United States
Environmental Protection
Agency
Office of Air Quality
Planning and Standards
Research Triangle Park, NC 27711
EPA 450/3-90-018
July 1990
Air
Enabling Document for New
Source Performance
Standards for Air Oxidation
Processes and Distillation
Operations in the
Synthetic Organic Chemical
Manufacturing Industry
U.S. Environmental Protection Agency
Region 5, Library (PI.-12J)
77 West Jackson Bou!;;,•:.,,;,
Chicago, IL 60604-351,0 "
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DISCLAIMER
This report has been reviewed by the Emission Standards Division of the Office
of Air Quality Planning and Standards, EPA, and approved for publication.
Mention of trade names or commercial products is not intended to constitute
endorsement or recommendation for use. The purpose of this document is to
provide information in a summary form but not to indicate the intent of any
EPA decisions. Copies of this report are available through the Library
Services Office (MD-35), U.S. Environmental Protection Agency, Research
Triangle Park, NC 27711, or from National Technical Information Services,
5285 Port Royal Road, Springfield, VA 22161.
11
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TABLE OF CONTENTS
LIST OF FIGURES iv
LIST OF TABLES . v
Section 1 Introduction 1
Section 2 Summary of Standards. ................... 3
Section 3 Total Resource Effectiveness (TRE) Index Value
Determination 19
Section 4 General Provisions 23
Section 5 Existing Sources Affected . 30
Section 6 Implementation Plan for Air Oxidation and Distillation
SOCMI NSPS 39
Section 7 Reprint of Regulations from Federal Register. . 42
APPENDIX A List of OAQPS Contacts. ...... A-l
m
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LIST OF FIGURES
Figure paqe
1 Regulatory Approach for Air Oxidation Processes . 6
2 Regulatory Approach for Distillation Operations 7
IV
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LIST OF TABLES
Paoe
1 Compliance Testing -- Methods and Procedures to Follow When
Achieving 98 Percent Emission Reduction Or An Emission
Limit to 20 ppmv 8
2 Compliance Testing -- Methods and Procedures to Follow When
Combusting Emissions in a Flare . 9
3 Compliance Testing -- Methods and Procedures to Follow When
Maintaining A TRE Index > 1.0 10
4 Monitoring and Reporting/Recordkeeping Requirements for
Complying with 98 Percent Reduction of TOC Emissions or a
Limit to 20 ppmv 12
5 Monitoring and Reporting/Recordkeeping Requirements for Affected
Facilities Complying with Flare Specifications. ... 13
6 Monitoring and Reporting/Recordkeeping Requirements for
Maintaining a TRE Index Value > 1.0 14
7 Performance Testing Parameters 15
8 Timing Requirements for SOCMI Air Oxidation Processes and
Distillation Operations ........ 17
9 Facilities Identified with Air Oxidation Processes 31
10 Facilities Identified with Distillation Operations 36
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Section 1. Introduction
The Environmental Protection Agency (EPA) promulgated standards of
performance (NSPS) for new, modified, and reconstructed air oxidation
processes and distillation operations in the synthetic organic chemical
manufacturing industry (SOCMI) on June 29, 1990 (55 FR 26912 and 55 FR 26931).
This Enabling Document presents pertinent information regarding the NSPS for
these two SOCMI source categories. Although the NSPS for these two source
categories were evaluated on their own merits and promulgated separately, the
actual standards and compliance procedures for these two source categories are
very similar. In view of this, the requirements discussed in the following
sections apply generally to both NSPS. However, where a difference exists
between the two NSPS, the difference is explicitly highlighted in the text.
This document is intended to assist the EPA enforcement and other
personnel who will be implementing these regulations and responding to
comments and questions concerning them. Comments on this document may be sent
to Doug Bell, Chief, Standards Preparation Section (MD-13), U.S. Environmental
Protection Agency, Research Triangle Park, North Carolina 27711.
Section 2 presents a summary of the standards' applicability, exemptions,
control requirements, performance testing requirements, monitoring
requirements, reporting and recordkeeping requirements, and compliance dates.
This section presents a brief synopsis designed to be useful in a quick
determination of whether or not a facility is subject to the rules.
Section 3 presents a discussion of the steps to follow to determine the
TRE index value for an affected facility and to identify the applicable
regulatory provisions.
Section 4 includes a discussion of three important sections of the
General Provisions (Subpart A of 40 CFR Part 60) which are specifically
referred to in these standards: §60.14 Modification; §60.15 Reconstruction;
and §60.18 General Control Device Requirements.
Section 5 presents the Standard Industrial Classification (SIC) codes for
the affected source categories and lists of sources that were identified
1
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during the development of these rulemakings. It should be noted, however,
that these lists may not be accurate or complete, and may not reflect current
operations at many facilities. These lists are provided here as a guideline
of the sources that might be affected by the NSPS if air oxidation or
distillation units within those facilities were modified or reconstructed
after proposal of the NSPS.
Section 6 presents an implementation plan to assist the EPA Regional
Offices and State and local agencies in enforcing these regulations. The need
for a detailed compliance monitoring strategy will be evaluated and developed
if determined necessary. Computer software will be developed to assist the
enforcing agency in calculating a given facility's TRE index (See Section 3
for a discussion of the TRE index), which is an essential parameter necessary
for determining applicability of the compliance provisions.
Section 7 contains a copy of the regulations for both SOCMI air oxidation
processes and distillation operations as they appeared in the Federal
Register.
Appendix A presents a list of people at OAQPS who can be contacted
regarding the technical as well as regulatory aspects of the promulgated
standards.
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Section 2. Summary of Standards
I. Applicability
1. Air Oxidation Processes
The standards apply to the following affected facilities:
• SOCMI air oxidation processes constructed, reconstructed,
or modified after October 21, 1983, that produce any of
the chemicals listed in §60.617 of the regulation as a
product, co-product, by-product, or intermediate.
2. Distillation Operations
The standards apply to the following affected facilities:
• SOCMI distillation operations constructed, reconstructed,
or modified after December 30, 1983, that are part of a
process unit producing any of the chemicals listed in
§60.667 of the regulation as a product, co-product,
by-product, or intermediate.
II. Total Resource Effectiveness (TRE) Index
• The TRE index provides a relative measure of the cost
effectiveness of control in dollars per megagram ($/Mg)
for a given vent stream. It is a dimensionless number
which represents the cost effectiveness of control for a
vent stream divided by the reference cost-effectiveness
value (in this case, $1900/Mg based on 1978 dollars).
• The TRE index concept is incorporated into the air
oxidation NSPS and distillation NSPS to determine the
applicability of regulatory requirements (i.e.,
monitoring, add-on control). For vent streams with a high
estimated cost effectiveness of control, no additional
control would be required. The equation for calculating
the TRE index is found in the regulations. (Refer to
Section 3 for an example TRE index calculation.)
III. Exemptions
1. Air Oxidation Processes
The following are exempt from all monitoring and most reporting/
recordkeeoina requirements:
• Any affected facility with a TRE index value > 4.0.
However, the affected facility must recalculate the TRE
index whenever there are process changes (e.g., changes in
production capacity, feedstock type, or catalyst type; or
replacing, removing, or adding recovery equipment on air
oxidation reactors). The facility must also maintain
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records of process changes and the recalculated TRE
indices. The affected facility is also required to report
when recalculated TRE indices are < 4.0.
2. Distillation Operations
The foil owing are exempt from the standards:
• Any distillation unit operating as part of a process unit
which produces coal tar or beverage alcohols, or which
does not use, contain, or produce VOC.
• Any distillation unit subject to the provisions of
Subpart DOO (polymer manufacturing processes).
• Any distillation unit designed and operated as a batch
operation. (A batch distillation operation is a
noncontinuous distillation operation in which a discrete
quantity or batch of liquid fuel is charged into a
distillation unit and distilled at one time. After the
initial charging, no additional liquid is added during the
distillation operation.)
The following are exempt from all monitoring and most reporting/
recordkeeping requirements:
• Any affected facility with a TRE index value > 8.0.
However, such a facility must recalculate the TRE index
whenever process or equipment changes are made. The
facility must also maintain records of the process or
equipment changes and recalculated TRE indices and report
when recalculated TRE indices are < 8.0.
• Any affected facility within a process unit with a total
design capacity for all chemicals produced within that
unit of less than 1 gigagram per year (Gg/yr) is exempt
from all provisions except for submitting an initial
report of the design capacity of the process unit and
maintaining records and reporting any equipment process
changes that increase the design production capacity.
• Any affected facility with a vent stream flow rate
< 0.008 standard cubic meters per minute (scm/min).
However, such an affected facility must monitor and
maintain records of volumetric flow rate and report
changes in process operation or equipment if the flow rate
increases above this level.
IV. Standards
The standards for both air oxidation processes and distillation
operations require compliance bv one of the following methods;
• If the TRE index is < 1.0, reduction of total organic
compounds (TOC) emissions by 98 weight-percent or to
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20 parts per million by volume (ppmv)(less methane and
ethane), whichever is less stringent;
• Combustion of emissions in a flare that meets the
requirements of 40 CFR 60.18; or
• Maintaining a TRE index > 1.0 without combustion control
(or using product recovery). (Note: For the purpose of
calculating TOC emissions to determine a TRE index, the
affected facility may exclude the following compounds with
negligible photochemical reactivity: methane, ethane,
1,1,1-trichloroethane, methylene chloride,
trichlorof1uoromethane, dichlorodif 1 uoromethane,
chlorodifluoromethane, trifluoromethane,
tri chlorotri f1uoroethane, di chlorotetraf1uoroethane,
chloropentafluoroethane, dichlorotrifluoroethane,
tetrafluoroethane, dichlorofluoroethane, and
chlorodi fluoroethane.)
Refer to Figures 1 and 2 for flow diagrams of the regulatory approach for
the standards.
V. Compliance Testing
The required methods or procedures to be followed when achieving
compliance with the standards for either air oxidation processes or
distillation operations are presented in Tables 1, 2, and 3. Table 1 presents
the compliance testing methods for those facilities achieving 98 percent
reduction of TOC emissions or a limit of 20 ppmv. Table 2 shows compliance
testing methods for flares. Table 3 presents the compliance methods to follow
when a facility's TRE index value is > 1.0. Note that when conducting
performance tests, all facilities must be operated at maximum conditions and
flow rates.
VI. Monitoring and Reporting/Recordkeeping Requirements
General monitoring and reporting/recordkeeping requirements for complying
with the standards for either air oxidation processes or distillation
operations are given below.
• Up-to-date, readily accessible records of data collected
during the initial performance test and of data collected
during all subsequent performance tests (where either
(1) the emissions control efficiency of a control device,
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Does the process unit containing the
air oxidation process(es) produce
any at the chemicals listed in
§60.617 as a product, by-product,
co-product or intermediate?
No
Yes
Was the air oxidation process unit
constructed, modified, or
reconstructed after October 21,1983?
No
The air oxidation process
unit Is not subject to the
SOCMI Air Oxidation
Processes rule
Yes
Then the air oxidation process unit
is an affected facility subject to the
SOCMI Air Oxidation processes rule
Does the affected facility within the
process unit have a total resource
effectiveness (TRE) index >4.0?
Yes
No
Recalculate the TRE index
whenever process changes
are made. Maintain records
of process changes and
recalculated TRE indices.
Other provisions of the
rule do not apply.
The affected facility must do one of
the following and comply with the
appropriate testing, monitoring,
reporting, and recordkeeping requirements.
Reduce TOG emissions by 98 weight-percent
or to 20 ppmv, whichever is less stringent
Combust emissions
in a flare that meets
the requirements of
40CFR60.18
Maintain a TRE index > 1.0
without VOC control
Is a boiler or process heater
used to achieve this level?
Yes
The vent stream must be introduced into the
flame zone of the boiler or process heater
Figure 1. Regulatory Approach for Air Oxidation Processes
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Exempt from all provisions of the
SOCMI Distillation Operations
rule except monitoring and
maintaining records of flowrate
and reporting operation changes
that increase fiowrate.
Yes
Does the process unit containing the
distillation operation^) produce
any of the chemicals listed in
§60.667 as a product, by-product,
co-product or intermediate?
No
Yes
Was the distillation unit constructed,
modified, or reconstructed after
December 30, 1983?
No
Yes
Does the distillation unit operate as
part of a process unit which produces
coal tar or beverage alcohols, or which
uses, contains, or produces no VOC?
The distillation unit is
not subject to the
SOCMI Distillation
Operations rule
Yes
No
Is the distillation unit subject
to Subpart DDD?
Yes
No
Then the distillation unit is an
affected facility subject to the
SOCMI Distillation Operations rule
Does the process unit have a total
design capacity for all chemicals
produced in that unit < 1 Qg/yr?
Yes
Exempt from allprovisions
of the SOCMI Distillation
Operations rule except
maintaining records and
reporting operation changes
that increase capacity.
Does the affected facility operate with
a vent stream rate < 0.008 scm/min?
No
Does the affected facility within the
process unit have a TRE index >8.0?
Yes
No
Recalculate the TRE index
whenever process changes
are made. Maintain records
of process changes and
recalculated TRE indices.
Other provisions of the
rule do not apply.
The affected facility must do one of
the following and comply with the
appropriate testing, monitoring,
reporting, and recordkeeping requirements.
Reduce TOC emissions by 98 weight-percent
or to 20 ppmv, whichever is less stringent
Is a boiler or procees heater
used to achieve this level?
Combust emissions
in a flare that meets
the requirements of
40CFR60.18
Maintain a TRE index > 1.0
without VOC control
,, Yes
The vent stream must be introduced into the
flame zone of the boiler or process heater
Figure 2. Regulatory Approach for Distillation Operations
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TABLE 1. COMPLIANCE TESTING — METHODS AND PROCEDURES TO FOLLOW WHEN ACHIEVING
98 WEIGHT-PERCENT EMISSION REDUCTION OR AN EMISSION LIMIT OF 20 ppmv
oo
: Provision Selected T
for Compliance
98% TOG Emission
Reduction
20 ppmv (dry basis
at 3% Oxygen)
:•.-.-:• :. . ' • ' . :••'; *
Compliance Test Requirement ?;l
Selection of sampling sites
{60.61 4(b)(1),60.664(b)(1)}
Volumetric flow rates
{60.61 4(b)(2), 60.664(b)(2)}
TOC concentration in control device
outlet {60.61 4(b)(4), 60.664(b)(4)}
TOC concentration in control device
inlet {60.61 4(b)(4). 60.664(b)(4)}
Selection of sampling sites
{60.61 4(b)(1), 60.664(b)(1)}
Volumetric flow rates
{60.614(b)(2),60.664(b)(2)}
Oxygen concentration
{60.61 4(b)(3). 60.664(b)(3)}
TOC concentration corrected
to 3 percent oxygen
{60.614(b)(3). 60.664(b)(3)}
•: ""•' •" ' Method ^ff^fltti^^-^r . -fS^
Method 1 or 1 A (to determine vent stream molar
composition or TOC reduction efficiency; control
device inlet sampling site shall be prior to
control device inlet and after recovery system)
Method 2. 2A. 2C. or 2D
Method 18 (1 hour sampling timejaking either an
integrated sample or 4 grab samples at 15 minute
intervals)
Method 1 or 1 A (to determine vent stream
molar composition)
Method 2, 2A, 2C. or 2D
Method 3 (emission rate correction factor,
integrated sampling and analysis procedure)
Equation given in 60.61 4(b)(3)
and 60.664(b)(3)
Regulatory citations are listed in brackets.
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TABLE 2. COMPLIANCE TESTING — METHODS AND PROCEDURES TO FOLLOW WHEN COMBUSTING EMISSIONS IN A FLARE
Provision Selected
for Compliance
Flare
"'''•"• -A-. :v. ";;::; .'. * v • •
;\ Compliance Test Requlferneint^ '..;^
Refer to flare specifications in 60.18
(60.61 4(c),60.664(c)}
Selection of sampling site for
determining net heating value of
the gas combusted and flow rate
{60.61 4(d)(1).60.664(d)(1)}
Molar
composition
of the process
vent stream
(needed to
determine the
net heating value
of the gas)
{60.61 4(d)(2).
60.664(d)(2)}
Concentration of TOC
including those containing
halogens
.'• ;.":"': •' ••• :"'-
Concentration of carbon
monoxide and hydrogen
''\ : '.
Content of water vapor
Total process vent stream concentration (by
volume) of compounds with halogens (ppmv, by
compound) {60.61 4(d)(6). 60.664(d)(6)}
• i Method or Procedure ••;.:' ' ; ; " • • '"' ' ;ff';
Refer to flare specifications in 60. 1 8
Method 1 or 1 A (site to be upstream of any control
device inlet, or upstream of any dilution of the stream
with air or any introduction of halogenated compounds
into the stream). No transverse site selection
method is needed if the vent diameter is <4 inches
Method 18
ASTM D 1946-77, Standard Method for Analysis of
Reformed Gas by Gas Chromotography
' ^:i:yff-^:'i!-" ''• ".-$'•• '>'-
Method 4
Summed from the individual concentrations of
compounds which were measured by Method 18
Regulatory citations are listed in brackets.
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TABLE 3. COMPLIANCE TESTING — METHODS AND PROCEDURES TO FOLLOW WHEN MAINTAINING
A TRE INDEX VALUE >1.0
Provision Selected
•f for Compliance ?; ;
TRE > 1.0
Jl
.; . .' . " J~"
Compliance Test Requirement
Selection of sampling site for determining
net heating value of the gas combusted and
flow rate {60.61 4(d)(1). 60.664(d)(1)}
Volumetric flow rate
{60.61 4(d)(3), 60.664(d)(3)}
Net heating value of vent stream
{ 60.61 4(d)(4), 60.664(d)(4)}
Emission rate of TOG in process
vent stream {60.614(d)(5), 60.664(d)(5)}
Molar
composition
of the process
vent stream
(used to
determine the
TRE index value)
{60.61 4(d)(2),
60 664(d)(2)}
Concentration of TOC
including those containing
halogens
'': '• !• :''. •;:::.•:• .'.- ..' ' . *:;•:/. :* ' :
Concentration of carbon
monoxide and hydrogen
Content of water vapor
Total process vent stream concentration (by
volume) of compounds with halogens (ppmv, by
compound) {60.614(d)(6), 60.664(d)(6)}
TRE index
value
{60.614(e),
60.664(e)}
Halogenated
vent streams
Nonhalogenated
vent streams
!•; Methods or Procedures
Method 1 or 1 A (site to be upstream of any control
device inlet, upstream of any dilution of the stream
with air or any introduction of halogenated compound
into the stream.) No transverse site selection
method needed if vent diameter is <4 inches.
Method 2, 2A, 2C, or 2D
Equation given in
60.61 4(d)(4) and 60.664(d)(4)
Equation given in
60.61 4(d)(5) and 60.664(d)(5)
Method 18
.....:.V. ' j
ASTM D1 946-77, Standard Method for Analysis of
Reformed Gas by Gas Chromotography
..,•.::•::.';:.£•.;.
Method 4
Summed from the individual concentrations of
compounds which were measured by Method 18
Equation for incineration in 60.61 4(e)(1) or
60.664(e)(1)
• <" L> :!•:•. •-•• .-.I-' •'.:.. ••••:,, ' . : • .:. '.}:
Incineration equation in 60.61 4(e)(1) or 60.664(e)(1)
and flare equation in 60.61 4(e)(2) and 60.664(e)(2)
Regulatory citations are listed in brackets.
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(2) outlet concentrations of TOC, or (3) the TRE index
value of a vent stream from a recovery system is
determined).
Monitoring of control or recovery device parameters, with
semiannual reports when monitored parameters are exceeded.
Records of any changes in production capacity, feedstock
type, or catalyst type, or of any replacement, removal or
addition of recovery equipment, on air oxidation or
distillation reactors.
Up-to-date, readily accessible continuous records of flow
indication and periods when the vent stream is diverted
from the control device or has no flow rate.
For distillation operations only:
• Records and reporting of any change in equipment or
process operations that increases the operating vent
stream flow rate above the low flow exemption level or
that increases the design production capacity above the
low capacity exemption level.
More specific requirements broken out by individual parameters are given
in Tables 4, 5, and 6. Table 4 presents the requirements when complying with
98 percent reduction of TOC emissions or a limit to 20 ppmv. Table 5 presents
the requirements when achieving compliance through use of a flare. Table 6
presents the requirements when achieving the standard by maintaining a TRE
index value greater than 1.0. An affected facility must maintain records on
site for 2 years. Reporting of monitored parameters is required only for
exceedances of defined parameter boundaries. Performance testing parameters
for the initial and subsequent performance tests are presented in Table 7.
VII. Compliance Dates
The compliance dates and timing requirements to be followed when seeking
compliance with the SOCMI NSPS for either air oxidation processes or
distillation operations are shown in Table 8.
