb/hr, or as otherwise specified by the Administrator, for units that do not produce electrical or
thermal output;
(F) Bias test results as specified in section 7.6.4 in appendix A to this part; and
(G) Bias adjustment factor from Equation A-12 in appendix A to this part for any
monitoring system that failed the bias test (except as otherwise provided in section 7.6.5 of
appendix A to this part) and 1.000 for any monitoring system that passed the bias test.
§ 75.59(a)(5)(iv) (iv) Description of any adjustment, corrective action, or maintenance prior to a passed test
or following a failed or aborted test.
§ 75.59(a)(5)(v) (v) F-factor value(s) used to convert NOx pollutant concentration and diluent gas (02 or
C02) concentration measurements into NOx emission rates (in lb/mmBtu), heat input or C02
emissions.
§ 75.59(a)(5)(vi) (vi) For flow monitors, the equation used to linearize the flow monitor and the numerical
values of the polynomial coefficients or K factor(s) of that equation.
§ 75.59(a)(5)(vii) (vii) For moisture monitoring systems, the coefficient or "K" factor or other mathematical
algorithm used to adjust the monitoring system with respect to the reference method.
§ 75.59(a)(6) (6) For each S02, NOx, Hg, or C02 concentration monitor, each component of a NOx-
diluent continuous emission monitoring system, and each C02 or 02 monitor used to determine
heat input, the owner or operator shall record the following information for the cycle time test:
(i) Component-system identification code (on and after January 1, 2009, only the
component identification code is required);
(ii) Date;
(iii) Start and end times;
(iv) Upscale and downscale cycle times for each component;
(v) Stable start monitor value;
(vi) Stable end monitor value;
(vii) Reference value of calibration gas(es);
(viii) Calibration gas level;
(ix) Total cycle time;
(x) Reason for test; and
(xi) Test number.
§ 75.59(a)(7) (7) In addition to the information in paragraph (a)(5) of this section, the owner or operator
shall record, for each relative accuracy test audit, supporting information sufficient to
substantiate compliance with all applicable sections and appendices in this part. Unless
otherwise specified in this part or in an applicable test method, the information in paragraphs
(a)(7)(i) through (a)(7)(vi) of this section may be recorded either in hard copy format,
electronic format or a combination of the two, and the owner or operator shall maintain this
information in a format suitable for inspection and audit purposes. This RATA supporting
information shall include, but shall not be limited to, the following data elements:
§ 75.59(a)(7)(i) (i) For each RATA using Reference Method 2 (or its allowable alternatives) in appendix A
to part 60 of this chapter to determine volumetric flow rate:
(A) Information indicating whether or not the location meets requirements of Method 1 in
appendix A to part 60 of this chapter; and
(B) Information indicating whether or not the equipment passed the required leak checks.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 142
-------
§ 75.59(a)(7)(ii) (ii) For each run of each RATA using Reference Method 2 (or its allowable alternatives in
appendix A to part 60 of this chapter) to determine volumetric flow rate, record the following
data elements (as applicable to the measurement method used):
(A) Operating level (low, mid, high, or normal, as appropriate);
(B) Number of reference method traverse points;
(C) Average stack gas temperature (°F);
(D) Barometric pressure at test port (inches of mercury);
(E) Stack static pressure (inches of H20);
(F) Absolute stack gas pressure (inches of mercury);
(G) Percent C02 and 02 in the stack gas, dry basis;
(H) C02 and 02 reference method used;
(I) Moisture content of stack gas (percent H20);
(J) Molecular weight of stack gas, dry basis (lb/lb-mole);
(K) Molecular weight of stack gas, wet basis (lb/lb-mole);
(L) Stack diameter (or equivalent diameter) at the test port (ft);
(M) Average square root of velocity head of stack gas (inches of H20) for the run;
(N) Stack or duct cross-sectional area at test port (ft2);
(0) Average velocity (ft/sec);
(P) Average stack flow rate, adjusted, if applicable, for wall effects (scfh, wet basis);
(Q) Flow rate reference method used;
(R) Average velocity, adjusted for wall effects;
(S) Calculated (site-specific) wall effects adjustment factor determined during the run, and,
if different, the wall effects adjustment factor used in the calculations; and
(T) Default wall effects adjustment factor used.
§ 75.59(a)(7)(iii) (iii) For each traverse point of each run of each RATA using Reference Method 2 (or its
allowable alternatives in appendix A to part 60 of this chapter) to determine volumetric flow
rate, record the following data elements (as applicable to the measurement method used):
(A) Reference method probe type;
(B) Pressure measurement device type;
(C) Traverse point ID;
(D) Probe or pitot tube calibration coefficient;
(E) Date of latest probe or pitot tube calibration;
(F) Average velocity differential pressure at traverse point (inches of H20) or the average
of the square roots of the velocity differential pressures at the traverse point ((inches of
H20)12);
(G) Ts, stack temperature at the traverse point (°F);
(H) Composite (wall effects) traverse point identifier;
(1) Number of points included in composite traverse point;
(J) Yaw angle of flow at traverse point (degrees);
(K) Pitch angle of flow at traverse point (degrees);
(L) Calculated velocity at traverse point both accounting and not accounting for wall
effects (ft/sec); and
(M) Probe identification number.
§ 75.59(a)(7)(iv) (iv) For each RATA using Method 6C, 7E, or 3 A in appendix A to part 60 of this chapter
to determine S02, NOx, C02, or 02 concentration:
(A) Pollutant or diluent gas being measured;
(B) Span of reference method analyzer;
(C) Type of reference method system (e.g., extractive or dilution type);
(D) Reference method dilution factor (dilution type systems, only);
(E) Reference gas concentrations (zero, mid, and high gas levels) used for the 3-point pre-
test analyzer calibration error test (or, for dilution type reference method systems, for the 3-
point pre-test system calibration error test) and for any subsequent recalibrations;
(F) Analyzer responses to the zero-, mid-, and high-level calibration gases during the 3-
point pre-test analyzer (or system) calibration error test and during any subsequent
recalibration(s);
(G) Analyzer calibration error at each gas level (zero, mid, and high) for the 3-point pre-
test analyzer (or system) calibration error test and for any subsequent recalibration(s) (percent
of span value);
(H) Upscale gas concentration (mid or high gas level) used for each pre-run or post-run
system bias check or (for dilution type reference method systems) for each pre -run or post-run
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 143
-------
system calibration error check;
(I) Analyzer response to the calibration gas for each pre-run or post-run system bias (or
system calibration error) check;
(J) The arithmetic average of the analyzer responses to the zero-level gas, for each pair of
pre- and post-run system bias (or system calibration error) checks;
(K) The arithmetic average of the analyzer responses to the upscale calibration gas, for
each pair of pre- and post-run system bias (or system calibration error) checks;
(L) The results of each pre-run and each post- run system bias (or system calibration error)
check using the zero-level gas (percentage of span value);
(M) The results of each pre-run and each post-run system bias (or system calibration error)
check using the upscale calibration gas (percentage of span value);
(N) Calibration drift and zero drift of analyzer during each RATA run (percentage of span
value);
(0) Moisture basis of the reference method analysis;
(P) Moisture content of stack gas, in percent, during each test run (if needed to convert to
moisture basis of CEMS being tested);
(Q) Unadjusted (raw) average pollutant or diluent gas concentration for each run;
(R) Average pollutant or diluent gas concentration for each run, corrected for calibration
bias (or calibration error) and, if applicable, corrected for moisture;
(S) The F-factor used to convert reference method data to units of lb/mmBtu (if
applicable);
(T) Date(s) of the latest analyzer interference test(s);
(U) Results of the latest analyzer interference test(s);
(V) Date of the latest N02 to NO conversion test (Method 7E only);
(W) Results of the latest N02 to NO conversion test (Method 7E only); and
(X) For each calibration gas cylinder used during each RATA, record the cylinder gas
vendor, cylinder number, expiration date, pollutant(s) in the cylinder, and certified gas
concentration(s).
§ 75.59(a)(7)(v) (v) For each test run of each moisture determination using Method 4 in appendix A to part
60 of this chapter (or its allowable alternatives), whether the determination is made to support a
gas RATA, to support a flow RATA, or to quality assure the data from a continuous moisture
monitoring system, record the following data elements (as applicable to the moisture
measurement method used):
(A) Test number;
(B) Run number;
(C) The beginning date, hour, and minute of the run;
(D) The ending date, hour, and minute of the run;
(E) Unit operating level (low, mid, high, or normal, as appropriate);
(F) Moisture measurement method;
(G) Volume of H20 collected in the impingers (ml);
(H) Mass of H20 collected in the silica gel (g);
(1) Dry gas meter calibration factor;
(J) Average dry gas meter temperature (°F);
(K) Barometric pressure (inches of mercury);
(L) Differential pressure across the orifice meter (inches of H20);
(M) Initial and final dry gas meter readings (ft3);
(N) Total sample gas volume, corrected to standard conditions (dscf); and
(O) Percentage of moisture in the stack gas (percent H20).
§ 75.59(a)(7)(vi) (vi) The raw data and calculated results for any stratification tests performed in accordance
with sections 6.5.6.1 through 6.5.6.3 of appendix A to this part.
§ 75.59(a)(7)(vii) (vii) For each RATA run using the Ontario Hydro Method to determine Hg concentration:
(A) Percent C02 and 02 in the stack gas, dry basis;
(B) Moisture content of the stack gas (percent H20);
(C) Average stack temperature (°F);
(D) Dry gas volume metered (dscm);
(E) Percent isokinetic;
(F) Particle-bound Hg collected by the filter, blank, and probe rinse (|ig):
(G) Oxidized Hg collected by the KC1 impingers (|ig):
(H) Elemental Hg collected in the HN03/H202 impinger and in the KMn04/H2S04
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 144
-------
impingers (|ig):
(I) Total Hg, including particle-bound Hg (|ig): and
(J) Total Hg, excluding particle-bound Hg (|ig)
§ 75.59(a)(7)(viii) (viii) Data elements for Methods 30A and 30B. [Reserved]
§ 75.59(a)(7)(ix) (ix) For a unit with a flow monitor installed on a rectangular stack or duct, if a site- specific
default or measured wall effects adjustment factor (WAF) is used to correct the stack gas
volumetric flow rate data to account for velocity decay near the stack or duct wall, the owner or
operator shall keep records of the following for each flow RATA performed with EPA Method
2 in appendices A-l and A-2 of this chapter, subsequent to the WAF determination:
(A) Monitoring system ID;
(B) Test number;
(C) Operating level;
(D) RATA end date and time;
(E) Number of Method 1 traverse points; and
(F) Wall effects adjustment factor (WAF), to the nearest 0.0001.
§ 75.59(a)(7)(x) (x) For each RATA run using Method 29 in appendix A-8 to part 60 of this chapter to
determine Hg concentration:
(A) Percent C02 and 02 in the stack gas, dry basis;
(B) Moisture content of the stack gas (percent H20);
(C) Average stack gas temperature (°F);
(D) Dry gas volume metered (dscm);
(E) Percent isokinetic;
(F) Particulate Hg collected in the front half of the sampling train, corrected for the front-
half blank value (|ig): and
(G) Total vapor phase Hg collected in the back half of the sampling train, corrected for the
back-half blank value (|ig).
§ 75.59(a)(8) (8) For each certified continuous emission monitoring system, continuous opacity
monitoring system, excepted monitoring system, or alternative monitoring system, the date and
description of each event which requires certification, recertification, or certain diagnostic
testing of the system and the date and type of each test performed. If the conditional data
validation procedures of §75.20(b)(3) are to be used to validate and report data prior to the
completion of the required certification, recertification, or diagnostic testing, the date and hour
of the probationary calibration error test shall be reported to mark the beginning of conditional
data validation.
§ 75.59(a)(9) (9) When hardcopy relative accuracy test reports, certification reports, recertification
reports, or semiannual or annual reports for gas or flow rate CEMS, Hg CEMS, or sorbent trap
monitoring systems are required or requested under § 75.60(b)(6) or § 75.63, the reports shall
include, at a minimum, the following elements (as applicable to the type(s) of test(s)
performed):
§ 75.59(a)(9)(i) (i) Summarized test results.
§ 75.59(a)(9)(ii) (ii) DAHS printouts of the CEMS data generated during the calibration error, linearity,
cycle time, and relative accuracy tests.
§ 75.59(a)(9)(iii) (iii) For pollutant concentration monitor or diluent monitor relative accuracy tests at
normal operating load:
(A) The raw reference method data from each run, i.e., the data under paragraph
(a)(7)(iv)(Q) of this section (usually in the form of a computerized printout, showing a series of
one-minute readings and the run average);
(B) The raw data and results for all required pre-test, post-test, pre-run and post-run
quality assurance checks (i.e., calibration gas injections) of the reference method analyzers, i.e.,
the data under paragraphs (a)(7)(iv)(E) through (a)(7)(iv)(N) of this section;
(C) The raw data and results for any moisture measurements made during the relative
accuracy testing, i.e., the data under paragraphs (a)(7)(v)(A) through (a)(7)(v)(0) of this
section; and
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 145
-------
§ 75.59(a)(9)(iv)
§ 75.59(a)(9)(v)
§ 75.59(a)(9)(vi)
§ 75.59(a)(9)(vii)
§ 75.59(a)(9)(viii)
§ 75.59(a)(9)(ix)
§ 75.59(a)(10)
§ 75.59(a)(10)(i)
§ 75.59(a)(10)(ii)
(D) Tabulated, final, corrected reference method run data (i.e., the actual values used in
the relative accuracy calculations), along with the equations used to convert the raw data to the
final values and example calculations to demonstrate how the test data were reduced.
(iv) For relative accuracy tests for flow monitors:
(A) The raw flow rate reference method data, from Reference Method 2 (or its allowable
alternatives) under appendix A to part 60 of this chapter, including auxiliary moisture data
(often in the form of handwritten data sheets), i.e., the data under paragraphs (a)(7)(ii)(A)
through (a)(7)(ii)(T), paragraphs (a)(7)(iii)(A) through (a)(7)(iii)(M), and, if applicable,
paragraphs (a)(7)(v)(A) through (a)(7)(v)(0) of this section; and
(B) The tabulated, final volumetric flow rate values used in the relative accuracy
calculations (determined from the flow rate reference method data and other necessary
measurements, such as moisture, stack temperature and pressure), along with the equations
used to convert the raw data to the final values and example calculations to demonstrate how
the test data were reduced.
(v) Calibration gas certificates for the gases used in the linearity, calibration error, and
cycle time tests and for the calibration gases used to quality assure the gas monitor reference
method data during the relative accuracy test audit.
(vi) Laboratory calibrations of the source sampling equipment. For sorbent trap
monitoring systems, the laboratory analyses of all sorbent traps, and information documenting
the results of all leak checks and other applicable quality control procedures.
(vii) A copy of the test protocol used for the CEMS certifications or recertifications,
including narrative that explains any testing abnormalities, problematic sampling, and
analytical conditions that required a change to the test protocol, and/or solutions to technical
problems encountered during the testing program.
(viii) Diagrams illustrating test locations and sample point locations (to verify that
locations are consistent with information in the monitoring plan). Include a discussion of any
special traversing or measurement scheme. The discussion shall also confirm that sample
points satisfy applicable acceptance criteria.
(ix) Names of key personnel involved in the test program, including test team members,
plant contacts, agency representatives and test observers on site.
(10) Whenever reference methods are used as backup monitoring systems pursuant to
§ 75.20(d)(3), the owner or operator shall record the following information:
(i) For each test run using Reference Method 2 (or its allowable alternatives in appendix A
to part 60 of this chapter) to determine volumetric flow rate, record the following data elements
(as applicable to the measurement method used):
(A) Unit or stack identification number;
(B) Reference method system and component identification numbers;
(C) Run date and hour;
(D) The data in paragraph (a)(7)(ii) of this section, except for paragraphs (a)(7)(ii)(A), (F),
(H), (L) and (Q) through (T); and
(E) The data in paragraph (a)(7)(iii), except on a run basis.
(11) For each reference method test run using Method 6C, 7E, or 3 A in appendix A to part
60 of this chapter to determine S02, NOx, C02, or 02 concentration:
(A) Unit or stack identification number;
(B) The reference method system and component identification numbers;
(C) Run number;
(D) Run start date and hour;
(E) Run end date and hour;
(F) The data in paragraphs (a)(7)(iv)(B) through (I) and (L) through (O); and
(G) Stack gas density adjustment factor (if applicable).
§ 75.59(a)(10)(iii)
(iii) For each hour of each reference method test run using Method 6C, 7E, or 3 A in
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 146
-------
appendix A to part 60 of this chapter to determine S02, NOx, C02, or 02 concentration:
(A) Unit or stack identification number;
(B) The reference method system and component identification numbers;
(C) Run number;
(D) Run date and hour;
(E) Pollutant or diluent gas being measured;
(F) Unadjusted (raw) average pollutant or diluent gas concentration for the hour; and
(G) Average pollutant or diluent gas concentration for the hour, adjusted as appropriate for
moisture, calibration bias (or calibration error) and stack gas density.
§ 75.59(a)(l 1) (11) For each other quality-assurance test or other quality assurance activity, the owner or
operator shall record the following (as applicable):
(i) Component/system identification code;
(ii) Parameter;
(iii) Test or activity completion date and hour;
(iv) Test or activity description;
(v) Test result;
(vi) Reason for test; and
(vii) Test code.
§ 75.59(a)(12) (12) For each request for a quality assurance test extension or exemption, for any loss of
exempt status, and for each single-load flow RATA claim pursuant to section 2.3.1.3(c)(3) of
appendix B to this part, the owner or operator shall record the following (as applicable):
(i) For a RATA deadline extension or exemption request:
(A) Monitoring system identification code;
(B) Date of last RATA;
(C) RATA expiration date without extension;
(D) RATA expiration date with extension;
(E) Type of RATA extension of exemption claimed or lost;
(F) Year to date hours of usage of fuel other than very low sulfur fuel;
(G) Year to date hours of non-redundant back-up CEMS usage at the unit/stack; and
(H) Quarter and year.
(ii) For a linearity test or flow-to-load ratio test quarterly exemption:
(A) Component-system identification code;
(B) Type of test;
(C) Basis for exemption;
(D) Quarter and year; and (E) Span scale.
[Reserved]
(iv) For a fuel flowmeter accuracy test extension:
(A) Component-system identification code;
(B) Date of last accuracy test;
(C) Accuracy test expiration date without extension;
(D) Accuracy test expiration date with extension;
(E) Type of extension; and
(F) Quarter and year.
(v) For a single-load (or single-level) flow RATA claim:
(A) Monitoring system identification code;
(B) Ending date of last annual flow RATA;
(C) The relative frequency (percentage) of unit or stack operation at each load (or
operating) level (low, mid, and high) since the previous annual flow RATA, to the nearest 0.1
percent;
(D) End date of the historical load (or operating level) data collection period; and
(E) Indication of the load (or operating) level (low, mid or high) claimed for the single-
load flow RATA.
§ 75.59(a)(13) (13) An indication that data have been excluded from a periodic span and range evaluation
§ 75.59(a)(12)(i)
§ 75.59(a)(12)(ii)
§ 75.59(a)(12)(iii)
§ 75.59(a)(12)(iv)
§ 75.59(a)(12)(v)
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 147
-------
of an S02 or NOx monitor under section 2.1.1.5 or 2.1.2.5 of appendix A to this part and the
reason(s) for excluding the data. For purposes of reporting under § 75.64(a), this information
shall be reported with the quarterly report as descriptive text consistent with § 75.64(g).
§ 75.59(a)(14) (14) For the sorbent traps used in sorbent trap monitoring systems to quantify Hg
concentration under subpart I of this part (including sorbent traps used for relative accuracy
testing), the owner or operator shall keep records of the following:
(i) The ID number of the monitoring system in which each sorbent trap was used to collect
Hg;
(ii) The unique identification number of each sorbent trap;
(iii) The beginning and ending dates and hours of the data collection period for each
sorbent trap;
(iv) The average Hg concentration (in (ig/dscm) for the data collection period;
(v) Information documenting the results of the required leak checks;
(vi) The analysis of the Hg collected by each sorbent trap; and
(vii) Information documenting the results of the other applicable quality control
procedures in § 75.15 and in appendices B and K to this part.
§ 75.59(b) (b) Excepted monitoring systems for gas-fired and oil-fired units. The owner or operator
shall record the applicable information in this section for each excepted monitoring system
following the requirements of appendix D to this part or appendix E to this part for determining
and recording emissions from an affected unit.
§ 75.59(b)(1) (1) For certification and quality assurance testing of fuel flowmeters tested against a
reference fuel flow rate (i.e., flow rate from another fuel flowmeter under section 2.1.5.2 of
appendix D to this part or flow rate from a procedure according to a standard incorporated by
reference under section 2.1.5.1 of appendix D to this part):
(i) Unit or common pipe header identification code;
(ii) Component and system identification codes of the fuel flowmeter being tested (on and
after January 1, 2009, only the component identification code is required);
(iii) Date and hour of test completion, for a test performed in-line at the unit;
(iv) Date and hour of flowmeter reinstallation, for laboratory tests;
(v) Test number;
(vi) Upper range value of the fuel flowmeter;
(vii) Flowmeter measurements during accuracy test (and mean of values), including units
of measure;
(viii) Reference flow rates during accuracy test (and mean of values), including units of
measure;
(ix) Level of fuel flowrate test during runs (low, mid or high);
(x) Average flowmeter accuracy for low and high fuel flowrates and highest flowmeter
accuracy of any level designated as mid, expressed as a percent of upper range value;
(xi) Indicator of whether test method was a lab comparison to reference meter or an in-line
comparison against a master meter;
(xii) Test result (aborted, pass, or fail); and
(xiii) Description of fuel flowmeter calibration specification or procedure (in the
certification application, or periodically if a different method is used for annual quality
assurance testing).
§ 75.59(b)(2) (2) For each transmitter or transducer accuracy test for an orifice-, nozzle-, or venturi-type
flowmeter used under section 2.1.6 of appendix D to this part:
(i) Component and system identification codes of the fuel flowmeter being tested (on and
after January 1, 2009, only the component identification code is required);
(ii) Completion date and hour of test;
(iii) For each transmitter or transducer: transmitter or transducer type (differential
pressure, static pressure, or temperature); the full-scale value of the transmitter or transducer,
transmitter input (pre-calibration) prior to accuracy test, including units of measure; and
expected transmitter output during accuracy test (reference value from NIST-traceable
equipment), including units of measure;
(iv) For each transmitter or transducer tested: output during accuracy test, including units
of measure; transmitter or transducer accuracy as a percent of the full-scale value; and
transmitter output level as a percent of the full-scale value;
(v) Average flowmeter accuracy at low and high level fuel flowrates and highest flowmeter
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 148
-------
accuracy of any level designated as mid fuel flowrate, expressed as a percent of upper range
value;
(vi) Test result (pass, fail, or aborted);
(vii) Test number; and
(viii) Accuracy determination methodology.
§ 75.59(b)(3) (3) For each visual inspection of the primary element or transmitter or transducer accuracy
test for an orifice-, nozzle-, or venturi-type flowmeter under sections 2.1.6.1 through 2.1.6.4 of
appendix D to this part:
(i) Date of inspection/test;
(ii) Hour of completion of inspection/test;
(iii) Component and system identification codes of the fuel flowmeter being
inspected/tested; and
(iv) Results of inspection/test (pass or fail).
§ 75.59(b)(4) (4) For fuel flowmeters that are tested using the optional fuel flow-to-load ratio procedures
of section 2.1.7 of appendix D to this part:
§ 75.59(b)(4)(i) (i) Test data for the fuel flowmeter flow-to-load ratio or gross heat rate check, including:
(A) Component/system identification code (on and after January 1, 2009, only the
monitoring system identification code is required);
(B) Calendar year and quarter;
(C) Indication of whether the test is for fuel flow-to-load ratio or gross heat rate;
(D) Quarterly average absolute percent difference between baseline for fuel flow-to-load
ratio (or baseline gross heat rate and hourly quarterly fuel flow-to-load ratios (or gross heat rate
value);
(E) Test result;
(F) Number of hours used in the analysis;
(G) Number of hours excluded due to co-firing;
(H) Number of hours excluded due to ramping;
(I) Number of hours excluded in lower 25.0 percent range of operation; and
(J) Test number.
