United States Office of Air Quality EPA-340/1-91-013
Environmental Protection Planning and Standards September 1991
Agency Research Triangle Park, NC 27711
Stationary Source Compliance Series
&EPA
Regulatory and
Inspection Manual for
Petroleum Refinery
Wastewater Systems
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EPA 340/1-91-013
REGULATORY AND INSPECTION MANUAL FOR
PETROLEUM REFINERY WASTEWATER SYSTEMS
Prepared for:
U.S. Environmental Protection Agency
Stationary Source Compliance Division
Washington, D.C. 20460
Prepared by:
Radian Corporation
3200 East Chapel Hill Road/Nelson Highway
Research Triangle Park, North Carolina 27709
September 1991
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TABLE OF CONTENTS
Section Page
1 Purpose of this Manual 1-1
2 Description of Emission Sources in a Refinery Wastewater System 2-1
2.1 Wastewater Collection Systems 2-1
2.1.1 Process Drains 2-1
2.1.2 Junction Boxes 2-4
2.2 Primary Treatment 2-8
2.2.1 Oil Water Separators 2-8
2.2.2 Auxiliary Equipment 2-13
3 Emissions Control Techniques 3-1
3.1 Process Drains 3-1
3.2 Junction Boxes 3-1
3.3 Oil-Water Separators 3-3.
3.4 Auxiliary Equipment 3-3
4 Overview of the Standard 4-1
5 Detailed Requirements of the Standard : 5-1
6 Inspection Procedures 6-1
6.1 Preparing for the Inspection 6-1
6.2 Notification 6-1
6.3 Equipment and Materials 6-1
6.4 Conducting the Inspection 6-2
6.4.1 Review of Records 6-2
6.4.2 Visual Inspection 6-2
Appendix A General Provisions of 40 CFR 60 A-1
Appendix B 40 CFR 60 Subpart QQQ New Source Performance Standard For Petroleum
Refinery Wastewater Systems B-1
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TABLE OF CONTENTS (Continued)
Section Page
Appendix C 40 CFR 60 Subparts K, Ka, and Kb New Source Performance Standard For
Storage Tanks c~1
Appendix D Issues and Answers About Subpart QQQ D"1
Appendix E Test Methods E'1
Appendix F Forms F'1
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LIST OF TABLES
Table Page
2-1 Classification of Refinery Wastewater Treatment Processes 2-3
5-1 Affected Facilities and Facilities Exempt from Standard in a Refinery Wastewater
System 5-2
5-2 Applicability Checklist 5-3
5-3 Detailed Requirements for Individual Drain Systems 5-6
5-4 Detailed Requirements for Oil-Water Separators 5-8
5-5 Requirements for Closed Vent Systems 5-11
5-6 Miscellaneous Requirements of the Standard 5-12
6-1 Compliance Checklist for Individual Drain Systems Using Water Sealed Controls.. 6-3
6-2 Compliance Checklist for Oil-Water Separators with Fixed and Floating Roofs 6-6
6-3 Compliance Checklist for Closed Vent Systems 6-9
in
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LIST OF FIGURES
Figure P«9e
2-1 Example Refinery Wastewater System 2"2
2-2 General Refinery Drain System 2~4
2-3 Types of Refinery Drains 2"6
2-4 Individual Drain System 2'7
2-5 Refinery Drain System Junction Boxes 2~9
2-6 Gas Trap Manhole 2-10
2-7 API Oil-Water Separator 2-11
2-8 Corrugated Plate Interceptor (CPI) 2-13
3-1 Closed Drain System 3-2
3-2 Typical Fixed-Roof Tank 3-4
3-3 Floating Roof 3-5
3-4 Primary and Secondary Seals 3-6
4-1 Aggregate Facility 4-2
4-2 Drain System With Catch Basin 4-4
rv
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SECTION 1
PURPOSE OF THIS MANUAL
Section 111 of the Clean Air Act, as amended in 1977, directed the U.S. Environmental
Protection Agency (EPA) to set standards of performance for any newly constructed, modified, or
reconstructed sources of air pollution that may endanger public health or welfare. These New Source
Performance Standards (NSPS) were to be promulgated for industries recognized as being significant
contributors to air pollution. Petroleum refining was identified as a significant contributor of volatile
organic compound (VOC) emissions to the atmosphere, and was therefore recognized as a priority
industry for standards development. Refinery fugitive emissions of VOC were further identified as a
specific source category to be regulated.
In May of 1984, NSPS were promulgated to control fugitive emissions from equipment leaks in
petroleum refineries. Refinery wastewater systems were recognized as an additional source of fugitive
VOC emissions, and standards of performance for refinery wastewater systems were promulgated on
November 23, 1988. The NSPS for refinery wastewater systems is found in Subpart QQQ of the Code of
Federal Regulations (40 CFR Part 60).
The purpose of this manual is to assist federal, state, and local regulatory personnel with the
enforcement of Subpart QQQ. This document contains all the information needed to enforce the
standard. Section 2 describes the components of a refinery wastewater system, and specifically
addresses the VOC emission sources that are subject to the NSPS. Section 3 describes the required
emission controls. Section 4 presents an overview of the standard, giving a paragraph by paragraph
explanation of the intent and requirements of the rule. Section 5 gives detailed requirements of the
standard, including applicability checklists and tables that further explain the rule. Finally, Section 6
provides guidelines for conducting inspections and includes a series of compliance checklists that can
be used by the inspector of the facility.
Several appendices are also included. Appendix A contains the general provisions (Subpart A)
of 40 CFR 60. Appendix B contains the most recent version of the New Source Performance Standard
for Petroleum Refinery Wastewater Systems (Subpart QQQ), while Appendix C includes a full copy of
Subparts K, Ka, and Kb. Subparts K, Ka, and Kb are New Source Performance Standards for storage
tanks. Appendix D summarizes the compliance issues associated with the standard, and Appendix E
gives applicable test methods required by the rule. Finally, Appendix F provides additional copies of all
the reference tables and-checklists discussed in Sections 5 and 6. The purpose of this appendix is to
provide regulatory personnel with all of the forms needed for compliance inspections in one section of
the document. The forms in this section can be reproduced and used for multiple inspections.
1-1
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SECTION 2
DESCRIPTION OF EMISSION SOURCES IN A REFINERY WASTEWATER SYSTEM
The design of a refinery wastewater system will vary for each facility. The components of the
system will be dependent on the size of the refinery, the quantity and quality of the wastewater, and the
degree of treatment necessary to meet effluent guidelines. In general, a wastewater system will include
three major segments. First, there will be a collection system consisting of drains, junction boxes, and
piping designed to collect and transport wastewater to the treatment processes. Second, there will be
primary treatment processes consisting of oil removal and recovery in an oil-water separator. Finally,
there will be additional treatment processes that can be classified as intermediate, secondary, or tertiary
wastewater treatment. These may include enhanced oil removal in air floatation devices, biological
treatment using trickling filters or activated sludge, and final polishing of wastewater using additional
filtration or carbon adsorption. Figure 2-1 illustrates an example refinery wastewater system. Table 2-1
shows the components of the refinery wastewater treatment system.
The highest concentrations of VOC in the wastewater will be found at the source of collection
and during primary treatment. Therefore, the potential for air emissions of VOCs will also be highest at
these points. For this reason, Subpart QQQ focuses on the control of air emissions from process
drains, junction boxes, and oil-water separators.
This section includes descriptions of the emission sources regulated by the NSPS for refinery
wastewater systems, along with general descriptions of the overall wastewater treatment process.
2.1 WASTEWATER COLLECTION SYSTEMS
Refinery wastewater is collected from process units and other areas of the refinery in a network
of drains. Process units are generally independent processes which cause chemical and physical
changes in refinery feedstock. Wastewater is generated by a variety of sources including cooling water,
condensed stripping steam, tank draw offs, and contact process water. In some older refineries,
process unit wastewater is mixed with stormwater in an integrated collection system. Newer refineries
have segregated collection systems that separate oily process wastewater from non-oily stormwater.
The focus of the NSPS is to control emissions from oily, VOC-laden wastewater. The following sections
will discuss the components of the wastewater collection system, with emphasis on the emission
sources targeted by the NSPS.
2.1.1 Process Drains
Oily wastewater generated by process units enters the collection system through a network of
individual process drains. A medium-sized refinery can have an many as 1000 drains. The process
drains are connected to lateral sewer lines, and there may be several lateral sewer lines in a process
2-1
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Primery Treatment
Intermediate Treatment
Secondary Treatment
Branch
Drain
M
M
\ ', Possible Location of
'• •' Junction Box or
Collection Tank
0 Possible Location of
Unit Oil Water
Separator
Process Drains
Slop Oil
Tank
V
Solids To
Disposal
Oil-Water Separation
Float Treatment
of Disposal
Air Floatation
v
Solids To
Disposal
Air Floatation
(optional)
Miscellaneous Treatment Process
(optional)
Figure 2-1. Example refinery wastewater system.
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TABLE 2-1. CLASSIFICATION OF REFINERY WASTEWATER
TREATMENT PROCESSES
Treatment
Objectives
Example Processes
Primary Treatment
Intermediate Treatment
Secondary Treatment
Removal of free oil and
suspended solids
Removal of emulsified oil,
free oil, suspended solids,
and colloidal solids
Dissolved organics
removal, reduction
in BOD and COD
Tertiary Treatment
Final polishing
API separators
Parallel plate separators
CPI separators
Dissolved air floatation
Induced air floatation
Coagulation-floatation
Coagulation-precipitation
Filtration
Activated sludge
Trickling filters
Aerated lagoons
Oxidation ponds
Rotating biological
contactor
Carbon adsorption
Filtration
2-3
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unit. The lateral sewers flow into junction boxes or manholes that are connected to the main trunk
sewer. Figure 2-2 illustrates a general refinery drain system.
All process drains are potentially sources of fugitive VOC emissions. Several types of process
drains are used in a refinery. The various types of drains are shown in Figure 2-3 and discussed below.
Open Drains
This type of drain is common in older refineries. A straight section of pipe, usually 4 to 6 inches
in diameter, extends vertically to a height of 4 to 6 inches above grade. The pipe is connected directly
to a lateral sewer line with the pipe directed either straight down or at an offset. Drain lines or piping
from the various sources within the process unit generally terminate just within, at, or slightly above the
mouth of the process drain. There is often more than one drain line directed to a single drain opening.
P-Lea Sealed Drains
P-leg sealed drains are similar to open drains, except that a "P" bend in the pipe is found below
grade. The P-bend provides a liquid seal for the individual drain, similar to that found in household
plumbing.
Seal Pot Drains
A seal pot drain has a cap covering the drain opening, and the bottom edge of the cap extends
below the level of the drain entrance. Liquid from the various drain pipes falls into the drain area outside
of the cap and then flows under the edge of the cap and into the drain line. The drain cap can be easily
removed to clean the drain entrance and drain line.
Closed Drains
This type of drain is not common in refinery process units. The drain riser extends about 12 to
18 inches above grade. The top of the riser is completely sealed with a flange. Drain pipes are welded
directly to the riser at points between grade and the flange seal. In some cases, an extra drain nozzle is
also welded to the riser. This line is normally closed with a valve, but provides access to the closed
drain system for intermittent and infrequent ~°eds such as pump drainage. Hoses or flexible lines can
be connected to the riser valve from the liquid source.
2.1.2 Junction Boxes
The relationship of individual process drains and junction boxes is important to applicability of
the NSPS. The standard defines an individual drain system as "all process drains connected to the first
common downstream junction box. The term also includes all such drains and common junction box,
together with their associated sewer lines and other junction boxes, down to the receiving oil-water
separator." (40 CFR Part 60 Subpart QQQ, §60.691) Figure 2-4 illustrates this definition.
The junction box is the central converging point of the process drains before entering the trunk
sewers. Junction boxes permit access to the sewer lines for cleaning and inspection, and separate
sewer lines.
2-4
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cn
REFINERY PROCESS UNIT
f T I ;•
Lateral
Sewers'
o ^N^ o o
Drain Risers
\
\r i i r
Junction
Boxes
o o o
REFINERY PROCESS UNIT
Trunk Sewer
Branch
Sewer
Junction Box
Branch
Sewer
Junction Box
To Wastewater
Treatment
Figure 2-2. General refinery drain system.
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Drain
Pipe
Drain
////////////
-s
Open, Unsealed
Configuration A
(Alternate Offset
configuration)
P-Leg Seal
Configuration B
Drain
Pipe
Seal
Pot
Drain
(L
V///7
Drain
Riser
A/7777777777^
Seal Pet
Configuration C
Closed Drain
Configuration D
Figure 2-3. Types of Refinery Drains.
2-6
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o o o
Process
Drains
3
To Oil-water Separator
Junction
Box
Figure 2-4. Individual drain system.
2-7
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Figure 2-5 shows two types of junction boxes commonly found in a refinery. First, there is the
typical junction box vented to prevent siphoning and vapor locks. Second, a junction box equipped with
a water seal pot is shown. A small amount of water continually flows down the vent pipe to maintain the
water seal. Finally, Figure 2-6 shows a gas trap manhole. This type of junction box includes a baffle
that separates the box into two chambers. Both chambers are vented to the atmosphere.
Most refinery sewer systems are designed for gravity flow of the wastewater from the process
units to the treatment processes. However, when gravity sewers are not feasible, lift stations are
needed to pump wastewater within the sewer system. Lift stations are collection points for wastewater,
and can be considered equivalent to junction boxes. A lift station is essentially a junction box with a
pump inside. The NSPS requires lift stations to meet the same emission control specified for junction
boxes.
2.2 Primary Treatment
Primary treatment in a refinery wastewater treatment system consists of removing free oil and
suspended solids from the wastewater. In most cases, the free oil is recovered and returned to the
refining process. The most common method for removing free oil is the use of an oil-water separator.
2.2.1 Oil-Water Separators
An oil-water separator is usually the first wastewater treatment process used in a refinery. All
separators rely on the different densities of water, oil, and solids to operate successfully. Wastewater
enters a quiescent zone in the separator where the various phases separate. Oils and solids with
specific gravities less than water float to the surface, while heavy solids sink to the bottom.
Oil-water separators are a source of VOC emissions because of the volatilization of organic
compounds from the surface of the separator. There are two types of oil-water separators commonly
used in a refinery. Each type is discussed below.
American Petroleum Institute (API) Separators
Figure 2-7 shows a typical API separator. In this separator, influent passes through trash bars
and a skimmer (the forebay) before entering the quiescent zone of the main bay. In the main bay,
wastewater velocity is kept very low to prevent any turbulent mixing. Free oil droplets are allowed to rise
to the surface where they coalesce in an oil layer. The oil layer is then skimmed from the water surface
using various types of skimming mechanisms. API separators are usually constructed of reinforced
concrete, although prefabricated fiberglass units are available.
Corrugated Plate Interceptors (CPI)
Figure 2-8 shows a diagram of a CPI, which consists of corrugated parallel plates. Wastewater
flows downward between the plates, with the lighter oil droplets floating upward into the tops of the
2-8
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Vent
N
Gas Tight
Cover
Grade
Concrete
Water
(a) TYPICAL JUNCTION BOX
Seal
Vent
Pot
»
»/
(b) JUNCTION BOX WITH WATER SEAL POT
Figure 2-5. Refinery drain system junction boxes.
2-9
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Vent
Gas Tight Lids
Vent
Figure 2-6. Gas Trap Manhole.
2-10
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Trash rack
Platform r
Cover forebay
if desired
Designed for inserting rubber
balloon stoppers, for diverting flows and
for cleaning separator section. Sluice gates
/ of gate valves may be installed if desired.
Sludge pump
Oil skimmers
Flight scraper chain sprocket
Skimmed-oil pump
L
Piers
Wood flight scraper
A
Oil-retention baffle
Diffusion device (vertical baffle)
Oil Skimmer
E
3 | p^s , , , , f
1 r Rnuu
__i p
d
7 r\ 1
\
Sludge hoppers
Section A-A
Note: This diagram is not to scale. A typical API separator is
15 feet wide by 60 feet long.
Oil-retention baffle
Figure 2-7. API Oil-Water Separator.
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Asjustable oullet weir
Oil skimmer Oil layer
Adjustable inlet water
Clean-water
outlet channel
^.; •.'•''V • :.'•.>'. V-'7:'
Concrete
Sludge pit
Concrete
Plate assembly consisting of
24 or 48 corrugated,
parallel plates.
Sediment trap
Figure 2-8. Corrugated Plate Interceptor (CPI).
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corrugation where they coalesce. The oil droplets move up the plate to form a floating layer that is
skimmed from the surface of the treatment tank.
2.2.2 Auxiliary Equipment
Auxiliary equipment associated with an oil-water separator can also be a source of emissions.
Grit chambers, sludge hoppers, weirs, and slop oil storage vessels receive and/or store oily wastewater
laden with VOCs. Any additional equipment located between the individual drain systems and the oil-
water separator that receives and stores oily wastewater is also potential emission source. The NSPS
requires emission controls for all of this equipment.
2-13
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SECTION 3
EMISSION CONTROL TECHNIQUES
The standards of performance for refinery wastewater systems consist of a combination of
equipment, work practice, and design and operational standards. The standards require emission
control for individual drain systems and oil-water separators. Individual drain systems include process
drains and junction boxes. The oil-water separator includes the separator and auxiliary equipment.
Emission control techniques for each emission source are discussed in this section.
3.1 Process Drains
An equipment standard with appropriate work practices will result in emission reductions from
process drains. Water seal controls on drains have been found to result in up to a 50 percent reduction
in VOC emissions. The water seal reduces emissions by limiting the effects of convection and diffusion
on VOC in the wastewater. Water seals can be either P-legs or seal pots, as shown in Figure 2-3. Water
seals will result in emission reductions only if the seals are properly maintained. Therefore, the
equipment standard must be coupled with work practices to ensure maximum effectiveness.
A second method for controlling VOC emissions from process drains is to use a completely
closed drain system. A closed drain was illustrated in Figure 2-3. Figure 3-1 shows a more detailed
schematic of a closed system. The use of a closed drain system is generally limited to units handling
extremely volatile compounds such as benzene, toluene, and xylene. The emission reduction achieved
by a closed system can be as high as 95 percent, depending on the maintenance of the system and the
efficiency of the control device.
3.2 Junction Boxes
The control of emissions from junction boxes can also be achieved by an equipment standard
supported by appropriate work practices. The most feasible method of reducing emissions from a
junction box is to install a tightly sealed cover. The cover reduces the exposure of the wastewater to the
atmosphere, thereby minimizing the effects of diffusion and convection on the VOCs present in the
waste stream.
Because of safety reasons, junction boxes need to be vented to the atmosphere. The design of
the vent can effect VOC emissions. An evaluation of the effects of different size vent pipes resulted in
the NSPS having requirements for maximum pipe diameters and minimum pipe lengths. The rates of
molecular diffusion and convection are influenced by pipe design. Therefore, the design of the vent pipe
can influence VOC emissions from a junction box.
3-1
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Process Unit
Boundary
U
Lateral
Drain
Sump Pumps
Oily Waste Pumped
To Intermediate
Storage Tanks or
Oil Water Separator
Underground
Collection
Tank
Figure 3-1. Closed Drain System.
3-2
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3.3 Oil-Water Separators
The most effective way to reduce emissions from oil-water separators is to install a fixed or
floating roof over the surface area of the separator. The cover reduces the effects of evaporation, wind
speed, and solar radiation. Emission reductions from roofs can be greater than 85%.
Fixed roofs can be constructed of various materials. The roof can be mounted on the sides of
the separator or supported by horizontal beams set in the sides of the tank. The space between the
roof and the edge of the separator can be sealed with gaskets, along with the spaces around any
access doors (see Figure 3-2).
The vapor space under a fixed roof may create a fire hazard or conditions resulting in an
explosion. This problem can be eliminated by purging the space with an inert gas and venting the
vapors to a recovery or destruction device. A fixed roof with vapors vented to a control device can
greatly reduce VOC emissions.
Floating roofs actually float on the surface of the oil, thereby minimizing the vapor space above
the wastewater. Floating roofs can be constructed of materials including plastic, glass foam blocks,
aluminum pontoons, or fiberglass. Seals are placed between the roof and the wall of the separator to
minimize VOC emissions. A primary seal consists of a foam or liquid-filled seal mounted in contact with
the liquid between the floating roof and the wall of the separator. Figure 3-3 shows a diagram of a
floating roof. Figure 3-4 shows primary and secondary seals on a floating roof. The effectiveness of the
roofs in reducing emissions depends on various factors, the most important being maintenance of the
seals around the roofs, doors, and other openings. The standard includes work practices to ensure
optimal performance of the control.
3.4 Auxiliary Equipment
Auxiliary equipment associated with the oil-water separator can also be impacted by the
standard. Any equipment that precedes the separator or handles and stores oily wastewater is subject
to control. Examples of equipment that would warrant control include slop oil tanks, weirs and splitter
boxes, forebays, grit chambers, or sludge hoppers. The most appropriate control for these types of
equipment is a property installed and maintained fixed roof.
3-3
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Pressure Relief Valve
Tank Support Column
Access Port
Gauge Hatch
';'•• '•'.':"'- :Flqicilevelv;^'..^ v';.1';
Manhole/Access Hatch
Nozzle (for
submerged fill
or drainage)
Figure 3-2. Typical fixed-roof tank (cross section).
3-4
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Adjacent Floating Cover
Glide Device
Skimming Manhole
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Metallic Weather Shield
Tank
Wall
Figure 3-4. Primary and Secondary Seals.
3-6
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SECTION 4
OVERVIEW OF THE STANDARD
This section provides an overview of Subpart QQQ. Each paragraph of the standard is
discussed in general terms in order to present an understanding of the provisions and intent of the rule.
The full text of Subpart QQQ appears in Appendix B.
§60.690 Applicability and designation of affected facility
The standards apply to any affected facility in a refinery for which construction, modification, or
reconstruction began after May 4, 1987. Three separate affected facilities are identified by the standard,
taking into account the complexity and interrelated nature of a refinery wastewater system. The three
affected facilities are:
a. Individual Drain Systems - An individual drain system is defined as all process drains
and sewer lines connected to the first common downstream junction box. It also
includes sewer lines and other junction boxes down to the receiving oil-water separator.
Figure 2-6 in Section 2 illustrates this definition.
b. Oil-Water Separators - Oil-water separator includes the separator along with any
skimmers, basins, weirs, or sludge hoppers associated with the separator. Basically, all
equipment that handles or treats oily wastewater up to and including the separator is
included as the affected facility.
c. Aggregate Facility - An aggregate facility includes an individual drain system together
with downstream sewer lines up to and including the oil-water separator. Figure 4-1
illustrates an aggregate facility. The purpose of including the aggregate facility as a
separate affected facility is to control VOCs from all sources prior to and including the
oil-water separator. This prevents VOC suppressed in one area of the system from
being emitted from a downstream component and results in more effective control of
emissions from the wastewater system.
§60.691 Definitions
This paragraph includes all definitions pertinent to the standard. Three definitions that deserve
special attention are those for individual drain system, oil-water separator, and aggregate facility.
§60.692-1 Standards: General
Compliance with the standard is determined by the review of records and reports, and through
visual inspections. The standards apply at all times except during startups, shutdowns, and malfunctions
4-1
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J 1^
Proc
Dra
-) (
.) (_
ess
ns
-)
>. > - ^
^ / /
L Junction Junction
Box Box
Oil-water Separator
o o o
o o o
n o o
c> O 6
Figure 4-1. Aggregate facility.
4-2
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within the process units. The standards do not apply to sewer systems that do not handle oily
wastewater or to equipment that does not come into contact with oily wastewater.
§60.692-2 Standards: Individual Drain Systems
Emission controls for three specific components of an individual drain system are detailed in this
paragraph. These components are process drains, junction boxes, and sewer lines.
a. Process Drains - The standard requires water seal controls on all drains. Initial and
monthly inspections will be required for active drains initial and weekly inspections will
be required for drains not in service. The frequency of inspection for out-of-service
drains is greater because of the possibility of these drains losing their water seals
through evaporation. Facilities can choose to seal or cap their out-of-service drains,
with the inspection frequency reduced to once every 6 months. Drains that lose their
water seal must be repaired as soon as practical, but not later than 24 hours after
detection.
b. Junction Boxes - Junction boxes are required to be tightly sealed with a cover, except
during inspection and maintenance. Junction boxes can be vented to the atmosphere,
when the vent pipe is at least 3 feet in length and less than 4 inches in diameter.
Inspections are required initially and every 6 months, and any repairs must be made
within 15 days of the inspection if they are technically feasible.
c. Sewer Lines - The standard prohibits any sewer lines from being open to the
atmosphere. For example, any new, modified, or reconstructed drain system will not be
allowed to transport wastewater in an open trench or ditch. Any sewer lines that are
above grade need to be inspected initially and every 6 months for any cracks or gaps in
the joints and seals. Any repairs must be made within 15 days of the inspection.
This paragraph also allows an exception to the standard. If a modified or reconstructed
individual drain system includes a catch basin in the configuration prior to the proposal date, the drain
system is exempt from the provisions of this paragraph. A catch basin is an open basin that serves as a
single collection point for storm water runoff. Figure 4-2 illustrates this scenario. New individual drain
systems will not be allowed to be routed through an existing catch basin.
§60.692-3 Standards. Oil-Water Separators
The standard requires two levels of control for separators based on the amount of wastewater
treated by the separator. This paragraph also applies to auxiliary equipment preceding the separator
that handles oily wastewater such as slop oil tanks and storage vessels.
4-3
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c
c
pr
X
pc
X
p
3 Jur
iction Box
Separator
Catch Basin
Drain
Figure 4-2. Drain system with catch basin.
4-4
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New separators and auxiliary equipment that handle 250 gallons per minute or less of
wastewater must be equipped with a fixed roof. The roof must be tightly sealed and inspected initially
and every 6 months for any cracks, gaps, or other flaws that can result in increased emissions. Any
repairs need to be made within 15 days of the inspection. The vapor space under the roof cannot be
purged unless the purged gas is vented to a control device. A pressure relief valve will be allowed for
safety or to allow proper operation, but the valve setting must be set at the maximum possible pressure.
Continuous venting through the relief valve will result in unnecessary emissions.
New separators handling greater than 250 gallons per minute of wastewater must meet the same
requirements of the small separators. In addition, vapors collected must be purged and vented to a
control device. The requirements of the closed vent system are given in §60.692-5.
Special provisions are provided in the standard for modified and reconstructed separators.
Modified or reconstructed separators that treat less than 600 gallons per minute of wastewater only have
to be equipped and operated with a fixed roof, jf the fixed roof was in place prior to proposal of the
standard. If a fixed roof was not in place prior to proposal, the separators must comply with the
provisions for new separators. Modified or reconstructed separators that treat 600 gallons per minute or
more must comply with the requirement of a closed vent system, regardless whether a fixed roof was in
place at proposal.
This paragraph also provides an exemption for any storage vessel that is impacted by the
Subpart K, Ka, and Kb standards for storage tanks. These subparts require some storage tanks to be
controlled for VOC emissions. The text of these subparts is given in Appendix C. In addition, slop oil
storage and handling requirements are also specified in this paragraph.
§60.692-4 Standards: Aggregate Facility
The components of an aggregate facility must comply with the same requirements for individual
drain systems and oil-water separators (§60.692-2 and §60.692-3). An aggregate facility is illustrated in
Figure 4-1.
§60.692-5 Standards: Closed Vent Systems and Control Devices
Design and operational standards are specified for closed vent systems and their associated
control devices. When vapors are purged and directed to a control device, a flow indicator must be
installed to insure conveyance of the gas. All vapor recovery and combustion devices must be designed
and operated to achieve a 95 percent recovery or destruction of the VOCs. As an alternative to the
percent reduction standard, combustion devices can meet a design standard that requires a minimum
residence time of 0.75 seconds at a minimum temperature of 816°C (1500°F). If flares are the control
4-5
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device, the flares must meet the requirements of 40 CFR 60.18. These requirements can be found in
Appendix A.
A closed vent system must remain gas tight during operation. Inspections of the system must
be conducted initially and every 6 months to insure that the system is operating with no detectable
emissions. No detectable emissions is defined as an instrument reading of less than 500 ppm. A
portable VOC analyzer can be used to conduct the inspection. When emissions are detected, repair
efforts must be initiated as soon as practical, but not later than 30 calendar days after detection.
§60.692-6 Standards: Delay of Repair
The standards for each affected facility call for prompt repair of any deficiencies discovered
during the required inspections. However, this provision of the regulation allows repairs to be delayed if
they cannot be accomplished without a complete or partial refinery or process unit shutdown. "^oairs
must occur before the end of the next refinery or process unit shutdown.
§60.692-7 Standards: Delay of Compliance
This paragraph allows for delays in compliance if it would result in full or partial shutdowns of
the refinery or process unit. For example, a new individual drain system may result in the need for new
controls on downstream equipment to meet compliance requirements for an aggregate facility.
Emissions from downstream equipment would not have to be controlled immediately if a full or partial
shutdown was needed to implement the controls.
§60.693-1 Alternative Standards for Individual Drain Systems
As an alternative to water seal controls, facilities may choose to install a completely closed drain
system. The facility must notify the enforcement authority that such an alternative has been chosen.
The closed vent system will be required to meet all of the requirements for closed systems.
§60.693-2 Alternative Standards for Oil-Water Separators
As an alternative to a fixed roof vented to a control device, facilities can choose to install floating
roofs on oil-water separators. A properly installed and maintained floating roof has been shown to give
equivalent emissions reductions compared to the fixed roof with a control device. Facilities must notify
the enforcement authority if they choose to use this alternative.
The floating roof must have both a primary liquid mounted seal and secondary seal. Both seals
must be measured for gaps between the seals and the separator wall within 60 days of installation. Gap
inspections on the primary seal must be conducted at least every 5 years following the initial inspection,
and gap inspections on the secondary seal must be conducted every year. In addition, any access
4-6
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doors or other openings must be inspected initially and every 6 months to ensure that there is a tight fit
and minimal chance for VOC emissions.
It may not be technically feasible to install a floating roof on all portions of an oil-water
separator. If that is the case, fixed roofs will be allowed on portions of the separator where a floating
roof is not appropriate.
Any repairs needed on a floating roof must be conducted within 30 days, unless they are not
feasible as allowed by §60.692-6.
§60.694 Permission to Use Alternative Means of Emission Limitation
Facilities may propose alternative emission controls for any of the affected facilities impacted by
this standard. If an alternative control is proposed, the facility must provide all of the information
necessary to show that the alternative will achieve an emission reduction equivalent to the controls
specified in the standard.
§60.695 Monitoring of Operations
Monitoring requirements consist of both inspections and continuous monitoring equipment for
control devices such as flares and incinerators. Monitoring is essential to successful implementation of
the standard.
§60.696 Performance Test Methods and Procedures and Compliance Provisions
Three types of compliance procedures are required by the standards. First, inspections are
required for all control equipment. Second, measurements using Method 21 are required when closed
vent systems are used. Finally, regular gap measurements are required of seals on floating roofs.
§60.697 Recordkeeping Requirements/§60.698 Reporting Requirements
These two paragraphs outline detailed recordkeeping and reporting requirements of the
standard. Section 5 summarizes these requirements.
4-7
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SECTION 5
DETAILED REQUIREMENTS OF THE STANDARD
This section presents a series of tables designed to simplify requirements of the regulation. The
description of each table is given below, along with an explanation of how to best use each table in
interpreting the standard.
Table 5-1. Affected Facilities and Facilities Exempt from the Standard in a Refinery Wastewater System
Each affected facility covered by the standard includes more than one specific piece of
equipment. This table itemizes the equipment that is included in each affected facility, along with
equipment that is exempt. Inspectors can use this information to clarify which equipment must be
considered in complying with the standard.
Table 5-2. Applicability Checklist
This checklist provides a series of decisions for determining if the standard is applicable to a
given facility. The checklist also helps to determine if a facility must meet the requirements for an
aggregate facility, or just an individual drain system or oil-water separator.
The checklist progresses from general "yes" or "no" decisions applicable to all facilities, to
specific decisions relative to each individually affected facility. For example, if the inspector is
concerned only with a modified/reconstructed drain system in a refinery, he or she should refer to
Sections I and III in the checklist. For an oil-water separator, one should refer to Sections I and IV. If
miscellaneous changes were being made to a refinery wastewater system, one should refer to Sections I
and V for the applicability of an aggregate facility. Table 5-2 also appears in Appendix F (Table F-1).
Table 5-3. Detailed Requirements for Individual Drain Systems
This table presents all the requirements needed for individual drain systems to comply with the
standard. The table specifically addresses the requirements for process drains, junction boxes, and
sewer lines. Included are the emission controls, monitoring and inspection intervals, and reporting and
recordkeeping requirements. This table is also found in Appendix F (Table F-2), and provides a handy
reference sheet for the inspector of a facility.
5-1
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TABLE 5-1. AFFECTED FACILITIES AND FACILITIES EXEMPT FROM
THE STANDARD IN A REFINERY WASTEWATER SYSTEM
AFFECTED FACILITY
EQUIPMENT INCLUDED IN
AFFECTED FACILITY
FACILITIES EXEMPT
FROM THE STANDARDS
Individual Drain System (IDS)
Oil Water Separator
Aggregate Affected Facility
Process drains
Junction boxes
Manholes acting as
junction boxes
Lift Stations
Sewer lines
Oil-water separators
Oil-water separator
forebays
Slop oil tanks receiving
recovered oil
Storage vessels receiving
oily wastewater
Weirs preceding the
oil-water separator
Splitter boxes preceding
the oil-water separator
Other equipment preceding
the separator that
transports, receives, or
stores oily wastewater
All of the above
Modified/reconstructed IDS that
flow into a catch basin that
exjsted prior to May 4, 1987
Drain systems that handle
stormwater exclusively
Slop oil tanks and storage
vessels already subject
to Subpart K, Ka, and
Kb standards
Storage tanks, vessels, or
auxiliary equipment that
do not come in contact with
oily wastewater
5-2
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TABLE 5-2. APPLICABILITY CHECKLIST
I. GENERAL
a. Construction, modification, or reconstruction of the refinery wastewater system commenced
after May 4, 1987.
Yes, the facility is subject to the NSPS, proceed to Sections II, III, IV and V.
No, the facility is exempt from the NSPS, no further inspection is necessary.
II. NEW INDIVIDUAL DRAIN SYSTEMS (IDS)
a. The new individual drain system will handle wastewater containing hydrocarbons.
Yes, the facility must meet the requirements of the standard for an aggregate
facility, regardless of the capital expenditure.
No, the drain system will handle only noncontact cooling water or stormwater
and is exempt from the standard.
III. MODIFIED OR RECONSTRUCTED INDIVIDUAL DRAIN SYSTEMS (IDS)
a. The modified/reconstructed IDS drains directly into the main sewer system, and there is not
an existing catch basin as part of the configuration of the existing drain system.
Yes, go to Ill-b.
No, there is a catch basin in the configuration that was present prior to
May 4, 1987, the IDS is exempt from the standard.
b. The modified/reconstructed IDS results in an emission increase and a capital expenditure.
Yes, the IDS is subject to the standard, go to 111-c.
No, the IDS is not an affected facility.
c. Emission increases created by the modified/reconstructed IDS can be offset elsewhere in the
aggregate facility.
Yes, only the IDS is subject to the standard.
No, go to Ill-d.
d. The modification/reconstruction created an emission increase in the aggregate facility that
cannot be offset.
Yes, the aggregate facility is subject to the standard.
No, emissions can be offset, only the IDS is an affected facility.
continued
5-3
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TABLE 5-2. APPLICABILITY CHECKLIST (Concluded)
IV. OIL-WATER SEPARATORS
a. A new oil-water separator is constructed.
Yes, the new separator is subject to the standard.
No, the standard does not apply.
b. A new oil-water separator is added upstream of an existing separator resulting in a capital
expenditure and an emission increase to the aggregate facility.
Yes, the new separator and downstream components are subject to the
standard.8
No, the standard does not apply.
c. A physical or operational change to an existing oil-water separator results in an emission
increase and capital expenditure.
Yes, the separator is subject to the standard.'1
No, the standard does not apply.
d. Auxiliary equipment is added to the operation of the separator, and the equipment comes
into contact with the oily wastewater.
Yes, the equipment is subject to the standard.
No, the standard does not apply.
V. AGGREGATE FACILITY
a. A physical or operational change is made in the aggregate facility that results in a capital
expenditure and an emission increase.
Yes, the aggregate facility is subject to the standard.8
No.
aSlop oil facilities should not be considered in determining whether a capital expenditure is made on the
aggregate facility.
bln determining whether_an oil-water separator will be modified, the capital cost of the new components
should be applied only-to the actual oil-water separator treatment unit. Slop oil facilities should not be
considered.
5-4
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Table 5-4. Detailed Requirements for Oil-Water Separators
As with Table 5-3, this table provides a reference sheet for the inspector. The table itemizes all
of the regulatory requirements for fixed roofs, floating roofs, and auxiliary equipment associated with an
oil-water separator. This table is also included in Appendix F (Table F-3).
Table 5-5. Requirements for Closed Vent Systems
Additional regulatory requirements are specified for closed vent systems. The closed vent
system could be associated with an oil-water separator having a fixed roof or a completely closed drain
system. Table 5-5 itemizes the regulatory requirements for closed vent systems, and can also be found
in Appendix F (Table F-4).
Table 5-6. Miscellaneous Requirements of the Standard
Table 5-6 summarizes reporting and recordkeeping requirements for modifications and facilities
exempt from the standard. This table is included in Appendix F (Table F-5).
5-5
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TABLE 5-3. DETAILED REQUIREMENTS FOR INDIVIDUAL DRAIN SYSTEMS
COMPONENT/CONTROL
MONITORING/INSPECTION REPORTING
RECORDKEEPING3
en
a.
PROCESS DRAINS
Required Control: Water seals.
i
Alternative Control: Completely closed drain system/caps or sealed drains when out of service.
Water seals (unit In service)
Water seals (unit out of service)
Caps/Seals (unit out of service)
Closed Systemb
Other control
Initially
Monthly
Initially
Weekly
Initially
Semiannually
None
None
Initial report/certification
Semiannual inspection
Delay of compliance
Initial report/certification
Semiannual inspection
Delay of compliance
Initial report/certification
Semiannual inspection
Delay of compliance
Notification to use
closed drain system
Notification to use
alternative control
Demonstration of
compliance
Location, date, corrective action
Expected date of repair
Design specifications
Location, date, corrective action
Expected date of repair
Location of out of service drains
Design specifications
Location, date, corrective action
Expected date of repair
Location of out of service drains
Design specifications
None
None
None
aRecords must be maintained for 2 year periods. Design specifications for equipment used to comply
life of the emission source.
Table 5-5 for requirements of recovery/destruction devices.
with the standard must be kept for the
(Continued)
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TABLE 5-3. DETAILED REQUIREMENTS FOR INDIVIDUAL DRAIN SYSTEMS (Concluded)
COMPONENT/CONTROL MONITORING/INSPECTION REPORTING RECORDKEEPING3
b. JUNCTION BOXES
Required Cdntrol: Tightly sealed cover, vent at least 3 feet in length, diameter 4 inches or less - or length *3 feet, diameter
s 4 inches
Alternative Control: Completely closed drain system
Covers Initially Initial report/certification Location, date, corrective action
Semiannually Semiannual inspection Expected date of repair
Delay of compliance Design specifications
c. SEWER LINES
Required Control: Closed to the atmosphere, no open sewers.
Alternative Control: Buried sewer.
Covered sewer lines Initially Initial report/certification Location, date, corrective action
Semiannually Semiannual inspection Expected date of repair
Delay of compliance Design specifications
Buried sewer lines None None Design specifications
aRecords must be maintained for 2 year periods. Design specifications for equipment used to comply with the standard must be kept for the
life of the emission source.
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TABLE 5-4. DETAILED REQUIREMENTS FOR OIL-WATER SEPARATORS
COMPONENT/CONTROL
MONITORING/INSPECTION
REPORTING
RECORDKEEPING3
tn
a. OIL-WATER SEPARATORS
Required Control: New separators.
<250 gpm (16 L/sec)
*250 gpm (16 L/sec)
Fixed roof.
Fixed roof, vapors vented to a control device.
Required Control: Modified/reconstructed separators.
<600 gpm (38 L/sec)
;>600 gpm (38 L/sec)
Fixed roof.
Fixed roof, vapors vented to a control device.
Alternative Control: Floating roof.
Fixed roof
Fixed roof vented to control^
Initially
Semiannually
Initial report/certification
Semiannual inspection
Delay of compliance
Location, date, corrective action
Expected date of repair
Design specifications
aRecords must be maintained for 2 year periods. Design specifications for equipment used to comply with the standard must be kept for the life
of the emission source.
bSame monitoring/inspection, reporting, and recordkeeping requirements for the fixed roof, plus additional requirements for the control device.
See Table 5-5 for requirements of recovery/destruction devices.
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TABLE 5-4. DETAILED REQUIREMENTS FOR OIL-WATER SEPARATORS (Continued)
COMPONENT/CONTROL MONITORING/INSPECTION
REPORTING
RECORDKEEPING3
c
Floating roof
Other control
Gap measurements on seals
within 60 days
Gaps on primary seals every
5 years
Gaps on secondary seals
every year
None
None
b. AUXILIARY EQUIPMENT, SLOP OIL TANKS
Required Control: New tanks and equipment.
Notification to use floating
roof as control
None
None
Notification to use
alternative control
Demonstration of
compliance
<250 gpm (16 L/sec)
2.250 gpm (16 L/sec)
Fixed roof (pressure relief valve allowed).
Fixed roof, vapors vented to a control device.
Modified/reconstructed tanks and equipment.
<600 gpm (38 1/sec)
>600 gpm (38 1 /sec)
Fixed roof (pressure relief valve allowed).
Fixed roof, vapors vented to a control device.
Design specifications
Location, date, corrective
action
Expected date of repair
None
None
None
None
(Continued)
aRecords must be maintained for two year periods. Design specifications for equipment used to comply with the standard must be kept for the
life of the emission source.
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TABLE 5-4. DETAILED. REQUIREMENTS FOR OIL-WATER SEPARATORS (Concluded)
COMPONENT/CONTROL
MONITORING/INSPECTION
REPORTING
RECORDKEEPING3
Fixed roof
1 ,
Fixed roof vented to control13
Other control
Initially
Semiannually
Initial report/certification
Semiannual inspection
Delay of compliance
Notification to use
alternative control
Demonstration of
compliance
Location, date, corrective action
Expected date of repair
Design specifications
V
o aRecords must be maintained for 2 year periods. Design specifications for equipment used to comply with the standard must be kept for the
life of the emission source.
^Same monitoring/inspection, reporting, and recordkeeping requirements for the fixed roof, plus additional requirements for the control device.
See Table 5-5 for requirements of recovery/destruction devices.
-------
TABLE 5-5. REQUIREMENTS FOR CLOSED VENT SYSTEMS
MONITORING/INSPECTION
1. Initial, semiannual inspections to ensure no detectable emissions as measured by Method 21.
2. Flow indicator to ensure flow to control device.
3. Control Devices
a. Thermal and Catalytic incinerators
continuous temperature recording device.
b. Carbon Adsorber
continuous monitoring device for measuring outlet VOC concentration, or inlet
and outlet VOC concentration.
c. Recovery devices other than a carbon adsorber
date and monitoring information necessary to ensure compliance.
d. Flare
monitoring requirement of 40 CFR 60.18.
REPORTING
1. Notification to use recovery device other than a carbon adsorber.
2. Initial certification of equipment needed to comply with standard.
3. Initial performance test for flares.
4. Initial and semiannual inspection reports, including reports on abnormal operation of control
devices.
5. Date of next shutdown if delay of compliance provisions apply.
RECORDKEEPING
1. Date, location, and corrective action for all repairs.
2. Expected date of repair if corrective action is delayed, with reason for delay.
3. Design specifications for all equipment used to comply with the standard.
4. Documentation-of control device performance.
5. Continuous records of control device performance.
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TABLE 5-6. MISCELLANEOUS REQUIREMENTS OF THE STANDARD
1. MODIFICATIONS
Reporting
The EPA Administrator must be notified prior to any modification of the refinery wastewater system.
2. STORMWATER SEWERS
Recordkeepina
The facility must keep records showing the location of any stormwater sewer. These records will be
used to document exemptions to the requirements of individual drain systems, and to insure that
wastewater from new drain systems does not flow into a stormwater sewer.