11
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TABLE 4. MONITORING AND REPORTING/RECORDKEEPING REQUIREMENTS FOR COMPLYING WITH 98 WEIGHT-PERCENT
REDUCTION OF TOC EMISSIONS OR A LIMIT OF 20 ppmv
Type of Control Device
,' •^^^»^:^; !'••' ...
U^jPor Compliance
Thermal
Incinerator
Catalytic
Incinerator
Boiler or Process Heater
Boiler or Process
Heater (design heat
input capacity <44 MW)
Boiler or Process Heater
(design heat input
capacity 244 MW)
•.:•• ; Monitoring Equipment
j Required
Temperature monitoring device
(installed in firebox) equipped
with a continuous recorder
(60.613(aX1).60.663(aX1)}
Flow indicator equipped
with a continuous recorder
(60.613(3X2), 60.66328°C (50°F) below the
average value measured during the most recent
performance test (60.615(cX1). 60.665(cX1)}
Periods when the vent stream is diverted
from the control device or has no flow rate.
(60.6150X2). 60.665(1X2)}
All 3-hour periods of operation when the average
temperature of vent stream upstream of the catalyst
bed is >28°C (50°F) below the average value from the
most recent performance test (60.615(0X2). 60.665(cX2)
All 3-hour periods of operation when the average
temperature difference across the catalyst bed is
28°C (50eF) below the
average value from the most recent
performance test (60.615(cX3). 60.665(cX3)
All periods when the boiler or process heater
is not operating (60.615(1X3). 60.665(1X3)}
ro
Regulatory citations are listed in brackets.
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TABLE 5. MONITORING AND REPORTING/RECORDKEEPING REQUIREMENTS FOR AFFECTED FACILITIES
COMPLYING WITH FLARE SPECIFICATIONS
Type of Control Device
Used for Compliance
Monitoring Equipment
a
Required
Parameters to be
Monitored
Recordkeeping
Requirements
Parameter Boundary Exceedences
to Report
Flare
Heat sensing device
{60.613(bXl). 60.663(bX1)}
Presence of a flame at the
pilot light
Continuous records
All periods when the pilot
flame is absent
(60.6150X4). 60.665(1X4))
Flow indicator
(60.613(bX2).60.663(bX2)}
Presence of flow to the flare
Continuous records
Periods when the vent stream is
o
diverted from the flare or has
no flow rate
(60.6150X2). 60.665(1X2)}
Regulatory citations are listed in brackets.
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TABLE 6. MONITORING AND REPORTING/RECORDKEEPING REQUIREMENTS
FOR MAINTAINING A TRE INDEX VALUE >1.0
1 ~nat,
rtecovery
Device
Absorber
Condenser
Carbon
Adsorber
Monitoring
Equipment
Required
Scrubbing liquid
temperature monitor
equipped with a
continuous recorder
{60.613(dX1Xi).
60.663(dX1Xi)}
Specific gravity
monitor equipped with
a continuous recorder
{60.61 3(dX1XI),
60.663(dXlXi)}
Organic monitoring
device equipped with
continuous recorder
{60.61 3(dXlX"),
eo.eeawxixii)}6
Condenser exit
temperature monitoring
device equipped with
continuous recorder
{60.61 3(dX2Xi),
60.663(dX2Xi)}
Organic monitoring
device equipped with
continuous recorder
{ 60.61 3(dX2X'').
60.663(dX2Xii)}.i'
Integrating steam (low
monitoring device and
carbon bed temperature
monitoring device.
each equipped with a
continuous recorder
{60.61 3(dX3Xi).
60.663(dX3Xi)}
Organic monitoring
device equipped with
continuous recorder
{60.613(dX3Xii).
60.663(dX3Xii)} b
Parameters to
be Monitored
Average exit temperature
of the absorbing liquid
Exit specific gravity (or
alternative parameter that
measures the degree of
absorbing liquid saturation, if
approved by the Administrator)
Concentration level or
reading indicated by the
organic monitoring device
at the outlet of the
absorber
Average exit (product
side) temperature
Concentration level or
reading indicated by the
organic monitoring device
at the outlet of the
condenser
Total steam mass flow during
carbon bed regeneration
cycles)
Temperature of the carbon bed
after regeneration (and within
15 minutes of completing any
cooling cycles(s)]
Concentration level or reading
indicated by the organic
monitoring device at the
outlet of the carbon adsorber
"' '• • '''•-. '•?' :' '•?:" ;':?:'!::-
Reeofdkeepitto;
Requirements
Continuous records
Continuous records
j
Continuous records
'-_ ''^ •• .'%:•:;:.'$• ''''. :? *
... •••?:.:,;'•: :|:.:.;|;;|;. V .
;::'•:;.• :.{'•. 1.CV- T
Continuous records
Continuous records
A;:W
• . v"-| _-y-" -;•
V. •^•l-'^'?;
Continuous records
Continuous records
Continuous records
Boundary Exeeedenees
to Report
All 3-hour periods of operation when
average temperature is >1 1 °C
(20° F) above the average
value from the most
recent performance test
{60.615(gX1Xi). 60.665(gX1XO}
All 3-hour periods of operation when
average liquid specific gravity is
>0.1 unit above or below the average
value from the most recent
performance test (60.6l5(gXlXii).
60.665(gX1Xi«)}
All 3-hour periods of operation
showing >20% of the amount measured
by the monitoring device during the
most recent performance test
{60.61 5(gX4),60.665(gX4)}
All 3-hour periods of operation
when average temperature is >6°C
(1 1 °F) above the average value from
the most recent performance test
{60.61 5(gX2). 60.665(gX2)}
All 3-hour periods of operation
showing >20% of the amount measured
by the monitoring device during the
most recent performance test
{60.61 5(gX4).60.665(gX4)}
When <10% below the value measured
during most recent performance test
{60.615(gX3XO. 60.665(gX3Xi)}
When >10 more than the value
measured during the most recent
performance test { 60.61 5(gX3Xii),
60.665(gX3X")}
All 3-hour periods of operation
showing >20% of the amount measured
by the monitoring device during the
most recent performance test
{60.615(gX4), 60.665(gX4)}
Regulatory citations are listed in brackets.
o
The organic concentration level may be monitored as an alternative to monitoring the other parameters) listed for this device.
14
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TABLE 7. PERFORMANCE TESTING PARAMETERS
Control Device
Parameters to
£
be Measured or Recorded
Measurement
Penod
Thermal
Incinerator
Average firebox temperature
{60.615(bX1XO. 60.665(0X1X0}
Measured at least every 15 minutes
and averaged over the length of
the performance test.
Percent reduction of TOG or
outlet concentration of TOG
(60.615(bX1Xii). 60.665(bX1XiO}
Catalytic
Incinerator
Average temperature upstream and
downstream of the catalyst bed
{60.615(bX1XO. 60.665(bX1Xi)}
Measured at least every 15 minutes
and averaged over the length of
the performance test.
Percent reduction of TOG or
outlet concentration of TOG
(60.615(bX1Xii). 60.665(bX1XiO}
Boiler or
Process
Heater
Description of location where the
vent stream is introduced into
the boiler or process heater
{60.615(bX2XO. 60.665(bX2Xi)}
Boiler or Process
Heater (design heat
input capacity <44 MW)
Average combustion temperature
{60.615(bX2XiO. 60.665(bX2Xii)}
Measured at least every 15 minutes
and averaged over the length of
the performance test.
Flare
Flare design (60.615(bX3). 60.665(bX3)}
Heat content determination
(60.615(bX3). 60.665(bX3)}
Visible emission reading
{60.615(bX3), 60.665(bX3)}
Flow rate measurement
(60.615(bX3). 60.66S(bX3)}
Exit velocity determination
{60.615(bX3), 60.665(bX3)}
Pilot flame observation
(60.615(bX3). 60.665(bX3)}
Absorber
Average exit temperature
of the absorbing liquid
{60.615ft)X4Xi).60.665^X4X0}
Measured at least every 15 minutes
and averaged for the length of the
performance test. (Measured
while the vent stream is
normally routed and constituted)
15
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TABLE 7. PERFORMANCE TESTING PARAMETERS
Recovery or
Control Devfee
Parameters to
a
be Measured or Recorded
Measurement
Period
Absorber (cont.)
Exit specific gravity (or alternative
parameter that measures the degree
of absorbing liquid
saturation, if approved
by the Administrator)
{60.615(bX4XO. 60.66S(bX4Xi)}
Measured every 15 minutes and
averaged for the length of the
performance test. (Measured
while the vent stream is
normally routed and constituted)
Concentration level or reading
indicated by the organic
monitoring device at the outlet of
the absorberc
{60.615(bX4Xiv). 60.665(bX4Xiv)}
Measured every 15 minutes and
averaged for the length of the
performance test. (Measured
while the vent stream is
normally routed and constituted)
Condenser
Average exit (product
side) temperature
{60.615(bX4Xi'), 60.665(bX4Xii)}
Measured every 15 minutes and
averaged for the length of the
performance test. (Measured
while the vent stream is
normally routed and constituted)
Concentration level or reading
indicated by the organic
monitoring device at the outlet of
the condenser c
{60.615(bX4Xiv). 60.665(bX4Xiv)}
Measured every 15 minutes and
averaged for the length of the
performance test. (Measured
while the vent stream is
normally routed and constituted)
Carbon
Adsorber
Total steam mass flow during
carbon bed regeneration cycle(s)
{60.615(bX4Xiii). 60.665(bX4Xiii)}
Measured every 15 minutes and averaged
for the length of the performance
test, (full carbon bed cycle)
Temperature of the carbon bed after
regeneration [and within 15 minutes
of completing any cooling cycles(s))
(60.615(bX4Xiii). 60.665(bX4XiiJ)}
Measured while the vent stream
is normally routed and
constituted.
Concentration level or reading
indicated by the organic
monitoring device at the outlet of
the carbon adsorber °
{60.615(bX4Xiv), 60.665(bX4Xiv)}
Measured every 15 minutes and
averaged for the length of the
performance test. (Measured
while the vent stream is
normally routed and constituted)
Regulatory citations are listed in brackets.
Parameter values measured during the initial (or subsequent) performance tests must be included in the
initial (or subsequent) performance test report. Up-to-date records of these parameters must also be maintained.
The organic concentration level may be measured as an alternative to the other parameters) required to be
measured for this device.
16
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TABLE 8. TIMING REQUIREMENTS FOR SOCMI AIR OXIDATION
PROCESSES AND DISTILLATION OPERATIONS
Activity
Date to
be Postmarked
Notification and Reoortinq (S6Q.7. S6Q.615. and 560.665)
1. Date of commencement of
construction or reconstruction
[§60.7(a)(l)]
2. Date of anticipated initial
startup [§60.7(a)(2)]
3. Date of actual initial startup
[§6p.7(a)(3)] and the specific
provision of the standard with
which the facility seeks to comply
[§60.615(a) or §60.665(1)]
4. Any physical or operational change
to an existing facility which
may increase the emission rate
[§60.7(a)(4)]
5. Date of commencement of
demonstration of CEMS performance
[§60.7(a)(5)3
6. Initial report of exceedances
[§60.615(j) or §60.665(1)]
7. Use of an alternative specific
provision for compliance with the
standards [§60.615(a) and
§60.665(a)]
No later than 30 days following
date of commencement8
No more than 60 days nor less
than 30 days prior to antici-
pated startup
Within 15 days after actual
startup3
60 days or as soon as
practicable before the
change is commenced
Not less than 30 days prior
to commencement
6 months following initial
startup (and semiannual
thereafter)
90 days before implementing the
change
Continued
"For those sources that were constructed, reconstructed, or modified between
the date of proposal and the date of promulgation, notification of the actual
oate of initial startup must be postmarked no later than 30 days following
the date of promulgation, the initial performance test must be conducted
within 60 days following promulgation if the maximum production rate at which
the affected facility will be operated has been achieved, or within 180 days
following promulgation if the maximum production capacity has not been
achieved.
17
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TABLE 8. TIMING REQUIREMENTS FOR SOCMI AIR OXIDATION
PROCESSES AND DISTILLATION OPERATIONS
Activity
Date to
be Postmarked
8. The occurrence and duration of any
startup, shutdown, or malfunction in
the operation of an affected facility
or any malfunction of air pollution
control equipment [§60.7(b)]
Performance Testing (560.8)
1. Initial performance test and written
report of results [§60.8(a)]
2. Any performance test [§60.8(d)]
3. Performance test if using an
alternative provision for compliance
with the standard [§60.615(a) and
§60.665(a)]
4. All performance testing and monitoring
measurements; all monitoring device
calibration checks; all adjustments
.and maintenance performed on these
devices [§60.7(d)]
Maintain records
Within 60 days after achieving
maximum production rate but
not later than 180 days after
initial startup8
30 days prior notification
required
Within 180 days after
implementing the change8
Maintain a file of this device
information and retain it for at
least 2 years after the date of
measurement or maintenance
Note: Wherever the subpart is more specific than the General Provisions, the
more specific language prevails.
8For those sources that were constructed, reconstructed, or modified between
the date of proposal and the date of promulgation, notification of the actual
date of initial startup must be postmarked no later than 30 days following
the date of promulgation, the initial performance test must be conducted
within 60 days following promulgation if the maximum production rate at which
the affected facility will be operated has been achieved, or within 180 days
following promulgation if the maximum production capacity has not been
achieved.
18
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Section 3. Total Resource Effectiveness fTREl Index Value Determination
This section describes the procedure that an owner or operator of an
affected facility must follow to determine the TRE index value and to identify
applicable regulatory provisions. Two examples are provided to illustrate the
procedure. Example 1 shows the case of a nonhalogenated distillation process
vent stream where the regulatory provisions require reduction of VOC emissions
by 98 weight percent or to 20 ppmv. Example 2 shows the case of a halogenated
air oxidation process vent stream where the regulatory provisions require
maintaining the TRE index value above 1.0.
Example 1
Consider a hypothetical n-butane distillation process vent stream
(nonhalogenated) that possesses the following characteristics:
(1) The vent stream flow rate (Q ) determined according to
§60.664(d)(3) is 18 scm/min (at a standard temperature of 20°C);
(2) The vent stream net heating value (HT) calculated using the equation
in Section 60.664(d)(4) is 0.37 MJ/scm (where the net enthalpy per
mole of vent stream is based on combustion at 25°C and 760 mm Hg,
but the standard temperature for determining the volume
corresponding to one mole is 20°C); and
(3) The hourly emissions of TOC (ETOC) calculated using the equation in
Section 60.664(d)(5) are 26.1 kilograms per hour (kg/hr). This
value excludes those compounds with negligible photochemical
reactivity (see Section 2.IV).
For an affected facility with a nonhalogenated vent stream, the TRE index
value must be de-termined for both an incinerator and a flare. The lower of
the two values is used for compliance purposes.
First, determine what the TRE index value would be if a flare is used to
control VOC emissions from this nonhalogenated vent stream. Because the vent
stream heating value is < 11.2 MJ/scm, the coefficients for the first flow
rate interval in Table 2 of the distillation regulation (see 55 FR 26948) are
used.
19
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These coefficients are:
a - 2.25
b - 0.288
c = -0.193
d = -0.0051
e - 2.08
Substituting these values into the TRE equation for a flare (found in
§60.664(e)(2), 55 FR 26945) gives the following result:
TRE - ETOC[a(Qs) + b(Qs)°-8 + c(Qs)(HT) + d(ETOC) + e]
TRE = 0.0383[2.25(18) + 0.288(18)°'8 - 0.193(284)(0.37) -
0.0051(26.1) + 2.08]
TRE = 0.0383[40.5 + 2.91 - 1.29 - 0.13 + 2.08]
TRE = 0.0383[44.07]
TRE = 1.69
This TRE index value is above the cutoff of 1.0.
The owner or operator, however, must perform an additional TRE
calculation to determine if it would be cost effective to control emissions
from this vent stream using an incinerator. Because the nonhalogenated vent
stream heating value of 0.37 MJ/scm is < 0.48, Design Category B is the
applicable incinerator design category as shown in Table 1 of the SOCMI
distillation regulation (55 FR 26947). Because the flow rate of the vent
stream is 18 scm/min, the coefficients for the first flow rate interval under
Category B are used. These coefficients are:
a = 8.54245
b = 0.10555
c = 0.09030
d = -0.17109
e = 0
f = 0.01025
Substituting these values into the TRE incinerator equation (found in
§60.664(e)(l), 55 FR 26945) gives the following result:
20
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TRE - ETOC[a + b(Qs)°'88 + c(QJ +d(Qs)(HT) + e^0'88)^)0'88 + f(Ys)°'5]
TRE - (0.0383)[8.54245 + 0.10555(18)0>88 + (0.09030)(18) +
(-0.17109)(18)(0.37) + 0(18)°-88(0.37)0'88 + 0.01025(18)°'5]
TRE - (0.0383)[8.54245 + 1.343 + 1.63 - 1.14 + 0 + 0.043]
TRE - (0.0383)[10.42]
TRE - 0.396
The owner or operator of the distillation affected facility must use the lower
of the two calculated TRE index values to demonstrate compliance with the
regulation. Because the TRE index value when using an incinerator is 0.396,
which is less than the cutoff value of 1.0, this distillation process unit
must reduce VOC emissions by 98 weight percent or to 20 ppmv because the cost
of incineration is considered to be reasonable.
Example 2
Consider a hypothetical ethylene dichloride air oxidation process vent
stream (halogenated) with the following characteristics:
(1) The vent stream flow rate (Qs) determined according to
§60.614(d)(3) is 512 scm/min (at standard temperature of 20°C);
(2) The vent stream net heating value (HT) calculated using the equation
in §60.614(d)(4) is 0.28 MJ/scm (where the net enthalpy per mole of
vent stream is based on combustion at 25°C and 760 mm Hg, but the
standard temperature for determining the volume corresponding to one
mole is 20°C); and
(3) The hourly emissions of TOC (ETQC) calculated using the equation in
§60.614(d)(5) are 45.2 kg/hr.
For an affected facility with a halogenated air oxidation process vent
stream, only the TRE index value of control with an incinerator needs to be
calculated. Because the vent stream heating value is < 3.5 MJ/scm,
Category Al is the applicable incinerator design category as shown in Table 1
of the SOCMI air oxidation regulation (55 FR 26927). Because the flow rate of
the vent stream is 512 scm/min, the coefficients for the second flow rate
interval under Category Al are used.
21
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These coefficients are:
a
b
c
d
e
f
20.00563
0.27580
0.30387
-0.13064
0
0.01025
Substituting these values into the TRE incinerator equation (found in
§60.614(e)(l), 55 FR 26925) gives the following result:
TRE - ETOC[a + b(Qs)°-M + c(Q.) + d(Qs)(HT) + e(Qs°-M)(HT°-88) + f(Qs)°'5]
TRE = (0.0221)[20.00 + 0.276(512)°-M + (0.304)(512) + (-0.131)(512)(0.28)
+ 0 + (0.010)(512)0'5]
TRE = 0.0221[20 + 66.84 + 155.65 - 18.78 + 0.226]
TRE = 0.0221[223.94]
TRE = 4.95
Because the calculated TRE index value when using an incinerator to control
VOC's in this air oxidation process vent stream is 4.95, which is greater than
the cutoff value of 1.0, the owner or operator of this air oxidation affected
facility must comply with §60.612(c) by maintaining the TRE index value above
1.0.
22
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Section 4. General Provisions
General provisions are presented in Subpart A of 40 CFR Part 60, from
§60.1 to §60.18. These provisions should be consulted whenever there are
questions regarding applicability of implementation of the standard. In this
section, summaries of §§60.14 (Modification), 60.15 (Reconstruction), and
60.18 (General Control Device Requirements) are presented. The reason for
explaining modification and reconstruction is to help ensure identification of
existing facilities to which the rule should be applied. The reason for
explaining general control device requirements is to ensure that flares used
to meet the standards will be operated properly.
I. Modification (§60.14)
Definition of Modification. Under Section 111 of the CAA, a modification
is any physical or operational change to an existing facility which results in
an increase in the emission rate to the atmosphere of any pollutant to which a
standard applies.
Potential Air Oxidation Modifications. Potential modifications involving
SOCMI air oxidation processes include catalyst substitution, process equipment
changes, and combinations of these changes.
Catalyst substitutions can be made to improve product mix, reduce
operating costs, or increase conversion rates. A change in catalysts may
cause significant changes in the quantity of VOC emissions. In addition,
these changes could require major modifications in the reactor system and
auxiliary process equipment. Changes in air oxidation process equipment could
result in increased VOC emissions and, if so, could constitute a modification
(e.g., an increase in the size of the reactor, addition of a reactor, and a
change in the product recovery system from an absorber to a condenser).
However, any changes in product recovery equipment would be intended to
increase product recovery and, therefore, VOC emissions would be expected to
decrease.
