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RULE 4401 STEAM-ENHANCED CRUDE OIL PRODUCTION WELLS (Adopted April 

11, 1991; Amended September 19, 1991; Amended December 17, 1992; 

Amended January 15, 1998; Amended December 14, 2006, Amended June 16, 

2011) 

1.0 Purpose 

The purpose of this rule is to limit the Volatile Organic Compound (VOC) emissions from 

steam-enhanced crude oil production wells. 

2.0 Applicability 

This rule is applicable to all steam-enhanced crude oil production wells and any associated 

VOC collection and control systems. 

3.0 Definitions 

3.1 Air Pollution Control Officer (APCO): as defined in Rule 1020 (Definitions). 

3.2 Background: a reading on a portable hydrocarbon detection instrument which is 

determined at a distance no greater than two (2) meters upwind from any 

component to be inspected and which is not influenced by any specific emission 

point. 

3.3 Component: includes, but is not limited to, any valve, fitting, threaded 

connection, pump, compressor, pressure relief device, pipe, flange, process 

drain, sealing mechanism, hatch, sight-glass, meter, or seal fluid system in VOC 

service. 

3.4 Component Type: includes, but is not limited to, any one (1) of the following 

groups: valves, fittings, threaded connections, pumps, compressors, pressure 

relief devices, pipes, flanges, process drains, sealing mechanisms, hatches, 

sight-glasses, meters, or seal fluid systems in VOC service. 

3.5 Compressor: a device used to compress gases or vapors or a combination of 

gases and vapors by the addition of energy, and includes all associated 

components used for connecting and sealing purposes. The phrase "all 

associated components used for connecting and sealing purposes" means the first 

VOC leak points (first components) connected on the body of the compressor. 

For example, a valve that is connected to a threaded hole on the body of the 

compressor, the first VOC leak point is the threaded connection on the body 

side of the compressor, but the valve itself is not a "first VOC leak point". 

Similarly, a compressor shaft seal is considered as a “first VOC leak point”. 
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3.6 Critical Component: a component that would require the shutdown of a critical 

process unit if that component was shut down or disabled. 

3.7 Critical Process Unit: a process unit that must remain in service because of its 

importance to the overall process that requires it to continue to operate, and has no 

equivalent equipment to replace it or cannot be bypassed, and it is technically 

infeasible to repair leaks from that process unit without shutting it down and 

opening the process unit to the atmosphere. 

3.8 Critical Process Unit Shutdown: the shutdown of a critical process unit or part of 

the critical process unit that causes the entire unit to cease operating. 

3.9 Cyclic Well: for purposes of this rule, a crude oil production well, which is 

periodically (at least once in the preceding two (2) year period) injected with 

steam from any source for the purpose of enhancing oil production. 

3.10 District: San Joaquin Valley Unified Air Pollution Control District, or any person 

designated to act on its behalf. 

3.11 EPA: United States Environmental Protection Agency, or any person designated 

to act on its behalf. 

3.12 Essential Component: a component that cannot be taken out of service without 

reducing, by more than 33 percent, the throughput of the process unit that it 

serves. 

3.13 Facility: a stationary source as defined in Rule 2201 (New and Modified 

Stationary Source Rule). 

3.14 Fitting: a component, excluding flanges and threaded connectors, used to attach 

or connect pipes or piping system. Examples of a “fitting” include, but are not 

limited to quick-disconnect fittings, push-in-fittings, and cam-locks. 

3.15 Front Line Production Equipment: a tank or vessel in which any organic liquid 

is placed, held, or stored and that is the first vessel that receives crude oil/fluids 

directly from wells subject to this rule including, but is not limited to, wash 

tanks, free water knockouts, separators, etc., and that is operating under 

atmospheric or near atmospheric pressure. After production is routed through at 

least one of such tanks or vessels, downstream vessels are no longer considered 

front line production equipment. A gauge tank, as defined in Section 3.0 of this 

rule, shall not be considered as Front Line Production Equipment. 