3. AUXILIARY EQUIPMENT
Recordkeepina
Plans and specifications for any equipment exempt from the standards must be kept to demonstrate that
this equipment does not come into contact with oily wastewater.
4. NONCONTACT COOLING WATER
Recordkeepina
Plans and specifications for noncontract cooling water exempt from the standards must be kept to
demonstrate that this water does not come into contact with oily wastewater or hydrocarbons.
5-12
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SECTION 6
INSPECTION PROCEDURES
Compliance with the standard is to be determined by review of records and reports, review of
performance tests, and inspections using the methods and procedures specified by the rule. As
required by the rule, all of the inspections are to be carried out by the owner and operator with records
of the inspections kept for a 2 year period. Therefore, compliance can be determined by the review of
plant records, along with spot inspections to verify the operation, performance, and condition of the
control equipment.
This section presents guidelines for conducting a compliance inspection. Compliance checklists
for each affected facility are given, along with instructions for completing the checklists and conducting
spot inspections.
6.1 Preparing for the Inspection
Prior to conducting an inspection, the inspector should search the EPA agency files and review
all information related to the facility to be inspected. A review of the files will help the inspector to
become familiar with the operation of the facility and the most recent compliance history. If prior
inspections have been made of the refinery wastewater system, a review of the records will help the
inspector prioritize areas of concern during the upcoming inspection.
The inspector must also review the regulation and be familiar with all compliance provisions.
The tables in Section 5 (and in Appendix F) are provided to allow for a thorough and quick review of the
provisions.
6.2 Notification
Since the primary means of determining compliance is the review of records and reports, it is
prudent to notify the facility management prior to the inspection. This will allow the facility time to gather
all relevant records and have them available for review. If possible, facilities should provide a map or
flow diagram of the wastewater system to allow the inspector to plan for any spot checks of equipment
and verify the records and reports.
6.3 Equipment and Materials
The inspection can be divided into two components. The first component is mandatory and
consists of a thorough review of the records and reports kept by the plant. Appendix F has been
prepared as a convenient way for the inspector to gather all checklists necessary to systematically
review the records and reports. Copies of this appendix should be made for each inspection. The
6-1
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The second component of the inspection is a visual inspection of the equipment subject to the
standard. Although compliance with the standard can be determined through a review of records and
reports, inspectors should conduct visual inspections to verify the information provided by the facility.
Visual inspections will also verify the condition- of the control equipment. The forms provided in
Appendix F can be used to document observations made during the visual inspections.
During the visual inspection, the inspector may also choose to conduct performance tests and
procedures to verify compliance. Reference Method 21 is to be used to test the integrity of a closed
vent system. A complete description of Method 21 is given in Appendix E. A portable VOC analyzer will
be needed to conduct the Method 21 procedures.
If a floating roof is used to control emissions from a separator, gap measurements are used to
insure the roof is tightly sealed. Gap measurement instructions are also given in Appendix E and
reproduced in Appendix F for the convenience of making copies. The inspector will need a set of
uniform probes for measuring gaps if they choose to use this technique.
6.4 Conducting the Inspection
As mentioned above, the inspection consists of two components: (1) review of records, and
(2). visual inspections. Both of these components will be discussed below.
6.4.1 Review of Records
Tables 6-1 to 6-3 are compliance checklists to be used in reviewing plant records and reports.
Each checklist provides a concise list of statements to be answered with yes or no responses. A "yes"
response to all statements in the checklist will indicate compliance with the standard. The inspector can
use these checklists to systematically review all of the plant records and reports applicable to the rule.
There are a few statements in each checklist that can be answered "no" and "the facility will still
be in compliance. These statements deal with the length of time needed for repair of deficiencies. In
some cases, refineries will not be able to make the necessary repairs in the time frame given by the rule.
For example, repairs to water sealed drains must be made within 24 hours. If repairs to the drains are
not made within 24 hours, statement 5 in Table 6-1 would be answered "no." However, as noted,
refineries can delay repair when repairs are not feasible. If all the statements in the "GENERAL" section
of the checklist are answered "yes," the facility would still be in compliance.
6.4.2 Visual Inspection
The tables also provide sections for visual inspections. In making visual inspections, the
inspector should refer to plant drawings and specifications for all control equipment. Notations should
be made if there are any discrepancies in the plant reports and records based on the visual inspection.
6-2
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TABLE 6-1. COMPLIANCE CHECKLIST FOR INDIVIDUAL DRAIN SYSTEMS
USING WATER SEALED CONTROLS
Complete this form for each individual drain system subject to the standard. A "yes" response to
all questions will indicate full compliance with the standard. A "no" response will indicate
noncompliance, unless the response is related to repair provisions that allow for delays.
LOCATION OF INDIVIDUAL DRAIN SYSTEM
NUMBER OF DRAINS NUMBER OF JUNCTION BOXES
SEWER LINES: BURIED ABOVE GROUND PARTIALLY BURIED/ABOVE GROUND
A. REVIEW OF RECORDS
1. A record of the design specifications for the drain system is available, yes no
including all control equipment for drains, junction boxes, and sewer
lines.
a. Record includes detailed schematics, piping and instrumentation
diagrams. yes no
b. Record includes dates and descriptions of any design changes. yes no
2. Certification of installation and inspection of equipment needed to
comply with the standards was submitted to the regulatory agency
within 60 days of initial startup. yes no
IF THE DRAIN SYSTEM IS ACTIVE
3. Water sealed drains were inspected when the unit was placed in service. yes no
Date of initial inspection .
4. Water sealed drains are inspected monthly. yes no
Date of last monthly inspection .
5. All repairs on water sealed drains were made immediately, or no later
than 24 hours after detection. yes no
(if "no" see GENERAL category below for delay of repair compliance)
6. All junction boxes are equipped with tight fitting covers. yes no
7. The junction boxes were inspected when they were put in service. yes no
Date of initial inspection
8. Junction boxes are inspected every 6 months. yes no
Date of last semiannual inspection
9. Broken seals and gaps were repaired within 15 days of detection. yes no
(if "no" see GENERAL category below for delay of repair compliance)
Continued
6-3
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TABLE 6-1. COMPLIANCE CHECKLIST FOR INDIVIDUAL DRAIN SYSTEMS
USING WATER SEALED CONTROLS
10. All sewer lines are tightly covered.
no
11. The sewer lines were inspected when they were put in service. ves no
Date of initial inspection _ .
12. Cracks, gaps, and other problems in the sewer line were repaired
within 15 days of detection. • Ves no
(if "no" see GENERAL category below for delay of repair compliance)
1 3. Covered sewer lines are inspected every 6 months. ves no
Date of last semiannual inspection _ .
IF ANY PART OF THE DRAIN SYSTEM IS INACTIVE
14. Water sealed drains were inspected when they were taken out of
service. yes no
Date drains were taken out of service _
15. Water sealed drains are inspected weekly. yes no
Date of last weekly inspection _
16. All drains that are capped or sealed were inspected following
initial installation of the caps or seals. yes no
Date when installation was complete _ .
1 7. All drains that are capped or sealed are inspected every 6
months. yes no
Date of last semiannual inspection _
GENERAL
18. All deficiencies have been recorded, including location, date,
and corrective action to be taken. yes no
19. When repairs were not made immediately, the expected date of
repair was noted. yes no
20. All reported deficiencies have been repaired or are scheduled for repair. yes no
B. VISUAL INSPECTION
1 Water seals present on all drains. yes no
2. Caps/seals on inactive drains are in place and tightly fitting. yes no
Continued
6-4
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TABLE 6-1. COMPLIANCE CHECKLIST FOR INDIVIDUAL DRAIN SYSTEMS
USING WATER SEALED CONTROLS (Concluded)
3. Covers on junction boxes are tight and have ho visible gaps or openings. yes no
4. Vents on junction boxes are at least 3 feet in length with a diameter of
4 inches or less. yes no
5. Joints and connections on sewer lines have no visible gaps, cracks,
or openings. yes no
6. Visual inspection of facility is consistent with written records. yes no
NOTE ALL DEFICIENCIES
6-5
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TABLE 6-2. COMPLIANCE CHECKLIST FOR OIL-WATER SEPARATORS
WITH FIXED AND FLOATING ROOFS
Complete this form for each oil-water separator subject to the standard. This form is applicable
only if fixed or floating roofs are the control technique used for compliance. A "yes" response to all
questions will indicate full compliance with the standard. A "no" response will indicate noncompliance,
unless the response is related to repair provisions that allow for-delays.
FLOATING ROOF
LOCATION OF OIL-WATER SEPARATOR
DESIGN CAPACITY FIXED ROOF
AUXILIARY EQUIPMENT SUBJECT TO THE STANDARD
A. REVIEW OF RECORDS
1. A record of the design specifications for the separator and control
equipment is available.
a. Record includes detailed schematics, piping and instrumentation
diagrams.
b. Record includes dates and descriptions of any design changes.
2. Certification of installation and inspection of equipment needed to
comply with the standards was submitted to the regulatory agency within
60 days of initial startup.
. IF THE CONTROL IS A FIXED ROOF OR A FLOATING ROOF
3. The roof was inspected and certified when the separator was placed in
service.
Date of initial inspection .
4.
5.
6.
7.
8.
9.
The roof is inspected every 6 months.
Date of last semiannual inspection
All repairs were made within 15 days of detection.
(if "no" see GENERAL category below for delay or repair compliance)
All auxiliary equipment subject to the standard is equipped with
tight fitting covers.
The auxiliary equipment was inspected and control equipment certified
when initially placed in service.
Date of initial inspection
Auxiliary equipment is inspected every 6 months.
Date of last semiannual inspection
Pressure relief valves (if present) on auxiliary equipment
are set at maximum release pressure.
yes
yes
yes
yes
yes
yes
yes
yes
yes
yes
yes
.no
no
no
no
no
no
no
no
no
no
no
Continued
6-6
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TABLE 6-2. COMPLIANCE CHECKLIST FOR OIL-WATER SEPARATORS
WITH FIXED AND FLOATING ROOFS
IF THE CONTROL IS A FLOATING ROOF
10. The EPA was notified that a floating roof was being installed. yes no
11. Measurement of primary gap seals was conducted within 60 days of
installation. yes no
Date of measurement .
12. Measurement of primary gap seal is conducted every 5 years. yes no
Date of last inspection .
13. Measurement of secondary gap seals was conducted within 60 days of
installation. yes no
Date of last measurement .
14. Measurement of secondary gap seal is conducted every year. yes no
Date of last measurement .
15. All doors and openings were inspected when the roof was installed. yes no
Date of initial inspection
16. All doors and openings are inspected every 6 months. yes no
Date of last semiannual inspection
GENERAL
17. All deficiencies have been recorded, including location, date, and
corrective action to be taken. yes no
18. When repairs were not made immediately, the expected date of repair
was noted. yes no
19. All reported deficiencies have been repaired or are scheduled for repair. yes no
B. VISUAL INSPECTION
FIXED ROOFS ON SEPARATORS AND AUXILIARY EQUIPMENT, FOR EACH SEPARATOR OR
AUXILIARY EQUIPMENT
1. The roof fit tightly with no visible gaps, cracks, or openings. yes no
2. All access doors and openings were sealed properly. yes no
Continued
6-7
-------
TABLE 6-2. COMPLIANCE CHECKLIST FOR OIL-WATER SEPARATORS
WITH FIXED AND FLOATING ROOFS (Concluded)
3. Pressure relief valves are set at maximum pressures. yes no
4. Visual inspection of facility is consistent with written records. yes no
FLOATING ROOFS
5.
6.
7.
8.
9.
10.
NOTE
All access doors and openings were sealed properly.
The gap width between the primary seal and the separator wall was
acceptable using gap measuring methods specified in the rule.3
The total gap area between the primary seal and the separator wall was
acceptable uisng gap measuring methods specified in the rule.
The gap width between the secondary seal and the separator wall was
acceptable using gap measuring methods specified in the rule.
The total gap area between the secondary seal and the separator wall was
acceptable using gap measuring methods specified in the rule.
Visual inspection of facility is consistent with written records.
ALL DEFICIENCIES
yes no
yes no
yes no
yes no
yes no
yes no
Procedure and worksheet for gap measurement is given in Appendix F
6-8
-------
TABLE 6-3. COMPLIANCE CHECKLIST FOR CLOSED VENT SYSTEMS
Complete this form when.a closed vent system is used to comply with the standard for an
individual drain system or oil-water separator. A "yes" response to all questions will indicate full
compliance with the standard. A "no" response will indicate noncompliance.
CLOSED VENT SYSTEM FOR: OIL-WATER SEPARATOR
INDIVIDUAL DRAIN SYSTEM
DESTRUCTION OR RECOVERY DEVICE
DATE OF STARTUP
A. REVIEW OF RECORDS
1 . A record of the design specifications for the closed vent system is
available. • yes no
a. Record includes detailed schematics, piping and instrumentation
diagrams. yes no
b. Record includes dates and descriptions of any design changes. yes no
2. Certification of installation and inspection of equipment needed to
comply with the standards was submitted to the regulatory agency within
60 days of initial startup. ' yes no
IF A CLOSED VENT SYSTEM IS USED FOR A DRAIN SYSTEM
3. The EPA was notified that a closed drain system was being installed. yes no
IF THE CONTROL DEVICE IS A FLARE
4. A report of the initial performance test was submitted within 60 days
of the intial startup. yes no
5. The presence of a flare pilot flame is monitored using a thermocouple
or other device designed to detect the presence of a flare. yes no
6. All periods when the flare pilot did not have a flame have been
recorded, with records kept for 2 years. yes no
7. The flare meets all other operational and monitoring requirements of
40 CFR 60.18. yes no
IF THE CONTROL DEVICE IS A THERMAL INCINERATOR
8. A temperature monitoring device equipped with a continuous monitor
is used to measure the temperature of the gas stream in the combustion
zone, (accuracy of 1% of the temperature measured in °C or ± 0.5° C
[± 1.0° F] whichever is greater). yes no
Continued
6-9
-------
TABLE 6-3. COMPLIANCE CHECKLIST FOR CLOSED VENT SYSTEMS
9. Documentation exists demonstrating 95% control efficiency [or #10). yes no
10. Documentation exists demonstrating minimum residence time of 0.75 seconds
and minimum temperature of 816°C (1500°F). yes no
11. A description of operating parameters used to determine compliance is
available. yes no
12. Continuous records of temperature of the gas stream in the combustion
zone of the incinerator are kept for 2 year periods. yes no
13. Records are kept for all 3-hour periods when the average temperature
of the gas stream in the combustion zone is more than 28°C (50°F)
below the design combustion zone temperature. yes no
14. All other periods of operation not in conformation with design criteria
are recorded. yes no
IF THE CONTROL DEVICE IS A CATALYTIC INCINERATOR
15. Temperature monitoring devices equipped with continuous recorders
are used to measure the temperature in the gas stream immediately
before and after the catalyst bed (accuracy of 1 % of the temperature
measured in °C or.+. 0.5°C [± 1.0°F] whichever is greater).
16. Documentation exists demonstrating 95% control efficiency [or #17]. yes no
17. Documentation exists demonstrating minimum residence time of
0.75 seconds and minimum temperature of 816°C (1500°F). yes no
18. A description of operating parameters used to determine compliance is
available. yes no
19. All periods of operation not in conformance with design criteria are
recorded. yes no
20. Continuous records are kept of the temperature of the gas stream
upstream and downstream of the catalyst bed. yes no
21. Records are kept for all 3-hour periods during which the average
temperature measured before the catalyst bed is more than 28°C
(50°F) below the design gas stream temperature. yes no
Continued
6-10
-------
TABLE 6-3. COMPLIANCE CHECKLIST FOR CLOSED VENT SYSTEMS
22. Records are kept for all 3-hour periods during which the average
temperature difference across the catalyst bed is less than 80% of
the design temperature difference. yes no
23. All periods of operation not in conformance with design criteria are
recorded. yes no
IF THE VAPOR RECOVERY DEVICE IS A CARBON ADSORBER
24. A monitoring device is used that continually indicates and records the
VOC concentration or reading of organics in the exhaust gas of the
control device outlet gas stream or inlet and outlet gas stream. yes no
25. Documentation exists demonstrating 95% control efficiency. yes no
26. A description of operating parameters used to determine compliance is
available. yes no
27. All periods of operation not in conformance with desing criteria are
recorded. yes no
28. Continuous records are kept of the VOC concentration level or reading
of organics of the control device outlet gas stream or inlet and outlet
gas stream. yes no
29. Records are kept for all 3-hour periods during which the average VOC
concentration level or reading of organics in the exhaust gases, or
inlet and outlet gas stream is more than 20% greater than the design
exhaust gas concentration level. yes no
30. All other periods of operation not in conformance with design criteria
are recorded. yes no
IF THE VAPOR RECOVERY DEVICE IS NOT A CARBON ADSORBER
31. The EPA was notified that a recovery device other than a carbon
was being used. yes no
32. A monitoring device is used that continually indicates and records
the VOC concentration or reading of organics in the exhaust gas of
the control device outlet gas stream or inlet and outlet gas stream. yes no
33. Documentation exists demonstrating 95% control efficiency. yes no
34. A description of operating parameters used to determine compliance is
available. ' yes no
Continued
6-11
-------
TABLE 6-3. COMPLIANCE CHECKLIST FOR CLOSED VENT SYSTEMS
35. Continuous records are kept of operating parameters needed to
determine compliance. yes no
36. All periods of operation not in conformance with design criteria are
recorded. Ves no
GENERAL
37. A flow indicator is present on the vent stream to the control device. yes no
38. Documentation exists describing the gas stream entering the control
device, including flow and VOC content under static and dynamic
liquid level conditions. yes no
39. Manufacturers design specifications for the control device are
available. yes no
40. The closed vent system was inspected initially and found to be
operating with no detectable emissions (<500 ppm above background) yes no
Date of initial inspection
41 The closed vent system is inspected every 6 months to ensure
operation with no detectable emissions. yes no
Date of last semiannual inspection .
42. All deficiencies have been recorded, including location, date, and
corrective action to be taken. yes no
43. The location, date, and corrective action was noted when detectable
emissions were measured during any inspection. yes no
44. When repairs were not made immediately, the expected date of repair
was noted and was within 30 days of the reported deficiency. yes no
45. All reported deficiencies were repaired within 30 days or are
scheduled for repair within 30 days of the initial report. yes no
B. VISUAL INSPECTION
1 A flow indicator is present on the vent stream to the control device. yes no
2. For flares, a device for detecting the flame is present. yes no
3. For incinerators, a temperature monitoring device in present. yes no
Continued
6-12
-------
TABLE 6-3. COMPLIANCE CHECKLIST FOR CLOSED VENT SYSTEMS (Concluded)
4. For carbon adsorbers, a device for measuring VOC content is present. yes no
5. The closed vent system has no detectable emissions.3 yes no
6. Visual inspection of facility is consistent with written records. yes no
NOTE ALL DEFICIENCIES
aProcedure for measuring detectable emissions is given in Appendix F
6-13
-------
Visual inspections will include drain systems, oil-water separators, and closed vent systems.
Considerations for inspecting each facility are given below.
Drain Systems
Acquisition of plant drawings and design specifications will be essential for the visual inspection
of a drain system. In some cases, an individual drain system will include numerous process drains,
many of which will be inaccessible. This will make the confirmation of the presence of water seals
difficult. When possible, visual inspection of a drain using a flashlight can confirm the presence of a
seal. In other cases, observing water drainage into a drain will insure a'seal is present. When visual
inspection is not possible, the inspector will have to rely on the accuracy of plant drawings.
Junction boxes, sealed drains, and above ground sewer lines can all be inspected visually. The
inspector should look for any cracks, gaps, worn gaskets, or other deficiencies that can result in
increased emissions. The vent pipes on all junction boxes can be measured simply using a tape
measure.
Oil-Water Separators
Separators using a floating roof for emission control can be visually inspected for gaps, cracks,
and other openings. In addition, the inspector may choose to measure all of the gaps in the primary
and secondary seals to insure compliance. The gap measurement instructions are given in Appendix F
Oil-water separators having fixed roofs with vapors vented to a control device can be inspected
visually and by using Reference Method 21 for measuring detectable emissions. The visual inspection
should include checks of all seals, doors, and joints. Auxiliary equipment should also be inspected if it
is part of the affected facility.
Closed Vent Systems
Method 21 can be used to check the integrity of the closed vent system. The closed vent
system should not have any detectable emissions as determined by an instrument reading of a portable
analyzer. Before using Method 21, the inspector should be carefully review the procedures given in
Appendix E.
Visual inspections should also be made of all control device instrumentation. The checklists
contain all of the instrumentation that should be included for each type of control. The inspector should
verify the plant records with actual observation of all monitoring instruments.
6-14
-------
APPENDIX A
General Provisions of 40 CFR 60
-------
Pt. 58, App. G
40 CFR Ch. I (7-1-90 Edition) Environmental Protection Agency
Parl 60
Wl
f *fur* I.
wriM! trAimcvtAH • •»,
m *iv*ci*«n tar prefect «f facet
penicxiUit end *u»fur
(44 FR 27571. M»y 10. 1»7»; 44 PR 65010. Nov. 9. 1978; 44 PR 72502, Dec. 14. 1919.
ed At 51 FR 05000. Mar 10. 1000. ft2 FR 2474D. 24750. July 1. 10B7)
PART 60—STANDARDS OF PERFORM-
ANCE FOR NEW STATIONARY
SOURCES
Subpart A—Ocnaral Provlil«n»
Sec
00 I Applicability
00 2 Definitions
60 3 Units and abbreviation*.
flO 4 Address.
80 S Determination of construction or
modification.
00 0 Review of plaiu.
00 1 Notification and record keeping.
do 8 Performance tests
00 9 Availability of In/onnatlon.
60 10 State authority
60 11 Compliance with atandarcta and
maintenance requirements
Sec.
00 12 Circumvention
00 13 Monitoring requirements
00 14 Modification
00 15 Reconstruction.
00 10 Priority I lit
00 17 Incorporations by reference
00.18 General control device requirements
Subpart •—Adaption and Submit**! of StaU
n*n» Ur DvtlgnaUd FatllllUi
00.30 Applicability
00 21 Definitions
00.22 Publication of guideline documents.
emission guidelines, and final compll
ance times.
00 23 Adoption and aubmlUal of Slaie
plans: public heatings
00 24 Emission standards and cumpll&nce
schedules.
194
195
-------
Port 60
sec
00 35 Emission Inventories. IOUTCC curved
lajice. report*.
90 26 Legal aulhorlly.
00 27 Acllona by the Administrator.
60 21 Plan revisions by the Stale.
60 It Plan revisions by the Administrator.
Sukp.il C— fj.UitM CM..II... m*4
SO }0 Scope
6031 Definitions.
60.32 Designated laeUlllea-
60.33 Emission guidelines.
ao.34 Compliance time*.
Which C*mlivcH«« Is
Aug.u»l 17. 1*71
DO to Applicability and designation of af-
fected faculty.
10.41 Definition*.
60.42 Standard (or paniculate matter.
•0.43 atandard lor aullur dloaJd*.
•0.44 Standard for nitrogen oxide*.
60.45 Emission and fuel monitoring.
60.46 Teat method* and procedure*.
60.47 Innovative technology walven:
waiver of •ulfur dloilda alandards of
performance for new alallonary aourcea
tor Homer City Dnlt No. 1 under section
lll(J) of the Clean Air Act for MuIU
Sleam Coal Cleaning Syal«m-
40 CFR Ch. I (7-1-90 Edition)
Sec
00 45b Compliance and performance lesl
method* and procedures for sulfur Jlux
Ide.
60 46b Compliance and performance test
oielhod* and procedure* tor ptrllculale
matter and nitrogen oxldea
60.47b Eml**lon monltprlnc for sulfur dl
oilde.
60.46b Emission morUtorljiff for partlculale
matter and nitrogen oxide*.
60 4Db Reporting and recordkeeplni re-
qulrement*.
— SI«Arf«t«« *f P«rf«rm«nc« f*r
60.60 Applicability and designation of af
fected facility.
60 tl Dellnltlons.
60.62 Standard for partlculale matter.
60.61 Monitoring of operations.
60.14 Test methoda and procedures.
60.60 Applicability and designation of af-
fected facllliy.
6061 Definitions
fo.62 Standard for paniculate matter.
60.63 Monitoring of operation*.
M.64 Teat methods and procedures.
A0.6& Recordaceplng and reporting re-
quirement*.
60.66 Deviation of authority
» P»rf.r«.«rs l«<
UlWrr !»»•*» 4)a«a«a Standard for partlculele matter.
60.03 Test methods and procedures
Environmental Protection Agency
Sec
Swbpaft J — Slanderrf
00 100 AppllcabUlly. designation of affect
ed facility, and reconstruction.
<0. 101 Definitions.
60.102 Standard lor partlculale matter.
60 103 ' Standard for carbon monoxide.
60.104 Standards lor sulfur oxide*.
60.106 Monitoring of emlaslona and oper-
ation*.
60 1 04 Test methods and procedures.
60 107 Reporting and recordkeeplng re-
quirement*.
60 106 Performance test and compliance
provisions.
60 10* Dtleittlon of authority.
tat Stat.
IfTJ. m*t
I. *Uy It, It7f
60 110 AppUcablllty and designation of af-
fected faculty.
60.111 Definition*
60.112 Standard for volatUe organic com-
pound* (VOCI.
60.113 Monltortn6 of operation*.
He
Sl*r«t*
Whldt
«f l>irr*o».... IW
Petralews U^uW> rW
C»»»..c.d Ahw May II,
l»7«. ««•• Prfw to JUy 23. I'M
60.1 lOa Applicability and dealgnatlon of af-
fected faculty.
60. 11 la Definitions
60.ll2a Standard for volatile organic com-
pounds (VOCI.
60. II 3a Testing and procedure*.
60.1 Ms Alternative means of emission limi-
tation.
60115* MonlUirlng of operation*.
lufcyert Kk
V.I.IB. O^Mfc U«M Utrm,, V.i..ls
(liKh>«ii( f.lr.l.um U«.uM Slemg* V..-
>.l.) l*r Which CeMlnKlle*. l»c.i»lnK-
Hm, ar MWHk.ll.. C«a«MiKed «H.r
My M. 1*64
60.1 lOb AppllcabUlly and dealgnallon of af-
fected facility.
60 I lib Definitions
80 lljb Standard for volatile organic com-
pound* (VOC)
60.113b Testing and procedure*.
60.114b Altemallve meana of emlaalon llm|.
lallon.
00. Il5b Recordkeeplng and reporting re-
quirements.
Sec.
60110b Monltorlni of operslloiLs
601l7b Delegation of sulhotlly
Port 60
S.c.ne*.ry lorn* Sm.lt.r*
60 120 Applicability and deilinallon of >f
fecled facility.
60 121 Definitions.
40.133 Standard for partlculale matter
40.133 Test method* and procedures.
40.130 Applicability and designation of af-
fected faculty.
40.131 Definitions
40.133 Standard lor paniculate mailer
40.133 Teat method* and procedure*.
M ll-i «.•«• .f P.rl.n.»>« IW Pii-
*M fv.«imn IW WMdt
Ci.- ..... t ArH> JUM 1 1. 1*71
40.140 Applicability and designation of •/
fected facility.
60.141 Definitions.
60.142 Standard for paniculate mailer
60.143 Monitoring of operations.
60.144 Teat methods and procedure*.
l»a»«rt Ha— ll..sir<. .f Pirf.f-^ic. I.,
••Uilsn» h*m §«*k .ayejMi
lMbMak* (WllM.i IW Whldi
C*nitnKfUfi It C.i.»a«c.d AtHr jAntMry
M. I*U
*0.140a Applicability and dolgnatlon of af-
fected faculties
60 14la Definitions
40.142a Standard* for paniculate matter
40.143a Monltodng of operations.
60.144aTe*t methods and procedure*.
40.145* Compliance provisions.
Svbfxrt O—fla«««rdi .1 P.H.rn>«nce f.r
S*w«fje Tre^nvnl Pl.nli
60 150 Applicability and designation ol al
fected facility.
60.161 Definition*.
40.IS1 Standard for paniculate matter
40.133 Monitoring of operations.
40.154 Teat method* and procedure*
60165 Reporting.
40.196 Delegation of authority.
Sttkpmt P—It«i»4»r4l *f P.ff.n»«nc. f.r
Prlmery Cmffmi Snril.r*
60.160 Applicability and designation of af
fected facility.
196
197
-------
Port 60
Hec
DO 111 fJetlnllloiui
00 103 Standard lur perlleulalc matter
OU 14} Standard lur sulfur dioxide.
00 104 Standard lur visible emlallona.
00 106 Monitoring of operations.
00 100 Tell method* and procedure*.
Iu»-per1 O~ It.n4.ra1a af Peftarwenc* fw
Primary ZlfM l Standard lor partlculaU mailer
•0101 Standard lor lullur dioxide
00114 Blalidard for vlalbl* emissions.
00 100 Monitoring of operallona.
00.110 Teal melhodl and procedurea.
SUnaWdi .f P.vf.
Primary Ak/mlnvm g»*WlH>« PUMi
00,190 Appllcablllly end designation ol el-
leclad faclllly.
40191 Definitions.
001(1 Standard for fluoride!.
40111 aundud for vUlble emissions
•0.194 Monitoring of operation*.
00. 190 Teel method* end procedure*.
Iubp.fi I— llanaarai at Periera»e»« l»r Hv«
Ph..prt«f* Perttllxer ln«tfirryt Wel-Pr*c*«t
Pk.iph.fi, lu>4 PUnh
00.300 Appllublllty end deelcrutlon of ef-
lecud fMlllly.
00101 Definitions.
40 101 Stenderd for fluortdee.
00.101 Monltorlrif of operetlone.
40.104 Teet method* end procedure*.
U—
rh«fk AiU Fl.nl.
40 110 Appllublllly end dulfiietlun of el
lecled feclllly.
00.111 Definition*.
40111 BUrtderd lor fluoride*.
00 111 Uonltorlfi* of opcretlori*.
40.114 Teat method* end procedure*.
40 Cf(l Ch I (/-l->0 Edlllon)
lubp.rt V-ll.nJ.idi .» Pol.im.no I.' In.
Ph.tphele P.rlllU.r Industry! DUmm.nlum
Ph.iph.l* Pl.nU
40 120 Applicability end de •(
lecUd I acillty
40 111 Definition*
00 113 BUndud for fluoride*.
00 11) Monltoruii of oi*ratloii*.
00.134 Te*l method* end procedure!
.f P.rf.r«*n<* I., Ih.
Pk..ph.l. PerlUliei liulutlryi Trip), iup.f-
•0.130 Applicability end deiliiiellon ol el
fecl*d fecUlty.
Mill DeflnlUon*.
M.lll BUndud for Huorlde*.
•0 111 Monltortni of operation*.
•0.314 Teet metliod* end procedu/e*.
X— lle^^Wi .f PerrVmnu l.> Ih.
iptMle ••rtlllie* InJu.lryi Onnul.r
•0.340 Applicability and de*l(iietlon ol »
fecled facility.
00341 Deflnltlone.
•0.341 Slandud for fluoride*.
•0.341 MorULorln* of operetlone
•0.144 Teat method* and procedure*.
twbpwrt Y — tlvneerrfi *f P.H.nM.nc. f.r O«l
Pr.p«r«ll.n Planli
00.310 Applicability and definition of «l
fecled fulllty.
40.301 D«flnlUona.
•0.1B3 BUndard* for particular matter.
•O.lal Monllorlnc of operation*.
00.3&4 Te*l method* and procedure*.
lubpwl I — Slenrfwa^ «f Perfena.nc. f.r
40.300 Appllcablllly arid deilinatlon of af
fecled facility.
40.301 Definition*.
(0.303 BUndard for partlculale matter
00.341 Btajidaid for carbon monoxide
40.344 Crnlaelon monllorlnl.
40.340 Monitoring of operation*.
40,344 Te*l method* and procedure*
AA— ll.n4.rJ. •> P.rf.ir».n«. f.i
1U.I Pl.nl. I ll.elde A'l >urn«.i C.n-
tlrucf.rf AH.f O«l.k.f II. IV/4 •n4 *n .(
a,/.,. Auau.l 17, I»«J
40.370 Applicability and dealgriallun of al
fecMd feclllty.
40.111 Definition*
00.171 Blaridard for partlculele uietter,
40,311 Embialon monllorlni
Environmental Protejdlon Agoncy
00 'A'l\ Monitoring of operation*.
flu 375 'I r*l method* and prootxiu/e*.
oil 370 Itceoidkeeplna' and reporting re
gillremenl*.
ml
An
AA»—
S1..I P1«nlu
. ITtl
no 3lOa Appllcablllly and deelfnallon of «J
IrcUd facility.
00 37 1 a IMflnlllona.
00 37 la dtandard for partlculaU matter.
00213a Emlailoo monllorllif .
00374* Monllorinc of operallona.
00 37oa Teal melhod* and procedure*.
00 370* flecordAeeplng and reporting re-
quirement*.
00 290 Applicability arid designation of al
fecUd facility
00 291 l>eflnltlona
0fl 292 Standard* for parllculate matLer.
00 293 Standards for paxtlculale matter
Irom glass melting furnace with modi-
fied proceaaea.
00 294-40 191 IHoerved)
00.204 Tell method* and procedure*.
lutp.fi DO—IrmMW* af P,
Pnrl 60
Ore
•0311 Hta»'l*rd for vi;lilllr uiinnli nun
pound*.
00.313 I'erlonnarice teat* mil ( nini^llini *•
provUloni
•0.314 Monitoring ol ernluloiu ainl inter
allon*
00310 Reporting and rectmlkernlnt le
qulremenu
40114 Teat method* and pioi.rilijre«
M — Il.n<»<« W p
KnflPvepMJH.
00 300 Applicability and dealgnaUon of ej
Ircted facility.
00 3g| f>eflnlllona.
00 303 Standard for partjculale matter.
0010] Blandard for total reduced lullur
cntai
00 204 Monllarfng of emlaeton* and oper-
ation*.
00 2B& Teat metliod* and prooedurea.
00 100 Innovative Utchiiolog? waiver.
Suapart CC— l
luap.fi OO~ll.n*.i4. .f P.ff.fn.ni. f.f
Stortanary O.. luraln.t
•0.130 Applicability and deilgnatlon ol af
lected facility.
40111 Definition!.
•0.133 BUndard for nitrogen ox Idei
•0.131 atandard for lulfur dioxide.
•O.J94 klonllorlng of operation*.
•0.130 Te*t method* and procedure*
••Apart HH-ll.fO.fJ. .f P.rf.m.ne. f..
Pl«ntt
00 300 Appllcablllly and dealgnallon of
lacted faclllly
00 301 Deflnlllon*
00 303 Standard for paniculate matter
00 302 Teat method* and procedure*.
00 303 Teil method! and procedure.
00 304 Modification*.
.1 P«
lubp.n I
00310 Applicability arid dealgnatlon of -af-
IccUd farlllly
nil 11 1 Definition* aridiymbola
40.340 Appllcablllly and dealgnallun of af
fecled facility.
40.141 Deflnlllona.
(0.143 Standard for partlculate matter
40.141 Monitoring of emliilon* and oper
atlon*.
40 144 Te*l method! and procedure*
Kwap«rt KK — Sl.nJ.rrf. .f P.rf.nfi.nc. f.f
UW-A^ a^tl.fy M.nut.duflr,, Pl.nl.
40 110 Applicability and designation ol al
fecled faclllly.
•0.171 Defuiltlona.
40 111 Standards for lead
40.113 Monitoring of emission* uid oper-
ation*.
00.17* Teal melhods and procedure*
luey.rt U— ll.nJ^J. ,1 P.f«.f»«fK. f.,
Melallk Mln.f.l Pranlilnf Planh
40310 Applicability and deilgnatlon of af
fected faclllly
•OKI Deflnlllona
•0 3B3 Standard for partlculate matter
00.3B) Reconstruction
40 304 Monitoring of operation*
•0.185 flecordaeeplng and reporting re
autremenl*.
00 304 Tell method* and procedure*
lofcpwl MM— II.fia-.fJ> .1 P.rf.fm.r». f.,
Aut.iv.kll. .n4 llahl-Duly Irucb SuH.t.
40390 Applicability artd deiliri.llon or af
fected licllHf
40191 Dellnlllorui
1UB
199
-------
Port 60
40 CFR Ch. I (7-1-90 Edition)
Environmental Protection
Port 60
Sec
00 3B2 Standard* for volatile organic com-
pound*.
00 393 Performance leal and compliance
provtjlona.
00 304 Monitoring of emUaloiu and oper-
ation!.
00 395 Reporting and recordkeeplng re-
quIrernenU.
00 396 Reference method. and procedure*.
60J91 Modifications.
00.308 Innovative technology walvera.
tukp.fi HH— tlenee**1* «l Parianawii. I ft
rh.iph.t. leek Ptanl.
•0.400 Applicability and designation of al
fecled (aclllly.
00.401 Definlllona.
00 403 Standard (or paniculate matter.
00.403 Monitoring of emlaalona and oper-
ation!.
00.404 Teat method! and procedure!.
Svbpwt n— Henslares .1 Perf*ni.iKe (at
AwMloia MM* MeMl.«tura
00.410 AppllcabUlly and designation of af-
fected facility.
00.421 Definition..
80433 Standard! (or particular matter.
00.421 Monitoring of operation!.
00.414 Teal method! and procedure!.
Iukp.rt Q4— II«n
P«rl.«»er>ia
Ih. Graphic Arl> Inevslryi PirMlcellen «e-
00.410 Applicability and dealgnatlon of af-
fected facility.
00.431 Definitions and notation!.
00.412 Standard for volatile organic com-
pound!.
00.413 Performance teal and compliance
provisions.
00.434 Monitoring of operation! and rec
. ordkeeplng.
00.435 Teat method! and procedure!.
tyke-art M — Stane'eres ef ParreriMitce far
Preiuire I.nilllva Tape wirf Ukel Svrfeca
Cealbi| Operellefis
00.440 Applicability and deilgnallon of af-
fected facility.
00.441 Definition! and symbols.
Sec
Subp.rt SI — Slondo.d. ,1 r»ri(rm.n« ID,
Induilrl.l Svrf.c. C..llna: tofa* Appllan(«i
00.450 Applicability and deilinatlon of af
fected facility
60.461 Definition!.
00451 Standard (or volatile organic com-
pound!.
00.463 Performance teat and compliance
provliloni
00.464 Monitoring of emluloru and oper-
ation!.
00.45ft Reporting and recordkeeplng re-
qulremenU.
00.450 Teal mclhoda and procedure!.
tuap.rt n— Itweertli «f T
Metal C*» Iwfece Ceellrnj
00.400 Applicability and dealgnatlon of al-
(ecled (aclllly.
00.401 Definition.
00.402 Standard, (or volatile organic com-
pound!.
•0403 Perfomann ' leil and compliance
provtalona.
00.404 Monllorlng of emlaaloni and oper-
ation!.
00.406 Reporting and recordkeeplng re-
quirement!.
60.460 Teal method! and procedure..
tvbpwi UU— It -i...J. .1 P«ft»n»<><. I.. AJ-
fhmll Prx»lb>t ml* Alph.ll l.*n.(
60.410 Applicability and dealgnatlon of af-
(ected facUIUea.
60.411 Definition!.
60.411 Standards for partlculate matter
00.413 Monitoring of operation..
60.414 Teal melhod! and procedures.
luapart W—tl.n..... .1 Paif.rmanc. l.r
I.ulp..nl ta.l>i .f VOC In lha lynlh.lk
Orgwik OioU.il M.nul.rtuilng Indutlry
00.460 Applicability and deiignallon of af-
fected (aclllly.
60.461 Dednltloni.
60.462-1 Standard*: General
60.462-2 Standards: Pump. In light liquid
•entice.
00.401-3 Standard.: Comprewor..
00 443 Standard lor volatile organic com *>.«»-« Standard.: Presaure rellel device.
pounds.
60.443 Compliance provisions.
60.444 Performance test procedures.
In gaa/vapor aervlce.
60.462-1 Standard.: Sampling connection
ayilema.
60.445 Monitoring o( operations and ree- «••««-• Standards: Open ended valves or
ordkeeplng lines.
60.440 Test method, and procedure.. 00.401-1 Standards: Valvea In gaa/vapor
00.441 Reporting requirement!.
Sec
«0 482 1 Standards Pumps and valve. In
heavy liquid aervlce. pressure relief de
vice. In light liquid or heavy liquid serv-
ice. and (langea and other connector*.
004S2-) Standard.: Delay ol repair.
00.401-10 SUuMard.: Cloaed vent .ystemi
and control device..
00.401-1 Alternative standard! for valvea—
allowable percentage of valvea leaking.
00 401-2 Alternative standard! lor valvea—
skip period leak detection and repair.
00 484 Equivalence of means of emission
limitation.
00 466 Teal method, and procedure.
00 400 Recordkeeplng requirement!.
00.401 Reporting requirement!.
00.401 Reconatructlon.
00.401 Lilt of chemical! produced by af-
fected facilities.
>u»p.f1 WW— Itaoeere* •« Patfentanc. (~
lha 6»»r»ce Ceil Sorrece Orflnf IneVntry
00 4*0 Applicability and dealgnatlon of af-
fected facility.
00.4tl Definitions.
00 493 Standard! for volatile organic com-
pounds.
00.401 Performance teal and compliance
provision!.
60.404 Monllorlng of emissions and oper-
' atlona.
00.405 Reporting and recordkeeplng re-
quirement!.
00.400 Te!t method, and procedure..
Sukpert XJ(— It.na'.re'i al P.rtenMno la*
«d In llghl liquid «rv(ce.
00.500 Applicability and designation ol af-
fected facility
00.601 Definlllona.
00.501 Standard, for Volatile Organic
Compound (VOC) emissions from bulk
gsaollne terminals.
00.501 Test methods and procedure!.
00.504 (Reserved]
00 506 Reporting and recordkeeplng.
00.500 Reconstruction.
Su»P«t AAA— llaneertf. af PefrWnBwice fer
New latieaiillel W.W Heetara
00.530 Applicability and dulgnatlon of af.
lected (aclllly.
•0511 Definition.
•0.511 Standard, (or participate mailer.
00.511 Compliance and certification.
•0.514 Test method, and procedure!.
60615 Laboratory accreditation.
•0.610 Pernuwcnl label, temporary label.
and owner's manual.
10 511 Reporting and recordkeeplng.
•0516 Prohibitions.
<0.61( Hearing and appeal procedures.
00 539a Delegation of authority
00.530b General provision* exrluslun^
Subp«rt Ml— Slondotdi «( P.rformonc* to,
th. Rubb.i Tlra Manufacturing InduilrY
•0.640 Applicability and deslin.tlon ul af
(ected (acllltles.
60.141 Definition.
60.541 Standards (or volatile organic com-
pounds.
00943. Alternate standard for volatile or
ganlc compounds.
00.643 Performance test and compliance
provtalons.
00 644 Monitoring of operation..
00.648 Recordkeeplng requirement..
60.546 Reporting requirement..
60.641 Teat method, and procedure..
00.646 Delegation ol authority
lokp.rH CCC— iff l«...rv.«|
Sukpert HF— tleneerd* el Parfamenca lor
Railkla Vinyl end Uralh.na Oellnc «nd
PitfiHnsj
00.880 Applicability and dealgnatlon of at
fected facility.
00.881 Definitions and symbols
60.582 Standard for volatile organic com-
pounds.
60.581 Test melhoda and procedures.
60.664 Monitoring of operation, and rec
ordkeeplng requirement..
00.605 Reporting requirements.
Iukp.rt OOO— Sl.n4««. .1 P.rl.n».n<. l.r
f^ulpw.nl l..ki •( VOC In P.lralaom «.-
00.800 Applicability and designation "of af
fecled facility.
00.8*1 Definition!.
00.5*2 Standards.
•0.8*1 Exception!.
fcikpert HHH— Slanderdi af P.rfonunc. l.r
S>ntk.llc Flkaf PtWuclUii F.dllll.i
60.600 Applicability and designation of af-
fected (aclllly.
60.601 Dednltloni.
60.602 Standard (or volatile organic com
pounds.
00.003 Per(ormance leal and -compliance
provisions
00.604 Reporting requirement!.
200
201
-------
>
en
Part 60
Sec
Swbpart III—Standard! of Parfartnanca Ur
Volatile Organic Compound (VOC) CmU-
tUnt From lh« Synthetic Organic Ch«mUal
Manufacturing Indwiliy (SOCMt) Air Oxi-
dation Unit Pr*c«M*i
00010 Applicability and designation of af
fecled facility.