23
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Potential Distillation Modifications. Potential modifications involving
distillation operations include process equipment changes, changes in
operating parameters, or a combination of both. Distillation is generally a
low maintenance operation. However, it is not uncommon for a chemical
producer to replace internal distillation column parts, such as trays and
packing. Replacement with the same type of trays or packing is not a
modification, but an emissions increase caused by a replacement with a
different type of trays would constitute a modification. Similarly,
replacement of column accessories (e.g., reboiler, condenser, vacuum systems)
could not be considered a modification unless the replacement involved a
design which led to increased emissions. A change in the inlet feed stream to
the distillation unit (either to different proportions of the same chemical,
or to different chemicals entirely) could be considered a modification if an
emissions increase resulted and if the unit was not originally designed to
handle the different feedstreams.
Exceptions. As described in §60.14(e), there are six specific exceptions
to the regulatory definition of modification, any one of which by itself, is
not considered a modification. Also §60.14(f) contains a general exception.
Wherever a subpart is more specific than the general provision, the more
specific language takes precedence. The exceptions under §60.14(e) are listed
below:
maintenance, repair, and replacement which the Administrator
determines to be routine for a source category;
an increase in production rate of an existing facility, if the
increase was accomplished without a capital expenditure on the
facility;
an increase in the hours of production;
the use of an alternative fuel or raw material if, prior to the date
that the source became subject to an applicable standard under 40
CFR Part 60, the facility was designed to use the alternative fuel
or raw material;
the addition or use of any air pollution control system or device
except when such a system is removed or replaced by a system that
the Administrator determines to be less environmentally beneficial;
or
the relocation or change in ownership of an existing facility.
24
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Capital expenditure. The second specific exception mentioned above
hinges on the term "capital expenditure." Capital expenditure is defined in
§60.2 as an expenditure for a physical or operational change to an existing
facility which exceeds the product of the applicable "annual asset guideline
repair allowance percentage" (specified in Internal Revenue Service (IRS)
Publication 534) and the existing facility's basis (defined by Section 1012 of
the Internal Revenue Code). However, the total expenditure for a physical or
operational change to an existing facility must not be reduced by any
"excluded additions" (as defined in IRS Publication 534) as would be done for
tax purposes.
Requirements following modification. Once modified, an existing facility
becomes an affected facility for each pollutant to which a standard applies
and for which there is an increase in the emission rate to the atmosphere.
Compliance time following modification. Compliance with all applicable
standards must be accomplished within 180 days of completing the physical or
operation change. This time period is specified in §60.14(g).
Further information about modification. The preamble to the proposed air
oxidation rule published in 48 FR 48132 (October 21, 1983), the proposed
distillation rule published in 48 FR 57538 (December 30, 1983), and the
preamble to the final SOCMI rules published in 55 FR 26912 and 55 FR 26931
(June 29, 1990) contain useful information on the intent of the modification
provision.
II. Reconstruction (§60.15)
Definition. Reconstruction is defined in §60.15(b) and means the
replacement of components of an existing facility to such an extent that
(1) the fixed capital cost of the new components exceeds 50 percent (half) of
the fixed capital cost that would be required to construct a comparable
entirely new facility, and (2) it is technologically and economically feasible
to meet the applicable performance standards of 40 CFR 60. Also, note that
§60.15(g) includes the caveat: "Individual subparts of [Part 60] may include
specific provisions which refine and delimit the concept of reconstruction set
forth in [§60.15]."
25
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Distillation. In most cases, equipment changes for a distillation
operation would not incur a high cost compared to the cost of a new facility.
Therefore, it is expected that few changes in distillation facilities would
constitute a reconstruction. However, for facilities that may undergo
reconstruction, the applicable requirements are discussed in this section.
Air oxidation. No existing facility is expected to undergo sufficient
replacement of components to be considered a reconstructed facility. Reactors
and pieces of product recovery equipment within an affected facility would, in
general, have different ages as well as different lifetimes. Moreover, such
types of equipment are rarely replaced. Therefore, it is likely that a
considerable interval of time would separate replacements of individual
reactors or product recovery devices.
Fixed capital cost. The term "fixed capital cost" included in the
definition is the capital needed to provide all the depreciable components.
Difference between reconstruction and modification. When an existing
facility is reconstructed, it becomes an affected facility, regardless of any
change in emission rate. If an existing facility is modified, a resulting .
increase in emission rate must occur.
Notification requirements. If an owner or operator of an existing
facility proposes to replace components and the fixed capital cost of the new
components exceeds 50 percent of the fixed capital cost that would be required
to construct a comparable entirely new facility, he or she must notify EPA of
the proposed replacements. It should be noted that the fixed capital cost of
the new components includes the capital cost of all depreciable components
replacement of which commences within any 2-year period following proposal of
the standard. The notice must be postmarked 60 days, or as soon as
practicable, before construction of the replacement begins, and the notice
must contain the seven key elements specified in §60.15(d):
1. Name and address of the owner or operator;
2. The location of the existing facility;
3. A brief description of the existing facility and the components
which are to be replaced;
26
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4. A description of the existing air pollution control equipment
and the proposed air pollution control equipment;
5. An estimate of the fixed capital cost of the replacements and
of constructing a comparable entirely new facility;
6. The estimated life of the existing facility after replacements;
and
7. A discussion of any economic or technical limitations the
facility may -have in complying with the applicable standards
after the proposed replacements.
Procedure following notification. The Administrator has 30 days from
receipt of the notice and any additional information he or she may reasonably
require within which to determine whether the proposed replacement constitutes
a reconstruction. The determination shall be based on technical and economic
information specified under §60.15(f):
1. The fixed capital cost of the replacements compared to the
fixed capital cost that would be required to construct a
comparable entirely new facility;
2. The estimated life of the facility after the replacements
compared to the life of a comparable entirely new facility;
3. The extent to which the components being replaced cause or
contribute to the emissions from the facility; and
4. Any economic or technical limitations on compliance with
applicable standards of performance which are inherent in the
proposed replacements.
III. General Control Device Requirements (§60.18)
When a flare is used to seek compliance with the standards, the flare
must meet the requirements of §60.18 which are discussed below.
Flare types. Flares used to meet compliance must be steam-assisted, air-
assisted, or non-assisted.
No visible emissions. Flares must be designed for and operated with no
visible emissions as confirmed by Reference Method 22 (except for periods not
to exceed 5 minutes during any consecutive 2 hours).
27
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Flame must be present. Flares must be operated with a flame present at
all times as monitored by a thermocouple (or equivalent device).
Net heating value. If the flare is steam-assisted or air-assisted, the
net heating value of the combustor gas must be 11.2 MJ/scm (300 Btu/scf) or
greater.
If the flame is non-assisted, the net heating value of the combusted gas
must be 7.45 MJ/scm (200 Btu/scf) or greater. The following equation will be
used to calculate the net heating value of the gas combusted in the flare:
HT - * I C,H,
i=l
where:
HT » Net heating value of the sample, MJ/scm; where the net enthalpy per
mole of offgas is based on combustion at 25°C and 760 mm Hg, but the
standard temperature for determining the volume corresponding to one
mole is 20°C;
K = Constant,
1.740 x 10"7 ( 1 ) (q mole) (_MJ_J
ppm scm kcal
where the standard temperature for (q mole) is 20°C;
scm
Cf = Concentration of sample component i in ppm on a wet basis, as
measured for organics by Reference Method 18 and measured for
hydrogen and carbon monoxide by ASTM D1946-77 (incorporated by
reference as specified in §60.17); and
HJ = Net heat of combustion of sample component i, kcal/g mole at 25°C
and 760 mm Hg. The heats of combustion may be determined using ASTM
D2382-76 (incorporated by reference as specified in §60.17) if
published values are not available or cannot be calculated.
Exit velocity for steam-assisted and non-assisted flares. Steam-assisted
and non-assisted flares must be designed for and operated with an exit
velocity less than 18.3 m/sec (60 ft/sec). This exit velocity is calculated
by dividing the volumetric flow rate (in units of standard temperature and
28
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pressure), as determined by Reference Methods 2, 2A, 2C, or 2D as appropriate,
by the unobstructed (free) cross sectional area of the flare tip.
There are two exceptions to this exit velocity requirement:
1) If the net heating value of the combusted gas is >37.3 MJ/scm
(1000 Btu/scf), the exit velocity can be greater than
18.3 m/sec (60 ft/sec) but must be <122 m/sec (400 ft/sec); and
2) An exit velocity greater than 18.3 m/sec (60 ft/sec) is allowed
if it is less than the maximum permitted velocity and less than
122 m/sec (400 ft/sec). The maximum permitted velocity for
steam-assisted and non-assisted flares is calculated as
follows:
l°9io(VMX) - (HT+28.8)/3.17
where:
Vmax = maximum permitted velocity, m/sec;
28.8 * constant;
31.7 = constant; and
HT = the net heating value.
Exit velocity for air-assisted flares. Air-assisted flares must be
designed and operated with an exit velocity less than the maximum permitted
velocity calculated as follows:
vmax • 8-706 + °-7084
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Section 5. Existing Sources Affected
Sources affected by the SOCMI NSPS for air oxidation processes and
distillation operations are industries with a Standard Industrial
Classification (SIC) Code of 2869. A list of facilities with air oxidation
processes identified during development of the standard was taken from
Table 3-6 of the document entitled "Air Oxidation Processes in SOCMI -
Background Information for Proposed Standards" (EPA-450/3-82-001a). This list
is presented in Table 9. It should be noted, however, that the list may not
be completely accurate at present because of the length of time that has
passed since technical work on the NSPS was performed. It is presented here
only as a guide to assist in identifying sources that may be affected. A list
of facilities with distillation operations identified in a profile of the
industry is presented in Table 10. Although this is only a partial listing,
it may be helpful in identifying affected sources. Note that in addition to
the construction of new sources, any modification or reconstruction at one of
these existing facilities may be affected by the standards.
30
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TABLE 9. FACILITY IDENTIFIED WITH AIR OXIDATION PROCESS
Company
Location
Primary Air-Oxidation Products(s)
(Manufacturing Process
in Parentheses)
Allied Chemical
Allied Chemical
American Cyanamid
Amoco-Standard Oil
Amoco-Standard Oil
Amoco-Standard Oil
Amoco-Standard Oil
Ashland
Badische
BASF Wyandotte
Borden, Inc.
Borden, Inc.
Borden, Inc.
Borden, Inc.
Borden, Inc.
Borden, Inc.
Borden, Inc.
Borden, Inc.
Borden, Inc.
Borden, Inc.
Borden, Inc.
Carolina Eastman
Celanese Chemical
Celanese Chemical
Celanese Chemical
Celanese Chemical
Celanese Chemical
Celanese Chemical
Celanese Chemical
Celanese Chemical
Celanese Chemical
Celanese
Celanese
Chembond
Chembond
Chembond
Chembond
Chevron
Chevron
Chemical
Chemical
El Segundo, CA
Frankford, PA
Charlotte, NC
Joliet, IL
Joliet, IL
Charleston, SC
Decatur, AL
Neal, WV
Freeport, TX
Kearny, NJ
Demopolis, AL
01 boll, TX
Fayetteville, NC
Louisville, KY
Sheboygan, WI
Fremont, CA
Kent, WA
La Grande, OR
Missoula, MT
Springfield, OR
Geismar, LA
Columbia, SC
Bay City, TX
Bay City, TX
Bay City, TX
Bishop, TX
Clear Lake, TX
Clear Lake, TX
Clear Lake, TX
Newark, NJ
Pampa, TX
Pampa, TX
Rock Hill, SC
Andalusia, AL
Springfield, OR
Springfield, OR
Winnfield, AL
Richmond, CA
Richmond, CA
Phathalic Anhydride (Xylene)
Acetone/Phenol
Glyoxal
Isophthalic Acid
Maleic Anhydride (Butane)
TPA
TPA
Maleic Anhydride (Benzene)
Cyclohexanone/Cyclohexanol
Phathalic Anhydride (Xylene)
Formaldehyde (Silver)
Formaldehyde (Silver)
Formaldehyde (Silver)
Formaldehyde (Silver)
Formaldehyde (Silver)
Formaldehyde (Silver)
Formaldehyde (Silver)
Formaldehyde (Silver)
Formaldehyde (Silver)
Formaldehyde (Silver)
Formaldehyde (Silver)
Dimethyl Terephthalate (DMT)
Acetic Acid (Wacker)
Acetaldehyde
Cyclohexanone/Cyclohexanol
Formaldehyde (Silver)
Acetaldehyde
Acetic Acid (Wacker)
Acrylic Acid
Formaldehyde (Mixed Metal)
Acetic Acid/Formic Acid/MEK/
Butyric Acid/Propionic
Acid
Acrylic Acid
Formaldehyde
Formaldehyde
Formaldehyde
Formaldehyde
Formaldehyde
Acetone/Phenol
Phathalic Anhydride (Xylene)
(Mixed Metal)
(Mixed Metal)
(Mixed Metal)
(Silver)
(Mixed Metal)
31
Continued
-------
TABLE 9. FACILITY IDENTIFIED WITH AIR OXIDATION PROCESS (Continued)
Company
Location
Primary Air-Oxidation Products(s)
(Manufacturing Process
in Parentheses)
Ciba-Geigy
Ciba-Geigy
Clark Chemical
Conoco Chemicals
Copolymer Rubber
and Chemical
Crompton and Knowles
Degussa
Denka
Diamond Shamrock
Diamond Shamrock
Dow Chemical
Dow Chemical
Dow Chemical
Dow Chemical
Dow Chemical
Dow Chemical
Dow Chemical
DuPont
DuPont
DuPont
DuPont
DuPont
DuPont
DuPont
DuPont
DuPont
DuPont
DuPont
DuPont
El Paso Natural Gas
Ethyl
Ethyl
Exxon
Firestone
GAF Corporation
General Electric
Georgia-Pacific
Georgia-Pacific
Georgia-Pacific
Georgia-Pacific
St. Gabriel, LA
Glen Falls, NY
Blue Island, IL
Lake Charles, LA
Baton Rouge, LA
Fair Lawn, NJ
Theodore, AL
Houston, TX
Deer Park, TX
La Porte, TX
Freeport, TX
Freeport, TX
Freeport, TX
Oyster Creek, TX
Oyster Creek, TX
Plaquemine, LA
Plaquemine, LA
Belle, WV
Healing Springs, NC
LaPorte, TX
Linden, NJ
Memphis, TN
Old Hickory, TN
Orange, TX
Orange, TX
Toledo, OH
Victoria, TX
Victoria, TX
Wilmington, NC
Odessa, TX
Baton Rouge, LA
Pasadena, TX
Baton Rouge, LA
Orange, TX
Calvert City, KY
St. Vernon, IN
Albany, OR
Columbus, OH
Coos Bay, OR
Crossett, AR
Hydrogen Cyanide
Hydrogen Cyanide
Acetone/Phenol
1,2-Dichloroethane
1,3-Butadiene
Benzaldehyde
Hydrogen Cyanide
Maleic Anhydride (Benzene)
1,2-Dichloroethane
1,2-Dichloroethane
1,2-Dichloroethane
Ethylene Oxide
Hydrogen Cyanide
Acetone/Phenol
1,2-Dichloroethane
1,2-Dichloroethane
Ethylene Oxide
Formaldehyde (Silver)
Formaldehyde (Silver)
Formaldehyde (Silver)
Formaldehyde (Silver)
Acrylonitrile
Terephthalic Acid (TPA)
Cyclohexanone/Cyclohexanol
Hydrogen Cyanide
Formaldehyde (Silver)
Cyclohexanone/Cyclohexanol
Hydrogen Cyanide
Terephthalic Acid (TPA)
1,3-Butadiene
1,2-Dichloroethane
1,2-Dichloroethane
Phathalic Anhydride (Xylene)
1,3-Butadiene
Formaldehyde (Mixed Metal)
Acetone/Phenol
Formaldehyde (Mixed Metal)
Formaldehyde (Mixed Metal)
Formaldehyde (Mixed Metal)
Formaldehyde (Silver)
32
-------
TABLE 9. FACILITY IDENTIFIED WITH AIR OXIDATION PROCESS (Continued)
Company
Location
Primary Air-Oxidation Products(s)
(Manufacturing Process
in Parentheses)
Georgia-Pacific
Georg'ia-Pacific
Georgia-Pacific
Georgia-Pacific
Georgia-Pacific
Getty Refining
B.F. Goodrich Chemical
Gulf Oil
Hereofina
Hercofina
Hercules
Hooker
ICI Americas
Petrochemicals
International Minerals
& Chemical
International Minerals
& Chemical
Kalama Chemical
Koppers
Koppers
Monsanto Chemical
Monsanto Chemical
Monsanto Chemical
Monsanto Chemical
Monsanto Chemical
Monsanto Chemical
Monsanto Chemical
Monsanto Chemical
Monsanto Chemical
Monsanto Chemical
Monsanto Chemical
Monsanto Chemical
Monsanto Chemical
Nipro
Northwest Indust.
Northwest Indust.
Oxirane
Pacific RC
Lufkin, TX
Plaquemine, LA
Russelville, SC
Taylorsville, MS
Vienna, GA
El Dorado, KS
Calvert City, KY
Vicksburg, MS
Wilmington, NC
Spartanburg, SC
Louisiana, MO
North Tonawanda, NY
Baton Rouge, LA
Seiple, PA
Seiple, PA
Kalama, WA
Bridgeville, PA
Cicero, IL
Addyston, OH
Alvin, TX
Bridgeport, NJ
Chocolate Bayou, TX
Chocolate Bayou, TX
Eugene, OR
Pensacola, FL
Springfield, MA
St. Louis, MO
St. Louis, MO
Texas City, TX
Texas City, TX
Texas City, TX
Augusta, GA
Beaumont, TX
Chattanooga, TN
Channelview, TX
Eugene, OR
Formaldehyde (Mixed.Metal)
Acetone/Phenol
Formaldehyde (Mixed Metal)
Formaldehyde (Mixed Metal)
Formaldehyde (Silver)
Acetone/Phenol
1,2-Dichloroethane
Formaldehyde (Mixed Metal)
DMT/TPA
DMT
Formaldehyde (Silver)
Formaldehyde (Silver)
1,2-Dichloroethane
Formaldehyde (Mixed Metal)
Formaldehyde (Silver)
Benzoic Acid/Phenol
Phathalic Anhydride
(Naphthalene)
Phathalic Anhydride
(Xylene)
Formaldehyde (Silver)
Acrylonitrile
Phathalic Anhydride
(Naphthalene)
Acetone/Phenol
Formaldehyde (Silver)
Formaldehyde (Silver)
Cyclohexanone/Cyclohexanol
Formaldehyde (Silver)
Maleic Anhydride (Benzene)
Maleic Anhydride (Butane)
Acrylonitrile
Hydrogen Cyanide
Phathalic Anhydride (Xylene)
Cyclohexanone/Cyclohexanol
Benzoic Acid/Phenol
Benzoic Acid/Phenol
Propylene Oxide/Styrene
Formaldehyde (Silver)
33
/^-3?T>ngr7pr
-------
TABLE 9. FACILITY IDENTIFIED WITH AIR OXIDATION PROCESS (Continued)
Company
Location
Primary Air-Oxidation Products(s)
(Manufacturing Process
in Parentheses)
Pfizer Chemicals
Pfizer Chemicals
P.P.G. Industries
Chemical-US
Reichhold Chemicals
Reichhold Chemicals
Reichhold Chemicals
Reichhold Chemicals
Reichhold Chemicals
Reichhold Chemicals
Reichhold Chemicals
Reichhold Chemicals
Reichhold Chemicals
Rohm and Haas
Rohm and Haas
Shell Chemical
Shell Chemical
Shell Chemical
Shell Chemical
Stauffer Chemical
Stepan
Tenneco
Tenneco
Tenneco
Tenneco
Tenneco
Tenneco
Tennessee Eastman
Tennessee Eastman
Tennessee Eastman
Tennessee Eastman
Tennessee Eastman
Texas Eastman
Toms River Chemical
U.S. Steel Chemical
U.S. Steel Chemical
U.S. Steel Chemical
Union Carbide
Union Carbide
Union Carbide
Terre Haute, IN
Terre Haute, IN
Lake Charles, LA
Hampton, SC
Houston, TX
Kansas City, KS
Malvern, AR
Moncure, NC
Morris, IL
Tacoma, WA
Tuscaloosa, AL
White City, OR
Deer Park, TX
Deer Park, TX
Deer Park, TX
Deer Park, TX
Martinex, CA
Nordo, LA
Long Beach, CA
Millsdale, IL
Fords, NJ
Fords, NJ
Fords, NC
Garfield, NJ
Garfield, NJ
Houston, TX
Kingsport, TN
Kingsport, TN
Kingsport, TN
Kingsport, TN
Kingsport, TN
Longview, TX
Toms River, NJ
Haverhill, OH
Neville Island, PA
Neville Island, PA
Bound Brook, NJ
Penuelas, Puerto Rico
Ponce, Puerto Rico
Benzoic Acid/Phenol
Maleic Anhydride (Benzene)
1,2-Dichloroethane
Formaldehyde (Silver)
Formaldehyde (Mixed Metal)
Formaldehyde (Silver)
Formaldehyde (Mixed Metal)
Formaldehyde (Mixed Metal)
Maleic Anhydride (Benzene)
Formaldehyde (Mixed Metal)
Formaldehyde (Silver)
Formaldehyde (Mixed Metal)
Acrylic Acid
Hydrogen Cyanide
Acetone/Phenol
1,2-Dichloroethane
p-t-Butylbenzoic Acid
1,2-Dichloroethane
1,2-Dichloroethane
Phathalic Anhydride (Xylene)
Formaldehyde (Mixed Metal)
Formaldehyde (Silver)
Maleic Anhydride (Benzene)
Benzoic Acid/Phenol
Formaldehyde (Silver)
1,3-Butadiene
Acetic Acid (Wacker)
n-Butyric Acid
Crotonic Acid
Isobutyric Acid
TPA
Acetaldehyde
Anthraquinone
Acetone/Phenol
Maleic Anhydride (Benzene)
Phathalic Anhydride
(Naphthalene)
Acetone/Phenol
Acetone/Phenol
Ethylene Oxide
34
-------
TABLE 9. FACILITY IDENTIFIED WITH AIR OXIDATION PROCESS (Concluded)
Union Carbide Seadrift, TX Ethylene Oxide
Union Carbide Taft, LA Acrylic Acid/Acrolein
Union Carbide Taft, LA Ethylene Oxide
Union Carbide Texas City, TX Propionic Acid
Vistron (SOHIO) Lima, OH Acrylonitrile
Vulcan Chemicals Geismar, LA 1,2-Dichloroethane
Wright Chemical Riegelwood, NC Formaldehyde (Mixed Metal)
35
-------
TABLE 10. FACILITIES IDENTIFIED WITH DISTILLATION OPERATIONS
Company
Location
Primary Air-Oxidation Product(s
(Manufacturing Process
in Parentheses)
Air Products &
Chemicals, Inc.