§ 75.59(b)(4)(ii) (ii) Reference data for the fuel flowmeter flow-to-load ratio or gross heat rate evaluation,
including:
(A) Completion date and hour of most recent primary element inspection or test number of
the most recent primary element inspection (as applicable); (on and after January 1, 2009, the
test number of the most recent primary element inspection is required in lieu of the completion
date and hour for the most recent primary element inspection);
(B) Completion date and hour of most recent flowmeter or transmitter accuracy test or test
number of the most recent flowmeter or transmitter accuracy test (as applicable); (on and after
January 1, 2009, the test number of the most recent flowmeter or transmitter accuracy test is
required in lieu of the completion date and hour for the most recent flowmeter or transmitter
accuracy test);
(C) Beginning date and hour of baseline period;
(D) Completion date and hour of baseline period;
(E) Average fuel flow rate, in 100 scfh for gas and lb/hr for oil;
(F) Average load, in megawatts, 1000 lb/hr of steam, or mmBtu/hr thermal output;
(G) Baseline fuel flow-to-load ratio, in the appropriate units of measure (if using fuel flow-
to-load ratio);
(H) Baseline gross heat rate if using gross heat rate, in the appropriate units of measure (if
using gross heat rate check);
(I) Number of hours excluded from baseline data due to ramping;
(J) Number of hours excluded from baseline data in lower 25.0 percent of range of
operation;
(K) Average hourly heat input rate;
(L) Flag indicating baseline data collection is in progress and that fewer than four calendar
quarters have elapsed since the quarter of the last flowmeter QA test;
(M) Number of hours excluded due to co-firing; and
(N) Monitoring system identification code.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 149
-------
§ 75.59(b)(5)
(5) For gas-fired peaking units or oil-fired peaking units using the optional procedures of
appendix E to this part, for each initial performance, periodic, or quality assurance/quality
control-related test:
§ 75.59(b)(5)(i) (i) For each run of emission data, record the following data:
(A) Unit or common pipe identification code;
(B) Monitoring system identification code for appendix E system (on and after January 1,
2009, component identification codes shall be reported in addition to the monitoring system
identification code);
(C) Run start date and time;
(D) Run end date and time;
(E) Total heat input during the run (mmBtu);
(F) NOx emission rate (lb/mmBtu) from reference method;
(G) Response time of the 02 and NOx reference method analyzers;
(H) Type of fuel(s) combusted during the run; this requirement remains in effect through
December 31, 2008
(I) Heat input rate (mmBtu/hr) during the run;
(J) Test number;
(K) Run number;
(L) Operating level during the run;
(M) NOx concentration recorded by the reference method during the run;
(N) Diluent concentration recorded by the reference method during the run;
(0) Moisture measurement for the run (if applicable).
§ 75.59(b)(5)(ii) (ii) For each run during which oil or mixed fuels are combusted record the following data:
(A) Unit or common pipe identification code;
(B) Monitoring system identification code for oil monitoring system (on and after January
1, 2009, component identification codes shall be reported in addition to the monitoring system
identification code);
(C) Run start date and time;
(D) Run end date and time;
(E) Mass flow or volumetric flow of oil, in the units of measure for the type of fuel
flowmeter;
(F) Gross calorific value of oil in the appropriate units of measure;
(G) Density of fuel oil in the appropriate units of measure (if density is used to convert oil
volume to mass);
(H) Hourly heat input (mmBtu) during run from oil;
(1) Test number;
(J) Run number; and
(K) Operating level during the run.
§ 75.59(b)(5)(iii) (iii) For each run during which gas or mixed fuels are combusted record the following
data:
(A) Unit or common pipe identification code;
(B) Monitoring system identification code for gas monitoring system (on and after January
1, 2009, component identification codes shall be reported in addition to the monitoring system
identification code);
(C) Run start date and time;
(D) Run end date and time;
(E) Volumetric flow of gas (100 scf);
(F) Gross calorific value of gas (Btu/100 scf);
(G) Hourly heat input (mmBtu) during run from gas;
(H) Test number;
(I) Run number; and
(J) Operating level during the run.
§ 75.59(b)(5)(iv) (iv) For each operating level at which runs were performed:
(A) Completion date and time of last run for operating level (as applicable). This
requirement remains in effect through December 31, 2008;
(B) Type of fuel(s) combusted during test;
(C) Average heat input rate at that operating level (mmBtu/hr);
(D) Arithmetic mean of NOx emission rates from reference method run at this level;
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 150
-------
(E) F-factor used in calculations of NOx emission rate at that operating level;
(F) Unit operating parametric data related to NOx formation for that unit type (e.g., excess
02 level, water/fuel ratio);
(G) Test number;
(H) Operating level for runs; and
(I) Component identification code (required on and after January 1, 2009).
§ 75.59(c) (c) Except as otherwise provided in § 75.58(b)(3)(i), units with add-on S02 or NOx
emission controls following the provisions of § 75.34(a)(1) or (a)(2), and for units with add-on
Hg emission controls, the owner or operator shall keep the following records on-site in the
quality assurance/quality control plan required by section 1 of appendix B to this part:
(1) A list of operating parameters for the add-on emission controls, including parameters in
§ 75.58(b), appropriate to the particular installation of add-on emission controls; and
(2) The range of each operating parameter in the list that indicates the add-on emission
controls are properly operating.
§ 75.59(d) (d) Excepted monitoring for low mass emissions units under § 75.19(c)(l)(iv). For oil-
and gas-fired units using the optional S02, NOx and C02 emissions calculations for low mass
emissions units under § 75.19, the owner or operator shall record the following information for
tests performed to determine a fuel and unit-specific default as provided in § 75.19(c)(l)(iv):
§ 75.59(d)(1) (1) For each run of each test performed using the procedures of section 2.1 of appendix E
to this part, record the following data:
(i) Unit or common pipe identification code;
(ii) Run start date and time;
(iii) Run end date and time;
(iv) NOx emission rate (lb/mmBtu) from reference method;
(v) Response time of the 02 and NOx reference method analyzers;
(vi) Type of fuel(s) combusted during the run;
(vii) Test number;
(viii) Run number;
(ix) Operating level during the run;
(x) NOx concentration recorded by the reference method during the run;
(xi) Diluent concentration recorded by the reference method during the run;
(xii) Moisture measurement for the run (if applicable); and
(xiii) An indicator ("flag") if the run is used to calculate the highest 3-run average NOx
emission rate at any load level.
§ 75.59(d)(2) (2) For each single-load or multiple-load appendix E test, record the following:
(i) The three-run average NOx emission rate for each load level;
(ii) An indicator that the average NOx emission rate is the highest NOx average emission
rate recorded at any load level of the test (if appropriate);
(iii) The default NOx emission rate (highest three-run average NOx emission rate at any
load level);
(iv) An indicator that the add-on NOx emission controls were operating or not operating
during each run of the test;
(v) Parameter data indicating the use and efficacy of control equipment during the test;
(vi) Indicator of whether the testing was done at base load, peak load or both (if
appropriate); and
(vii) The default NOx emission rate for peak load hours (if applicable).
§ 75.59(d)(3) (3) For each unit in a group of identical units qualifying for reduced testing under
§ 75.19(c)(l)(iv)(B), record the following data:
(i) The unique group identification code assigned to the group. This code must include the
ORIS code of one of the units in the group;
(ii) The ORIS code or facility identification code for the unit;
(iii) The plant name of the facility at which the unit is located, consistent with the facility's
monitoring plan;
(iv) The identification code for the unit, consistent with the facility's monitoring plan;
(v) A record of whether or not the unit underwent fuel and unit-specific testing for
purposes of establishing a fuel and unit-specific NOx emission rate for purposes of § 75.19;
(vi) The completion date of the fuel and unit-specific test performed for purposes of
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 151
-------
§ 75.59(e)
§ 75.59(f)
§ 75.60
§ 75.60(a)
§ 75.60(b)
establishing a fuel and unit-specific NOx emission rate for purposes of § 75.19;
(vii) The fuel and unit-specific NOx default rate established for the group of identical units
under § 75.19;
(viii) The type of fuel combusted for the units during testing and represented by the
resulting default NOx emission rate;
(ix) The control status for the units during testing and represented by the resulting default
NOx emission rate;
(x) Documentation supporting the qualification of all units in the group for reduced testing
based on the criteria established in § 75.19(c)(l)(iv)(B)(i); and
(xi) Purpose of group tests.
(e) Excepted monitoring for Hg low mass emission units under §75.81(b). For qualifying
coal-fired units using the alternative low mass emission methodology under §75.81(b), the
owner or operator shall record the data elements described in §75.59(a)(7)(vii),
§75.59(a)(7)(viii), or §75.59(a)(7)(x), as applicable, for each run of each Hg emission test and
re-test required under §75.81(c)(1) or §75.81(d)(4)(iii).
(f) DAHS Verification. For each DAHS (missing data and formula) verification that is
required for initial certification, recertification, or for certain diagnostic testing of a monitoring
system, record the date and hour that the DAHS verification is successfully completed. (This
requirement only applies to units that report monitoring plan data in accordance with
§75.53(g) and (h).)
Subpart G — Reporting Requirements
§ 75.60 General provisions.
(a) The designated representative for any affected unit subject to the requirements of this
part shall comply with all reporting requirements in this section and with the signatory
requirements of § 72.21 of this chapter for all submissions.
(b) Submissions. The designated representative shall submit all reports and petitions
(except as provided in § 75.61) as follows:
(1) Initial certifications. The designated representative shall submit initial certification
applications according to § 75.63.
(2) Recertifications. The designated representative shall submit recertification
applications according to § 75.63.
(3) Monitoring plans. The designated representative shall submit monitoring plans
according to § 75.62.
(4) Electronic quarterly reports. The designated representative shall submit electronic
quarterly reports according to § 75.64.
(5) Other petitions and communications. The designated representative shall submit
petitions, correspondence, application forms, designated representative signature, and petition-
related test results in hardcopy to the Administrator. Additional petition requirements are
specified in §§ 75.66 and 75.67.
(6) Semiannual or annual RATA reports. If requested in writing (or by electronic mail) by
the applicable EPA Regional Office, appropriate State, and/or appropriate local air pollution
control agency, the designated representative shall submit a hardcopy RATA report within 45
days after completing a required semiannual or annual RAT A according to section 2.3.1 of
appendix B to this part, or within 15 days of receiving the request, whichever is later. The
designated representative shall report the hardcopy information required by § 75.59(a)(9) to the
applicable EPA Regional Office, appropriate State, and/or appropriate local air pollution
control agency that requested the RATA report.
(7) Routine appendix E retest reports. If requested in writing (or by electronic mail) by
the applicable EPA Regional Office, appropriate State, and/or appropriate local air pollution
control agency, the designated representative shall submit a hardcopy report within 45 days
after completing a required periodic retest according to section 2.2 of appendix E to this part,
or within 15 days of receiving the request, whichever is later. The designated representative
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 152
-------
shall report the hardcopy information required by § 75.59(b)(5) to the applicable EPA Regional
Office, appropriate State, and/or appropriate local air pollution control agency that requested
the hardcopy report.
(8) Routine retest reports for Hg low mass emissions units. If requested in writing (or by
electronic mail) by the applicable EPA Regional Office, appropriate State, and/or appropriate
local air pollution control agency, the designated representative shall submit a hardcopy report
for a semiannual or annual retest required under §75.81 (d)(4)(iii) for a Hg low mass emissions
unit, within 45 days after completing the test or within 15 days of receiving the request,
whichever is later. The designated representative shall report, at a minimum, the following
hardcopy information to the applicable EPA Regional Office, appropriate State, and/or
appropriate local air pollution control agency that requested the hardcopy report: a summary of
the test results; the raw reference method data for each test run; the raw data and results of all
pretest, post-test, and post-run quality-assurance checks of the reference method; the raw data
and results of moisture measurements made during the test runs (if applicable); diagrams
illustrating the test and sample point locations; a copy of the test protocol used; calibration
certificates for the gas standards or standard solutions used in the testing; laboratory
calibrations of the source sampling equipment; and the names of the key personnel involved in
the test program, including test team members, plant contact persons, agency representatives
and test observers.
§ 75.60(c) (c) Confidentiality of data. The following provisions shall govern the confidentiality of
information submitted under this part.
(1) All emission data reported in quarterly reports under § 75.64 shall remain public
information.
(2) For information submitted under this part other than emission data submitted in
quarterly reports, the designated representative must assert a claim of confidentiality at the time
of submission for any information he or she wishes to have treated as confidential business
information (CBI) under subpart B of part 2 of this chapter. Failure to assert a claim of
confidentiality at the time of submission may result in disclosure of the information by EPA
without further notice to the designated representative.
(3) Any claim of confidentiality for information submitted in quarterly reports under
§ 75.64 must include substantiation of the claim. Failure to provide substantiation may result
in disclosure of the information by EPA without further notice.
(4) As provided under subpart B of part 2 of this chapter, EPA may review information
submitted to determine whether it is entitled to confidential treatment even when confidentiality
claims are initially received. The EPA will contact the designated representative as part of
such a review process.
§ 75.61 § 75.61 Notifications.
§ 75.61(a) (a) Submission. The designated representative for an affected unit (or owner or operator,
as specified) shall submit notice to the Administrator, to the appropriate EPA Regional Office,
and to the applicable State and local air pollution control agencies for the following purposes,
as required by this part.
§ 75.61(a)(1) (1) Initial certification and recertification test notifications. The owner or operator or
designated representative for an affected unit shall submit written notification of initial
certification tests and revised test dates as specified in §75.20 for continuous emission
monitoring systems, for the excepted Hg monitoring methodology under §75.81(b), for
alternative monitoring systems under subpart E of this part, or for excepted monitoring systems
under appendix E to this part, except as provided in paragraphs (a)(l)(iii), (a)(l)(iv) and (a)(4)
of this section. The owner or operator shall also provide written notification of testing
performed under § 75.19(c)(l)(iv)(A) to establish fuel-and-unit-specific NOx emission rates for
low mass emissions units. Such notifications are not required, however, for initial certifications
and recertifications of excepted monitoring systems under appendix D to this part.
§ 75.61(a)(l)(i) (i) Notification of initial certification testing and full recertification. Initial certification
test notifications and notifications of full recertification testing under § 75.20 (b)(2) shall be
submitted not later than 21 days prior to the first scheduled day of certification or
recertification testing. In emergency situations when full recertification testing is required
following an uncontrollable failure of equipment that results in lost data, notice shall be
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 153
-------
sufficient if provided within 2 business days following the date when testing is scheduled.
Testing may be performed on a date other than that already provided in a notice under this
subparagraph as long as notice of the new date is provided either in writing or by telephone or
other means at least 7 days prior to the original scheduled test date or the revised test date,
whichever is earlier.
§ 75.6 l(a)(l)(ii) (ii) Notification ofcertification retesting, and partial recertification testing. Forretesting
required following a loss of certification under § 75.20(a)(5) or for partial recertification
testing required under § 75.20(b)(2), notice of the date of any required RATA testing or any
required retesting under section 2.3 in appendix E to this part shall be submitted either in
writing or by telephone at least 7 days prior to the first scheduled day of testing; except that in
emergency situations when testing is required following an uncontrollable failure of equipment
that results in lost data, notice shall be sufficient if provided within 2 business days following
the date when testing is scheduled. Testing may be performed on a date other than that already
provided in a notice under this subparagraph as long as notice of the new date is provided by
telephone or other means at least 2 business days prior to the original scheduled test date or the
revised test date, whichever is earlier.
§ 75.6 l(a)(l)(iii) (iii) Repeat of testing without notice. Notwithstanding the above notice requirements, the
owner or operator may elect to repeat a certification or recertification test immediately, without
advance notification, whenever the owner or operator has determined during the certification
or recertification testing that a test was failed or must be aborted, or that a second test is
necessary in order to attain a reduced relative accuracy test frequency.
§ 75.61(a)(l)(iv) (iv) Waiver from notification requirements. The Administrator, the appropriate EPA
Regional Office, or the applicable State or local air pollution control agency may issue a
waiver from the notification requirement of paragraph (a)(l)(ii) of this section, for a unit or a
group of units, for one or more recertification tests or other retests. The Administrator, the
appropriate EPA Regional Office, or the applicable State or local air pollution control agency
may also discontinue the waiver and reinstate the notification requirement of paragraph
(a)(l)(ii) of this section for future recertification tests (or other retests) of a unit or a group of
units.§ 75.61(a)(l)(iv)
§ 75.61(a)(2) (2) New unit, newly affected unit, new stack, or new flue gas desulfurization system
operation notification. The designated representative for an affected unit shall submit written
notification: For a new unit or a newly affected unit, of the planned date when a new unit or
newly affected unit will commence commercial operation, or becomes affected, or, for new
stack or flue gas desulfurization system, of the planned date when a new stack or flue gas
desulfurization system will be completed and emissions will first exit to the atmosphere.
(i) Notification of the planned date shall be submitted not later than 45 days prior to the
date the unit commences commercial operation or becomes affected, or not later than 45 days
prior to the date when a new stack or flue gas desulfurization system exhausts emissions to the
atmosphere.
(ii) If the date when the unit commences commercial operation or becomes affected, or the
date when the new stack or flue gas desulfurization system exhausts emissions to the
atmosphere, whichever is applicable, changes from the planned date, a notification of the
actual date shall be submitted not later than 7 days following: The date the unit commences
commercial operation or becomes affected, or the date when a new stack or flue gas
desulfurization system exhausts emissions to the atmosphere.
§ 75.61(a)(3) (3) Unit shutdown and recommencement of commercial operation. For an affected unit
that will be shut down on the relevant compliance date specified in §75.4 or in a State or
Federal pollutant mass emissions reduction program that adopts the monitoring and reporting
requirements of this part, if the owner or operator is relying on the provisions in §75.4(d) to
postpone certification testing, the designated representative for the unit shall submit
notification of unit shutdown and recommencement of commercial operation as follows:
(i) For planned unit shutdowns (e.g., extended maintenance outages), written notification
of the planned shutdown date shall be provided at least 21 days prior to the applicable
compliance date, and written notification of the planned date of recommencement of
commercial operation shall be provided at least 21 days in advance of unit restart. If the actual
shutdown date or the actual date of recommencement of commercial operation differs from the
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 154
-------
planned date, written notice of the actual date shall be submitted no later than 7 days following
the actual date of shutdown or of recommencement of commercial operation, as applicable;
(ii) For unplanned unit shutdowns (e.g., forced outages), written notification of the actual
shutdown date shall be provided no more than 7 days after the shutdown, and written
notification of the planned date of recommencement of commercial operation shall be provided
at least 21 days in advance of unit restart. If the actual date of recommencement of
commercial operation differs from the expected date, written notice of the actual date shall be
submitted no later than 7 days following the actual date of recommencement of commercial
operation.
§ 75.61(a)(4)
(4) Use of backup fuels for appendix E procedures. The designated representative for an
affected oil-fired or gas-fired peaking unit that is using an excepted monitoring system under
appendix E of this part and that is relying on the provisions in § 75.4(f) to postpone testing of a
fuel shall submit written notification of that fact no later than 45 days prior to the deadline in
§ 75.4. The designated representative shall also submit a notification that such a fuel has been
combusted no later than 7 days after the first date of combustion of any fuel for which testing
has not been performed under appendix E after the deadline in § 75.4. Such notice shall also
include notice that testing under appendix E either was performed during the initial combustion
or notice of the date that testing will be performed.
§ 75.61(a)(5)
(5) Periodic relative accuracy test audits, appendix E retests, and low mass emissions unit
retests. The owner or operator or designated representative of an affected unit shall submit
written notice of the date of periodic relative accuracy testing performed under section 2.3.1 of
appendix B to this part, of periodic retesting performed under section 2.2 of appendix E to this
part, of periodic retesting of low mass emissions units performed under §75.19(c)(l)(iv)(D),
and of periodic retesting of Hg low mass emissions units performed under §75.81 (d)(4)(iii),
no later than 21 days prior to the first scheduled day of testing.
§ 75.61(a)(5)®
(i) Written notification under paragraph (a) (5) of this section may be provided either by
mail or by facsimile. In addition, written notification may be provided by electronic mail,
provided that the respective State agency or office of EPA agrees that this is an acceptable
form of notification.
§ 75.61(a)(5)(ii) (ii) Notwithstanding the notice requirements under paragraph (a)(5) of this section, the
owner or operator may elect to repeat a periodic relative accuracy test, appendix E retest, or
low mass emissions unit retest immediately, without additional notification whenever the
owner or operator has determined that a test was failed, or that a second test is necessary in
order to attain a reduced relative accuracy test frequency.
§ 75.6 l(a)(5)(iii) (iii) Waiver from notification requirements. The Administrator, the appropriate EPA
Regional Office, or the applicable State air pollution control agency may issue a waiver from
the requirement of paragraph (a)(5) of this section to provide notice to the respective State
agency or office of EPA for a unit or a group of units for one or more tests. The
Administrator, the appropriate EPA Regional Office, or the applicable State air pollution
control agency may also discontinue the waiver and reinstate the requirement of paragraph
(a)(5) of this section to provide notice to the respective State agency or office of EPA for
future tests for a unit or a group of units. In addition, if an observer from a State agency or
EPA is present when a test is rescheduled, the observer may waive all notification requirements
under paragraph (a)(5) of this section for the rescheduled test.
§ 75.61 (a)(6) (6) Notice of combustion of emergency fuel under appendix D or E. The designated
representative of an oil-fired unit or gas-fired unit using appendix D or E of this part shall, for
each calendar quarter in which emergency fuel is combusted, provide notice of the combustion
of the emergency fuel in the cover letter (or electronic equivalent) which transmits the next
quarterly report submitted under § 75.64. The notice shall specify the exact dates and hours
during which the emergency fuel was combusted.
§ 75.61(a)(7) (7) Long-term cold storage and recommencement of commercial operation. The
designated representative for an affected unit that is placed into long-term cold storage that is
relying on the provisions in §75.4(d) or §75.64(a), either to postpone certification testing or to
discontinue the submittal of quarterly reports during the period of long-term cold storage, shall
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 155
-------
provide written notification of long-term cold storage status and recommencement of
commercial operation as follows:
§75.61 (a)(7)(i) (i) Whenever an affected unit has been placed into long-term cold storage, written
notification of the date and hour that the unit was shutdown and a statement from the
designated representative stating that the shutdown is expected to last for at least two years
from that date, in accordance with the definition for long-term cold storage of a unit as
provided in §72.2.
§75.61 (a)(7)(ii) (ii) Whenever an affected unit that has been placed into long-term cold storage is expected
to resume operation, written notification shall be submitted 45 calendar days prior to the
planned date of recommencement of commercial operation. If the actual date of
recommencement of commercial operation differs from the expected date, written notice of the
actual date shall be submitted no later than 7 days following the actual date of
recommencement of commercial operation.
§ 75.61(a)(8) (8) Certification deadline date for new or newly affected units. The designated
representative of a new or newly affected unit shall provide notification of the date on which
the relevant deadline for initial certification is reached, either as provided in §75.4(b) or
§75.4(c), or as specified in a State or Federal S02, NOx, or Hg mass emission reduction
program that incorporates by reference, or otherwise adopts, the monitoring, recordkeeping,
and reporting requirements of subpart F, G, H, or I of this part. The notification shall be
submitted no later than 7 calendar days after the applicable certification deadline is reached.