00 OM Definitions.
60612 Standards.
*00fll3 Monitoring of emissions and oper-
ations.
BO OH Ten methods and procedures
00 615 Reporting and recordkeeplng re-
quirement*.
00 010 Reconstruction.
00 017 Chemicals affected by tubparl III.
60 618 Delegation of Authority.
Swbport JJJ—Standard* *l Parfarmanc* far
f •trolaum Dry Claanart
00 020 Applicability and designation of af-
fected factllly.
00021 Definition).
00 022 Standards for volatile organic com-
pounds.
60 623 Equivalent equipment and proce-
dures.
60 624 Teal methods and procedures.
00.625 Recordkeeplng requirements.
Sub part KKK—Standard* al farfarrnanca lor
fqulpmanl Laak* af VOC Fram Oruhara
Natural Oa* •r»««Mlng Plant*
60 630 Applicability and designation of af
fected facility.
60031 Deflnltlops.
60 632 Standards.
60.033 exceptions.
60.634 Alternative means of emission limi-
tation.
60-635 Recordkeeplng requirements.
60.630 Reporting requirements.
Swbport ILL—Standard* «f ••rUrmanca Ur
Onthara Natural Oa* fraark Taya Caaling fajdPrt^
Sec.
60.710 Applicability and d«l«naUoD of af-
fected facility.
60.711 Definitions, symbols, and croa»-ref-
erencc table*.
60.713 Standard* for volatile oanmlc com-
pounds.
60.713 Compliance provision*.
60.714 Installation of monitoring device*
and reoordkeeplnf.
60.715 Tert methods and procedure*.
60.710 Permisalon to us« alternative mean*
of emlaalon Umilation.
60.717 Reportlnc and monltorlnc require-
ment*.
60.718 Delegation of Authority.
Svbpart TTT — Stai»daid» af ParvWavonca fW b>-
dmlrtal Swfvoa Ca-*io». Stwrawa Casting
af P1«*tk Part* rW iMlnaaa Mo*hln<»
60.710 AppUcmblllty and deaurnatlon of af-
fected facility.
60.721 Definition*.
60.723 Standards for volatile organic com-
pound*.
60.729 Performance te*t and compliance
provisions.
60.724 Reportlnc w»d reoordkeeplnc re-
quirement*.
60.725 Teat method* and procedure*.
60.720 Delegations of authority.
VW_ tlandaid* af Paffanaam* f*r
Oath* af S«.<«
-------
>
dr>
§60.2
Alternative method means any
method of sampling and analyzing for
ui air pollutant which Is not a refer-
ence or equivalent method but which
has been demonstrated to the Admin
Ulralor's satisfaction to. In specific
cues, produce results adequate for his
determination of compliance.
Capital expenditure means an ex-
penditure for a physical or operational
chance to an existing facility which
exceeds the product of the applicable
"annual asset guideline repair allow-
ance percentage" specified In the
latest edition of Internal Revenue
Service (IRS) Publication 634 and the
existing facility's basis, as defined by
section 1013 of the Internal Revenue
Code. However, the total expenditure
for a physical or operational change to
an existing faculty must not be re-
duced by any "excluded additions" as
defined In IRS Publication 634. as
would be done for tax purposes.
Commenced means, with respect to
the definition of nets source In section
lll(aX2> of the Act. that an owner or
operator hu undertaken a continuous
program of construction or modifica-
tion or that an owner or operator has
entered Into a contractual obligation
to undertake and complete, within a
reasonable time, a continuous program
of construction or modification.
Construction means fabrication,
erection, or Installation of an affected
facility.
Continuous monitoring system
means the total equipment, required
under the emission monitoring sec-
tions In applicable subparts, • used to
sample and condition (If applicable).
to analyze, and to provide a perma-
nent record of emissions or process pa-
rameters.
Equivalent method means any
method of sampling and analyzing for
an air pollutant which has been dem-
onstrated to the Administrator's satis-
faction to have a consistent and quan-
titatively known relationship to the
reference method, under specified con-
ditions.
Eiiiting facility means, with refer-
ence to a stationary source, any appa-
ratus of the type for which a standard
Is promulgated In this part, and the
construction or modification of which
was commenced before the dale of
40 CFR Ch. I (7-1-90 Edition)
proposal of that standard; or any ap
paralus which could be altered In such
a way as to be of that type.
fsokinetic sampling means sampling
In which the linear velocity of the gas
entering the sampling nozzle Is equal
to that of the undisturbed gas stream
at the sample point.
Mai/unction means any sudden and
unavoidable failure of air pollution
control equipment or process equip.
ment or of a process to operate In a
normal or usual manner. Failures that
are caused entirely or In part by poor
maintenance, careless operation, or
any other preventable upset condition
or preventable equipment breakdown
shall not be considered malfunctions.
Modification means any physical
change In. or change In the method of
operation of, an existing facility which
Increases the amount of any air pollut-
ant (to which a standard applies) emit-
ted Into the atmosphere by that facili-
ty or which result* In the emission of
any air pollutant (to which a standard
applies) Into the atmosphere not pre-
viously emitted.
Jfoniforinp- device means the total
equipment, required under the moni-
toring of operations sections In appli-
cable subparts, used to measure and
record (If applicable) process param-
eters.
Nitrogen oxides means all oxides of
nitrogen except nitrous oxide, as meas-
ured by test methods set forth In this
part.
One-hour period means any 80-
minute period commencing on the
hour.
Opacity means the degree to which
emissions reduce the transmission of
light and obscure the view of an object
In the background.
Owner or operator means any person
who owns, leases, operates, controls, or
supervises an affected facility or a sta-
tionary source of which an affected fa-
cility Is a part.
Particulate matter means any finely
divided solid or liquid material, other
than uncomblned water, as measured
by the reference methods specified
under each applicable subpart. or an
equivalent or alternative method.
Proportional tampltno means sam-
pling at a rate that produces a con
Environmental Protection Agency
slant ratio of sampling rate to stack
gas flow rate.
Reference method means any
method of sampling and analyzing for
an air pollutant as specified In the ap-
plicable subpart.
Run means the net period of time
during which an emission sample Is
collected. Unless otherwise specified, a
run may be either Intermittent or con-
tinuous within the limits of good engi-
neering practice.
Shutdown means the cessation of op-
eration of an affected facility for any
purpose.
Six-minute period means any one of
the 10 equal parts of a one-hour
period.
Standard means a standard of per-
formance proposed or promulgated
under this part.
Standard conditions means a tem-
perature of 303 K (M'P) and a pres-
sure of 101.3 kilopaacsds (M.02 In Hg>.
Startup means the setting In oper-
ation of an affected facility for any
purpose.
Volatile Organic Compound means
any organic compound which partici-
pates In atmospheric photochemical
reactions; or which la measured by a
referenca method, an equivalent
method, an alternative method, or
which I* determined by procedures
specified under any subpart.
(44 PR 5S11J. aept 16. int. as amended at
45 PR 5817, Jan. 1), I MO; 45 PR 15415. Dec.
14. Itao: 54 PR SMI. Feb. 14. !•••)
I 60.) Unlls and abhrcrtauona.
Used In this part are abbreviations
and symbols of unlU of measure.
These are defined as follows:
(a) System International (SI) units
of -measure:
A—ampere
I—tram
Hi—heru
J-Joule
K-decree Kelvin
if—kilogram
m—meter
m •—cubic meter
mt—mullcram—10"' ffram
nun—millimeter—10"' meter
Ms—mecacrmm—10' sram
tnol—mole
N—newton
nt—nanotram—10" • tram
tun—nanometer—10" • meter
§60.3
Pa—pascal
s—second
V-volt
W-wttt
O—ohm
|if—mlcrotrain—10"' cram
(b) Other units of measure:
Btu—British thermal unit
*C—decree Celsius (cenllgrftde)
cal—calorie
dm—cubic feel per mlnul*
cu ft—cubic feel
del—dry cubic feet
dem—dry cubic meter
dscf—dry cubic feet at standard conditions
dscm—dry cubic meter at standard condi-
tion*
eq—equivalent
*P—decree Fahrenheit
ft—leet
sal—gallon
gr—train
g-eq—tram equivalent
hr— hour
In-lnch
k-I.OOO
l-Uter
Ipm—liter per minute
Ib—pound
meq—mUUequlvalent
mln—minute
ml—mluuiter
moL «rt—molecular welihl
ppb—parts per billion
ppm—parts per million
pala—pounds per square Inch absolute
pall—pounds per square Inch tMe
•R—decree Raruune
scf—cubic leet at standard conditions
Beth—cubic feet per hour at standard condl
Uons
•cm—cubic meter at standard conditions
sec second
aq ft—square feet
std—at standard conditions
(c) Chemical nomenclature:
CdS—cadmium sulflde
CO—carbon monoxide
CfV-carbon dioxide
HC1—hydrochloric acid
fit—mercury
H.O—water
H«-h7droten sulflde
BJBO.—suUuric acid
N.—nllroten
NO—nitric oxide
NO,—nllroten dioxide
NO.—nllroten oxides
O«—oxyten
8O.—«uUur dioxide
8O.—sulfur trioxlde
SO.—sulfur oxides
(d) Miscellaneous:
204
205
-------
§60.4
A 3 T M ~ AmerlCAJl Society (or TeflUtg uid
M«teil»U
IU PR 31000. July IB. 1611. 4] KH 36178
July 21. 16111
160.4 Addreii.
(» AJ1 requMls. reports, appllna-
tloiu, «ubnutt»la. and other communi-
cations to the Administrator punuanl
to thla part shall be (Ubmllled In du-
plicate to the appropriate Regional
Office of the U.S. Environment*! Pro-
tection Agency to the attention of the
Director of the Division Indicated In
the following list o( EPA Regional Of-
fices.
Region 1 (Connecticut. Maine. Muuchu-
•etu. New Hunpjhlre. Rhode Island. Ver-
mont). Director. Air UanMemenl Dirt
•Ion. D.S. Environmental Protection
Axency. John P. Kennedy Federal Build
Int. Boiton. HA 0320}.
Redon II (Ncn Jeraey. Hew York, Puerto
Rico. Virgin lilandt). Director. Air and
Wute Uanaiemeat Dlvblon. O.S. Eovl-
roninental ProUctloo Asency. Pederal
Olllc* BuUdlnf. M Pederal Plaza (Poley
Square). New York, NY 10211.
Rerlon III (Delaware. DUtrtct of ColumbU.
Maryland. Pcnruylvanla. Virginia, West
Virginia), Director. Air and WuU Man-
agement Division. U.S Environmental
Protection Agency. CurtU Building. SUth
and Walnut SlreeU. Philadelphia. PA
leioa
Region IV (Alabama. Plonda. OJorgla. Ken-
lucky. Mlailailppl. North Carolina. South
Carolina, Tenneeeee). Director. Air and
Wute Management Division. U.8. Ulrt-
ronmenlAl Protection Agency. 94B Court-
land Street. HE.. Atlanta, OA 10366.
Region V (Illinois. Indiana. Michigan. Min-
nesota. Ohio. Wisconsin). Director, Air
Management Division. U.8. Environmen-
tal Protection Agency. 210 South Dear-
bom Street. Chicago. IL (OM4.
Region VI (Arkansas. Louisiana, New
Mexico. Oklahoma. Texas): Director; Air.
Pesticides, and Toxics Division; US Envi-
ronmental Protection Agency. 1445 Ross
Avenue. Dallas. TX 76302.
Region VII (Iowa. Kansas. Missouri. Nebras-
ka). Director. Air and Toxics Division. US.
Environmental Protection Agency. 726
Minnesota Avenue. Kansas City. KS
(6101.
Region VIII (Colorado. Montana, North
Dakota. South Dakota, Utah. Wyoming).
Director. Air and Waste Management Di-
vision. U.8. Environmental Protection
40 CFR Ch. I (7-1-90 Edition)
Agency. 1600 LlJtcoln Street. Denver. CO
B01D6.
Region IX (American Samoa. Arizona. Call
fomls. Ouun. Hswill. Nevsds). Dlrectoi.
Air and Wute Management Division. U S
Environmental Protection Agency. 215
Fremont Street. San Francisco. CA 04105
Region X (AJuka. Oregon. Idaho. Washing
ton), Director. A^r and Waste Manage
raent Division. U.S. Environmental Protec-
tion Agency. 1200 Sixth Avenue. Seattle.
WA 68101.
(b) Section 11 HO direct! the Admin
Istrator to delegate to each Stale.
when appropriate, the authority to Im-
plement and enforce standards of per-
formance for new stationary sources
located In such State. All Information
required to be submitted to EPA under
paragraph (a) of this section, must
also be submitted to the appropriate
State Agency of any Stale to which
this authority has been delegated
(provided, that each specific delega-
tion may except sources from a certain
Federal or State reporting require-
ment). The appropriate mailing ad-
dress, for those States whose delega-
tion request has been approved ls u
follows:
(A) (Reserved!
(B) State of Alabama. Air Pollution Con
trol Division. Air Pollution Control Commis-
sion. 646 8. McDonough Street. Montgom-
ery. AL 3(104.
(C) Stale of Alaska. Department of Envi-
ronmental Conservation. Pouch O. Juneau.
AKS.ill
(D) Ai-liona:
Arizona Department of Health Servlcea.
1740 West Adams Street. Phoenix, AZ
(6007.
Marlcopa County Department 01* Health
Services. Buresu of Air Pollution Control.
1136 Cait Roosevelt Street. Phoenix. AZ
*1006.
Pints County Health Department. Air Qual
Ity Control District. 161 West Congress.
Tucson. AZ (6701.
Plma County Air Pollution Control District.
161 West Congress Street. Tucson. AZ
(6701.
(I) The following table lists the >peclllc
source and pollutant categories that have
been delegated to the air pollution control
agencies In Arizona. A star (•) Is used to In-
dlcale each category that has been delegat-
ed.
Environmental Proie>ctlon Agency
§60 4
,-
»
*
•
»
»
•
•
»
•
•
•
»
•
.
a>
-
•
WLUJTAKT
CATEGORY
ARIZONA
>
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• *
* •"•
• «-
» K
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» X
• *
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» *•
* M
• ~*
» c
» <
* «:
» •<
- r*
fc83£
egp-
QS5
*~0
General Provlaton*
Ceo* rat 1 of Unit*
Conatructeil After 8/1 //M
Electric Ucllitf S(«u
Generating Uolta
Coaetructe4 After 9/10/76
Incinerator*
Portland Cewent Plant*
Nitric Acid Plant*
Sulfurlc Acid Plant*
Asphalt Concrete Plant*
Petroleta* leflnerle*
Storage V*e*el* for
PajtroleiaB Liquid*
Constructed After
6/11/75 Prior to 5/14/7*
Storage Veaaale Por
Patrol*u» Liquid*
Canatructad After 3/18/76
Secondary Lead Satelttra
Secondary iraaa And Ironic
Inept Production
Iron And Steel Manta
Sevaxe Treatment Plant*
FriMrr Copper Sewltera
l»rl*arj Zinc Saeltera
Prlatai-y Lead S*Mlter*
Prlatary Mus»lnu»
leduction Planta
Phoephate Fertilizer
Induatry: W*t Procc**
Phoaphorlc Acid Planta
Phoaphate Fertllltcr
laduatry: Super
Phoaphorlc Acid Plant*
Phoaphatc Fertiliser
Induatry: Dlaa»onlu«
Phoaphate Plant
Phoaphate Fertilizer
Indue try : Triple
Super Phoaphate Plant
Phoaphale Fertlllicr
Indue 1 17 : Cranul ar
rrlpla Super Phoaphatc
Storafc Facllitie*
Coal Preparation Plants
Perralloy Production
Factlltlea
i
SOURCE r
1
5
PI
vt
?
9*
z
3
y»
206
207
-------
§60.4
40 CFR Ch. I (7-1-90 Edilicn)
>
00
DEI.CnATlON STATUS OF
NEW SOUICI PKHMINHAWK S'lANIiAKIlS (MM1:.)
rux MavAuA
All
ruLLUTIOM
aottfoi
ACUCT
roLLUTAVT
CATtQOIT
Cl.ra
W..ho.
*.
M
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LUTAMTS
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HCSHAr:
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i
•
Indtcslas 4el«aatlo«
(E> 8UU of Arkansas: Chief. Division of
Air Pollution Control. Arkansas Depart.
ment ol Pollutloo Control and Ecology* tool
National DrlY.. P.O. Box HN. Little Rock.
AR 13300.
California:
Amador County Air Pollution Control Dla-
Irtct. P.O. Box 410.110 Court Street. Jack-
son. CA OM43
Bay Area Air Pollution Control District. OB
Ellis Street. Bat Francisco. CA MIOt.
Butu County Air Pollution Control Dis-
trict. P.O. Box 11H, 31* Ntlson Anmu.
OrovtUe. CA ioMJ
Calavcru County Air Pollution Control Dis-
trict. Government Center, d Dora4o •
Rod. Sui Andrea*. CA *(><•
Colusa County Air Pollution Control Dis-
trict. 161 Fremont Street. Colust, CA
»5»S3
El Dorado Air Pollution Control District,
310 Fair Lane. PlacervUle, CA I6M7
Fresno County Air Pollution Control Dis-
trict. 1311 Fulton Mall. Fresno. CA 13131
Olenn County Air Pollution Control Dis-
trict. P.O. Box 361. 130 North Coluu
Street. Willows. CA 05U1
Oreat Basin Unified Air Pollution Control
District. 1J7 Short Street. Suite «. Bishop.
CA MM4
Imperial County Air Pollution Control Dis-
trict. County Services Building, til West
Main Street. El Centre. CA tilt)
Kern County Air Pollution Control District.
1*01 B Street. Suite 360. Bakerslleld. CA
01101
Kings County Air Pollution Control Dis-
trict, 110 Campus Drive. Hanford. CA
OHIO
Lake County Air Pollution Control District,
3U North Forbes Street. Lakeport. CA
HU3
Isssrn County Air Pollution Control Dis-
trict. I7t Russell Avenue. Susanvllle. CA
MHO
aladara County Air Pollution Control Dis-
trict. 115 W. Yosemlle Avenue. Madera.
CA 03011.
Msxlpou County Air Pollution Control Dis-
trict. Box ». liarlposa, CA 96110
Mendoclno County Air Pollution Control
District, County Courthouse. Uklah. CA
Merced County Air Pollution Control Dis-
trict, P.O. Box 411. 340 East ISth Street.
Merced. CA Otl40
Modoc County Air Pollution Control Dis-
trict. 303 West 4th Street. Allures. CA
•0101
Monterey Bay Unified Air Pollution Con-
trol. 1104 Monroe Street. Suite 10. Salinas.
CA93000
Nevada County Air Pollution Control Dis-
trict. H.E.W. Complex. Nevada City. CA
09060
Environmental froffe
-------
§60.4
40 CFR Ch. I (7-1-90 Edition)
Environmental Protection Ag«ncy
§ 60.4
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rOI CALIfDRHlA
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COKTROL
OISTKICT
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STANDARDS fU* HAZ>*t>iXJb
AIR ttll 1 IITAKTS(MEStlAPS)
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211
-------
§60.4
SlmK ol Colorado. Department of
lleaJth, Air Pollution Control Division. 4210
Eul llth Avenue. Denver. CO 10220
EDITOHIAJ. NOTE. For a tsbla listing Reilon
VIHs NSP3 deleiallon slalus, see para-
graph (c) o/ this lection.
Stale of Connecticut. Departmenl ol
Environment^ Protection. Slate Office
Building. HaxUord. CT 0(115.
(I) State ol Delaware. Delaware Depart-
ment of Nalural Resources and Environ-
mental Control. (t Kln«a Highway. P.O.
Boi,UOI. Dover. DE IBWI
State of Iowa: Iowa Department of
Natural Resources. Environment*! Protec-
tion Dlvblon. Henry A. Wallace Building.
900 East Grand. Dlvblon of Air Pollution Conuol, De-
partment for Nalurml Resources and Envi-
ronmental Protection, ll.fi. 127. Frankfort.
KY 40(01.
State of Loublana: Procrarn Admlnb-
Irator. Air Quality Dlvblon. Loublana De-
partment ol Environment*! Quality. P.O.
Box 440X. Baton Rouge. LA 70(04.
Stale of Maine. Department of Envi-
ronmental Prolecllon, St*te House. Augus-
ta. ME 04330.
40 CFR Ch. I (7-1-90 Edition)
(V) State ft Maryland Bureau of Air
quality and Noise Control. Maryland Stale
Departmenl of Heallh and Mental Hygiene.
201 West Preston Street. Baltimore. MD
11201.
(W) Commonwealth of MassachuselLs
Massachuselts Department of Envlronmen
tal Quality Engineering. Division of Air
Quality Control. One Winter Street. Boston
MA 03108
(X) Stale of Michigan. Air Pollullon Con
Irol Dlvblon. Michigan Departmenl of Nat
ural Resources, Stevens T Mason Building
(th Floor. Lansing. Ml 4((1(.
(Y) Mlnnesot* Pollution Control Agency.
Dlvblon of Air Quality. 520 Lafayelle Road.
St. Paul. MN 5(155.
(Zl Bureau of Pollullon Conlrol. Depart
ment of Natural Resources. P.O. Box 10385.
Jackson. MS 39309.
(AAI State of Missouri: Missouri Depart
roenl of Natural Resources. Dlvblon of En-
vironment*! Quality. P.O. Box I7(. Jeffer-
son City. MO (5102.
(BBI Stale of Montana. Departmenl of
Heallh and Environment*! Services, Air
Quality Bureau, Cogswell Building. Helena,
MT 59(01.
CDITOIIIAI Non: For a table Ibtlng Region
VIIIs NSPS delegation status, see para-
graph of tub section.
(CO SUte of Nebraska. Nebraska Depart-
ment of Environments! ConUol. P.O. Box
94(77, SUte House SUllon. Lincoln. NE
M509.
Lincoln-Lancaster County Heallh Depart-
ment. Dlvblon of EnvlronmenUl Heallh.
2200 81. Marys Avenue. Lincoln. NE ((501
(DD) Nevada:
Nevada Department of Conservation and
Natural Resources. Dlvblon of Environ-
ments! Protection. 201 South Fall Streel.
Canon City. NV (9710.
Clark County County DlsLrlcC Heallh De-
partment, Air Pollution Control Dlvblon.
(35 Shadow Lane. Las Vegas. NV (910(.
Washoe County District Heallh Depart-
ment. Dlvblon of EnvlronmenUl Prolec-
tlon. 10 Klrman Avenue. Reno. NV (9502
(/I The following uble IbU the specific
source and pollutant categories that have
been delegaUd to the air pollution control
agencies In Nevada. A aUr (•) b used to Indi-
cate each csUgory that has been delegated.
Environmental Protection Agemcy
•
y
§60.4
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C«D>[atlol Uolla
Constructed After «/l7/7l
Electric Ucllltj Steasi
CeD*ratto( Unite
Constructed After t/K/78
Inclnarstore
Portland CeettDt Hants
Nitric Acid Plante
Sulfurlc Acid Plants
Asphalt Concrete Plants
Petroleum Refineries
Storage Vessels for
Patrolaua Liquids
Cooatrwcted After
6/11/7) Prior to J/K/71
PaCroleuai Ll^ulSa
Construct^ After 5/lo/7(
Secondary Lea4 Sewltere
Secondary lr*ae *nd Broni*
ln|Ot Production
Iroa And Iteel Plante
Sevate Treatment Plante
PrlMry Copper Sn«ltera
PrlsMry Zinc Sntelcera
Prisury lead Snvltere
Primary Alisminum
(eduction Plants
Pboephete Pertlllser
Industry: Wet Proceee
Phosphoric Acid Plante
Phoephate Pertlllser
Induetry: Super
Phoephorlc Acid Plsnte
Phosphate Pertiliser
Induetryi Dlasavinluai
Phoephete Plant
Phosphate fortillier
Induetry: Triple
Super Phosphate Plent
Phoephete fertiliser
Industry: Granular
Triple Super Phoaphate
Storage Facilltiee
Coal Preparation Plants
Ferralloy Production
Facilities
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212
213
-------
§60.4
40 CFR Ch. I (7-1-90 Edition)
NATIONAL EMISSION
STAHDAIDS FOI H«7JM!•«• Omraano, U-U to WMtfi CorMfrucaon
Comm*nc»d Altar ••f*«n*«r It 1i>Tt
f or*** Cwntml Ptanb _
NMric ACU PtanU _
A**wH Cora** Ftvtfa . ._ _....
Stoiae* VMMM to* Pvfrofeum U»M» Corwtoctod Ata Jvw
11. I»f3. «nd prtar tt bUf 1C. 11-Tt,
Siof«0« v*MMii tar pMotaM U«*«U« CerMwdMl Afur U«r
11. 1*71
S«oondMy BIM* and aranu Ingo* Pmducten PtanU _.
iron and S«M< PtonU _
SM^» TrackMrt Mm :.
Primary L*Md SnM*»fi _
N«w JVMT
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214
Environmental Protection A0«ncy
§ 60.4
cc
DO
EE
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FFF
QGO
HUH
ILL
OOO
PPf
Vtaiw I™JU»«T O>vrt«li Hw*ng h
LMk« ol Vote** Onj*nic Compound* In S
«ao* C*n
Coding IndMtoy
V in) UivtlwrM Codtng end Pt*i«og
LMM of VOC ki P«»otaun fUkxjriM
PvfcotMn Ory
flOT* L*M
PUnu
l VOC Ironi Orwriori) N«k«»J G«*
U«i QM Proc»Mir« PltviU, SO. E
ProoMt.ng Pl*r«*
Wool FlwotaM bwtMton Utwwtockrtig PUnU
(GO) SUlc of New Mexico: Director, New
Mexico EnvlroamenlAl Improvement Divi-
sion. Health and Environment Department.
HBO St. FrancU Drive. SantA Pe. NM 87603
(I) The City of Albuquerque and Berna-
IILlo County: Director. Th« Albuquerque En-
vironmenUJ Health Department. The City
ol Albuquerque. P.O. Box 1293. AJbuquer-
que. NM 81103
(HH) New York: New York SUte Depart
ment of Environmental Conservation. &0
Wolf Road Albany. New York 12233. atten-
tion: Dtvlilon of Air Reaource*.
(II) North Carolina Environmental Man-
agement Commlailon. Department of Natu-
ral and Economic Resource*. Division of En-
vironmental Management, P.O. Box 27087,
Raleigh, NC 27611. Attention: Air Quality
Section.
UJ> Stale of North Dakota. SUU Dtp art
tQtnt of Health and Consolidated Laborato-
ries, Division of Environmental Engineering.
State Capitol. Bismarck. NT) 58905
EDITOKIAJ. NOTE: For a table listing Region
VIII's NSPS delegation tlalus. tee para
graph (c> of this section.
(KK> State of Ohio:
(I) Medina, Summit and Portage Counties.
Director. Akron Regional Air Quality Man
agemenl District. 177 South Broadway.
Akron. OH 44308.
(11) Stark County. Director. Air Pol lull on
Control DlvUlon. Canton City Health De
partmenl, City Hall Annex Second Fluor.
218 Cleveland Avenue SW. Canton. OH
44702.
(Ill) Butler. Clermonl. Hamilton and
Warren Counties: Director. Southwestern
Ohio Air Pollution Control Agency. 2400
Beekman Street. Cincinnati. OH 45214
Cuyahoga County Commissioner. Dl
vision of Air Pollution Control Department
215
-------
§60.4
ol Public Health and Welfare. 21JS Broad-
way Avenu<. Cleveland. OH 4411>.
(v) Belmont, Carroll. Columblana. Hurl-
con. Jefferson, and Monroe Counllea: Direc-
tor. North Ohio Valley Air Authority
(NOVAA). 114 Adunj Street. SteubenvUle.
OH 41B92.
(vll Clark. Darke, Oreene, Miami. Mont-
gomery, and Preble Counllea.- Supervisor.
Regional Air Pollution Control Afency
(RAPCA). Monlffomery County Health De-
partment. 4»l Wait Third Street. Dayton.
OH «»402.
(vl|) LUCM County and the City- of Ross-
ford (In Wood County): Director, Toledo En-
vironmental Services Afency, 2fl Main
Street. Toledo. OH 4}Mt.
(vlll) Adami. Brown. Lawrence, and Scloto
Countlei; Engineer Director. Air Dlvlalon.
Portsmouth City Health Department, 140
Second Street, Portsmouth. OH 4IM1,
(III Allen. Aahland. Auflalxe. Crawford.
Defiance. Erie. Fulton. Hancock Rerdln.
Henry. Huron. Marlon. Mercer, Ottawa.
PauJdlnf. Putnam. Rlchland. Banduaky.
Seneca. Van Wen, Williams. Wood (except
City of Roatfordl, and Wyandot Counties:
Ohio Environmental Protection Afency.
Northwest District Air PoUuUon Dnlt 10JJ
Dexlac Grove Drive, Bowline; Oraen. OH
41402.
(x> Ashtabula. Holmes, Loraln. and Wayne
Counllea: Ohio Environmental Protection
Afency, Northeast District Office. Air Pol-
lullon Unit. 9110 East Aurora Road. Twlnj-
burl. OH 440IT.
(xl) Alhen*. Coahocton. Oallla, Guernsey,
Hocklnt. Jackson. Malfi. Morgan. Muakln-
ffum. Noble. Perry. Pike. Rosa. Tuacerewaa.
Vlnton. and Waahlnflon Countlea: Ohio En-
vlronmenlal Protection Afency, Southeail
District Oltlct. Air PoUuUon Dnlt. lit*
Front Street. Lai an. OH 411M.
(xll) Champalfn. Clinton. Hlfhland.
Lof an. and Shelby Counties: Ohio Environ-
mental Protection Afency, Southwest DU-
trtcl Office. Air Pollution DnlU Eaat Fourth
Street. Dayton. OH 49401
(kill) Delaware. Palrflald. Fayella. Frank-
lin. Knox. Ucklnf. MailUon. Morrow.
Plduway. and Union Countlee: Ohio Envi-
ronmental Protection Afency. Cantral DU-
trtcl Olllce. Air Pollution Onlt. P.O. Bon
1O4». Columbus. OH 4Jlf4-el4».
(xlv) Oeaufe and Lake Countlea: Lake
County General Health District. Air Pollu-
tion Control. lOt Main Street. Palneavllle.
OH 44011.
(xvl Mahonlnl and Trumbull Countlea:
Mahonlnf-Trumbull Air Pollution Control
Afency. 0 Weat Front Street. Youncstown.
OH 44101.
(LL) State of Oklahoma. Oklahoma Slate
Department of Health. Air Quality Service.
P.O. Box IMM. Oklahoma city. OK 13181.
(I) Oklahoma City and County: Director.
Oklahoma City-County Health Department.
40 CFR Ch. I (7-1-90 tdlllon)
B21 Northeut 13rd Street. Oklahoma City
OK 13105
(II) Tula* County. Tuba City County
Health Department. ««!« Eait Fifteenth
SUeet. Tulaa. OK 14112.
( MM i State of Oregon. Department of En
vlronmenlal Quality. Yeon Building. S22
S.W. Filth. Portland. OR 81304
(I)— (vlll)IReaerved)
(Ix) Lane Regional Air Pollution Author
lly. 221 North Fifth. Sulle 801. Springfield
OR »1411.
(NX) (a) City of Philadelphia: Philadel-
phia Department of Public Health. Air
Manafement Service*. 900 S. Broad Street
Philadelphia. PA 1114*.
(b) Commonwealth of Pennsylvania: De-
partment of environmental Resource*. Poit
Orrica Box lotl. HarrUburf. PA 11120.
(c) Allefheny County: Allefheny County
Health Department, Bureau of Air Pollu-
tion Control, 101 Thirty-ninth Street. Pitts-
burgh. PA 11201.
(OO) State of Rhode Island Rhode Island
Department of Environmental Manage-
ment. 304 Cannon Bulldlnf. Davis Street.
Providence. RI OJBOt.
(PP) Stale of South Carolina. Office of
Environmental Quality Control, Depart-
ment of Health and Environmental Control.
atOO Bull Street. Columbia. 8C 2>201.
(QQ) StaU of South Dakota. Department
of Water and Natural Resource*. Office of
Air Quality and Solid Waste. Joe Foai
Bulldlnf. 12! East Capitol. Pierre. SD
Enrroaiu. NOTE For a table listlnf Region
Vlll'a N8PS delegation status, see para-
fraf h (c) of this section.
(RR) Division of Air Pollution Control.
Tenneasee Department of Public Health.
ia« Capitol Hill Bulldlnf. Naehvtlle. TV
Knox County Department of Air Pollution.
City/County Bulldlnf. Room LJ22. 400
Main Avenue. KnoivlUe, TN J1902.
Air PoUuUon Control Bureau, Metropolitan
Health Department, all 2Jrd Avenue
North. Nashville. TO J1201.
IBS) Stale of Tcxaa. Texas Air Conlrol
Board. MIO Utf hway aoo East. Austin. TX
11121.
(TT) State of Utah. Department ol
Health, Bureau of Air Quality, 2B« North
14M West, P.O. Box IHW. Salt Lake City.
OTf4lll— OfM.
EoiToalu. NOR; For a table Itstlnf Region
Vlir* NSPS delegation status, see para
graph (c) of till* section.
(UUI State of Vermont: Vermont Afency
of Environmental Conservation. Air Pollu-
tion Control. Stale Office Building. Montpe
Her, VTOKfOa.
216
Environmental Protection Agency
(W) Commonwealth of Virginia. Virginia
Sl.lt Air Pollution Control Board. Room
1109. Ninth Street Office Bulldlnf. Rich-
mond. VA 2121B.
(WWXII Walhlntton: State of Washing
ton. Department of Ecology. Olympta, WA
SBSOi
111) Northwest Air Pollution Aulhorlly.
201 Pioneer Building. Second and Pine
Streets. Mounl Vemon. WA tflll.
till) Puget Sound Air Pollution Control
Agency. 200 West Mercer Street. Room 209.
Seattle. WA Bolls-jes«
(Iv) Spokane County Air Pollution Control
Authority. North 111 Jefferson. Spokane.
WABB20I.
(v) Southwell Air Pollution Control Au-
lhorlly. Sulle 1901 H. NE Haul Dell
Avenue. Vancouver. WA »ttt.
(vl) Olympic Air Pollution Control Au-
thority. 120 East State Avenue, Olympla.
WA B8501
(vll) [Reserved)
(vlll) Benton Franklin-Walla Walla Coun-
ties Air Pollution Conlrol Authority. 850
§604
Oeorfe Washington Wsy Rlchland WA
BB352
CCX) Stale of West Virginia Air Pulluilon
Conlrol Commission. 1558 Washington
Street East. Charleston. WV 2i311
(YY) Wisconsin—Wisconsin Department
of Natural Resources. PO Box 1B21. Madl
son. W1 91101
(ZZ) Slate of Wyoming. Department of
Environmental Quality. Air Quality Olvl
•Ion. Herschler Building. 122 West 25lh
Slreel. Cheyenne. WY 02002
EoiToaiu. NOTK: For a lable listing Region
VIU'S NSPS delefellort Itslui. see (isis
graph (c) of this section.
(AAA) Territory of Ouam Ouam Envlrun-
menial Protection Afency. Post Office Box
2BBB. Afana. Guam B9BIO
(1) The followlnf lable lists the specific
source and pollutant categories that have
been delegated la the air pollution control
agency In Ouam. A star I') b used to hull
cate each category that has been delegated
217
-------
§60.4
40 CFR Ch. I (7-1-90 Edition)
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roeall Fuel Fired Stau
Generating Unlta
Electric Utility Stea»
Generating Unlta
Conatructed After _9/18/78
Nitric Acid Plane*
Sulfurlc Acid Plante
Aefhalt Concrete Plant*
Storage Vaaaal* for
tatroleuaj Liquid*
Conatruct«d After
6/11/73 Prior to J/J S^78
Storage Vea**la for
Patroleuaj Liquid*
Conatructed After 5/U/78
tacoodarr Laad Sfteltera
Secondary Braaa and Bronte
Inftot Production
Sawae^a Treatment Plante
'rlatary Copper S*i«*tar*
'riaary L«*d Sajalt*ra
Primary AlualDua
Reduction Plant*
Fhoaphate Partiliier
Phoaphorlc Acid Plant*
Phoaphat* Fartilicar
indue try i Super
Phoaphoric Acid Plant*
Phoiphata rartlllver
nduetry ; OiaavoaiuM
•ho*phata Plant
Phoaphata Fertlliier
nduetry: Triple
hoaphate Fartillier
nduvtrjr: Granular
rlpla Super Fhoaph*t*
torai* Facllitlea
oel Preparation Plant*
trralloy Production
acllitic*
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218
Environmental Protection
§60.4
DCLCCATION STATUS Or
NCU souict rtumutAW.r. STANDAUiS(NSrs)
AIH
rOLLUTIOK
CONTtOL
ACCNCY
POLI.UTAMT
CATICOX
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(BBB) Commonwealth of Puerto Rico:
Commonwealth of Puerto Rico Environ-
menUJ Quality Board, P.O. Box 1H88. San-
turce. PR 00010, Attention: Air QuaJltjr
Area Director
-------
§60.5
40 CFR Ch. I (7-1-90 Edition)
OeLEGATION STATUS OF NEW SOURCE PEH^ORMANCE STANDARDS—Continued
HhSPSi to <*«wn VIM)
Si.i*
co "~ *~
ea K»fi puip n*i . ....
CC GUM maVM4*c*«tna ptanu.
EE Suffice* au*ng ol trwut Itstn
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lo«ri
RA PIMM* Mntf*« Up* anrf tab*. wrlM jspm*M.i (MM ol VOC in p-vMaWn i
HHH SyntTMK MMr prodsjcfcn
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ILL Omhot* ncRstttl QM pcocsMswie; SIX •*»•*irccllnf 1 10.4 Iff the LUt ol CFR
Section* Affected fcppetrlnc In III* Finding
Aid* lection of thla volume.
I SO 6 Determination of construction or
modification.
(a) When requested to do 10 by an
owner or operator, the Administrator
will make a determination of whether
action taken or Intended to be taken
by such. owner or operator constitutes
construction (Including reconstruc-
tion) or modification or the com-
mencement thereof within the mean-
Ing of this part.
(b> The Administrator will respond
to any request for a determination
under paragraph (a) of this section
within 30 days of receipt of such re-
quest.
140 PR SS41S. Dec. IS. IdlSl
I «0.i Review of plan.
(a) When requested to do so by an
owner or operator, the Administrator
will review plans for construction or
modification for the purpose of pro
220
Environmental Protection Agency
vldlng technical advice to the owner or
operator
(bull A separate request shall be
submitted for each construction or
modification project.
(2) Each request shaJl Identify the
location of such project, and be accom-
panied by technical Information de-
scribing the proposed nature, size,
design, and method of operation of
each affected facility Involved In such
project. Including Information on any
equipment to be used for measure
ment or control of emissions.
(c> Neither a request for plans
review nor advice furnished by the Ad-
ministrator In response to such re-
quest shall (1) relieve an owner or op-
erator of legal responsibility for com-
pliance with any provision of this part
or of any applicable Slate or local re-
quirement, or (2) prevent the Adminis-
trator from Implementing or enforcing
any provision of this part or taking
any other action authorized by the
Act.
13D FR 14171. Dec. 2]. It'll, ai amended at
39 FR (114. Mar. I. 1614]
I 60.7 Notification and record keeping.
(a) Any owner or operator subject to
the provisions of this part shall fur-
nish the Administrator written notifi-
cation as follows:
(1) A notification of the dale con-
struction (or reconstruction as defined
under I 90.15) of an affected facility Is
commenced postmarked no later than
30 days after such dale. This require-
ment shall not apply In the case of
mass-produced facilities which are
purchased In completed form.
(2) A notification of the anticipated
date of Initial startup of an affected
facility postmarked not more than 80
days nor less than 30 days prior to
such date.
(3) A noimcatlon of the actual date
of Initial startup of an affected facility
postmarked within 15 days after such
dale.
(4) A notification of any physical or
operallonal change to an existing fa-
cility which may Increase the emission
rale of any air pollutant to which a
standard applies, unless that change Is
specifically exempted under an appli-
cable subpart or I'n 180.HM
else nature of the change, present urnl
proposed emission control systems.
productive capacity of the facility
before and after the change. aJid the
expected completion date of the
change. The Administrator may re-
quest additional relevant liiformailun
subsequent to this notice.
(5) A notification ol Ihe dale upon
which demonstration of the contliiu
ous monitoring system performance
commences In accordance with
|60.13(cl. Notification shall be l.osl
marked not less than 30 days prior to
such date.
(«) A notification of the anticipated
date for conducting the opacity obscr
vatlons required by J flO.llleKll uf
this part. The notification shall also
Include, If appropriate, a request (or
the Administrator to provide a visible
emissions reader during a performance
test. The notification shall be post
marked not less than 30 days prior to
such date.
(7) A notification that continuous
opacity monitoring system data results
will be used to determine compliance
with the applicable opacity standard
during a performance test required by
I 60.8 In lieu of Method 9 observation
data as allowed by I 60.1 l(e)<5) of this
part. This notification shall be post-
marked not less than 30 days prior lo
the date of the performance lest.
(b> Any owner or operator subject to
the provisions of this part shall main-
tain records of the occurrence and du-
ration of any startup, shutdown, or
malfunction In the operation of an af
fected facility: any malfunction of the
air pollution control equipment; or
any periods during which a continuous
monitoring system or monitoring
devtce Is Inoperative.
(c) Each owner or operator required
to Install a continuous monitoring
system shall submit a written report
of excess emissions (as defined In ap-
plicable subparlsl lo Ihe Admlnlslra
lor for every calendar quarter. All
quarterly reports shall be postmarked
by the 30th day following the end of
each calendar quarter and shall In
elude Ihe following Information:
221
-------
§60.8
il) The magnitude ol excess emls
slons computed In accordance with
leOOIh). any convenlon laclor(s)
used, and the dat« and lime ot com-
mencement and completion of each
tune period of excess emissions.
(2) Specific Identification of each
period of excess emtulona that occun
during ilartupa. ihuldownj. and mat-
functions of the affected loclllty. The
naturt and cause of any malfunction
(If known), the corrective action Uken
or prevenlntlve measure* adopted.
(3) The date and tune Identifying
each period during which the continu-
ous monitoring system was Inoperative
except for zero and span cheek* and
the nature of the system repair* or ad-
justments.
(4) When no excels emissions have
occurred or the continuous monitoring
system(s) have not been Inoperative.
repaired, or adjusted, such Informa-
tion shall be stated In the report.
• PR «1I4. Mar 8. 1(74: 43 PR 17136. Nov.
'. l»77: 44 PR 9JJI3. June II. Hit; 54 FR
•««3 Ftb 14. I BBS. 64 FR 31344 May 17.
III9I
(609 A'.IUbilHv at Informatuin
The avallBblllly lo tin- imlilli- "I In
formation provided to. or otherwise
obtained by. the Administrator under
this part shall be governed by pari 2
of this chapter < Information submit
led voluntarily to (lie Administrator
(or the purposes of It 60 5 and 60 6 Is
governed by II 2 201 through 2 213 of
this chapter and not by I 2 301 of llils
chapter.)
KO.IO SUle aulhurlly.
The provisions of this part shall not
be construed In any manner to pre-
clude any State or political subdivision
thereof from:
(a) Adopting and enforcing any
emission standard or limitation appll
cable to an affected facility, provided
that such emission standard or llrnlla
tlon Is not leas stringent than I he
standard applicable lo such facility
(b) Requiring the owner or operator
of an affected facility to obtain per-
mits. licenses, or approvals prior to Ini-
tialing construction, modification, or
operation of such facility.
86011 Compliance with >Und»idi and
maintenance requirements
(a) Compliance with standards In
this part, other than opacity stand
ards. shall be determined only by per
fonnance tests established by I 60 8.
unless otherwise specified In the appll-
cable standard.
(b) Compliance with opacity stand
ards In this part shall be determined
by conducting observations In accord
ance with Reference Method 9 In Ap
pendlx A of this part, any alternative
method that U approved by the Ad
mlnlslrator. or as provided In para-
graph (e>(5) of this Section For pur
poses of determining Initial compll
ance. the minimum total lime of ob-
servations shall be 3 hours (30 a
minute averages) for the performance
test or other set of observations
(meaning those fugitive-type emission
sources subject only to an opacity
standard).