Allied Chemical Corp.
American Cyanamid Co.
American Hoechst Corp.
Amoco Corp.
Amoco Corp.
Amoco Corp.
Ashland Oil. Inc.
BASF Wyandotte Corp.
Bordon
Caleasieu Chemical Corp.
Cape Industries
Cape Industries
Celanese Corp.
Celanese Corp.
Celanese Corp.
Celanese Corp.
Celanese Corp.
Chevron
Chevron
Columbia Nitrogen Corp.
Continental Oil Co.
Continental Oil Co.
Continental Oil Co.
Cosden Oil & Chemical
Company
CYRO Industries
Denka Chemicals Co.
Diamond Shamrock Corp.
Dow Badische Co.
Dow Badische Co.
Dow Badische Co.
Dow Badische Co.
Dow Badische Co.
Dow Badische Co.
E.I. DuPont de Nemours & Co.
E.I. DuPont de Nemours & Co.
E.I. DuPont de Nemours & Co.
E.I. DuPont de Nemours & Co.
E.I. DuPont de Nemours & Co.
E.I. DuPont de Nemours & Co.
E.I. DuPont de Nemours & Co.
E.I. DuPont de Nemours & Co.
E.I. DuPont de Nemours & Co.
E.I. DuPont de Nemours & Co.
E.I. DuPont de Nemours & Co.
E.I. DuPont de Nemours & Co.
E.I. DuPont de Nemours & Co.
Pensacola, FL
Danville, IL
Avondale, LA
Baton Rouge, LA
Joliet, IL
Joliet. IL
Texas dity, TX
Catlettsburg, KY
Geismar, LA
Fayetteville, NC
Lake Charles, LA
Wilmington, NC
Wilmington, NC
Bay City, TX
Bishop, TX
Bishop. TX
Clear take, TX
Clear Lake. TX
Richmond, CA
Richmond, CA
Augusta, GA
Baltimore, MD
Lake Charles, LA
Lake Charles, LA
Big Spring, TX
New Orleans, LA
Houston, TX
Deer Park, TX
Freeport, TX
Freeport, TX
Freeport, TX
Freeport, TX
Freeport, TX
Freeport, TX
Beaumont, TX
Cape Fear, NC
Deepwater, NJ
Deepwater, NJ
Houston, TX
Laplace, LA
Louisville. KY
Memphis. TN
Old Hickory, TN
Orange, TX
Orange. TX
Victoria, TX
Victoria, TX
Methanol
Tri chl orof 1uoromethane
Acrylonitrile
Styrene
Maleic anhydride
Isophthalic acid
Styrene
Cumene
Ethylene glycol
Formaldehyde
Ethylene oxide
Methyl toluate
Methyl benzoate
Vinyl acetate
Formaldehyde
Methanol
Acetaldehyde
Acetic acid
Phenol
Acetone
Caprolactum
Alkyl benzene
Ethyl dichloride
Vinyl chloride
Cyclohexane
Methyl methacrylate
Chloroprene
Perchloroethylene
Cyclohexanol
Cyclohexanone
Acrylic acid
Isobutanol
Isobutraldehyde
Caprolactum
Acrylonitrile
Dimethyl terephthalate
Tri chlorof1uoromethane
Dichlorof1uoromethane
Vinyl acetate
Chloroprene
Chlorodi f1uoromethane
Methyl methacrylate
Dimethyl terephthalate
Ethylene
Ethylene
Adiponitrile
Hexanthylene diamine
36
-------
TABLE 10. FACILITIES IDENTIFIED WITH DISTILLATION OPERATIONS (Continued)
Company
Location
Primary Air-Oxidation Productfs
(Manufacturing Process
in Parentheses)
Eastman Kodak
Eastman Kodak
Eastman Kodak
Eastman Kodak
Eastman Kodak
El Paso Natural Gas Co.
El Paso Natural Gas Co.
Ethyl Corp.
Ethyl Corp.
Ethyl Corp.
Exxon Corp.
Exxon Corp.
Exxon Corp.
FMC Corp.
FMC Corp.
FMC Corp.
FMC Corp.
B.F. Goodrich Co.
Hani in Group, Inc.
Hani in Group, Inc.
Hani in Group, Inc.
Hani in Group, Inc.
ICI Americas, Inc.
Koppers Co., Inc.
Koppers Co., Inc.
Mobil Oil Corp.
Mobil Oil Corp.
Mobil Oil Corp.
Monsanto Co.
Monsanto Co.
Monsanto Co.
Monsanto Co.
Monsanto Co.
Monsanto Co.
Monsanto Co.
Monsanto Co.
Monsanto Co.
Montrose Chemical Corp.
Montrose Chemical Corp.
Nipro, Inc.
Nipro, Inc.
Occidental Petroleum Co.
PPG Industries, Inc.
PPG Industries, Inc.
PPG Industries, Inc.
PPG Industries, Inc.
PPG Industries, Inc.
PPG Industries, Inc.
PPG Industries, Inc.
PPG Industries, Inc.
Kingsport, TN
Kingsport, TN
Kingsport, TN
Kingsport, TN
Kingsport. TN
Odessa, TX
Odessa, TX
Baton Rouge, LA
Baton Rouge, LA
Baton Rouge, LA
Baytown, TX
Bayway, NJ
Bayway. NJ
Bayport, TX
Bayport, TX
Bayport, TX
Bayport, TX
Calvert City, KY
Moundsville, WV
Port Arthur, TX
Port Arthur. TX
St. James, LA
Baton Rouge, LA
Bridgevilte, PA
Cierco, IL
Beaumont, TX
Beaumont, TX
Beaumont, TX
Alvin, TX
Alvin, TX
Alvin, TX
Alvin, TX
Alvin, TX
Alvin, TX
St. Louis, MO
Texas City, TX
Texas City, TX
Henderson, NV
Henderson. NW
Augusta, GA
Augusta, GA
Bayport. TX
Beaumont, TX
Lake Charles, LA
Lake Charles, LA
Lake Charles, LA
Lake Charles, LA
Natrium, WV
Natrium, WV
Natrium, WV
Acetic acid
Acetic acid, anhydride
Acetone
Ethyl acetate
Dimethyl terephthalate
Styrene
Ethyl benzene
Perchloroethylene
Trichloroethylene
Vinyl chloride
Cyclohexane
Acetone
Mesityl alcohol
Acetone
Allyl alcohol
Glycidol
Glycerin
Ethylene
Methyl chloride
Cumene
Cyclohexane
Ethyl benzene
Ethyldichloride
Maleic anhydride
Phthalic anhydride
Butadiene
Propylene
Ethylene
Alkyl benzene
Cumene
Acetpne
Adipic Acid
Acrylonitrile
Phenol
Maleic anhydride
Styrene
Phthalic anhydride
Chlorobenzene
Dichlorobenzene
Cyclohexanol
Cyclohexanone
Ethanolanimes
Ethylene oxide
Vinly chloride
Perch!oroethylene
Tricnloroethylene
Trichlorpethane
Carbon disulfide
Chlorobenzene
Dichlorobenzene
37
-------
TABLE 10. FACILITIES IDENTIFIED WITH DISTILLATION OPERATIONS (Concluded)
Company
Location
Primary Air-Oxidation Product(s
(Manufacturing Process
in Pare7ntneses)
Phillips Petroleum Co.
Phillips Petroleum Co.
Phillips Petroleum Co.
Pilot Chemicals
Pilot Chemicals
Quantum Chemical Co.
Quantum Chemical Co.
Rohm & Haas Co.
Rohn & Haas Co.
Rubicon Chemicals, Inc.
Rubicon Chemicals, Inc.
Shell Chemical Co.
Shell Chemical Co.
Shell Chemical Co.
Shell Chemical Co.
Shell Chemical Co.
Shell Chemical Co.
Shell Chemical Co.
Standard Oil Co. (Ohio)
The Stepan Chemical Co.
Sun Co., Inc.
Sun Co., Inc.
Sun Co., Inc.
Sun Co., Inc.
Tenneco, Inc.
Union Carbide Co.
Union Carbide Co.
Union Carbide Co.
Union Carbide Co.
Union Carbide Co.
Union Carbide Co.
Union Carbide Co.
Union Carbide Co.
Union Carbide Co.
Union Carbide Co.
Union Carbide Co.
Union Carbide Co.
U.S. Industrial
Chemicals Co.
Vulcan Materials Co.
Vulcan Materials Co.
Vulcan Materials Co.
Vulcan Materials Co.
Vulcan Materials Co.
Witco Chemical Corp.
Guayama, PR
Sweeny, TX
Sweeny, TX
Houston, TX
Houston, TX
Morris, IL
Morris, IL
Deer Park, TX
Deer Park. TX
Geismar, LA
Geismar, LA
Deer Park, TX
Deer Park, TX
Deer Park, TX
Deer Park, TX
Deer Park, TX
Dominiguez. CA
Geismar, LA
Lima, OH
El wood, IL
Corpus Christi, TX
Corpus Christi, TX
Corpus Christi,-TX
Tulsa, OK
Garfield. NJ
Brownsville, TX
Brownsville, TX
Institute & South
Charleston, WV
Institute & South
Charleston, WV
Institute & South
Charleston, WV
Institute & South
Charleston, WV
Institute & South
Charleston, WV
Institute 4 South
Charleston. WV
Seadrift, TX
Taft, LA
Taft, LA
Taft, LA
Deer Park, TX
Geismar, LA
Geismar, LA
Geismar, LA
Geismar, LA
Wichita, KS
Carson, CA
Cyclohexane
Ethylene
Propylene
1-Butene
Butadiene
Ethylene
Propylene
Acetone cyanohydride
Methyl methacrylate
Aniline
Diphenylamione
Acetone
Ally! chloride
Methyl ethyl ketone
Cumene
Butadiene
Acetone
Ethylene glycol
Acrylonitrile
Phtnalic anhydride
Ethyl benzene
Cumene
Styrene
Cyclohexane
Formaldehyde
Acetic acid
Acetic acid, anhydride
Acetone
Alkyl benzene
Ethanol
Formic acid
Ethyl acetate
Ethylene oxide
Ethylene oxide
Ethyl acrylate
Acrylic esters
Acrylic acid
Vinyl acetate
Methyl chloride
Percnloroethylene
Carbon tetrachloride
Ethyl dichloride
Perch!oroethylene
Alkyl benzene
38
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Section 6. Implementation Plan for SOCHI
Air Oxidation Processes (40 CFR 60. Suboart III)
and Distillation Operations (Suboart NNN)
This plan identifies those activities and documents necessary to enable
the regional offices and delegated authorities to implement and enforce the
new source performance standards for air oxidation processes and distillation
operations in the synthetic organic chemical manufacturing industry .(SOCMI)
promulgated in June 1990. This plan notes the lead office, contact person,
due date, and objective of each activity and document identified.
The goal of each activity and document identified in this plan is the
successful implementation of the SOCMI NSPS. In setting the deadline for each
item identified in this plan, SSCD and ESD tried to set realistic dates, i.e.,
a balance between the need for timely guidance and training and the
recognition of the competing demands made upon the person responsible for
developing that guidance or training. Given that these two forces are often
in a state of flux, the deadlines in this plan are subject to change. SSCD
and ESD hope to keep all parties informed of changes in deadlines as soon as
those changes are known. If you have any questions regarding this plan,
please contact Ron Shafer at FTS 382-2810 or Debbie Stackhouse at
FTS 629-5258.
1. SOCMI Compliance Monitoring Strategy
LEAD: SSCD CONTACT: Ron Shafer
DUE DATE: 11/1/90 TELEPHONE: FTS 382-2810
OBJECTIVE: SSCD will explore the need for a compliance monitoring strategy
(CMS). Designed for use by the headquarters, regions, and delegated
authorities, a CMS describes the responsibilities of each office in
implementing the rule and provides guidance on targeting inspections and using
self-monitoring data (where available and applicable). Because these NSPS are
automatically delegated in most cases to State and local authorities, SSCD
will explore the need to develop such a plan. A decision whether or not to
develop a compliance monitoring strategy for these SOCMI NSPS will be made by
11/1/90.
39
-------
II. Summary of Rules (Air Oxidation Processes and Distillation Operations)
LEAD: ESD CONTACT: Debbie Stackhouse
DUE DATE: July 1990 TELEPHONE: FTS 629-5258
OBJECTIVE: Designed for use by the regions, headquarters, State and local
authorities, a/id owners/operators of affected facilities, this document will
provide "plain English" summaries of the rules. This document will also
consist of flowcharts or tables for determining applicability, standards,
compliance, and exemptions.
III. Inspection Manual and Training for Subparts III and NNN
LEAD: SSCD CONTACT: Ron Shafer
DUE DATE: est. FY91 TELEPHONE: FTS 382-2810
OBJECTIVE: Designed for use by regional, State and local inspectors and
in-house auditors, these documents will provide a step-by-step guide to
inspecting the facilities affected by Subparts III and NNN. SSCD is
considering the need to include development of an inspection manual and
training for Subparts III and NNN on the Technical Agenda for FY91.
IV. List of Sources Affected
LEAD: SSCD with ESD CONTACT: Ron Shafer
DUE DATE: July 1990 TELEPHONE: FTS 382-2810
OBJECTIVE: Designed for use by headquarters, regions, and delegated
authorities, this document will be an initial compilation of sources known to
be or believed to be affected by Subparts III and NNN. These two lists will
be compiled from information in existing databases and from data gathered in
the process of rule development. The list will al§o provide SICs for source
categories affected by the new rules. The regional offices will need to
identify to SSCD those sources for which there is not enough information to
input the source in CDS.
40
-------
V. Compilation of Available Technical Support
LEAD: SSCD with ESD CONTACT: Ron Shafer
DUE DATE: 11/30/90 TELEPHONE: FTS 382-2810
OBJECTIVE: Designed for headquarters, regions, delegated authorities, and
owners/operators of affected facilities, this document will serve as an
annotated bibliography of existing reference books, guidance background
•
information documents, and hotlines related to synthetic organic chemical
manufacturing control methodology, health risks, and related topics. This
document must be placed on the Technical Agenda and probably will be put
together with contractor assistance.
VI. Computer Program for Calculating TRE Index Value
LEAD: ESD CONTACT: Robert Rosensteel
DUE DATE: FY91 TELEPHONE: FTS 541-5608
OBJECTIVE: Designed for use by the regional office or State and local permit
reviewers (or complying facilities), this computer program will calculate the
TRE index value when the appropriate vent stream parameters (i.e., flow rate,
heating value, VOC emission rate, and halogenation status) are input. The
program will enable the user to quickly and accurately calculate the TRE index
value so that the correct regulatory provisions can be applied. The program
will be available by the first quarter of FY91.
41
-------
Section 7
This section contains a copy of the regulations for VOC emissions from
SOCMI air oxidation processes (Subpart III) and VOC emissions from SOCMI
distillation operations (Subpart NNN).
42
-------
26922
Federal Ragiatar / Vol s& No. 128 / Friday. June 29. 1990 / Rules and Regulation.-
pertaining to the standards ha* been put
in the docket (A-81-22).
Regulatory Flexibility Analysis
The Regulatory nexibility Act of 1980
require* that adverse effects of ail
Federal regulations upon small
businesses be identified. According to
current Small Business Administration
guidelines, a small business in the air
oxidation industry is one that has 1.000
employees or less. Currently only 4
percent of existing air oxidation
companies (three companies) employ
less than 1.000 people. No new,
modified, or reconstructed small air
oxidation facilities will be adversely
affected by the standards. This
conclusion is based on the fact that in
doing the economic analysis for this
standard, the price increase and
profitability impacts have been
estimated from the perspective of the
smaller air oxidation facilities in
operation. The findings of this analysis
that producers of air oxidation
chemicals, under a worst-case scenario.
would be able to pass through NSPS
compliance costs to their customers
while keeping the price increase of their
product under 5 percent accurately
reflects the impacts for small air
oxidation companies.
The economies of scale that exist in
this industry hinder the entrance of
small businesses. Furthermore, if a
company has die capital available to
enter the industry, the NSPS will require
only a small percentage increase in the
capital required for the project
Pursuant to the provisions of 5 U.S.C.
605(b). I hereby certify that this rule will
not have a significant economic impact
on a substantial number of small
entities.
List of Subjects in 40 CFR Part 60
Air pollution control. Incorporation by
reference. SOCM1 air oxidation
processes.
Dated: fune 1.1990.
William K. Rmlly.
Administrator.
PART 60-{ AMENDED)
40 CFR part 60 is amended as follows:
1. The authority citation for part 60
continues to read as follows:
Authority: Scat. 101. 111. 114.118. and 301
of the Clean Air Act (CAA) at amended (42
U.S.C. 7401. 7411. 7414. 7416. 7801).
2. Section 60.17 is amended by
revising (a)(6) and (a){38). removing
fa)(48). and redesignating (a)(47) through
(a)(55) as (a)(40) through (a)(S4) to read
as follows:
160.17 Incorporation by reference.
••••••
(a) • ' •
(6) ASTM D1946-77, Standard Method
for Analysis of Reformed Gas by Gas
Chromatography. IBR approved for
if 60.45(f)(5)(i). 60.18(f). 60.614(d)(2)(ii).
60.814(d)(4).
• • • • *
(38) ASTM D2382-76. Heat of
Combustion of Hydrocarbon Fuels by
Bomb Calorimeter [High-Precision
Method], IBR approved for { 60.18(f).
60.48S(g). 80.814(d)(4).
• • • • • -
3. By adding subpart III to read as •
follows:
Subpart Ill-Standards of Performance for
Volatile Organic Compound Emissions
From the Synthetic Organic Chemical
Manufacturing Industry (SOCMI) Air
Oxidation Unit Processes
Sec.
60.010 Applicability and designation of
affected facility.
80.811 Definitions.
80.812 Standards.
80.813 Monitoring of (millions and
operations.
80.814 Test methods and procedures.
80.815 Reporting and recordkeeping
requirements.
60.618 Reconstruction.
60.617 Chemicals affected by subpart in.
80.818 Delegation of Authority.
Subpart III—Standards of Performance
for Volatile) Organic Compound (VOC)
Emissions) From th« Synthetic Organic
Gnomical Manufacturing Industry
(SOCMI) Air Oxidation Unit Processes
980.610 AppOcsbUlty and designation of
affected faculty.
(a) The provisions of this subpart
apply to each affected facility
designated in paragraph (b) of this
section that produces any of the
chemicals listed in | 60.617 as a product,
co-product by-product or intermediate,
except as provided in paragraph (c) of
this section.
(b) The affected facility is any of the
following for which construction.
modification, or reconstruction
commenced after October 21.1983:
(1) Each air oxidation reactor not
discharging its vent stream into a
recovery system.
(2) Each combination of an air
oxidation reactor and the recovery
system into which its vent stream is
discharged.
(3) Each combination of two or more
air oxidation reactors and the common
recovery system into which their vent
streams are discharged.