§ 75.61(b) (b) The owner or operator or designated representative shall submit notification of
certification tests and recertification tests for continuous opacity monitoring systems as
specified in § 75.20(c)(8) to the State or local air pollution control agency.
§ 75.61(c) (c) If the Administrator determines that notification substantially similar to that required in
this section is required by any other State or local agency, the owner or operator or designated
representative may send the Administrator a copy of that notification to satisfy the
requirements of this section, provided the ORISPL unit identification number(s) is denoted.
§ 75.62 § 75.62 Monitoring plan submittals.
§ 75.62(a) (a) Submission.
(1) Electronic. Using the format specified in paragraph (c) of this section, the designated
representative for an affected unit shall submit a complete, electronic, up-to-date monitoring
plan file (except for hardcopy portions identified in paragraph (a)(2) of this section) to the
Administrator as follows: no later than 21 days prior to the initial certification tests; at the time
of each certification or recertification application submission; and (prior to or concurrent with)
the submittal of the electronic quarterly report for a reporting quarter where an update of the
electronic monitoring plan information is required, either under §75.53(b) or elsewhere in this
part.
(2) Hardcopy. The designated representative shall submit all of the hardcopy information
required under § 75.53 to the appropriate EPA Regional Office and the appropriate State
and/or local air pollution control agency prior to initial certification. Thereafter, the designated
representative shall submit hardcopy information only if that portion of the monitoring plan is
revised. The designated representative shall submit the required hardcopy information as
follows: no later than 21 days prior to the initial certification test; with any certification or
recertification application, if a hardcopy monitoring plan change is associated with the
certification or recertification event; and within 30 days of any other event with which a
hardcopy monitoring plan change is associated, pursuant to § 75.53(b). Electronic submittal of
all monitoring plan information, including hardcopy portions, is permissible provided that a
paper copy of the hardcopy portions can be furnished upon request.
§ 75.62(b) (b) Contents. Monitoring plans shall contain the information specified in
§ 75.53 of this part.
§ 75.62(c) (c) Format. The designated representative shall submit each monitoring plan in a format
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 156
-------
specified by the Administrator.
§ 75.63
§ 75.63(a)
§ 75.63(a)(1)
§ 75.63(a)(2)
§ 75.63(b)
§ 75.63(b)(1)
§ 75.63(b)(2)
§ 75.63 Initial certification or recertification application.
(a) Submission. The designated representative for an affected unit or a combustion source
shall submit applications and reports as follows:
(1) Initial certifications.
(1) For CEM systems or excepted monitoring systems under appendix D or E to this part,
within 45 days after completing all initial certification tests, submit:
(A) To the Administrator, the electronic information required by paragraph (b)(1) of this
section. Except for subpart E applications for alternative monitoring systems or unless
specifically requested by the Administrator, do not submit a hardcopy of the test data and
results to the Administrator.
(B) To the applicable EPA Regional Office and the appropriate State and/or local air
pollution control agency, the hardcopy information required by paragraph (b)(2) of this section
(ii) For units for which the owner or operator is applying for certification approval of the
optional excepted methodology under § 75.19 for low mass emissions units, submit, no later
than 45 days prior to commencing use of the methodology:
(A) To the Administrator, the electronic low mass emission qualification information
required by §75.53 (f)(5)(i) or §75.53 (h)(4)(i) (as applicable) and paragraph (b)(l)(i) of this
section; and
(B) To the applicable EPA Regional Office and appropriate State and/or local air pollution
control agency, the hardcopy information required by § 75.19(a)(2) and § 75.53 (f)(5)(ii) or
§75.53(h)(4)(ii) (as applicable), the hardcopy results of any appendix E (of this part) tests or
any CEMS data analysis used to derive a fuel-and-unit-specific default NOx emission rate.
(2) Recertifications and diagnostic testing.
(i) Within 45 days after completing all recertification tests under § 75.20(b), submit to the
Administrator the electronic information required by paragraph (b)(1) of this section. Except
for subpart E applications for alternative monitoring systems or unless specifically requested
by the Administrator, do not submit a hardcopy of the test data and results to the
Administrator.
(ii) Within 45 days after completing all recertification tests under § 75.20(b), submit the
hardcopy information required by paragraph (b)(2) of this section to the applicable EPA
Regional Office and the appropriate State and/or local air pollution control agency. The
applicable EPA Regional Office or appropriate State or local air pollution control agency may
waive the requirement to provide hardcopy recertification test data and results. The applicable
EPA Regional Office or the appropriate State or local air pollution control agency may also
discontinue the waiver and reinstate the requirement of this paragraph to provide a hardcopy
report of the recertification test data and results.
(iii) Notwithstanding the requirements of paragraphs (a)(2)(i) and (a)(2)(ii) of this section,
for an event for which the Administrator determines that only diagnostic tests (see §75.20(b))
are required rather than recertification testing, no hardcopy submittal is required; however, the
results of all diagnostic test(s) shall be submitted prior to or concurrent with the electronic
quarterly report required under §75.64. Notwithstanding the requirement of §75.59(e), for
DAHS (missing data and formula) verifications, no hardcopy submittal is required; the owner
or operator shall keep these test results on-site in a format suitable for inspection.
(b) Contents. Each application for initial certification or recertification shall contain the
following information, as applicable:
(1) Electronic.
(1) A complete, up-to-date version of the electronic portion of the monitoring plan,
according to § 75.53(e) and (f), in the format specified in § 75.62(c).
(ii) The results of the test(s) required by § 75.20, including the type of test conducted,
testing date, information required by § 75.59, and the results of any failed tests that affect data
validation.
(2) Hardcopy.
(i) Any changed portions of the hardcopy monitoring plan information required under
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 157
-------
§ 75.63(c)
§ 75.64
§ 75.64(a)
§ 75.64(a)(1)
§ 75.64(a)(2)
§ 75.53(e) and (f). Electronic submittal of all monitoring plan information, including the
hardcopy portions, is permissible, provided that a paper copy can be furnished upon request.
(ii) The results of the test(s) required by § 75.20, including the type of test conducted,
testing date, information required by § 75.59(a)(9), and the results of any failed tests that affect
data validation.
(iii) [Reserved]
(iv) Designated representative signature certifying the accuracy of the submission.
(c) Format. The electronic portion of each certification or recertification application shall
be submitted in a format to be specified by the Administrator. The hardcopy test results shall
be submitted in a format suitable for review and shall include the information in § 75.59(a)(9).
§ 75.64 Quarterly reports.
(a) Electronic submission. The designated representative for an affected unit shall
electronically report the data and information in paragraphs (a), (b), and (c) of this section to
the Administrator quarterly, beginning with the data from the earlier of the calendar quarter
corresponding to the date of provisional certification or the calendar quarter corresponding to
the relevant deadline for initial certification in §75.4(a), (b), or (c). The initial quarterly report
shall contain hourly data beginning with the hour of provisional certification or the hour
corresponding to the relevant certification deadline, whichever is earlier. For an affected unit
subject to §75.4(d) that is shutdown on the relevant compliance date in §75.4(a) or has been
placed in long-term cold storage (as defined in §72.2 of this chapter), quarterly reports are not
required. In such cases, the owner or operator shall submit quarterly reports for the unit
beginning with the data from the quarter in which the unit recommences commercial operation
(where the initial quarterly report contains hourly data beginning with the first hour of
recommenced commercial operation of the unit). For units placed into long-term cold storage
during a reporting quarter, the exemption from submitting quarterly reports begins with the
calendar quarter following the date that the unit is placed into long-term cold storage. For any
provisionally-certified monitoring system, §75.20(a)(3) shall apply for initial certifications, and
§75.20(b)(5) shall apply for recertifications. Each electronic report must be submitted to the
Administrator within 30 days following the end of each calendar quarter. Prior to January 1,
2008, each electronic report shall include for each affected unit (or group of units using a
common stack), the information provided in paragraphs (a)(1), (a)(2), and (a)(8) through
(a)(15) of this section. During the time period of January 1, 2008 to January 1, 2009, each
electronic report shall include, either the information provided in paragraphs (a)(1), (a)(2), and
(a)(8) through (a)(15) of this section or the information provided in paragraphs (a)(3) through
(a)(15) of this section. On and after January 1, 2009, the owner or operator shall meet the
requirements of paragraphs (a)(3) through (a)(15) of this section only. Each electronic report
shall also include the date of report generation.
(1) Facility information:
(1) Identification, including:
(A) Facility/ORISPL number;
(B) Calendar quarter and year for the data contained in the report; and
(C) Version of the electronic data reporting format used for the report.
(ii) Location, including:
(A) Plant name and facility ID;
(B) EPA AIRS facility system ID;
(C) State facility ID;
(D) Source category/type;
(E) Primary SIC code;
(F) State postal abbreviation;
(G) County code; and
(H) Latitude and longitude.
(2) The information and hourly data required in § 75.53 and §§ 75.57 through 75.59,
excluding the following:
(i) Descriptions of adjustments, corrective action, and maintenance;
(ii) Information which is incompatible with electronic reporting (e.g., field data sheets, lab
analyses, quality control plan);
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 158
-------
(iii) Opacity data listed in § 75.57(f), and in § 75.59(a)(8);
(iv) For units with S02 or NOx add-on emission controls that do not elect to use the
approved site-specific parametric monitoring procedures for calculation of substitute data, the
information in § 75.58(b)(3);
(v) [Reserved]
(vi) Information required by § 75.57(h) concerning the causes of any missing data periods
and the actions taken to cure such causes;
(vii) Hardcopy monitoring plan information required by § 75.53 and hardcopy test data
and results required by § 75.59;
(viii) Records of flow monitor and moisture monitoring system polynomial equations,
coefficients, or "K" factors required by § 75.59(a)(5)(vi) or § 75.59(a)(5)(vii);
(ix) Daily fuel sampling information required by § 75.58(c)(3)(i) for units using assumed
values under appendix D;
(x) Information required by §§ 75.59(b)(l)(vi), (vii), (viii), (ix), and (xiii), and (b)(2)(iii)
and (iv) concerning fuel flowmeter accuracy tests and transmitter/transducer accuracy tests;
(xi) Stratification test results required as part of the RATA supplementary records under
§ 75.59(a)(7);
(xii) Data and results of RAT As that are aborted or invalidated due to problems with the
reference method or operational problems with the unit and data and results of linearity checks
that are aborted or invalidated due to problems unrelated to monitor performance; and
(xiii) Supplementary RATA information required under §75.59(a)(7), except that:
(A) The applicable data elements under §75.59(a)(7)(ii)(A) through (T) and under
§75.59(a)(7)(iii)(A) through (M) shall be reported for flow RAT As at circular or rectangular
stacks (or ducts) in which angular compensation for yaw and/or pitch angles is used (i.e.,
Method 2F or 2G in appendices A-l and A-2 to part 60 of this chapter), with or without wall
effects adjustments;
(B) The applicable data elements under §75.59(a)(7)(ii)(A) through (T) and under
§75.59(a)(7)(iii)(A) through (M) shall be reported for any flow RATA run at a circular stack in
which Method 2 in appendices A-l and A-2 to part 60 of this chapter is used and a wall effects
adjustment factor is determined by direct measurement;
(C) The data under §75.59(a)(7)(ii)(T) shall be reported for all flow RATAs at circular
stacks in which Method 2 in appendices A-l and A-2 to part 60 of this chapter is used and a
default wall effects adjustment factor is applied; and
(D) The data under §75.59(a)(7)(ix)(A) through (F) shall be reported for all flow RATAs
at rectangular stacks or ducts in which Method 2 in appendices A-l and A-2 to part 60 of this
chapter is used and a wall effects adjustment factor is applied.
§ 75.64(a)(3)
(3) Facility Identification information, including:
(i) Facility/ORISPL number;
(ii) Calendar quarter and year for the data contained in the report; and
(iii) Version of the electronic data reporting format used for the report.
§ 75.64(a)(4)
(4) In accordance with §75.62(a)(l), if any monitoring plan information required in
§75.53 requires an update, either under §75.53(b) or elsewhere in this part, submission of the
electronic monitoring plan update shall be completed prior to or concurrent with the submittal
of the quarterly electronic data report for the appropriate quarter in which the update is
required.
§ 75.64(a)(5)
(5) Except for the daily calibration error test data, daily interference check, and off-line
calibration demonstration information required in §75.59(a)(1) and (2), which must always be
submitted with the quarterly report, the certification, quality assurance, and quality control
information required in §75.59 shall either be submitted prior to or concurrent with the
submittal of the relevant quarterly electronic data report.
§ 75.64(a)(6)
(6)The information and hourly data required in §§75.57 through 75.59, and daily
calibration error test data, daily interference check, and off-line calibration demonstration
information required in §75.59(a)(1) and (2).
§ 75.64(a)(7)
(7) Notwithstanding the requirements of paragraphs (a)(4) through (a)(6) of this section,
the following information is excluded from electronic reporting:
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 159
-------
(i) Descriptions of adjustments, corrective action, and maintenance;
(ii) Information which is incompatible with electronic reporting (e.g., field data sheets, lab
analyses, quality control plan);
(iii) Opacity data listed in §75.57(f), and in §75.59(a)(8);
(iv) For units with S02 or NOx add-on emission controls that do not elect to use the
approved site-specific parametric monitoring procedures for calculation of substitute data, the
information in §75.58(b)(3);
(v) Information required by §75.57(h) concerning the causes of any missing data periods
and the actions taken to cure such causes;
(vi) Hardcopy monitoring plan information required by §75.53 and hardcopy test data and
results required by §75.59;
(vii) Records of flow monitor and moisture monitoring system polynomial equations,
coefficients, or "K" factors required by §75.59(a)(5)(vi) or §75.59(a)(5)(vii);
(viii) Daily fuel sampling information required by §75.58(c)(3)(i) for units using assumed
values under appendix D of this part;
(ix) Information required by §§75.59(b)(l)(vi), (vii), (viii), (ix), and (xiii), and (b)(2)(iii)
and (iv) concerning fuel flowmeter accuracy tests and transmitter/transducer accuracy tests;
(x) Stratification test results required as part of the RATA supplementary records under
§75.59(a)(7);
(xi) Data and results of RAT As that are aborted or invalidated due to problems with the
reference method or operational problems with the unit and data and results of linearity checks
that are aborted or invalidated due to problems unrelated to monitor performance; and
(xii) Supplementary RATA information required under §75.59(a)(7)(i) through
§75.59(a)(7)(v), except that:
(A) The applicable data elements under §75.59(a)(7)(ii)(A) through (T) and under
§75.59(a)(7)(iii)(A) through (M) shall be reported for flow RAT As at circular or rectangular
stacks (or ducts) in which angular compensation for yaw and/or pitch angles is used (i.e.,
Method 2F or 2G in appendices A-l and A-2 to part 60 of this chapter), with or without wall
effects adjustments;
(B) The applicable data elements under §75.59(a)(7)(ii)(A) through (T) and under
§75.59(a)(7)(iii)(A) through (M) shall be reported for any flow RATA run at a circular stack in
which Method 2 in appendices A-l and A-2 to part 60 of this chapter is used and a wall effects
adjustment factor is determined by direct measurement;
(C) The data under §75.59(a)(7)(ii)(T) shall be reported for all flow RATAs at circular
stacks in which Method 2 in appendices A-l and A-2 to part 60 of this chapter is used and a
default wall effects adjustment factor is applied; and
(D) The data under §75.59(a)(7)(vii)(A) through (F) shall be reported for all flow RATAs
at rectangular stacks or ducts in which Method 2 in appendices A-l and A-2 to part 60 of this
chapter is used and a wall effects adjustment factor is applied.
§ 75.64(a)(8) (8) Tons (rounded to the nearest tenth) of S02 emitted during the quarter and cumulative
S02 emissions for the calendar year.
§ 75.64(a)(9) (9) Average NOx emission rate (lb/mmBtu, rounded to the nearest thousandth) during the
quarter and cumulative NOx emission rate for the calendar year.
§ 75.64(a)(10) (10) Tons of C02 emitted during quarter and cumulative C02 emissions for calendar year.
§ 75.64(a)(l 1) (11) Total heat input (mmBtu) for quarter and cumulative heat input for calendar year.
§ 75.64(a)(12) (12) Unit or stack or common pipe header operating hours for quarter and cumulative unit
or stack or common pipe header operating hours for calendar year.
§ 75.64(a)(13) (13) For low mass emissions units for which the owner or operator is using the optional
low mass emissions methodology in § 75.19(c) to calculate NOx mass emissions, the
designated representative must also report tons (rounded to the nearest tenth) of NOx emitted
during the quarter and cumulative NOx mass emissions for the calendar year.
§ 75.64(a)(14) (14) For low mass emissions units using the optional long term fuel flow methodology
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 160
-------
under § 75.19(c), for each quarter report the long term fuel flow for each fuel according to
§75.58(f)(2).
§ 75.64(a)(15) (15) For units using the optional fuel flow to load procedure in section 2.1.7 of appendix
D to this part, report both the fuel flow-to-load baseline data and the results of the fuel flow-to-
load test each quarter.
§ 75.64(b) (b) The designated representative shall affirm that the component/system identification
codes and formulas in the quarterly electronic reports, submitted to the Administrator pursuant
to § 75.53, represent current operating conditions.
§ 75.64(c) (c) Compliance certification. The designated representative shall submit a certification in
support of each quarterly emissions monitoring report based on reasonable inquiry of those
persons with primary responsibility for ensuring that all of the unit's emissions are correctly
and fully monitored. The certification shall indicate whether the monitoring data submitted
were recorded in accordance with the applicable requirements of this part including the quality
control and quality assurance procedures and specifications of this part and its appendices, and
any such requirements, procedures and specifications of an applicable excepted or approved
alternative monitoring method. For a unit with add-on emission controls, the designated
representative shall also include a certification, for all hours where data are substituted
following the provisions of § 75.34(a)(1), that the add-on emission controls were operating
within the range of parameters listed in the monitoring plan and that the substitute values
recorded during the quarter do not systematically underestimate S02 or NOx emissions,
pursuant to § 75.34.
§ 75.64(d) (d) Electronic format. Each quarterly report shall be submitted in a format to be specified
by the Administrator, including both electronic submission of data and (unless otherwise
approved by the Administrator) electronic submission of compliance certifications.
§ 75.64(e) (e) [Reserved]
§ 75.64(f) (f) Method of submission. Beginning with the quarterly report for the first quarter of the
year 2001, all quarterly reports shall be submitted to EPA by direct computer-to-computer
electronic transfer via EPA-provided software, unless otherwise approved by the
Administrator.
§ 75.64(g) (g) Any cover letter text accompanying a quarterly report shall either be submitted in
hardcopy to the Agency or be provided in electronic format compatible with the other data
required to be reported under this section.
§ 75.65 § 75.65 Opacity reports.
The owner or operator or designated representative shall report excess emissions of
opacity recorded under § 75.57(f) to the applicable State or local air pollution control agency.
§ 75.66 § 75.66 Petitions to the Administrator.
§ 75.66(a) (a) General. The designated representative for an affected unit subject to the requirements
of this part may submit a petition to the Administrator requesting that the Administrator
exercise his or her discretion to approve an alternative to any requirement prescribed in this
part or incorporated by reference in this part. Any such petition shall be submitted in
accordance with the requirements of this section. The designated representative shall comply
with the signatory requirements of § 72.21 of this chapter for each submission.
§ 75.66(b) (b) Alternative flow monitoring method petition. In cases where no location exists for
installation of a flow monitor in either the stack or the ducts serving an affected unit that
satisfies the minimum physical siting criteria in appendix A of this part or where installation of
a flow monitor in either the stack or duct is demonstrated to the satisfaction of the
Administrator to be technically infeasible, the designated representative for the affected unit
may petition the Administrator for an alternative method for monitoring volumetric flow. The
petition shall, at a minimum, contain the following information:
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 161
-------
(1) Identification of the affected unit(s);
(2) Description of why the minimum siting criteria cannot be met within the existing
ductwork or stack(s). This description shall include diagrams of the existing ductwork or
stack, as well as documentation of any attempts to locate a flow monitor; and
(3) Description of proposed alternative method for monitoring flow.
§ 75.66(c) (c) Alternative to standards incorporated by reference. The designated representative for
an affected unit may apply to the Administrator for an alternative to any standard incorporated
by reference and prescribed in this part. The designated representative shall include the
following information in an application:
(1) A description of why the prescribed standard is not being used;
(2) A description and diagram(s) of any equipment and procedures used in the proposed
alternative;
(3) Information demonstrating that the proposed alternative produces data acceptable for
use in the Acid Rain Program, including accuracy and precision statements, NIST traceability
certificates or protocols, or other supporting data, as applicable to the proposed alternative.
§ 75.66(d) (d) Alternative monitoring system petitions. The designated representative for an affected
unit may submit a petition to the Administrator for approval and certification of an alternative
monitoring system or component according to the procedure in subpart E of this part. Each
petition shall contain the information and data specified in subpart E, including the information
specified in § 75.48, in a format to be specified by the Administrator.
§ 75.66(e) (e) Parametric monitoring procedure petitions. The designated representative for an
affected unit may submit a petition to the Administrator, where each petition shall contain the
information specified in § 75.58(b) for the use of a parametric monitoring method. The
Administrator will either:
(1) Publish a notice in the Federal Register indicating receipt of a parametric monitoring
procedure petition; or
(2) Notify interested parties of receipt of a parametric monitoring petition.
§ 75.66(f) (f) [Reserved]
§ 75.66(g) (g) Petitions for emissions or heat input apportionments. The designated representative of
an affected unit shall provide information to describe a method for emissions or heat input
apportionment under §§ 75.13, 75.16, 75.17, or appendix D of this part. This petition may be
submitted as part of the monitoring plan. Such a petition shall contain, at a minimum, the
following information:
(1) A description of the units, including their fuel type, their boiler type, and their
categorization as Phase I units, substitution units, compensating units, Phase II units, new units,
or non-affected units;
(2) A formula describing how the emissions or heat input are to be apportioned to which
units;
(3) A description of the methods and parameters used to apportion the emissions or heat
input; and
(4) Any other information necessary to demonstrate that the apportionment method
accurately measures emissions or heat input and does not underestimate emissions or heat input
from affected units.
§ 75.66(h) (h) Partial recertification petition. The designated representative of an affected unit may
provide information and petition the Administrator to specify which of the certification tests
required by § 75.20 apply for partial recertification of the affected unit. Such a petition shall
include the following information:
(1) Identification of the monitoring system(s) being changed;
(2) A description of the changes being made to the system;
(3) An explanation of why the changes are being made; and
(4) A description of the possible effect upon the monitoring system's ability to measure,
record, and report emissions.
§ 75.66(i) [Reserved] Emergency fuel petition. The designated representative for an affected unit
may submit a petition to the Administrator to use the emergency fuel provisions in section
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 162
-------
2.1.4 of appendix E to this part. The designated representative shall include the following
information in the petition:
(1) Identification of the affected plant and unit(s);
(2) A procedure for determining the NOx emission rate for the unit when the emergency
fuel is combusted; and
(3) A demonstration that the permit restricts use of the fuel to emergencies only.
§ 75.66(j) (j) Petition for alternative method of accounting for emissions prior to completion of
certification tests. The designated representative for an affected unit may submit a petition to
the Administrator to use an alternative to the procedures in § 75.4(d)(3), (e)(3), (f)(3) or (g)(3)
to account for emissions during the period between the compliance date for a unit and the
completion of certification testing for that unit. The designated representative shall include:
(1) Identification of the affected unit(s);
(2) A detailed explanation of the alternative method to account for emissions of the
following parameters, as applicable: S02 mass emissions (in lbs), NOx emission rate (in
lbs/mmBtu), C02 mass emissions (in lbs) and, if the unit is subject to the requirements of
subpart H of this part, NOx mass emissions (in lbs); and
(3) A demonstration that the proposed alternative does not underestimate emissions.