(c) The opacity standards set forth
In this part shall apply al all tlinjjs
excepl during periods of startup, shut
down, malfunction, and as otherwise
provided In the applicable standard
223
-------
§60.11
40 CFR Ch. I (7-l790 Edition)
(d) At all limes. Including periods o(
startup, shutdown, and malfunction.
owner? and operators shall, to the
extent practicable, maintain and oper-
ate any affected facility Including as-
•oclated air pollution control equip-
ment In a manner consistent with
good air pollution control practice for
minimizing emission*. Determination
of whether acceptable operating and
maintenance procedures are being
used will be bued on Information
available to the Administrator which
may Include, but Is not limited to,
monitoring results, opacity observa-
tions. review of operating and mainte-
nance procedures, and Inspection of
the source.
(eKl) For the purpose of demon
strallng Initial compliance, opacity ob-
servations (hall be conducted concur-
rently with the Initial performance
test required In I 60.8 unless one of
the following condition* apply. If no
performance teat under 1 00.8 I* re-
quired, then opacity observations shall
be conducted within 40 day* after
achieving the maximum production
rale at which the affected facility will
be operated but no later than 180 day*
after Initial startup of the facility. II
visibility or other condition* prevent
the opacity observation* from being
conducted concurrently with the Ini-
tial performance test required under
I 80.8, the lource owner or operator
shall reschedule the opacity observa-
tions as soon after the Initial perform-
ance test as possible, but not later
than 30 day* thereafter, and shall
advise the Administrator of the re-
scheduled date. In these case*, the 30-
day prior notification to the Adminis-
trator required In 1 80.7(aM6> shall be
waived. The rescheduled opacity ob-
servations (hall be conducted (to the
extent possible) under the aame oper-
ating condition* that existed during
the Initial performance teat conducted
under I 80.8. The visible emissions ob-
server shall determine whether visibil-
ity or other condition* prevent the
opacity observations from being made
concurrently with the Initial perform-
ance test In accordance with proce-
dure* contained In Reference Method
• of Appendix B of this part. Opacity
readings of portions of plume* which
contain condensed, uncomblned water
vapor shall not be used for purposes or
determlng compliance with opacity
standards. The owner or oper&lor uf
an affected facility shall make avail-
able. upon request by the Administra-
tor, such records as may be necessary
to determine the conditions under
which the visual observations were
made and shall provide evidence Indi-
cating proof of current visible observer
emission certification. Except as. pro-
vided In paragraph (eKS) of this sec-
tion. the result* of continuous moni-
toring by transmlssomeler which Indi-
cate that the opacity at the time
visual observations were made was not
In excess of the standard are probative
but not conclusive evidence of the
actual opacity of an emission, provided
that the source shall meet the burden
of proving that the Instrument used
meets (at the time of the alleged viola-
tion) Performance Specification I In
Appendix B of this part, has been
properly maintained and (at the time
of the alleged violation) that the re-
suiting data have not been altered In
any way.
<2> Except a* provided In paragraph
(e)(3) of this section, the owner or op-
erator of an affected facility to which
an opacity standard In this part ap-
plies shall conduct opacity observa-
tion* In accordance with paragraph (b)
of this section, (hall record the opaci-
ty of emission*, and (hall report to the
Administrator the opacity results
along with the result* of the Initial
performance test required under
1 60.8. The Inability of an owner or op-
erator to secure a visible emissions ob
server (hall not be considered a reason
for not conducting the opacity obser-
vations concurrent with the Initial per-
formance teat.
(3) The owner or operator of an af-
fected facility to which an opacity
standard In this part applies may re-
quest the Administrator to determine
and to record the opacity of emissions
from the affected facility during the
Initial performance test and at such
times as may be required. The owner
or operator of the affected facility
•hall report the opacity results. Any
request to the Administrator to deter
mine and to record the opacity of
emission* from an affected facility
shall be Included In the notification
224
Environmental Protection Agency
§ 60 II
required In I 60 1(a>(6> If. for some
reason, the Administrator cannot de-
termine and record the opacity of
emissions from the affected facility
during the performance test, then the
provisions of paragraph (eXl) of this
section shall apply.
(4) An owner or operator of an af-
fected facility using a continuous
opacity monitor (transmlssometer)
shall record the monitoring data pro-
duced during the Initial performance
test required by | 60.8 and (hall fur-
nish the Administrator a written
report of the monitoring results along
with Method 8 and I 60.8 performance
test results.
(&) An owner or operator of an at
(ected facility subject to an opacity
standard may submit, for compliance
purposes, continuous opacity monitor-
Ing system (COM3) data results pro-
duced during any performance test re-
quired under I 60.8 In lieu of Method t
observation data. If an owner or opera-
tor elects to submit COM3 data for
compliance with the opacity standard,
he shall notify the 'Administrator of
that decision. In writing, at least 30
days before any performance test re-
quired under | 60.8 Is conducted. Once
the owner or operator of an affected
facility has notified the Administrator
to that effect, the COMS data result*
will be used to determine opacity com-
pliance during subsequent tests re-
quired under I 60.8 until the owner or
operator notifies the Administrator. In
writing, to the contrary. For the pur-
pose of determining compliance with
the opacity standard during a per-
formance test required under 1 80.8
using COMS daU, the minimum total
time of COMS data collection shall be
averages of all 6-mlnute continuous
periods within the duration of the
mas* emission performance test. Re-
sults of the COM3 opacity determina-
tions shall be submitted along with
the results of the performance test re-
quired under 1 60.8. The owner or op-
erator of an affected facility using a
COMS for compliance purposes Is re-
sponsible for demonstrating that the
COMS meets the requirements speci-
fied In | 60.13(c) of this part, that the
COMS has been properly maintained
and operated, and that the resulting
data have not been altered In any way.
If COMS data results are Mibiiill
for compliance with the opacity :
ard for a period of lime dnrtng <
Method 9 data Indicates noni.oiu
ance. the Method 9 data will be u ed
to determine opacity compliance.
(6) Upon receipt from an owner or
operator of the written reports of the
results of the performance tests re
quired by | 60.6. the opacity observa-
tion results and observer certification
required by |60.ll(e)(l). and the
COMS results. If applicable, the Ad-
ministrator will make a finding con-
cerning compliance with opacity and
other applicable standards If COMS
data results are used to comply with
an opacity standard, only those results
are required to be submitted along
with the performance test results re-
quired by | 60.B. If the Administrator
finds that an affected facility Is In
compliance with all applicable stand
ards for which performance tests are
conducted In accordance with I 60.8 of
this part but during the time such per
formance tests are being conducted
falls to meet any applicable opacity
standard, he shall notify the owner or
operator and advise him that he may
petition the Administrator within 10
days of receipt of notification to make
appropriate adjustment to the opacity
standard for the affected facility.
(7) The Administrator will grant
such a petition upon a demonstration
by the owner or operator that the af
fected facility and associated air pollu
tlon control equipment was operated
and maintained In a manner to mini-
mize the opacity of emissions during
the performance tests; that the per-
formance tests were performed under
the conditions established by the Ad-
ministrator; and that the affected fa-
cility and associated air pollution con-
trol equipment were Incapable of
being adjusted or operated to meet the
applicable opacity standard.
(8) The Administrator will establish
an opacity standard for the affected
facility meeting the above require
menU at a level at which the source
will be able, as Indicated by the per
formance and opacity tests, to meet
the opacity standard at all limes
during which the source Is meeting
the mass or concentration emission
standard. The Administrator will pro-
225
-------
>
-•4
§60.12
mutate the new opacity standard In
the FEDERAL REGISTER
(() Special provision* set forth under
an applicable subpart of this part shall
supersede any conflicting provisions of
this section.
[IB FR mas. Oct. IS. 191}. u amended at
19 FR 1911}. Nov. 12. 1914: 41 PR 1*00. Mar.
1. I9TI: 49 FR 13119. Apr. 4. 1910; «8 FR
48335. Oct. II. 1983: SO FR 11113. Dec. 11.
1085: SI PR 1190. Jan. It. lilt. S3 FR »1I1.
Mar. 28. 19«1I
0 60.12 Circumvention.
No owner or operator subject to the
provisions of this part shall build,
erect. Install, or use any article, ma-
chine, equipment or process, the use of
which conceals an emission which
would otherwise constitute a violation
of an applicable standard. Such con-
cealment Includes, but ls not limited
to. the use of gaseous diluents to
achieve compliance with an opacity
standard or with a standard which Is
based on the concentration of a pollut-
ant In the gases discharged to the at-
mosphere.
119 FR 9114. Mar. 1.19141
0 60.13 Monitoring requirements.
(a) For the purposes of this section.
«JI continuous monitoring systems re-
quired under applicable subparU shall
be subject to the provisions of this sec-
tion upon promulgation of perform-
ance specifications for continuous
monitoring systems under Appendix B
to this part and. If the continuous
monitoring system Is used to demon-
strate compliance with emission limits
on a continuous basis. Appendix P to
this part, unless otherwise specified In
an applicable subpart or by the Ad-
ministrator. Appendix F U applicable
December «. 1087.
(b) All continuous monitoring sys-
tems and monitoring devices shall be
Installed and operational prior to con-
ducting performance tests under
160 8. Verification of operational
status shall, as a minimum. Include
completion of the manufacturer's writ-
ten requirements or recommendations
(or Installation, operation, and calibra-
tion of the device.
(Oil the owner or operator of an af-
fected facility elects to submit contln-
ous opacity monitoring system
40 CFR Ch. I (7-1-90 Edition)
(COMS) data for compliance with the
opacity standard as provided under
|60.1l(e>(5). he shall conduct a per-
formance evaluation of the COMS u
specified In Performance Specification
1. Appendix B. of this part before the
performance tut required under I 60 8
Is conducted. Otherwise, the owner or
operator of an affected facility shall
conduct a performance evaluation of
the COMS or continuous emission
monitoring system (CEMS) during any
performance test required under | 80.8
or within 30 days thereafter In accord-
ance with the applicable performance
specification In Appendix B of this
part. The owner or operator of an af-
fected facility shall conduct COMS or
CEMS performance evaluations at
such other times as may be required
by the Administrator under section
114 of the Act.
(1) The owner or operator of an af-
fected facility using a COMS to deter-
mine opacity compliance during any
performance test required under I 80.8
and as described In |60 ll(el(5) shall
furnish the Administrator two or.
upon request, more copies of a written
report of the results ol the COMS per-
formance evaluation described In para-
graph (c) of this section at least 10
days before the performance test re-
quired under | 60.8 Is conducted.
(2) Except as provided In paragraph
(c)(l) of this section, the owner or op-
erator of an affected facility shall fur-
nish the Administrator within 80 days
of completion two or, upon request.
more copies of a written report of the
results of the performance evaluation.
(did) Owners and operators of all
continuous emission monitoring sys-
tems Installed In accordance with the
provisions of this part shall check the
zero (or low-level value between 0 and '
20 percent ol span value) and span (60
to 100 percent of span value) calibra-
tion drifts at least once dally In ac-
cordance with a written procedure.
The zero and span shall, as a mini-
mum, be adjusted whenever the 24
hour zero drift or 24-hour span drift
exceeds two times the limits of the ap-
plicable performance specifications In
Appendix B. The system must allow
the amount of excess zero and span
drift measured at the 24 hour Interval
checks to be recorded and quantified.
Environmental Protection Agency
whenever specified. For continuous
monitoring systems measuring opacity
ol emissions, the optical surfaces ex-
posed to the effluent gases shall be
cleaned prior to performing the zero
and span drift adjustments except
that for systems using automatic zero
adjustments. The optical surfaces
shall be cleaned when the cumulative
automatic zero compensation exceeds
4 percent opacity.
12) Unless otherwise approved by the
Administrator, the following proce-
dures shall be followed for continuous
monitoring systems measuring opacity
of emissions. Minimum procedures
shall Include a method for producing a
simulated zero opacity condition and
an upscale (span) opacity condition
using a certified neutral density filter
or other related technique to produce
a known obscuration of the light
beam. Such procedures shall provide a
system check of the analyzer Internal
optical surfaces and all electronic cir-
cuitry Including the lamp and photo-
detector assembly.
(e) Except for system breakdowns,
repairs, calibration checks, and zero
and span adjustments required under
paragraph (d) of this section, all con-
tinuous monitoring systems shall be In
continuous operation and shall meet
minimum frequency of operation re-
quirements as follows:
(1) All continuous monitoring sys-
tems referenced by paragraph (c) of
this section for measuring opacity of
emissions shall complete a minimum
of one cycle of sampling and analyzing
(or each successive 10 second period
and one cycle of data recording (or
each successive 8 minute period.
(2) All continuous monitoring sys-
tems referenced by paragraph (c) of
this section for measuring emissions,
except opacity, shall complete a mini-
mum of one cycle of operation (sam-
pling, analyzing, and data recording)
for each successive 15-mlnute period.
((I All continuous monitoring sys-
tems or monitoring devices shall be In-
stalled such that representative meas-
urements of emissions or process pa-
rameters from the affected facility are
obtained. Additional procedures for lo-
cation of continuous monitoring sys-
Icins contained In the applicable Per-
§60 13
formance Specifications of ApptTKltx
B o( this part shall be used
(g) When the effluents from a single
affected facility or two or more ailed
ed facilities subject to the same emis-
sion standards are combined before
being released to the atmosphere, the
owner or operator may Install applica-
ble continuous monitoring systems on
each effluent or on the combined el
fluent. When the affected facilities are
not subject to the same emission
standards, separate continuous moni-
toring systems shall be Installed un
each effluent. When the effluent (rom
one affected facility Is released to the
atmosphere through more than one
point, the owner or operator shall In
stall an applicable continuous moni-
toring system on each separate eftlu
ent unless the Installation of (ewer
systems Is approved by.the Atlmlnls
trator. When more than one contlnu
oils monitoring system Is used to meas
ure the emissions from one affected
facility (e.g., multiple breechlngs. mul
tfple outlets), the owner or operator
shall report the results as required
from each continuous monitoring
system.
(h) Owners or operators o( all con
tlnuous monitoring systems for meas
urement of opacity shall reduce all
data to fl minute averages and for con-
tinuous monitoring systems other
than opacity to 1-hour averages for
time periods as defined In I 80 2. Six
minute opacity averages shall be cal-
culated from 38 or more data points
equally spaced over each 6 minute
period. For continuous monitoring sys-
tems other than opacity. 1-hour aver-
ages shall be computed from four or
more data points equally spaced over
each 1-hour period. Data recorder
during periods of continuous monitor-
ing system breakdowns, repairs, call
bratlon checks, and zero and span ad
justments shall not be included In the
data averages computed under thlj
paragraph. An arithmetic or Integrat-
ed average of all data may be used
The data may be recorded In reduced
or nonreduced form (e g.. ppm pollut-
ant and percent O. or ng/J of pollut
ant). All excess emissions shall be con
verted Into units of the standard usuig
the applicable conversion procedures
specified In subparts After conversion
226
221
-------
oo
§60.13
utlo units of the standard, the data
may be rounded to the came number
of significant digits as used In Hie ap
pllcable subparts to specify the emis-
sion limit (e.g.. rounded to the nearest
1 percent opacity).
(I) Alter receipt and consideration of
written application, the Administrator
may approve alternative* to any moni-
toring procedures or requirements of
this part Including, but not limited to
the-following:
(I) Alternative monitoring require-
ments when Installation of • continu-
ous monitoring system or monitoring
device specified by this part would not
provide accurate measurements due to
liquid water or other Interference*
caused by substances with the effluent
gases.
(2) Alternative monitoring require-
ments when the a/reeled facility Is In-
frequently operated.
(3) Alternative monitoring require-
ments to accommodate continuous
monitoring systems that require addi-
tional measurements to correct (or
stack moisture condition!.
(4) Alternative locations for Install-
ing continuous monitoring systems or
monitoring devices when the owner or-
operator can demonstrate that Instal-
lation at alternate location* will
enable accurate and representative
measurements.
(5) Alternative method* of convert-
Ing pollutant concentration measure-
ments to unlU of the standards.
(6) Alternative procedures lor per-
forming dally checks of icro and span
drift that do not Involve use of »pan
gases or test cells.
(7) Alternatives to the A.S.T.M. test
methods or sampling procedures speci-
fied by any subpart.
(8) Alternative continuous monitor-
Ing systems that do not meet the
design or performance requirements In
Performance Specification 1, Appen-
dix B. but adequately demonstrate a
definite and consistent relationship
between Its measurements and the
measurements of opacity by a system
complying with the requirement* In
Performance Specification 1. The Ad-
ministrator may require that such
demonstration be performed for each
affected facility.
40 CFR Ch I (7-1-90 tdilion)
(9) Alternative monitoring require-
ments when the el fluent from a single
affected facility or the combined efflu
enl from two or more affected facili-
ties are released to the atmosphere
lluough more than one point.
(|) An alternative to the relative ac
curacy test specified In Performance
Specification 2 of Appendix B may be
requested as follows;
(1) An alternative to the reference
method tests for determining relative
accuracy Is available for sources with
emission rale* demonstrated to be less
than SO percent of the applicable
standard. A source owner or operator
may petition the Administrator to
waive the relative accuracy lest In sec-
tion 1 of Performance Specification 2
and substitute the procedures In sec-
tion 10 If the results of a performance
test conducted according to the re-
quirements In I 40.6 of this subpart or
other testa performed following the
criteria In I f 0.8 demonstrate thai the
emission rale of the pollutant of Inter-
est In the unit* of the applicable
standard Is less than 60 percent of the
applicable standard. For sources sub-
ject to standards expressed as control
efficiency level*, a source owner or op-
erator may petition the Administrator
to waive the relative accurancy test
and substitute the procedures In sec-
tion 10 of Performance Specification 2
If the control device exhaust emission
rate Is less than 50 percent of the level
needed to meet the control efficiency
requirement. The alternative proce-
dure* do not apply If the continuous
emission monitoring system-Is used to
determine compliance continuously
with the applicable standard. 1'he pe-
tition to waive the relative accurancy
lest shall Include a detailed descrip-
tion of the procedures to be applied.
Included shall be location and proce-
dure for conducting the alternative.
the concentration or response levels of
the alternative RA materials, and the
other equipment checks Included In
the alternative procedure. The Admin
Utrator will review the petition for
completeness and applicability. The
determination to grant a waiver will
depend on the Intended use of the
CEMS data (e.g.. data collection pur-
poses other than NSPS) and may re-
quire specifications more stringent
Environmental Protection Agency
lhan In Performance Specification 2
(e t. the applicable emission limit Is
more stringent than NSPS).
(21 The waiver of a CEMS relative
accuracy test will be reviewed and may
be rescinded at such time following
successful completion of the alterna-
tive RA procedure that the CEMS
data Indicate the source emissions ap-
proaching the level of the applicable
standard. The criterion for reviewing
the waiver Is the collection of CEMS
data showing that emissions have ex-
ceeded TO percent of the applicable
standard tor seven, consecutive, aver-
aging periods as specified by the appli-
cable regulatlon(s). For sources sub-
ject to standards expressed as control
efficiency levels, the criterion for re-
viewing the waiver Is the collection of
CEMS data showing that exhaust
emlssons have exceeded 70 percent of
the level needed to meet the control
efficiency requirement for seven, con-
secutive, averaging periods as specified
by the applicable regulation^) [e.g.,
I «0.45(g> <2> and (3). I (0.73(0. and
I 80 8«(e>] It Is the responsibility of
the source operator to maintain
records and determine the level of
emissions relative to the criterion on
the waiver of relative accuracy testing.
If this criterion Is exceeded, the owner
or operator must notify the Adminis-
trator within 10 days of such occur-
rence and Include a description of the
nature and cause of the Increasing
emissions. The Administrator will
review the notification and may re-
scind the waiver and require the
owner or operator to conduct a rela-
tive accuracy test of the CEMS as
specified In section 7 of Performance
Specification 2.
140 FR 40295. Oct. B. 1B16; 40 FR 69305.
Dec 1J. IBIS, u amended at 41 PR J6IB6.
Aui 20. 1*7*: 41 FR l»3t. Mar. JO. lt»: 41
PR 33810. M»y 15. lilj; 41 PR »*•>. July
20 1911; (I PR 91»J, Mar. 18. 11*1: M PR
17351. May II. IM7: 51 FR 21007, June 4.
iern
t«U4 Modification.
(a) Except u provided under para-
graphs (e) and (f) of this section, any
physical ur operational change to an
existing facility which results In an In-
crease In the emission rale to the at-
mosphere of any pollutant to which a
§60.14
standard applies shall be considered u
modification within the meaning <•!
section 111 of the Act Upon moilllli"
tlon. an existing facility shall heroine
an affected facility for each pollution
to which a standard applies and l->r
which there Is an Increase In the emis-
sion rate to the atmosphere
(b) Emission rale shall be expressed
as kg/hr of any pollutant discharged
Into the atmosphere for which a
standard Is applicable. The Admlnls
tralor shall use the following lo deter
mine emission rate:
(1) Emission factors as specified In
the latest Issue of "Compilation of Air
Pollutant Emission Factors." EPA
Publication No. AP-42. or other emls
slon factor* determined by the Admln-
Islralor to be superior to AP-42 emis-
sion factors. In cases where utilization
of emission factors demonstrate that
the emission level resulting from the
physical or operational change will
either clearly Increase or clearly not
Increase.
(2> Material balances, continuous
monitor data, or manual emission tests
In cases where utilization of emission
factors as referenced In paragraph
(b)(l> of this section does not demon-
strate to the Administrator's sallsfac
tlon whether the emission (evel result-
ing from the physical or operational
change will either clearly Increase or
clearly not Increase, or where an
owner or operator demonstrates lo the
Administrator's satisfaction that there
are reasonable grounds to dispute the
result obtained by the Administrator
utilizing emission (actors as referenced
In paragraph (bid) of this section.
When the emission rate Is based on re-
sults from manual emission tests or
continuous monitoring systems, the
procedures specified In Appendix C of
this parl shall be used to determine
whether an Increase In emission rate
has occurred. Tests shall be conducted
under such conditions as the Admlnls-
Iralor shall specify to the owner or op
erator based on representative per-
formance of the facility. At least three
valid tesl runs must be conducled
before and at least three after the
physical or operational change. All op-
erating parameters which may affect
emissions must be held constant lo the
228
229
-------
>
(D
§60.15
maximum feasible degree (or all leu
run*.
(c) The addition of an t/fecled facili-
ty to a stationary source u an expan-
sion to that source or u a replacement
for an existing facility shall not by
Itself bring within the applicability of
this pan any other facility within that
source.
(d) (Reserved)
(e) The following shall not, by them
selyes. be considered modification*
under this part:
(1) Maintenance, repair, and replace-
ment which the Administrator deter-
mines to be routine (or a source cate-
gory, subject to the provisions of para-
graph (0 of this section and I 60.15.
(2) An Increase In production rate of
an existing facility. U that Increase
can be accomplished without a capita]
expenditure on that facility.
(3) An Increase In the hours of oper-
ation.
(4) Use of an alternative fuel or raw
material If. prior to the date any
standard under this part becomes ap-
plicable to that source type, as provid-
ed by | 60.1. the existing facility was
designed to accommodate that alterna-
tive use. A facility shall be considered
to be designed to accommodate an al-
ternative fuel or raw material If that
use could be accomplished under the
facility's construction specifications as
amended prior to the change. Conver-
sion to coal required for energy consid-
erations, as specified In section
lll(a)(8) of the Act. shall not be con-
sidered a modification.
(5) The addition or use of any
system or device whose primary func-
tion Is the reduction of air pollutants.
except when an emission control
system 1* removed or la replaced by a
system which the Administrator deter-
mines to be leas environmentally bene-
ficial.
(8) The relocation or change In own-
ership of an existing facility.
(f > Special provisions set forth under
an applicable aubpart of this part shall
supersede any conflicting provisions of
this section.
(g) Within 180 day* of the comple-
tion of any physical or operational
change subject to the control meas-
ures specified In paragraph (a) of this
40 CFR Ch. I (7-1-90 tdlllon)
section, compliance with all applicable
standards must be achieved
140 FR (Kit. Dec. It. IBID, amended » 43
FR 34347. Au| 3. IBIS. 45 PR 9611, Jin 13.
|B«0)
IfO.lD Rccontlrucllon.
(a) An existing facility, upon recon-
struction, becomes an affected facility.
Irrespective of any change In emission
rale.
(b) "Reconstruction" means the re-
placement of components of an exist-
ing facility to such an extent that:
(1) The fixed capital cost of the new
component* exceeds 50 percent of the
fixed capital cost that would be re-
quired to construct a comparable en-
tirely new facility, and
(2) It Is technologically and economi-
cally feasible to meet the applicable
standards set forth In this part.
(c) "Fixed capital cost" means the
capital needed to provide all the de-
preciable components.
(d) If an owner or operator of an ex-
isting facility proposes to replace com-
ponents, and the fixed capital cost of
the new components exceeds 60 per-
cent of the fixed capital cost that
would be required to construct a com-
parable entirely new facility, he shall
notify the Administrator of the pro-
posed replacements. The notice must
be postmarked 60 days (or as soon as
practicable) before construction of the
replacements Is commenced and must
Include the following Information:
(!) Name and address of the owner
or operator.
(2) The location of the existing facil-
ity.
(3) A brief description of the exist-
ing facility and the components which
are to be replaced.
(4) A description of the existing air
pollution control equipment and the
proposed air pollution control equip-
ment.
(5) An estimate of the fixed capital
cost of the replacements and of con-
structing a comparable entirely new
facility.
(6) The estimated life of the existing
facility after the replacements.
<7) A discussion of any economic or
technical limitations the facility may
have In complying with the applicable
Environmental Protection Agency
rlandards of performance after the
proposed replacements.
(e) The Administrator will deter-
mine, within 30 days of the receipt of
the notice required by paragraph (d)
of this section and any additional In-
formation he may reasonably require.
whether the proposed replacement
constitutes reconstruction.
(f) The Administrator's determina-
tion under paragraph (e) shall be
based on:
(1) The fixed capital cost of the re-
placements In comparison 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 compo-
nents being replaced cause or contrib-
ute to the emissions from the facility;
artd
(4) Any economic or technical limita-
tions on compliance with applicable
standards of performance which are
Inherent In the proposed replace-
ments.
(8) Individual subparts of this part
may Include specific provisions which
refine and delimit the concept of re-
construction set forth In this section.
140 FR 5X20. Dec l». IBIS)
06016 Priority ILL
PRIORITIZED MAJOR SOURCE CATEGORIES
CtguMc OOTUI UonAcuttg InOMrf
(SOCUIt ind VoMt Org*/* UMU Sung* »«»-
Mta •ndHtndfeg Equtoiwrt
(•I SOCU1 uril pnuMla
Hi) VobM ogMc 1*M (VOU Uongo .«•••> « Pip«
OyOw*,
{•I PffctikimvVono
(D) PMrotown Mtvwd
OiafMc Afl»
PotrnMra and HMkM. Ao^fc RMOM
Mfcwri Wool (TMMod)
Sutononr Worn*) GofflfeNlon Engtao*
InduattW SuriMO Goovno; Fabric
§60.16
PRIORITIZED MAJOR SOURCE CAteooRits-
Confmuad
Htm tUlOh- Ubwrcl ProoMMng
S«condo/r Coop* ICW*l*d)
Hock piop*r««on
ftnd O»«y fro"
Potrmm and RMbw Po*r«V>rt«n*
|b| SBR preduckn
IndUMW Sw1K» Cocflng M*UI Col
dMn TiMMfxvuton wJ MwlcHng
Br-Pnx)ucl Cofe* Ovwu
InduMW Swlw* Owing
Ciud* Cm And N«M4 CM Production
Socondftry AJun**m
Pourfi (DvMwfl
Aggi«gftl» Induatr CUr. Srwta.
Oypun
Sodium C*t>oml*
Scaandvv 2toc (D«*Md|
*nd R**w. AB&SAN RMbu
A^tfMft ProoMAine and AlpftAfl HooNno
Brtcfc tfA RcUIMl CUy Producu
C«rurtc Clvy UVMtKturtng |D«MIMl)
Saru «nd Bode Add |D»nnd)
and RMln*. PorrMI* RvMna
TMniol Pncu* |D«.ud)
l FMd Datuortnoton (DHMwfl
U
44
M
M
17.
M
LMd odd tenon1 iMrajl«cluro •
InduovW HMtooo cotlno, (MUI (urvlu* •
I low nunfcv* two NgrtoM prtoi*r. • g No. I to N
prtortty. No- BS to tov prtoi*r
2 Fofmoriy Mod ~SMMnfr Chr •"* F*r Atft"
IMkM* •OO'C* oitagonr. Ud Inchxtod on IM emo*
NSPS k» bokw do.ofcjiiod ia Btol MUCO 01*000;
4 Not Drtoffinod. dnc* «n NSPS to M» mftv »ow
230
231
-------
§60.17
147 FR 851, Jut a. 1062. u amended it 47
FR 31810. July 23. 1982. 51 PR 42786. Nov
23. I Ban. 52 FR 11428. Apr B. 1967)
N>
O
060.17 Incorporation! by reference.
The materials listed below are Incor-
porated by reference In the corre-
sponding section* noted. These Incor-
porations by reference were approved
by the Director of the Federal Regis-
ter on the dale listed. These materials
are^ Incorporated u they exist on the
date of the approval, and a notice of
any change In these materials will be
published In the Fconuu. REOIITU.
The materials are available for pur-
chase at the corresponding address
noted below, and all are available for
Inspection at the Office of the Federal
Register. Room 1401. 1100 L, Street.
NW. Washington. DC and at the Li-
brary (MLV35), U.S. EPA. Research
Triangle Park. NC.
(a) The following materials are avail-
able /or purchase from at least one of
the following addresses: American So-
ciety for Testing and Materials
(ASTM). 1B18 Race Street. Philadel-
phia. Pennsylvania 10103; or the Uni-
versity Microfilms International. 300
North Zeeb Road. Ann Arbor, Michi-
gan 48106.
(I) ASTM D380-77. Standard Specifica-
tion for Clarification of Coali by Rank. In-
corporation by reference (IBR) approved
January 37. 1983. for 116041(1). 80.46(1X4)
cl). (II). (vl). 60.41s: 60.4lb: 60.251 (b). (c).
(» ASTM D3I7B-13. Standard Test Meth-
ods for Carbon and Hydrogen In the Analy-
tU Sample of Coal and Coke. IBR approved
January 27. lit! for I 60.45(1X5X1).
(3) ASTM D3116-74. Standard Method for
Ultimate Analysis of Coal and Coke. IBR
approved January 27. 1013. for
I60.45UM5XI); Appendix A to part CO.
Method It.
(4) ASTM DM31-6J (Reapproved 1011).
Standard Method for Analysis of Natural
Oases and Related Types of Gaseous Mix-
tures by the Mass Spectrometer. IBR ap-
proved January 17. 1983 for I 60 4S(fX6XI).
(6) ASTM DI945-64 (Reapproved »818).
Standard Method for Analysis of Natural
Oas by Gas Chromatoaraphy. IBR ap-
proved January 31. 1083 for |604S(fXSKI)
(11 ASTM DI046-77. Standard Method for
Analysis of Reformed Gas by Gas Chroma
toiraphy. IBR approved for II BO 45(1X5X1).
6016(1). 60 614(dX2XH>. (dX4l. 60664
(dH3XII>and(dX4>.
(1) ASTM D1015-17. standard Test
Method lor Oroaa Calorific Value of Solid
40 CFR Ch. I (7-1-90 Edition)
Fuel by the Adlabatlc Bomb Calorimeter.
IUR approved January 27. 1983 for
16045(1X5X11): 16046(1). Appendix A to
part 60. Method IB.
(8) ASTM DI826-11. Standard Test
Method (or Calorific Value of Oases In Nsl
Ural Oas Range by Continuous Recording
Calorimeter. IBR approved January 27.
1883. (or || 60.45(1X1X11): 60.46(gl: 60 296(1).
Appendix A to part 60. Method IB
(0) ASTM D240-76. Standard Test Method
for Heal of Combustion of Liquid Hydrocar-
bon Fuels by Bomb Calorimeter. IBR ap
proved January 17. lit}, lor 160.461 g):
«0 396(11: Appendix A to part 60. Method 19.
(10) ASTM D3M-76. Standard Specific.
lion for Fuel Oils. IBR approved January
V\. 1063. for 11 60.tOb; 804lb; 60.11Kb).
•O.lllalb).
(11) ASTM D2660-7B. Standard Specific.
lion for Qas Turbine Fuel Olli. IBR ap-
proved January 27. 1(13 for It ao 11 lib).
so.lllatb). 60.135(bH2>.
(12) ASTM D078-78. Standard Specific.-
lion for Diesel Fuel Oils, IBR approved Jan-
uary 27, 1BI3 for II 60.llllb). 60 lll.lb)
(111 ASTM D31I-83. Test Method for
Vapor Pressure of Petroleum Products
(Reid Method). IBR approved April I. 1917
for 1160111(1). 60.!lla(g). 60 lllb(g). and
601160(1X2X11)
(14) ASTM AB0-76. Standard Specification
for Perromanganese. IBR approved January
27. 1963 for I (0.261.
(15) ASTM A4B3-64 (Reapproved 1974).
Standard Specification for Slllcomanganeae.
IBR.approved January 27. 1B83 for I 60.261.
(16) ASTM A101-13. Standard Specifics
lion for Perrochromlum, IBR approved Jan-
uary 37. 1983 for I 60 261
(17) ASTM A100-60 (Reapproved 1914).
Standard Specification for Ferroslllcon. IBR
approved January 27.1083 for I 60.261.
(II) ASTM A4S3-76. Standard Specifica-
tion lor Perrochromeslllcon. IBR approved
January 37.1013 for 160 J6I.
(19) ASTM A495-76. Standard Specifica-
tion for Calcium-Silicon and Calcium Man-
ganese-Silicon, IBR approved January 27,
1M3 for | 60.361
(10) ASTM D 1073-80. Standard Method
for Total Sulfur In Puel Oases, IBR ap-
proved July 31. 1914 (or I 60.335(6X2).
(21) ASTM D2986-71 (Reapproved 1078).
Standard Method for Evaluation of Air,
Assay Media by the Monodlspene OOP
(Dloclyl Phlhalate) Smoke Test. IBR ap
proved January 27, 1003 for Appendix A to
parl 60. Method 5. par. 3.1.1: Method 12.
par. 4.1.1: Method 17. par. 3.1.1.
(22) ASTM D 1102-77. Standard Specific*
lion for Reagent Waler. Incorporated by
Reference approved January 27. 1BB3. for
Appendix A lo parl 60. Method 6. par. 3 1.1:
Method 1. par. 11.2: Method 7C. par 1.1 I:
Environmental ProUctlon Agency
Method ID. par 3 1.1. Method B. par. 3 1.3:
Method 12. par 4 1.3.
(23) (Reserved)
(341 ASTM D2234-76. Standard Methods
(or Collection of a Gross Sample of Coal.
IBR approved January 21. 1983. for Appen
dl> A U> pan 60. Method IB
(251 ASTM O3173-13. Standard Test
Method for Moisture In the Analysis
Sample of Coal and Coke. IBR approved
January 27, 1B83. for Appendix A lo pan 60.
Method IB.
(26) ASTM D3171-16. Standard Teal
Methods for Total Sulfur In the Analysis
Sample of Coal and Coke. IBR approved
January 21 1963. for Appendix A to part 60.
Method IB.
(27) ASTM D2013-72. Standard Method of
Preparing Coal Samples for Analysts. IBR
approved January 27. 1BB3. for Appendix A
lo pan BO. Method IB
(28) ASTM D210-05 (Reapproved 1916).
Standard Method of Sampling Petroleum
and Petroleum Products. IBR approved Jan-
uary 27. 1BB3. for Appendix A lo pan 10.
Method IB.
(2B> ASTM D737-65. Standard Test
Method for Air Permeability of Textile Fab-
rics. IBR approved January 27. 1B83 for
|«l 331.1.
(30) ASTM DI415-60 (Reapproved 1980).
Standard Test Method (or Density of Paint.
Vamtsh. Lacquer, and Related Products.
IBR approved January 17. IBB3 for
|60.435(d)(l). Appendix A lo pan 60.
Method 34. par. 2.1. and Method 34A. par.
3.2
(31) ASTM D236B-61. Standard Test
Method for Volatile Content of Coatings.
IBR approved January 17. 1B83 for Appen-
dix A lo part 60. Method 24. par. 1.1.
(33) ASTM D31B3-1B. Standard Melhod
lor Waler Contenl of Water Reducible
Paints by Direct Injection Into a Oas Chro-
malograph. IBR approved January 27. 1083
lor Appendix A lo pan 80. Melhod 34. par.
2.3.
(33) ASTM D40I1-6I. Standard Test
Melhod for Waler In Paints and Paint Ma-
terials by the Karl Fischer Ttlntlon
Melhod. IBR approved January 31. 1083 for
Appendlx A to part 60. Method 34. par. 3.4.
(34) ASTM E160-83 (Reapproved 1*11).
General Techniques of Ultraviolet Quanti-
tative Analysis, IBR approved for
I 60.485(d). | 80.9B3(b). and I 60.612(1)
(35) ASTM E168-67 (Reapproved 1071).
. Oeneral Techniques of Infrared Quantita-
tive Analysis. IBR approved for I 60 485(d>.
I 60 693(b). and I 60.832(1).
(36) ASTM E260-13. General Gas Chro-
malography Procedures. IBR approved for
I 60 485(d). | 60 593(b). and | 60 033(1).
(31) ASTM 02810-81. Test Method for
Vapor Pressure—Temperature Relationship
and Initial Decomposition Temperature of
Liquids by tsolenlseope. IBR approved April
§60 17
8. 1967 for 11 80 4651 el. 60 I I Ibi III11.
60.ll6h(e)(3)(ll). and 60 Il6bt(><2»l>
(38) ASTM D2382-16. Heal c.1 Combustion
of Hydrocarbon Fuels by bomb Caluruiieter
IHIgh-Preclslon Methodl. IBH approved fur
|| 60 18(1), «0 485(8). OOeUMlH) and
60B64(d)(4).
(30) ASTM D2S04 81 (Reapproved 1911).
Noncondensable Oases In C, SJid LlglUer
Hydrocarbon Products by Oas Chrooistug
raphy. IBR approved for I 60 485(g>
(40) ASTM O86 76. Distill.tlon of I'elrole
urn Products. IBR approved for |eo5U3idi
and |60.633(h)
(41) (Reserved)
(43) ASTM D 3031 -01. St.iid.sd Teat
Melhod (or Total Sulfur In N.tur.l Ou by
Hydrogenatlon. IBR approved July 31, ID64
for | 60.335(bK2)
(43) ASTM D 4084-82. Standard Method
for Analysts of Hydrogen Sulflde In Gaseous
Fuels (Lead Acetate Reaction R.te
Method). IBR approved July 31. I9B4 for
|60336(b)(l).
(44) ASTM D 3248-81. Standard Method
for Sulfur In Petroleum Oas by Oxldatlve
Mlcrocoulometry, IBR approved July 31.
1064 for I 60.33B(bX2)
(45) ASTM D25B4 68. Standard Teal
Melhod for Ignition Loss of Cured Heln
forced Resins. IBR approved February 25.
1089 lor | 60 665(el.
(46) ASTM D3431-80. Standard Test
Melhod for Trace Nitrogen In Liquid Petro-
leum Hydrocarbons (Mlcrocoulomelrlc
Melhod). IBR approved November 25. 1988.
(or Appendix A to pan 60. Melhod IB
(41) ASTM D12B-64 (reapproved 18181
Standard Test Melhod for Sulfur In Pelrole
. urn Products (Oeneral Bomb Melhod). I11U
approved lor Appendix A lo part 60
Melhod IB
(48) ASTM DI652-83. Standard Test
Method (or Sulfur In Petroleum Products
(High Temperature Method). IBR approved
for Appendix A la part 60. Melhod 10.
(40) ASTM D1B35 88. Standard Specific.
tlon for LJquefled Petroleum (LP) Oases, to
be approved for I 60.41b.
(60) ASTM D3286-85. Standard Test
Melhod for Gross Calorific Value of Coal
and Coke by the Isothermal-Jacket Bomb
Calorimeter. IBR approved for Appendix A
to part 60. Method IB.
(51) ASTM D4051-8I, Standard Practice
for Manual Sampling of Petroleum arid Pe
Iroleum Products, IBR approved for Appen
dlx A to part 60. Melhod 10
(611 ASTM D4230-85. Standard Ten
Methods for Sulfur In the Analysis Sample
of Coal and Coke Using High Temperature
Tube Furnace Combustion Methods. IBR
approved for Appendix A lo part 60
Melhod 10.
(53) ASTM D2016-74 (Reapproved 1983).
Standard Test Methods for Moisture Con
232
213
-------
§60.18
tent of Wood • • • for Appendix A. Method
28
ASTM D4443-64. Standard Tut
Melhodi (or Direct Moisture Content MeaJ-
urement In Wood and Wood-bue
Materials • • • (or Appendli A. Method II.
(55) (Reserved!
ISO) ASTM DI3V-64 (Reapproved l>7a>.
Standard Tttl Method for Sulfur In Petrol*-
um ProducU (General Bomb Method). IBR
approved Auiuit 17. l»tt, (or |«0.10«hk».
1ST) ASTM DIS13-I3. Standard Tat
Method (or Sui/ur In Petroleum ProducU
IHIin-Teaiperalurt Method). IBR approved
Auiuit II. KM. lor | go.lOeihXl).
(58) ASTM 02121-17. Standard Te.l
Method (or Sulfur In Petroleum ProducU
by JC-Ray Spectrometry, IBR approved
Aucust It. tin. (or I 40.104(hXl).
(S»> ASTM DI2(t-S7. Standard Teat
Method (or Sulfur In Petroleum ProducU
(Lamp Method). IBR approved August 17.
(»»». for | (O.KKXhXl).
(b) The following material U avail-
able tor purchase from the Association
of Official Analytical ChemUU. 1111
North 10th Street. Suite 310. Arling-
ton. VA 2230*.
(1) AOAC Method ». Official Method! of
Analyili of the Aaaoclatlon of Official Ana-
lytical ChemUU. llth edition. 1(70. pp. 11-
12. IBR approved January 27. 1M3 tor
H«020«dKl). «0.214(dX3>. 4M).224(dX3).
e0.3341dKl). «0.344(fM3>.
(c) The following material Is avail-
able for purchase from the American
Petroleum Institute. 1220 L Street
NW.. Washington. DC 20005.
(I) API Publication 26 n. Evaporation
Loai from External Floating Roof Tanks.
Second Edition. February ISM. IBR ap-
proved January 17. 1M3. for 11*0.111(1).
«0 Iliad). «0 llla(IKl) and tU>.UetX«x2KI>.
The following material Is avail-
able for purchase from the Technical
Association of the Pulp and Paper In
dutlry (T/'"?!). Dunwoody Park, At-
lanta. OA JJ341.
ID TAPPI Method T934 oa-01. IBR ap-
proved January 31. 191} for I «0 3«4(dK4).
lc> The following material Is avail-
able for purchase from the Water Pol-
lution Control Federation (WPCP).
2821 Pennsylvania Avenue NW..
Washington. DC 20037.
(!) Method 20>A. Total Realdue Dried at
101-109 -C. In Standard Mttliodi far UM tr
omlnarion a/ WoUr and WaiUwoUr. Ibth
Edition. I»SO. IBR approved February U.
1615 (or | 80 «>3lb)
40 CFR Ch. I (7-1-90 Edition)
(f) The following material Is avail
able for purchase from the following
address: Underwriter's Laboratories.
Inc. (ULI. 333 Pflngjlen Road. North
brook.IL 60062
III UU 103. Slllh Edition revbed as or
September 3. l«8t. Standard lor Chlmneyi.
Factory-built. Residential Type and Build
Inf Heallni Appliance.
. 1170, rcvltcd 19«4.
(h) The ASME Power Teit Codes 4.1.
• August 1972. Is available for pur-
chase from the following address: The
American Society of Mechanical Engi-
neers. 22 Law Drive. Box 2350. Fair-
field. NJ 07007-3350.
141 FR 37». Jan. 37. 19831
CDlToaiAJ. Nor*: For Federal Reflater clla-
lions affecting |*0.17. see the LUl of CFR
Sections Affected In the Finding Aldi tec-
lion of this volume.
1(0.18 General control device requite-
menu.
(a) Introduction. This section con-
tains requirements for control devices
used to comply with applicable sub-
parts of parts 80 and 01. The require-
ments are placed here for administra-
tive convenience and only apply to fa-
cilities covered by subparts referring
to this section.
(b) flares. Paragraphs (c) through
(f) apply to flares.
(CK1) Flares shall be designed for
and operated with no visible emissions
as determined by the methods speci-
fied In paragraph (f), except for peri-
ods not to exceed k total of 5 minutes
during any 2 consecutive hours.