(c) Each affected facility that has a
total resource effectiveness (TRE) index
43
value greater than 4.0 la exempt from all
provisions of this subpart except for
II 60.612.00.614(0. aOAlSTh). and
60.615(1].
(Not*: The Intent of these standards is to
minimize the emissions of VOC through the
application of BDT, The numerical emission
limits in these standards are expressed in
terms of total organic compounds (TOC).
measured as TOC minus methane and
ethane. This emission limit reflects the
performance of BDT.)
{60.611 Definitions.
As used in this subpart all terms not
defined here shall have the meaning
given them in the Act and in subpart A
of part 60. and the following terms shall
have the specific meanings given them.
Air Oxidation Reactor means any
device or process vessel in which one or
more organic reactants are combine
with air. or a combination of air and
oxygen, to produce one or more organic
compounds. Ammoxidation and
oxychlorination reactions are included
in this definition.
Air Oxidation Reactor Recovery
Train means an individual recovery
system receiving the vent stream from at
least one air oxidation reactor, along
with all air oxidation reactors feeding
vent streams into this system.
Air Oxidation Unit Process means a
unit process, including.ammoxidation
and oxychlorination unit process, that
uses air. or a combination of air and
oxygen, as an oxygen source in
combination with one or more organic
reactants to produce one or more
organic compounds.
Boilers means any enclosed
combustion device that extracts useful
energy in the form of steam.
By Compound means by individual
stream components, not carbon
equivalents.
Continuous recorder means a data
recording device recording an
instantaneous data value at least once
every 15 minutes.
Flame zone means the portion of the
combustion chamber in a boiler
occupied by the flame envelope.
Flow indicator means a device which
indicates whether gas flow is present in
a vent stream.
Halogenated Vent Stream means any
vent stream determined to have a total
concentration (by volume) of
compounds containing halogens of 20
ppmv (by compound) or greater.
Incinerator, means any enclosed
combustion device that is used for
destroying organic compounds and does
not extract energy in the form of steam
or process heat
-------
Federal Register / Vol. 55. No. 126 / Friday. June 29. 1990 / Rules and Regulations
26923
Process Heater means a device that
.nsfers heat liberated by burning fuel
10 fluids contained in tubes, including all
fluids except water that is heated to
produce steam.
Process Unit means equipment
assembled and connected by pipes or
ducts to produce, as intermediates or
final products, one or more of the
chemicals in i G0.617. A process unit can
operate independently if supplied with
sufficient fuel or raw materials and
sufficient product storage facilities.
Product means any compound or
chemical listed in \ 80.617 that is
produced for sale as a final product as
that chemical or is produced for use in a
process that needs that chemical for the
production of other chemicals in another
facility. By-products, co-products, and
intermediates are considered to be
products.
Recovery Device means an individual
unit of equipment, such as an absorber.
condenser, and carbon adsorber.
capable of and used to recover
chemicals for use, reuse or sale.
Recovery System means an individual
recovery device or series of such
devices applied to the same process
stream.
Total organic compounds (TOC)
means those compounds measured
'ccording to the procedures in
i 60.614(b)(4). For the purposes of
measuring molar composition as
required in i a0.614(d)(2)(i). hourly
emissions rate as required in
J 60.614(d)(5) and i 60.614(e) and TOC
concentration as required in
j 60.615(b)(4) and J e0.615(g}(4). those
compounds which the Administrator has
determined do not contribute
appreciably to the formation of ozone
are to be excluded. The compounds to
be excluded are identified in
Environmental Protection Agency's
statements on ozone abatement policy
for SIP revisions (42 FR 35314; 44 FR
32042; 45 FR 32424; 45 FR 48942).
Total resource effectiveness (TRE)
Index Value means a measure of the
supplemental total resource requirement
per unit reduction of TOC associated
with an individual air oxidation vent
stream, based on vent stream flow rate.
emission rate of TOC. net heating value,
and corrosion properties (whether or not
the vent stream is halogenated), as
quantified by the equation given under
| 60.614(e).
Vent Stream means any gas stream,
containing nitrogen which was
introduced as air to the air oxidation
reactor, released to the atmosphere
directly from any air oxidation reactor
recovery train or indirectly, after
diversion through other process
equipment The vent stream excludes
equipment leaks and relief valve
discharges including, but not limited to,
pumps, compressors, and valves.
$60.612 Standard*.
Each owner or operator of any
affected facility shall comply with
paragraph (a), (b). or (c) of this section
for each vent stream on and after the
date on which the initial performance
test required by i 60.8 and i 60.814 is
completed, but not later than 60days
after achieving the maximum production
rate at which the affected facility vail be
operated, or 180 days after the initial
start-up, whichever date comes first.
Each owner or operator shall either:
(a) Reduce emissions of TOC (minus
methane and ethane) by 98 weight-
percent, or to a TOC (minus methane
and ethane) concentration of 20 ppmv
on a dry basis corrected to 3 percent
oxygen, whichever is less stringent. If a
boiler or process heater is used to
comply with this paragraph, then the
vent stream shall be introduced into the
flame zone of the boiler or process
heater or
(b) Combust the emissions in a flare
that meets the requirements of I 60.18;
or
(c) Maintain a TRE Index value
greater than 1.0 without use of VOC
emission control devices.
J 60.613 Monitoring o< «ml««lon« tnd
optrattona.
(a) The owner or operator of an
affected facility that uses an incinerator
to seek to comply with the TOC
emission limit specified under
J 60.612(a) shall install, calibrate,
maintain, and operate according to
manufacturer's specifications the
following equipment:
(1) A temperature monitoring device
equipped with a continuous recorder
and having an accuracy of ±1 percent
of the temperature being monitored
expressed in degrees Celsius or ±0.5 "C.
whichever is greater.
(i) Where an incinerator other than a
catalytic incinerator is used, a
temperature monitoring device shall be
installed in the firebox.
(ii) Where a catalytic incinerator is
used temperature monitoring devices
shall be installed in the gas stream
immediately before and after the
catalyst bed.
(2) A flow indicator that provides a
record of vent stream flow to the
incinerator at least once every hour for
each affected facility. The flow indicator
shall ba installed in the vent stream
from each affected facility at a point
closest to the inlet of each incinerator
and before being joined with any other
vent stream.
44
(b) The owner or operator of an
affected facility that uses • flare to seek
to comply with | 60.612(b) shall install.
calibrate, maintain, and operate
according to manufacturer's
specifications the following equipment:
(1) A heat sensing device, such as an
ultra-violet sensor or thermocouple, at
the pilot light to indicate the continuous
presence of a flame.
(2) A flow indicator that provides a
record of vent stream flow to the flare at
leest once every hour for each affected
facility. The flow indicator shall be
installed in the vent stream from each
affected facility at a point closes', to the
flare and before being joined with any
other vent stream.
(c) The owner or operator of an
affected facility that uses a boiler or
process heater to seek to comply with
{ 60.612(a) shall install, calibrate.
maintain and operate according to the
manufacturer's specifications in the
following equipment:
(1) A flow indicator that provides a
record of vent stream flow to the boiler
or process heater at least once every
hour for each affected facility. The flow
indicator shall be installed in the vent
stream from each air oxidation reactor
within an affected facility at a point
closest to the inlet of each boiler or
process heater and before being joined
with any other vent stream.
(2) A temperature monitoring device
in the firebox equipped with a
continuous recorder and having an
accuracy of ±1 percent of the
temperature being measured expressed
in degrees Celsius or ±0.5 *C.
whichever is greater, for boilers or
process heaters of less than 44 MW (150
million Btu/hr) heat input design
capacity.
(3) Monitor and record the periods of
operation of the boiler or process heater
if the design input capacity of the boiler
is 44 MW (150 million Btu/hr) or greater.
The records must b« readily available
for inspection.
(d) The owner or operator of an
affected facility that seeks to
demonstrate compliance with the TRE
index value limit specified under
I 60.812(c) shall install, calibrate.
maintain, and operate according to
manufacturer's specifications the
following equipment, unless alternative
monitoring procedures or requirements
are approved for that facility by the
Administrator: .
(1) Where an absorber is the fmat
recovery device in a recovery system:
(i) A scrubbing liquid temperature
monitoring device having an accuracy of
±1 percent of the temperature being
monitored expressed in degrees Celsius
-------
or 0.5 *C whichever it greater, and •
specific gravity monitoring device
having an accuracy of 0.02 specific
gravity units, each equipped with a
continuoua recorder
(ii) An organic monitoring device used
to indicate the concentration level of
organic compound* exiting the recovery
device bated on a detection principle
such as infra-red, photoionization. or
thermal conductivity, each equipped
with a continuoua recorder.
(2) Where a condenser ia the final
recovery device in a recovery system
(i) A condenser exit (product aide)
temperature monitoring device equipped
with a continuous recorder and having
an acuracy of ±1 percent of the
temperature being monitored expressed
in degrees Celsius or 0.3 'C. whichever
is greater
(ii) An organic monitoring device used
to indicate the concentration level of
organic compounds exiting the recovery
device based on a detection principle
such as infra-red, photoionization. or
thermal conductivity, each equipped
with a continuous recorder.
(3) Where a carbon adsorber is the
final recovery device in a recovery
system:
(i) An integrating steam flow
monitoring device having an accuracy of
10 percent and a carbon bed
temperature monitoring device having
an accuracy of ±1 percent of the
temperature being monitored expressed
in degrees Celsius or ±0.5 'C.
whichever is greater, both equipped
with a continuous recorder
(ii) An organic monitoring device used
to indicate the concentration level of
organic compounds exiting the recovery
device based on a detection principle
such as infra-red, photoionization. or
thermal conductivity, each equipped
with a continuous recorder.
(e) An owner or operator of an
affected facility seeking to demonstrate
compliance with the standards specified
under | 60.812 with control devices
other than an incinerator, boiler, process
heater, or flare: or recovery devices
other than an absorber, condenser, or
carbon adsorber shall provide to the
Administrator information describing
the operation of the control device or
recovery device and the process
parameters) which would indicate
proper operation and maintenance of
the device. The Administrator may
request further information and will
specify appropriate monitoring
procedures or requirements.
§60.»i4 Te« methods and pracwIurM.
(a) For the purpose of demonstrating
compliance with 160.612, all affected
facilities shall be run at full operating
conditions and flow rates during any
performance test
(b) The following methods in
appendix A to this part except aa
provided under i 60.8(b) shall be used
as reference methods to determine
compliance with the emission limit or
percent reduction efficiency specified
under | fl0.612(a).
(1) Method 1 or 1A. as appropriate, for
selection of the sampling sites. The
control device inlet sampling site for
determination of vent stream molar
composition or TOG (less methane and
ethane) reduction efficiency shall be
prior to the inlet of the control device
and after the recovery system.
(2) Method 2.2A. 2C, or 2D. as
appropriate, for determination of the
volumetric flow rates.
(3) The emission rate correction
factor, integrated sampling and analysis
procedure of Method 3 shall be used to
determine the oxygen concentration
(%O»d) for the purposes of determining
compliance with the 20 ppmv limit The
sampling site shall be the same as that
of the TOG samples and the samples
shall be taken during the same time that
the TOC samples are taken.
The TOC concentration corrected to 3
percent 0» (CJ shall be computed using
the following equation:
174J
C.-CTOC
where:
C,» Concentration of TOC corrected to 3
percent Oi, dry basis, ppm by volume.
Croc—Concentration of TOC (minus methana
and ethane), dry basis, ppm by volume.
*O««««Concentration of Oi. dry basis.
percent by volume.
(4) Method 18 to determine
concentration of TOC in the control
device outlet and the concentration of
TOC in the inlet when the reduction
efficiency of the control device is to be
determined.
(i) The sampling time for each run
shall be 1 hour in which either an
integrated sample or four grab samples
shall be taken. If grab sampling is used
then the samples shall be taken at 15-
minute intervals.
(ii) The emission reduction (R) of TOC
(minus methane and ethane) shall be
determined using the following equation:
E.-MSSS rate of TOC entering the control
device, kg TOC/hr.
E.«Maas rate of TOC discharged to the
atmosphere. k|TOC/hr.
(iii) The mass rates of TOC (E* E.)
shall be computed using the following
equations:
;-Kt|
n
Z
i-i
n
•M I C«MjQ.
i-i
Where:
C«. (^-Concentration of sample component
"1" of the gas stream at the inlet and
outlet of the control device, respectively.
dry basts ppm by volume.
MM. M.,-Molecular weight of sample
component T of the gas stream at the
inlet and outlet of the control device.
respectively, g/g-mole (Ib/Ib-mole).
Qi. Q.-Flow rate of gas stream at the inlet
and outlet of the control device.
respectively, dscm/min (dscf/hr).
K,-Constant 2.494 x l
-------
26925
F*k»l Rotator / VoL 55. No. 128 / Friday, lune 29. 1990 / Rule* and Regulation!
for determining the net heating value of
the gas combusted to determine
compliance under i flO812(b) and for
determining the process vent stream
TRE index value to determine
compliance under 160.612(c).
(l)(i) Method 1 or 1A. as appropriate.
for selection of the sampling site. The
sampling site for the vent stream flow
rate and molar composition
determination prescribed in i 60.614(d)
(2) and (3) shall be. except for the
situations outlined in paragraph (d)(lp)
of this section, pnor to the inlet of any
control device, prior to any post-reactor
dilution of the stream with air. and prior
to any post-reactor introduction of
halogenated compounds into the vent
stream. No transverse site selection
method is needed for vents smaller than
4 inches in diameter.
(ii) If any gas stream other than the air
oxidation vent stream from the affected
facility is normally conducted through
the final recovery device.
(A) The sampling site for vent stream
flow rate and molar composition shall
be prior to the final recovery device and
prior to the point at which the nonair
oxidation stream is Introduced.
(B) The efficiency of the final recovery
device is determined by measuring the
TOG concentration using Method 18 at
the inlet to the final recovery device
after the introduction of any nonair
oxidation vent stream and at the outlet
of the final recovery device.
(C) This efficiency is applied to the
TOG concentration measured prior to
the final recovery device and prior to
the introduction of the nonair oxidation
stream to determine the concentration of
TOG in the air oxidation stream from
the final recovery device. This
concentration of TOG is then used to
perform the calculations outlined in
J 60.614{d) (4) and (5).
(2) The molar composition of the
process vent stream shall be determined
as follows:
(i) Method 18 to measure the
concentration of TOG including those
containing halogens.
(ii) ASTM D1946-77 (Incorporation by
reference as specified in | 60.17 of this
part) to measure the concentration of
carbon monoxide and hydrogen.
(iii) Method 4 to measure the content
of water vapor.
(3) The volumetric flow rate shall be
determined using Method 2.2A. 2C. or
2D. aa appropriate.
(4) The net heating value of the vent
stream shall be calculated using the
following equation:
n
HT-K/ i OH,)
where:
HT-Net heating value of the sample. MJ/
son, where the net enthalpy per mole of
offgM Is based on combustion st 23 C
and 780 mm Hg, but the standard
temperature for determining the volume
corresponding to one mole is 20 'C, as in
the definition of Q. (offgas flow rate).
K,-Constant 1.740 X 10"
(1) (g mole) (MI).
ppm
kcal
whew standard temperature for
is 20 'C.
C,-Concentration of compound i in ppm. as
measured for organic* by Method 18 and
measured for hydrogen and carbon
monoxide by ASTM D1946-77
(incorporated by reference •» specified
in | 80.17 of this part) as indicated in
| 80.814(d](2).
H,-Net heat of combustion j. kcal/g-mol*.
based on combustion st 23 *C and 780
nun Hg. The heat* of combustion of vent
stream components would be required to
be determined using ASTM D2382-7B
(incorporation by reference is specified
in I 80.17 of this part) if published values
•re not available or cannot be
calculated.
TRE -
Eroc
(a) (
(5) The emission rate of TOG in the
process vent stream shall be calculated
using the following equation:
-K,
X QHQ.
where:
ETOC-Emission rate of TOC ta me *emPle-
kg/hr
K.-Constant 2.484 x l
-------
28928
(i) where for a vent stream flow rate
(scnj/min) at a standard temperature of
20 C that is greater than or equal to 14 2
scm/min:
TRE=TRE indsx value.
Q, = Vent strsam flow rate (scir,/m!->; at a
standard temperature of 20 'C.
H
•
-Vent stream net heating value (MI/««n)
where the net enthalpy of combustion
per mole of vent stream is based on
combustion *t 23 «C and 760 mm Hg. but
the standard temperature for determining
the volume corresponding to one mole i,8
20 C as in the definition of Qr
•Q. for all vent stream categories listed in
Table 1 except for Category B vent
streams where Y.-(QJ(HTJ/3.8.
emi3l'-anM 0{TOC "Parted in
a. b. c. d. «. and f are coefficients.
The set of coefficients which apply t
frora
WUJNO COM
47
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Federal Register / Vol. 55. No. 126 / Friday. June 29.1990 / Rules and Regulations
28827
TABLE 1. AIR OXIDATION NSPS TRE COEFFICIENTS FOR VENT STREAKS CONTROLLED BY AN INCINERATOR
DESIGN CATEGORY Al. FOR HALOGENATED PROCESS VENT STREAMS, IF 0 « NET HEATING VALUE (MJ/SCTi) « 3.5:
Q. • Vent Stream Flow rate
9 (gCT/min)
14.2 0. 18.8
18.8 Of 699
699 O; " MOO
1400 0, " 2100
2100 0« " 2800
2800 Q, < 3500
a
19.18370
20.00563
39 87022
59.73481
79 59941
99.46400
b
0.27580
0.27580
0.29973
0.31467
0.32572
0.33456
c
0.75762
0.30387
0.30387
0.30387
0.30387
0.30387
d
-0.13064
-0.13064
-0.13064
-0.13064
-0.13064
-0.13064
•
0
0
0
0
0
0
f
0.0102S
0.01025
0.01449
0.01775
0.02049
0.02291
DESIGN CATEGORY A2. FOR HALOGENATED PROCESS VENT STREAMS. IF NET HEATING VALUE > 3.5 MJ/scm:
Q« » Vent Stream Flow rate
* (scm/iiHn)
14.2 < 0. 18.8
18.8 < Q! I 699
699 « 0, 1400
1400 < 0, 2100
2800 < Q, 3500
a
18.84466
19.66658
39.19213
58.71768
78.24323
97.76879
b
0.26742
0.26742
0.29062
0.30511
0.31582
0.32439
C
-0.20044
-0.25332
-0.25332
-0.25332
-0.25332
-0.25332
d
oooooo
e
oooooo
f
0.01025
0 01025
0.01449
0.01775
0.02049
0.02291
DESIGN CATEGORY B. FOR NONHALOGENATED PROCESS VENT STREAMS. IF 0 £ NET HEATING VALUE (MJ/son) < 0.48
Q. • Vent Stream Flow rate
14.2 < Qs < 1340
1340 < 0. < 2690
2690 « Q, < 4040
a
8.54245
16.94386
25.34528
b
0.10555
0.11470
0.12042
c
0.09030
0.09030
0.09030
d
-0.17109
-0.17109
-0.17109
e
0
0
0
f
0.01025
0.01449
0.01775
DESIGN CATEGORY C. FOR NONHALOGENATEO PROCESS VENT STREAMS. IF 0.48 < NET HEATING VALUE (MJ/scm) « 1.9
Q. • Vent Stream Flow rate
14.2 < 0, < 1340
1340 < Q! < 2690
2690 < qj < 4040
a
9.25233
18.36363
27.47492
b
0.06105
0.06635
0.06965
c
0.31937
0.31937
0.31937
d
-0.16181
-0.16181
-0.16181
e
0
0
0
f
0.01025
0.01449
0.01775
DESIGN CATEGORY 0. FOR NONHALOGENATED PROCESS VENT STREAMS, IF 1.9 < NET HEATING VALUE (MJ/sc») < 3.6:
Q. • Vent Stream Flow rate
14.2 « Q. < 1180
1180 < Oj < 2370
2370 < Q, < 3550
a
6.67868
13.21633
19.75398
b
0.06943
0.07546
0.07922
c
0.02582
0.02582
0.02582
d
0
0
0
e
0
0
0
f
0.0102S
0.01449
0.01775
DESIGN CATEGORY E. FOR NONHALOGENATED PROCESS VENT STREAMS. IF NET HEATING VALUE > 3.6 MJ/jcm:
Y. • Dilution Flow rate
(sdWmln) -0.1 (HT)/3.6
14.2 < Y, < 1180
1180 < Y, < 2370
2370 < YJ < 3550
a
6.67868
13.21633
19.75398
b
0
0
0
c
000
d
-0.00707
-0.00707
-0.00707
t
0.02220
0.02412
0.02533
f
0.0102S
0.01449
0.0177S
48
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26928
JF«d«ral Register / Vol. 55. No. 126 / Friday, June 29. 1990 / Rale, and Relations
(ii) Where for a vent stream flow rate
(scm/min) at a standard temperature of
20 *C that ia less than 14.2 scm/min:
TRE-TRE index value.