§ 75.66(k) (k) Petition for an alternative to the stabilization criteria for the cycle time test in section
6.4 of appendix A to this part. The designated representative for an affected unit may submit a
petition to the Administrator to use an alternative stabilization criteria for the cycle time test in
section 6.4 of appendix A to this part, if the installed monitoring system does not record data in
1-minute or 3-minute intervals. The designated representative shall provide a description of
the alternative criteria.
§ 75.66(1) (1) Any other petitions to the Administrator under this part. Except for petitions addressed
in paragraphs (b) through (k) of this section, any petition submitted under this paragraph shall
include sufficient information for the evaluation of the petition, including, at a minimum, the
following information:
(1) Identification of the affected plant and unit(s);
(2) A detailed explanation of why the proposed alternative is being suggested in lieu of the
requirement;
(3) A description and diagram of any equipment and procedures used in the proposed
alternative, if applicable;
(4) A demonstration that the proposed alternative is consistent with the purposes of the
requirement for which the alternative is proposed and is consistent with the purposes of this
part and of section 412 of the Act and that any adverse effect of approving such alternative will
be de minimis; and
(5) Any other relevant information that the Administrator may require.
§ 75.67 § 75.67 Retired units petitions.
§ 75.67(a) (a) [Reserved]
§ 75.67(b) (b) For combustion sources seeking to enter the Opt-in Program in accordance with part
74 of this chapter that will be permanently retired and governed upon entry into the Opt-in
Program by a thermal energy plan in accordance with § 74.47 of this chapter, an exemption
from the requirements of this part, including the requirement to install and certify a continuous
emissions monitoring system, may be obtained from the Administrator if the designated
representative submits to the Administrator a petition for such an exemption prior to the
deadline in § 75.4 by which the continuous emission or opacity monitoring systems must
complete the required certification tests.
Subpart H — NOx Mass Emissions Provisions
§ 75.70 §75.70 NOx mass emissions provisions.
§ 75.70(a) (a) Applicability. The owner or operator of a unit shall comply with the requirements of
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 163
-------
§ 75.70(a)(1)
§ 75.70(a)(2)
§ 75.70(b)
§ 75.70(c)
§ 75.70(c)(1)
§ 75.70(c)(2)
§ 75.70(c)(3)
this subpart to the extent that compliance is required by an applicable State or federal NOx
mass emission reduction program that incorporates by reference, or otherwise adopts the
provisions of, this subpart.
(1) For purposes of this subpart, the term "affected unit" shall mean any unit that is subject
to a State or federal NOx mass emission reduction program requiring compliance with this
subpart, the term "non-affected unit" shall mean any unit that is not subject to such a program,
the term "permitting authority" shall mean the permitting authority under an applicable State or
federal NOx mass emission reduction program that adopts the requirements of this subpart, and
the term "designated representative" shall mean the responsible party under the applicable State
or federal NOx mass emission reduction program that adopts the requirements of this subpart.
(2) In addition, the provisions of subparts A, C, D, E, F, and G and appendices A through
G of this part applicable to NOx concentration, flow rate, NOx emission rate and heat input, as
set forth and referenced in this subpart, shall apply to the owner or operator of a unit required
to meet the requirements of this subpart by a State or federal NOx mass emission reduction
program. When applying these requirements, the term "affected unit" shall mean any unit that
is subject to a State or federal NOx mass emission reduction program requiring compliance
with this subpart, the term "permitting authority" shall mean the permitting authority under an
applicable State or federal NOx mass emission reduction program that adopts the requirements
of this subpart, and the term "designated representative" shall mean the responsible party under
the applicable State or federal NOx mass emission reduction program that adopts the
requirements of this subpart. The requirements of this part for S02, C02 and opacity
monitoring, recordkeeping and reporting do not apply to units that are subject to a State or
federal NOx mass emission reduction program only and are not affected units with an Acid
Rain emission limitation.
(b) Compliance dates. The owner or operator of an affected unit shall meet the
compliance deadlines established by an applicable State or federal NOx mass emission
reduction program that adopts the requirements of this subpart.
(c) Prohibitions.
(1) No owner or operator of an affected unit or a non-affected unit under § 75.72(b)(2)(ii)
shall use any alternative monitoring system, alternative reference method, or any other
alternative for the required continuous emission monitoring system without having obtained
prior written approval in accordance with paragraph (h) of this section.
(2) No owner or operator of an affected unit or a non-affected unit under § 75.72(b)(2)(ii)
shall operate the unit so as to discharge, or allow to be discharged emissions of NOx to the
atmosphere without accounting for all such emissions in accordance with the applicable
provisions of this part, except as provided in §75.74.
(3) No owner or operator of an affected unit or a non-affected unit under § 75.72(b)(2)(ii)
shall disrupt the continuous emission monitoring system, any portion thereof, or any other
approved emission monitoring method, and thereby avoid monitoring and recording NOx mass
emissions discharged into the atmosphere, except for periods of recertification or periods when
calibration, quality assurance testing, or maintenance is performed in accordance with the
provisions of this part applicable to monitoring systems under §75.71, except as provided in
§75.74.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 164
-------
§ 75.70(c)(4)
§ 75.70(d)
§ 75.70(d)(1)
§ 75.70(d)(2)
(4) No owner or operator of an affected unit or a non-affected unit under § 75.72(b)(2)(ii)
shall retire or permanently discontinue use of the continuous emission monitoring system, any
component thereof, or any other approved emission monitoring system under this part, except
under any one of the following circumstances:
(i) During the period that the unit is covered by a retired unit exemption that is in effect
under the State or federal NOx mass emission reduction program that adopts the requirements
of this subpart;
(ii) The owner or operator is monitoring NOx mass emissions from the affected unit with
another certified monitoring system approved, in accordance with the provisions of paragraph
(d) of this section; or
(iii) The designated representative submits notification of the date of certification testing
of a replacement monitoring system in accordance with § 75.61.
(d) Initial certification and recertification procedures.
(1) The owner or operator of an affected unit that is subject to an Acid Rain emissions
limitation shall comply with the initial certification and recertification procedures in § 75.20 of
this part, except that the owner or operator shall meet any additional requirements set forth in
an applicable State or federal NOx mass emission reduction program that adopts the
requirements of this subpart.
(2) The owner or operator of an affected unit that is not subject to an Acid Rain emissions
limitation shall comply with the initial certification and recertification procedures established
by an applicable State or federal NOx mass emission reduction program that adopts the
requirements of this subpart. The owner or operator of an affected unit that is subject to an
Acid Rain emissions limitation shall comply with the initial certification and recertification
procedures established by an applicable State or federal NOx mass emission reduction program
that adopts the requirements of this subpart for any additional NOx-diluent CEMS, flow
monitors, diluent monitors or NOx concentration monitoring system required under the NOx
mass emissions provisions of §75.71 or the common stack provisions in § 75.72.
§ 75.70(e)
(e) Quality assurance and quality control requirements. For units that use continuous
emission monitoring systems to account for NOx mass emissions, the owner or operator shall
meet the applicable quality assurance and quality control requirements in § 75.21, appendix B
to this part, and § 75.74(c) for the NOx-diluent continuous emission monitoring systems, flow
monitoring systems, NOx concentration monitoring systems, moisture monitoring systems, and
diluent monitors required under § 75.71. Units using the low mass emissions excepted
methodology under § 75.19 shall meet the applicable quality assurance requirements of that
section, except as otherwise provided in § 75.74(c). Units using excepted monitoring methods
under appendices D and E to this part shall meet the applicable quality assurance requirements
of those appendices.
§ 75.70(f)
(f) Missing data procedures. Except as provided in § 75.34, paragraph (g) of this section,
and § 75.74(c)(7), the owner or operator shall provide substitute data from monitoring systems
required under § 75.71 for each affected unit as follows:
§ 75.70(f)(1)
(1) For an owner or operator using a continuous emissions monitoring system, substitute
for missing data in accordance with the applicable missing data procedures in §§ 75.31 through
75.37 whenever the unit combusts fuel and:
(i) A valid, quality-assured hour of NOx emission rate data (in lb/mmBtu) has not been
measured and recorded for a unit by a certified NOx-diluent continuous emission monitoring
system or by an approved monitoring system under subpart E of this part;
(ii) A valid, quality-assured hour of flow data (in scfh) has not been measured and
recorded for a unit from a certified flow monitor or by an approved alternative monitoring
system under subpart E of this part;
(iii) A valid, quality-assured hour of heat input rate data (in mmBtu/hr) has not been
measured and recorded for a unit from a certified flow monitor and a certified diluent (C02 or
02) monitor or by an approved alternative monitoring system under subpart E of this part,
where heat input is required either for calculating NOx mass or allocating allowances under the
applicable State or federal NOx mass emission reduction program that adopts the requirements
of this subpart;
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 165
-------
(iv) A valid, quality-assured hour of NOx concentration data (in ppm) has not been
measured and recorded by a certified NOx concentration monitoring system, or by an approved
alternative monitoring method under subpart E of this part, where the owner or operator
chooses to use a NOx concentration monitoring system with a flow monitor to calculate NOx
mass emissions. The initial missing data procedures for determining monitor data availability
and the standard missing data procedures for a NOx concentration monitoring system shall be
the same as the procedures specified for a NOx-diluent continuous emission monitoring system
under §§ 75.31, 75.32, and 75.33; or
(v) A valid, quality-assured hour of moisture data (in percent H20) has not been measured
or recorded for an affected unit, either by a certified moisture monitoring system or an
approved alternative monitoring method under subpart E of this part. This requirement does
not apply when a default percent moisture value, as provided in § 75.11(b) or § 75.12(b), is
used to account for the hourly moisture content of the stack gas.
§ 75.70(f)(2)
(2) For an owner or operator using an excepted monitoring system under appendix D or E
of this part, substitute for missing data in accordance with the missing data procedures in
section 2.4 of appendix D to this part or in section 2.5 of appendix E to this part whenever the
unit combusts fuel and:
(i) A valid, quality-assured hour of fuel flow rate data has not been measured and recorded
by a certified fuel flowmeter that is part of an excepted monitoring system under appendix D or
E of this part; or
(ii) A fuel sample value for gross calorific value, or if necessary, density or specific
gravity, from a sample taken an analyzed in accordance with appendix D of this part is not
available; or
(iii) A valid, quality-assured hour of NOx emission rate data has not been obtained
according to the procedures and specifications of appendix E to this part.
§ 75.70(g)
(g) Reporting data prior to initial certification. If the owner or operator of an affected
unit has not successfully completed all certification tests required by the State or federal NOx
mass emission reduction program that adopts the requirements of this subpart by the applicable
date required by that program, he or she shall determine, record and report hourly data prior to
initial certification using one of the following procedures, consistent with the monitoring
equipment to be certified:
(1) For units that the owner or operator intends to monitor for NOx mass emissions using
NOx emission rate and heat input rate, the maximum potential NOx emission rate and the
maximum potential hourly heat input of the unit, as defined in § 72.2 of this chapter.
(2) For units that the owner or operator intends to monitor for NOx mass emissions using a
NOx concentration monitoring system and a flow monitoring system, the maximum potential
concentration of NOx and the maximum potential flow rate, as defined in section 2.1.4.1 of
appendix A to this part;
(3) For any unit, the reference methods under § 75.22 of this part.
(4) For any unit using the low mass emissions excepted monitoring methodology under
§ 75.19, the procedures in paragraphs (g)(1) or (2) of this section.
(5) Any unit using the procedures in paragraph (g)(2) of this section that is required to
report heat input for purposes of allocating allowances shall also report the maximum potential
hourly heat input of the unit, as defined in § 72.2 of this chapter.
(6) For any unit using continuous emissions monitors, the conditional data validation
procedures in § 75.20(b)(3)(ii) through (b)(3)(ix).
§ 75.70(h)
§ 75.70(h)(1)
(h) Petitions.
(1) The designated representative of an affected unit that is subject to an Acid Rain
emissions limitation may submit a petition to the Administrator requesting an alternative to any
requirement of this subpart. Such a petition shall meet the requirements of § 75.66 and any
additional requirements established by an applicable State or federal NOx mass emission
reduction program that adopts the requirements of this subpart. Use of an alternative to any
requirement of this subpart is in accordance with this subpart and with such State or federal
NOx mass emission reduction program only to the extent that the petition is approved by the
Administrator, in consultation with the permitting authority.
§ 75.70(h)(2)
(2) Notwithstanding paragraph (h)(1) of this section, petitions requesting an alternative to
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 166
-------
a requirement concerning any additional CEMS required solely to meet the common stack
provisions of § 75.72 shall be submitted to the permitting authority and the Administrator and
shall be governed by paragraph (h)(3)(ii) of this section. Such a petition shall meet the
requirements of § 75.66 and any additional requirements established by an applicable State or
federal NOx mass emission reduction program that adopts the requirements of this subpart.
§ 75.70(h)(3) (3)(i) The designated representative of an affected unit that is not subject to an Acid Rain
emissions limitation may submit a petition to the permitting authority and the Administrator
requesting an alternative to any requirement of this subpart. Such a petition shall meet the
requirements of § 75.66 and any additional requirements established by an applicable State or
federal NOx mass emission reduction program that adopts the requirements of this subpart.
(ii) Use of an alternative to any requirement of this subpart is in accordance with this
subpart only to the extent that it is approved by the Administrator and by the permitting
authority if required by an applicable State or federal NOx mass emission reduction program
that adopts the requirements of this subpart.
§ 75.71 § 75.71 Specific provisions for monitoring NOx and heat input for the purpose of
calculating NOx mass emissions.
§ 75.71(a) (a) Coal-fired units. The owner or operator of a coal-fired affected unit shall either:
(1) Meet the general operating requirements in § 75.10 for a NOx-diluent continuous
emission monitoring system (consisting of a NOx pollutant concentration monitor, an 02 or
C02 diluent gas monitor, and a data acquisition and handling system) to measure NOx emission
rate and for a flow monitoring system and an 02 or C02 diluent gas monitoring system to
measure heat input rate, except as provided in accordance with subpart E of this part; or
(2) Meet the general operating requirements in § 75.10 for a NOx concentration
monitoring system (consisting of a NOx pollutant concentration monitor and a data acquisition
and handling system) to measure NOx concentration and for a flow monitoring system. In
addition, if heat input is required to be reported under the applicable State or federal NOx mass
emission reduction program that adopts the requirements of this subpart, the owner or operator
also must meet the general operating requirements for a flow monitoring system and an 02 or
C02 monitoring system to measure heat input rate. These requirements must be met, except as
provided in accordance with subpart E of this part.
§ 75.71 (b) (b) Moisture correction.
(1) If a correction for the stack gas moisture content is needed to properly calculate the
NOx emission rate in lb/mmBtu (e.g., if the NOx pollutant concentration monitor in a NOx-
diluent monitoring system measures on a different moisture basis from the diluent monitor) or
to calculate the heat input rate, the owner or operator of an affected unit shall account for the
moisture content of the flue gas on a continuous basis in accordance with § 75.12(b).
(2) If a correction for the stack gas moisture content is needed to properly calculate NOx
mass emissions in tons, in the case where a NOx concentration monitoring system which
measures on a dry basis is used with a flow rate monitor to determine NOx mass emissions, the
owner or operator of an affected unit shall account for the moisture content of the flue gas on a
continuous basis in accordance with § 75.11(b) except that the term "S02" shall be replaced by
the term "NOx."
(3) If a correction for the stack gas moisture content is needed to properly calculate NOx
mass emissions, in the case where a diluent monitor that measures on a dry basis is used with a
flow rate monitor to determine heat input rate, which is then multiplied by the NOx emission
rate, the owner or operator shall install, operate, maintain, and quality assure a continuous
moisture monitoring system, as described in § 75.11(b).
§ 75.71(c) (c) Gas-fired nonpeaking units or oil-fired nonpeaking units. The owner or operator of an
affected unit that, based on information submitted by the designated representative in the
monitoring plan, qualifies as a gas-fired or oil-fired unit but not as a peaking unit, as defined in
§ 72.2 of this chapter, shall either:
(1) Meet the requirements of paragraph (a) of this section and, if applicable, paragraph (b)
of this section; or
(2) Meet the general operating requirements in § 75.10 for a NOx-diluent continuous
emission monitoring system, except as provided in accordance with subpart E of this part, and
use the procedures specified in appendix D to this part for determining hourly heat input rate.
However, for a common pipe configuration, the heat input rate apportionment provisions in
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 167
-------
section 2.1.2 of appendix D to this part shall not be used to meet the NOx mass reporting
provisions of this subpart, unless all of the units served by the common pipe are affected units
and have similar efficiencies; or
(3) Meet the requirements of the low mass emissions excepted methodology under
paragraph (e)(2) of this section and under § 75.19, if applicable.
§ 75.71(d) (d) Gas-fired or oil-fired peaking units. The owner or operator of an affected unit that
qualifies as a peaking unit and as either gas-fired or oil-fired, as defined in § 72.2 of this
chapter, based on information submitted by the designated representative in the monitoring
plan, shall either:
(1) Meet the requirements of paragraph (c) of this section; or
(2) Use the procedures in appendix D to this part for determining hourly heat input and the
procedure specified in appendix E to this part for estimating hourly NOx emission rate.
However, for a common pipe configuration, the heat input apportionment provisions in section
2.1.2 of appendix D to this part shall not be used to meet the NOx mass reporting provisions of
this subpart unless all of the units served by the common pipe are affected units and have
similar efficiencies. In addition, if after certification of an excepted monitoring system under
appendix E to this part, the operation of a unit that reports emissions on an annual basis under
§ 75.74(a) of this part exceeds a capacity factor of 20.0 percent in any calendar year or exceeds
an annual capacity factor of 10.0 percent averaged over three years, or the operation of a unit
that reports emissions on an ozone season basis under § 75.74(b) of this part exceeds a
capacity factor of 20.0 percent in any ozone season or exceeds an ozone season capacity factor
of 10.0 percent averaged over three years, the owner or operator shall meet the requirements of
paragraph (c)(1) or (c)(2) of this section by no later than December 31 of the following
calendar year. If the required CEMS are not installed and certified by that date, the owner or
operator shall report hourly NOx mass emissions as the product of the maximum potential NOx
emission rate (MER) and the maximum hourly heat input of the unit (as defined in § 72.2 of
this chapter), starting with the first unit operating hour after the deadline and continuing until
the CEMS are provisionally certified.
§ 75.71(e) (e) Low mass emissions units. Notwithstanding the requirements of paragraphs (c) and (d)
of this section, for an affected unit using the low mass emissions (LME) unit under §75.19 to
estimate hourly NOx emission rate, heat input and NOx mass emissions, the owner or operator
shall calculate the ozone season NOx mass emissions by summing all of the estimated hourly
NOx mass emissions in the ozone season, as determined under §75.19 (c)(4)(ii)(A), and
dividing this sum by 2000 lb/ton.
§ 75.71(f) (f) Other units. The owner or operator of an affected unit that combusts wood, refuse, or
other materials shall comply with the monitoring provisions specified in paragraph (a) of this
section and, where applicable, paragraph (b) of this section.
§ 75.72 §75.72 Determination of NOx mass emissions for common stack and multiple stack
configurations.
The owner or operator of an affected unit shall either: calculate hourly NOx mass
emissions (in lbs) by multiplying the hourly NOx emission rate (in lbs/mmBtu) by the hourly
heat input rate (in mmBtu/hr) and the unit or stack operating time (as defined in §72.2), or, as
provided in paragraph (e) of this section, calculate hourly NOx mass emissions from the hourly
NOx concentration (in ppm) and the hourly stack flow rate (in scfh). Only one methodology
for determining NOx mass emissions shall be identified in the monitoring plan for each
monitoring location at any given time. The owner or operator shall also calculate quarterly and
cumulative year-to-date NOx mass emissions and cumulative NOx mass emissions for the
ozone season (in tons) by summing the hourly NOx mass emissions according to the procedures
in section 8 of appendix F to this part.
§ 75.72(a) (a) Unit utilizing common stack with other affected unit(s). When an affected unit utilizes
a common stack with one or more affected units, but no nonaffected units, the owner or
operator shall either:
§ 75.72(a)(1) (1) Install, certify, operate, and maintain a NOx-diluent continuous emissions monitoring
system and a flow monitoring system in the common stack, record the combined NOx mass
emissions for the units exhausting to the common stack, and, for purposes of determining the
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 168
-------
§ 75.72(a)(2)
§ 75.72(b)
§ 75.72(b)(1)
§ 75.72(b)(2)
hourly unit heat input rates, either:
(1) Apportion the common stack heat input rate to the individual units according to the
procedures in § 75.16(e)(3); or
(ii) Install, certify, operate, and maintain a flow monitoring system and diluent monitor in
the duct to the common stack from each unit; or
(iii) If any of the units using the common stack are eligible to use the procedures in
appendix D to this part,
(A) Use the procedures in appendix D to this part to determine heat input rate for that unit;
and
(B) Install, certify, operate, and maintain a flow monitoring system and a diluent monitor
in the duct to the common stack for each remaining unit; or
(2) Install, certify, operate, and maintain a NOx-diluent continuous emissions monitoring
system in the duct to the common stack from each unit and, for purposes of heat input
determination, either:
(i) Install, certify, operate, and maintain a flow monitoring system in the duct to the
common stack from each unit; or
(ii) For any unit using the common stack and eligible to use the procedures in appendix D
to this part,
(A) Use the procedures in appendix D to determine heat input rate for that unit; and
(B) Install, certify, operate, and maintain a flow monitoring system in the duct to the
common stack for each remaining unit.
(b) Unit utilizing common stack with nonaffected unit(s). When one or more affected units
utilizes a common stack with one or more nonaffected units, the owner or operator shall either:
(1) Install, certify, operate, and maintain a NOx-diluent continuous emission monitoring
system in the duct to the common stack from each affected unit and, for purposes of heat input
determination,
(1) Install, certify, operate, and maintain a flow monitoring system in the duct to the
common stack from each affected unit; or
(ii) For any affected unit using the common stack and eligible to use the procedures in
appendix D to this part,
(A) Use the procedures in appendix D to determine heat input for that unit; however, for a
common pipe configuration, the heat input apportionment provisions in section 2.1.2 of
appendix D to this part shall not be used to meet the NOx mass reporting provisions of this
subpart unless all of the units served by the common pipe are affected units and have similar
efficiencies; and
(B) Install, certify, operate, and maintain a flow monitoring system in the duct to the
common stack for each remaining affected unit that exhausts to the common stack; or
(2) Install, certify, operate, and maintain a NOx-diluent continuous emission monitoring
system in the common stack; and
(i) Designate the nonaffected units as affected units in accordance with the applicable
State or federal NOx mass emissions reduction program and meet the requirements of
paragraph (a)(1) of this section; or
(ii) Install, certify, operate, and maintain a flow monitoring system in the common stack
and a NOx-diluent continuous emission monitoring system in the duct to the common stack
from each nonaffected unit. The designated representative shall submit a petition to the
permitting authority and the Administrator to allow a method of calculating and reporting the
NOx mass emissions from the affected units as the difference between NOx mass emissions
measured in the common stack and NOx mass emissions measured in the ducts of the
nonaffected units, not to be reported as an hourly value less than zero. The permitting
authority and the Administrator may approve such a method whenever the designated
representative demonstrates, to the satisfaction of the permitting authority and the
Administrator, that the method ensures that the NOx mass emissions from the affected units are
not underestimated. In addition, the owner or operator shall also either:
(A) Install, certify, operate, and maintain a flow monitoring system in the duct from each
nonaffected unit or,
(B) For any nonaffected unit exhausting to the common stack and otherwise eligible to use
the procedures in appendix D to this part, determine heat input rate using the procedures in
appendix D for that unit. However, for a common pipe serving both affected and non-affected
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 169
-------
units, the heat input rate apportionment provisions in section 2.1.2 of appendix D to this part
shall not be used to meet the NOx mass reporting provisions of this subpart. For any remaining
nonaffected unit that exhausts to the common stack, install, certify, operate, and maintain a
flow monitoring system in the duct to the common stack; or
(iii) Install a flow monitoring system in the common stack and record the combined
emissions from all units as the combined NOx mass emissions for the affected units for
recordkeeping and compliance purposes, in accordance with paragraph (a) of this section; or
(iv) Submit a petition to the permitting authority and the Administrator to allow use of a
method for apportioning NOx mass emissions measured in the common stack to each of the
units using the common stack and for reporting the NOx mass emissions. The permitting
authority and the Administrator may approve such a method whenever the designated
representative demonstrates, to the satisfaction of the permitting authority and the
Administrator, that the method ensures that the NOx mass emissions from the affected units are
not underestimated.