(2) Flares shall be operated with •
flame present at all tunes, as deter-
mined by the methods specified In
paragraph (f).
(3) Flares shall be used only with
the net heating value of the gas being
combusted being 11.2 MJ/scm (300
Btu/scf) or greater If the flare Is
steam-assisted or alr-asslsled; or with
the net healing value of the gas being
combusted being 7.45 MJ/scm (200
Btu/scf) or greater If the flare Is non-
234
Envlronmanlol FroUctlan Agency
assisted. The net heating value of the
gas being combusted shall be deter-
mined by the methods specified In
paragraph (f).
(4X1) Steam-assisted and nonasslsted
n&res shall be designed for and operat-
ed with an exit velocity, as determined
by the methods specified In paragraph
UH4), less than 18.3 m/sec (80 ft/sec),
except as provided In paragraphs
(b)(4) (II) and (111).
(II) Steam-assisted and nonasslsted
flares designed for and operated with
an exit velocity, as determined by the
methods specified In paragraph (f)(4).
equal to or greater than IB.3 m/sec (80
ft/sec) but leas than 122 m/sec (400
ft/sec) are allowed If the net heating
value of the gas being combusted Is
greater than 37.3 MJ/scm (1.000 Btu/
scf).
(Ill) Steam-assisted and nonasslsted
flares designed for and operated with
an exit velocity, as determined by the
methods specified In paragraph (fK4>,
less than the velocity. V_. as deter-
mined by the method specified In
paragraph (f>(6). and less than 122 m/
sec (400 ft/sec> are allowed.
(6) Air assisted Hares shall be de-
signed and operated with an exit ve-
locity less than the velocity. V_. as
determined by the method specified In
paragraph (f)(8).
(8) Flares used to comply with this
section shall be steam-assisted, air as-
sisted, or nonasslsted.
§60.18
(d) Owners or operators of (lares
used to comply with the provisions of
this subpart shall monitor these con
trol devices to ensure that they are op
erated and maintained In confonnance
with their designs Applicable subparts
will provide provisions slating how
owners or operators of flares shall
monitor these control devices
Flares used to comply will) provl
slons of this subparl shall be operated
at all times when emissions may be
vented to them.
(f)(l) Reference Method 22 shall be
used to determine the compliance of
flares with the visible emission provi-
sions of this subparl. The observation
period Is 2 hours and shall be used ac-
cording lo Method 22.
(2) The presence of a flare pilot
flame shall be monitored using a ther-
mocouple or any other equivalent
device to detect the presence of a
flame.
(3) The net heating value of the gas
being combusted In a flare shall be cal-
culated using the following equation:
n
H, • K I C.H,
1 1-1 ' '
where:
HT-Nel heating value of the umple. MJ/
•cm: where the net enthalpy per mole of
off | a* U based on combustion at 25 'C
and 700 nun Hg, but the «Ujid.vrd tern
perature for determlnlni the volume
corresponding U> one mole U 20 'C.
K = Constant, , ,_!_.
1.740 x 10 *ppnr
sen?
where the standard temperature for /Qjnoje. is ZO°C;
( scm J
(^-.Concentration of umple component I In
ppm on • wet b.uU. ** meMured for or-
ItnlcA by Reference Method 18 and
measured (or hydrogen and carbon mon-
oxide by ASTM D1946 77 (Incorporated
by reference as specified In | 00.17>; and
H,-Net heal of combustion ot Bam pie com
ponent I. kcsJ/f mole at 25 *C and 700
nun Hg. The heats of combustion may
be determined using ASTM D23B2 70
(Incorporated by reference as specified
In 10017) If published values are not
available or cannot be calculated
(4) The actual exit velocity of & Marc
shall be determined by dividing the
235
-------
§ 60.20
volumetric ftowrate (In unlls of stand-
ard temperature and pressure), as de
lennuied by Reference Methods 2. 2A,
2C. or '2D as appropnate; by the unob-
structed (free) cross se'ctlonal area of
the flare tip.
(5) The maximum permitted veloci-
ty. V.^. for flares complying with
paragraph (c)(4)(lll) shall be deter-
mined by the following equation.
Loi,t *v»M>-(Hr-t2S.SI/31.7
V_-Maxlmum permitted velocity. M/MC
2M-Constant
31.7-Conltant
H,-The net heating value ai determined In
paragraph (1X3).
(6) The maximum permitted veloci-
ty. V_. for air assisted flares shall be
determined by the following equation.
V_-l.70«+0.70*4 (H,)
V... "Maximum permitted velocity, m/aec
l.70<-Con»tAnl
0.70li-Conitant
HT-The net heatlni value a* determined tn
paragraph (fM3).
(51 FR 1701. Jan. 91. lilt)
5> Subpart B—Adoption and Submlttal
ivj of Stale Fiona far Designated Fa-
fO cllllles
Soonci: 40 FR 63348. Nov. 17. 1876. imleai
otherwise noted.
BC0.20 Appl{csblllly.
The provisions of this subpart apply
to Slates upon publication of a final
guideline document under I 60.22(a).
I SO 21 Definition!.
Terms used but not defined In this
subpart shall have the meaning given
them In the Act and In subparl A:
(a) DaignaUd pollutant means any
air pollutant, emissions of which are
subject to a standard of performance
for new stationary sources but for
which air quality criteria have not
been Issued, and which Is not Included
on a list published under section
1081 a) or section 112(b)(lHA> of the
Act.
(b) DatgnaUd facility means any
existing facility (see 180.2 or
promulgated under | 60.27(d).
(e) Emiijion guideline means a
guideline set forth In Subpart C of
this part, or In a final guideline docu-
ment published under 160.22(a).
which reflects the degree of emission
reduction achievable through the ap-
plication of the best system of emis-
sion reduction which (taking Into ac-
count the cost of such reduction) the
Administrator has determined has
been adequately demonstrated for des-
ignated facilities.
(f > Emitnion standard means a legal-
ly enforceable regulation setting forth
an allowable rate of emissions Into the
atmosphere, or prescribing equipment
specifications for control of air pollu-
tion emissions.
(g) Compliance ichedule means a le-
gally enforceable schedule specifying a
date or dates by which a source or cat-
egory of sources must comply with
specific emission standards contained
In a plan or with any Increments of
progress to achieve such compliance.
increments at progrea means
steps to achieve compliance which
must be taken by an owner or operator
of a designated facility, Including:
(1) Submlttal of a final control plan
for the designated facility to the ap-
propriate air pollution control agency:
(2) Awarding of contracts for emis-
sion control systems or for process
modifications, or Issuance of orders for
the purchase of component parts to
accomplish emission control or process
modification:
(3) Initiation of on-sltc construction
or Installation of emission control
equipment or process change:
(4) Completion of on-slte construc-
tion or Installation of emission control
equipment or process change; and
(6) Final compliance.
Environmental Protection Agency
(I) Region means an air quality con
trol region designated under section
107 of the Act and described In part 81
of this chapter.
(j) Local agencv means any local
governmental agency.
0 CO 22 Publication of guideline docu-
menU, iniliilon guideline!, and final
compliance timer
(a) Concurrently upon or after pro-
posal of standards of performance for
the control of a designated pollutant
from affected facilities, the Adminis-
trator will publish a draft guideline
document containing Information per-
tinent to control of the designated pol-
lutant form designated facilities.
Notice of the availability of the draft
guideline document will be published
In the FEDERAL REGISTER and public
comments on Its contents will be Invit-
ed. After consideration of public com-
ments and upon or after promulgation
of standards of performance for con-
trol of a designated pollutant from af-
fected facilities, a final guideline docu-
ment will be published and notice of
Its availability will be published In the
FEDERAL REGISTER.
(b) Guideline documents published
under this section will provide Infor-
mation for the development of State
plans, such as:
(1) Information concerning known
or suspected endangerment of public
health or welfare caused, or contribut-
ed to. by the designated pollutant.
(2) A description of systems of emis-
sion reduction which. In the judgment
of the Administrator, have been ade-
quately demonstrated.
(3) Information on the degree of
emission reduction which Is achievable
with each system, together with Infor-
mation on the costs and .environmen-
tal effects of applying each system to
designated facilities.
(4) Incremental periods of time nor-
mally expected to be necessary for the
design. Installation, and startup of
Identified control-systems.
(5> of this
section will be proposed for comment
upon publication of the drafl guide-
line document, and after consideration
of comments will be promulgated In
Subpart C of this part with such modi-
fications as may be appropriate.
(d)(l) If the Administrator deter-
mines that a designated pollutant may
cause or contribute to endangerment
of public welfare, but that adverse ef-
fects on public health have not been
demonstrated, he will Include the de-
termination In the draft guideline doc-
ument and In the FEDERAL REGISTER
notice of Its availability. Except as
provided In paragraph (d>(2> of this
section, paragraph (c) of this section
shall be Inapplicable In such cases.
(2) If the Administrator determines
at any tune on the basis of new Infor
matlon that a prior determination
under paragraph (d)(l) of this section
Is Incorrect or no longer correct, he
will publish notice of the determina-
tion In the FEDERAL REGISTER, revise
the guideline document as necessary
under paragraph (a) of this section.
and propose and promulgate emission
guidelines and compliance times under
paragraph (c) of this section.
140 PR 81341. Nov. 17. 1B7S. u amended at
M FR 62IW. Dec. 20. 1IM)
ltO.23 Adoption and >ubmltul of Slate
plant; public hearing!.
(a)(l) Within nine months after
notice of the availability of a final
guideline document Is published under
I 80 22(a>. each Stat«*ahall adopt and
submit to the Administrator. In ac-
cordance with 160 4. a plan for the
236
237
-------
APPENDIX B
40 CFR 60 Subpart QQQ
New Source Performance Standard
For Petroleum Refinery Wastewater Systems
-------
§ 60.684
6 60.684 Recordkceplnf and reporting re-
quirement*.
(a) At 30 minute Interval* during
each 1-hour test run of each perform-
ance teal of a wet acnibber control
device and at least once every 4 hour*
thereafter, the owner or operator ahall
record the measurements required by
I 60.683U).
(b) At 30 minute Interval* during
each 2'hour tut run of each perform-
ance teit of a wet electrostatic prectpl-
Ulor control device and at least once
every 4 hour* thereafter, the owner or
operator shall record the measure-
ment! required by I 80.M3.
(b) The owner or operator shall con-
duct performance tests while the prod-
uct with the highest loss on Ignition
(LOI) expected to be produced by the
affected facility I* being manufac-
tured.
(c) The owner or operator shall de-
termine compliance with the partlcu-
late matter standard In I 60.682 as fol
Iowa:
(1) The emission rate (E) of partlcu-
late matter ahall be computed for each
run using the following equation:
_ K>
when:
E-eroUdon rate of partlculau matter, kg/
Mi (Ib/too).
Ci— concentration of particular matter.
g/dscm (g/dacf ).
Q»- volumetric low rate of effluent fu.
dscm/hr (dscf/hr).
PM,— average glass pul] rmle. Mg/hr (ton/
hr).
K-converalon factor. 1000 g/kg (453.* g/lb).
(2> Method 6E shall be used to deter-
mine the paniculate matter concen-
tration (C,) and the volumetric flow
rate (Q^l of the effluent gaa. The sam-
pling time and sample volume shall be
at leut 120 minute* and 2.66 dscm (SO
dscf).
(3) The average glass pull rate (P..,)
for the manufacturing line shall be
the arithmetic average of three glass
pull rate determination* taken at
Interval* of at leut 30 minute* during
each run.
The Individual glass pull rates
shall be computed using the following
equation:
P,-K' U W. fcf 11 O-ILOI/100))
where:
P,-glau pull r»te at Interval "I", Mi/hr
(ton/hr).
Lt**llna speed, m/mln (ft/mln>.
W.. trimmed mat width, m (ft).
M-mat mm weight. «/mMlb/(f>
LOI^loas on Ignition, welfht percent.
5B2
Environmental Protection Agency
§60.691
K -conversion factor. SxlO"' (mln M«>/
(iir SI 13x10 '(mln lon)/(hr lb»
(I) ASTM Standard Tesl Melhod
D2584-68 (Reapproved 1979) (Incorpo-
rated by reference— see 160.17), shall
be used lo determine Ihe LOI for each
run.
(II) Line speed (L.). trimmed mat
width (W.). and mat gram weight (M)
shall be determined for each run from
the process Information or from direct
measurements.
(d) To comply with I 60.684(d). the
owner or operator shall record meas-
urements as required In 1 60.684 (a)
and (b) using the monitoring devices
In I 60.683 (a) and (b) during the par-
tlculate matter runs.
134 FR 8960. Peb 14. 1988)
Subpart QQQ — Standards of Per-
formance for VOC Emissions
From Petroleum Refinery
WaiUwaUr Systems
Bounce. 53 PR 41621. Nov. 23. lose, unleu
otherwise noted.
1 60.690 Applicability and designation of
affected facility.
(aHD-The provisions of thl* subpart
apply to a/fected facilities located In
petroleum refineries for which con-
struction. modification, or reconstruc-
tion Is commenced after May 4, 1987.
(2) An Individual drain system Is a
separate affected facility.
(3) An oil-water separator Is a sepa-
rate affected facility.
(4) An aggregate facility Is a sepa-
rate affecled facility.
(b) Notwithstanding the provisions
of 40 CFR 60.l4(e)(2). the construction
or Installation of a new Individual
drain system shall constitute a modifi-
cation to an affected facility described
In I 60.690(a)(4). For purposes of this
paragraph, a new Individual drain
system shall be limited to all process
drains and the first common Junction
box.
B 60.69 1 Definitions.
As used In this subpart. all terms not
defined herein shall have the meaning
given them In the Act or In Subpart A
of 40 CFR part 60. and the following
terms shall have the specific meanings
given them.
Acttve service means that a drain la
receiving refinery wastewaler Irom a
process unit that will continuously
maintain a water seal
Aggregate facility means an Individ-
ual drain system together with ancil-
lary downstream sewer lines and oil-
water separators, down to and Includ-
ing the secondary oil water separator.
as applicable.
Catch basin means an open basin
which serves as a single collection
point for stormwater runoff received
directly from refinery surfaces and for
refinery wnstewater from process
drains.
Closed vent system means a system
that Is not open to the atmosphere
and Is composed of piping, connec
tlons. and. If necessary, flow Inducing
devices that transport gas or vapor
from an emission source to a control
device.
Completely closed drain system
means an Individual drain system that
Is not open to the atmosphere and La
equipped and operated with a closed
vent system and control device com-
plying with the requirements of
I 60.692-5.
Control device means an enclosed
combustion device, vapor recovery
system or flare.
Filed roof means a cover that Is
mounted to a tank or chamber In a
stationary manner and which does not
move with fluctuations In wastewater
levels.
Floating roof means a pontoon-type
or double-deck type cover that rests on
the liquid surface.
Gas-tight means operated with no
detectable emissions.
Individual drain system means all
process drains connected to the first
common downstream Junction box.
The term Includes all such drains and
common Junction box. together with
their associated sewer lines and other
Junction boxes, down to the receiving
oil-water separator.
Junction box means a manhole or
access point lo a wastewater sewer
system line.
No detectable emissions means less
than 500 ppm above background
levels, as measured by a detection In
583
-------
OJ
(V)
§60.693-1
struraenl In accordance with Method
21 In Appendix A of 40 CKK put 60.
Non-contact cooling water *yj(em
meuu a once-through drain, collection
and treatment system designed and
operated lor collecting cooling water
which does not come Into contact with
hydrocarbon] or oily wutewater and
which U not reclrculated through a
cooling tower.
Oil-water separator meana
waslewaler treatment equipment used
to separate oil from water consisting
of a separation tank, which also In-
clude* the (orebay and other separator
basins, skimmers, weln. grit chamber*.
and iludge hoppera. Slop oil facilities.
Including Uuika. are Included In thla
term along with storage vessels and
auxiliary equipment located between
Individual drain systems and the oll-
water separator. Thla term does not
Include storage vessels or auxiliary
equipment which do not come In con-
tact with or store oily wastewater.
Oily uicuteuater means wastewater
generated during the refinery process
ifnlch contains oil, emulsified oil. or
bcher hydrocarbons. OUy wastewater
originates from a variety of refinery
processes Including cooling water, con-
densed stripping steam. Unk draw-off.
and contact process water.
Petroleum means the crude oil re-
moved from the earth and the oils de-
rived from tax sands, shale, and coal.
Petroleum re/tae,ry means any facili-
ty engaged In producing gasoline, ker-
osene, distillate fuel oils, residual fuel
oils, lubricants, or other products
through the distillation of petroleum.
or through the redistillation of petro-
leum, cracking, or reforming unfin-
ished petroleum derivatives.
Sewer line means a lateral, trunk
line, branch line, ditch, channel, or
other conduit used to convey refinery
wastewater to downstream compo-
nents of a refinery wastewater treat-
ment system. This term does not In-
clude burled, below-trade sewer lines.
Slop oil means the floating oil and
solids that accumulate on the surface
of an oil-water separator.
Storage vejiel means any Unk. reser-
voir, or container used for the storage
of petroleum liquids. Including oily
wastewater.
40 CFR Ch. I (7-1-90 Edition)
Stormwater sewer jyjfem means a
drain and collection system designed
and operated for the sole purpose of
collecting Stormwater and which la
segregated from the process
wutewater collection lyslem.
Wtulewater jyjfem means any com-
ponent, piece ot equipment, or Instal-
lation that receives, treats, or process-
ea oily wastewater from petroleum re-
finery process units.
Water teal control* means a seal pot.
p-leg trap, or other type of trap filled
with water that has a design capability
to create a water barrier between the
sewer and the atmosphere.
IM.tll-l Standard*: General.
(a) Each owner or operator subject
to the provisions of this subpart shall
comply with the requirements of
1180.092-1 to 60.682-5 ai.d with
II 60.693-1 and 60.68)-]. except during
periods of startup, shutdown, or mal-
function.
(b) Compliance with 1160.682-1 to
60.682-1 and with 1160.683-1 and
60.683-2 will be determined by review
of records and reports, review of per-
formance teat results, and Inspection
using the methods and procedures
specified In 160.686.
(c) Permission to use alternative
means of emission limitation to meet
the requirements of II 60.6(2-2
through 60.692-4 may be granted as
provided In 160.694.
(dXl) Stormwater sewer systems are
not subject to the requirements of this
subpart.
(2) Ancillary equipment, which Is
physically separate from the
waslewater system and does not come
In contact with or store oily
wastewater. Is not subject to the re-
quirements' of this subpart.
<3> Non-contact cooling water sys-
tems are not subject to the require-
ments of this aubpart.
(1) An owner or operator shall dem-
onstrate compliance with the exclu-
sions In paragraph* (dKl). (2). and (3)
of this section as provided In 160.697
(h). (I), and (]).
Environmental Protection Agency
060692-2 Standard*: liidmduul drftln
kyltcml.
(«> Each drain shall be equipped
with water seal controls
(2) Each drain In active service shall
be checked by visual or physical In-
spection Initially and monthly thereaf-
ter for Indications of low water levels
or other conditions that would reduce
the effectiveness of the water seal con-
trols.
(3) Except as provided In paragraph
(a)(4) of this section, each drain out of
active service shall be checked by
visual or physical Inspection Initially
and weekly thereafter for Indications
of low water levels or other problems
that could result In VOC emissions.
(41 As an alternative to the require-
ments In paragraph (a)(3> of this sec-
tion. If an owner or operator elects to
Install a tightly sealed cap or plug over
a drain that Is out of service. Inspec-
tions shall be conducted Initially and
semlannually to ensure caps or plugs
are In place and properly Installed.
(5) Whenever low water levels or
missing or Improperly Installed caps or
plugs are Identified, water shall be
added or first efforts at repair shall be
made as soon as practicable, but not
later than 24 hours after detection.
except as provided In I 60 692-6.
If a broken seal or gap Is Identi-
fied, first effort at repair shall be
made as soon as practicable, but not
later than IS calendar days after the
broken seal or gap Is Identified, except
as provided In I 60.692-6.
(Oil) Sewer lines shall not be open
to the atmosphere and shall be cov-
ered or enclosed In a manner so as to
have no visual gaps or cracks In Joints.
seals, or other emission Interfaces.
§ 60 697 3
(2) The portion ol each unbi'ilnl
sewer line shall be visually Inspt-i-tcil
Initially and semlannually I lii-ri-.ili.T
lor Indication of cracks. BHKJ. i.i uiliei
problems that could result In VOC
emissions.
(3) Whenever cracks, gups, or other
problems are detected, repairs shall be
made as soon as practicable, bul not
later than 15 calendar days after Iden
tlflcatlon. except as provided In
| 60.692-6.
(d) Except as provided In paragraph
of this section, each modified or re-
constructed Individual drain system
that has a catch basin In the existing
configuration prior to May 4. 1987
shall be exempt from the provisions of
this section
(e) Refinery wastewater routed
through new process drains and a new
first common downstream Junction
box. either as part of a new Individual
drain system or an existing Individual
drain system, shall not be routed
through a downstream catch basin.
160(92-3 Standard* Oil »«Ur ttpan
ton.
(a) Each oil-water separator tank.
slop oil tank, storage vessel, or other
auxiliary equipment subject to the re-
quirements of this subparl shall be
equipped and operated with a fixed
roof, which meets the following speci-
fications, except as provided In para
graph (d) ol this section or In I 60.693
2.
(1) The fixed roof shall be Installed
to completely cover the separator
tank, slop oil tank, storage vessel, or
other auxiliary equipment with no
separation between the roof and the
wall.
(2) The vapor space under a fixed
roof shall not be purged unless the
vapor Is directed to a control device.
(3) If the roof has access doors or
openings, such doors or openings shall
be gaskeled. latched, and kept closed
at alt times during operation of the
separator system, except during In
spectlon and maintenance.
(4) Roof seals, access doors, ajid
other openings shall be checked by
visual Inspection Initially and semlan
nually thereafter to ensure that no
cracks or gaps occur between the roof
584
585
-------
CD
OJ
§ 60.697-4
and wall and that access doors and
other openings are closed and gasket-
ed properly.
IS} When a broken seal or gasket or
other problem la Identified, first ef-
forts at repair shall be made u coon as
practicable, but not later than 15 cal-
endar days after It it Identified, except
as provided In | 80.092-6.
(b) Each oil-water separator tank or
auxiliary equipment with a design ca-
pacity to treat more than Id Utcn per
second (250 gpm) of refinery
wastewater ahail. In addition U> the re-
quirements In paragraph (a) of this
section, be equipped and operated
with a closed vent ayatem and control
device, which meet the requirements
of | 60.692-6. except u provided In
paragraph (c) of thU section or In
I 80.803-3
(c)(l) Each modified or reconstruct-
ed oil-water separator tank with a
maximum design capacity to treat less
than 38 liters per second (600 gpm) of
refinery waslewater which was
jtoulpped and operated with a fUed
Yoof covering the entire separator
*ank or a portion of the separator
tank prior to May 4, 1B87 shall be
exempt from the requirements of
paragraph (b) of this section, but shall
meet the requirements of paragraph
(a) of this section, or may elect to
comply with paragraph (cK2) of this
section.
(2) The owner or operator may elect
to comply with the requirements of
paragraph (a) of this section for the
existing fixed roof coveting a portion
of the separator tank and comply with
the requirements for floating roots In
160.893-2 for the remainder of the
separator tank.
(d) Storage vessels. Including slop oil
tanlts and other auxiliary tanks that
are subject to the requirements of 40
CFR Subparts K. Ka, or Kb. are not
subject to the requirements of this
section.
(e> Slop oil from an oil-water separa-
tor tank and oily wast«wat«r from slop
oil handling equipment shall be col-
lected, stored, transported, recycled.
reused, or disposed of In an enclosed
system. Once slop oil U returned to
the process unit or Is disposed of. It Is
no longer within the scope of this sub-
part. Equipment used In handling slop
40 CFR Ch. I (7-1-90 Edition)
oil shall be equipped with a fixed roof
meeting the requirements of para-
graph (a) of this section.
(f) Each oil-water separator tank.
slop oil tank, storage vessel, or other
auxiliary equipment that Is required
to comply with paragraph (a) of this
section, and not paragraph (b) of this
section, may be equipped with a pres-
sure control valve as necessary for
proper system operation. The pressure
control valve shall be set at the maxi-
mum pressure necessary for proper
system operation, but such that the
value will not vent continuously.
I M.692-4 Standard!: A(gref«U facility.
A new, modified, or reconstructed
aggregate facility shall comply with
the requirements of || 80.682-2 and
80.892-3.
1*0.612-6 Standard* Clo.ed venl ir.l.mi
and control device*.
(a) Enclosed combustion devices
shall be designed and operated to
reduce the VOC emissions vented to
them with an efficiency of 95 percent
or greater or to provide a minimum
residence time of 0.15 seconds at a
minimum temperature of 818'C
(1.500'F).
(b) Vapor recovery systems (for ex
ample, condensers and adsorbers) shall
be designed and operated to recover
the VOC emissions vented to them
with an efficiency of 95 percent or
greater.
(c) Flare* used to comply with this
subpart shall comply with the require
menu of 40 CFR 80.18.
(d) Closed vent systems and control
devices used to comply with provisions
of this subpart shall be operated at all
times when emissions may be vented
to them.
(eKl) Closed vent systems shall be
designed and operated with no detect-
able emissions, as Indicated by an In-
strument reading of less than 500 ppm
above background, as determined
during the Initial and semiannual In
spectlons by the methods specified In
I 60.688.
(2) Closed vent systems shall be
purged to direct vapor to the control
device.
Environmental Protection Agency
(3) A flow Indicator shall be Installed
on a venl stream to a control device to
ensure that the vapors are being
routed to the device.
(4) All gauging and sampling devices
shall be gas-light except when gauging
or sampling Is taking place.
(5) When emissions from a closed
syslem are detected, first efforts at
repair to eliminate the emissions shall
be made as soon as practicable, but not
later than 30 calendar days from the
date the emissions are detected, except
as provided In i 60.692-6.
t 60.692-6 Standard!: Delay of repair.
(a) Delay of repair of facilities that
are subject to the provisions of this
subpart will be allowed If the repair Is
technically Impossible without a com-
plete or partial refinery or process
unit shutdown.
(b) Repair of such equipment shall
occur belore the end of the next refin-
ery or process unit shutdown.
060.692-7 Standard* Delay of compli-
ance.
(a) Delay of compliance of modified
Individual drain systems with ancillary
downstream treatment components
will be allowed If compliance with the
provisions of this subpart cannot be
achieved without a refinery or process
unit shutdown.
(b) Installation of equipment neces-
sary to comply with the provisions of
this subpart shall occur no later than
the next scheduled refinery or process
unit shutdown.
060.693-1 Alternative lUndardl for Indi-
vidual drain ayatema.
(a) An owner or operator may elect
to construct and operate a completely
closed drain system.
Each completely closed drain
system shall be equipped and operated
with a closed vent syslem and control
device complying with the require-
ments of I 60 692-5
(c) An owner or operator must notify
the Administrator In the report re-
quired In 40 CFR 60.1 that the owner
or operator has elected to construct
and operate a completely closed drain
syslem.
(d) If an owner or operator elects to
comply with the provisions of this sec-
§60.693 2
tlon. then the owner or operator does
not need to comply with tliu provisions
of {| 60.692-2 or 60 694
(e)(l) Sewer lines shall not be open
to the atmosphere and shall be cov
ered or enclosed In a manner so as to
have no visual gaps or cracks In Julius.
seals, or other emission Interfaces.
(2) The portion of each unburled
sewer line shall be visually Inspected
Initially and semlannually thereafter
for Indication of cracks, gaps, or other
problems that could result In VOC
emissions.
(3) Whenever cracks, gaps, or other
problems are detected, repairs shall be
made as soon as practicable, but not
later than 15 calendar days after Iden
llflcatlon, except as provided In
I 80.692-8.
(60.691-2 Alternative ilandardi for oil
waler •fp.r.loti
(a) An owner or operator may elect
to construct and operate a floating
roof on an oil-water separator tank.
slop oil tank, storage vessel, or other
auxiliary equipment subject to the re
qulrements of this subpart which
meets the following specifications.
(I) Each floating roof shall be
equipped with a closure device be-
tween the wall of the separator and
the roof edge. The closure device Is to
consist of a primary seal and a second-
ary seal.
(I) The primary seal shall be a
liquid-mounted seal
(A) A liquid-mounted seal means a
foam- or liquid-filled seal mounted In
contact with the liquid between the
wall of the separator and the floating
roof.
(B) The gap width between the prl
mary seal and the separator wall shall
not exceed 3.8 cm (15 In.) at any
point.
(C) The total gap area between the
primary seal and the separator wall
shall not exceed 67 cmVm (3.2 In.VftJ
of separator wall perimeter.
(II) The secondary seal shall be
above the primary seal and cover the
annular space between the floating
roof and the wall of the separator.
(A) The gap width between the sec-
ondary seal and the separator wall
586
587
-------
§ 60.694
shall not exceed 1.3 cm (05 In.) at any
poliU.
(B) The total gap area between the
secondary seal and the separator wall
shall not exceed 6.7 cm'/m (0.33 In V
ft) of separator wall perimeter.
(Ill) The maximum gap width and
total gap area shall be determined by
the methods and procedure* specified
In I 60.«06(d>.
(A) Measurement of primary seal
Baps shall be performed within 60 cal-
endar days after Initial Installation of
the floating roof and Introduction of
refinery wastewater and once every 5
years thereafter.
(I) and (II) of this
section.
(2) Except as provided In paragraph
(a)(4) of this section, each opening In
'J3 the roof shall be equipped with a gas-
i, keled cover, seal, or lid. which shall be
maintained In a closed position at all
times, except during Inspection and
maintenance.
(3) The roof shall be floating on the
liquid (I.e., off the roof supports) at all
times except during abnormal condi-
tions (I.e.. low now rale).
(4) The floating roof may be
equipped with one or more emergency
roof drains for removal of stormwater.
Each emergency roof drain shall, be
fitted with a slotted membrane fabric
cover that covers at least 90 percent of
the drain opening area or a flexible
fabric sleeve seal.
(SKI) Access doors and other open-
Ings shall be visually Inspected Initial-
ly and semlannually thereafter to
ensure that there Is a light fit around
the edges and to Identify other prob-
lems that could result In VOC emis-
sions.
(II) When a broken seal or gasket on
an access door or other opening Is
Identified, It shall be repaired as soon
as practicable, but not later than 30
calendar days after It Is Identified.
except as provided In 160.6(2-6.
40 CFR Ch. I (7-1-90 Edition)
(b) An owner or operator must
notify the Administrator In the report
required by 40 CFR 60.7 that the
owner or operator has elected to con
struct and operate a floating roof
under paragraph (a) of this section.
(c) For portions, of the oil-water sep
aralor tank where It Is Infeaslble to
construct and operate a floating roof,
such as the skimmer mechanism and
weirs, a fixed roof meeting the re-
quirements of I 60.692-3(a) shall be In
stalled.
(d) Except as provided In paragraph
(c) of this section. If an owner or oper-
ator elects to comply with the provi-
sions of this section, then the owner or
operator does not need to comply with
the provisions of 1160.682-3 or 60694
applicable to the same facilities.
OCO.C94 Prrmlulon lo me alternative
meant of emUilon limitation.
(a) If, In the Administrator's Judg-
ment, an alternative means of emis-
sion limitation will achieve a reduction
In VOC emissions at least equivalent
to the reduction In VOC emissions
achieved by the applicable require-
ment In 160.692, the Administrator
will publish In the FEDUUL REGISTER a
notice permitting the use of the alter-
native means for purposes of compli-
ance with that requirement. The
notice may condition the permission
on requirements related to the oper-
ation and maintenance of the alterna-
tive means.
(b) Any notice under paragraph (a)
of this section shall be published only
after notice and an opportunity for a
hearing.
(c) Any person seeking permission
under this section shall collect, verify,
and submit to the Administrator Infor-
mation showing that the alternative
means achieves equivalent emission re-
ductions.
I 60 695 Monitoring of operation*.
(a) Each owner or operator subject
to the provisions of this subparl shall
Install, calibrate, maintain, and oper
ale according to manufacturer's speci-
fications the following equipment.
unless alternative monitoring proce
dures or requirements are approved
for that facility by the Administrator
Environmental Protection Agency
(1) Where a thermal Incinerator Is
used for VOC emission reduction, a
temperature monitoring device
equipped with a continuous recorder
shall be used to measure the tempera
lure of the gas stream In the combus-
tion zone of the Incinerator The tem-
perature monitoring device shall have
an accuracy of 1 percent of the tem-
perature being measured In 'C or ±0.5
•C (4 1.0 -F). whichever Is greater.
(2) Where a catalytic Incinerator Is
used for VOC emission reduction, tem-
perature monitoring devices, each
equipped with a continuous recorder
shall be used to measure the tempera-
ture In the gas stream Immediately
before and after the catalyst bed of
the Incinerator. The temperature
monitoring devices shall have an accu-
racy of I percent of the temperature
being measured In 'C or ±0.5 'C (±1.0
•F). whichever la greater.
(3) Where a carbon adsorber Is used
for VOC emissions reduction, a moni-
toring device that continuously Indi-
cates and records the VOC concentra-
tion level or reading of organlcs In the
exhaust gases of the control device
outlet gas stream or Inlet and outlet
gas stream shall be used.
(4) Where a flare Is used for VOC
emission reduction, the owner or oper-
ator shall comply with the monitoring
requirements of 40 CFR 60.18(f)(2).
(b) Where a VOC recovery device
other than a carbon adsorber Is used
lo meet the requirements specified In
t 60.692-5(a>. the owner or operator
shall provide lo the Administrator In-
formation describing the operation of
the control device and the process
parameter(s) that would Indicate
proper operation and maintenance of
Ihe device. The Administrator may re-
quest further Information and will
specify appropriate monitoring proce-
dures or requirements
(c) An alternative operational or
process parameter may be monitored
If II can be demonstrated that another
parameter will ensure that the control
device Is operated In conformance with
these standards and the control de-
vice's design specifications.
§ 60.696
960.696 Performance leil melhudi nnd
procedure* and compliance priiviclona
(a) Before using any equipment In
stalled In compliance with the ri-uulie
menls of II 80.692-2. 60 692 3. 60 692
4. 60.092-5. or 60.693. the owner or op
eralor shall Inspect such equipment
for Indications of potential emissions,
defects, or other problems that may
cause the requirements of this snuparl
not to be met Points of Inspection
shall Include, but are not limited to.
seals, flanges. Joints. gaskeU. hatches.
caps, and plugs.
(b) The owner or operator of each
source that Is equipped with a closed
vent system and control device as re
quired In 160.692-5 (other than a
flare) Is exempt from 1608 of the
General Provisions and shall use
Method 21 to measure the emission
concentrations, using 500 ppm as Hie
no delectable emission limit The In
strumenl shall be calibrated each day
before using. The calibration gases
shall he:
(1) Zero air (less than 10 ppm of hy
drocarbon In air), and
(2) A mixture of either methane or
n-hexane and air at a concentration of
approximately, but less lhan, 10.000
ppm methane or n-hexane.
(c) The owner or operator shall con
duct a performance ttst Initially, and
at other limes as requested by the Ad-
ministrator, using the test methods
and procedures In } 60.18 as fol
lows:
(1) The maximum gap widths and
maximum gap areas between the prl
mary seal and the separator wall and
between the secondary seal and the
separator wall shall be determined In
dlvldually within 60 calendar days of
the Initial Installation of the floating
roof and Introduction of refinery
wastewater or 60 calendar days after
the equlpmenl Is placed back Into serv
Ice using the following procedure
588
589
-------
CD
(In
§ 60.697
when the separator Is rilled to the
design operating level and when the
roof Is floating off the roof supports.
(I) Measure leal gaps around the
entire perimeter of the separator In
each place where a 0 32 cm (0.12S In.)
diameter uniform probe passes freely
(without forcing or binding against
seal) between the teal and the wall of
the separator and measure the gap
width and perlmetrlcal distance of
each s>jch location.
(II) The total surface area of each
gap described In (didXI) of this sec-
tion shall be determined by using
probes of various widths to measure
accurately the actual distance from
the wall to the seal and multiplying
each such width by Its respective peri-
metrical distance.
(Ill) Add the gap surface area of each
gap location for the primary aeal and
the secondary seal Individually, divide
the sum for each seal by the nominal
perimeter of the separator basin and
compare each to the maximum gap
area as specified In I 60.693-2.
(2) The gap widths and total gap
area shall be determined using the
procedure In paragraph (d)(l) of this
section according to the following fre-
quency:
(1) For primary seals, once every 5
years.
(II) For secondary seals, once every
year.
0 60.697 Rccor4kecplng requirement*.
(a) Each owner or operator of a fa-
cility subject to the provisions of this
subp&rl shall comply with the record-
keeping requirements of this section.
All records shall be retained for a
period of 2 yeara after being recorded
unless otherwise noted.
(b)(l) For Individual drain systems
subject to 160.692-2. the location.
date, and corrective action shall be re-
corded for each drain when the water
seal Is dry or otherwise breached.
when a drain cap or plug Is missing or
Improperly Installed, or other problem
Is Identified that could result In VOC
emissions, as determined during the
Initial and periodic visual or physical
Inspection.
(2) For junction boxes aubject to
I 60.692-2. the location, date, and cor-
rective action shall be recorded for In-
40 CFR Ch I (7-1-90 Edition)
specllons required by t 60 692-2(b>
when a broken seal. gap. ur other
problem Is Identified that could result
In VOC emissions
(3) For sewer lines subject io
H60692-2 and 60 693-Ke). the loca
tlon, dale, and corrective action shall
be recorded for Inspections required
by || 60 692-2(c) and 60 693 Kc) when
a problem Is Identified Ihut could
result In VOC emissions.
(c) For oil-water separators subject
to 160 692-3. the location, dale, and
corrective action shall be recorded for
Inspections required by by 160.692
3(a) when a problem Is Identified that
could result In VOC emissions.
(d) For closed vent systems subject
to 160.692-5 and completely closed
drain systems subject to 160.693-1.
the location, date, and corrective
action shall be recorded for Inspec-
tions required by I 80.692-5(e) during
which detectable emissions are meas-
ured or a problem Is Identified that
could result In VOC emission*
(e)(l) If an emission point cannot be
repaired or corrected without a proc-
ess unit shutdown, the expected date
of a successful repair shall be record-
ed.
(2) The reason for the delay as speci-
fied In I 60.692-6 shall be recorded If
an emission point or equipment prob-
lem Is not repaired or corrected In the
specified amount of time.
(3) The signature of the owner or
operator (or deslgnee) whose decision
It was that repair could not be effected
without refinery or process shutdown
shall be recorded.
(4) The date of successful repair or
corrective action shall be recorded.
(f)(l) A copy of the design speclllca-
lions for all equipment used to comply
with the provisions of this subpart
shall be kept for the life of the source
In a readily accessible location.
<2) The following Information per-
taining to the design specifications
shall b« kept.
(I) Detailed schematics, and piping
and Instrumentation diagrams.
(II) The dates and descriptions of
any changes In the design specifica-
tions.
(3) The following Information per
talnlng to the operation and malnte-
nance of closed drain systems and
Environmental Protection Ag»nry
closed venl systems shall be kept In a
readily accessible location
(I) Documentation demonstrating
that the conlrol device will achieve
the required control efficiency during
maximum loading conditions shall be
kept for the life of the facility. This
documentation Is to Include a general
description of the gas streams that
enter the control device. Including
flow and VOC content under varying
liquid level conditions (dynamic and
static) and manufacturer's design spec-
ifications for the control device. If an
enclosed combustion device with a
minimum residence time of 0.75 sec-
onds and a minimum temperature of
Bia-C (1.500'F) Is used to meet the 95-
percent requirement, documentation
that those conditions exist la sufficient
to meet the requirements of this para-
graph.
(ID A description of the operating
parameter (or parameters) to be moni-
tored to ensure that the control device
will be operated In coaformance with
these standards and the control de-
vice's design specifications and an ex-
planation of the criteria used for selec-
tion of that parameter (or parameters)
shall be kept for the life of the facili-
ty
(111) Periods when the closed venl
systems and control devices required
In 160.692 are not operated as de-
signed. Including periods when a flare
pilot does not have a flame shall be re-
corded and kept for 2 years after the
Information Is recorded.
(Iv) Dates of startup and shutdown
of the closed vent system and control
devices required In I 60.692 shall be re-
corded and kept for 2 yeara after the
Information Is recorded.
(v) The dates of each measurement
of detectable emissions required In
1160.692. 60.603. or 60.692-t shall be
recorded and kept for 2 yeara after the
Information Is recorded.
(vl) The background level measured
during each detectable emissions
measurement shall be recorded and
kept for 2 years after the Information
Is recorded.
(vl!) The maximum Instrument read-
ing measured during each detectable
emission measurement shall be record-
ed and kept for 2 years after the Infor-
mation Is recorded.
§ 60.697
(vlll) Each owner or operator of an
affected facility that ustf.s a therm*)
Incinerator shall maintain i.niilhuiuus
records of the temperature of the Has
stream In the combustion zone of llie
Incinerator and records of all 3-hour
periods of operation during which the
average temperature of the gas stream
In the combustion zone Is more than
28'C (50'F) below the design combus-
tion zone temperature, and shall keep
such records for 2 years after the In-
formation Is recorded
(Lx) Each owner or operator of an af-
fected facility that uses a catalytic In-
cinerator shall maintain continuous
records of the temperature of the gas
stream both upstream and down-
stream of the catalyst bed of the Incin-
erator, records of all 3-hour periods of
operation during which the average
temperature measured before the cat-
alyst bed Is more than 28'C (50'F>
below the design gas stream tempera-
ture, and records of all 3-hour periods
during which the average temperature
difference across the catalyst bed Is
less than 80 percent of the design tem-
perature difference, and shall keep
auch records for 2 years after the In-
formation Is recorded.
(x) Each owner or operator of an af
fected facility that uses a carbon ad
sorber shall maintain continuous
records of the VOC concentration
level or reading of organlcs of the con-
trol device outlet gas stream or Inlet
and outlet gas stream and records of
all 3-hour periods of operation during
which the average VOC concentration
level or reading of organlcs In the ex-
haust gases, or Inlet and outlet gas
stream. Is more than 20 percent great-
er than the design exhaust gas concen-
tration level, and shall keep such
records for 2 years after the Informa-
tion la recorded.
(g) If an owner or operator elects to
Install a tightly sealed cap or plug over
a drain that Is out of active service,
the owner or operator shall keep for
the life of a facility In a readily acces-
sible location, plans or specifications
which Indicate the location of such
drains.
(h) For stonr.water sewer systems
subject to the exclusion In | 60 692-
KdXl). an owner or operator shall
keep for the life of the facility in R
590
591
-------
00
§ 60.698
readily accessible location, plans or
specification* which demonstrate Hint
no waslewater from any process unlls
or equipment Is directly discharged in
the slormwater sewer system.
(I) For ancillary equipment subject
to the exclusion In i 60.692-l(d)(2). an
owner or operator shall keep (or the
life of a facility In a readily accessible
location, plans or specifications which
demonsrate that the ancillary equip
ment'does not come In contact with or
store oily waslewaler.
()) For non-contact cooling water
systems subject to the exclusion In
I e0.692-l(d>(3>. an owner or operator
shall keep for the life of the facility In
a readily accessible location, plans or
specifications which demonstrate that
the cooling water does not contact hy-
drocarbons or oily wastewater and Is
not reclrculatcd through a cooling
tower
(Approved by the Office of Management
and Budget under control number 2060-
0112)
t (0.698 Iteportlni requirement!.
An owner or operator electing to
comply with the provisions of I 60.693
shall notify the Administrator of the
alternative standard selected In the
report required In | 80 7.
(bid) Each owner or operator of a
facility subject to this subpart shall
submit to the 'Administrator within 60
days alter Initial startup a certifica-
tion that the equipment necessary to
comply with these standards has been
Installed and that the required Initial
Inspections or tests of process drains.
sewer lines. Junction boxes, oil-water
separators, and closed vent systems
and control devices have been carried
out In accordance with these stand-
ards. Thereafter, the owner or opera-
tor shall submit to the Administrator
semiannual!/ a certification that all of
the required Inspections have been
carried out In accordance with these
standards.
(2) Each owner or operator of an af-
fected facility that use* a flare shall
submit to the Administrator within 60
days after Initial startup, as required
under I 60 8(a). a report of the results
of the performance test required In
I 60 696(0.