3.16 Fuel Burning Equipment: as defined in Rule 1020 (Definitions). 
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3.17 Gauge Tank: for the purposes of this rule only, a tank which is used exclusively 

for measuring the amount of produced fluid produced by an oil well(s) and meets 

all the following conditions: 

3.17.1 Has a capacity of 100 barrels (4,200 gallons) or less, 

3.17.2 Is in operation on or before December 14, 2006, 

3.17.3 Receives or stores produced fluid (crude oil or mixture of crude oil and 

water), 

3.17.4 Is connected to at least one steam-enhanced crude oil production well 

with a closed vent, 

3.17.5 Is upstream of all front line production equipment, 

3.17.6 Does not have its VOC emissions controlled to at least 99%, and 

3.17.7 The true vapor pressure (TVP) of the produced fluid in the gauge tank, 

at all times, shall be less than 0.5 psia as determined pursuant to the 

provisions of Section 6.2.3. 

3.18 Inaccessible Component: a component that is located more than 15 feet above 

ground when access is required from the ground; or a component that is located 

more than six (6) feet away from a platform when access is required from the 

platform, or a component in a location that would require the elevation of 

monitoring personnel higher than six (6) feet above permanent support surfaces. 

3.19 Inspection: checking and/or testing in order to detect leaks. 

3.19.1 District Inspection: inspection of components by District personnel or 

their representative to insure facilities and/or operators are in compliance 

with District requirements. 

3.19.2 Operator Inspection: inspection of components conducted by the operator 

pursuant to the inspection and re-inspection schedules specified in this 

rule for the purpose of demonstrating compliance with this rule. 

3.20 Leak: The dripping of VOC-containing liquid or the detection of a concentration 

of total organic compound, above background, determined according to the test 

method specified in Section 6.3.3 that exceeds any of the values specified in Table 

1, Section 3.20.1 and Section 3.20.2 of this rule. Any liquid or gas coming from 

a component undergoing repair or replacement, or during sampling of process 

fluid from a component into a container is not considered a leak provided such 
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activities are done as expeditiously as possible and with minimal spillage of 

material and VOC emissions to the atmosphere. 

Table 1 Gas Lean in ppmv as Methane 

Type of Component Major Gas Leak Minor Gas Leak 

1. PRDs Greater than 10,000 400 to 10,000 

2. Components other than PRDs Greater than 10,000 2,000 to 10,000 

3.20.1 Major Liquid Leak: a visible mist or a continuous flow of liquid that 

is not seal lubricant. 

3.20.2 Minor Liquid Leak: a liquid leak, except seal lubricant, that is not a 

major liquid leak and drips liquid at a rate of more than three drops per 

minute. 

3.21 Leak Minimization: reducing a leak to the lowest achievable level without 

damaging the component using best modern practices which include, but are not 

limited to, adding sealing material to the component, tightening the component, 

or adjusting the component without shutdown of the process that the component 

serves and that can be safely accommodated. 

3.22 Major Component: a pump five (5) brake horsepower or larger, any compressor, 

or any pressure relief valve four (4) inches in diameter or larger. 

3.23 Open-ended Line or Valve: a line or valve, except PRD, having one side of the 

line or valve seat in contact with the process fluid and one side open to the 

atmosphere, either directly or through an open piping. 

3.24 Operate: to perform any activity with, or on any steam-enhanced crude oil 

production well, including but not limited to producing, steam-enhancing, venting, 

maintaining or repairing. 

3.25 Pilot Testing: testing of a new cyclic well for up to 180 days from each 

production zone for the purpose of determining the viability of developing a 

steam-enhanced production zone. 

3.26 Portable Hydrocarbon Detection Instrument: a hand-held hydrocarbon analyzer 

that meets the criteria specified in EPA Method 21, 40 CFR Part 60. The 

instrument shall be calibrated on methane. 

3.27 Pressure Relief Device (PRD): a pressure relief valve or a rupture disk. 

3.28 Pressure Relief Valve (PRV): an automatic pressure-relieving device associated 

with a process vessel or piping system that is activated by pressure upstream of 

the device and relieves to the atmosphere (atmospheric PRV). 
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3.29 Process Drain: an open portion of a non-continuous piping system, including 

open origination portion(s) of such a system used for collection and transport of 

liquids discharged from process vessels, spills, or other sources. Drain 

origination points and drain termination points are not open-ended lines. 

Process drains are not open-ended lines. 

3.30 Process System: an APCO-approved system that is not open to the atmosphere 

and is composed of hard-piping, ductwork connections and, if necessary, flow 

inducing devices that transport gases or vapors from a piece of equipment to a 

process stream, fuel gas system, sales gas system or an injection well approved 

by the Department of Oil, Gas, and Geothermal Resources (DOGGR). 