§ 75.72(c)
§ 75.72(c)(1)
(c) Unit with a main stack and a bypass stack. Whenever any portion of the flue gases
from an affected unit can be routed through a bypass stack to avoid the installed NOx-diluent
continuous emissions monitoring system or NOx concentration monitoring system, the owner
and operator shall either:
(1) Install, certify, operate, and maintain separate NOx-diluent continuous emissions
monitoring systems and flow monitoring systems on the main stack and the bypass stack and
calculate NOx mass emissions for the unit as the sum of the NOx mass emissions measured at
the two stacks;
§ 75.72(c)(2)
§ 75.72(c)(3)
§ 75.72(d)
(2) Monitor NOx mass emissions at the main stack using a NOx-diluent CEMS and a flow
monitoring system and measure NOx mass emissions at the bypass stack using the reference
methods in § 75.22(b) for NOx concentration, flow rate, and diluent gas concentration, or NOx
concentration and flow rate, and calculate NOx mass emissions for the unit as the sum of the
emissions recorded by the installed monitoring systems on the main stack and the emissions
measured by the reference method monitoring systems; or
(3) Install, certify, operate, and maintain a NOx-diluent CEMS and a flow monitoring
system only on the main stack. If this option is chosen, it is not necessary to designate the
exhaust configuration as a multiple stack configuration in the monitoring plan required under
§ 75.53, since only the main stack is monitored. For each unit operating hour in which the
bypass stack is used and the emissions are either uncontrolled (or the add-on controls are not
documented to be operating properly), report NOx mass emissions as follows. If the unit heat
input is determined using a flow monitor and a diluent monitor, report NOx mass emissions
using the maximum potential NOx emission rate, the maximum potential flow rate, and either
the maximum potential C02 concentration or the minimum potential 02 concentration (as
applicable). The maximum potential NOx emission rate may be specific to the type of fuel
combusted in the unit during the bypass (see § 75.33(c)(8)). If the unit heat input is
determined using a fuel flowmeter, in accordance with appendix D to this part, report NOx
mass emissions as the product of the maximum potential NOx emission rate and the actual
measured hourly heat input rate. Alternatively, for a unit with NOx add-on emission controls,
for each unit operating hour in which the bypass stack is used but the add-on NOx emission
controls are not bypassed, the owner or operator may report the maximum controlled NOx
emission rate (MCR) instead of the maximum potential NOx emission rate provided that the
add-on controls are documented to be operating properly, as described in the quality
assurance/quality control program for the unit, required by section 1 in appendix B of this part.
To provide the necessary documentation, the owner or operator shall record parametric data to
verify the proper operation of the NOx add-on emission controls as described in § 75.34(d).
Furthermore, the owner or operator shall calculate the MCR using the procedure described in
section 2.1.2.1(b) of appendix A to this part by replacing the words "maximum potential NOx
emission rate (MER)" with the words "maximum controlled NOx emission rate (MCR)" and by
using the NOx MEC in the calculations instead of the NOx MPC.
(d) Unit with multiple stack or duct configuration. When the flue gases from an affected
unit discharge to the atmosphere through more than one stack, or when the flue gases from an
affected unit utilize two or more ducts feeding into a single stack and the owner or operator
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 170
-------
chooses to monitor in the ducts rather than in the stack, the owner or operator shall either:
§ 75.72(d)(1)
§ 75.72(d)(2)
§ 75.72(d)(3)
§ 75.72(e)
§ 75.72(f)
§ 75.72(g)
§ 75.73
§ 75.73(a)
(1) Install, certify, operate, and maintain a NOx-diluent continuous emission monitoring
system and a flow monitoring system in each of the multiple stacks and determine NOx mass
emissions from the affected unit as the sum of the NOx mass emissions recorded for each stack.
If another unit also exhausts flue gases into one of the monitored stacks, the owner or operator
shall comply with the applicable requirements of paragraphs (a) and (b) of this section, in order
to properly determine the NOx mass emissions from the units using that stack;
(2) Install, certify, operate, and maintain a NOx-diluent continuous emissions monitoring
system and a flow monitoring system in each of the ducts that feed into the stack, and
determine NOx mass emissions from the affected unit using the sum of the NOx mass emissions
measured at each duct, except that where another unit also exhausts flue gases to one or more
of the stacks, the owner or operator shall also comply with the applicable requirements of
paragraphs (a) and (b) of this section to determine and record NOx mass emissions from the
units using that stack; or
(3) If the unit is eligible to use the procedures in appendix D to this part and if the
conditions and restrictions of § 75.17(c)(2) are fully met, install, certify, operate, and maintain
a NOx-diluent continuous emissions monitoring system in one of the ducts feeding into the
stack or in one of the multiple stacks, (as applicable) in accordance with § 75.17(c)(2), and use
the procedures in appendix D to this part to determine heat input rate for the unit.
(e) Units using a NOx concentration monitoring system and a flow monitoring system to
determine NOx mass. The owner or operator may use a NOx concentration monitoring system
and a flow monitoring system to determine NOx mass emissions for the cases described in
paragraphs (a) through (c) of this section and in paragraph (d)(1) or paragraph (d)(2) of this
section (in place of a NOx-diluent continuous emissions monitoring system and a flow
monitoring system). However, this option may not be used for the case described in paragraph
(d)(3) of this section. When using this approach, calculate NOx mass according to sections 8.2
and 8.3 in appendix F to this part. In addition, if an applicable State or federal NOx mass
reduction program requires determination of a unit's heat input, the owner or operator must
either:
(1) Install, certify, operate, and maintain a C02 or 02 diluent monitor in the same location
as each flow monitoring system. In addition, the owner or operator must provide heat input
rate values for each unit utilizing a common stack. The owner or operator may either:
(1) Apportion heat input rate from the common stack to each unit according to
§ 75.16(e)(3), where all units utilizing the common stack are affected units, or
(ii) Measure heat input from each affected unit, using a flow monitor and a C02 or 02
diluent monitor in the duct from each affected unit; or
(2) For units that are eligible to use appendix D to this part, use the procedures in
appendix D to this part to determine heat input rate for the unit. However, the use of a fuel
flowmeter in a common pipe header and the provisions of sections 2.1.2.1 and 2.1.2.2 of
appendix D of this part are not applicable to any unit that is using the provisions of this subpart
to monitor, record, and report NOx mass emissions under a State or federal NOx mass emission
reduction program and that shares a common pipe with a nonaffected unit.
(f) [Reserved]
(g) Procedures for apportioning heat input to the unit level. If the owner or operator of a
unit using the common stack monitoring provisions in paragraphs (a) or (b) of this section does
not monitor and record heat input at the unit level and the owner or operator is required to do
so under an applicable State or federal NOx mass emission reduction program, apportion heat
input from the common stack to each unit according to § 75.16(e)(3).
§ 75.73 Recordkeeping and reporting.
(a) General recordkeeping provisions. The owner or operator of any affected unit shall
maintain for each affected unit and each non-affected unit under § 75.72(b)(2)(ii) a file of all
measurements, data, reports, and other information required by this part at the source in a form
suitable for inspection for at least three (3) years from the date of each record. Except for the
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 171
-------
§ 75.73(a)(1)
§ 75.73(a)(2)
§ 75.73(a)(3)
§ 75.73(a)(4)
§ 75.73(a)(5)
§ 75.73(a)(6)
§ 75.73(a)(7)
§ 75.73(a)(8)
§ 75.73(b)
§ 75.73(c)
§ 75.73(c)(1)
§ 75.73(c)(2)
certification data required in § 75.57(a)(4) and the initial submission of the monitoring plan
required in § 75.57(a)(5), the data shall be collected beginning with the earlier of the date of
provisional certification or the compliance deadline in § 75.70(b). The certification data
required in § 75.57(a)(4) shall be collected beginning with the date of the first certification test
performed. The file shall contain the following information:
(1) The information required in §§ 75.57(a)(2), (a)(4), (a)(5), (a)(6), (b), (c)(2), (d), (g),
and (h).
(2) The information required in §§ 75.58(b)(2) or (b)(3) (for units with add-on NOx
emission controls), as applicable, (d) (as applicable for units using Appendix E to this part),
and (f) (as applicable for units using the low mass emissions unit provisions of § 75.19).
(3) For each hour when the unit is operating, NOx mass emissions, calculated in
accordance with section 8.1 of appendix F to this part.
(4) During the second and third calendar quarters, cumulative ozone season heat input and
cumulative ozone season operating hours.
(5) Heat input and NOx methodologies for the hour.
(6) Specific heat input record provisions for gas-fired or oil-fired units using the
procedures in appendix D to this part. In lieu of the information required in § 75.57(c)(2), the
owner or operator shall record the information in § 75.58(c) for each affected gas-fired or oil-
fired unit and each non-affected gas- or oil-fired unit under § 75.72(b)(2)(ii) for which the
owner or operator is using the procedures in appendix D to this part for estimating heat input.
(7) Specific NOx record provisions for gas-fired or oil-fired units using the optional low
mass emissions excepted methodology in § 75.19. In lieu of recording the information in
§§ 75.57(b), (c)(2), (d), and (g), the owner or operator shall record, for each hour when the unit
is operating for any portion of the hour, the following information for each affected low mass
emissions unit for which the owner or operator is using the low mass emissions excepted
methodology in § 75.19(c):
(i) Date and hour;
(ii) If one type of fuel is combusted in the hour, fuel type (pipeline natural gas, natural gas,
residual oil, or diesel fuel) or, if more than one type of fuel is combusted in the hour, the fuel
type which results in the highest emission factors for NOx;
(iii) Average hourly NOx emission rate (in lb/mmBtu, rounded to the nearest thousandth);
and
(iv) Hourly NOx mass emissions (in lbs, rounded to the nearest tenth).
(8) Formulas from monitoring plan for total NOx mass.
(b) Certification, quality assurance and quality control record provisions. The owner or
operator of any affected unit shall record the applicable information in § 75.59 for each
affected unit or group of units monitored at a common stack and each non-affected unit under
§ 75.72(b)(2)(ii).
(c) Monitoring plan recordkeeping provisions.
(1) General provisions. The owner or operator of an affected unit shall prepare and
maintain a monitoring plan for each affected unit or group of units monitored at a common
stack and each non-affected unit under § 75.72(b)(2)(ii). Except as provided in paragraph (d)
or (f) of this section, a monitoring plan shall contain sufficient information on the continuous
emission monitoring systems, excepted methodology under § 75.19, or excepted monitoring
systems under appendix D or E to this part and the use of data derived from these systems to
demonstrate that all the unit's NOx emissions are monitored and reported.
(2) Whenever the owner or operator makes a replacement, modification, or change in the
certified continuous emission monitoring system, excepted methodology under § 75.19,
excepted monitoring system under appendix D or E to this part, or alternative monitoring
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 172
-------
§ 75.73(c)(3)
§ 75.73(d)
§ 75.73(d)(1)
§ 75.73(d)(2)
§ 75.73(d)(3)
§ 75.73(d)(4)
§ 75.73(d)(5)
§ 75.73(d)(6)
system under subpart E of this part, including a change in the automated data acquisition and
handling system or in the flue gas handling system, that affects information reported in the
monitoring plan (e.g., a change to a serial number for a component of a monitoring system),
then the owner or operator shall update the monitoring plan.
(3) Contents of the monitoring plan for units not subject to an Acid Rain emissions
limitation. Prior to January 1, 2009, each monitoring plan shall contain the information in
§75.53(e)(1) or §75.53(g)(1) in electronic format and the information in §75.53(e)(2) or
§75.53(g)(2) in hardcopy format. On and after January 1, 2009, each monitoring plan shall
contain the information in §75.53(g)(1) in electronic format and the information in
§75.53(g)(2) in hardcopy format, only. In addition, to the extent applicable, prior to January 1,
2009, each monitoring plan shall contain the information in §75.53(f)(l)(i), (f)(2)(i), and (f)(4)
or §75.53(h)(l)(i), and (h)(2)(i) in electronic format and the information in §75.53(f)(l)(ii) and
(f)(2)(ii) or §75.53(h)(l)(ii) and (h)(2)(ii) in hardcopy format. On and after January 1, 2009,
each monitoring plan shall contain the information in §75.53(h)(l)(i), and (h)(2)(i) in
electronic format and the information in §75.53(h)(l)(ii) and (h)(2)(ii) in hardcopy format,
only. For units using the low mass emissions excepted methodology under §75.19, prior to
January 1, 2009, the monitoring plan shall include the additional information in §75.53(f)(5)(i)
and (f)(5)(ii) or §75.53(h)(4)(i) and (h)(4)(ii). On and after January 1, 2009, for units using the
low mass emissions excepted methodology under §75.19 the monitoring plan shall include the
additional information in §75.53(h)(4)(i) and (h)(4)(ii), only. Prior to January 1, 2008, the
monitoring plan shall also identify, in electronic format, the reporting schedule for the affected
unit (ozone season or quarterly), and the beginning and end dates for the reporting schedule.
The monitoring plan also shall include a seasonal controls indicator, and an ozone season fuel-
switching flag.
(d) General reporting provisions.
(1) The designated representative for an affected unit shall comply with all reporting
requirements in this section and with any additional requirements set forth in an applicable
State or federal NOx mass emission reduction program that adopts the requirements of this
subpart.
(2) The designated representative for an affected unit shall submit the following for each
affected unit or group of units monitored at a common stack and each non-affected unit under
§ 75.72(b)(2)(ii):
(i) Initial certification and recertification applications in accordance with § 75.70(d);
(ii) Monitoring plans in accordance with paragraph (e) of this section; and
(iii) Quarterly reports in accordance with paragraph (f) of this section.
(3) Other petitions and communications. The designated representative for an affected
unit shall submit petitions, correspondence, application forms, and petition-related test results
in accordance with the provisions in § 75.70(h).
(4) Quality assurance RATA reports. If requested by the permitting authority, the
designated representative of an affected unit shall submit the quality assurance RATA report
for each affected unit or group of units monitored at a common stack and each non-affected
unit under § 75.72(b)(2)(ii) by the later of 45 days after completing a quality assurance RATA
according to section 2.3 of appendix B to this part or 15 days of receiving the request. The
designated representative shall report the hardcopy information required by §75.59(a)(9) to the
permitting authority.
(5) Notifications. The designated representative for an affected unit shall submit written
notice to the permitting authority according to the provisions in §75.61 for each affected unit
or group of units monitored at a common stack and each non-affected unit under
§ 75.72(b)(2)(ii).
(6) Routine appendix E retest reports. If requested by the applicable EPA Regional
Office, appropriate State, and/or appropriate local air pollution control agency, the designated
representative shall submit a hardcopy report within 45 days after completing a required
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 173
-------
§ 75.73(e)
§ 75.73(e)(1)
§ 75.73(e)(2)
periodic retest according to section 2.2 of appendix E to this part, or within 15 days of
receiving the request, whichever is later. The designated representative shall report the
hardcopy information required by § 75.59(b)(5) to the applicable EPA Regional Office,
appropriate State, and/or appropriate local air pollution control agency that requested the
hardcopy report.
(e) Monitoring plan reporting.
(1) Electronic submission. The designated representative for an affected unit shall submit
to the Administrator a complete, electronic, up-to-date monitoring plan file for each affected
unit or group of units monitored at a common stack and each non-affected unit under
§ 75.72(b)(2)(ii), no later than 21 days prior to the initial certification test; at the time of a
certification or recertification application submission; and whenever an update of the electronic
monitoring plan is required, either under § 75.53 or elsewhere in this part.
(2) Hardcopy submission. The designated representative of an affected unit shall submit
all of the hardcopy information required under § 75.53, for each affected unit or group of units
monitored at a common stack and each nonaffected unit under § 75.72(b)(2)(ii), to the
permitting authority prior to initial certification. Thereafter, the designated representative shall
submit hardcopy information only if that portion of the monitoring plan is revised. The
designated representative shall submit the required hardcopy information as follows: no later
than 21 days prior to the initial certification test; with any certification or recertification
application, if a hardcopy monitoring plan change is associated with the recertification event;
and within 30 days of any other event with which a hardcopy monitoring plan change is
associated, pursuant to § 75.53(b). Electronic submittal of all monitoring plan information,
including hardcopy portions, is permissible provided that a paper copy of the hardcopy
portions can be furnished upon request.
§ 75.73(f) (f) Quarterly reports.
§ 75.73(f)(1) (1) Electronic submission. The designated representative for an affected unit shall
electronically report the data and information in this paragraph (f)(1) and in paragraphs (f)(2)
and (3) of this section to the Administrator quarterly, unless the unit has been placed in long-
term cold storage (as defined in §72.2 of this chapter). For units placed into long-term cold
storage during a reporting quarter, the exemption from submitting quarterly reports begins with
the calendar quarter following the date that the unit is placed into long-term cold storage. In
such cases, the owner or operator shall submit quarterly reports for the unit beginning with the
data from the quarter in which the unit recommences operation (where the initial quarterly
report contains hourly data beginning with the first hour of recommenced operation of the
unit). Each electronic report must be submitted to the Administrator within 30 days following
the end of each calendar quarter. Except as otherwise provided in §75.64(a)(4) and (a)(5),
each electronic report shall include the information provided in paragraphs (f)(l)(i) through
(l)(vi) of this section, and shall also include the date of report generation. Prior to January 1,
2009, each report shall include the facility information provided in paragraphs (f)(l)(i)(A) and
(B) of this section, for each affected unit or group of units monitored at a common stack. On
and after January 1, 2009, only the facility identification information provided in paragraph
(f)(l)(i)(A) is required.
§ 75.73(f)(l)(i) (i) Facility information:
(A) Identification, including:
(1) Facility/ORISPL number;
(2) Calendar quarter and year data contained in the report; and
(3) Electronic data reporting format version used for the report.
(B) Location of facility, including:
(1) Plant name and facility identification code;
(2) EPA AIRS facility system identification code;
(3) State facility identification code;
(4) Source category/type;
(5) Primary SIC code;
(6) State postal abbreviation;
(7) FIPS county code; and
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 174
-------
(8) Latitude and longitude.
§75.73(f)(l)(ii)
(ii) The information and hourly data required in paragraphs (a) and (b) of this section,
except for:
(A) Descriptions of adjustments, corrective action, and maintenance;
(B) Information which is incompatible with electronic reporting (e.g., field data sheets, lab
analyses, quality control plan);
(C) For units with NOx add-on emission controls that do not elect to use the approved site-
specific parametric monitoring procedures for calculation of substitute data, the information in
§ 75.58(b)(3);
(D) Information required by § 75.57(h) concerning the causes of any missing data periods
and the actions taken to cure such causes;
(E) Hardcopy monitoring plan information required by § 75.53 and hardcopy test data and
results required by § 75.59;
(F) Records of flow polynomial equations and numerical values required by
§ 75.59(a)(5)(vi);
(G) Daily fuel sampling information required by § 75.58(c)(3)(i) for units using assumed
values under appendix D;
(H) Information required by § 75.59(b)(2) concerning transmitter or transducer accuracy
tests;
(I) Stratification test results required as part of the RATA supplementary records under
§ 75.59(a)(7);
(J) Data and results of RAT As that are aborted or invalidated due to problems with the
reference method or operational problems with the unit and data and results of linearity checks
that are aborted or invalidated due to operational problems with the unit; and
(K) Supplementary RATA information required under §75.59(a)(7), except that:
(/) The applicable data elements under §75.59(a)(7)(ii)(A) through (T) and under
§75.59(a)(7)(iii)(A) through (M) shall be reported for flow RAT As at circular or rectangular
stacks (or ducts) in which angular compensation for yaw and/or pitch angles is used (i.e.,
Method 2F or 2G in appendices A-l and A-2 to part 60 of this chapter), with or without wall
effects adjustments;
(2) The applicable data elements under §75.59(a)(7)(ii)(A) through (T) and under
§75.59(a)(7)(iii)(A) through (M) shall be reported for any flow RATA run at a circular stack in
which Method 2 in appendices A-l and A-2 to part 60 of this chapter is used and a wall effects
adjustment factor is determined by direct measurement;
(3) The data under §75.59(a)(7)(ii)(T) shall be reported for all flow RATAs at circular
stacks in which Method 2 in appendices A-l and A-2 to part 60 of this chapter is used and a
default wall effects adjustment factor is applied; and
(4) The data under §75.59(a)(7)(ix)(A) through (F) shall be reported for all flow RATAs
at rectangular stacks or ducts in which Method 2 in appendices A-l and A-2 to part 60 of this
chapter is used and a wall effects adjustment factor is applied.
§75.73(f)(l)(iii)
§ 75.73(f)(l)(iv)
(iii) Average NOx emission rate (lb/mmBtu, rounded to the nearest thousandth) during the
quarter and cumulative NOx emission rate for the calendar year.
(iv) Tons of NOx emitted during quarter, cumulative tons of NOx emitted during the year,
and, during the second and third calendar quarters, cumulative tons of NOx emitted during the
ozone season.
§75.73(f)(l)(v)
§75.73(f)(l)(vi)
(v) During the second and third calendar quarters, cumulative heat input for the ozone
season.
(vi) Unit or stack or common pipe header operating hours for quarter, cumulative unit,
stack or common pipe header operating hours for calendar year, and, during the second and
third calendar quarters, cumulative operating hours during the ozone season.
§75.73(f)(l)(vii)
§75.73 (f) (1) (viii)
(vii) Reporting period heat input.
(viii) New reporting frequency and begin date of the new reporting frequency (if
applicable).
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 175
-------
§ 75.73(f)(2)
§ 75.73(f)(3)
§ 75.73(f)(4)
§ 75.74
§ 75.74(a)
§ 75.74(b)
§ 75.74(c)
§ 75.74(c)(1)
§ 75.74(c)(2)
§ 75.74(c)(2)®
(2) The designated representative shall certify that the component and system
identification codes and formulas in the quarterly electronic reports submitted to the
Administrator pursuant to paragraph (e) of this section represent current operating conditions.
(3) Compliance certification. The designated representative shall submit and sign a
compliance certification in support of each quarterly emissions monitoring report based on
reasonable inquiry of those persons with primary responsibility for ensuring that all of the
unit's emissions are correctly and fully monitored. The certification shall state that:
(1) The monitoring data submitted were recorded in accordance with the applicable
requirements of this part, including the quality assurance procedures and specifications; and
(ii) With regard to a unit with add-on emission controls and for all hours where data are
substituted in accordance with § 75.34(a)(1), the add-on emission controls were operating
within the range of parameters listed in the monitoring plan and the substitute values do not
systematically underestimate NOx emissions.
(4) The designated representative shall comply with all of the quarterly reporting
requirements in §§ 75.64(d), (f), and (g).
§ 75.74 Annual and ozone season monitoring and reporting requirements.
(a) Annual monitoring requirement. (1) The owner or operator of an affected unit subject
both to an Acid Rain emission limitation and to a State or federal NOx mass reduction program
that adopts the provisions of this part must meet the requirements of this part during the entire
calendar year.
(2) The owner or operator of an affected unit subject to a State or federal NOx mass
reduction program that adopts the provisions of this part and that requires monitoring and
reporting of hourly emissions on an annual basis must meet the requirements of this part during
the entire calendar year.