40 CFR Ch. I (7-1-90 Edilion)
(c> A report that summarizes all li,
specllons when a water seal was dry or
otherwise breached, when a drain cup
or plug was missing or Improperly |n
stalled, or when cracks, gaps, or ulner
problems were Identified thai could
result In VOC emissions. Including In
formation about the repairs or correc-
tive action taken, shall be submitted
Initially and semlannually thereafter
to the Administrator.
(d> As applicable, a report shall be
submitted semlannually to the Admin-
istrator that Indicates:
(1) Each 3-hour period of operation
during which the average temperature
of the gas stream In the combustion
zone of a thermal Incinerator, as meas
ured by the temperature monitoring
device. Is more than 28 *C (SO 'Fi
below the design combustion zone
temperature,
(2) Each 3-hour period of operation
during which the average temperature
of the gas stream Immediately before
the catalyst bed of a catalytic Inciner-
ator, as measured by the temperature
monitoring device. Is more than 28'C
(50'P) below the deslen gas stream
temperature, and any 3-hour period
during which the average temperature
difference across the catalyst bed (I.e .
the difference between the tempera-
tures of the gas stream Immediately
before and after the catalyst bed), as
measured by the temperature monitor-
Ing device. Is less than 80 percent of
the design temperature difference, or.
(3) Each 3-hour period of operation
during which the average VOC con-
centration level or reading of organlcs
In the exhaust gases from a carbon ad-
sorber Is more than 20 percent greater
than the design exhaust gas concen-
tration level or reading.
If compliance with the provisions
of this subpart Is delayed pursuant to
160.892-7, the notification required
under 40 CFR 60.7(a>(4> shall Include
the estimated date of the next sched-
uled refinery or process unit shutdown
after the dale of notification and the
reason why compliance with the
standards Is technically Impossible
without a rellnery or process unit
shutdown.
Environmental Protection Agency
(Approved by the Office of Management
wid Budget under control number 2060-
011JI
| 60 699 Delegation of authority
(a) III delegating Implementation
and enforcement authority to a State
ujider section 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
Stale.
(b) Authorities which will not be del-
egated to Stales:
Subpart RRR—(Reserved)
Subpart SSS—Standards ol Perform-
ance for Magnetic Tape Coating
Facilities
Soirmct: 63 PR 3BB14. Oct. i. IBM. unleM
otherwise noted.
160.710 Applicability and destination of
affected facility.
(a) The affected facilities to which
the provisions of this subpart apply
are:
(1) Each coating operation: and
(2) Each piece of coating mix prepa-
ration equipment.
(b) Any new coaling operation that
utilizes less than 38 m* of solvent or
any modified or reconstructed coaling
operation thai utilizes less than 310
m> of solvent for the manufacture of
magnetic tape per calendar year Is
subject only to the requirements of
I 60.1U(a>. I 60.117(0), and | 80.111(0.
If the amount of solvent utilized for
the manufacture of magnetic tape
equals or exceeds these amounts In
any calendar year, the facility Is sub-
ject to 160.112 and all other sections
of this subpart. Once a facility has
become subject to 160.V12 and all
other sections of this subpart. It will
remain subject to those requirements
regardless of changes In annual sol-
vent utilization.
tc) This subpart applies to any af-
fected facility for which construction,
modification, or reconstruction begins
after January 22. 1986.
§ 60.711
060.711 nennlliom, • rmholi. »"J trim
reference Ublea
(a) All terms used In tills subparl
thai are not defined below have Hie
meaning given to them In the Act ajid
In Subpart A ol this part
(1) Base film means Ihe substrate
that Is coaled lo produce magnetic
Upe.
(2) Capture si/jl.
(10) Drying oven means a chamber
In which heal Is used to bake. cure, po-
lymerize, or dry a surface coating.
592
593
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APPENDIX C
40 CFR 60 Subparts K, Ka, and Kb
New Source Performance Standard for Storage Tanks
-------
o
§60.108
the outlet continuous monitoring
system;
(III) Identification of times when
hourly averages have been obtained
based on manual sampling methods;
(Iv) Identification ot the times when
the pollutant concentration exceeded
full span of the continuous monitoring
system: and
(v) Description of any modifications
to the continuous monitoring system
that could aifect tl)e ability of the
continuous 'monitoring system to
comply with Performance Specifica-
tions 2 or 3.
(vl) Results of dally drift tests and
quarterly accuracy assessments as re-
quired under appendix F. Procedure 1.
(5) If subject to 160.104(b><2>, for
each day In which a Method 8 sample
result was not obtained, the date for
which and brief explanation as to why
a Method 8 sample result was not ob-
tained, for approval by the Adminis-
trator.
(6) If subject to 160.104<3>, for
1 each 8-hour shift In which a feed
sulfur measurement was not obtained.
the date for which and brief explana-
tion as to why a feed sulfur measure-
ment was not obtained, for approval
by the Administrator.
(d) If no exceedances (as defined In
paragraphs (cXIMI) through (CXIMIII)
and (c)(2) of this section) occur In a
quarter, and If the owner or operator
has not changed the standard under
I 60.104(b) under which compliance Is
obtained, then the owner or operator
may submit a semiannual report In
which a statement Is Included that
states that no exceedances had oc-
curred during the affected quarter(s).
If the owner or operator elects to
comply with an alternative provision
of I 60.104(b>. a quarterly report must
be submitted for the quarter during
which a change occurred.
(e) For any periods for which sulfur
dioxide or oxides emissions data are
not available, the owner or operator of
the affected facility shall submit a
signed statement Indicating If any
changes were made In operation of the
emission control system during the
period of data unavailability which
could affect the ability of the system
to meet the applicable emission limit.
Operations of the control system and
40 CFR Ch. I (7-1-90 Edition)
affected facility during periods of data
unavailability are to be compared with
operation of the control system and
affected facility before and following
the period of data unavailability.
(f) The owner or operator of the af-
fected facility shall submit a signed
statement certifying the accuracy and
completeness of the Information con-
tained In the report.
(Approved by the Office of Management
and Budget under control number 2080-
0011)
(54 FR 34029. Auf. IT, 1*801
8 60.108 Performance left and compliance
provlalona.
(a) Section 60.8(d) shall apply to the
Initial performance test specified
under paragraph (c) of this section.
but not to the dally performance tests
required thereafter as specified In
|80.108(d). Section 80.8(f) does not
apply when determining compliance
with the standards specified under
180.104 shall meet
that standard at all tunes. Including
periods of startup, shutdown, and mal-
functions.
(c) The Initial performance test shall
consist of the Initial 7-day average cal-
culated for compliance with
i 60.104(b)(l), (b)(2). or (b)(3>.
(d) After conducting the Initial per-
formance test prescribed under I 80.8,
the owner or operator of a fluid cata-
lytic cracking unit catalyst regenera-
tor subject to i 60.104 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 shall not be
delegated to States:
•U) Section 80.105(a>(13)(lll>.
(2) Section 80.108(g)U2>.
[94 FR 34031, Aug. 17. 1»8B]
Subpnrt K—Stondordi of Perform-
ance for Storage Veitoli for Pe-
troleum Liquids for Which Con-
struction, Reconstruction, or
Modification Commenced After
June 11, 1973, and Prior to May
19, 197S
D 60.110 Applicability and deilfnallon of
affected facility.
(a) Except as provided In | 60.110(b).
the affected facility to which this sub-
part applies Is each storage vessel for
petroleum liquids which has a storage
capacity greater than 151,412 liters
(40,000 gallons).
(b) This subpart does not apply to
storage vessels for petroleum or con-
densate stored, processed, and/or
treated at a drilling and production fa-
cility prior to custody transfer.
§60.111
(c) Subject to the requirements of
this subpart Is any facility under para-
graph (a) of this section which:
(1) Has a capacity greater than 151,
416 liters (40,000 gallons), but not ex-
ceeding 246.052 liters (65.000 gallons).
and commences construction or modi-
fication after March 8. 1974. and prior
to May 19, 1978.
(2) Has a capacity greater than
246,052 liters (65,000 gallons) and com-
mences construction or modification
alter June 11. 1973. and prior to May
IB. 1978.
[42 FR 37937. July 25. 1977. as amended at
45 FR 23378. Apr. 4. 1980]
060.111 Definitions
As used In this subpart, all terms not
defined herein shall have the meaning
given them In the Act and In Subpart
A of this part.
(a) Storage vessel means any tank.
reservoir, or container used for the
storage of petroleum liquids, but does
not Include:
(1) Pressure vessels which are de-
signed to operate In excess of 15
pounds per square Inch gauge without
emissions to the atmosphere except
under emergency conditions.
(2) Subsurface caverns or porous
rock reservoirs, or
(3) Underground tanks If the total
volume of petroleum liquids added to
and taken from a tank annually does
not exceed twice the volume of the
tank.
(b) Petroleum liquidj means pi-lrole-
um. condensate, and any finished or
Intermediate products manufactured
In a petroleum refinery but does not
mean Nos. 2 through 6 fuel oUs as
specified In ASTM D396-78. gas tur-
bine fuel oils Nos. 2-GT through 4-GT
as specified In ASTM D2880-78. or
dlesel fuel oils Nos. 2-D and 4-D as
specified In ASTM D975-78. (These
three methods are Incorporated by ref-
erence—see 160.17.)
(c) Petroleum refinery means each
facility engaged In producing gasoline.
kerosene, distillate fuel oils, residual
fuel oils, lubricants, or other products
through distillation of petroleum or
through redistillation, cracking, ex-
tracting, or reforming of unfinished
petroleum derivatives.
316
317
-------
o
rb
§60.112
(d) Petroleum means the crude oil
removed from the earth and the oils
derived from tar sands, shale, and coal.
Drilling and production facility
means all drilling and aervlclng equip-
ment, wells, flow lines, separator!.
equipment, gathering lines, and auxil-
iary nontransportatlon-related equip-
ment used In the production ol petro-
leum but does not Include natural gas-
oline plants.
(1) True vapor pressure means the
equilibrium partial pressure exerted
by a petroleum liquid as determined In
accordance with methods described In
American Petroleum Institute Bulletin
2517, Evaporation Loss from External
Floating-Roof Tanks. Second Edition.
February 1980 (Incorporated by refer-
ence—see 160.11).
(J) Floating roof means a storage
vessel cover consisting of a double
deck, pontoon' single deck. Internal
floating cover or covered floating roof,
which rests upon and U supported by
the petroleum liquid being contained.
and Is equipped with a closure seal or
seals to close the space between the
roof edge and tank wall.
(k) Vapor recovery tvttem means a
vapor gathering system capable of col-
lecting all hydrocarbon vapors and
gases discharged from the storage
vessel and a vapor disposal system ca-
pable of processing such hydrocarbon
vapors and gases so as to prevent their
emission to the atmosphere.
(1) Reid vapor pressure Is the abso-
lute vapor pressure of volatile crude
oil and volatile nonvlscous petroleum
liquids, except liquified petroleum
gases, as determined by ASTM D323-
82 (Incorporated by reference—see
I 60.17).
40 CFR Ch. I (7-1-90 Edition)
(39 PR »317. Mar. 8. 1914; 39 PR 13176. Apr
17, 1874, u amended it 39 PR 20714. June
14, 1974; 45 PR 23379, Apr. 4. 1980: 48 PR
3737. Jan. 27. 1983; 52 PR 11429, Apr B
1987)
060.112 Standard for volatile orfanlc
compoundi (VOC).
(a) The owner or operator of any
storage vessel to which this subpart
applies shall store petroleum liquids as
follows:
(1) If the true vapor pressure of the
petroleum liquid, as stored. Is equal to
or greater than 78 nun Hg (1.5 psla)
but not greater than 570 mm Hg (11.1
psla). the storage vessel shall be
equipped with a floating roof, a vapor
recovery system, or their equivalents.
(2) If the true vapor pressure of the
petroleum liquid as stored Is greater
than 670 mm Hg (11.1 psla), the stor-
age vessel shall be equipped with a
vapor recovery system or Its equiva-
lent.
(39 PR nil. Mar. 8. 1974; 39 PR 13778. Apr.
11. 1914. u amended at 45 FR 23319. Apr. 4.
19801
I «0.113 Monitoring ol operation!.
(a) Except as provided In paragraph
(d) of this section, the owner or opera-
tor subject to this subpart shall main-
tain a record of the petroleum liquid
stored, the period of storage, and the
maximum true vapor pressure of that
liquid during the respective storage
period.
(b) Available data on the typical
Reid vapor pressure and the maximum
expected storage temperature of the
stored product may be used to deter-
mine the maximum true vapor pres-
sure from nomographs contained In
API Bulletin 2517, unless the Adminis-
trator specifically requests that the
liquid be sampled, the actual storage
temperature determined, and the Reid
vapor pressure determined from the
sample(s).
(c) The true vapor pressure of each
type of crude oil with a Reid vapor
pressure less than 13.8 kPa (2.0 psla)
or whose physical properties preclude
determination by the recommended
method Is to be determined from avail-
able data and recorded If the estimat-
ed true vapor pressure Is greater than
6.9 kPa (1.0 psla).
Environmental Protection Agency
(d) The following are exempt from
the requirements of this section:
(1) Each owner or operator of each
affected facility which stores petrole-
um liquids with a Reid vapor pressure
of less than 6.9 kPa (1.0 psla) provided
the maximum true vapor pressure
does not exceed 6.9 kPa (1.0 psla).
(2) Each owner or operator of each
affected facility equipped with a vapor
recovery and return or disposal system
In accordance with the requirements
of I 60.112.
[<5 PR 23379, Apr. 4. 1080]
Subport Ko—Standard! of Perform-
ance for Storage VeiieU far Pe-
troleum Liquids for Which Con-
struction, Reconstruction, or
Modification Commenced After
May 18, 1978, and Prior to July
23, 1984
ie0.110» Applicability and delimitation of
affected facility.
(a) Except as provided In paragraph
(b) of this section, the affected facility
to which this subpart applies Is each
storage vessel for petroleum liquids
which has a storage capacity greater
than 151,416 liters (40.000 gallons) and
for which construction Is commenced
after May 18. 1978.
(b) Each petroleum liquid storage
vessel with a capacity of less than
1.589.873 liters (420.000 gallons) used
for petroleum or condensate stored,
processed, or treated prior to custody
transfer Is not an affected facility and.
therefore. Is exempt from the require-
ments of this subpart.
(45 FR 23319, Apr. 4. 1980)
« 60.111. Definition*.
In addition to the terms and their
definitions listed In the Act and Sub-
Part A of this part the following defi-
nitions apply In this subpart:
(a) Storage vessel means each tank,
reservoir, or container used for the
itorage of petroleum liquids, but does
not Include:
(1) Pressure vessels which are de-
signed to operate In excess of 204.9
kp» (15 pslg) without emissions to the
•tmosphere except under emergency
conditions.
§60.11 la
(2) Subsurface caverns or porous
rock reservoirs, or
(3) Underground tanks if the total
volume of petroleum liquids added Lo
and taken from a tank annually does
not exceed twice the volume of the
tank.
(b) Petroleum liquids means petrole-
um, condensate, and any finished or
Intermediate products manufactured
In a petroleum refinery but does not
mean Nos. 2 through 6 fuel oils as
specified In ASTM D396-78. gas tur-
bine fuel oils Nos. 2-OT through 4-OT
as specified In ASTM D2880-18, gas
turbine fuel oils Nos. 2-GT through 4-
OT as specified In ASTM D2880-78, or
dlesel fuel oils Nos. 2-D and 4-D as
specified In ASTM D975-78. (These
three methods are Incorporated by ref-
erence—see | 60.17.)
(c) Petroleum refinery means each
facility engaged In producing gasoline,
kerosene, distillate fuel oils, residual
fuel oils, lubricants, or other products
through distillation of petroleum or
through redistillation, cracking, ex-
tracting, or reforming of unfinished
petroleum derivatives.
(d) Petroleum means the crude oil
removed from the earth and the oils
derived from tar sands, shale, and coal.
(e) Condemate means hydrocarbon.
liquid separated from natural gas
which condenses due to changes In the
temperature or pressure, or both, and
remains liquid at standard conditions.
(f) True vapor pressure means the
equilibrium partial pressure exerted
by a petroleum liquid such as deter-
mined In accordance with methods de-
scribed In American Petroleum Insti-
tute Bulletin 2517, Evaporation Loss
from External Floating-Roof Tanks,
Second Edition. February 1980 (Incor-
porated by reference—see I 60.17).
(g) Reid vapor pressure Is the abso-
lute vapor pressure of .volatile crude
oil and nonvlscous petroleum liquids,
except liquified petroleum gases, as
determined by ASTM D323-82 (Incor-
porated by reference—see I 60.17).
(h) Liquid-mounted seal means a
foam or liquid-filled primary seal
mounted In contact with the liquid be-
tween the tank wall and the floating
roof continuously around the circum-
ference of the tank.
318
319
-------
o
G)
§ 60.112a
(I) Metallic shoe teal Includes but la
not limited to a metal sheet held verti-
cally against the tank wall by springs
or weighted levers and Is connected by
braces to the floating roof. A flexible
coated fabric (envelope) spans the an-
nular space between the metal sheet
and the floating rcof.
(J) Vapor-mounted teal means a
foam-filled primary seal mounted con-
tinuously around the circumference of
the tank so there Is I an annular vapor
space underneath the seal. The annu-
lar vapor space Is bounded by the
bottom of the primary seal, the tank
wall, the liquid surface, and the float-
Ing roof.
(k) Custody transfer means the
transfer of produced petroleum and/
or condensate. after processing and/or
treating In the producing operations.
from storage tanks or automatic trans-
fer facilities to pipelines or any other
forms of transportation.
(45 FR 23378. Apr. 4. 1980. ai amended at 48
FR 3737, Jan. 27. 19(3; 19 FR 1149*. Apr. S.
19871
860.112. Standard for volatile organic
eompoundi (VOC).
(a) The owner or operator of each
storage vessel to which this subpart
applies which contains a petroleum
liquid which, as stored, has a true
vapor pressure equal to or greater
than 10.3 tPa (1.5 psla) but not great-
er than 76.6 kPa (11.1 psla) shall equip
the storage vessel with one of the fol-
lowing:
(1) An external floating roof, con-
sisting of a pontoon-type or double-
deck-type cover that rests on the sur-
face of the liquid contents and Is
equipped with a closure device be-
tween the tank wall and the roof edge.
Except as provided In paragraph
(a)( 1XIIKD) of this section, the closure
device Is to consist of two seals, one
above the other. The lower seal Is re-
ferred to as the primary seal and the
upper seal Is referred to as the second-
ary seal. The roof Is to be floating on
the liquid at all tunes (I.e.. off the roof
leg supports) except during Initial fill
and when the tank Is completely emp-
tied and subsequently refilled. The
process of emptying and refilling when
the roof Is resting on the leg supports
40CFRCH. I (7-1-90 tdlilon)
shall be continuous and shall be ac-
complished as rapidly as possible.
(1) The primary seal Is to be either a
metallic shoe seal, a liquid-mounted
seal, or a vapor-mounted seal. Each
seal Is to meet the following require-
ments:
(A) The accumulated area of gaps
between the tank wall and the metal-
lic shoe seal or the liquid-mounted seal
shall not exceed 212 cm* per meter of
tank diameter (10.0 In ' per ft of tank
diameter) and the width of any por-
tion of any gap shall not exceed 3.81
cm UK In).
(B) The accumulated area of gaps
between the tank wall and the vapor-
mounted seal shall not exceed 21.2 cm'
per meter of tank diameter (1.0 In* per
ft of tank diameter) and the width of
any portion of any gap shall not
exceed 1.27 cm (M In).
(C) One snd of the metallic shoe Is
to extend Into the stored liquid and
the other end Is to extend a minimum
vertical distance of 61 cm (24 In) above
the stored liquid surface.
(D) There are to be no holes, tears,
or other openings In the shoe, seal
fabric, or seal envelope.
(11) The secondary seal is to meet the
following requirements:
(A) The secondary seal Is to be In-
stalled above the primary seal so that
It completely covers the space between
the roof edge and the tank wall except
as provided In paragraph (aXIXIIXB)
of this section.
(B) The accumulated area of gaps
between the tank wall and the second-
ary seal used In combination with a
metallic shoe or liquid-mounted pri-
mary seal shall not exceed 21.2 cm* per
meter of tank diameter (1.0 In' per ft.
of tank diameter) and the width of
any portion of any gap shall not
exceed 1.27 cm (H In.). There shall be
no gaps between the tank wall and the
secondary seal used In combination
with a vapor-mounted primary seal.
(C) There are to be no holes, tears or
other openings In the seal or seal
fabric.
(D) The owner or operator Is ex-
empted from the requirements for sec-
ondary seato and the secondary seal
gap criteria when performing gap
measurements or Inspections of the
primary seal.
Environmental Protection Agency
(III) Each opening In the roof except
for automatic bleeder vents and rim
space vents Is to provide a projection
below the liquid surface. Each opening
In the roof except for automatic bleed-
er vents, rim space vents and leg
sleeves Is to be equipped with a cover.
seal or lid which Is to be maintained In
a closed position at all times (I.e., no
visible gap) except when the device Is
In actual use or as described In par-
graph (a)(l)(lv) of this section. Auto-
matic bleeder vents are to be closed at
all times when the roof Is floating,
except when the roof Is being floated
off or Is being landed on the roof leg
supports. Rim vents are to be set to
open when the roof Is being floated off
the roof legs supports or at the manu-
facturer's recommended setting.
(Iv) Each emergency roof drain Is to
be provided with a slotted membrane
fabric cover that covers at least 90 per-
cent of the area of the opening.
(2) A fixed roof with an Internal
floating type cover equipped with a
continuous closure device between the
tank wall and the cover edge. The
cover Is to be floating at all times, (I.e.,
off the leg supports) except during Ini-
tial fill and when the tank Is complete-
ly emptied and subsequently refilled.
The process of emptying and refilling
when the cover Is resting on the leg
supports shall be continuous and shall
be accomplished as rapidly as possible.
Each opening In the cover except for
automatic bleeder vents and the rim
space vents Is to provide a projection
below the liquid surface. Each opening
In the cover except for automatic
bleeder vents, rim space vents, stub
drains and leg sleeves Is to be equipped
• with a cover, seal, or lid which Is to be
maintained In a closed position at all
times (I.e.. no visible gap) except when
the device Is In actual use. Automatic
bleeder vents are to be closed at all
times when the cover Is floating
except when the cover Is being floated
off or Is being landed on the leg sup-
ports. Rim vents are to be set to open
only when the cover Is being floated
off the leg supports or at the manufac-
turer's recommended setting.
(3) A vapor recovery system which
collects all VOC vapors and gases dis-
charged from the storage vessel, and a
vapor return or disposal system which
§ 60.113a
Is designed to process such VOC
vapors and gases so as to reduce their
emission to the atmosphere by at least
95 percent by weight.
(4) A system equivalent to those de-
scribed In paragraphs (axl). (a)(2). or
(a)(3) of this section as provided In
I SO. 114a.
(b) The owner or operator of each
storage vessel to which this subpart
applies which contains a petroleum
liquid which, as stored, has a true
vapor pressure greater than 76.8 kPa
(11.1 psla), shall equip the storage
vessel with a vapor recovery system
which collects all VOC vapors and
gases discharged from the storage
vessel, and a vapor return or disposal
system which Is designed to process
such VOC vapors and gases so as to
reduce their emission to the atmos-
phere by at least 95 percent by weight.
[45 FR 23379. Apr. 4. 1980. u amended at 45
FR 83229, Dec. 18. 1980)
0 60.113a Testing and procedure!.
(a) Except as provided In 5 60.8(b)
compliance with the standard pre-
scribed In 160.112a shall be deter-
mined as follows or In accordance with
an equivalent procedure as provided In
I 60.1 Ma.
(1) The owner or operator of each
storage vessel to which this subpart
applies which has an external floating
roof shall meet the following require-
ments:
(I) Determine the gap areas and
maximum gap widths between the pri-
mary seal and the tank wall and be-
tween the secondary seal and the tank
wall according to the following fre-
quency:
(A) For primary seals, gap measure-
ments shall be performed within 60
days of the Initial till with petroleum
liquid and at least once every five
years thereafter. All primary seal In-
spections or gap measurements which
require the removal or dislodging of
the secondary seal shall be accom-
plished as rapidly as possible and the
secondary seal shall be replaced as
soon as possible.
(B) For secondary seals, gap meas-
urements shall be performed within 60
days of the Initial fill with petroleum
320
321
-------
o
§ 60.1Mo
liquid and at least once every year
thereafter.
(C) If any storage vessel Is out of
service for a period of one year or
more, subsequent refilling with petro-
leum liquid shall be considered Initial
fill for the purpose* of paragraphs
(aXIXIXA) and (aXIXIXB) of this sec-
tion.
" diameter uni-
form probe passes freely (without
forcing or binding against seal) be-
tween the seal and the tank wall and
measure the circumferential distance
of each such location.
(C) The total surface area of each
gap described In paragraph
(aXIXIlXB) of this section shall be de-
termined by using probes of various
widths to accurately measure the
actual distance from the tank wall to
the seal and multiplying each such
40 CFR Ch. I (7-1-90 Edition)
width by Its respective circumferential
distance.
(Ill) Add the gap surface area of each
gap location for the primary seal and
the secondary seal Individually. Divide
the sum for each seal by the nominal
diameter of the tank and compare
each ratio to the appropriate ratio In
the standard In I «0.112a(a)UKI> and
I 60.112a(a)(l)(ll).
(lv> Provide the Administrator 30
days prior notice of the gap measure-
ment to afford the Administrator the
opportunity to have an observer
present.
(2) The owner or operator of each
storage vessel to which this subpart
applies which has a vapor recovery
and return or disposal system shall
provide the following Information to
the Administrator on or before the
date on which construction of the
storage vessel commences:
(I) Emission data. If available, for a
similar vapor recovery and return or
disposal system used on the same type
of storage vessel, which can be used to
determine the efficiency of the
system. A complete description of the
emission measurement method used
must be Included.
(11) The manufacturer's design speci-
fications and estimated emission re-
duction capability of the system.
(Ill) The operation and maintenance
plan for the system.
(Iv) Any other Information which
will be useful to the Administrator In
evaluating the effectiveness of the
system In reducing VOC emissions.
149 PR 23171. Apr. 4.1MO. as amended tl 92
PR 1141*. Apr. 8. 1687)
ICO.lUa Alternative means of emliilon
limitation.
(a) If. In the Administrator's Judg-
ment, an alternative means of emis-
sion limitation will achieve a reduction
In emissions at least equivalent to the
reduction In emissions achieved by any
requirement In I ao.UZa. the Adminis-
trator will publish In the FEDERAL REG-
ISTEB a notice permitting the use of
the alternative means for purposes of
compliance with that requirement.
(b) Any notice under paragraph (a)
of this section will be published only
Environmental Protection Agency
after notice and an opportunity for a
hearing.
(c) Any person seeking permission
under this section shall submit to the
Administrator a written application In-
cluding:
(1) An actual emissions test that
uses a full-sized or scale-model storage
vessel that accurately collects and
measures all VOC emissions from a
given control device and that accurate-
ly simulates wind and accounts for
other emission variables such as tem-
perature and barometric pressure.
(2) An engineering evaluation that
the Administrator determines Is an ac-
curate method of determining equiva-
lence.
(d) The Administrator may condi-
tion the permission on requirements
that may be necessary to ensure oper-
ation and maintenance to achieve the
same emissions reduction as specified
In | eO.llZa.
(e) The primary vapor-mounted seal
In the "Volume-Maximizing Seal"
manufactured by R.F.I. Services Cor-
poration Is approved as equivalent to
the vapor-mounted seal required by
I60.112a(a)(l)(l> and must meet the
gap criteria specified In
I e0.112a(a)(l)(l)(B). There shall be no
gaps between the tank wall and any
secondary seal used In conjunction
with the primary seal In the "Volume-
Maximizing Seal".
(91 FR 11431. Apr. «. HID
OCO.llSa Monitoring of operations.
(a) Except as provided In paragraph
(d) of this section, the owner or opera-
tor subject to this subpart shall main-
tain a record of the petroleum liquid
stored, the period of storage, and the
maximum true vapor pressure of that
liquid during the respective storage
period.
(b) Available data on the typical
Reid vapor pressure and the maximum
expected storage temperature of the
stored product may be used to deter-
mine the maximum true vapor pres-
sure from nomographs contained In
. API Bulletin 2517, unless the Adminis-
trator specifically requests that the
liquid be sampled, the actual storage
temperature determined, and the Reid
vapor pressure determined from the
sample(s).
§ 60.11 Ob
Cc) The true vapor pressure of each
type of crude oil with a Reid vapor
pressure less than 13.8 kPa (20 psla)
or whose physical properties preclude
determination by the recommended
method Is to be determined from avail-
able data and recorded If the estimat-
ed true vapor pressure Is greatei than
6.9kPa(1.0 psla)
(d) The following are exempt from
the requirements of this section:
(1) Each owner or operator of each
storage vessel storing a petroleum
liquid with a Reid vapor pressure of
less than 6.9 kPa (1.0 psla) provided
the maximum true vapor pressure
does not exceed 6.9 kPa (1 0 psla).
(2) Each owner or operator of each
storage vessel equipped with a vapor
recovery and return or disposal system
In accordance with the requirements
of |60.112a(a)(3)and(b).
(45 FR 33379. Apr. 4. 1980)
Subpart Kb—Standards of Perform-
ance for Volatile Organic Liquid
Storage Vessels (Including Petro-
leum Liquid Storage Vessels) for
Which Construction, Reconstruc-
tion, or Modification Commenced
after July 23, 1984
SODKCI: 93 FR 1U39. Apr. 1. 1981, unleu
otherwise noted.
iSO.IlOb Applicability and designation of
affected facility.
(a) Except as provided In paragraphs
(b). (c). and (d) of this section, the af-
fected facility to which this subpart
applies Is each storage vessel with a ca-
pacity greater than or equal to 40
cubic meters (m*) that Is used to store
volatile organic liquids (VOL's) for
which construction, reconstruction, or
modification Is commenced after July
23, 1984.
(b) Except as specified In paragraphs
(a) and (b) of I 60.116b. storage vessels
with design capacity less than 75 m'
are exempt from the General Provi-
sions (part 60, subpart A) and from
the provisions of this subpart.
(c) Except as specified In paragraphs
(a) and (b) of J60.116b. vessels either
with a capacity greater than or equal
to 151 m1 storing a liquid with a maxl-
322
323
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9
Oi
§60.1 lib
mum true vapor pressure less than 3.5
kPa or with a capacity greater than or
equal to 75 m' but less than 151 m'
storing a liquid with a maximum true
vapor pressure less than 15.0 kPa are
exempt from the General Provisions
(part 60. subpart A) and from the pro-
visions of this subpart.
(d) This subpart does not apply to
the following:
(1) Vessels at coke oven by-product
plants. .
(2) Pressure vessels designed to oper-
ate In excess of 204.9 kPa and without
emissions to the atmosphere.
(3) Vessels permanently attached to
mobile vehicles such as trucks, rail-
cars, barges, or ships.
(4) Vessels with a design capacity
less than or equal to 1,580.874 m* used
for petroleum or condeniate stored,
processed, or treated prior to custody
transfer.
(5) Vessels located at bulk gasoline
plants.
• (6) Storage vessels located at gaso-
•Une service stations.
(7) Vessels used to store beverage al-
•Johol.
[52 FR 1142B. Apr. I, 1(87, u amended »t 64
PR 33*7]. Au«. 11. l»e»)
8 60.11 Ib Definition..
Terms used In this subpart are de-
fined In the Act, In Subpart A of this
part, or In this subpart as follows:
(a) Bulk gas flint plant means any
gasoline distribution facility that has
a gasoline throughput less than or
equal to 75.700 liters per day. Gasoline
throughput shall be the maximum cal-
culated design throughput as may be
limited by compliance with an enforce-
able condition under Federal require-
ment or Federal, State or local law,
and discoverable by the Administrator
and any other person.
(b) Condeniate means hydrocarbon
liquid separated from natural gas that
condenses due to changes In the tem-
perature or pressure, or both, and re-
mains liquid at standard conditions.
(c) Custody transfer means the
transfer of produced petroleum and/
or condensate, after processing and/or
treatment In the producing operations.
from storage vessels or automatic
transfer facilities to pipelines or any
other forms of transportation.
40 CFR Ch. I (7-1-90 Edition)
(d) fill means the Introduction or
VOL Into a storage vessel but not nec-
essarily to complete capacity.
(e) Gasoline service station means
any site where gasoline Is dispensed to
motor vehicle fuel tanks from station-
ary storage tanks.
(f) Maximum true vapor pressure
means the equilibrium partial pressure
exerted by the stored VOL at the tem-
perature equal to the highest calen-
dar-month average of the VOL storage
temperature for VOL's stored above or
below the ambient temperature or at
the local maximum monthly average
temperature as reported by the Na-
tional Weather Service for VOL's
stored at the ambient temperature, as
determined:
(1) In accordance with methods de-
scribed In American Petroleum Insti-
tute Bulletin 2517. Evaporation Loss
From External Floating Roof Tanks,
(Incorporated by reference—see
I 60.17): or
(2) As obtained from standard refer-
ence texts: or
(3) As determined by ASTM Method
D2879-83 (Incorporated by reference-
see I 60.17);
(4) Any other method approved by
the Administrator.
(g) Reid vapor pressure means the
absolute vapor pressure of volatile
crude oil and volatile nonvlscous pe-
troleum liquids except liquified petro-
leum gases, as determined by ASTM
D323-82 (Incorporated by reference-
see I 60.17).
(h) Petroleum means the crude oil
removed from the earth ahd the oils
derived from tar sands, shale, and coal.
(I) Petroleum liQuids means petrole-
um, condensate. and any finished or
Intermediate products manufactured
In a petroleum refinery.
(j) Storage vessel means each tank,
reservoir, or container used for the
storage of volatile organic liquids but
does not Include:
(1) Frames, housing, auxiliary sup-
ports, or other components that are
not directly Involved In the contain-
ment of liquids or vapors; or
(2) Subsurface caverns or porous
rock reservoirs.
(k) Volatile organic liquid (VOL)
means any organic liquid which can
emit volatile organic compounds Into
Environmental Protection Agency
the atmosphere except those VOL's
that emit only those compounds
which the Administrator has deter-
mined do not contribute appreciably
to the formation of ozone. These com-
pounds are Identified In EPA state-
ments on ozone abatement policy for
SIP revisions (42 FR 35314, 44 FR
32042. 45 FR 32424, and 45 FR 48941).
(I) Waste means any liquid resulting
from Industrial, commercial, mining or
agricultural operations, or from com-
munity activities that Is discarded or Is
being accumulated, stored, or physical-
ly, chemically, or biologically treated
prior to being discarded or recycled.
[51 FR 114». Apr. t. 1»87. u amended at 64
FR 33873. Aug. 11, 18891
Standard for Tolatlle orfvnlc
compound! (VOC).
(a) The owner or operator of each
storage vessel either with a design ca-
pacity greater than or equal to 151 m'
containing a VOL that, as stored, has
a maximum true vapor pressure equal
to or greater than 5.2 kPa but lesi
than 76.6 kPa or with a design capac-
ity greater than or equal to 75 m1 but
less than 151 m* containing a VOL
that, as stored, has a maximum true
vapor pressure equal to or greater
than 27.6 kPa but less than 78.6 kPa.
shall equip each storage vessel with
one of the following:
(DA fixed roof In combination with
an Internal floating roof meeting the
following specifications:
(I) The Internal floating roof shall
rest or float on the liquid surface (but
not necessarily In complete contact
with It) Inside a storage vessel that has
a fixed roof. The Internal floating roof
shall be floating on the liquid surface
at all times, except during Initial fill
and during those Intervals when the
storage vessel Is completely emptied or
subsequently emptied and refilled.
When the roof Is resting on the leg
supports, the process of filling, empty-
Ing, or refilling shall be continuous
and shall be accomplished as rapidly
as possible.
(II) Each Internal floating roof shall
be equipped with one of the following
closure devices between the wall of the
storage vessel and the edge of the In-
ternal floating roof:
§60.112b
(A) A foam-or liquid filled seal
mounted In contact with the liquid
(liquid-mounted seal). A liquid-mount-
ed seal means a foam-or liquid-filled
seal mounted In contact with the
liquid between the wall of the storage
vessel and the floating roof continu-
ously around the circumference of the
tank.
(B) Two seals mounted one above
the other so that each forma a contin-
uous closure that completely covers
the space between the wall of the stor-
age vessel and the edge of the Internal
floating roof. The lower seal may be
vapor-mounted, but both must be con-
tinuous.
(C) A mechanical shoe seal. A me-
chanical shoe seal Is a metal sheet
held vertically against the wall of the
storage vessel by springs or weighted
levers and Is connected by braces to
the floating roof. A flexible coated
fabric (envelope) spans the annular
space between the metal sheet and the
floating roof.
(Ill) Each opening In a noncontact
Internal floating roof except for auto-
matic bleeder venU (vacuum breaker
vents) and the rim space vents Is to
provide a projection below the liquid
surface.
(Iv) Each opening In the Internal
floating roof except for leg sleeves.
automatic bleeder vents, rim space
vents, column wells, ladder wells.
sample wells, and stub drains Is to be
equipped with a cover or lid which Is
to be maintained In a closed position
at all times (I.e., no visible gap) except
when the device Is In actual use. The
cover or lid shall be equipped with a
gasket. Covers on each access hatch
and automatic gauge float well shall
be bolted except when they are In use.
(v) Automatic bleeder vents shall be
equipped with a gasket and are to be
closed at air times when the roof Is
floating except when the roof Is being
floated off or Is being landed on the
roof leg supports.
(vl) Rim space vents shall be
equipped with a gasket and are to be
set to open only when the Internal
floating roof Is not floating or at the
manufacturer's recommended setting.
(vll) Each penetration of the Inter-
nal floating roof for the purpose of
sampling shall be a sample well. The
324
325
-------
o
dn
§60.113b
sample well shall have a silt fabric
cover that covers at least 90 percent of
the opening.
(vlll) Each penetration of the Inter-
nal floating roof that allows for pas-
sage of a column supporting the fixed
roof shall have a flexible fabric sleeve
seal or a gasketed sliding cover.
(Ix) Each penetration of the Internal
floating roof that allows for passage of
a ladder shall have • gasketed sliding
cover. I
(2) An external floating roof. An ex-
ternal floating roof means » pontoon-
type or double-deck type cover that
rests on the liquid surface In a vessel
with no fixed roof. Each external
floating roof must meet the following
specifications:
(I) Each external floating roof shall
be equipped with a closure device be-
tween the wall of the storage vessel
and the roof edge. The closure device
Is to consist of two seals, one above the
other. The lower seal to referred to as
pje primary seal, and the upper seal to
referred to as the secondary seal.
• (A) The primary seal shall be either
a mechanical shoe seal or a liquid-
mounted seal. Except a* provided In
160.113b(b)<4). the seal shall com-
pletely cover the annular apace be-
tween the edge of the floating roof
and tank wall.
(B) The secondary seal shall com-
pletely cover the annular space be-
tween the external floating roof and
the wall of the storage vessel In a con-
tinuous fashion except as allowed In
|60.113b(b)(4).
(II) Except for automatic bleeder
vents and rim space vents, each open-
Ing In a noncontact external floating
roof shall provide a projection below
the liquid surface. Except for auto-
matic bleeder vents, rim space vents.
roof drains, and leg sleeves, each open-
Ing In the roof Is to be equipped with a
gasketed cover, seal, or lid that to to be
maintained In a closed position at all
times (I.e.. no visible gap) except when
the device to In actual use. Automatic
bleeder vents are to be closed at all
times when the roof to floating -except
when the roof to being floated off or to
being landed on the roof leg supports.
Rim vents are to be set to open when
the roof to being floated off the roof
legs supports or at the manufacturer's
40 CFR Ch. I (7-1-90 Edition)
recommended setting. Automatic
bleeder vents and rim space v«nts are
to be gasketed. Each emergency roof
drain to to be provided with a slotted
membrane fabric cover that covers at
least 90 percent of the area of the
opening.
(Ill) The roof shall be floating oh the
liquid at all times (I.e., off the roof leg
supports) except during Initial fill
until the roof Is lifted off leg supports
and when the tank Is completely emp-
tied and subsequently refilled. The
process of filling, emptying, or refill-
ing when the roof to resting on the leg
supports shall be continuous and shall
be accomplished as rapidly u possible.
<3) A closed vent system and control
device meeting the following specifica-
tions:
(1) The closed vent system shall be
designed to collect all VOC vapors and
gases discharged from the storage
vessel and operated with no detectable
emissions as Indicated by an Instru-
ment reading of less than 500 ppm
above background and visual Inspec-
tions, as determined In part 60. Sub-
part W. I 60.485(b>.
(11) The control device shall be de-
signed and operated to reduce Inlet
VOC emissions by 95 percent or great-
er. If a flare to used as the control
device. It shall meet the specifications
described In the general control device
requirements (| 80.18) of the General
Provisions.
(4) A system equivalent to those de-
scribed In paragraphs (a)(l), (a)(2). or
(a)(3) of this section as provided In
I SO.lUb of this subpart.
(b) The owner or operator of each
storage vessel with a design rapacity
greater than or equal to 75 m' whlcn
contains a VOL that, as stored, has a
maximum true vapor pressure greater
than or equal to 76.6 kPa shall equip
each storage vessel with one of the fol-
lowing:
(DA closed vent system and control
device as specified In 160.112b(a)(3).
(2) A system equivalent to that de-
scribed In paragraph (bXl) as provided
In I 60.114b of this subpart.
tttUUb Toting and procedure!.
The owner or operator of each stor-
age vessel as specified In J60.112b(a)
Environmental Protection Agency
shall meet the requirements of para-
graph (a), (b). or (c) of this section.
The applicable paragraph for a par-
ticular storage vessel depends on the
control equipment Installed to meet
the requirements of I 60.112b.
(a) After Installing the control
equipment required to meet
I ao.H2b(a)(l) (permanently affixed
roof and Internal floating roof), each
owner or operator shall:
(1) Visually Inspect the Internal
floating roof, the primary seal, and
the secondary seal (If one to In serv-
ice), prior to filling the storage vessel
with VOL. If there are holes, tears, or
other openings In the primary seal,
the secondary seal, or the seal fabric
or defects In the Internal floating roof,
or both, the owner or operator shall
repair the Items before filling the stor-
age vessel.
(2> For Vessels equipped with a
liquid-mounted or mechanical shoe
primary seal, visually Inspect the In-
ternal floating roof and the primary
seal or the secondary seal (If one to In
service) through manholes and roof
hatches on the fixed roof at least once
every 12 months after Initial fill. If
the Internal floating roof to not resting
on the surface of the VOL Inside the
storage vessel, or there to liquid accu-
mulated on the roof, or the seal to de-
tached. or there are holes or tears In
the seal fabric, the owner or operator
shall repair the Items or empty and
remove the storage vessel from service
within 45 days. If a failure that to de-
tected during Inspections required In
this paragraph cannot be repaired
within 45 days and If the vessel cannot
be emptied within 45 days, a 30-day
extension may be requested from the
Administrator In the Inspection report
required In 1 60.115b(a)(3). Such a re-
quest for an extension must document
that alternate storage capacity to un-
available and specify a schedule of ac-
tions the company will take that will
assure that the control equipment will
be repaired or the vessel will be emp-
tied as soon as possible.
(3) For vessels equipped with a
double-seal system as specified In
(I) Visually Inspect the vessel as
specified In paragraph (a)(4) of this
section at least every 5 years: or
§60.113b
(II) Visually Inspect the vessel as
specified In paragraph (a)<2) of this
section.
(4) Visually Inspect the Internal
floating roof, the primary seal, the
secondary seal (If one Is In service).
gaskets, slotted membranes and sleeve
seals (If any) each time the storage
vessel to emptied and degassed. If the
Internal floating roof has defects, the
primary seal has holes, tears, or other
openings In the seal or the seal fabric.
or the secondary seal has holes, tears.
or other openings In the seal or the
seal fabric, or the gaskets no longer
close off the liquid surfaces from the
atmosphere, or the slotted membrane
has more than 10 percent open area.
the owner or operator shall repair the
Items as necessary so that none of the
conditions specified In this paragraph
extol before-refilling the storage vessel
with VOL. In no event shall Inspec-
tions conducted In accordance with
this provision occur at Intervals great-
er than 10 years In the case of vessels
conducting the annual visual Inspec-
tion as specified In paragraphs (a)(2)
and (a)(3(ll) of this section and at In-
tervals no greater than 5 years In the
case of vessels specified In paragraph
(a)(3)(l) of this section.