3.31 Process Unit: a manufacturing process which is independent of other processes 

and is continuous when supplied with a constant feed of raw material and 

sufficient storage facilities for the final product. 

3.32 Production Zone: a subsurface geologic formation or group of formations of oilbearing material through which steam could migrate from a steam injection well, 

or cyclic well being steamed to an oil production well. 

3.33 Pump: a device used to transport fluids by the addition of energy, and includes all 

associated components used for connecting or sealing purposes. The phrase "all 

associated components used for connecting and sealing purposes" means the first 

VOC leak points (first components) on the body of the pump. For example, a 

valve that is connected to a threaded hole on the body of the pump, the first 

VOC leak point is the threaded connection on the body side of the pump, but the 

valve itself is not a "first VOC leak point". Similarly, a pump shaft seal is 

considered as a “first VOC leak point”. 

3.34 Release: a VOC emission to the atmosphere from a PRD caused by an increase 

in upstream pressure. A leak caused by improper reseating of the PRD is not a 

release. 

3.35 Rupture Disk: a rigid diaphragm held between flanges for the purpose of isolating 

organic compounds from the atmosphere or from a downstream pressure relief 

valve. Rupture disks are designed to fail at a certain pressure point. 

3.36 Service or Repair: a well shall be considered under service or repair during rigup, operation, and rig-down of any rig or pulling unit used to repair or maintain 

surface or downhole well equipment. 

3.37 Sight glass: a device located on a fluid line or a process vessel that allows an 

operator to view the product or material inside a fluid line or a process vessel. 
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3.38 Small Producer: a person who produces a monthly average of less than 6,000 

barrels of crude oil per day from all operations in any one county within the 

District, and who does not engage in refining, transporting, or marketing of 

refined petroleum products. An operator shall qualify as a small producer only in 

the county where the operator’s crude oil production does not exceed the threshold 

specified above. 

3.39 Steam Drive Well: a crude oil production well which produces from the same 

production zone in which a steam injection well is completed and is within: 

3.39.1 250 feet of a steam injection well, if the injection well is within a 

production well pattern of two and one-half (2 1/2) acres or smaller, or 

3.39.2 350 feet of a steam injection well, if the injection well is within a 

production well pattern of greater than two and one-half (2 1/2) acres but 

less than or equal to five (5) acres, or 

3.39.3 500 feet of a steam injection well, if the injection well is within a 

production well pattern larger than five (5) acres, or 

3.39.4 1000 feet of a steam injection well, and responds to steam injected in an 

irregular production well pattern, and exhibits any visible emissions. 

3.40 Steam-Enhanced Crude Oil Production Well: a steam drive well, cyclic well, or 

any other well in which the temperature of crude oil is raised, by the injection of 

steam, above the production zone temperature that existed prior to the injection of 

steam. 

3.41 Steam Injection Well: a well into which steam is injected that enhances the 

production of oil from other wells in the same production zone. Cyclic wells 

which enhance production of oil from other wells in the production zone are 

considered injection wells. 

3.42 Tag: a piece of paper, metal, plastic or other suitable material that is attached to a 

component for the purpose of identification or other information. 

3.43 True Vapor Pressure (TVP): as defined in Rule 4623 (Storage of Organic 

Liquids). 

3.44 Turnaround: a scheduled shutdown of a process unit for maintenance and repair 

work. 

3.45 Unsafe-to-Monitor Component: a component installed at a location that would 

prevent the safe inspection or repair of a component as defined by OSHA 

standards or in provisions for worker safety stated in 29 CFR 1910. 
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3.46 Vacuum Service: operating under a negative gauge pressure or below 

atmospheric pressure. 

3.47 Valve: a device that regulates the flow of fluid in a piping system by means of 

an external actuator acting to permit or block passage of fluid. 

3.48 Visible Emissions: from well vents, visible emissions are any visible plume 

including water vapor. When the ambient air temperature is 60oF or less a well 

vent shall be considered to have visible emissions if there is any visible plume and 

there is a leak as defined above. 

3.49 Volatile Organic Compound (VOC): as defined in Rule 1020 (Definitions). 

3.50 VOC Collection and Control System: an APCO-approved system that is not open 

to the atmosphere and that is composed of hard-piping, ductwork connections and, 

if necessary, flow inducing devices that transport gas or vapor from a piece or 

pieces of equipment to an APCO-approved control device that has a VOC 

destruction or removal efficiency of at least 99%, or that transports gases or 

vapors back to a process system. 