(b) Ozone season monitoring requirements. The owner or operator of an affected unit that
is not required to meet the requirements of this subpart on an annual basis under paragraph (a)
may either:
(1) Meet the requirements of this subpart on an annual basis; or
(2) Meet the requirements of this subpart during the ozone season, except as specified in
paragraph (c) of this section.
(c) If the owner or operator of an affected unit chooses to meet the requirements of this
subpart on less than an annual basis in accordance with paragraph (b)(2) of this section, then:
(1) The owner or operator of a unit that uses continuous emissions monitoring systems or a
fuel flowmeter to meet any of the requirements of this subpart shall quality assure the hourly
ozone season emission data required by this subpart. To achieve this, the owner or operator
shall operate, maintain and calibrate each required CEMS and shall perform diagnostic testing
and quality assurance testing of each required CEMS or fuel flowmeter according to the
applicable provisions of paragraphs (c)(2) through (c)(5) of this section. Except where
otherwise noted, the provisions of paragraphs (c)(2) and (c)(3) of this section apply instead of
the quality assurance provisions in sections 2.1 through 2.3 of appendix B to this part, and
shall be used in lieu of those appendix B provisions.
(2) Quality assurance requirements prior to the ozone season. The provisions of this
paragraph apply to each ozone season. The owner or operator shall, at a minimum, perform
the following diagnostic testing and quality assurance assessments, and shall maintain the
following records, to ensure that the hourly emission data recorded at the beginning of the
current ozone season are suitable for reporting as quality-assured data:
(i) For each required gas monitor (i.e., for each NOx pollutant concentration monitor and
each diluent gas (C02 or 02) monitor, including C02 and 02 monitors used exclusively for heat
input determination and 02 monitors used for moisture determination), a linearity check shall
be performed and passed in the second calendar quarter no later than April 30.
(A) Conduct each linearity check in accordance with the general procedures in section 6.2
of appendix A to this part, except that the data validation procedures in sections 6.2(a) through
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 176
-------
(f) of appendix A do not apply.
(B) Each linearity check shall be done "hands-off," as described in section 2.2.3(c) of
appendix B to this part.
(C) In the time period extending from the date and hour in which the linearity check is
passed through April 30, the owner or operator shall operate and maintain the CEMS and shall
perform daily calibration error tests of the CEMS in accordance with section 2.1 of appendix B
to this part. When a calibration error test is failed, as described in section 2.1.4 of appendix B
to this part, corrective actions shall be taken. The additional calibration error test provisions of
section 2.1.3 of appendix B to this part shall be followed.
(D) If the linearity check is not completed by April 30, data validation shall be determined
in accordance with paragraph (c)(3)(ii)(E) of this section.
§ 75.74(c)(2)(ii)
(ii) For each required CEMS (i.e., for each NOx concentration monitoring system, each
NOx-diluent monitoring system, each flow rate monitoring system, each moisture monitoring
system and each diluent gas CEMS used exclusively for heat input determination), a relative
accuracy test audit (RATA) shall be performed and passed in the first or second calendar
quarter, but no later than April 30.
§ 75.74(c)(2)(ii)(A)
(A) Conduct each RATA in accordance with the applicable procedures in sections 6.5
through 6.5.10 of appendix A to this part, except that the data validation procedures in sections
6.5(f)(1) through (f)(6) do not apply, and, for flow rate monitoring systems, the required
RATA load level(s) (or operating level(s)) shall be as specified in this paragraph.
§ 75.74(c)(2)(ii)(B)
(B) Each RATA shall be done "hands-off," as described in section 2.3.2 (c) of appendix B
to this part. The provisions in section 2.3.1.4 of appendix B to this part, pertaining to the
number of allowable RATA attempts, shall apply.
§ 75.74(c)(2)(ii)(C)
(C) For flow rate monitoring systems installed on peaking units or bypass stacks and for
flow monitors exempted from multiple-level RATA testing under section 6.5.2 (e) of appendix
A to this part, a single-load (or single-level) RATA is required. For all other flow rate
monitoring systems, a 2-load (or 2-level) RATA is required at the two most frequently-used
load or operating levels (as defined under section 6.5.2.1 of appendix A to this part), with the
following exceptions. Except for flow monitors exempted from 3-level RATA testing under
section 6.5.2 (e) of appendix A to this part, a 3-load flow RATA is required at least once every
five years and is also required if the flow monitor polynomial coefficients or K factor(s) are
changed prior to conducting the flow RATA required under this paragraph.
§ 75.74(c)(2)(ii)(D)
(D) A bias test of each required NOx concentration monitoring system, each NOx-diluent
monitoring system and each flow rate monitoring system shall be performed in accordance
with section 7.6 of appendix A to this part. If the bias test is failed, a bias adjustment factor
(BAF) shall be calculated for the monitoring system, as described in section 7.6.5 of appendix
A to this part and shall be applied to the subsequent data recorded by the CEMS.
§ 75.74(c)(2)(ii)(E)
(E) In the time period extending from the hour of completion of the required RATA
through April 30, the owner or operator shall operate and maintain the CEMS by performing,
at a minimum, the following activities:
(/) The owner or operator shall perform daily calibration error tests and (if applicable)
daily flow monitor interference checks, according to section 2.1 of appendix B to this part.
When a daily calibration error test or interference check is failed, as described in section 2.1.4
of appendix B to this part, corrective actions shall be taken. The additional calibration error
test provisions in section 2.1.3 of appendix B to this part shall be followed. Records of the
required daily calibration error tests and interference checks shall be kept in a format suitable
for inspection on a year-round basis.
(2) If the owner or operator makes a replacement, modification, or change in a certified
monitoring system that significantly affects the ability of the system to accurately measure or
record NOx mass emissions or heat input or to meet the requirements of § 75.21 or appendix B
to this part, the owner or operator shall recertify the monitoring system according to
§ 75.20(b).
§ 75.74(c)(2)(ii)(F)
(F) Data Validation.
For each RATA that is performed by April 30, data validation shall be done according to
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 177
-------
sections 2.3.2(a) - (j) of appendix B to this part. However, if a required RATA is not
completed by April 30, data from the monitoring system shall be invalid, beginning with the
first unit operating hour on or after May 1. The owner or operator shall continue to invalidate
all data from the CEMS until either:
(/) The required RATA of the CEMS has been performed and passed; or
(2) A probationary calibration error test of the CEMS is passed in accordance with
§75.20(b)(3)(ii). Once the probationary calibration error test has been passed, the owner or
operator shall perform the required RATA in accordance with the conditional data validation
provisions and within the 720 unit or stack operating hour time frame specified in §75.20(b)(3)
(subject to the restrictions in paragraph (c)(3)(xii) of this section), and the term "quality
assurance" shall apply instead of the term "recertification." However, in lieu of the provisions
in §75.20(b)(3)(ix), the owner or operator shall follow the applicable provisions in paragraphs
(c)(3)(xi) and (c)(3)(xii) of this section.
§ 75.74(c)(3) (3) Quality assurance requirements within the ozone season. The provisions of this
paragraph apply to each ozone season. The owner or operator shall, at a minimum, perform
the following quality assurance testing during the ozone season, i.e., in the time period
extending from May 1 through September 30 of each calendar year:
§ 75.74(c)(3)(i) (i) Daily calibration error tests and (if applicable) interference checks of each CEMS
required by this subpart shall be performed in accordance with sections 2.1.1 and 2.1.2 of
appendix B to this part. The applicable provisions in sections 2.1.3, 2.1.4 and 2.1.5 of
appendix B to this part, pertaining, respectively, to additional calibration error tests and
calibration adjustments, data validation, and quality assurance of data with respect to daily
assessments, shall also apply.
§ 75.74(c)(3)(ii) (ii) For each gas monitor required by this subpart, linearity checks shall be performed in
the second and third calendar quarters, as follows:
(A) For the second calendar quarter, the pre-ozone season linearity check required under
paragraph (c)(2)(i) of this section shall be performed by April 30.
(B) For the third calendar quarter, a linearity check shall be performed and passed no later
than July 30.
(C) Conduct each linearity check in accordance with the general procedures in section 6.2
of appendix A to this part, except that the data validation procedures in sections 6.2(a) through
(f) of appendix A do not apply.
(D) Each linearity check shall be done "hands-off," as described in section 2.2.3(c) of
appendix B to this part.
(E) Data Validation. For second and third quarter linearity checks performed by the
applicable deadline (i.e., April 30 or July 30), data validation shall be done in accordance with
sections 2.2.3(a), (b), (c), (e), and (h) of Appendix B to this part. However, if a required
linearity check for the second calendar quarter is not completed by April 30, or if a required
linearity check for the third calendar quarter is not completed by July 30, data from the
monitoring system (or range) shall be invalid, beginning with the first unit operating hour on or
after May 1 or July 31, respectively. The owner or operator shall continue to invalidate all
data from the CEMS until either:
(1) The required linearity check of the CEMS has been performed and passed; or
(2) A probationary calibration error test of the CEMS is passed in accordance with
§75.20(b)(3)(ii). Once the probationary calibration error test has been passed, the owner or
operator shall perform the required linearity check in accordance with the conditional data
validation provisions and within the 168 unit or stack operating hour time frame specified in
§75.20(b)(3) (subject to the restrictions in paragraph (c)(3)(xii) of this section), and the term
"quality assurance" shall apply instead of the term "recertification." However, in lieu of the
provisions in §75.20(b)(3)(ix), the owner or operator shall follow the applicable provisions in
paragraphs (c)(3)(xi) and (c)(3)(xii) of this section.
(F) A pre-season linearity check performed and passed in April satisfies the linearity check
requirement for the second quarter.
(G) The third quarter linearity check requirement in paragraph (c)(3)(ii)(B) of this section
is waived if:
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 178
-------
(/) Due to infrequent unit operation, the 168 operating hour conditional data validation
period associated with a pre-season linearity check extends into the third quarter; and
(2) A linearity check is performed and passed within that conditional data validation
period.
§ 75.74(c)(3)(iii)
§ 75.74(c)(3)(iv)
§ 75.74(c)(3)(v)
§ 75.74(c)(3)(ix)
§ 75.74(c)(3)(x)
(iii) For each flow monitoring system required by this subpart, except for flow monitors
installed on non-load-based units that do not produce electrical or thermal output, flow-to-load
ratio tests are required in the second and third calendar quarters, in accordance with section
2.2.5 of appendix B to this part. If the flow-to-load ratio test for the second calendar quarter is
failed, the owner or operator shall follow the procedures in section 2.2.5(c)(8) of appendix B to
this part. If the flow-to-load ratio test for the third calendar quarter is failed, data from the
flow monitor shall be considered invalid at the beginning of the next ozone season unless, prior
to May 1 of the next calendar year, the owner or operator has either successfully implemented
Option 1 in section 2.2.5.1 of appendix B to this part or Option 2 in section 2.2.5.2 of appendix
B to this part, or unless a flow RATA has been performed and passed in accordance with
paragraph (c)(2)(ii) of this section.
(iv) For each differential pressure-type flow monitor used to meet the requirements of this
subpart, quarterly leak checks are required in the second and third calendar quarters, in
accordance with section 2.2.2 of appendix B to this part. For the second calendar quarter of
the year, only the unit or stack operating hours in the months of May and June shall be used to
determine whether the second calendar quarter is a QA operating quarter (as defined in § 72.2
of this chapter). Data validation for quarterly flow monitor leak checks shall be done in
accordance with section 2.2.3(g) of appendix B to this part. If the leak check for the third
calendar quarter is failed and a subsequent leak check is not passed by the end of the ozone
season, then data from the flow monitor shall be considered invalid at the beginning of the next
ozone season unless a leak check is passed prior to May 1 of the next calendar year.
(v) A fuel flow-to-load ratio test in section 2.1.7 of appendix D to this part shall be
performed in the second and third calendar quarters if, for a unit using a fuel flowmeter to
determine heat input under this subpart, the owner or operator has elected to use the fuel flow-
to-load ratio test to extend the deadline for the next fuel flowmeter accuracy test. Automatic
deadline extensions may be claimed for the two calendar quarters outside the ozone season (the
first and fourth calendar quarters), since a fuel flow-to-load ratio test is not required in those
quarters. If a fuel flow-to-load ratio test is failed, follow the applicable procedures and data
validation provisions in section 2.1.7.4 of appendix D to this part. If the fuel flow-to-load ratio
test for the third calendar quarter is failed, data from the fuel flowmeter shall be considered
invalid at the beginning of the next ozone season unless the requirements of section 2.1.7.4 of
appendix D to this part have been fully met prior to May 1 of the next calendar year.
(ix) If, for any required CEMS, diagnostic linearity checks or RAT As other than those
required by this section are performed during the ozone season, use the applicable data
validation procedures in section 2.2.3 (for linearity checks) or 2.3.2 (for RAT As) of appendix
B to this part.
(x) If any required CEMS is recertified within the ozone season, use the data validation
provisions in § 75.20(b)(3) and, if applicable, paragraphs (c)(3)(xi) and (c)(3)(xii) of this
section.
§ 75.74(c)(3)(xi)
(xi) If, at the end of the second quarter of any calendar year, a required quality assurance,
diagnostic, or recertification test of a monitoring system has not been completed, and if data
contained in the quarterly report are conditionally valid pending the results of test(s) to be
completed in a subsequent quarter, the owner or operator shall indicate this by means of a
suitable conditionally valid data flag in the electronic quarterly report for the second calendar
quarter. The owner or operator shall resubmit the report for the second quarter if the required
quality assurance, diagnostic, or recertification test is subsequently failed. In the resubmitted
report, the owner or operator shall use the appropriate missing data routine in §§75.31 through
75.37 to replace with substitute data each hour of conditionally valid data that was invalidated
by the failed quality assurance, diagnostic, or recertification test. Alternatively, if any required
quality assurance, diagnostic, or recertification test is not completed by the end of the second
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 179
-------
calendar quarter but is completed no later than 30 days after the end of that quarter (i.e., prior
to the deadline for submitting the quarterly report under §75.73), the test data and results may
be submitted with the second quarter report even though the test date(s) are from the third
calendar quarter. In such instances, if the quality assurance, diagnostic, or recertification
test(s) are passed in accordance with the conditional data validation provisions of §75.20(b)(3),
conditionally valid data may be reported as quality-assured, in lieu of reporting a conditional
data flag. If the tests are failed and if conditionally valid data are replaced, as appropriate,
with substitute data, then neither the reporting of a conditional data flag nor resubmission is
required.
§ 75.74(c)(3)(xii) (xii) If, at the end of the third quarter of any calendar year, a required quality assurance,
diagnostic or recertification test of a monitoring system has not been completed, and if data
contained in the quarterly report are conditionally valid pending the results of test(s) to be
completed, the owner or operator shall do one of the following:
§ 75.74(c)(3)(xii)(A) (A) If the results of the required tests are not available within 30 days of the end of the
third calendar quarter and cannot be submitted with the quarterly report for the third calendar
quarter, then the test results are considered to be missing and the owner or operator shall use
the appropriate missing data routine in §§75.31 through 75.37 to replace with substitute data
each hour of conditionally valid data in the third quarter report. In addition, if the data in the
second quarterly report were flagged as conditionally valid at the end of the quarter, pending
the results of the same missing tests, the owner or operator shall resubmit the report for the
second quarter and shall use the appropriate missing data routine in §§75.31 through 75.37 to
replace with substitute data each hour of conditionally valid data associated with the missing
quality assurance, diagnostic, or recertification tests; or
§ 75.74(c)(3)(xii)(B) (B) If the required quality assurance, diagnostic, or recertification tests are completed no
later than 30 days after the end of the third calendar quarter, the test data and results may be
submitted with the third quarter report even though the test date(s) are from the fourth calendar
quarter. In this instance, if the required tests are passed in accordance with the conditional data
validation provisions of §75.20(b)(3), all conditionally valid data associated with the tests shall
be reported as quality assured. If the tests are failed, the owner or operator shall use the
appropriate missing data routine in §§75.31 through 75.37 to replace with substitute data each
hour of conditionally valid data associated with the failed test(s). In addition, if the data in the
second quarterly report were flagged as conditionally valid at the end of the quarter, pending
the results of the same failed test(s), the owner or operator shall resubmit the report for the
second quarter and shall use the appropriate missing data routine in §§75.31 through 75.37 to
replace with substitute data each hour of conditionally valid data associated with the failed
test(s).
§ 75.74(c)(4) (4) The owner or operator of a unit using the procedures in appendix D of this part to
determine heat input rate is required to maintain fuel flowmeters only during the ozone season,
except that for purposes of determining the deadline for the next periodic quality assurance test
on the fuel flowmeter, the owner or operator shall include all fuel flowmeter QA operating
quarters (as defined in § 72.2) for the entire calendar year, not just fuel flowmeter QA
operating quarters in the ozone season. For each calendar year, the owner or operator shall
record, for each fuel flowmeter, the number of fuel flowmeter QA operating quarters. The
owner or operator shall include all calendar quarters in the year when determining the deadline
for visual inspection of the primary fuel flowmeter element, as specified in section 2.1.6(c) of
appendix D to this part.
§ 75.74(c)(5) (5) The owner or operator of a unit using the procedures in appendix D of this part to
determine heat input rate is only required to sample fuel for the purposes of determining
density and GCV during the ozone season, except that:
(i) The owner or operator of a unit that performs sampling from the fuel storage tank upon
delivery must sample the tank between the date and hour of the most recent delivery before the
first date and hour that the unit operates in the ozone season and the first date and hour that the
unit operates in the ozone season.
(ii) The owner or operator of a unit that performs sampling upon delivery from the
delivery vehicle must ensure that all shipments received during the calendar year are sampled.
(iii) The owner or operator of a unit that performs sampling on each day the unit combusts
fuel or that performs fuel sampling continuously must sample the fuel starting on the first day
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 180
-------
the unit operates during the ozone season. The owner or operator then shall use that sampled
value for all hours of combustion during the first day of unit operation, continuing until the
date and hour of the next sample.
§ 75.74(c)(6) (6) The owner or operator shall, in accordance with § 75.73, record and report the hourly
data required by this subpart and shall record and report the results of all required quality
assurance tests, as follows:
(i) All hourly emission data for the period of time from May 1 through September 30 of
each calendar year shall be recorded and reported. For missing data purposes, only the data
recorded in the time period from May 1 through September 30 shall be considered quality-
assured;
(ii) The results of all daily calibration error tests and flow monitor interference checks
performed in the time period from May 1 through September 30 shall be recorded and
reported;
(iii) For the time periods described in paragraphs (c)(2)(i)(C) and (c)(2)(ii)(E) of this
section, hourly emission data and the results of all daily calibration error tests and flow monitor
interference checks shall be recorded. The results of all daily calibration error tests and flow
monitor interference checks performed in the time period from April 1 through April 30 shall
be reported. The owner or operator may opt to report unit operating data, daily calibration
error test and flow monitor interference check results, and hourly emission data in the time
period from April 1 through April 30. However, only the data recorded in the time period
from May 1 through September 30 shall be used for NOx mass compliance determination;
(iv) The results of all required quality assurance tests (RATAs, linearity checks, flow-to-
load ratio tests and leak checks) performed during the ozone season shall be reported in the
appropriate ozone season quarterly report; and
(v) The results of RATAs (and any other quality assurance test(s) required under
paragraph (c)(2) or (c)(3) of this section) which affect data validation for the current ozone
season, but which were performed outside the ozone season (i.e., between January 1 and April
30 of the current calendar year), shall be reported in the quarterly report for the second quarter
of the current calendar year (or in the report for the third calendar quarter of the current
calendar year, if the unit or stack does not operate in the second quarter).
§ 75.74(c)(7) (7) The owner or operator shall use only quality-assured data from within ozone seasons in
the substitute data procedures under subpart D of this part and section 2.4.2 of appendix D to
this part.
§ 75.74(c)(7)(i) (i) The lookback periods (e.g., 2160 quality-assured monitor operating hours for a NOx-
diluent continuous emission monitoring system, a NOx concentration monitoring system, or a
flow monitoring system) used to calculate missing data must include only quality-assured data
from periods within ozone seasons.
§ 75.74(c)(7)(ii) (ii) The applicable missing data procedures of §§ 75.31 through 75.37 shall be used, with
one exception. When a fuel which has a significantly higher NOx emission rate than any of the
fuel(s) combusted in prior ozone seasons is combusted in the unit, and no quality-assured NOx
data have been recorded in the current, or any previous, ozone season while combusting the
new fuel, the owner or operator shall substitute the maximum potential NOx emission rate, as
defined in § 72.2 of this chapter, from a NOx-diluent continuous emission monitoring system,
or the maximum potential concentration of NOx, as defined in section 2.1.2.1 of appendix A to
this part, from a NOx concentration monitoring system. The maximum potential value used
shall be specific to the new fuel. The owner or operator shall substitute the maximum potential
value for each hour of missing NOx data until the first hour that quality-assured NOx data are
obtained while combusting the new fuel, and then shall resume use of the missing data routines
in§§ 75.31 through 75.37 ; and
§ 75.74(c)(7)(iii) (iii) In order to apply the missing data routines described in §§ 75.31 through 75.37 on an
ozone season-only basis, the procedures in those sections shall be modified as follows:
(A) The use of the initial missing data procedures in § 75.31 shall commence with the first
unit operating hour in the first ozone season for which emissions data are required to be
reported under § 75.64.
(B) In § 75.31(a), the phrases "During the first 720 quality-assured monitor operating
hours within the ozone season" and "during the first 2,160 quality-assured monitor operating
hours within the ozone season" apply respectively instead of the phrases "During the first 720
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 181
-------
quality-assured monitor operating hours" and "during the first 2,160 quality-assured monitor
operating hours."
(C) In § 75.32(a), the phrases "the first 720 quality-assured monitor operating hours within
the ozone season" and "the first 2,160 quality-assured monitor operating hours within the
ozone season" apply, respectively, instead of the phrases "the first 720 quality-assured monitor
operating hours" and "the first 2,160 quality-assured monitor operating hours."
(D) In § 75.32(a)(1), the phrase "Following initial certification, prior to completion of
3,672 unit (or stack) operating hours within the ozone season" applies instead of the phrase
"Prior to completion of 8,760 unit (or stack) operating hours following initial certification".
(E) In Equation 8, the phrase "Total unit operating hours within the ozone season" applies
instead of the phrase "Total unit operating hours."
(F) In § 75.32(a)(2), the phrase "3,672 unit (or stack) operating hours within the ozone
season" applies instead of the phrase "8,760 unit (or stack) operating hours."
(G) In the numerator of Equation 9, the phrase "Total unit operating hours within the
ozone season" applies instead of the phrase "Total unit operating hours," and the phrase "3,672
unit operating hours within the ozone season" applies instead of the phrase "8,760 unit
operating hours." In the denominator of Equation 9, the number "3,672" applies instead of
"8,760."
(H) Use the following instead of the first three sentences in § 75.32(a)(3): "When
calculating percent monitor data availability using Equation 8 or 9, the owner or operator shall
include all unit or stack operating hours within the ozone season, and all monitor operating
hours within the ozone season for which quality-assured data were recorded by a certified
primary monitor; a certified redundant or non-redundant backup monitor or a reference method
for that unit; or by an approved alternative monitoring system under subpart E of this part. No
hours from more than three years (26,280 clock hours) earlier shall be used in Equation 9. For
a unit that has accumulated fewer than 3,672 ozone season operating hours in the previous
three years, use the following: in the numerator of Equation 9 use 'Total unit operating hours
within the ozone season for which quality-assured data were recorded in the previous three
years'; and in the denominator of Equation 9 use 'Total unit operating hours within the ozone
season, in the previous three years'."
(I) In § 75.33(a), the phrases "the first 720 quality-assured monitor operating hours within
the ozone season" and "the first 2,160 quality-assured monitor operating hours within the
ozone season" apply, respectively, instead of the phrases "the first 720 quality-assured monitor
operating hours" and "the first 2,160 quality-assured monitor operating hours".