Q.= l4.2»cm/min.
HT-{FLOW)(HVAL)/14.2.
Where the following inputs are used:
FlOW.Vent stream flow rate Iscm/min). at
a standard temperature of 20 'C.
HVALm Vent stream net heating value (MI/
ton), when the net enthalpy per mole of
vent atream i* baaed on combuation at 25
*C and TOO mm Hg. but the standard
temperature for determining the volume
corresponding to 1 mole ia 20 "C aa in the
definition of Q,.
Y.-14.2 icm/min for all vent stream
categories listed in Table 1 except for
Category E vent streams, where
Y, = |14.2)(HT)/3.8.
Hourly emissions of TOC rep. rted in
kg/hr.
a. b. c, d. a. snd f are coefficients.
The set of coefficients that apply to a
vent stream can be obtained from Table
1.
(2) The equation for calculating the
TRE index value of a vent stream
controlled by a flare is as follows:
TRE -
where:
TRE=TRE index value.
ETOC=Hourly emission rate of TOC reported
in kg/hr.
Q. = Ver.t stream flow rate (son/min) si a
standard temperature of 20 *C.
offgas is based on combustion at 25 'C
and 780 mm Hg. but tlie standard
temperature for determining the volume
corresponding to 1 mole is 20 *C as m tie
definition of Q,
a, b. c. d. and e are coefficients,
to a
laoiez.
TABLE 2.-A.-R OX.GATIC-, PROCESSES NSPS TRE COEFRCIENTS FOR VENT STREAMS CONTROLLED BY A FLARE
HT <11.2MJ/»cm
H» ..11 2 MJ/scm " ~
a
0.3C9
b
0.288
0619
c
-0.193
-0.0043
d
-00051
-0.0034
2.08
203
(f) Each owner or operator of an
affected facility seeking to comply with
i 60.810(c) or } 60.612(c) shall
recalculate the TRE index value for that
affected facility whenever process
changes are made. Some examples of
process changes are changes in
production capacity, feedstock type, or
catalyst type, or whenever there is
replacement removal, or addition of
recovery equipment. The TRE index
value shall be recalculated based on test
data, or on best engineering estimates of
the effects of the change to the recovery
system.
(1) Where the recalculated TRE index
value is less than or equal to 1.0. the
owner or operator shall notify the
Administrator within 1 week of the
recalculation and shall conduct •
performance test according to the
methods and procedures required by
{ 60.614 to determine compliance with
i 80.612(a). Performance tests must be
conducted as soon aa possible after the
process change but no later than ISO
days from the time of the process
change.
(2) Where the initial TRE index value
is greater than 4.0 and the recalculated
TRE index value ia less than or equal to
4.0, but greater than IA the owner or
operator shall conduct a performance
test in accordance with $ 60.8 and
§ 60.614 and shall comply with i 60.613,
S 60.614. and { 60.615. Performance tests
must be conducted as soon as possible
after the process change but no later
than 180 days from the time of the
process change.
} 60.615 Reporting and rtcordkeeplng
(a) Each owner or operator subject to
1 60.612 shall notify the Administrator of
the specific provisions of | 60.612
(S 60.612 (a) (b). or (c)) with which the
owner or operator has elected to
comply. Notification shall be submitted
with the notification of initial start-up
required by S eo.7(a)(3]-. If an owner or
operator elects at a later elate to use an
alternative provision of § 60.612 with
which he or she will comply, then the
Administ-ator shall be notified by the
owner or operator go days before
implementing a change and, upon
implementing the change, a performance
test shall be performed as specified by
I 60.614 within 180 days.
(b) Each owner or operator subject to
the provisions of this subpart shall keep
up-to-date, readily accessible records of
the following data measured during each
performance test and also include the
following data in the report of the initial
performance test required under { 60.8.
Where a boiler or process heater with a
design heat input capacity of 44 MW
(ISO million Btu/hour) or greater is used
to comply with S 60.612(a), a report
containing performance test data need
not be submitted, but a report containing
the information of { 60.615(b)(2)(i) ia
required. The same data specified in this
section shall be submitted in the reports .
of all subsequently required
performance tests where either the
emission control efficiency of a control
device, outlet concentration of TOC or
the TRE index value of a vent stream
from a recovery system ia determined.
(1) Where an owner or operator
subject to this subpart seeks to
demonstrate compliance with { 60.612(2)
through use of either a thermal or
catalytic incinerator
(i) The average firebox temperature of
the incinerator (or the average
temperature upstream and downstream
of the catalyst bed for a catalytic
incinerator), measured at least every is
minutes and averaged over the same
time period of the performance testing,
and
(ii) The percent reduction of TOC
determined aa specified in | 60.614(b)
achieved by the incinerator, or the
concentration of TOC (ppmv, by
49
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Federal Renter / Vol. 55. No. 126 / Friday. June 29. 1990 / Rules and Regulations
compound) determined as specified in
; 60.614(b) at the outlet of the control
device on a dry basis corrected to 3
percent oxygen.
(2) Where an owner or operator
subject to the provision* of this subpart
seeks to demonstrate compliance with
{ 60.612(a) through use of a boiler or
process heater
(i) A description of the location at
which the vent stream is introduced into
the boiler or process heater, and
(ii) The average combustion
temperature of the boiler or process
heater with a design heat input capacity
of less than 44 MW (150 million Btu/hr)
measured at least every IS minutes and
averaged over the same time period of
the performance testing.
(3) Where an owner or operator
subject to the provisions of this subpart
seeks to comply with i 60.612(b) through
the use of a smokeless flare, flare design
(i.e.. steam-assisted, air-assisted, or
nonassisted). all visible emission
readings, heat content determinations.
flow rate measurements, and exit
velocity determinations made during the
performance test, continuous records of
the flare pilot flame monitoring, and
recards of all periods of operations
during which the pilot flame is absent.
(4) Where an owner or operator seeks
to demonstrate compliance with
J60.812(c):
(i] Where an absorber is the final
recovery device in a recovery system.
the exit specific gravity (or alternative
parameter which is a measure of the
degree of absorbing liquid saturation, if
approved by the Administrator), and
average exit temperature of the
absorbing liquid, measured at least
every 15 minutes and averaged over the
same time period of the performance
testing (both measured while the vent
stream is normally routed and
constituted), or
(ii) Where a condenser is the final
recovery device in a recovery system,
the average exit (product side)
temperature, measured at least every 15
minutes and average over the same time
period of the performance testing while
the vent stream is normally routed and
constituted.
(iii) Where a carbon adsorber is the
final recovery device in a recovery
system, the total steam mass flow
measured at least every 15 minutes and
averaged over the same time period of
the performance test (full carbon bed
cycle), temperature of the carbon bed
after regeneration (and within 15
minutes of completion of any cooling
cycle(s). and duration of the carbon bed
steaming cycle (all measured while the
vent stream is normally routed and
constituted), or
(iv) As an alternative to
J60.815(b)(4)(i).(ii)or(iii).the
concentration level or reading indicated
by the organic monitoring device at the
outlet of the absorber, condenser, or
carbon adsorber measured at least
every 15 minutes and averaged over the
same time period of the performance
testing while the vent stream is normally
routed and constituted.
(v) All measurements and calculations
performed to determine the TRE index
value of the vent stream.
(c) Each owner or operator subject to
the provisions of this subpart shall keep
up-to-date, readily accessible
continuous records of the equipment
operating parameters specified to be
monitored under | 60.813(a) and (c) as
well as up-to-date, readily accessible
records of periods of operation during
which the parameter boundaries
established during the most recent
performance test are exceeded. The
Administrator may at any time require a
report of these data. Where a
combustion device is used by an owner
or operator seeking to demonstrate
compliance with i 80.612(a) or (c).
periods of operation during which the
parameter boundaries established
during the most recent performance
tests are exceeded are denned as
follows:
(1) For thermal incinerators, all 3-hour
periods of operation during which the
average combustion temperature was
more than 28*C (50'F) below the average
combustion temperature during the most
recent performance test at which
compliance with i 60.812(a) was
determined.
(2) For catalytic incinerators, ail 3-
hour periods of operation during which
the average temperature of the vent
stream immediately before the catalyst
bed is more than 28 *C (50 'F) below the
average temperature of the vent stream
during the most recent performance test
at which compliance with i 60.612(a)
was determined. The owner or operator
also shall record all 3-hour periods of
operation during which the average
temperature difference across the
catalyst bed is less than 80 percent of
the average temperature difference of
the device during the most recent
performance test at which compliance
with | 60.812(a) was determined.
(3) All 3-hour periods of operation
during which the average combustion
temperature was more than 28 *C (50 *F)
below the average combustion
temperature during the most recent
performance test at which compliance
with 160.812(a) was determined for
boilers or process heaters with a design
heat input capacity of less than 44 MW
(150 million Btu/hr).
50
(4) For boilers or process heaters.
whenever there is a change in the
location at which the vent stream is
introduced into the flame zone as
required under f 60.612(a).
(d) Each owner or operator subject to
the provisions of this subpart shall keep
up-to-date, readily accessible
continuous records of the flow
indication specified under 5 60.613(a)(2).
} 60.813(b)(2), and S 60.813(c)(l). as well
as up-to-date, readily accessible records
of all periods when the vent stream is
diverted from the control device or has
no flow rate.
(e) Each owner or operator subject to
the provisions of this subpart who uses
a boiler or process heater with a design
heat input capacity of 44 MW or greater
to comply with J 60.612(a) shall keep an
up-to-date, readily accessible record of
all periods of operation of the boiler or
process heater. (Examples of such
records could include records of steam
use. fuel use. or monitoring data
collected pursuant to other State or
Federal regulatory requirements).
(f) Each owner or operator subject to
the provisions of this subpart shall keep
up-to-date, readily accessible
continuous records of the flare pilot
flame monitoring specified in
§ 60.813(b). as well as up-to-date,
readily accessible records of all periods
of operations in which the pilot flame is
absent.
(g) Each owner or operator subject to
the provisions of this subpart shall keep
up-to-date, readily accessible
continuous records of the equipment
operating parameters specified to be
monitored under i 60.613(c) as well as
up-to-date, readily accessible records of
periods of operation during which the
parameter boundaries established
during the most recent performance test
are exceeded. The Administrator may at
any time require a report of these data.
Where the owner or operator seeks to
demonstrate compliance with
J 60.812(c). periods of operation during
which the parameter boundaries
established during the most recent
performance tests are exceeded are
defined as follows:
(1) Where an absorber is the final
recovery device in a recovery system.
and where an organic monitoring device
is not used:
(i) All 3-hour periods of operation
during which the average absorbing
liquid temperature was more than 11 "C
(20 *F) above the average absorbing
liquid temperature during the most
recent performance test or
(ii) All 3-hour periods of operation
during which the average absorbing
liquid specific gravity was more than 0.1
J
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Federal Register / Vol. 55, No. 128 / Friday. June 29. 1990 / Rules and Regulations
unit above, or more than 0.1 unit below,
the average absorbing liquid specific
gravity during the most recent
performance test (unless monitoring of
sn alternative parameter, which is a
measure of the degree of absorbing
liquid saturation, is approved by the
Administrator, in which case he or she
will define appropriate parameter
boundaries and periods of operation
during which they are exceeded).
(2) When a condenser is the final
recovery device in a recovery system,
and where an organic nor.itonr.g device
is not used, all 3-hour periods of
operation during which the average exit
(product side) condenser operating
temperature was more than 8 'C (11 'FJ
above the average exit (product side)
operating temperature during the most
recent performance test.
(3) Where a carbon adsorber is the
final recovery device in a recovery
system and where an organic monitoring
device is not used:
(i) All carbon bed regeneration cycles
during which the total mass steam flow
was more than 10 percent below the
total mass steam flow during the most
recent performance test or
(ii) All carbon bed regeneration cycles
danng which the temperature of the
carbon bed after regeneration (and after
completion of any cooling cycle(s)) was
r.ore than 10 percent greater than die
-arbon bed temperature (in degrees
Celsius) during the most recent
performance test.
(4) Where an absorber, condenser, or
carbon adsorber is the final recovery
device in the recovery system and an
organic monitoring device approved by
the Administrator is used all 3-hour
periods of operation during which the
average concentration level or reading
of organic compounds in the exhaust
gases is more than 20 percent greater
than the exhaust gas organic compound
concentration level or reading measured
by the monitoring device during the
most recent performance test.
(h) Each owneror operator subject to
the provisions of this subpart and
seeding to demonstrate compliance with
i 60.6l2(c) shall keep up-to-date, readily
accessible records of:
(1) Any changes in production
capacity, feedstock type, or catalyst
type, or of any replacement, removal or
addition of recovery equipment or air
oxidation reactors;
(2) Any recalculation of the TRE index
value performed pursuant to { 60.814(f);
(3) The results of any performance test
performed pursuant to the methods and
procedures required by ( 60.614(d).
(i) Each owner and operator subject to
the provision* of this subpart is exempt
from the quarterly reporting
requirements contained in j 60.7(c) of
the Genera] Provisions.
0) Each owner or operator that seeks
to comply with the requirements of this
subpart by complying with the
requirements of J 60.812 shall submit to
the Administrator semiannual reports of
the following information. The initidl
report shall be submitted within 6
months after the initial start-up-date.
(1) Exceedances of monitored
parameters recorded under i 60.615(c)
and (g).
(2) All periods recorded under
J 60.615(d) when the vent stream is
diverted from the control device or has
no flow rate.
(3) Ail periods recorded under
8 60.615(e) when the boiler or process
heater was not operating.
(4) All periods recorded under
! 60.615(f) in which the pilot flame of the
flare was absent.
(3) Any recalculation of the TRE index
value, as recorded under { 60.315(h).
Ik) The requirements of $ 00.615(1)
remain in force until and unless EPA. in
delegating enforcement authority to a
State under section lll(c) of the Act
approves reporting requirements or an
alternative means of compliance
surveillance adopted by such State. In
that event affected sources within the
State will be relieved of the obligation to
comply with { 60.815(j). provided Uiat
they comply with the requirements
established by the State.
(1) The Administrator will specify
appropriate reporting and recordkeeping
requirement* where the owner or
operator of an affected facility seeks to
demonstrate compliance with the
standards specified under § 60.812 other
than as provided under { 60.613 (a), fb),
(c). and (d).
580.916 Reconstruction.
For purposes of this subpart "fixed
capital cost of the new components," as
used in § 60.15, includes the fixed
capital cost of all depreciable
components which are or will be
replaced pursuant to ail continuous
programs of component replacement
which are commenced within any 2-year
period following October 21,1983. For
purposes of this paragraph,
"commenced" means that an owner or
operator has undertaken a continuous
program of component replacement or
that an owner or operator has entered
into a contractual obligation to
undertake and complete, within a
reasonable time, a continuous program
of component replacement
(Approved by OMB under the control number
2060-0053)
§ 60.617 Chemicals affected by •ubpart HI.
Cn*mmlname
I CAS No. •
A-.8ta-dertyoe.._
Aceae acj _ _.
Acetone
Acetoortrile
Acalocftenone _
Acrotem „
Acrylic acx»
Ac-fionitrte .
AnBiraqunore
Ssraaidanyde
Bonzoic acid, tech
1.3-Butadiene
p-l-flutyt benzoc aod
N-8utytic «aa
Cfotoncacid
Cumene nydroreroxiae_
C(ianol . ..
Cyclohexanone
!t»repftt!afate..
Ethytena denjonde
Etnyte«» owe
75-07-0
64-16-7
67-64-1
:5-05-8
S8-86-2
'07-02-8
79-10-7
107-13-1
84-«S-1
IOC-S2-7
65-65-0
109-9J-0
98-73-7
107-92-8
3724-65-0
90-15-9
108-P3-O
108-94-1
H,drogen cymrvda...
Isobuiync sod
isoprtnaic acid
ksaleic aonyanda—
M«tny4 smyl ketone
s-Metnyt styrene'
Pneno)
PWhafe annyande .
_J
Procyt«na ox«Je..
Styrena
107-O8-?
75-21-8
50-00-0
64-ia-«
T37-22-2
74-90-8
79-31-2
121-91-i
108-31-6
78-93-3
98-83-9
1C8-9S-2
85-44-9
79-09-4
75-56-9
10O-42-S
100-21-0
°CAS numbers refer to tn» Chemical Abstracts
Registry numbers assigned to (pea*: cnwncaM.
rsomers or matures o4 chemcaH. Some Homers or
rnnrtures mat ar» covered by m* standards do not
ftav* CAS numoars assorted to trwm. The standards
aopiy to an or ff» cnemcaJa Uad. vnoowr CAS
numoers nav* bean turned or not.
§ 60.SU D4ri«
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Federal Register / Vol. 55, No. 128 / Friday, June 29. 1990 / Rules and Regulations
no plant* either large or small would
suffer significant economic impact under
this NSPS.
It is difficult to estimate the specific
effects of the NSPS on new businesses
entering the industry. In general.
however, if a company has the capital
available to enter the industry, the NSPS
will require only a small percentage
increase in the capital needed for the
project.
Pursuant to the provisions of 5
U.S.C.A. eOS(b), 1 hereby certify that this
rule will not have a significant economic
impact on a substantial number of small
entities.
List of Subjects in 40 CFR Part 60
Air pollution control. Incorporation by
reference. SOCMI distillation unit
operations. Reporting and recordkeeping
requirements. Intergovernmental
relations.
Dated: June 13.1990.
William K. Reilly.
Administrator.
PART 60—(AMENDED]
40 CFR part 60 is amended as follows:
1. The authority citation for part 60
continues to read as follows:
Authority: Sees. 101. 111. 114.118, and 301
of the Clean Air Act (CAA) as amended (42
U.S.C 7401. 7411. 7414. 7416. 7801).
§60.17 [Amended]
2. Section 60.17 is amended in
paragraph (a)(6) by removing the period
at the end of the paragraph and adding
the phrase "60.664(d)(2)(ii) and
60.664(d)(4)" and in paragraph (a)(38) by
removing the period at the end of the
paragraph and adding the phrase "and
60.664(d)(4)".
3. By adding subpart NN'N as follows:
Subpart NNH—Standard* of Performance
for Volatile Organic Compound Emissions
From Synthetic Organic Chemical
Manufacturing Industry Distillation
Operations
Sec.
60.660 Applicability and designation of
affected facility.
60.661 Definitions.
60.662 Standards.
60.663 Monitoring of emissions and
operations,
60.664 Test methods and procedures.
60.665 Reporting and recordkeeping
requirements.
60.666 Reconstruction.
60.667 Chemicals affected by Subpart NNN.
60.668 Delegation of Authority.
Subpart NNN—Standards of
Performance for Volatile Organic
Compound (VOC) Emissions From
Synthetic Organic Chemical
Manufacturing Industry (SOCMI)
Distillation Operations
{60.660 Applicability and designation of
affected facility.
(a) The provisions of this subpart
apply to each affected facility
designated in paragraph (b) of this
section that is part of a process unit that
produces any of the chemicals listed in
5 60.667 as a product op-product by-
product or intermediate, except as
provided in paragraph (c).
(b) The affected facility is any of the
following for which construction.
modification, or reconstruction
commenced after December 30.1983:
(1) Each distillation unit not
discharging its vent stream into a
recovery system.
(2) Each combination of a distillation
unit and the recovery system into which
its vent stream is discharged.
(3) Each combination of two or more
distillation units and the common
recovery system into which their vent
streams are discharged.
(c) Exemptions from the provisions of
paragraph (a) of this section are as
follows:
(1) Any distillation unit operating as
part of a process unit which produces
coal tar or beverage alcohols, or which
uses, contains, and produces no VOC is
not an affected facility.
(2) Any distillation unit that is subject
to the provisions of Subpart ODD is not
an affected facility.
(3) Any distillation unit that is
designed and operated as a batch
operation is not an affected facility.
(4) Each affected facility that has a
total resource effectiveness (TRE) index
value greater than 8.0 is exempt from all
provisions of this subpart except for
$ i 60.662:80.664 (d). (e), and (f): and
60.665 (h) and (1).
(5) Each affected facility in a process
unit with a total design capacity for all
chemicals produced within that unit of
less than one gigagram per year is
exempt from all provisions of this
subpart except for the recordkeeping
and reporting requirements in
paragraphs (j). (1)(6), and (n) of { 60.665.
(6) Each affected facility operated
with a vent stream flow rate less than
0.008 scm/min is exempt from all
provisions of this subpart except for the
test method and procedure and the
recordkeeping and reporting
requirements in § 60.664(g) and
paragraphs (i). (1)(5). and (o) of 560.665
[Note: The intent of these standards is to
minimize the emissions of VOC through the
application of best demonstrated technology
(BDT). The numerical emission limiti in these
standards are expressed in terms of total
organic compounds (TOO. measured at TOC
less methane and ethane. This emiasion limit
reflects the performance of BDT.)
} 60.661 Definitions.