(5) Notify the Administrator In writ-
Ing at least 30 days prior to the filling
or refilling of each storage vessel for
which an Inspection Is required by
paragraphs (a)(l) and (a)(4) of this
section to afford the Administrator
the opportunity to have an observer
present. If the Inspection required by
paragraph (a>(4) of this section to not
planned and the owner or operator
could not have known about the In-
spection 30 days In advance or refilling
the tank, the owner or operator shall
notify the Administrator at least 7
days prior to the refilling of the stor-
age vessel. Notification shall be made
by telephone Immediately followed by
written documentation demonstrating
why the Inspection was unplanned. Al-
ternatively, this notification Including
the written documentation may be
made In writing and sent by express
mall so that It to received by the Ad-
ministrator at least 7 days prior to the
refilling.
(b) After Installing the control
equipment required to meet
326
327
-------
o
§60.113b
I 60.112b(B)(2) (external floating roof).
the owner or operator shall:
(1) Determine the gap areas and
maximum gap widths, between the pri-
mary seal and the wall of the storage
vessel and between the secondary seal
and the wall of the storage vessel ac-
cording to the following frequency.
(I) Measurement! of gaps between
the tank wall and the primary seal
(seal gaps) shall be performed during
the hydrostatic testing of the vessel or
within 60 days of the Initial fill with
VOL and at least once every 5 years
thereafter.
(II) Measurements of gaps between
the tank wall and the secondary seal
shall be performed within 60 days of
the Initial fill with VOL and at least
once per year thereafter.
(Ill) If any source ceases to store
VOL for a period of 1 year or more.
subsequent Introduction of VOL Into
the vessel shall be considered an Inl-
tlat-flll for the purposes of paragraphs
(b)iIKO and (bXIXIl) of this section.
(7; Determine gap widths and areas
In the primary and secondary seals In-
dividually by the following procedures:
(1) Measure seal gaps. If any. at one
or .more, floating roof levels when the
roof Is floating off the roof leg sup-
ports.
(II) Measure seal gaps around the
entire circumference of the tank In
each place where a 0.32-cm diameter
uniform probe passes freely (without
forcing or binding against seal) be-
tween the seal and the wall of the
storage vessel and measure the circum-
ferential distance of each such loca-
tion.
(Ill) The total surface area of each
gap described In paragraph (b)(2)(ll> of
this section shall be determined by
using probes of various widths to
measure accurately the actual distance
from the tank wall to the seal and
multiplying each such width by Its re-
spective circumferential distance.
(3) Add the gap surface area of each
gap location for the primary seal and
the secondary seal Individually and
divide the sum for each seal by the
nominal diameter of the tank and
compare each ratio to the respective
standards In paragraph (b>(4) of this
section.
40 CFR Ch. I (7-1-90 Edition)
(4) Make necessary repairs or empty
the storage vessel within 45 days of
Identification In any Inspection for
seals not meeting the requirements
listed In (b)(4)(l) and (II) of this sec-
tion:
(I) The accumulated area of gaps be-
tween the tank wall and the mechani-
cal shoe or liquid-mounted primary
seal shall not exceed 212 Cm* per
meter of tank diameter, and the width
of any portion of any gap shall not
exceed 3.81 cm.
(A) One end of the mechanical shoe
Is to extend Into the stored liquid, and
the other end Is to extend a minimum
vertical distance of 61 cm above the
stored liquid surface.
(B) There are to be no holes, tears,
or other openings In the shoe, seal
fabric, or seal envelope.
(II) The secondary seal Is to meet the
following requirements:
(A) The secondary seal Is to be In-
stalled above the primary seal so that
It completely covers the space between
the roof edge and the tank wall except
aa provided In paragraph There are to be no holes, tears.
or other openings In the seal or seal
fabric.
(Ill) If a failure that .Is detected
during Inspections required In para-
graph (b)(l> of I 60.113b(b) cannot be
repaired within 45 days and If the
vessel cannot be emptied within 45
days, a 30-day extension may be re-
quested from the Administrator In the
Inspection report required In
160.il5b(b)(4). Such extension re-
quest must Include a demonstration of
unavailability of alternate storage ca-
pacity and a specification of a sched-
ule that will assure that the control
equipment will be repaired or the
vessel will be emptied as soon as possi-
ble.
(5) Notify the Administrator 30 days
In advance of any gap measurements
required by paragraph (b)(l) of this
section to afford the Administrator
Environmental Protection Agency
the opportunity to have an observer
present.
(6) Visually Inspect the external
floating roof, the primary seal, second-
ary seal, and fittings each time the
vessel Is emptied and degassed.
(I) If the external floating roof has
defects, the primary seal has holes,
tears, or other openings In the seal or
the seal fabric, or the secondary seal
has holes, tears, or other openings In
the seal or the seal fabric, the owner
or operator shall repair the Items as
necessary so that none of the condi-
tions specified In this paragraph exist
before filling or refilling the storage
vessel with VOL.
(ID For all the Inspections required
by paragraph (b)(6) of this section, the
owner or operator shall notify the Ad-
ministrator In writing at least 30 days
prior to the filling or refilling of each
storage vessel to afford the Adminis-
trator the opportunity to Inspect the
storage vessel prior to refilling. If the
Inspection required by paragraph
(b)(8) of this section Is not planned
and the owner or operator could not
have known about the Inspection 30
days In advance of refilling the tank,
the owner or operator shall notify the
Administrator at least 7 days prior to
the refilling of the storage vessel. No-
tification shall be made by telephone
Immediately followed by written docu-
mentation demonstrating why the In-
spection was unplanned. Alternatively.
this notification Including the written
documentation may be made In writ-
Ing and sent by express mall so that It
Is received by the Administrator at
least 7 days prior to the refilling.
(c) The owner or operator of each
source that Is equipped with a closed
vent system and control device as re-
quired In |60.112b (a)(3) or (b)(2)
(other than a flare) la exempt from
i 60.8 of the General Provisions and
shall meet the following requirements.
(1) Submit for approval by the Ad-
ministrator as an attachment to the
notification required by I 60.7(a)(l) or,
If the facility Is exempt from
i60.7(a)(l). as an attachment to the
notification required by 160.7UX2).
an operating plan containing the In-
formation listed below.
(I) Documentation demonstrating
that the control device will achieve
§60.114b
the required control efficiency during
maximum loading conditions. This
documentation Is to Include a descrlp
tlon of the gas stream which enters
the control device. Including flow and
VOC content under varying liquid
level conditions (dynamic and static)
and manufacturer's design specifica-
tions for the control device. If the con-
trol device or the closed vent capture
system receives vapors, gases, or liq-
uids other than fuels from sources
that are not designated sources under
this subpart, the efficiency demonstra-
tion Is to Include consideration of all
vapors, gases, and liquids received by
the closed vent capture system and
control device. If an enclosed combus-
tion device with a minimum residence
time of 0.75 seconds and a minimum
temperature of 816 'C Is used to meet
the 95 percent requirement, documen-
tation that those conditions, will exist
Is sufficient to meet the requirements
of this paragraph.
(11) A description of the parameter
or parameters to be monitored to
ensure that the control device will be
operated In conformance with Its
design and an explanation of the crite-
ria used for selection of that parame-
ter (or parameters).
(2) Operate the closed vent system
and control device and monitor the pa-
rameters of the closed vent system and
control device In accordance with the
operating plan submitted to the Ad-
ministrator In accordance with para-
graph (c)(l) of this section, unless the
plan was modified by the Administra-
tor during the review process. In this
case, the modified plan applies.
-------
o
CD
§60.1)5b
reduction In emissions achieved by any
requirement In I 60.112b. the Adminis-
trator will publish In the FEDERAL REG-
ISTIH a notice permitting the use of
the alternative means for purposes of
compliance with that requirement.
(b) Any notice under paragraph (a)
of this section will be published only
after notice and an opportunity for a
hearing.
(c) Any person seeking permission
under this section shall submit to the
Administrator a written application In-
cluding:
(1) An actual emissions test that
uses a full-sized or scale-model storage
vessel that accurately collects and
measures all VOC emissions from a
given control device and that accurate-
ly simulates wind and accounts for
other emission variable! such as tem-
perature and barometric pressure.
(2) An engineering evaluation that
the Administrator determines Is an ac-
curate method of determining equlva-
•ij(d) The Administrator may condi-
tion the permission on requirements
that may be necessary to ensure oper-
ation and maintenance to achieve the
same emissions reduction as specified
In t 60.112b.
fl 60.115b Reporting and recordkeeplng re-
quirement*.
The owner or operator of each stor-
age vessel as specified In. I 80.112b(a)
shall keep records and furnish reports
as required by paragraphs (a), (b). or
(c) of this section depending upon the
control equipment Installed to meet
the requirements of |80.112b. The
owner or operator shall keep copies of
all reports and records required by
this section, except for the record re-
quired by (c)(l), for at least 2 years.
The record required by (c)(l> will be
kept for the life of the control equip-
ment.
(a) After Installing control equip-
ment In accordance with
I 60.112b(a)(l> (fixed roof and Internal
floating roof), the owner or operator
shall meet the following requirements.
(1) Furnish the Administrator with a
report that describes the control
equipment and certifies that the con-
trol equipment meets the specifica-
tions of I60.112b(a)(l) and
40 CFR Ch. I (7-1-90 Edition)
! 60.113b(a)(l). This report shall be an
attachment to the notification re-
quired by I eo.7(a)(3).
(2) Keep a record of each Inspection
performed as required by |60.113b
(a)(l). (a)(2). (a)(3). and (a)(4>. Each
record shall Identify the storage vessel
on which the Inspection was per-
formed and shall contain the date the
vessel was Inspected and the observed
condition of each component of the
control equipment (seals. Internal
floating roof, and fittings).
(3) If any of the conditions described
In | 6u.U3b(aH2) are detected during
the annual visual Inspection required
by 160.113b(a)(2). a report shall be
furnished to the Administrator within
30 days of the Inspection. Each report
shall Identify the storage vessel, the
nature of the defects, and the date the
storage vessel was emptied or the
nature of and date the repair was
made.
(4) After each Inspection required by
180.113b(a)(3) that finds holes or
tears In the seal or Seal fabric, or de-
fects In the Internal floating roof, or
other control equipment defects listed
In | 60.113b(aK3)(li). a report shall be
furnished to the Administrator within
30 days of the Inspection. The report
shall Identify the storage vessel and
the reason It did not meet the specifi-
cations of |61.112b(a)(l) or
160.113b(a)(3) and list each repair
made.
(b) After Installing control equip-
ment In accordance with
161.112b(a)(2) (external floating roof).
the owner or operator shall meet the
following requirements.
(1) Furnish the Administrator with a
report that describes the control
equipment and certifies that the con-
trol equipment meets the specifica-
tions of 180.112b(a)(2) and
I 60.113b(b)(2), (b)<3), and <4). This
report shall be an attachment to the
notification required by I 60.7(a)(3).
(2) Within 80 days of performing the
seal gap measurements required by
180.113b(b)(l>. furnish the Adminis-
trator with a report that contains:
(I) The date of measurement.
(II) The raw data obtained In the
measurement.
(Ill) The calculations described In
I 60.113b <2> and (b)(3).
Environmental Protection Agency
(3) Keep a record of each gap meas-
urement performed as required by
I 60.113b(b). Each record shall Identify
the storage vessel In which the meas-
urement was performed and shall con-
tain:
(I) The date of measurement.
(ID The raw data obtained In the
measurement.
(Ill) The calculations described In
I 60.113b (b)(2) and (b)(3).
(4) After each seal gap measurement
that detects gaps exceeding the limita-
tions specified by 160.113b(b)(4),
submit a report to the Administrator
within 30 days of the Inspection. The
report will Identify the vessel and con-
lain the Information specified In para-
graph (b)(2) of this section and the
date the vessel was emptied or the re-
pairs made and date of repair.
(c) After Installing control equip-
ment In accordance with |80.112b
(a)(3) or (b)(l) (closed vent system and
control device other than a flare), the
owner or operator shall keep the fol-
lowing records.
(DA copy of the operating plan.
(2) A record of the measured values
of the parameters monitored In ac-
cordance with I 80.1130(0(2).
(d) After Installing it closed vent
system and flare to comply with
I 60.112b. the owner or operator shall
meet the following requirements.
(DA report containing the measure-
ments required by I 80.1B(f) (D. (2).
(3). (4). (5), and (8) shall be furnished
to the Administrator as required by
I 60.8 of the General Provisions. This
report shall be submitted within 9
months of the Initial start-up date.
(2) Records shall be kept of all peri-
ods of operation during which the
flare pilot flame Is absent.
(3) Semiannual reports of all periods
recorded under g 80.DSb(d)(2) In
which the pilot name was absent shall
be furnished to the Administrator.
I 60.1 Ifib Monitoring of operation!.
(a) The owner or operator shall keep
copies of all records required by this
section, except for the record required
by paragraph (b) of this section, for at
least 2 years. The record required by
paragraph (b) of this section will be
kept for the life of the source.
§60.ll6b
(b) The owner or operator of each
storage vessel as specified In
| eo.llOb(a) shall keep readily accessi-
ble records showing the dimension of
the storage vessel and an analysis
showing the capacity of the storage
vessel. Each storage vessel with a
design capacity less than 75 m' Is sub-
ject to no provision of this subpart
other than those required by this
paragraph.
(c) Except as provided In paragraphs
(f) and (g> of this section, the owner or
operator of each storage vessel either
with a design capacity greater than or
equal to 151 m'storing a liquid with a
maximum true vapor pressure greater
than or equal to 3.5 kpa or with a
design capacity greater than or equal
to 75 m1 but less than 151 m' storing a
liquid with a maximum true vapor
pressure greater than or equal to 15.0
kPa shall maintain a record of the
VOL stored, the period of storage, and
the maximum true vapor pressure of
that VOL during the respective stor-
age period.
(d) Except as provided In paragraph
(g) of this section, the owner or opera-
tor of each storage vessel cither with a
design capacity greater than or equal
to 161 m' storing a liquid with a maxi-
mum true vapor pressure that Is nor-
mally less than 5.2 kPa or with a
design capacity greater than or equal
to 75 m* but less than 151 m1 storing a
liquid with a maximum true vapor
pressure that Is normally less than
27.8 kPa shall notify the Administra-
tor within 30 days when the maximum
true vapor pressure of the liquid ex-
ceeds the respective maximum true
vapor vapor pressure values for each
volume range.
(e) Available data on the storage
temperature may be used to determine
the maximum true vapor pressure as
determined below.
(D For vessels operated above or
below ambient temperatures, the max-
imum true vapor pressure Is calculated
based upon the highest expected cal-
endar-month average a', the storage
temperature. For vessels operated at
ambient temperatures, the maximum
true vapor pressure Is calculated based
upon the maximum local monthly av-
erage ambient temperature as report-
ed by the National Weather Service.
330
331
-------
o
(b
§60.117b
(2) For crude oil or refined petrole-
um products the vapor pressure may
be obtained by the following:
(I) Available data on the Reid vapor
pressure and the maximum expected
storage temperature based on the
highest expected calendar-month aver-
age temperature of the stored product
may be used to determine the maxi-
mum true vapor pressure from nomo-
graphs contained In API Bulletin 2617
(Incorporated by ' reference—see
9 60.17). unless the Administrator spe-
cifically requests that the liquid be
sampled, the actual storage tempera-
ture determined, and the Reid vapor
pressure determined from the
sampled).
(II) The true vapor pressure of each
type of crude oil with a Reid vapor
pressure less than 13.8 kPa or with
physical properties that preclude de-
termination by the recommended
method Is to be determined from avail-
able data and recorded If the estimat-
ed maximum true vapor pressure Is
greater than 3.5 ItPa.
(3) For other liquids, the vapor pres-
sure:
(I) May be obtained from standard
reference texts, or
(ID Determined by ASTM Method
D2879-83 (Incorporated by reference-
see | 60.17); or
(111) Measured by an appropriate
method approved by the Administra-
tor; or '
(Iv) Calculated by an appropriate
method approved by the Administra-
tor.
(f) The owner or operator of each
vessel storing a waste mixture of Inde-
terminate or variable composition
shall be subject to the following re-
quirements.
(1) Prior to the Initial filling of the
vessel, the highest maximum true
vapor pressure for the range of antici-
pated liquid compositions to be stored
will be determined using the methods
described In paragraph (e) of this sec-
tion.
(2) For vessels In which the vapor
pressure of the anticipated liquid com-
position Is above the cutoff for moni-
toring but below the cutoff for con-
trols as defined In |60.112b(a>. an Ini-
tial physical test of the vapor pressure
Is required; and a physical test at least
40 CFR Ch. I (7-1-90 Edition)
once every 6 months thereafter Is re-
quired as determined by the following
methods:
(I) ASTM Method D2879-83 (Incor-
porated by reference—see I 60.17): or
(ID ASTM Method D323-82 (Incorpo-
rated by reference—see 160.17); or
(111) As measured by an appropriate
method as approved by the Adminis-
trator.
(g) The owner or operator of each
vessel equipped with a closed vent
system and control device meeting the
specifications of 160.112b Is exempt
from the requirements of paragraphs
(c) and 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 del-
egated to States: II 60.111b(f)(4),
60.1Mb. aO.U6b(e)(3)(lll).
60.116b(e)(3)(lv). and 60.116b(f)(2)(lll).
[52 PR 11429. Apr. I. 1987, u amended at 52
PR 22710. June It. 1987)
Subport L—Standards of forformanco
far Secondary Lead Smeltert
160.120 Applicability and de.ljn.tlon of
UTecUd facility.
(a) The provisions of this subpart
are applicable to the following affect-
ed facilities In secondary lead smelters:
Pot furnaces of more than 250 kg (550
Ib) charging capacity, blast (cupola)
furnaces, and reverberator/ furnaces.
(b) Any facility under paragraph (a)
of this section that commences con-
atructlon or modification after June
11, 1973, Is subject to the requirements
of this subpart.
(49 FR 37937. July 25. 1977)
B 60.121 Definition!.
As used In this subpart, all terms not
defined herein shall have the meaning
given them In the Act and In Subpart >
A of this part.
(a) Rcvcrbcratoni furnace Includes
the following types of re.verberatory
Environmental Protection Agency
furnaces: stationary, rotating, rocking,
and tilting.
(b) Secondary lead imeller means
any facility producing lead from a
leadbearlng scrap material by smelting
to the metallic form.
(c) Lead means elemental lead or
alloys In which the predominant com-
ponent Is lead.
[39 FR 9317, Mar. 8. 1974; 39 FR 13776, Apr.
17, 1974)
{60.122 Standard for partlculate matter.
(a) On and after the date on which
the performance test required to be
conducted by | 60.8 Is completed, no
owner or operator subject to the provi-
sions of this subpart shall discharge or
cause the discharge Into the atmos-
phere from a blast (cupola) or rever-
beratory furnace any gases which:
(1) Contain partlculate matter In
excess of 50 mg/dscm (0.022 gr/dscf).
(2) Exhibit 20 percent opacity or
greater.
(b) On and after the date on which
the performance test required to be
conducted by I 60.8 Is completed, no
owner or operator subject to the provi-
sions of this subpart shall discharge or
cause the discharge Into the atmos-
phere from any pot furnace any gases
which exhibit 10 percent opacity or
greater.
[39 FR 9317. Mar. 8, 1974, as amended at 40
FR 46239. Oct. 6. 1979)
0 60.123 Teat methods and procedure*.
(a) In conducting the performance
tests required In I 60.8, the owner or
operator shall use as reference meth-
ods and procedures the test methods
In Appendix A of this part or other
methods and procedures as specified
In this section, except as provided In
I 60.8(b).
(b) The owner or operator shall de-
termine compliance with the partlcu-
late matter standards In 160.122 as
follows:
(1) Method 5 shall be used to deter-
mine the partlculate matter concen-
tration during representative periods
of furnace operation. Including charg-
ing and tapping. The sampling time
and sample volume for each run shall
be at least 60 minutes and 0.90 dscm
(31.8dscf).
§60.132
(2) Method 9 and the procedures In
160.11 shall be used to determine
opacity.
(94 FR 6»«7. Peb 14. 1886]
Subpart M—Standards of Perform-
ance for Secondary Brass and
Bronze Production Plants
'60.130 Applicability and designation of
affected facility.
(a) The provisions of this subpart
are applicable to the following a/fect-
ed facilities In secondary brass or
bronze production plants: Reverbera-
tory and electric furnaces of 1,000 kg
(2205 Ib) or greater production capac-
ity and blast (cupola) furnaces of 250
kg/h (550 Ib/h) or greater production
capacity. Furnaces from which molten
bra-is or bronze are cast Into the shape
of finished products, such as foundry
furnaces, are not considered to be af-
fected facilities.
(b) Any facility under paragraph (a)
of this section that commences con-
struction or modification after June
11, 1873, Is subject to the requirements
of this subpart.
141 FR 37937. July 29. 1977. u amended it
49 FR 43616. Oct. 30. 1984)
C 60.131 Definition.
As used In this subpart, all terms not
defined herein shall have the meaning
given them In the Act and In Subpart
A of this part.
(a) Bnuj or bronze means any metal
alloy containing copper as Its predomi-
nant constituent, and lesser amounts
of zinc. tin. lead, or other metals.
(b) Reverberatorv furnace Includes
the following types of reverberatory
furnaces: Stationary, rotating, rocking.
and tilting.
(c) Electric furnace means any fur-
nace which uses electricity to produce
over 50 percent of the heat required In
the production of refined brass or
bronze.
(d) Blast furnace means any furnace
used to recover metal from slag.
(38 FR 9318. Mar. 8. 1974]
0 60.132 Standard for partlculate matter.
(a) On and after the date on which
the performance test required to be
332
333
-------
APPENDIX D
Issues and Answers About Subpart QQQ
-------
METHODOLOGY
"Issues and Answers About Subpart QQQ" were compiled through the review of documents
addressing the proposal and promulgation of the standard, and through conversations with Regional and
State enforcement personnel. Each issue that was identified from these sources has been addressed
individually in the following section.
D-l
-------
ISSUES AND ANSWERS ABOUT SUBPART QQQ
A. Determination of Affected Facility.
B. Emission Offsets for Individual Drain Systems.
C. Emission Offsets for Aggregate Facilities.
D. Existing Catch Basins and Exemptions to the Standard.
E. New Catch Basins and Individual Drain Systems.
F. Conflicts with Subparts QQQ K and K, Ka, and Kb Requirements for Storage Tanks.
G. Using Upgraded Emission Control on Subpart K Tanks as Offsets for Wastewater NSPS
Compliance.
H. Applicability of NSPS to Lift and Pump Stations to NSPS.
I. Vents on Junction Boxes with Fire Baffles.
J. Controls on Auxiliary Oil-Water Separator Equipment.
K. Water Draws and Oil-Water Gauging From Slop Oil Tanks.
L. Wastewater Downstream from a Slop Oil Tank.
M. Regulation of Above Grade Collection Equipment.
N. Production of Oil Water During Tank Shutdowns.
O. Existing Catch Basins and New Individual Drain Systems.
D-2
-------
A. ISSUE: DETERMINATION OF AFFECTED FACILITY
Section 60.l4(e)(2) of the General Provisions for New Source Performance Standards states that an
increase in the production rate of an existing facility is not considered a modification if the increase does
not involve a capital expenditure. A capital expenditure for petroleum refineries is considered to by any
expenditure greater than 7%. The refinery wastewater NSPS makes exceptions to this provision in
regard to determining an affected facility for individual drain systems and aggregate facilities. How are
the modification provisions applied in the NSPS for refinery wastewater systems?
ANSWER:
The addition of any new drain system that results in increased emissions shall be considered a
modification to the aggregate facility, regardless of the capital expenditure provision.
Changes within an existing individual drain system that do not constitute a capital expenditure in the
aggregate facility shall not be considered a modification of the aggregate facility.
Changes within an existing individual drain system that result in increased emissions shall be considered
a modification to the individual drain system only.
Changes within an existing individual drain system that result in a capital expenditure as defined by the
General Provisions shall be considered a modification to the individual drain system only.
B. ISSUE: EMISSION OFFSETS FOR INDIVIDUAL DRAIN SYSTEMS.
Individual drain systems can be modified by the addition of one of two drains. If this occurs, can the
emissions created by the new drains be offset?
ANSWER:
Yes, emission offsets are allowed if new drains are added to an existing individual drain system, thereby
causing the individual drain system to become a modified affected facility. However, the offsets are
allowed only within that affected facility, and not in any other part of the wastewater system.
C. ISSUE: EMISSIONS OFFSETS FOR AGGREGATE FACILITIES.
Process changes or new equipment may result in the aggregate facility becoming a modification due to
increased emissions and a capital expenditure. Can emissions created by the modification be offset?
ANSWER:
Yes, emission offsets are allowed only within the affected aggregate facility, and not in any other part of
the wastewater system.
D. ISSUE: EXISTING CATCH BASINS AND EXEMPTIONS TO THE STANDARD.
Catch basins in refinery wastewater systems receive stormwater that has low organic content. Existing
wastewater systems may have catch basins located between process drain systems junction boxes and
the oil water separators. Are individual drain systems located upstream from the catch basin exempt
from the standard if they are modified or reconstructed?
D-3
-------
ANSWER:
Yes, if the individual drain systems and the catch basin were in place prior to May 4, 1987, the date of
proposal.
E. ISSUE: NEW CATCH BASINS AND INDIVIDUAL DRAIN SYSTEMS.
How would the regulation affect catch basins constructed after May 4, 1987?
ANSWER:
A catch basin constructed after the proposal date shall not receive any process wastewater from new or
existing individual drain systems. The new catch basin shall receive only stormwater.
F. ISSUE: CONFLICTS WITH SUBPARTS QQQ AND K, Ka, AND Kb
REQUIREMENTS FOR STORAGE TANKS.
The refinery wastewater NSPS calls for controls on slop oil tanks associated with aggregate facilities and
oil water separators. The NSPS for volatile organic liquid (VOL) storage vessels also calls for controls
on these tanks. Are slop tanks and other associated storage tanks controlled by the storage vessel
NSPS exempt from additional control by the wastewater NSPS?
ANSWER:
Yes. Storage vessels that are controlled under the K Subparts are exempt from all of the requirements
of Subpart QQQ.
G. ISSUE: USING UPGRADED EMISSION CONTROL ON SUBPART K TANKS AS
OFFSETS FOR WASTEWATER NSPS COMPLIANCE.
Since the NSPS for refinery wastewater exempts all tanks controlled by Subpart K, can upgraded
controls resulting in reduced emissions be used as offsets in the refinery wastewater NSPS?
ANSWER:
Yes. Even though tanks controlled by the Subpart K standards will not be subject to further control by
the Subpart QQQ standards, refineries may choose to upgrade the existing controls on the Subpart K
tanks for the purposes of offsetting emissions in affected aggregate facilities or oil water separators.
H. ISSUE: APPLICABILITY OF LIFT AND PUMP STATIONS TO NSPS.
Wastewater systems often include lift and pump stations. These were not specifically identified in the
regulation. How are lift and pump stations regulated?
ANSWER: _
Lift and pump stations are considered to be part of the individual drain system and not auxiliary
equipment. Lift stations and pump stations should be considered as junction boxes, and controlled as
required by the standards for junction boxes.
D-4
-------
I. ISSUE: VENTS ON JUNCTION BOXES WITH FIRE BAFFLES.
Junction boxes can be constructed with fire baffles that create two separate compartments within the
junction box. Can both sides of the junction box be vented?
ANSWER:
Yes. The baffles essentially create two junction boxes. Both sides of the box can therefore be vented
as if each side were an individual box.
J. ISSUE: CONTROLS ON AUXILIARY OIL-WATER SEPARATOR EQUIPMENT.
Oil-water separators are often preceded by bar screens, splitter boxes, weirs, and other auxiliary
equipment. Maintenance of this equipment may make it difficult to control emissions using control
techniques applicable to oil-water separators. Is this equipment subject to control by the NSPS?
ANSWER:
Yes, this equipment is subject to the same control as the oil-water separator. However, the NSPS does
allow for alternative controls to be used, which would minimize maintenance problems. For example,
separators treating 250 gal/min of wastewater or more must be controlled with a fixed roof with vapors
vented to a control device. This also applies to the auxiliary equipment. The standard does allow for
floating roofs to be used as equivalent control in lieu of the fixed roof with vapors vented to a control
device. If a floating roof is used on the separator, then only fixed roofs would be needed on the
auxiliary equipment with no venting to control devices required. Access doors can be used on the
auxiliary equipment as long as they are gaskets are installed, and doors are latched and kept closed
during operation, allowing for normal inspection and maintenance.
K. ISSUE: WATER DRAWS AND OIL-WATER GAUGING FROM SLOP OIL TANKS.
The NSPS requires that "...oily wastewater from slop oil handling equipment be collected, stored,
transported, recycled, reused, or disposed of in an enclosed system." A literal interpretation of this rule
would not allow for visual inspection of water draws and oil water gauging that is common in industry
practice. Can operators visually inspect water draws, therefore violating the integrity of the "closed
system."
ANSWER:
Yes, if there is no other technically feasible alternative available at the site for monitoring the drawdowns.
However, the system shall be operated in a closed manner during all other periods of operation.
L. ISSUE: WASTEWATER DOWNSTREAM FROM A SLOP OIL TANK.
A slop oil tank is used to separate water and oil from process units. The water from the slop oil tank is
pumped directly to an equalization basin that is located downstream from the secondary oil-water
separator. Are the facilities downstream from the slop tank subject to the regulations?
ANSWER:
If the wastewater is pumped directly to the equalization basin that is located downstream from the
oil-water separator, no other facilities are affected by the regulations. The assumption is made that the
D-5
-------
quality of water drawn from the slop oil tank is adequate to bypass the API separators, and therefore will
have low concentrations of VOC.
If the wastewater was pumped to a facility located upstream of the API separator, then all facilities
downstream from the slop tanks up to and including the primary and secondary API separators would
be impacted.
M. ISSUE: REGULATION OF ABOVE GRADE COLLECTION EQUIPMENT.
Facilities may occasionally include water collection vessels that are located above grade. Examples of
these vessels would include water drain sumps and sealed drain funnels. Are these vessels impacted by
the standards?
ANSWER:
No, collection equipment above grade is not subject to the regulations.
N. ISSUE: PRODUCTION OF OILY WATER DURING TANK SHUTDOWNS.
As a matter of refinery practice, excess oily water can be generated because of tank shutdowns and
maintenance. Tank shutdowns may occur every 10-15 years. Does the production of this excess
wastewater cause the facility to become a modification or reconstruction, and therefore an affected
facility?
ANSWER:
No, because the increased production of oily wastewater is not the result of a capital expenditure.
O. ISSUE: EXISTING CATCH BASINS AND NEW INDIVIDUAL DRAIN SYSTEMS.
Can an new individual drain system that includes new drains and a new common downstream junction
box be exempt from the standard if it is routed through an existing catch basin?
ANSWER:
No, the regulation prohibits routing of any new individual drain system through an existing catch basin.
However, any new drains added to an individual drain system that is connected to a catch basin that
was in the wastewater configuration prior to May 4, 1987 are exempt.
D-6
-------
APPENDIX E
Test Methods
1. Reference Method 21
2. Gap Measurement Instructions
-------
m
PI. 60, App. A, M.lh. 20
In Ueu of O« concentration measurement, a
CO, correction (actor 1* needed. Calculate
the CO. correction factor a* follows:
1.2.1 Calculate the fuel-specific P. value
for the fuel burned during the te*l using
value* obtained from Method It, Section
5.2. and the following equation.
P.-0.209
p.
Eq. 30-2
where:
F.-PUel factor baaed on the ratio of oxygen
volume to the ultimate CO, volume pro-
duced by the (uel at aero percent exceas
air, dlmenalonleu.
0.20*-FracUon of air that U oxygen, per-
cent/100.
F.-Ratio of the volumt of dry effluent fa*
to the groat calorific Taint of the fuel
from Method 1». damVJ (dacf/lO* Blu).
P.-Ratio of the volum* of carbon dloiid*
produced to the grow calorific value of
the fuel from Method It. demVJ (dacf*
Btu).
7.2.2. Calculate the CO. correction (actor
for correcting measurement data to It per-
cent oxygen, a* follow*:
.
*•" 7"
Eq. 20-J
where:
Xco.-CO, Correction (actor, percent.
6.9~20.B percent Oi-lt percent O,. the de-
fined O. correction value, percent.
I.I Correction of Pollutant Concentra-
tion* to It percent O,. Calculate the NO.
and SO, gas concentration* adjusted to If
percent O, using Equation 20-4 or SO-5. a*
appropriate. The correction to IS percent O>
1* very sensitive to the accuracy of the O, or
CO, concentration measurement. At the
level of the analyzer drift ipeclfled In Sec-
tion 3. the O. or CO. correction can exceed S
percent at the concentration level* expected
In gai turbine exhaust gasea. Therefore, O,
or CO, analyser liability and careful cali-
bration are necessary.
1.3.1 Correction of Pollutant Concentra-
tion Using O, Concentration. Calculate the
O, corrected pollutant concentration, a* fol-
towa:
C..-C.
5.9
JO.a-%0,
40 CFR Ch. I (7-1-90 Edition)
C.*,-Pollutant concentration corrected to
IS percent Ot ppm.
C«-*Pollutanl concentration measured, dry
bail*, ppm.
%O,-Measured O, concentration dry bull.
percent.
7.3.2 Correction of PolluUnt Concenlra-
MOD Uiliu CO> Concentration. Calculate the
CO, corrected pollutant concentration, u
follow*:
*co.
Eg. 20-s
where:
%COi-Mea*ured CO, concentration meas-
ured, dry basis, percent.
7.4 Average Adjuatcd NO. Concentration.
Calculate the average adjusted NO. concen-
tration by lummlnt the adjusted value* (or
each sample point and dlvldlm by the
number ol polnU (or each run.
7.t NO. and SO, Emission Rate Calcula-
tion!. The emission ratea (or NO. and SO, In
unjtj of pollutant mass per quantity of heat
Input can be calculated mine the pollutant
and diluent concentration* and fuel specific
P-facton baaed on the (uel combuitton
characteristic*. The measured eoncentra-
Uona of pollutant In unlU of part* per mil-
lion by volume (ppm) must be converted to
nun* per unit volume concentration unit*
(or the** calculation*. Use the following
table for *uch convenient:
CONVERSION FACTORS FOR CONCENTRATION
ppmtMOJ
10*
Id'
ISM
taw
l.lll
• 10"
I tC>
.10-
> 10-'
I 10-'
7.S.1 Calculation of Emission Rate Using
Oxygen Correction. Both the Ot concentra-
tion and the pollutant concentration must
be on a (try bajl*. Calculate the pollutant
emlatlon rate, a* follow*:
2Q.»
E-CA 20,»-
Eq. 20-0
where:
where:
E~Maa* eml**lon rate of pollutant. ng/J
lib/10-Btu).
970
Envlronmento! Protection Agency
752 Calculation of Emission Rule Using
Carbon Dioxide Correction. The COi con-
centration and the pollutant concentration
may be on either a dry basis or a wet basis.
but both concentrations must be on the
•ame basl* for the calculations. Calculate
the pollutant emission rat« using Equation
20-1 or 20-«:
E-C.P.
E-C.P.
100
100
%CO,.
Eq. 20-1
Eq. 20-8
where:
C.- Pollutant concentration measured on a
moUt sample basl*. ng/im' (Ib/scf)
%CO,._ Measured CO, concentration meas
ured on a moist aample bul*. percent.
8. Bibliography
1. Curtl*. P. A Method for Analyzing NO.
Cylinder duel-Specific Ion Electrode Pro-
cedure, Monograph available from Emission
Measurement Laboratory. ESED, Research
Triangle Purl;. NC 27711. October 191«.
3. Sigsby. John E.. P. M. Black. T. A.
Bellar. and O. L Klosterman. Chemllu-
muiucenl Method for Analysis of Nitrogen
Compound* In Mobile Source Emissions
(NO. NO,, and NH, ). "Environment*) Sci-
ence and Technology," 7:61-54, January
1673.
3. Shlgehara. R.T.. R.M Neullcht. and
W.S Smith. Validating Orsat Analysis Data
from Fossil Fuel-Fired Unit*. Emission
Measurement Branch. Emission Standards
and Engineering Division. Office of Air
Quality Planning and Standards. U.S. Envi-
ronmental Protection Agency. Research Tri-
angle Park. NC 37711. June 1879.
METHOD 21 — DSTIXMJNATION or VOLATIU
Oacuuc CourouHDs Luna
1. XppllcaolIUy ana Principle
1.1 Applicability. This method applies to
the determination of volatile organic com
pound (VOC) leak* from process equipment.
These source* Include, but are not limited
to. valves, flange* and other connections.
pumps and compressors, pressure relief de
vices, process drain*, open-ended valves.
pump and compressor seal system degassing
vents, accumulator vessel vents, agitator
seals, and acceu door seal*.
1.3 Principle. A portable Instrument Is
used to detect VOC leak* from Individual
sources. The Instrument detector type Is not
PI. 60, App. A, Moth. 71
specified, but It must meet the speclllcu
lions and performance criteria contained In
Section 3 A leak definition concentration
based on a reference compound Li specified
In each applicable regulation This pruce
dure Is Intended to locate and classl/y levies
only, and Is not to be used as a direct tneus
ure of mass emission rates from Individual
sources.
2. Definitions
2.1 Leak Definition Concentration The
local VOC concentration al the surface of a
leak source thai Indicates that a VOC emla
slon (leak) Is present The leak definition Is
an Instrument meter reading bajed on a rcf
erence compound.
2.2 Reference Compound The VOC spe-
cies selected as an Instrument calibration
basis for specification or the leak definition
concentration (For example If a leak defl
nltlon concentration Is 10.000 ppmv as
methane, then any source emission that re-
sults In a local concentration thai yields a
meter reading of 10.000 on an Instrument
calibrated with methane would be classified
as a leak. In this example, the leak defini-
tion Is 10,000 ppmv. and the reference com-
pound Is methane.)
2.3 Calibration Gas. The VOC compound
used to adjust the Instrument meter reading
to a known value The calibration gu Is usu
ally '.he reference compound at a concentra-
tion approximately equal to the leak dellnl
tlon concentration.
2.4 No Detectable Emission. Any VOC
concentration al a potential leak source (ad-
Justed for local VOC ambient concenlra
tlon) that Is less than a value corresponding
to the Instrument readability specification
of section 3.1.He) Indicates thai a leak Is not
present
2.5 Response Factor The ratio of the
known concentration of a VOC compound
to the observed meter reading when meas-
ured using an Instrument calibrated wlih
the reference compound specified In the ap-
plication regulation
2.0 Calibration Precision. The degree of
agreement between measurements of the
same known value, expressed aj the relative
percentage of the average difference be-
tween the meter readings and the known
concentration to the known concentration
2.1 Response Time The time Interval
from a step change In VOC concentration at
the Input of the sampling system to the
time at which »0 percent of the correspond
Ing final value Is reached as displayed on
the Instrument readout meter.
3. Apparatus
3 1 Monitoring Instrument.
3.1.1 Specifications
a. The VOC Instrument detector shall re-
spond to the compounds being processed
Detector types which may meet this re-
971
-------
m
rb
PI. 60, App. A, Math. 21
qulrement Include, but are nol limited to,
catalytic oxidation, name lonlzatlon. Infrs-
red absorption, and photolonlzatlon.
b. Both the linear response range and the
meuurable range of the Instrument for
each of the VOC to be measured, and for
the VOC calibration gas that Is used for
calibration, shall encompass the leak defini-
tion concentration specified tn the rcgula-
tlon. A dilution orobe assembly may be used
to bring the VOC concentration within both
range*, however, the specifications for In-
• I rum en t response time and sample probe
diameter ihall itlll be met.
c. The scale of the Instrument meter ihall
be readable to ±2.5 percent of the specified
leak definition concentration when perform
Ln< a no delectable emission survey.
d. The Instrument shall be equipped with
an electrically driven pump to Insure that a
sample Is provided to the detector at a con*
stant flow rate. The nominal sample flow
rate, as measured at the sample probe tip,
shall be 0.10 to 3.0 liters per minute when
the probe U fitted with a glass wool plug or
filter that may be used to prevent plugging
of the Instrument.
e. The Instrument shall be Intrinsically
safe as defined by the applicable U.3.A,
standards (e.g.. National Electric Code by
the National Plre Prevention Association)
for operation In any explosive atmospheres
that may be encountered In Its use. The In-
strument shall, at it minimum. b« Intrinsi-
cally safe for Class 1, Division 1 condition!.
and Class 2. Division 1 conditions, as defined
by the example Code. The Instrument shall
not be operated with any safety device, such
as an exhaust flame arrester, removed.
f. The Instrument shall be equipped with
a probe or probe extension for sampling not
to exceed Vi In. In outside diameter, with a
single end opening for admission of sample.
3.1.2 Performance Criteria.
(a) The instrument response factors for
each of the VOC to be measured shall be
less than 10. When no Instrument Is avail-
able that meets this specification when cali-
brated with the reference VOC specified In
the applicable regulation, the available In-
strument may be calibrated with one of the
VOC to be measured, or any other VOC. so
long as the Instrument then has a response
factor of less than 10 for each of the VOC
to be measured.
(b) The instrument response time shall be
equal to or less than 30 seconds. The Instru-
ment pump, dilution probe (If any), sample
probe, and probe filter, that will be used
during testing, shall all be In place during
the response time determination.
c. The calibration precision must be equal
tu or leas than 10 percent of the calibration
gas value.
d. The evaluation procedure for each pa-
rameter Is given In Section 4.4.
40 CFR Ch. I (7-1-90 Edition)
3.1.3 Performance Evaluation Require-
ments.
a. A response factor must be determined
for each compound that Is to be measured.
either by testing or from reference sources
The response factor tests are required
before placing the analyzer Into service, but
do not have to be repeated at subsequent In-
tervals.
b. The calibration precision lest must be
completed prior to placing the analyzer Into
service, and at subsequent 3-month Intervals
or at the next use whichever la later.
c. The response time test Is required prior
to placing the Instrument Into service. It t.
modification to the sample pumping system
or flow configuration Is made that would
change the response time, a new test u> re-
quired prior to further use.
3.2 Calibration Oases. The monitoring In
struraent Is calibrated In terms of parts per
million by volume (ppmv) of the reference
compound specified In the applicable regu-
lation. The calibration gases required tor
monitoring and Instrument performance
evaluation are a zero gas (air, less than 10
ppmv VOC) and a calibration gas In air mix-
ture approximately equal to the leak defini-
tion specified In the regulation. If cylinder
calibration gas mixtures are used, they must
be analyzed and certified by the manufac-
turer to be within ±2 percent accuracy, and
a shelf life must be specified. Cylinder
standards must be either reanalyzed or re-
placed at the end of the specified shelf life.
Alternately, calibration gases may be pre-
pared by the user according to any accepted
gaseous standards preparation procedure
that will yield a mixture accurate to within
±2 percent. Prepared standards must be re-
placed each day of use unless It can be dem-
onstrated that degradation does not occur
during storage.
Calibrations may be performed using i
compound other than the reference com-
pound If a conversion factor Is determined
for that alternative compound so that the
resulting meter readings during source sur-
veys can be converted to reference com-
pound results.
4. Procedures
4.1 Pretest Preparations. Perform the In
liniment evaluation procedures given In
Section 4.4 If the evaluation requirements of
Section 3.1.3 have not been met.
4.2 Calibration Procedures. Assemble and
start up the VOC analyzer according to the
manufacturer's Instructions. After the ap-
propriate warmup period and zero Internal
calibration procedure, Introduce the calibra-
tion gas Into the instrument sample probe.
Adjust the Instrument meter readout to cor
respond to the calibration gas value.
Nor*: If the meter readout cannot be ad-
justed to the proper value, a malfunction of
Environmental Protection Agency
the analyzer U Indicated and corrective ac-
tions are necessary before use.
4.3 Individual Source Surveys.
4.3.1 Type I-Leak Definition Baaed on
Concentration. Place the probe Inlet at the
surface of the component Interface where
leakage could occur. Move the probe along
the Interface periphery while observing the
Instrument readout. If an Increased meter
reading Is observed, slowly sample the Inter-
face where leakage Is Indicated until the
maximum meter reading Is obtained. Leave
the probe Inlet at this maximum reading lo-
cation (or approximately two tune* the In-
strument response time. If the maximum
observed meter reading Is greater than the
leak definition bi the applicable regulation.
record and report the results as specified In
the regulation reporting requirements. Ex-
amples of the application of this general
technique to specific equipment types are:
a. Valves—The most common source of
leaks from valves Is at the seal between the
stem and housing. Place the probe at the
Interface where the item exit* the packing
gland and sample the stem circumference.