(J) Instead of the last sentence of § 75.33(a), use "For the purposes of missing data
substitution, the owner or operator of a unit shall use only quality-assured monitor operating
hours of data that were recorded within the ozone season and no more than three years (26,280
clock hours) prior to the date and time of the missing data period."
(K) In §§ 75.33(b), 75.33(c), 75.35, 75.36, and 75.37, the phrases "720 quality-assured
monitor operating hours within the ozone season" and "2,160 quality-assured monitor
operating hours within the ozone season" apply, respectively, instead of the phrases "720
quality-assured monitor operating hours" and "2,160 quality-assured monitor operating hours."
(L) In § 75.34(a)(3) and (a)(5), the phrases "720 quality-assured monitor operating hours
within the ozone season" and "2160 quality-assured monitor operating hours within the ozone
season" apply instead of "720 quality-assured monitor operating hours" and "2160 quality-
assured monitor operating hours", respectively.
§ 75.74(c)(8) (8) The owner or operator of a unit with NOx add-on emission controls or a unit capable of
combusting more than one fuel shall keep records during ozone season in a form suitable for
inspection to demonstrate that the typical NOx emission rate or NOx concentration during the
prior ozone season(s) included in the missing data lookback period is representative of the
ozone season in which missing data are substituted and that use of the missing data procedures
will not systematically underestimate NOx mass emissions. These records shall include:
(i) For units that can combust more than one fuel, the fuel or fuels combusted each hour;
and
(ii) For units with add-on emission controls, using the missing data options in
§§75.34(a)(1) through 75.34(a)(5), the range of operating parameters for add-on emission
controls (as defined in the quality assurance/quality control program for the unit required by
section 1 in appendix B to this part) and information for verifying proper operation of the add-
on emission controls during missing data periods, as described in §75.34(d).
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 182
-------
§ 75.74(c)(9) (9) The designated representative shall certify with each quarterly report that NOx
emission rate values or NOx concentration values substituted for missing data under subpart D
of this part are calculated using only values from an ozone season, that substitute values
measured during the prior ozone season(s) included in the missing data lookback period are
representative of the ozone season in which missing data are substituted, and that NOx
emissions are not systematically underestimated.
§ 75.74(c)(10) (10) Units may qualify to use the low mass emissions excepted monitoring methodology in
§ 75.19 on an ozone season basis. In order to be allowed to use this methodology, a unit may
not emit more than 50 tons of NOx per ozone season, as provided in § 75.19 (a)(l)(i)(A)(3).
If any low mass emissions unit fails to provide a demonstration that its ozone season NOx
mass emissions are less than or equal to 50 tons, then the unit is disqualified from using the
methodology. The owner or operator must install and certify any equipment needed to ensure
that the unit is monitored using an acceptable methodology by December 31 of the following
year.
§ 75.74(c)(l 1) (11) Units may qualify to use the optional NOx mass emissions estimation protocol for
gas-fired and oil-fired peaking units in appendix E to this part on an ozone season basis. In
order to be allowed to use this methodology, the unit must meet the definition of "peaking unit"
in §72.2 of this chapter, except that the words "year", "calendar year" and "calendar years" in
that definition shall be replaced by the words "ozone season", "ozone season", and "ozone
seasons", respectively. In addition, in the definition of the term "capacity factor" in §72.2 of
this chapter, the word "annual" shall be replaced by the words "ozone season" and the number
"8,760" shall be replaced by the number "3,672".
§ 75.75 Additional ozone season calculation procedures for special circumstances.
(a) The owner or operator of a unit that is required to calculate ozone season heat input for
purposes of providing data needed for determining allocations, shall do so by summing the
unit's hourly heat input determined according to the procedures in this part for all hours in
which the unit operated during the ozone season.
(b) The owner or operator of a unit that is required to determine ozone season NOx
emission rate (in lbs/mmBtu) shall do so by dividing ozone season NOx mass emissions (in lbs)
determined in accordance with this subpart, by heat input determined in accordance with
paragraph (a) of this section.
§ 75.75
§ 75.75(a)
§ 75.75(b)
Subpart I — Hg Mass Emission Provisions
§75.80 §75.80 General provisions.
§ 75.80(a) (a) Applicability. The owner or operator of a unit shall comply with the requirements of
this subpart to the extent that compliance is required by an applicable State or Federal Hg mass
emission reduction program that incorporates by reference, or otherwise adopts the provisions
of, this subpart.
(1) For purposes of this subpart, the term "affected unit" shall mean any coal-fired unit (as
defined in § 72.2 of this chapter) that is subject to a State or Federal Hg mass emission
reduction program requiring compliance with this subpart. The term "non-affected unit" shall
mean any unit that is not subject to such a program, the term "permitting authority" shall mean
the permitting authority under an applicable State or Federal Hg mass emission reduction
program that adopts the requirements of this subpart, and the term "designated representative"
shall mean the responsible party under the applicable State or Federal Hg mass emission
reduction program that adopts the requirements of this subpart.
(2) In addition, the provisions of subparts A, C, D, E, F, and G and appendices A through
G of this part applicable to Hg concentration, flow rate, moisture, diluent gas concentration,
and heat input, as set forth and referenced in this subpart, shall apply to the owner or operator
of a unit required to meet the requirements of this subpart by a State or Federal Hg mass
emission reduction program. The requirements of this part for S02, NOx, C02 and opacity
monitoring, recordkeeping and reporting do not apply to units that are subject only to a State or
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 183
-------
§ 75.80(b)
§ 75.80(c)
§ 75.80(c)(1)
§ 75.80(c)(2)
§ 75.80(c)(3)
§ 75.80(c)(4)
§ 75.80(d)
§ 75.80(e)
Federal Hg mass emission reduction program that adopts the requirements of this subpart, but
are not affected units under the Acid Rain Program or under a State or Federal NOx mass
emission reduction program that adopts the requirements of subpart H of this part.
(b) Compliance dates. The owner or operator of an affected unit shall meet the
compliance deadlines established by an applicable State or Federal Hg mass emission
reduction program that adopts the requirements of this subpart.
(c) Prohibitions.
(1) No owner or operator of an affected unit or a nonaffected unit under § 75.82(b)(2)(ii)
shall use any alternative monitoring system, alternative reference method, or any other
alternative for the required continuous emission monitoring system without having obtained
prior written approval in accordance with paragraph (h) of this section.
(2) No owner or operator of an affected unit or a non-affected unit under § 75.82(b)(2)(ii)
shall operate the unit so as to discharge, or allow to be discharged emissions of Hg to the
atmosphere without accounting for all such emissions in accordance with the applicable
provisions of this part.
(3) No owner or operator of an affected unit or a non-affected unit under § 75.82(b)(2)(ii)
shall disrupt the continuous emission monitoring system, any portion thereof, or any other
approved emission monitoring method, and thereby avoid monitoring and recording Hg
mass emissions discharged into the atmosphere, except for periods of recertification or periods
when calibration, quality assurance testing, or maintenance is performed in accordance with the
provisions of this part applicable to monitoring systems under § 75.81.
(4) No owner or operator of an affected unit or a non-affected unit under § 75.82(b)(2)(ii)
shall retire or permanently discontinue use of the continuous emission monitoring system, any
component thereof, or any other approved emission monitoring system under this part, except
under any one of the following circumstances:
(i) During the period that the unit is covered by a retired unit exemption that is in effect
under the State or Federal Hg mass emission reduction program that adopts the requirements of
this subpart; or
(ii) The owner or operator is monitoring Hg mass emissions from the affected unit with
another certified monitoring system approved, in accordance with the provisions of paragraph
(d) of this section; or
(iii) The designated representative submits notification of the date of certification testing
of a replacement monitoring system in accordance with § 75.61.
(d) Initial certification and recertification procedures.
(1) The owner or operator of an affected unit that is subject to the Acid Rain Program or to
a State or Federal NOx mass emission reduction program that adopts the requirements of
subpart H of this part shall comply with the applicable initial certification and recertification
procedures in § 75.20 and § 75.70(d), except that the owner or operator shall meet any
additional requirements for Hg concentration monitoring systems, sorbent trap monitoring
systems (as defined in § 72.2 of this chapter), flow monitors, C02 monitors, 02 monitors, or
moisture monitors, as set forth under § 75.81, under the common stack provisions in § 75.82,
or under an applicable State or Federal Hg mass emission reduction program that adopts the
requirements of this subpart.
(2) The owner or operator of an affected unit that is not subject to the Acid Rain Program
or to a State or Federal NOx mass emission reduction program that adopts the requirements of
subpart H of this part shall comply with the initial certification and recertification procedures
established by an applicable State or Federal Hg mass emission reduction program that adopts
the requirements of this subpart.
(e) Quality assurance and quality control requirements. For units that use continuous
emission monitoring systems to account for Hg mass emissions, the owner or operator shall
meet the applicable quality assurance and quality control requirements in § 75.21 and appendix
B to this part for the flow monitoring systems, Hg concentration monitoring systems, moisture
monitoring systems, and diluent monitors required under § 75.81. Units using sorbent trap
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 184
-------
monitoring systems shall meet the applicable quality assurance requirements in § 75.15,
appendix K to this part, and sections 1.5 and 2.3 of appendix B to this part.
§ 75.80(f) (f) Missing data procedures. Except as provided in § 75.38(b) and paragraph (g) of this
section, the owner or operator shall provide substitute data from monitoring systems required
under § 75.81 for each affected unit as follows:
§ 75.80(f)(1) (1) For an owner or operator using an Hg concentration monitoring system, substitute for
missing data in accordance with the applicable missing data procedures in §§ 75.31 through
75.38 whenever the unit combusts fuel and:
(i) A valid, quality-assured hour of Hg concentration data (in (ig/scm) has not been
measured and recorded, either by a certified Hg concentration monitoring system, by an
appropriate EPA reference method under § 75.22, or by an approved alternative monitoring
method under subpart E of this part; or
(ii) A valid, quality-assured hour of flow rate data (in scfh) has not been measured and
recorded for a unit either by a certified flow monitor, by an appropriate EPA reference method
under § 75.22, or by an approved alternative monitoring system under subpart E of this part; or
(iii) A valid, quality-assured hour of moisture data (in percent H20) has not been measured
or recorded for an affected unit, either by a certified moisture monitoring system, by an
appropriate EPA reference method under § 75.22, or an approved alternative monitoring
method under subpart E of this part. This requirement does not apply when a default percent
moisture value, as provided in § 75.11(b) is used to account for the hourly moisture content of
the stack gas, or when correction of the Hg concentration for moisture is not necessary; or
(iv) A valid, quality-assured hour of heat input rate data (in MMBtu/hr) has not been
measured and recorded for a unit, either by certified flow rate and diluent (C02 or 02)
monitors, by appropriate EPA reference methods under § 75.22, or by approved alternative
monitoring systems under subpart E of this part, where heat input is required for allocating
allowances under the applicable State or Federal Hg mass emission reduction program that
adopts the requirements of this subpart.
§ 75.80(f)(2) (2) For an owner or operator using a sorbent trap monitoring system to quantify Hg mass
emissions, substitute for missing data in accordance with the missing data procedures in §
75.39.
§ 75.80(g) (g) Reporting data prior to initial certification. If, by the applicable compliance date under
the State or Federal Hg mass emission reduction program that adopts the requirements of this
subpart, the owner or operator of an affected unit has not successfully completed all required
certification tests for any monitoring system(s), he or she shall determine, record and report
hourly data prior to initial certification using one of the following procedures, for the
monitoring system(s) that are uncertified:
(1) For Hg concentration and flow monitoring systems, report the maximum potential
concentration of Hg as defined in section 2.1.7 of appendix A to this part and the maximum
potential flow rate, as defined in section 2.1.4.1 of appendix A to this part; or
(2) For any unit, report data from the reference methods under § 75.22; or
(3) For any unit that is required to report heat input for purposes of allocating allowances,
report (as applicable) the maximum potential flow rate, as defined in section 2.1.4.1 of
appendix A to this part, the maximum potential C02 concentration, as defined in section
2.1.3.1 of appendix A to this part, the minimum potential 02 concentration, as defined in
section 2.1.3.2 of appendix A to this part, and the minimum potential percent moisture, as
defined in section 2.1.5 of appendix A to this part.
§ 75.80(h) (h) Petitions.
(1) The designated representative of an affected unit that is also subject to the Acid Rain
Program may submit a petition to the Administrator requesting an alternative to any
requirement of this subpart. Such a petition shall meet the requirements of § 75.66 and any
additional requirements established by the applicable State or Federal Hg mass emission
reduction program that adopts the requirements of this subpart. Use of an alternative to any
requirement of this subpart is in accordance with this subpart and with such State or Federal
Hg mass emission reduction program only to the extent that the petition is approved in writing
by the Administrator, in consultation with the permitting authority.
(2) Notwithstanding paragraph (h)(1) of this section, petitions requesting an alternative to
a requirement concerning any additional CEMS required solely to meet the common stack
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 185
-------
provisions of § 75.82 shall be submitted to the permitting authority and the Administrator and
shall be governed by paragraph (h)(3) of this section. Such a petition shall meet the
requirements of § 75.66 and any additional requirements established by an applicable State or
Federal Hg mass emission reduction program that adopts the requirements of this subpart.
(3) The designated representative of an affected unit that is not subject to the Acid Rain
Program may submit a petition to the permitting authority and the Administrator requesting an
alternative to any requirement of this subpart. Such a petition shall meet the requirements of §
75.66 and any additional requirements established by the applicable State or Federal Hg mass
emission reduction program that adopts the requirements of this subpart. Use of an alternative
to any requirement of this subpart is in accordance with this subpart only to the extent that it is
approved in writing by the Administrator, in consultation with the permitting authority.
§ 75.81 § 75.81 Monitoring of Hg mass emissions and heat input at the unit level.
The owner or operator of the affected coal-fired unit shall either:
§ 75.81 (a) (a) Meet the general operating requirements in § 75.10 for the following continuous
emission monitors (except as provided in accordance with subpart E of this part):
(1) A Hg concentration monitoring system (as defined in § 72.2 of this chapter) or a
sorbent trap monitoring system (as defined in § 72.2 of this chapter), to measure the mass
concentration of total vapor phase Hg in the flue gas, including the elemental and oxidized
forms of Hg, in micrograms per standard cubic meter (|ig/scm): and
(2) A flow monitoring system; and
(3) A continuous moisture monitoring system (if correction of Hg concentration for
moisture is required), as described in § 75.11(b). Alternatively, the owner or operator may use
the appropriate fuel-specific default moisture value provided in § 75.11 or a site-specific
moisture value approved by petition under § 75.66; and
(4) If heat input is required to be reported under the applicable State or Federal Hg mass
emission reduction program that adopts the requirements of this subpart, the owner or operator
must meet the general operating requirements for a flow monitoring system and an 02 or C02
monitoring system to measure heat input rate.
§ 75.81(b) (b) For an affected unit that emits 464 ounces (29 lb) of Hg per year or less, use the
following excepted monitoring methodology. To implement this methodology for a qualifying
unit, the owner or operator shall meet the general operating requirements in § 75.10 for the
continuous emission monitors described in paragraphs (a)(2) and (a)(4) of this section, and
perform Hg emission testing for initial certification and ongoing quality-assurance, as
described in paragraphs (c) through (e) of this section.
§ 75.81(c) (c) To determine whether an affected unit is eligible to use the monitoring provisions in
paragraph (b) of this section:
(1) The owner or operator must perform Hg emission testing one year or less before the
compliance date in §75.80(b), to determine the Hg concentration (i.e., total vapor phase Hg) in
the effluent.
(i) The testing shall be performed using one of the Hg reference methods listed in
§75.22(a)(7), and shall consist of a minimum of 3 runs at the normal unit operating load, while
combusting coal. The coal combusted during the testing shall be representative of the coal that
will be combusted at the start of the Hg mass emission reduction program (preferably from the
same source(s) of supply).
(ii) The minimum time per run shall be 1 hour if Method 30 A is used. If either Method
29 in appendix A-8 to part 60 of this chapter ASTM D6784-02 (the Ontario Hydro Method)
(incorporated by reference under §75.6 of this part), or Method 30B is used, paired samples
are required for each test run and the runs must be long enough to ensure that sufficient Hg is
collected to analyze. When Method 29 in appendix A-8 to part 60 of this chapter or the
Ontario Hydro method is used, the test results shall be based on the vapor phase Hg collected
in the back-half of the sampling trains (i.e., the non-filterable impinger catches). For each
Method 29 in appendix A-8 to part 60 of this chapter, Method 30B, or Ontario Hydro method
test run, the paired trains must meet the relative deviation (RD) requirement specified in
§75.22(a)(7) or in Method 30B, as applicable. If the RD specification is met, the results of the
two samples shall be averaged arithmetically.
(iii) If the unit is equipped with flue gas desulfurization or add-on Hg emission controls,
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 186
-------
the controls must be operating normally during the testing, and, for the purpose of establishing
proper operation of the controls, the owner or operator shall record parametric data or S02
concentration data in accordance with §75.58(b)(3)(i).
(iv.) If two or more of units of the same type qualify as a group of identical units in
accordance with §75.19(c)(l)(iv)(B), the owner or operator may test a subset of these units in
lieu of testing each unit individually. If this option is selected, the number of units required to
be tested shall be determined from Table LM-4 in §75.19. For the purposes of the required
retests under paragraph (d)(4) of this section, EPA strongly recommends that (to the extent
practicable) the same subset of the units not be tested in two successive retests, and that every
effort be made to ensure that each unit in the group of identical units is tested in a timely
manner.
(2) Based on the results of the emission testing, Equation 1 of this section shall be used to
provide a conservative estimate of the annual Hg mass emissions from the unit:
E = N K CHg Qmax (Eq.l)
Where:
E = Estimated annual Hg mass emissions from the affected unit, (ounces/year)
K = Units conversion constant, 9.978 x 10"10 oz-scm/(ig-scf
N = Either 8,760 (the number of hours in a year) or the maximum number of operating hours
per year (if less than 8.760) allowed by the unit's Federally-enforceable operating permit.
CHg = The highest Hg concentration (|ig/scm) from any of the test runs or 0.50 (ig/scm,
whichever is greater
Qmax = Maximum potential flow rate, determined according to section 2.1.4.1 of appendix A
to this part, (scfh)
Equation 1 of this section assumes that the unit operates at its maximum potential flow rate,
either year-round or for the maximum number of hours allowed by the operating permit (if unit
operation is restricted to less than 8,760 hours per year). If the permit restricts the annual unit
heat input but not the number of annual unit operating hours, the owner or operator may divide
the allowable annual heat input (mmBtu) by the design rated heat input capacity of the unit
(mmBtu/hr) to determine the value of "N" in Equation 1. Also, note that if the highest Hg
concentration measured in any test run is less than 0.50 (ig/scm, a default value of 0.50 (ig/scm
must be used in the calculations.
(3) If the estimated annual Hg mass emissions from paragraph (c)(2) of this section are
464 ounces per year or less, then the unit is eligible to use the monitoring provisions in
paragraph (b) of this section, and continuous monitoring of the Hg concentration is not
required (except as otherwise provided in paragraphs (e) and (f) of this section).
§ 75.81(d) (d) If the owner or operator of an eligible unit under paragraph (c)(3) of this section elects
not to continuously monitor Hg concentration, then the following requirements must be met:
§ 75.81(d)(1) (1) The results of the Hg emission testing performed under paragraph (c) of this section
shall be submitted as a certification application to the Administrator and to the permitting
authority, no later than 45 days after the testing is completed. The calculations demonstrating
that the unit emits 464 ounces (or less) per year of Hg shall also be provided, and the default
Hg concentration that will be used for reporting under § 75.84 shall be specified in both the
electronic and hard copy portions of the monitoring plan for the unit. The methodology is
considered to be provisionally certified as of the date and hour of completion of the Hg
emission testing.
§ 75.81(d)(2) (2) Following initial certification, the same default Hg concentration value that was used
to estimate the unit's annual Hg mass emissions under paragraph (c) of this section shall be
reported for each unit operating hour, except as otherwise provided in paragraph (d)(4)(iv) or
(d)(6) of this section. The default Hg concentration value shall be updated as appropriate,
according to paragraph (d)(5) of this section.
§ 75.81(d)(3) (3) The hourly Hg mass emissions shall be calculated according to section 9.1.3 in
appendix F to this part.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 187
-------
§ 75.81(d)(4) (4) The Hg emission testing described in paragraph (c) of this section shall be repeated
periodically, for the purposes of quality-assurance, as follows:
(i) If the results of the certification testing under paragraph (c) of this section show that the
unit emits 144 ounces (9 lb) of Hg per year or less, the first retest is required by the end of the
fourth QA operating quarter (as defined in § 72.2 of this chapter) following the calendar
quarter of the certification testing; or
(ii) If the results of the certification testing under paragraph (c) of this section show that
the unit emits more than 144 ounces of Hg per year, but less than or equal to 464 ounces per
year, the first retest is required by the end of the second QA operating quarter (as defined in §
72.2 of this chapter) following the calendar quarter of the certification testing; and
(iii) Thereafter, retesting shall be required either semiannually or annually (i.e., by the end
of the second or fourth QA operating quarter following the quarter of the previous test),
depending on the results of the previous test. To determine whether the next retest is due
within two or four QA operating quarters, substitute the highest Hg concentration from the
current test or 0.50 (ig/scm (whichever is greater) into the equation in paragraph (c)(2) of this
section. If the estimated annual Hg mass emissions exceeds 144 ounces, the next test is due
within two QA operating quarters. If the estimated annual Hg mass emissions is 144 ounces or
less, the next test is due within four QA operating quarters.
(iv) An additional retest is required when there is a change in the coal rank of the primary
fuel (e.g., when the primary fuel is switched from bituminous coal to lignite). Use ASTM
D388-99 (incorporated by reference under §75.6 of this part) to determine the coal rank. The
four principal coal ranks are anthracitic, bituminous, subbituminous, and lignitic. The ranks of
anthracite coal refuse (culm) and bituminous coal refuse (gob) shall be anthracitic and
bituminous, respectively. The retest shall be performed within 720 unit operating hours of the
change.
§ 75.81(d)(5) (5) The default Hg concentration used for reporting under §75.84 shall be updated after
each required retest. This includes retests that are required prior to the compliance date in
§75.80(b). The updated value shall either be the highest Hg concentration measured in any of
the test runs or 0.50 (ig/scm, whichever is greater. The updated default value shall be applied
beginning with the first unit operating in which Hg emissions data are required to be reported
after completion of the retest, except as provided in paragraph (d)(4)(iv) of this section, where
the need to retest is triggered by a change in the coal rank of the primary fuel. In that case,
apply the updated default Hg concentration beginning with the first unit operating hour in
which Hg emissions are required to be reported after the date and hour of the fuel switch.
§ 75.81(d)(6) (6) If the unit is equipped with a flue gas desulfurization system or add-on Hg controls, the
owner or operator shall record the information required under § 75.58(b)(3) for each unit
operating hour, to document proper operation of the emission controls. For any operating hour
in which this documentation is unavailable, the maximum potential Hg concentration, as
defined in section 2.1.7 of appendix A to this part, shall be reported.
§ 75.81(e) (e) For units with common stack and multiple stack exhaust configurations, the use of the
monitoring methodology described in paragraphs (b) through (d) of this section is restricted as
follows:
(1) The methodology may not be used for reporting Hg mass emissions at a common stack
unless all of the units using the common stack are affected units and the units' combined
potential to emit does not exceed 464 ounces of Hg per year times the number of units sharing
the stack, in accordance with paragraphs (c) and (d) of this section. If the test results
demonstrate that the units sharing the common stack qualify as low mass emitters, the default
Hg concentration used for reporting Hg mass emissions at the common stack shall either be the
highest value obtained in any test run or 0.50 (ig/scm, whichever is greater.