As used in this subpart. all terms not
defined here shall have the meaning
given them in the Act and in subpart A
of part 60, and the following terms shall
have the specific meanings given them.
Batch distillation operation means a
noncontinuous distillation operation in
which a discrete quantity or batch of
liquid feed is charged into a distillation
unit and distilled at one time. After the
initial charging of the liquid feed, no
additional liquid is added during the
distillation operation.
Boiler means any enclosed
combustion device that extracts useful
energy in the form of steam.
By compound means by individual
stream components, not carbon
equivalents.
Continuous recorder means a data
recording device recording an
instantaneous data value at least once
every 15 minutes.
Distillation operation means an
operation separating one or more feed
stream(s) into two or more exit
stream(s). each exit stream having
component concentrations different
from those in the feed stream(s). The
separation is achieved by the
redistribution of the components
between the liquid and vapor-phase as
they approach equilibrium within the
distillation unit.
Distillation unit means a device or
vessel in which distillation operations
occur, including all associated internals
(such as trays or packing) and
accessories (such as reboiler. condenser.
vacuum pump, steam jet. etc.). plus any
associated recovery system.
Flame zone means the portion of the
combustion chamber in a boiler
occupied by the flame envelope.
Flow indicator means a device which
indicates whether gas flow is present in
a vent stream.
Hclogenated vent stream means any
vent stream determined to have a total
concentration (by volume) of
compounds containing halogens of 20
ppmv (by compound) or greater.
Incinerator means any enclosed
combustion device that is used for
destroying organic compounds and does
not extract energy in the form of steam
or process heat
Process heater means a device that
transfers heat liberated by burning fuel
to fluids contained in tubes, including all
52
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Federal Register / Vol. 55, No. 128 / Friday. June 29. 1990 / Rules and Regulations
26943
fluids except water that is heated to
produce steam.
Process unit means equipment
assembled and connected by pipes or
ducts to produce, as intermediates or
final products, one or more of the
chemicals in S 60.667. A process unit can
operate independently if supplied with
sufficient fuel or raw materials and
sufficient product storage facilities.
Product means any compound or
chemical listed in § 60.667 that is
produced for sale as • final product as
that chemical, or for use in the
production of other chemicals or
compounds. By-products, co-products.
and intermediates are considered to be
products.
Recovery device means an individual
unit of equipment, such as an absorber,
carbon adsorber, or condenser, capable
cf and used for the purpose of
recovering chemicals for use. reuse, or
sale.
Recovery system means an individual
recovery device or series of such
devices applied to the same vent stream.
Total organic compounds (TOC)
means those compounds measured
according to the procedures in
5 60.664(b)(4). For the purposes of
measuring molar composition as
required in S 60.664(dj(2){i): hourly
emissions rate as required in
§ 60.664(d)(5) and { 60.664(e); andTOC
concentration as required in
5 60.665(b)(4) and { 60.665(g)(4], those
compounds which the Administrator has
determined do not contribute
appreciably to the formation of ozone
are to be excluded. The compounds to
be excluded are identified in
Environmental Protection Agency's
statements on ozone abatement policy
for State Implementation Plans (SIP)
revisions (42 FR 35314; 44 FR 32042; 45
FR 32424: 45 FR 48942).
TRE index value means a measure of
the supplemental total resource
requirement per unit reduction of TOC
associated with an individual
distillation vent stream, based on vent
stream flow rate, emission rate of TOC
net heating value, and corrosion
properties (whether or not the vent
stream is halogenated), as quantified by
the equation given under { 80.664(e).
Vent stream means any gas stream
discharged directly from a distillation
facility to the atmosphere or indirectly
to the atmosphere after diversion
through other process equipment. The
vent stream excludes relief valve
discharges and equipment leaks
including, but not limited to. pumps,
compressors, and valves.
} 60.862 Standards.
Each owner or operator of any
affected facility shall comply with
paragraph (a), (b). or (c) of this section
for each vent stream on and after the
date on which the initial performance
test required by { 60.3 and i 60.664 is
completed, but not later than 60 days
after achieving the maximum production
rate at which the affected facility will be
operated, or 180 days after the initial
start-up, whichever date comes first
Each owner or operator shall either:
(a) Reduce emissions of TOC (less
methane and ethane) by 98 weight-
percent or to a TOC (less methane and
ethane) concentration of 20 ppmv, on a
dry basis corrected to 3 percent oxygen.
whichever is less stringent If a boiler or
process heater is used to comply with
this paragraph, then the vent stream
shall be introduced into the flame zone
of the boiler or process heater, or
(b) Combust the emissions in a flare
that meets the requirements of { 60.18:
or
(c) Maintain a TRE index value
greater than 1.0 without use of VOC
emission control devices.
§ 60.663 Monitoring of emlutohst and
operations.
(a) The owner or operator of an
affected facility that uses an incinerator
to seek to comply with the TOC
emission limit specified under
i 60.662(a) shall install, calibrate.
maintain, and operate according to
manufacturer's specifications the
following equipment:
(1) A temperature monitoring device
equipped with a continuous recorder
and having an accuracy of ±1 percent
of the temperature being monitored
expressed in degrees Celsius or ±0.5 'C.
whichever is greater.
(i) Where an incinerator other than a
catalytic incinerator is used, a
temperature monitoring device shall be
installed in the firebox.
(ii) Where a catalytic incinerator is
used, temperature monitoring devices
. shall be installed in the gas stream
immediately before and after the
catalyst bed.
(2) A flow indicator that provides a
record of vent stream flow to the
incinerator at least once every hour for
each affected facility. The flow indicator
shall be installed in the vent stream
trom each affected facility at a point
closest to the inlet of each incinerator
and before being joined with any other
vent stream.
(b) The owner or operator of an
affected facility that uses a flare to seek
to comply with i 60.662(b) shall install
calibrate, maintain and operate
according to manufacturer's
specifications the following equipment.
(1) A heat sensing device, such as a
ultra-violet beam sensor or
thermocouple, at the pilot light to
indicate the continuous presence of a
flame.
(2) A flow indicator that provides a
record of vent stream flow to the Oare at
least once every hour fur each affected
facility. The flow indicator shall be
installed in the vent stream from e^h
affected facility at a point closest to ihe
flare and before being joined with any
other vent stream.
(c) The owner or operator of an
affected facility that uses a boiler or
process heater to seek to comply with
S 60.662(a) shall install, calibrate.
maintain and operate according to th»
manufacturer's specifications in the
following equipment:
(1) A flow indicator that provides a
record of vent stream flow to the boiler
or process heater at least once every
hour for each affected facility. The flow
indicator shall be installed in the vent
stream from each distillation unit within
an affected facility at a point closest to
the inlet of each boiler or process heater
and before being joined with any other
vent stream.
(2) A temperature monitoring device
in the firebox equipped with a
continuous recorder and having an
accuracy of ±1 percent of the
temperature being measured expressed
in degrees Celsius or ±0.5 *C
whichever is greater, for boilers or
process heaters of less than 44 MW (ISO
million Btu/hr) heat input design
capacity.
(3) Monitor and record the periods of
operation of the boiler or process heater
if the design heat input capacity of the
boiler or process heater is 44 MW (150
million Btu/hr) or greater. The records
must be readily available for inspection.
(d) The owner or operator of an
affected facility that seeks to comply
with the TRE index value limit specified
under i 60.662(c) shall install, calibrate.
maintain, and operate according to
manufacturer's specifications the
following equipment, unless alternative
monitoring procedures or requirements
are approved for that facility by the
Administrator:
(1) Where ar. absorber is the f.nul
recovery device in the recovery system:
(i) A scrubbing liquid temperature
monitoring device having an accuracy of
±1 percent of the temperature being
monitored expressed in degrees Celsius
or ±0.5 'C. whichever is greater, and a
specific gravity monitoring device
having an accuracy of ±0.02 specific
53
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26944
Federal Register / Vol. 55, No. 128 / Friday, June 29, 1990 / Rules and Regulations
gravity units, each equipped with a
continuous recorder, or
(ii) An organic monitoring device used
to indicate the concentration level of
organic compounds exiting the recovery
device based on a detection principle
such as infrared, photoionization. or
thermal conductivity, each equipped
with a continuous recorder.
(Z) Where a condenser is the final
recovery device in the recovery system:
(i) A condenser exit (product side)
temperature monitoring device equipped
with a continuous recorder and having
an accuracy of ±1 percent of the
temperature being monitored expressed
in degrees Celsius or ±0.5 *C.
whichever is greater, or
(ii) An organic monitoring device used
to monitor organic compounds exiting
the recovery device based on a
detection principle such as infra-red.
photoionization. or thermal conductivity.
each equipped with a continuous
recorder.
(3) Where a carbon adsorber is the
final recovery device unit in the
recovery system:
(i) An integrating steam flow
monitoring device having an accuracy of
±10 percent and a carbon bed
temperature monitoring device having
an accuracy of ±1 percent of the
temperature being monitored expressed
in degrees Celsius or ±0.5 'C,
whichever is greater, both equipped
with a continuous recorder, or
(ii) An organic monitoring device used
to indicate the concentration level of
organic compounds exiting the recovery
device based on a detection principle
such as infra-red, photoionization. or
thermal conductivity, each equipped
with a continuous recorder.
(e) An owner or operator of an
affected facility seeking to demonstrate
compliance with the standards specified
tinder t 60.662 with control devices
other than incinerator, boiler, process
heater, or flare: or recovery device other
than an absorber, condenser, or carbon
absorber shall provide to the
Administrator information describing
the operation of the control device or
recovery device and the process
parameters) which would indicate
proper operation and maintenance of
the device. The Administrator may
request further information and will
specify appropriate monitoring
procedures or requirements.
§*O.M4 Test methods and procedure*.
(a) For the purpose of demonstrating
compliance with ( 60.662. all affected
facilities shall be run at full operating
conditions and flow rates during any
performance test.
(b) The following methods in
appendix A to this part except as
provided under i 60.8(b), shall be used
as reference methods to determine
compliance with the emission limit or
percent reduction efficiency specified
under 160.662(a).
(1) Method 1 or 1A. as appropriate, for
selection of the sampling sites. The
control device inlet sampling site for
determination of vent stream molar
composition or TOC (less methane and
ethane) reduction efficiency shall be
prior to the inlet of the control device
and after the recovery system.
(2) Method 2.2A. 2C. or 20. as
appropriate, for determination of the gas
volumetric flow rates.
[3] The emission rate correction
factor, integrated sampling and analysis
procedure of Method 3 shall be used to
determine the oxygen concentration
(%On) for the purposes of determining
compliance with the 20 ppmv limit The
sampling site shall be the same as that
of the TOC samples, and the samples
shall be taken during the same time that
the TOC samples are taken.
The TOC concentration corrected to 3
percent 0> (C,) shall be computed using
the following equation:
C,=Croc
17.9
20.9- %O5<
where:
C,»Concentration of TOC corrected to 3
percent Oi. dry batii. ppm by volume.
Croc-Concentration of TOC (minus methane
and ethane), dry bans, ppm by volume.
%On-Concentration of O». dry basis.
percent by volume.
(4) Method 18 to determine the
concentration of TOC in the control
device outlet and the concentration of
TOC in the inlet when the reduction
efficiency of the control device is to be
determined.
(i) The sampling time for each run
shall be 1 hour in which either an
integrated sample or four grab samples
shall be taken. If grab sampling is used
then the samples shall be taken at 15-
minute intervals.
(ii) The emission reduction (R) of TOC
(minus methane and ethane) shall be
determined using the following equation:
E.-E.
xioo
where:
R-Emission reduction, percent by weight.
E,—M«»» rate of TOC entering the control
device, kg TOC/hr.
E.»Mass rate of TOC discharged to th*
atmosphere, kg TOC/hr.
(iii) The mass rates of TOC (E* E.)
shall be computed using the following
equations:
-(
I-'
n
Z
I-1
where:
CD, CM "Concentration of sample component
"j" of the gas stream it the inlet and
outlet of the control device, respectively.
dry basis, ppm by volume.
MO. M^—Molecular weight of sample
component "|" of the gai (tream at th^
inlet and outlet of the control device.
respectively, g/g-mole (Ib/lb-mole).
Oj. Q.- Flow rate of gas itream at the inlf>'
and outlet of the control device.
respectively, dscm/min (dicf/hr).
Kt-Constant 2.494xlO-*(l/ppm) (g-mole/
tan) (kg/g) (min/hr), when standard
temperature for (g-mole/tcm) is 20 *C.
(iv) The TOC concentration (Croc) i*
the sum of the individual components
and shall be computed for each run
using the following equation:
CTOC=
n
I C,
where:
CTOC»Concentration of TOC (minus methane
and ethane), dry bat it. ppm by volume.
C,=Concentration of sample components "|",
dry basis, ppm by volume.
n-Number of components in the sample.
(5) When a boiler or process heater
with a design heat input capacity of 44
MW (150 million Btu/hour) or greater is
used to seek to comply with | 60.662(a).
the requirement for an initial
performance test is waived, in
accordance with f 60.8(b). However, the
Administrator reserves the option to
require testing at such other times as
may be required, as provided for in
section 114 of the Act
(c) When a flare is used to seek to
comply with { fl0.662(b). the flare shall
comply with the requirements of | 60.18.
(d) The following test methods in
appendix A to this part except as
provided under f 60.8(b), shall be used
for determining the net heating value of
54
-------
Federal Register / Vol. 55. N'o. 128 / Friday. June 29, 1990 / Rules and Regulations
26945
the gas combusted to determine
compliance under i 60.862(b) and for
determining the process vent stream
TRE index value to determine
compliance under 160.662(c).
(l)(i) Method 1 or 1A. as appropriate.
for selection of the sampling site. The
sampling site for the vent stream flow
rate and molar composition
determination prescribed in J 60.664(d)
(2) and (3) shall be. except for the
situations outlined in paragraph (d)(l)(i!)
of this section, prior to the inlet of any
control device, prior to any post-
distillation dilution of the stream with
air. and prior to any post-distillation
introduction of halogenated compounds
into the process vent stream. No
transverse site selection method is
needed for vents smaller than 4 inches
in diameter.
(ii) If any gas stream other than the
distilla'ion v»nt stream from the
affected facility is normally conducted
through the final recovery device.
(A) The sampling site for vent stream
flow rate and molar composition shall
be prior to the final recovery device and
prior to the point at which the
nondistillation stream is introduced.
(B) The efficiency of the final recovery
device is determined by measuring the
TOC concentration using Method 18 at
the inlet to the final recovery device
after the introduction of any
nondistillation vent stream and at the
outlet of the final recovery device.
(C) This efficiency is applied to the
TOC concentration measured prior to
the final recovery device and prior to
the introduction of the nondistillation
stream to determine the concentration of
TOC in the distillation vent stream from
the final recovery device. This
concentration of TOC is then used to
perform the calculations outlined in
§ 60.684(d) (4) and (5).
(2) The molar composition of the
process vent stream shall be determined
as follows:
(i) Method 18 to measure the
concentration of TOC including those
containing halogens.
(ii) ASTM D1946-77 (incorporation by
reference as specified in S 60.17 of this
part) to measure the concentration of
carbon monoxide and hydrogen.
(iii) Method 4 to measure the content
of water vapor.
(3) The volumetric flow rate shall be
determined using Method 2,2A, 2C, or
2D. as appropriate.
(4) The net heating value of the ver.t
stream shall be calculated using the
following equation:
H' = Kl/ 2 C,H,j
where:
HT=Net heating value of the sample. MJ/
icm. where the net enthalpy per mole of
vent stream it based on combustion at C5
'C and 760 mm Hg. but the standard
temperature for determining the volume
corresponding to one moie it 20'C. as in
the definition of Q, (vent stream flow
rate).
Kt = Constant, 1.740x10''
(1) (g-mole) (MJ).
ppm sera kcal
where standard temperature for
(g-mol«)
is 20'C.
C,=Concentration on a wet basis of
compound j in ppm. as measured for
organics by Method 18 and measured for
hydrogen and carbon monoxide by
ASTM D1946-77 (incorporation by
reference as specified in I 80.17 of this
part) as indicated in i 60.664(d)(2).
H,=Net heat of combustion of compound j.
kcal/g-mole. bated on combustion at 25
'C and 760 mm Hg.
The heats of combustion of vent
stream components would be required
to be determined using ASTM D2382-76
(incorporation by reference as specified
in S 60.17 of this part) if published
values are not available or cannot be
calculated.
(5) The emission rate of TOC in the
vent stream shall be calculated using the
following equation:
Eroc = Kj
where:
Eroc-Emission rate of TOC ir. t.'.e sample.
kg/hr.
Kj-Constant. 2.494x:3-«ll/pprr.) (g-mole/
scm) (kg/g) (mm, hr). whers standard
temperature for (g-mclr.'scm) is 20 *C.
C,-Concentration on a basis of compound j
in ppm as measured by Method 13 as
indicated in i 60.6&;(d);:).
M. = Molecular \vetght of sample j. g;g-mole
Q,»Vent stream flow rate (scm/rwn) a: a
temperature of 20 'C,
(6) The total process vent stream
concentration (by volume) of
compounds containing halogens (ppmv.
by compound) shall be summed from the
individual concentrations of compounds
containing halogens which were
measured by Method 18.
(e) For purposes of complying with
$ 60.662(c) the owner or operator of a
facility affected by this subpart shall
calculate the TRE index value of the
vent stream using the equation for
incineration in paragraph (ej(l) of this
section for halogenated vent streams.
The owner or operator of an affected
facility with a nonhalogenated vent
stream shall determine the TRE index
value by calculating values using both
the incinerator equation in (e)(l) and the
flare equation in (e)(2) of this section
and selecting the lower of the two
values.
(1) The equation for calculating the
TRE index value of a vent stream
controlled by an incinerator is as
follows:
TRE =
(i) where for a vent stream flow rate
(scm/min) at a standard temperature of
20 *C that is greater than or equal to 14.2
scm/min:
THEATRE index value. •
Q,*=Vent stream flow rate (scm/min) at a
standard temperature of 20 'C.
HT=Vent stream net heating value (MJ/scm).
where the net enthalpy per mole of vent
stream is based on combustion at 25 'C
and 760 mm Hg. but the standard
temperature for determining the volume
corresponding to one mole is 20 *C as in
the definition of Q,.
Y. = Q. for all vent stream categories listed ;n
Table 1 except for Category E vent
streams where Y, = (Q.) (HT)/3.6.
ETOC = Hourly emissions of TOC reported in
kg/hr.
a. b, c, d. e. and f are coefficients.
55
-------
2604*1 Federal Rerister / VoL 55. No. 128 / Friday. June 29. 1990 / Rules and Regulations
The t»t of coefficient! that apply to a
vent stream can be obtained from Table
1.
56
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28948
Fedani Regbtar / Vol. 55. No. 128 / Friday. June 29, 1990 / Rules and Regulation*
(ii) when for a vent itream flow rate
(scm/min) at a standard temperature of
20 *C that is leas than 14.2 son/min:
TRE—TRE index value.
0.=14.2 ion/mia
HT-(FLOW)(HVAL)/14A
where by the following inputs are used:
FLOW-Vent itream flow nte (tcm/min). at
• ttandard temperature of 20 *C
HVAL- Vent stream net betting value (MI/
ton), where the net enthalpy per mole of
vent itream i» bated on combustion at 25
*C and 760 mm Hg, but the standard
temperature for determining the volume
corresponding to one mole is 20 *C as in
definition of Q»
Y.-14.2 scm/min for ill vent stresm
categories listed in Table 1 except for
Category E vent streams, where
Hourly emissions of TOC reported in
kg/hr.
a. b. c. d. e. and f are coefficients.
The set of coefficients that apply to a
vent stream can be obtained from Table
1.
(2) The equation for calculating the
TRE index value of a vent stream
controlled by a flare is as follows:
TRE>
where:
TRE-TRE index value.
ETOC-Hourly emission rate of TOC reported
in kg/hr.
Q.-Vent stresm flow rate (scm/min) st a
ttandard temperature of 20 'C.
HT-Vent stream net heating value (MJ/tan)
where the net enthalpy per mole of
offgas Is based on combustion at 25 *C
and 780 mm Hg, but the standard
temperature for determining the volume
corresponding to one mole is 20 *C as in
the definition of Q,
a. b. c d. and e are coefficients.
The let of coefficients that apply to a
vent stream shall be obtained from
Table 2.
TABLE 2.—DISTILLATION NSPS TRE COEFFICIENTS FOR VENT STREAMS CONTROLLED BY A FLARE
K, <11 S UJ/tan _
MT i112MJ/«em
s •
2.25
0.309
b
0.288
0.0619
e
-0.193
-0.0043
d
-0.0051
-0.0034
e
2.08
2.08
(0 Each owner or operator of an
affected facility seeking to comply with
! 60.660(c)(4) or f 60.662(c) shall
recalculate the TRE index value for that
affected facility whenever process
changes are made. Examples of process
changes include changes in production
capacity, feedstock type, or catalyst
type, or whenever there la replacement
removal, or addition of recovery
equipment. The TRE index value shall
be recalculated based on test data, or on
best engineering estimates of the effects
of the change to the recovery system.