Also, place the probe at the Interface of the
packing gland take-up flange seal and
sample the periphery. In addition, aurvey
valve housing! of multipart assembly at the
surface of all Interfaces where a leak could
occur.
b. Flanges and Other Connections—For
welded flanges, place the probe at the outer
edge of the flange-gasket Interface and
sample the circumference of the flange.
Sample other types of n on permanent Joints
Seal System Degassing Vents. Accumu-
lator Vessel Vents, Pressure Relief Devices—
If applicable, observe whether or not the
applicable ducting or piping exists. Also, de-
termine If any sources exist In the ducting
or piping where emissions could occur prior
to the control device. If the required duct-
Ing or piping exists and there are no sources
where the emissions could be vented to the
atmosphere prior lo the control device, then
It Is presumed that no delectable emission*
are present. If there are sources In the duel-
ing or piping where emissions could be
vented or sources where leaks could occur.
Ihe sampling surveys described In this para
graph shall be used to determine If delect*
ble emissions exist.
4.3.3 Alternative Screening Procedure A
screening procedure based on the formation
of bubbles In a soap solution thai Is sprayed
on a potential leak source may be used for
those sources that do nol have continuously
moving parts, thai do nol have surface tern
peratures greater than the boiling point or
leaa than the freezing point of the soap solu
lion, that do not have open areas to the at
mosphere that the soap solution cannot
bridge, or that do not exhibit evidence of
972
973
-------
m
co
Ft. 60, App. A, M«lh. 22
liquid leakage. Sources that have these con
dltlons present must be surveyed using the
Instrument techniques of 4.3.1 or 4.3.2.
Spray a soap solution over all potential
leak sources. The soap solution may be a
commercially available leak detection solu-
tion or may be prepared using concentrated
detergent and water. A pressure sprayer or
a squeeze bottle may be used to dispense the
solution. Observe the potential leak sites to
determine I/ any bubble* are formed. If no
bubbles are observed, the source U pre-
sumed to have no detectable emissions or
leaks as applicable. If aay bubbles are ob-
served, the Instrument techniques of 4.3.1 or
4.3.3 shall be used to determine If a leak
exists, or U the source hu detectable emis-
sions, as applicable.
4.4 Instrument Evaluation Procedures. At
the beginning of the Instrument perform-
ance evaluation teat, assemble and start up
the Instrument according to the manufac-
turer's Instruct Ions for recommended
warmup period and preliminary adjust-
ments.
4.4 1 Response Factor. Calibrate the In-
strument with the reference compound as
specified In the applicable relation. For
each organic species that U to be measured
during Individual source surveys, obtain or
prepare a known standard In air at a con-
centration of approximately BO percent of
the applicable leak definition unless limited
by volatility or exploslvlly. In these cues.
prepare a standard at 90 percent of the
saturation concentration, or 70 percent of
the lower explosive limit, respectively. In-
troduce this mixture to the analyzer and
record the observed meter reading. Intro-
duce tero air until a stable reading Is ob-
tained. Make a total of three measurements
by alternating between the known mixture
and it TO air. Calculate the response factor
for each repetition and the avenge re-
sponse factor.
AJternatlvety. it response factors have
been published for the compounds of Inter-
est for the Instrument or detector type, the
response factor determination U not re-
quired, and existing results may be refer-
enced. Examples of published response fac-
tor* for flame lonizatlon and catalytic oxi-
dation detectors are Included In Section 5.
4.4.2 Calibration Precision. Make a total
of three measurements by alternately using
zero gas and the specified calibration gas.
Record the meter readings. Calculate the
average algebraic difference between the
meter readings and the known value. Divide
this average difference by the known cali-
bration value and mutlply by 100 to expre&s
the resulting calibration precision as a per-
centage.
4.4.3 Response Time. Introduce zero gas
into (he Instrument sample probe. When
the meter reading has stabilized, switch
quickly to the specified calibration gas.
40 CFRCh. I (7-1-90 Edition)
Measure the time from switching to when
DO percent of the final stable reading U »i.
talned. Perform this test sequence lhr«c
times and record the results. Calculate the
average response lime.
6. Bibliography
5,1 DuBose. D.A.. and Q.E Harris Rc.
apoiue Factors of VOC Analyzers at a Meier
Reading of 10.000 ppmv for Selected Orac-
le Compounds. U.S. Environmental Pro tec
tlon Agency, Research Triangle Park NO
Publication No. EPA 000/2-81-051 Septem-
ber 1981.
5,2 Brown, O.E.. et al. Response Facton
of VOC Analyzers Calibrated with Methane
for Selected Organic Compounds. U.S. Envi-
ronment*] Protection Agency. Research Trl
angle Park. NC. Publication No. EPA flOO/2-
ai-022. May 1881.
5.3 DuBose. D.A.. et al. Response of Port
able VOC Analyzers to Chemical Mixtures
U.S. Environmental Protection Agency. Re
search Triangle Park. NC, Publication No
EPA 000/2-81-110. September 1981.
METHOD 52—Vis DAI. DETERMINATION or Fu
omvx EMISSIONS FROM MATUIM.
Bounces AW SUOKC EMISSIONS noti
FULAXS
1. Introduction
This method Involves the visual determi-
nation of fugitive emissions. I.e., emissions
not emitted directly from a process stack or
duct. Fugitive emission* Include emlssloni
that (1) escape capture by process equip-
ment exhaust hoods; (2) are emitted durlni
material transfer <3> are emitted from
buildings housing material processing or
handling? equipment; and (4) are emitted dJ-
rectly from process equipment. This method
Is used also to determine visible smoke eous
•Ions from flares used for combustion of
waste process materials.
This method determine* the amount of
time that any visible emissions occur during
the observation period. I.e.. the accumulated
emission lime. This method does not require
that the opacity of emissions be determined.
Since this procedure requires only the de-
termination of whether a visible emission
occurs and does not require the determine
tlon of opacity levels, observer certification
according to the procedures of Method 9 are
not required. However, It Is necessary thai
the observer Is educated on the general pro
cedures for determining the presence of visi-
ble emissions. As a minimum, the observer
must be trained and knowledgeable regard
Ing the effects on the visibility of emissions
caused by background contrast, ambient
lighting, observer position relative to Ugh*-
Ing. wind, and the presence of uncomblned
water (condensing water vapor). This train
Ing Is to be obtained from written material*
Environmental ProUdian Agency
found In References 7.1 and 1.2 or from the
lecture portion of the Method 0 certl/lca
tlon course.
2. Applicability and Principle
2.1 Applicability This method applies to
the determination u( the frequency of fugl
live emissions from stationary sources do
cated Indoors or outdoors) when specified as
the test method for determining compliance
with new source performance standards.
This method also U applicable for the de
termination of the frequency of visible
smoke emissions from flares.
2.2 Principle. Fugitive emissions pro-
duced during material processing, handling.
and transfer operations or smoke emission*
from flares are visually determined by an
observer without the aid of Instruments.
3. De/tntdonj
3.1 Emission Frequency. Percentage of
time that emissions are visible during the
observation period.
3.2 Emission Time Accumulated amount
o! time that emissions are visible during the
observation period
3.9 Fugitive Em Its I oos Pollutant gener
ated by an affected facility which is not col-
lected by a capture system and Is released to
the atmosphere.
3.4 Smoke Emissions. Pollutant generat-
ed by combustion In a flare Mid occurring
Immediately downstream of the flame.
Smoke occurring within the name, but noi
downstream of the flame. Is not considered
a smoke emission.
3.6 Observation Period. Accumulated
time period during which observations are
conducted, not to be leu than the period
specified In the applicable regulation.
4. Equipment
4.1 Stopwatches. Accumulative type with
unit divisions of at least 0.6 seconds; two re-
quired.
4.2 Light Meter. Ught meter capable of
measuring Illuminance In the 60- to 200 lux
range: required for Indoor observations
only.
6. Procedure
5.1 Position. Survey the affected facility
or building or structure housing the process
to be observed and determine the locations
of potential emissions. If the affected (aclll
iy Is located Inside a building, determine an
observation location lhat Is consistent with
th« requirements of the applicable regula-
tion (I.e.. outside observation of emissions
escaping the building/structure or Inside ob
•ervallon of emissions directly emitted from
the affected facility process unit). Then
•elect a position that enables a clear view u(
the potential emission pottiKs/ of the ulfect
ed facility or of the building or structure
housing the affected facility, as appropriate
'or the applicable subpart. A position at
least 15 feel, but not more than 0.25 miles.
Pt. 60, App. A, M«th. 11
from ihe emission source is rccumrm-niJi it
For outdoor local Jons, select a position
where the sun is not directly in the otw.-i -•
er's eyes.
5.2 Field Records
5 2 1 Outdoor location Ut-cord the f"l
lowing Information on Hie field data shft-t
(Figure 22-1 >, company name. Industry
process unit, observer's name observer's a/
filiation, and dale Record also the ealtrnal
ed wind speed, wind direction, and iky con
dltlon. Sketch the process unit being ob
served and note the observer location rela
live to the source and the sun Indicate the
potential and actual emission polnU on the
sketch.
5.2.2 Indoor Location Record the folio*
Ing information on the field data theet
/Figure 22-2): company name. Industry
process unit, observer's name observer's af
filiation, and dale Record u appropriate
the type, location, and Intensity of lighting •
on the dota sheet Sketch the process un.i
being observed and note observer location
relstlve to the source Indicate the potential
and actual fugitive emission polnu on the
sketch
5 3 Indoor Lighting Requirements For
Indoor locations, use a light meter to mes.;.
ure the level of Illumination at a location a*
close to the emission source(s) as is feaslblr
An Illumination of greater than 100 lux (10
foot candles) Is considered neceaaary tot
proper application of this method.
i.4 Observations Record the clock time
when observations begin. Use one stopwatch
to monitor the duration of the observation
period; start this stopwatch when the obs».-r
vatlon period begins If the observation
period Is divided Into two or more segments
by process shutdowns or observer real
breaks, stop the stopwatch when a brr.uk
begins and restart ll without resetting when
the break ends. Stop the stopwatch al the
end of the observation period The accmmi
lated time Indicated by this stopwatch Ls the
duration of the observation period When
the observation period Is completed, record
the clock lime
During the observation period, contlnoub
Iy watch the emission source. Upon obscrv
Ing an emission (condensed water vapor la
not considered an emission), atari the
second accumulative atopwaich. atop ln«
watch when the emission slops. Continue
this procedure for the entire observation
period. The accumulated elapsed lime on
Ihls alopwalch Is the total time emissions
were visible during the observation period
t.e . the emission tltne
5 4 I Observation Period Choose an <>U
servaLion period of sufficient length to meet
the requirements for determining compli-
ance with the emission regulation In the *p
pllcable subpart When the length of the ob-
servation period Is specifically stated (n tlie
974
975
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GAP MEASUREMENT WORKSHEET
When floating roofs are used as an alternative emission control for oil-water separators, gap
measurements must be conducted periodically to insure maximum emission reduction. This worksheet
provides guidelines for conducting gap measurements of the seals.
Primary Seals
Inspection Intervals: Within 60 days of installation and every 5 years.
Gap Width Criteria: Gaps not to exceed 3.8 cm (1.5 in.) at any point.
Gap Length Criteria: Area not to exceed 67 cm2/m (0.32 in2/ft) of separator wall
perimeter.
Secondary Seals
Inspection Intervals: Within 60 days of installation and every year.
Gap Width Criteria: Gaps not to exceed 1.3 cm (0.5 in.) at any point.
Gap Length Criteria: Area not to exceed 6.7 cm2/m (0.32 in2/ft) of separator
wall perimeter.
Procedure
For each primary and secondary seal, proceed as follows:
1. Measure the seal gaps around the entire perimeter of the separator in 'each place where a
0.32-cm (0.125 in.) diameter uniform probe passes freely between the seal and the wall, without
forcing or binding against the seal.
2. Record the actual gap width and the perimetrical distance of the gap.
3. Add the gap surface area for each gap location.
4. Divide the sum of the gaps by the nominal perimeter of the separator basin.
5. Check all gap widths and total gap area for compliance with the standard.
Calculations (use centimeters or inches)
Gap width x Gap length = Gap Area
Sum of gap areas
Nominal perimeter of basin (use meters or feet)
Sum of Gap Area + Perimeter =
E-4
-------
APPENDIX F
Appendix F is designed to be a collection of forms that the inspector can use to conduct a compliance
inspection. This section can be copied as needed for numerous inspections. Included in the appendix are
the following forms:
Table F-1. Applicability Checklist Page F-1
Table F-2. Detailed Requirements for Individual Drain Systems Page F-3
Table F-3. Detailed Requirements for Oil-water Separators Page F-5
Table F-4. Requirements for Closed Drain Systems Page F-8
Table F-5. Miscellaneous Requirements of the Standard Page F-9
Table F-6. Compliance Checklist for Individual Drain Systems Page F-10
Table F-7. Compliance Checklist for Oil-water Separators Page F-13
Table F-8. Compliance Checklist for Closed Vent Systems Page F-16
Table F-9. Gap Measurement Instructions Page F-21
Table F-10. Delay of Repair Reporting Form Page F-22
Table F-11. Method 21 Checklist Page F-23
-------
TABLE F-1. APPLICABILITY CHECKLIST
GENERAL
a. Construction, modification, or reconstruction of the refinery wastewater system commenced
after May 4, 1987.
Yes, the facility is subject to the NSPS, proceed to Sections II, III, IV and V.
No, the facility is exempt from the NSPS.
NEW INDIVIDUAL DRAIN SYSTEMS (IDS)
a. The new individual drain system will handle wastewater containing hydrocarbons.
Yes, the facility must meet the requirements of the standard for an aggregate
facility, regardless of the capital expenditure.
No, the drain system will handle only noncontact cooling water or stormwater
and is exempt from the standard.
MODIFIED OR RECONSTRUCTED INDIVIDUAL DRAIN SYSTEMS (IDS)
a. The modified/reconstructed IDS drains directly into the main sewer system, and there is not
an existing catch basin as part of the configuration of the existing drain system.
Yes, go to Ill-b.
No, there is a catch basin in the configuration that was present prior to
May 4, 1987, the IDS is exempt from the standard.
b. The modified/reconstructed IDS results in an emission increase and a capital expenditure.
Yes, the IDS is subject to the standard, go to Ill-c.
No, the IDS is not an affected facility.
c. Emission increases created by the modified/reconstructed IDS can be offset elsewhere in the
aggregate facility.
Yes, only the IDS is subject to the standard.
No, go to Ill-d.
d. The modification/reconstruction created an emission increase in the aggregate facility that
cannot be offset.
Yes, the aggregate facility is subject to the standard.
No, emissions can be offset, only the IDS is an affected facility.
continued
F-1
-------
TABLE F-1. APPLICABILITY CHECKLIST (Concluded)
IV. OIL-WATER SEPARATORS
a. A new oil-water separator is constructed.
Yes, the new separator is subject to the standard.
No, the standard does not apply.
b. A new oil-water separator is added upstream of an existing separator resulting in a capital
expenditure and an emission increase to the aggregate facility.
Yes, the new separator and downstream components are subject to the
standard.8
No, the standard does not apply.
c. A physical or operational change to an existing oil-water separator results in an emission
increase and capital expenditure.
Yes, the separator is subject to the standard.
No, the standard does not apply.
d. Auxiliary equipment is added to the operation of the separator, and the equipment comes into
contact with the oily wastewater.
Yes, the equipment is subject to the standard.
. No, the standard does not apply.
V. AGGREGATE FACILITY
a. ' A physical or operational change is made in the aggregate facility that results in a capital
expenditure and an emission increase.
Yes, the aggregate facility is subject to the standard.8
No.
aSlop oil facilities should not be considered in determining whether a capital expenditure is made on the
aggregate facility.
"In determining whether an oil-water separator will be modified, the capital cost of the new components
should be applied only to the actual oil-water separator treatment unit. Slop oil facilities should not be
considered.
F-2
-------
TABLE F-2. DETAILED REQUIREMENTS FOR INDIVIDUAL DRAIN SYSTEMS
COMPONENT/CONTROL
MONITORING/INSPECTION REPORTING
RECORDKEEPING3
•n
i
OJ
a, PROCESS DRAINS
Required Control: Water seals.
Alternative Control: Completely closed drain system/caps or sealed drains when out of service.
Water seals (unit in service)
Water seals (unit out of service)
Caps/Seals (unit out of service)
Closed System13
Other control
Initially
Monthly
Initially
Weekly
Initially
Semiannually
None
None
Initial report/certification
Semiannual inspection
Delay of compliance
Initial report/certification
Semiannual inspection
Delay of compliance
Initial report/certification
Semiannual inspection
Delay of compliance
Notification to use
closed drain system
Notification to use
alternative control
Demonstration of
compliance
Location, date, corrective action
Expected date of repair
Design specifications
Location, date, corrective action
Expected date of repair
Location of out of service drains
Design specifications
Location, date, corrective action
Expected date of repair
Location of out of service drains
Design specifications
None
None
None
aRecords must be maintained for 2 year periods. Design specifications for equipment used to comply with the standard must be kept for the
life of the emission source.
'-'See Table 5-5 for requirements of recovery/destruction devices. Continued
-------
TABLE F-2. DETAILED REQUIREMENTS FOR INDIVIDUAL DRAIN SYSTEMS (Concluded)
COMPONENT/CONTROL MONITORING/INSPECTION REPORTING RECORDKEEPING3
b. JUNCTION BOXES
Required Control: Tightly sealed cover, vent at least 3 feet in length, diameter 4 inches or less - or length ;>3 feet, diameter
£ 4 inches
Alternative Control: Completely closed drain system
Covers Initially Initial report/certification Location, date, corrective action
Semiannually Semiannual inspection Expected date of repair
Delay of compliance Design specifications
c. SEWER LINES
Required Control: Closed to the atmosphere, no open sewers.
Alternative Control: Buried sewer.
Covered sewer lines Initially Initial report/certification Location, date, corrective action
Semiannually Semiannual inspection Expected date of repair
Delay of compliance Design specifications
Buried sewer lines None None Design specifications
aRecords must* be maintained for 2 year periods. Design specifications for equipment used to comply with the standard must be kept for the
life of the emission source.
-------
TABLE F-3. DETAILED REQUIREMENTS FOR OIL-WATER SEPARATORS
COMPONENT/CONTROL
MONITORING/INSPECTION
REPORTING
RECORDKEEPING3
i
ui
a. OIL-WATER SEPARATORS
Required Control: New separators.
<250 gpm (16 L/sec)
2250 gpm (16 L/sec)
Fixed roof.
Fixed roof, vapors vented to a control device.
Modified/reconstructed separators.
<600 gpm (38 L/sec)
^600 gpm (38 L/sec)
Fixed roof.
Fixed roof, vapors vented to a control device.
Alternative Control: Floating roof.
Fixed roof
Fixed roof vented to control'3
Initially
Semiannually
Initial report/certification
Semiannual inspection
Delay of compliance
Location, date, corrective action
Expected date of repair
Design specifications
aRecords must be maintained for 2 year periods. Design specifications for equipment used to comply with the standard must be kept for the life
of the emission source.
bSame monitoring/inspection, reporting, and recordkeeping requirements for the fixed roof, plus additional requirements for the control device.
See Table 5-5 for requirements of recovery/destruction devices
-------
TABLE F-3. DETAILED REQUIREMENTS FOR OIL-WATER SEPARATORS (Continued)
CONTROL
MONITORING/INSPECTION
REPORTING
RECORDKEEPING3
Floating roof
Other control
Gap measurements on seals
within 60 days
Gaps on primary seals every
5 years
Gaps on secondary seals
every year
None
None
b. AUXILIARY EQUIPMENT, SLOP OIL TANKS
Required Control: New tanks and equipment.
Notification to use floating
roof as control
None
None
Notification to use
alternative control
Demonstration of
compliance
<250 gpm (16 L/sec)
>.250 gpm (16 L/sec)
Fixed roof (pressure relief valve allowed).
Fixed roof, vapors vented to a control device.
Modified/reconstructed tanks and equipment.
<600 gpm (38 1/sec)
2.600 gpm (38 1/sec)
Fixed roof (pressure relief valve allowed).
Fixed roof, vapors vented to a control device.
Design specifications
Location, date, corrective
action
Expected date of repair
None
None
None
None
Continued
aRecords must be maintained for two year periods. Design specifications for equipment used to comply with the standard must be kept for the
life of the emission source.
-------
TABLE F-3. DETAILED REQUIREMENTS FOR OIL-WATER SEPARATORS (Concluded)
CONTROL
MONITORING/INSPECTION
REPORTING
RECORDKEEPING3
Fixed roof
Fixed roof vented to control*3
Other control
Initially
Semiannually
Initial report/certification
Semiannual inspection
Delay of compliance
Notification to use
alternative control
Demonstration of
compliance
Location, date, corrective action
Expected date of repair
Design specifications
aRecords must be maintained for 2 year periods. Design specifications for equipment used to comply with the standard must be kept for the
life of the emission source.
"Same monitoring/inspection, reporting, and recordkeeping requirements for the fixed roof, plus additional requirements for the control device.
See Table. 5-5 for requirements of recovery/destruction devices.
-------
TABLE F-4. REQUIREMENTS FOR CLOSED VENT SYSTEMS
MONITORING/INSPECTION
1. Initial, semiannual inspections to ensure no detectable emissions as measured by Method 21.
2. Flow indicator to ensure flow to control device.
3. Control Devices
a. Thermal and Catalytic incinerators
continuous temperature recording device.
b. Carbon Adsorber
continuous monitoring device for measuring outlet VOC concentration, or inlet
and outlet VOC concentration.
c. Recovery devices other than a carbon adsorber
date and monitoring information necessary to ensure compliance.
d. Flare
monitoring requirement of 40 CFR 60.18.
REPORTING
1. Notification to use recovery device other than a carbon adsorber.
2. Initial certification of equipment needed to comply with standard.
3. Initial performance test for flares.
4. Initial and semiannual inspection reports, including reports on abnormal operation of control
devices.
5. Date of next shutdown if delay of compliance provisions apply.
RECORDKEEPING
1. Date, location, and corrective action for all repairs.
2. Expected date of repair if corrective action is delayed, with reason for delay.
3. Design specifications for all equipment used to comply with the standard.
4. Documentation of control device performance.
5. Continuous records of control device performance.
F-8
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TABLE F-5. MISCELLANEOUS REQUIREMENTS OF THE STANDARD
1 Modifications
Reporting
The EPA Administrator must be notified prior to any modification of the refinery wastewater system.
2. Stormwater Sewers
Recordkeeping
The facility must keep records showing the location of any stormwater sewer. These records will be
used to document exemptions to the requirements of individual drain systems, and to insure that
wastewater from new drain systems does not flow into a stormwater sewer.
3. Ancillary Equipment
Recordkeepinq
Plans and specifications for any equipment exempt from the standards must be kept to demonstrate that
this equipment does not come into contact with oily wastewater.
4. Noncontact Cooling Water
Recordkeeping
Plans and specifications for noncontract cooling water exempt from the standards must be kept to
demonstrate that this water does not come into contact with oily wastewater or hydrocarbons.
F-9
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TABLE F-6. COMPLIANCE CHECKLIST FOR INDIVIDUAL DRAIN SYSTEMS
USING WATER SEALED CONTROLS
Complete this form for each individual drain system subject to the standard. A "yes" response to
all questions will indicate full compliance with the standard. A "no" response will indicate
noncompliance, unless the response is related to repair provisions that allow for delays.
LOCATION OF INDIVIDUAL DRAIN SYSTEM
NUMBER OF DRAINS NUMBER OF JUNCTION BOXES__
SEWER LINES: BURIED ABOVE GROUND PARTIALLY BURIED/ABOVE GROUND
A. REVIEW OF RECORDS
1. A record of the design specifications for the drain system is available, yes no
including all control equipment for drains, junction boxes, and sewer
lines.
a. Record includes detailed schematics, piping and instrumentation
diagrams. yes no
b. Record includes dates and descriptions of any design changes. yes no
2. Certification of installation and inspection of equipment needed to
comply with the standards was submitted to the regulatory agency
within 60 days of initial startup. yes no
IF THE DRAIN SYSTEM IS ACTIVE
3. Water sealed drains were inspected when the unit was placed in service. yes no
Date of initial inspection .
4. Water sealed drains are inspected monthly. yes no
Date of last monthly inspection .
5. All repairs on water sealed drains were made immediately, or no later
than 24 hours after detection. yes no
(if "no" see GENERAL category below for delay of repair compliance)
6. All junction boxes are equipped with tight fitting covers. yes no
7. The junction boxes were inspected when they were put in service. yes no
Date of initial inspection .
8. Junction boxes are inspected every 6 months. yes no
Date of last semiannual inspection .
9. Broken seals and gaps were repaired within 15 days of detection. yes no
(if "no" see GENERAL category below for delay of repair compliance)
Continued
F-10
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TABLE F-6. COMPLIANCE CHECKLIST FOR INDIVIDUAL DRAIN SYSTEMS
USING WATER SEALED CONTROLS
10. All sewer lines are tightly covered. Ves no
11. The sewer lines were inspected when they were put in service. yes no
Date of initial inspection
12. Cracks, gaps, and other problems in the sewer line were repaired
within 15 days of detection. yes no
(if "no" see GENERAL category below for delay of repair compliance)
13. Covered sewer lines are inspected every 6 months. yes no
Date of last semiannual inspection .
IF ANY PART OF THE DRAIN SYSTEM IS INACTIVE
14. Water sealed drains were inspected when they were taken out of
service. yes no
Date drains were taken out of service .
15. Water sealed drains are inspected weekly. yes no
Date of last weekly inspection
16. All drains that are capped or sealed were inspected following
initial installation of the caps or seals. yes no
Date when installation was complete .
17. All drains that are capped or sealed are inspected every .6
months. yes no
Date of last semiannual inspection .
GENERAL
18. All deficiencies have been recorded, including location, date,
and corrective action to be taken. yes no
19. When repairs were not made immediately, the expected date of
repair was noted. yes no
20. All reported deficiencies have been repaired or are scheduled for repair. yes no
B. VISUAL INSPECTION
1. Water seals present on all drains. yes no
2. Caps/seals on inactive drains are in place and tightly fitting. yes no
•
Continued
F-11
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TABLE F-6. COMPLIANCE CHECKLIST FOR INDIVIDUAL DRAIN SYSTEMS
USING WATER SEALED CONTROLS (Concluded)
3.
4.
5.
6.
Covers on junction boxes
are tight and have no visible gaps or openings.
yes
no
Vents on junction boxes are at least 3 feet in length with a diameter of
4 inches or less.
Joints and connections on
or openings.
Visual inspection of facility
sewer lines have no visible gaps, cracks,
is consistent with written records.
yes
yes
yes
no
no
no
NOTE ALL DEFICIENCIES
F-12
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TABLE F-7. COMPLIANCE CHECKLIST FOR OIL-WATER SEPARATORS
WITH FIXED AND FLOATING ROOFS
Complete this form for each oil-water separator subject to the standard. This form is applicable
only if fixed or floating roofs are the control technique used for compliance. A "yes" response to all
questions will indicate full compliance with the standard. A "no" response will indicate noncompliance,
unless the response is related to repair provisions that allow for delays.
LOCATION OF OIL-WATER SEPARATOR
DESIGN CAPACITY FIXED ROOF FLOATING ROOF
AUXILIARY EQUIPMENT SUBJECT TO THE STANDARD
A. REVIEW OF RECORDS
1. A record of the design specifications for the separator and control
equipment is available. yes no
a. Record includes detailed schematics, piping and instrumentation
diagrams. yes no
b. Record includes dates and descriptions of any design changes. yes no
2. Certification of installation and inspection of equipment needed to
comply with the standards was submitted to the regulatory agency within
60 days of initial startup. yes no
IF THE CONTROL IS A FIXED ROOF OR A FLOATING ROOF
3. The roof was inspected and certified when the separator was placed in
service. yes no
Date of initial inspection .
4. The roof is inspected every 6 months. yes no
Date of last semiannual inspection
5. All repairs were made within 15 days of detection. yes no
(if "no" see GENERAL category below for delay or repair compliance)
6. All auxiliary equipment subject to the standard is equipped with
tight fitting covers. yes no
7. The auxiliary equipment was inspected and control equipment certified
when initially placed in service. yes no
Date of initial inspection
8. Auxiliary equipment is inspected every 6 months. yes no
Date of last semiannual inspection .
9. Pressure relief valves (if present) on auxiliary equipment
are set at maximurn release pressure. yes no
Continued
F-13
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TABLE F-7. COMPLIANCE CHECKLIST FOR OIL-WATER SEPARATORS
WITH FIXED AND FLOATING ROOFS
IF THE CONTROL IS A FLOATING ROOF
10. The EPA was notified that a floating roof was being installed. yes no
11. Measurement of primary gap seals was conducted within 60 days of
installation. yes no
Date of measurement
12. Measurement of primary gap seal is conducted every 5 years. yes no
Date of last inspection
13. Measurement of secondary gap seals was conducted within 60 days of
installation. yes no
Date of last measurement
14. Measurement of secondary gap seal is conducted every year. yes no
Date of last measurement .
15. All doors and openings were inspected when the roof was installed. yes no
Date of initial inspection
16. All doors and openings are inspected every 6 months. yes no
Date of last semiannual inspection
GENERAL
17. All deficiencies have been recorded, including location, date, and
corrective action to be taken. yes no
18. When repairs were not made immediately, the expected date of repair
was noted. yes no
19. All reported deficiencies have been repaired or are scheduled for repair. yes no
B. VISUAL INSPECTION
FIXED ROOFS ON SEPARATORS AND AUXILIARY EQUIPMENT, FOR EACH SEPARATOR OR
AUXILIARY EQUIPMENT
1. The roof fit tightly with no visible gaps, cracks, or openings. yes no
2. All access doors and openings were sealed properly. yes no
Continued
F-14
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TABLE F-7. COMPLIANCE CHECKLIST FOR OIL-WATER SEPARATORS
WITH FIXED AND FLOATING ROOFS (Concluded)
3.
4.
Pressure relief valves are set at maximum pressures.
Visual inspection of facility is consistent with written records.
yes
yes
no
no
FLOATING ROOFS
5.
6.
7.
8.
9.
10.
All access doors and openings were sealed property.
The gap width between the primary seal and the separator wall was
acceptable using gap measuring methods specified in the rule.
The total gap area between the primary seal and the separator wall was
acceptable uisng gap measuring methods specified in the rule.
The gap width between the secondary seal and the separator wall was
acceptable using gap measuring methods specified in the rule.
The total gap area between the secondary seal and the separator wall was
acceptable using gap measuring methods specified in the rule.
Visual inspection of facility is consistent with written records.
yes
yes
yes
yes
yes
yes
no
no
no
no
no
no
NOTE ALL DEFICIENCIES
F-15
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TABLE F-8. COMPLIANCE CHECKLIST FOR CLOSED VENT SYSTEMS
Complete this form when a closed vent system is used to comply with the standard for an
individual drain system or oil-water separator. A "yes" response to all questions will indicate full
compliance with the standard. A ''no" response will indicate noncompliance.
CLOSED VENT SYSTEM FOR: OIL-WATER SEPARATOR
INDIVIDUAL DRAIN SYSTEM
DESTRUCTION OR RECOVERY DEVICE
DATE OF STARTUP
A. REVIEW OF RECORDS
1. A record of the design specifications for the closed vent system is
available. . yes no
a. Record includes detailed schematics, piping and instrumentation
diagrams. yes no
b. Record includes dates and descriptions of any design changes. yes no
2. Certification of installation and inspection of equipment needed to
comply with the standards was submitted to the regulatory agency within
60 days of initial startup. yes no
IF A CLOSED VENT SYSTEM IS USED FOR A DRAIN SYSTEM
3. The EPA was notified that a closed drain system was being installed. yes no
IF THE CONTROL DEVICE IS A FLARE
4. A report of the initial performance test was submitted within 60 days
of the intial startup. yes no
5. The presence of a flare pilot flame is monitored using a thermocouple
or other device designed to detect the presence of a flare. yes no
6. All periods when the flare pilot did not have a flame have been
recorded, with records kept for 2 years. yes no
7. The flare meets all other operational and monitoring requirements of
40 CFR 60.18. yes no
IF THE CONTROL DEVICE IS A THERMAL INCINERATOR
8. A temperature monitoring device equipped with a continuous monitor
is used to measure the temperature of the gas stream in the combustion
zone, (accuracy of 1 % of the temperature measured in °C or.+. 0.5° C
[_+. 1.0°F] whichever is greater). yes no
Continued
F-16
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TABLE F-8. COMPLIANCE CHECKLIST FOR CLOSED VENT SYSTEMS
9. Documentation exists demonstrating 95% control efficiency [or #10]. yes no
10. Documentation exists demonstrating minimum residence time of 0.75 seconds
and minimum temperature of 816°C (1500°F). yes no
11. A description of operating parameters used to determine compliance is
available. yes no
12. Continuous records of temperature of the gas stream in the combustion
zone of the incinerator are kept for 2 year periods. yes no
13. Records are kept for all 3-hour periods when the average temperature
of the gas stream in the combustion zone is more than 28°C (50°F)
below the design combustion zone temperature. yes no
14. All other periods of operation not in conformation with design criteria
are recorded. yes no
IF THE CONTROL DEVICE IS A CATALYTIC INCINERATOR
15. Temperature monitoring devices equipped with continuous recorders
are used to measure the temperature in the gas stream immediately
before and after the catalyst bed (accuracy of 1 % of the temperature
measured in °C or +_ 0.5°C [± 1.0°F] whichever is greater).
16. Documentation exists demonstrating 95% control efficiency [or #17]. yes no
17. Documentation exists demonstrating minimum residence time of
0.75 seconds and minimum temperature of 816°C (ISOO^F). yes no
18. A description of operating parameters used to determine compliance is
available. yes no
19. All periods of operation not in conformance with design criteria are
recorded. yes no
20. Continuous records are kept of the temperature of the gas stream
upstream and downstream of the catalyst bed. yes no
21. Records are kept for all 3-hour periods during which the average
temperature measured before the catalyst bed is more than 28°C
(50°F) below the design gas stream temperature. yes no
Continued
F-17
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TABLE F-8. COMPLIANCE CHECKLIST FOR CLOSED VENT SYSTEMS
22. Records are kept for all 3-hour periods during which the average
temperature difference across the catalyst bed is less than 80% of
the design temperature difference. yes no
23. All periods of operation not in conformance with design criteria are
recorded. yes no
IF THE VAPOR RECOVERY DEVICE IS A CARBON ADSORBER
24. A monitoring device is used that continually indicates and records the
VOC concentration or reading of organics in the exhaust gas of the
control device outlet gas stream or inlet and outlet gas stream. yes no
25. Documentation exists demonstrating 95% control efficiency. yes no
26. A description of operating parameters used to determine compliance is
available. yes no
27. All periods of operation not in conformance with desing criteria are
recorded. yes no
28. Continuous records are kept of the VOC concentration level or reading
of organics of the control device outlet gas stream or inlet and outlet
gas stream. yes no
29. Records are kept for all 3-hour periods during which the average VOC
concentration level or reading of organics in the exhaust gases, or
inlet and outlet gas stream is more than 20% greater than the design
exhaust gas concentration level. yes no
30. All other periods of operation not in conformance with design criteria
are recorded. yes no
IF THE VAPOR RECOVERY DEVICE IS NOT A CARBON ADSORBER
31. The EPA was notified that a recovery device other than a carbon
was being used. yes no
32. A monitoring device is used that continually indicates and records
the VOC concentration or reading of organics in the exhaust gas of
the control device outlet gas stream or inlet and outlet gas stream. yes no
33. Documentation exists demonstrating 95% control efficiency. yes no
34. A description of operating parameters used to determine compliance is
available. yes no
Continued
F-18
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TABLE F-8. COMPLIANCE CHECKLIST FOR CLOSED VENT SYSTEMS
35. Continuous records are kept of operating parameters needed to
determine compliance. yes no
36. All periods of operation not in conformance with design criteria are
recorded. yes no
GENERAL
37. A flow indicator is present on the vent stream to the control device. yes no
38. Documentation exists describing the gas stream entering the control
device, including flow and VOC content under static and dynamic
liquid level conditions. yes no
39. Manufacturers design specifications for the control device are
available. yes no
40. The closed vent system was inspected initially and found to- be
operating with no detectable emissions (<500 ppm above background) yes no
Date of initial inspection
41. The closed vent system is inspected every 6 months to ensure
operation with no detectable emissions. yes no
Date of last semiannual inspection .
42. All deficiencies have been recorded, including location, date, and
corrective action to be taken. yes no
43. The location, date, and corrective action was noted when detectable
emissions were measured during any inspection. yes no
44. When repairs were not made immediately, the expected date of repair
was noted and was within 30 days of the reported deficiency. yes no
45. All reported deficiencies were repaired within 30 days or are
scheduled for repair within 30 days of the initial report. yes no
B. VISUAL INSPECTION
1. A flow indicator is present on the vent stream to the control device. yes no
2. For flares, a device for detecting the flame is present. yes no
3. For incinerators, a temperature monitoring device in present. yes no
Continued
F-19
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TABLE F-8. COMPLIANCE CHECKLIST FOR CLOSED VENT SYSTEMS (Concluded)
4. For carbon adsorbers, a device for measuring VOC content is present. yes no
5. . The closed vent system has no detectable emissions. yes no
6. Visual inspection of facility is consistent with written records. yes no
NOTE ALL DEFICIENCIES
F-20
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F-9. GAP MEASUREMENT WORKSHEET
When floating roofs are used as an alternative emission control for oil-water separators, gap
measurements must be conducted periodically to insure maximum emission reduction. This worksheet
provides guidelines for conducting gap measurements of the seals.
Primary Seals
Inspection Intervals: within 60 days of installation and every 5 years.
Gap Width Criteria: gaps not to exceed 3.8 cm (1.5 in.) at any point.
Gap Length Criteria: area not to exceed 67 cm2/m (0.32 in2/ft) of separator wall
perimeter.
Secondary Seals
Inspection Intervals: within 60 days of installation and every year.
Gap Width Criteria: gaps not to exceed 1.3 cm (0.5 in.) at any point.
Gap Length Criteria: area not to exceed 6.7 cm2/m (0.32 in2/ft) of separator
wall perimeter.
Procedure
Procedure
For each primary and secondary seal, proceed as follows:
1. Measure the seal gaps around the entire perimeter of the separator in each place where a
0.32 cm (0.125 in.) diameter uniform probe passes freely between the seal and the wall, without
forcing or binding against the seal.
2. Record the actual gap width and the perimetrical distance of the gap.
3. Add the gap surface area for each gap location.
4. Divide the sum of the gaps by the nominal perimeter of the separator basin.
5. Check all gap widths and total gap area for compliance with the standard.
Calculations (use centimeters or inches)
Gap width x Gap length = Gap Area
Sum of gap areas
Nominal perimeter of basin (use meters or feet)
Sum of Gap Area - Perimeter =
F-21
-------
F-10. DEU\Y OF REPAIR REPORTING FORM
If emission points cannot be repaired or corrected without a process unit shutdown or because of any other
reason, the owner/operator shall record the following information.
Location of Emission Point
Corrective Action to Be Taken
Reason for Delay of Repair
Date of Next scheduled Process Unit Shutdown
Anticipated Date of Repair
Signature of Decision Maker
FOLLOWUP:
Actual Date Repair Completed
F-22
-------
F-11. METHOD 21 CHECKLIST
1. Instrument Detector
a. Instrument Type:
b. Serial Number:
c. Manufacturer and Model:
d. Calibration Gas:
e. Instrument Lower Limit of Detection (ppmv):
f. Saturation Point of Instrument Without Dilution Probe:
g. Did you use a dilution probe? yes no
h. Can instrument scale read ±5% of leak definitions? yes no
i. Does instrument include a pump capable of 1 /2 to 1 /3
1 /min flow rate? yes no
2. Instrument Performance
a. Has a response factor for the detector been determined? yes no
b. Is the response factor < 10? yes no
c. Report response factor:
d. Has a response time test for the detectors been performed? yes no
e. Is response time .<30 seconds? yes no
f. Report response time:
g. Have there been any changes to the sample pumping system
or flow configuration since the response time test? yes no
h. Has a calibration precision test for the detector been
completed? yes no
i. Report date of last calibration precision test:
j. Is calibration precision ^.10% of calibration gas
value? yes no
F-23
-------
F-12. CALIBRATION CHECKLIST (METHOD 21)
Completed
1. Calibration Gas
a. Is a zero gas used as a first step in calibrating the detector? yes no
b. For calibration gas:
1. Cylinder standards
a. has it been certified by the manufacturer to be
±2% accuracy?
b. report shelf life:
c. are the standards reanalyzed or replaced after shelf life?
d. from whom do you purchase cylinder standards?
2. Prepared standards
a. is the mixture accurate to within ± 2 percent?
b. are the standards replaced each day of use?
2. Calibration Procedure Checklist
a. Assemble and start-up VOC analyzer.
b. Allow for instrument warm-up.
c. Zero internal calibration procedure.
d. Introduce calibration gas into sample probe.
e. Adjust meter readout to correspond to calibration gas value.
3. Instrument Evaluation Procedures
a. Assemble and start-up instrument according to manufacturer's instructions.
b. Response Factor
1. Calibrate with reference compound.
2. Obtain or prepare known standard of the organic species to be measured.
3. Introduce standard to analyzer and record observed meter reading.
4. Introduce zero air until a stable reading is obtained.
5. Repeat 3 and 4 twice more to obtain three measurements.
6. Calculated 3 individual and 1 average response factors.
7. Was a published response factor used? yes no
F-24
-------
F-12. CALIBRATION CHECKLIST (METHOD 21 ((Concluded)
Completed
C. Calibration precision
1. Make three measurements by alternately using zero gas and specified
calibration gas.
2. Record meter readings.
3. Calculate average algebraic difference between meter readings and known
value.
4. Calculate calibration precision (%) Average algebraic difference* 100.
(Known calibration value).
D. Response time
1. Introduce zero gas into sample probe.
2. When meter has stabilized, switch quickly to specified calibration gas.
3. Measure time form switching to 90 percent of final stable reading.
4. Repeat twice more.
5. Calculate average response time.
F-25
-------
TECHNICAL REPORT DATA
ff lease read Instructions on the reverse before completing/
\. REPORT NO.
EPA 340/1-91-013
3. RECIPIENT'S ACCESSION NO.
4. TITLE AND SUBTITLE
Inspection Manual - New Source Performance
Standards for Emissions from Petroleum
Refinery Wastewater Systems
5. REPORT DATE
September, 1991
6. PERFORMING ORGANIZATION CODE
7. AUTHOR(S)
8. PERFORMING ORGANIZATION REPORT NO
9. PERFORMING ORGANIZATION NAME AND ADDRESS
Alpha-Gamma Technologies, Inc.
900 Ridgefield Drive, Suite 350
Raleigh, NC 27609
10. PROGRAM ELEMENT NO.
11. CONTRACT/GRANT NO.
68-02-4464
12. SPONSORING AGENCY NAME AND ADDRESS
Stationary Source Compliance Division
US Environmental Protection Agency
401 M Street, SW
Washington, DC 20460
13. TYPE OF REPORT AND PERIOD COVERED
Final
14. SPONSORING AGENCY CODE
15. SUPPLEMENTARY NOTES
16. ABSTRACT
Information and guidance is provided to assist federal, state, and
local regulatory personnel with the enforcement of the New Source
Performance Standards for Petroleum Refinery Wastewater Systems,
Subpart QQQ of the Code of Federal Regulations (40 CFR Part 60).
The inspection manual includes descriptions of the emission sources
to be regulated, emissions control techniques, de.tailed requirements
of the standard, and a series of checklists and inspection forms.
Appendices include the full text of the regulation, along with other
supporting information to guide regulatory personnel.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
Air pollution
Pollution control
Standards of performance
VOC emissions
Petroleum refineries
Wastewater treatment systems
b.IDENTIFIERS/OPEN ENDED TERMS
Air pollution
c. COSATI Field/Croup
18 DISTRIBUTION STATE*
'unlimited
Unclassified
20. SECURITY CLASS [This page)
Unclassified
22. PRICE
seftn 2220-1 (R«v. 4-77) PREVIOUS EDITION is OBSOLETE
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