(i) The initial emission testing required under paragraph (c) of this section may be
performed at the common stack if the following conditions are met. Otherwise, testing of the
individual units (or a subset of the units, if identical, as described in paragraph (c)(l)(iv) of this
section) is required:
(A) The testing must be done at a combined load corresponding to the designated normal
load level (low, mid, or high) for the units sharing the common stack, in accordance with
section 6.5.2.1 of appendix A to this part;
(B) All of the units that share the stack must be operating in a normal, stable manner and
at typical load levels during the emission testing. The coal combusted in each unit during the
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 188
-------
testing must be representative of the coal that will be combusted in that unit at the start of the
Hg mass emission reduction program (preferably from the same source(s) of supply);
(C) If flue gas desulfurization and/or add-on Hg emission controls are used to reduce
level the emissions exiting from the common stack, these emission controls must be operating
normally during the emission testing and, for the purpose of establishing proper operation of
the controls, the owner or operator shall record parametric data or S02 concentration data in
accordance with §75.58(b)(3)(i);
(D) When calculating E, the estimated maximum potential annual Hg mass emissions from
the stack, substitute the maximum potential flow rate through the common stack (as defined in
the monitoring plan) and the highest concentration from any test run (or 0.50 |ig/scm. if
greater) into Equation 1;
(E) The calculated value of E shall be divided by the number of units sharing the stack. If
the result, when rounded to the nearest ounce, does not exceed 464 ounces, the units qualify to
use the low mass emission methodology; and
(F) If the units qualify to use the methodology, the default Hg concentration used for
reporting at the common stack shall be the highest value obtained in any test run or 0.50
Hg/scm, whichever is greater; or
(ii) The retests required under paragraph (d)(4) of this section may also be done at the
common stack. If this testing option is chosen, the testing shall be done at a combined load
corresponding to the designated normal load level (low, mid, or high) for the units sharing the
common stack, in accordance with section 6.5.2.1 of appendix A to this part. Provided that the
required load level is attained and that all of the units sharing the common stack are fed from
the same on-site coal supply during normal operation, it is not necessary for all of the units
sharing the stack to be in operation during a retest. However, if two or more of the units that
share the stack are fed from different on-site coal supplies (e.g., one unit burns low-sulfur coal
for compliance and the other combusts higher-sulfur coal), then either:
(A) Perform the retest with all units in normal operation; or
(B) If this is not possible, due to circumstances beyond the control of the owner or
operator (e.g., a forced unit outage), perform the retest with the available units operating and
assess the test results as follows. Use the Hg concentration obtained in the retest for reporting
purposes under this part if the concentration is greater than or equal to the value obtained in the
most recent test. If the retested value is lower than the Hg concentration from the previous test,
continue using the higher value from the previous test for reporting purposes and use that same
higher Hg concentration value in Equation 1 to determine the due date for the next retest, as
described in paragraph (e)(l)(iii) of this section.
(iii) If testing is done at the common stack, the due date for the next scheduled retest hall
be determined as follows:
(A) Substitute the maximum potential flow rate for the common stack (as defined in the
monitoring plan) and the highest Hg concentration from any test run (or 0.50 |ig/scm. if
greater) into Equation 1;
(B) If the value of E obtained from Equation 1, rounded to the nearest ounce, is greater
than 144 times the number of units sharing the common stack, but less than or equal to 464
times the number of units sharing the stack, the next retest is due in two QA operating quarters;
(C) If the value of E obtained from Equation 1, rounded to the nearest ounce, is less than
or equal to 144 times the number of units sharing the common stack, the next retest is due in
four QA operating quarters.
(2) For units with multiple stack or duct configurations, Hg emission testing must be
performed separately on each stack or duct, and the sum of the estimated annual Hg mass
emissions from the stacks or ducts must not exceed 464 ounces of Hg per year. For reporting
purposes, the default Hg concentration used for each stack or duct shall either be the highest
value obtained in any test run for that stack or 0.50 (ig/scm, whichever is greater.
(3) For units with a main stack and bypass stack configuration, Hg emission testing shall
be performed only on the main stack. For reporting purposes, the default Hg concentration
used for the main stack shall either be the highest value obtained in any test run for that stack
or 0.50 (ig/scm, whichever is greater. Whenever the main stack is bypassed, the maximum
potential Hg concentration, as defined in section 2.1.7 of appendix A to this part, shall be
reported.
§ 75.81(f) (f) At the end of each calendar year, if the cumulative annual Hg mass emissions from an
affected unit have exceeded 464 ounces, then the owner shall install, certify, operate, and
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 189
-------
maintain a Hg concentration monitoring system or a sorbent trap monitoring system no later
than 180 days after the end of the calendar year in which the annual Hg mass emissions
exceeded 464 ounces. For common stack and multiple stack configurations, installation and
certification of a Hg concentration or sorbent trap monitoring system on each stack (except for
bypass stacks) is likewise required within 180 days after the end of the calendar year, if:
(1) The annual Hg mass emissions at the common stack have exceeded 464 ounces times
the number of affected units using the common stack; or
(2) The sum of the annual Hg mass emissions from all of the multiple stacks or ducts has
exceeded 464 ounces; or
(3) The sum of the annual Hg mass emissions from the main and bypass stacks has
exceeded 464 ounces.
§ 75.81(g)
§ 75.82
§ 75.82(a)
§ 75.82(a)(1)
§ 75.82(a)(2)
§ 75.82(b)
§ 75.82(b)(1)
§ 75.82(b)(2)
(g) For an affected unit that is using a Hg concentration CEMS or a sorbent trap system
under § 75.81(a) to continuously monitor the Hg mass emissions, the owner or operator may
switch to the methodology in § 75.81(b), provided that the applicable conditions in paragraphs
(c) through (f) of this section are met.
§ 75.82 Monitoring of Hg mass emissions and heat input at common and multiple stacks.
(a) Unit utilizing common stack with other affected unit(s). When an affected unit utilizes
a common stack with one or more affected units, but no nonaffected units, the owner or
operator shall either:
(1) Install, certify, operate, and maintain the monitoring systems described in § 75.81(a) at
the common stack, record the combined Hg mass emissions for the units exhausting to the
common stack. Alternatively, if, in accordance with § 75.81(e), each of the units using the
common stack is demonstrated to emit less than 464 ounces of Hg per year, the owner or
operator may install, certify, operate and maintain the monitoring systems and perform the Hg
emission testing described under § 75.81(b). If reporting of the unit heat input rate is required,
determine the hourly unit heat input rates either by:
(1) Apportioning the common stack heat input rate to the individual units according to the
procedures in § 75.16(e)(3); or
(ii) Installing, certifying, operating, and maintaining a flow monitoring system and diluent
monitor in the duct to the common stack from each unit; or
(2) Install, certify, operate, and maintain the monitoring systems and (if applicable)
perform the Hg emission testing described in § 75.81 (a) or § 75.81 (b) in the duct to the
common stack from each unit.
(b) Unit utilizing common stack with nonaffected unit(s). When one or more affected
units utilizes a common stack with one or more nonaffected units, the
owner or operator shall either:
(1) Install, certify, operate, and maintain the monitoring systems and (if applicable)
perform the Hg emission testing described in § 75.81 (a) or § 75.81 (b) in the duct to the
common stack from each affected unit; or
(2) Install, certify, operate, and maintain the monitoring systems described in § 75.81(a) in
the common stack; and
(i) Install, certify, operate, and maintain the monitoring systems and (if applicable)
perform the Hg emission testing described in § 75.81 (a) or § 75.81 (b) in the duct to the
common stack from each non-affected unit. The designated representative shall submit a
petition to the permitting authority and the Administrator to allow a method of calculating and
reporting the Hg mass emissions from the affected units as the difference between Hg mass
emissions measured in the common stack and Hg mass emissions measured in the ducts of the
non-affected units, not to be reported as an hourly value less than zero. The permitting
authority and the Administrator may approve such a method whenever the designated
representative demonstrates, to the satisfaction of the permitting authority and the
Administrator, that the method ensures that the Hg mass emissions from the affected units are
not underestimated; or
(ii) Count the combined emissions measured at the common stack as the Hg mass
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 190
-------
emissions for the affected units, for recordkeeping and compliance purposes, in accordance
with paragraph (a) of this section; or
(iii) Submit a petition to the permitting authority and the Administrator to allow use of a
method for apportioning Hg mass emissions measured in the common stack to each of the units
using the common stack and for reporting the Hg mass emissions. The permitting authority
and the Administrator may approve such a method whenever the designated representative
demonstrates, to the satisfaction of the permitting authority and the Administrator, that the
method ensures that the Hg mass emissions from the affected units are not underestimated.
(3) If the monitoring option in paragraph (b)(2) of this section is selected, and if heat input
is required to be reported under the applicable State or Federal Hg mass emission reduction
program that adopts the requirements of this subpart, the owner or operator shall either:
(i) Apportion the common stack heat input rate to the individual units according to the
procedures in §75.16(e)(3); or
(ii) Install a flow monitoring system and a diluent gas (02 or C02) monitoring system in
the duct leading from each affected unit to the common stack, and measure the heat input rate
in each duct, according to section 5.2 of appendix F to this part.
§ 75.82(c) (c) Unit with a main stack and a bypass stack. Whenever any portion of the flue gases
from an affected unit can be routed through a bypass stack to avoid the Hg monitoring
system(s) installed on the main stack, the owner and operator shall either:
(1) Install, certify, operate, and maintain the monitoring systems described in § 75.81(a)
on both the main stack and the bypass stack and calculate Hg mass emissions for the unit as the
sum of the Hg mass emissions measured at the two stacks;
(2) Install, certify, operate, and maintain the monitoring systems described in § 75.81(a) at
the main stack and measure Hg mass emissions at the bypass stack using the appropriate
reference methods in § 75.22(b). Calculate Hg mass emissions for the unit as the sum of the
emissions recorded by the installed monitoring systems on the main stack and the emissions
measured by the reference method monitoring systems;
(3) Install, certify, operate, and maintain the monitoring systems and (if applicable)
perform the Hg emission testing described in § 75.81(a) or § 75.81(b) only on the main stack.
If this option is chosen, it is not necessary to designate the exhaust configuration as a multiple
stack configuration in the monitoring plan required under § 75.53, since only the main stack is
monitored. For each unit operating hour in which the bypass stack is used, report, as
applicable, the maximum potential Hg concentration (as defined in section 2.1.7 of appendix A
to this part), and the appropriate substitute data values for flow rate, C02 concentration, 02
concentration, and moisture (as applicable), in accordance with the missing data procedures of
§§75.31 through 75.37;
(4) If the monitoring option in paragraph (c)(1) or (c)(2) of this section is selected, and if
heat input is required to be reported under the applicable State or Federal Hg mass emission
reduction program that adopts the requirements of this subpart, the owner or operator shall:
(i) Use the installed flow and diluent monitors to determine the hourly heat input rate at
each stack (mmBtu/hr), according to section 5.2 of appendix F to this part; and
(ii) Calculate the hourly heat input at each stack (in mmBtu) by multiplying the measured
stack heat input rate by the corresponding stack operating time; and
(iii) Determine the hourly unit heat input by summing the hourly stack heat input values.
§ 75.82(d) (d) Unit with multiple stack or duct configuration. When the flue gases from an affected
unit discharge to the atmosphere through more than one stack, or when the flue gases from an
affected unit utilize two or more ducts feeding into a single stack and the owner or operator
chooses to monitor in the ducts rather than in the stack, the owner or operator shall either:
(1) Install, certify, operate, and maintain the monitoring systems and (if applicable)
perform the Hg emission testing described in § 75.81(a) or § 75.81(b) in each of the multiple
stacks and determine Hg mass emissions from the affected unit as the sum of the Hg mass
emissions recorded for each stack. If another unit also exhausts flue gases into one of the
monitored stacks, the owner or operator shall comply with the applicable requirements of
paragraphs (a) and (b) of this section, in order to properly determine the Hg mass emissions
from the units using that stack;
(2) Install, certify, operate, and maintain the monitoring systems and (if applicable)
perform the Hg emission testing described in § 75.81 (a) or § 75.81 (b) in each of the ducts that
feed into the stack, and determine Hg mass emissions from the affected unit using the sum of
the Hg mass emissions measured at each duct, except that where another unit also exhausts flue
gases to one or more of the stacks, the owner or operator shall also comply with the applicable
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 191
-------
requirements of paragraphs (a) and (b) of this section to determine and record Hg mass
emissions from the units using that stack; or
(3) If the monitoring option in paragraph (d)(1) or (d)(2) of this section is selected, and if
heat input is required to be reported under the applicable State or Federal Hg mass emission
reduction program that adopts the requirements of this subpart, the owner or operator shall:
(i) Use the installed flow and diluent monitors to determine the hourly heat input rate at
each stack or duct (mmBtu/hr), according to section 5.2 of appendix F to this part; and
(ii) Calculate the hourly heat input at each stack or duct (in mmBtu) by multiplying the
measured stack (or duct) heat input rate by the corresponding stack (or duct) operating time;
and
(iii) Determine the hourly unit heat input by summing the hourly stack (or duct) heat input
values.
§ 75.83 § 75.83 Calculation of Hg mass emissions and heat input rate.
The owner or operator shall calculate Hg mass emissions and heat input rate in accordance
with the procedures in sections 9.1 through 9.3 of appendix F to this part.
§ 75.84 § 75.84 Recordkeeping and reporting.
§ 75.84(a) (a) General recordkeeping provisions. The owner or operator of any affected unit shall
maintain for each affected unit and each non-affected unit under § 75.82(b)(2)(ii) a file of all
measurements, data, reports, and other information required by this part at the source in a form
suitable for inspection for at least 3 years from the date of each record. Except for the
certification data required in § 75.57(a)(4) and the initial submission of the monitoring plan
required in § 75.57(a)(5), the data shall be collected beginning with the earlier of the date of
provisional certification or the compliance deadline in § 75.80(b). The certification data
required in § 75.57(a)(4) shall be collected beginning with the date of the first certification test
performed. The file shall contain the following information:
(1) The information required in §§ 75.57(a)(2), (a)(4), (a)(5), (a)(6), (b), (c)(2), (g) (if
applicable), (h), and (i) or (j) (as applicable). For the information in § 75.57(a)(2), replace the
phrase "the deadline in § 75.4(a), (b) or (c)" with the phrase "the applicable certification
deadline under the State or Federal Hg mass emission reduction program";
(2) The information required in § 75.58(b)(3), for units with flue gas desulfurization
systems or add-on Hg emission controls;
(3) For affected units using Hg CEMS or sorbent trap monitoring systems, for each hour
when the unit is operating, record the Hg mass emissions, calculated in accordance with section
9 of appendix F to this part.
(4) Heat input and Hg methodologies for the hour; and
(5) Formulas from monitoring plan for total Hg mass emissions and heat input rate (if
applicable);
§ 75.84(b) (b) Certification, quality assurance and quality control record provisions. The owner or
operator of any affected unit shall record the applicable information in § 75.59 for each
affected unit or group of units monitored at a common stack and each non-affected unit under §
75.82(b)(2)(ii).
§ 75.84(c) (c) Monitoring plan recordkeeping provisions.
(1) General provisions. The owner or operator of an affected unit shall prepare and
maintain a monitoring plan for each affected unit or group of units monitored at a common
stack and each non-affected unit under § 75.82(b)(2)(ii). The monitoring plan shall contain
sufficient information on the continuous monitoring systems and the use of data derived from
these systems to demonstrate that all the unit's Hg emissions are monitored and reported.
(2) Updates. Whenever the owner or operator makes a replacement, modification, or
change in a certified continuous monitoring system or alternative monitoring system under
subpart E of this part, including a change in the automated data acquisition and handling
system or in the flue gas handling system, that affects information reported in the monitoring
plan (e.g., a change to a serial number for a component of a monitoring system), then the
owner or operator shall update the monitoring plan.
(3) Contents of the monitoring plan. Each monitoring plan shall contain the information
in § 75.53(g)(1) in electronic format and the information in § 75.53(g)(2) in hardcopy format.
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 192
-------
§ 75.84(d)
§ 75.84(d)(1)
§ 75.84(d)(2)
§ 75.84(d)(3)
§ 75.84(d)(4)
§ 75.84(d)(5)
§ 75.84(e)
§ 75.84(f)
§ 75.84(f)(1)
(d) General reporting provisions.
(1) The designated representative for an affected unit shall comply with all reporting
requirements in this section and with any additional requirements set forth in an applicable
State or Federal Hg mass emission reduction program that adopts the requirements of this
subpart.
(2) The designated representative for an affected unit shall submit the following for each
affected unit or group of units monitored at a common stack and each non-affected unit under §
75.82(b)(2)(ii):
(i) Initial certification and recertification applications in accordance with § 75.80(d);
(ii) Monitoring plans in accordance with paragraph (e) of this section; and
(iii) Quarterly reports in accordance with paragraph (f) of this section.
(3) Other petitions and communications. The designated representative for an affected
unit shall submit petitions, correspondence, application forms, and petition-related test results
in accordance with the provisions in § 75.80(h).
(4) Quality assurance RATA reports. If requested by the permitting authority, the
designated representative of an affected unit shall submit the quality assurance RATA report
for each affected unit or group of units monitored at a common stack and each non-affected
unit under § 75.82(b)(2)(ii) by the later of 45 days after completing a quality assurance RATA
according to section 2.3 of appendix B to this part or 15 days of receiving the request. The
designated representative shall report the hardcopy information required by § 75.59(a)(9) to
the permitting authority.
(5) Notifications. The designated representative for an affected unit shall submit written
notice to the permitting authority according to the provisions in § 75.61 for each affected unit
or group of units monitored at a common stack and each non-affected unit under §
75.82(b)(2)(ii).
(e) Monitoring plan reporting.
(1) Electronic submission. The designated representative for an affected unit shall submit
to the Administrator a complete, electronic, up-to-date monitoring plan file for each affected
unit or group of units monitored at a common stack and each non-affected unit under §
75.82(b)(2)(ii), as follows: No later than 21 days prior to the commencement of initial
certification testing; at the time of a certification or recertification application submission; and
whenever an update of the electronic monitoring plan is required, either under § 75.53 or
elsewhere in this part.
(2) Hardcopy submission. The designated representative of an affected unit shall submit
all of the hardcopy information required under § 75.53, for each affected unit or group of units
monitored at a common stack and each non-affected unit under § 75.82(b)(2)(ii), to the
permitting authority prior to initial certification. Thereafter, the designated representative shall
submit hardcopy information only if that portion of the monitoring plan is revised. The
designated representative shall submit the required hardcopy information as follows: no later
than 21 days prior to the commencement of initial certification testing; with any certification or
recertification application, if a hardcopy monitoring plan change is associated with the
recertification event; and within 30 days of any other event with which a hardcopy monitoring
plan change is associated, pursuant to § 75.53(b). Electronic submittal of all monitoring plan
information, including hardcopy portions, is permissible provided that a paper copy of the
hardcopy portions can be furnished upon request.
(f) Quarterly reports.
(1) Electronic submission. Electronic quarterly reports shall be submitted, beginning with
the calendar quarter containing the compliance date in §75.80(b), unless otherwise specified in
the final rule implementing a State or Federal Hg mass emissions reduction program that
adopts the requirements of this subpart. The designated representative for an affected unit
shall report the data and information in this paragraph (f)(1) and the applicable compliance
certification information in paragraph (f)(2) of this section to the Administrator quarterly,
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 193
-------
§75.84(f)(l)(i)
§ 75.84(f)(l)(ii)
§ 75.84(f)(l)(iii)
§ 75.84(f)(l)(iv)
except as otherwise provided in §75.64(a) for units in long-term cold storage. Each electronic
report must be submitted to the Administrator within 30 days following the end of each
calendar quarter. Except as otherwise provided in §75.64(a)(4) and (a)(5), each electronic
report shall include the date of report generation and the following information for each
affected unit or group of units monitored at a common stack:
(i) The facility information in §75.64(a)(3); and
(ii) The information and hourly data required in paragraphs (a) and (b) of this section,
except for:
(A) Descriptions of adjustments, corrective action, and maintenance;
(B) Information which is incompatible with electronic reporting (e.g., field data sheets, lab
analyses, quality control plan);
(C) For units with flue gas desulfurization systems or with add-on Hg emission controls,
the parametric information in § 75.58(b)(3);
(D) Information required by § 75.57(h) concerning the causes of any missing data periods
and the actions taken to cure such causes;
(E) Hardcopy monitoring plan information required by § 75.53 and hardcopy test data and
results required by § 75.59;
(F) Records of flow polynomial equations and numerical values required by §
75.59(a)(5)(vi);
(G) Stratification test results required as part of the RATA supplementary records under §
75.59(a)(7);
(H) Data and results of RAT As that are aborted or invalidated due to problems with the
reference method or operational problems with the unit and data and results of linearity checks
that are aborted or invalidated due to operational problems with the unit;
(I) Supplementary RATA information required under §75.59(a)(7), except that:
(/) The applicable data elements under §75.59(a)(7)(ii)(A) through (T) and under
§75.59(a)(7)(iii)(A) through (M) shall be reported for flow RAT As at circular or rectangular
stacks (or ducts) in which angular compensation for yaw and/or pitch angles is used (i.e.,
Method 2F or 2G in appendices A-l and A-2 to part 60 of this chapter), with or without wall
effects adjustments;
(2) The applicable data elements under §75.59(a)(7)(ii)(A) through (T) and under
§75.59(a)(7)(iii)(A) through (M) shall be reported for any flow RATA run at a circular stack in
which Method 2 in appendices A-l and A-2 to part 60 of this chapter is used and a wall effects
adjustment factor is determined by direct measurement;
(3) The data under §75.59(a)(7)(ii)(T) shall be reported for all flow RATAs at circular
stacks in which Method 2 in appendices A-l and A-2 to part 60 of this chapter is used and a
default wall effects adjustment factor is applied; and
(4) The data under §75.59(a)(7)(ix)(A) through (F) shall be reported for all flow RATAs
at rectangular stacks or ducts in which Method 2 in appendices A-l and A-2 to part 60 of this
chapter is used and a wall effects adjustment factor is applied.
(J) For units using sorbent trap monitoring systems, the hourly gas flow meter readings
taken between the initial and final meter readings for the data collection period; and
(iii) Ounces of Hg emitted during quarter and cumulative ounces of Hg emitted in the
year-to-date (rounded to the nearest thousandth); and
(iv) Unit or stack operating hours for quarter, cumulative unit or stack operating hours for
year-to-date; and
§ 75.84(f)(l)(v)
§ 75.84(f)(2)
§ 75.84(f)(2)®
§ 75.84(f)(2)(h)
(v) Reporting period heat input (if applicable) and cumulative, year-to-date heat input.
(2) Compliance certification.
(i) The designated representative shall certify that the monitoring plan information in each
quarterly electronic report (i.e., component and system identification codes, formulas, etc.)
represent current operating conditions for the affected unit(s)
(ii) The designated representative shall submit and sign a compliance certification in
support of each quarterly emissions monitoring report based on reasonable inquiry of those
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 194
-------
persons with primary responsibility for ensuring that all of the unit's emissions are correctly
and fully monitored. The certification shall state that:
(A) The monitoring data submitted were recorded in accordance with the applicable
requirements of this part, including the quality assurance procedures and specifications; and
(B) With regard to a unit with an FGD system or with add-on Hg emission controls, that
for all hours where data are substituted in accordance with § 75.38(b), the add-on emission
controls were operating within the range of parameters listed in the quality-assurance plan for
the unit (or that quality-assured S02 CEMS data were available to document proper operation
of the emission controls), and that the substitute values do not systematically underestimate Hg
emissions.
§ 75.84(f)(3) (3) Additional reporting requirements. The designated representative shall also comply
with all of the quarterly reporting requirements in §§ 75.64(d), (f), and (g).
Unofficial Version - Parts 72 and 75 (01/03/08) — Page 195
------- |