(1) Where the recalculated TRE Index
value is less than or equal to 1.0. the
owner or operator shall notify the
Administrator within 1 week of the
recalculation and shall conduct a
performance test according to the
methods and procedures required by
i 60.664 in order to determine
compliance with f 60.662(a).
Performance tests must be conducted as
soon as possible after the process
change but no later than 180 days from
the time of the process change.
(2) Where the initial TRE index value
is greater than 8.0 and the recalculated
TRE index value is less than or equal to
8.0 but greater than 1.0. the owner or
operator shall conduct a performance
test in accordance with 160.8 and
i 60.664 and shall comply with § 40.663.
I 60.664 and } 60.665. Performance tests
must be conducted as soon as possible
after the process change but no later
than 160 days from the time of the
process change.
(gj Any owner or operator subject to
the provisions of this subpart seeking to
demonstrate compliance with
f a0860(c)(6) shall use Method 2. 2A. 2C,
or 2D as appropriate, for determination
of volumetric flow rate.
1 60.688 Reporting and Recordkeeplng
(a) Each owner or operator subject to
i 60.662 shall notify the Administrator of
the specific provisions of i 60.662
(i 60.662 (a), (b). or (c)) with which the
owner or operator has elected to
comply. Notification shall be submitted
with the notification of initial start-up
required by f 00.7(a)(3). If an owner or
operator elects at a later date to use an
alternative provision of | 60.662 with
which he or she will comply, then the
Administrator shall be notified by the
owner or operator 90 days before
implementing a change and. upon
implementing the change, a performance
test shall be performed as specified by
{ 60.664 within 160 days.
(b) Each owner or operator subject to
the provisions of this subpart shall keep
an up-to-date, readily accessible record
of the following data measured during
each performance test and also include
the following data in the report of the
initial performance test required under
160.8. Where a boiler or process heater
with a design heat input capacity of 44
MW (150 million Btu/hour) or greater is
used to comply with i 60.662(a), a report
containing performance test data need
not be submitted, but a report containing
the information in i 60.665{b)(2)(i) is
required. The same data specified in this
section shall be submitted in the reports
of all subsequently required
performance tests where either the
emission control efficiency of a control
device, outlet concentration of TOC or
the TRE index value of a vent stream
from a recovery system is determined.
(1) Where an owner oroperator
subject to the provisions of this subpart
seeks to demonstrate compliance with
i 60.662(a) through use of either a
thermal or catalytic incinerator
(i) The average firebox temperature of
the incinerator (or the average
temperature upstream and downstream
of the catalyst bed for a catalytic
incinerator), measured at least every 15
minutes and averaged over the same
58
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Federal Register / Vol. 55. No. 126 / Friday. June 29. 1990 / Rules and Regulations
28949
time period of the performance testing.
and
(ii) The percent reduction of TOG
determined ai specified in 4 60.664(b)
achieved by the incinerator, or the
concentration of TOC (ppmv. by
compound) determined as specified in
§ 60.664(b) at the outlet of the control
device on a dry basis corrected to 3
percent oxygen.
(2) Where an owner or operator
subject to the provisions of this subpart
seeks to demonstrate compliance with
S 60.662(a) through use of a boiler or
process heater
(i) A description of the location at
which the vent stream is introduced into
the boi'er or process heater, and
(ii) The average combustion
temperature of the boiler or process
heater with a design heat input capacity
of less than 44 MW (150 million Bru/hr)
measured at least every IS minutes and
averaged over the same time period of
the performance testing.
(3) Where an owner or operator
subject to the provisions of this subpart
seeks to demonstrate compliance with
{ 60.662(b) through use of a smokeless
flare, flare design (i.e.. steam-assisted.
air-assisted or nonassisted), all visible
emission readings, heat content
determinations, flow rate
measurements, and exit velocity
determinations made during the
performance test, continuous records of
the flare pilot flame monitoring, and
records of all periods of operations
during which the pilot flame is absent
(4) Where an owner or operator
subject to the provisions of this subpart
seeks to demonstrate compliance with
J 60.662(c):
(i) Where an absorber is the final
recovery device in the recovery system.
the exit specific gravity (or alternative
parameter which is a measure of the
degree of absorbing liquid saturation, if
approved by the Administrator), and
average exit temperature, of the
adsorbing liquid measured at least every
15 minutes and averaged over the same
time period of the performance testing
iboth measured while the vent'stream is
normally routed and constituted), or
(ii) Where a condenser is the final
recovery device in the recovery system.
the average exit (product side)
temperature measured at least every 15
minutes and averaged over the same
time period of the performance testing
while the vent stream is routed and
constituted normally, or
(iii) Where a carbon adsorber is the
final recovery device in the recovery
system, the total steam mass flow
measured at least every 15 minutes and
averaged over the same time period of
the performance test (full carbon bed
cycle), temperature of the carbon bed
after regeneration (and within 15
minutes of completion of any cooling
cycle(s)). and duration of the carbon bed
steaming cycle (all measured while the
vent stream is routed and constituted
normally), or
(iv) As an alternative to { 60.665(b)(4)
((i), (ii) or (iii). the concentration level or
reading indicated by the organics
monitoring device at the outlet of the
absorber, condenser, or carbon
adsorber, measured at least every 15
minutes and averaged over the same
time period of the performance testing
while the vent stream is normally routed
and constituted.
(v) All measurements and calculations
performed to determine the TRE index
value of the vent stream.
(c) Each owner or operator subject to
the provisions of this subpart shall keep
up-to-date, readily accessible
continuous records of the equipment
operating parameters specified to be
monitored under J 80.663 (a) and (c) as
well as up-to-date, readily accessible
records of periods of operation during
which the parameter boundaries
established during the most recent
performance test are exceeded. The
Administrator may at any time require a
report of these data. Where a
combustion device is used to comply
with i 60.662(a). periods of operation
during which the parameter boundaries
established during the most recent
performance tests are exceeded are
defined as follows:
(1) For thermal incinerators, all 3-hour
periods of operation during which the
average combustion temperature was
more than 28 "C (50 *F) below the
average combustion temperature during
the most recent performance test at
which compliance with S 60.882(a) was
determined.
(2) For catalytic incinerators, all 3-
hour periods of operation during which
the average temperature of the vent
stream immediately before the catalyst
bed is more than 28 'C (50 *F) below the
average temperature of the vent stream
during the most recent performance test
at which compliance with i G0.662(«)
was determined. The owner or operator
also shall record all 3-hour periods of
operation during which the average
temperature difference across the
catalyst bed is less than 80 percent of
the average temperature difference of
the device during the most recent
performance test at which compliance
with i 60.662(a) was determined.
(3) All 3-hour period* of operation
during which the average combustion^
temperature was more than 28 *C (50 *F)
below the average combustion
temperature during the most recent
59
performance test at which compliance
with i 60.662(a) was determined for
boilers or process heaters with a design
heat input capacity of less than 44 MW
(150 million Bru/hr).
(4) For boilers or process heaters.
whenever there is a change in the
location at which the vent stream is
introduced into the flame zone as
required under i 60.662(a).
(d) Each owner or operator subject to
the provisions of this subpart shall keep
up to date, readily accessible continuous
records of the flow indication specified
under § 60.663(a)(2), § 60.663(b)(2) and
{ 60.663(c)(l). as well as up-to-data,
readily accessible records of ail periods
when the vent stream is diverted from
the control device or has no flow rate.
(e) Each owner or operator subject to
the provisions of this subpart who uses
a boiler or process heater with a design
heat input capacity of 44 MW or greater
to comply with § 60.662(a) shall keep an
up-to-date, readily accessible record of
all periods of operation of the boiler or
process heater. (Examples of such
records could include records of steam
use, fuel use, or monitoring data
collected pursuant to other State or
Federal regulatory requirements.)
(f) Each owner or operator subject to
the provisions of this subpart shall keep
up-to-date, readily accessible
continuous records of the flare pilot
flame monitoring specified under
S 60.663(b). as well as up-to-date.
readily accessible records of all periods
of operations in which the pilot flame is
absent.
(g) Each owner or operator subject to
the provisions of this subpart shall keep
up-to-date, readily accessible
continuous records of the equipment
operating parameters specified to be
monitored under i 80.663(d), as well as
up-to-date, readily accessible records of
periods of operation during which the
parameter boundaries established
during the most recent performance test
are exceeded. The Administrator may at
any time require a report of these data.
Where an owner or operator seeks to
comply with S 90.362(c). periods of
operation during which the parameter
boundaries established during the most
recent performance tests are exceeded
are defined as follows:
(1) Where an absorber is the final
recovery device in a recovery system.
and where an organic compound
monitoring device is not used:
(i) All 3-hour periods of operation
during which the average absorbing
liquid temperature was more than 11 'C
(20 *F) above the average absorbing
liquid temperature during the moat
recent performance test, or
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28950 Federal Register / Vol. 55. No. 126 / Friday. June 29, 1990 / Rules and Regulations
(ii) All 3-hour periods of operation
during which the avenge absorbing
liquid specific gravity was more than 0.1
unit above, or more than 0.1 unit below,
the average absorbing liquid specific
gravity during the most recent
performance test (unless monitoring of
an alternative parameter, which is a
measure of the degree of absorbing
liquid saturation, is approved by the
Administrator, in which case he will
define appropriate parameter
boundaries and periods of operation
during which they an exceeded).
(2) Where a condenser is the final
recovery device in a system, and where
an organic compound monitoring device
is not used, all 3-hour periods of
operation during which the average exit
(product side) condenser operating
temperature was more than 0 *C (11'F)
above the average exit (product side)
operating temperature during the most
recent performance test.
(3) When a carbon adsorber is the
final recovery device in a system, and
where an organic compound monitoring
device is not used:
(i) All carbon bed regeneration cycles
during which the total mass steam flow
was more than 10 percent betow the
total mass steam flow during the most
recent performance test, or
(ii) All carbon bed regeneration cycles
during which the temperature of the
carbon bed after regeneration (and after
completion of any cooling cycle(s)) was
more than 10 percent greater than the
carbon bed temperature (in degrees
Celsius) during the most recent
performance test.
(4) Where an adsorber, condenser, or
carbon absorber is the final recovery
device in the recovery system and
where an organic compound monitoring
device is used, all 3-hour periods of
operation during which the average
organic compound concentration level
or reading of organic compounds in the
exhaust gases is more than 20 percent
greater than the exhaust gas organic
compound concentration level or
reading measured by the monitoring
device during the most recent
performance test
(h) Each owner or operator of an
affected facility subject to the provisions
of this subpart and seeking to
demonstrate compliance with 160.662(c)
.shall keep up-to-date, readily accessible
records of:
(1) Any changes in production
capacity, feedstock type, or catalyst
type, or of any replacement removal or
addition of recovery equipment or a
distillation unit
(2) Any recalculation of the TRE index
value performed pursuant to | 60.864(0;
and
(3) The results of any performance test
performed pursuant to the methods and
procedures required by 160.664(d).
(i) Each owner or operator of an
affected facility that seeks to comply
with the requirements of this subpart by
complying with the flow rate cutoff in
{ 60.660(c)(6) shall keep up-to-date.
readily accessible records to indicate
that the vent stream flow rate is less
than 0.008 m*/min and of any change in
equipment or process operation that
increases the operating vent stream flow
rate, including a measurement of the
new vent stream flow rate.
(j) Each owner or operator of an
affected facility that seeks to comply
with the requirements of this subpart by
complying with the design production
capacity provision in 160.660(c)(5) shall
keep up-to-date, readily accessible
records of any change in equipment or
process operation that increases the
design production capacity of the
process unit in which the affected
facility is located.
(k) Each owner and operator subject
to the provisions of this subpart is
exempt from the quarterly reporting
requirements contained in { 60.7(c) of
the General Provisions.
(1) Each owner or operator that seeks
to comply with the requirements of this
subpart by complying with the
requirements of i 60.660 (c)(4). (c)(5). or
(c)(6) or 160.662 shall submit to the
Administrator semiannual reports of the
following recorded information. The
initial report shall be submitted within 6
months after the initial start-up date.
(1) Exceedances of monitored
parameters recorded under f 60.665 (c)
and (g).
(2) All periods recorded under
160.665(d) when the vent stream is
diverted from the control device or has
no flow rate.
(3) All periods recorded under
{ 60.665(e) when the boiler or process
heater was not operating.
(4) All periods recorded under
160.665(0 in which the pilot flame of the
flare was absent
(5) Any change in equipment or
process operation that increases the
operating vent stream flow rate above
the low flow exemption level in
160.660(c)(6), including a measurement
of the new vent stream flow rate, as
recorded under i 60.665(i). These must
be reported as soon as possible after the.
change and no later than 180 days after 4
the change. A performance test must be
completed with the same time period to
verify the recalculated flow value and to
obtain the vent stream characteristics of
heating value and ETOC- The
performance test is subject to the
requirements of | 60.8 of the General
60
Provisions. Unless the facility qualifies
for an exemption under the low capacity
exemption status in 160.660(c)(5). the
facility must begin compliance with the
requirements set forth in } 60.662.
(6) Any change in equipment or
process operation, as recorded under
i 60.665(j). that increases the design
production capacity above the low
capacity exemption level in
| 60.660(c)(5) and the new capacity
resulting from the change for the
distillation process unit containing the
affected facility. These must be reported
as soon as possible after the change and
no later than 180 days after the change.
A performance test must be completed
within the same time period to obtain
the vent stream flow rate, heating value,
ETOC- The performance test is subject to
the requirements of I 60.8 of the General
Provisions. Unless the facility qualifies
for an exemption under the low flow
exemption in f 60.660(c)(6). the facility
must begin compliance with the
requirements set forth in | 60.662.
(7) Any recalculation of the TRE index
value, as recorded under | 60.665(h).
(m) The requirements of | 60.665(1)
remain in force until and unless EPA, in'
delegating enforcement authority to a
State under section lll(c) of the Act
approves reporting requirements or an
alternative means of compliance
surveillance adopted by such State. In
that event affected sources within the
State will be relieved of the obligation to
comply with | 60.665(1). provided that
they comply with the requirements
established by the State.
(n) Each owner or operator that seeks
to demonstrate compliance with
i 60.660(c)(5) must submit to the
Administrator an initial report detailing
the design production capcity of the
process unit.
(o) Each owner or operator that seeks
to demonstrate compliance with
160.660(c)(6) must submit to the
Administrator an initial report including
a flow rate measurement using the test
methods specified in | 60.664.
(p) The Administrator will specify
appropriate reporting and ncordkeeping
requirements where the owner or
operator of an affected facility complies
with the standards specified under
{ 60.662 other than as provided under
I 60.663(a). (b). (c) and (d).
{60.664 Reconstruction.
For purposes of this subpart "fixed
capital cost of the new components," as
used in 160.15. includes the fixed
capital cost of all depreciable
components which an or will be
replaced pursuant to all continuous
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Federal Register / VoL 55. No. 128 / Friday, June 29, 1900 / Roles and Regulations
28951
programs of component replacement
which are commenced within any 2-year
period following December 30.1983. For
purposes of this paragraph.
"commenced" means that an owner or
operator has undertaken a continuous
program of component replacement or
that an owner or operator has entered
into a contractual obligation to
undertake and complete, within a
reasonable time, a continuous program
of component replacement.
(Approved by the Office of Management and
Budget under the control number 2060-0055)
§ 60.667
NNN.
Chemicals affected by Subpart
Chemical name
CAS No.'
107-05-1
513-35-9
"I
62-53-3
71-43-2
98-11-3
66081-81-2
65-85-0
100-44-7
92-52-4
80-05-7
76-08-4
106-99-0
Aeetaldehyde _ : 75-07-0
AcetaWoi _ ] 107-89-1
Acetic acid _ ; 64-19-7
Acetic anfivdnde | 1C9-24-7
Acetone i 67-64-t
Acetone cyanonydrn 75-86-5
Acetylene 74-86-2
Acrylic acid 79-10-7
Acrylomtnle 107-13-1
Adipic acid 124-04-9
Aaiponrtnle ' i11-89-3
Alcohols. C-11 or lower mixtures !
Aicono's. C-12 or higfier, mnrtures
Ally! eWorld* _ |
Amylene _
Amyienes. mixed !..
Aniline
Benzene
3enzenesuHonic acid j
Benzenesultonic acid d.-n-atkyt da- i
nvatrves. sodium salts ,
Bonzoic acid, tech !
Benzyl cniorvde j
9,phenyl ;
Bisonenol A _ ;
Srometone ',
1 .^Butadiene ....'
Bjtaaiene and butane fractions i
n-Butana ,
1 4.8utanednl j 110-63-4
Butanes, mixed ,
i-Butene | 106-98-9
2-8utene 25167-67-3
Butenes, mixed _ i
n-Butyl acetate ; 123-88-4
oufyt acrylala j 141-02-2
n-8utyl alconol _ j 71-38-3
see-Butyl alcohol | 78-92-2
tort-Butyl alconol __ i 75-65-0
Butylbenzyi pnthalate , 85-68-7
Bjfytene glycol _ ; 107-88-0
tert-Sutyl nvdroperoxide '. 75-91-2
2 8utyna-1.4-diot i 110-65-6
Bufyraioenyda ; 123-72-8
Butyric anhydnde , 106-31-0
Caprolactam , 105-60-2
Carbon disulfide.. 75-15-0
Carbon tetrabrormoe j 558-13-4
Carbon tetraenlonde | 56-23-5
Chtorobenzene 108-90-7
2 -CMoro-4-onate,
sodMjm sail ...........................................
Pentaarytnntol .»..„.„ ............................. __
n-Pantana ......... . ------------------------- ...... _
3-Pentenenrtnte ................... _ ..................
Pantanaa, mixed ......................................
Perchtoroethyleoe
123-01-3
142-72-3
108-31-8
108-78-1
141-79-7
128-08-7
87-56-1
74-89-5
25378-45-8
74-87-3
75-00-2
78-93-3
74-88-4
108-10-1
60-62-8
107-83-5
872-50-4
..i
91-20-3
98-95-3
27215-95-8
143-08-08
25154-52-3
9018-45-9
25377-83-7
1 -Phai lylelhyl hydropat oxnJa..
Phanylpropana
Phosgana
Phthake anhydride
PropwnaJdehyde — _
Propiooic acid
Propyl alcohol
Propylana cftlorohydnn
Propylene glycol
Prooylene oxide
Sodium cyanide
Styrane
Terephtnahc acid
1.1.2^-Tetracnloroethane....
Tetraetrtyl lead
Tetra (methyl-ethyl) lead.—
Tatrametrtyl lead...
Toluene.
Totuene-2.4-diarnine _. _
Toluene-2.4-;and. 2.6)-d«aocyanata
(80/20 mature) ,
Tribrornornethane „-
1.1.1 -Tnchloroetnane „—
1,1.2-TncMoroathana
Trichtorofluoiomethane _ _..
1.1,2-TncfKoro-l ^^-tnfluoroemana.......
Tnetnandamme.
TnethyMna glycol—
Vinyl acetate
Vinyl cnionda
Vfnytid0Hei cfUondt..
nvXylvn.*
XylanaaliT
nvXylanol.
115-77-5
109-68-0
4635-87-4
109-67-1
127-18-4
108-95-2
3071-32-7
103-65-1
75-44-5
85-44-9
74-98-6
123-38-6
79-09-4
71-23-8
115-07-1
78-89-7
57-55-6
75-58-9
143-33-9
50-70-4
100-42-5
100-21-0
79-34-5
78-00-2
109-99-9
75-74-1
108-88-3
95-80-7
26471-62-5
75-25-2
71-55-8
79-00-5
79-01-8
75-69-4
78-13-1
102-71-8
112-27-6
108-05-4
75-01-4
75-35-*
108-38-3
95-47-6
106-42-3
1330-20-7
578-28-1
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26952 Federal Register / Vol. 55. No. 126 / Friday. June 29. 1990 / Rules and Regulations
•CAS rut*** rttar to ttw Own** Abstract*
flvgomy nunow* M*gn«tf i» iptafto eternal*.
momtn. or rarturw « ctwmeak. Sonw Momr* or
momrw VIM an eovmd by Vw «wiOvdi do not
h«v» CAS numCOT uagnia a m»m. Th« «anmrd»
apply 10 il ol *• cmmcjfci Mid. wtwow CAS
numMn lwv« M«n MMgnM or not
|M.66a Ortte«tlon of authority.
(a) In delegating implementation and
enforcement authority to a State under
f lll(c) of the Act the authorities
contained in paragraph (b) of this
section shall be retained by the
Administrator and not transferred to a
State.
(b) Authorities which will not be
delegated to States: 160.663(e).
[FR Doc. 90-14265 Filed 6-28-90; 8:45 am)
62
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