3.51 VOC Emissions: emissions resulting from the operation of a steam-enhanced 

crude oil production well. Such emissions include uncondensed casing vent 

emissions and any emissions resulting from the handling, transfer, storage, or 

disposal of condensed and uncondensed casing vapors. 

3.52 Well Stimulation: cyclic steam injection of a well for up to 180 days prior to the 

well being placed in service as a continuous steam injection well. 

3.53 Well Vent: an opening on a well head that facilitates or blocks the flow of well 

casing vapors to the atmosphere or to a VOC collection and control system. 

4.0 Exemptions 

4.1 Any steam-enhanced crude oil production well undergoing service or repair during 

the time the well is not producing. 

4.2 The requirements of this rule for cyclic wells shall not apply to up to 40 wells 

owned by a company and undergoing pilot testing provided; 

4.2.1 the production zone on that property has not been injected with steam 

during the preceding two (2) years, 

4.2.2 the well is located more than 1000 feet from an existing well vent vapor 

collection and control system operated by the company, and 
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4.2.3 the operation is under District permit. 

4.3 The requirements of this rule shall not apply to up to 40 cyclic wells owned by a 

company and undergoing well stimulation, provided; 

4.3.1 the well is located more than 1000 feet from an existing well vent vapor 

collection and control system operated by the company, and 

4.3.2 the operation is under District permit. 

4.4 The requirements of this rule shall not apply to up to five (5) cyclic wells owned 

by a company that is not a small producer, in each stationary source as defined in 

Rule 2201 (New and Modified Stationary Source Review Rule), and up to 20 

cyclic wells owned by a small producer, provided the requirements of Section 

4.4.1 and Section 4.4.2 are met. 

4.4.1 the well is located more than 1000 feet from an existing well vent vapor 

control system operated by the company, and 

4.4.2 the operation is under District permit. 

4.5 The requirements of this rule shall not apply to components serving the 

produced fluid line. 

4.6 Except for complying with the applicable requirements of Section 6.1, Section 

6.6.6 and Section 7.2, the requirements of this rule shall not apply to 

components described in Section 4.6.1 through Section 4.6.4. An operator 

claiming an exemption pursuant to Section 4.6 shall provide proof of the 

applicable criteria to the satisfaction of the APCO. 

4.6.1 Pressure relief devices, pumps, and compressors that are enclosed and 

whose emissions are controlled with an operating VOC collection and 

control system as defined in Section 3.0. 

4.6.2 Components buried below ground. 

4.6.3 Components used exclusively in vacuum service. 

4.6.4 One-half inch nominal or less stainless steel tube fittings which have been 

demonstrated to the APCO to be leak-free based on initial inspection using 

the test method specified in Section 6.3.3. 
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4.7 The requirements of Section 5.4.1 through Section 5.4.7 of this rule shall not 

apply to components exclusively handling gas/vapor or liquid with a VOC 

content of ten percent by weight or less (≤10 wt.%), as determined by the test 

methods in Section 6.3.4. 

5.0 Requirements 

5.1 An operator shall not operate a steam-enhanced crude oil production well unless 

the operator complies with the requirements of either Section 5.1.1 or Section 

5.1.2. 

5.1.1 The steam-enhanced crude oil production well vent is closed and the 

front line production equipment downstream of the wells that carry 

produced fluids (crude oil or mixture of crude oil and water) is 

connected to a VOC collection and control system as defined in Section 

3.0. The well vent may be temporarily opened during periods of 

attended service or repair of the well provided such activity is done as 

expeditiously as possible with minimal spillage of material and VOC 

emissions to the atmosphere. 

5.1.2 The steam-enhanced crude oil production well vent is open and the well 

vent is connected to a VOC collection and control system as defined in 

Section 3.0. 

5.2 Determination of Compliance with the Leak Standards 

5.2.1 An operator shall be in violation of this rule if any District inspection 

demonstrates that one or more of the conditions in Section 5.2.2 exist at 

the facility or if any operator inspection conducted pursuant to Section 5.4 

demonstrates that one or more of the conditions in Section 5.2.2 exist at 

the facility. 

5.2.2 Leak Standards 

The following conditions shall be used for determination of violation 

during an inspection pursuant to the provisions of Section 5.2.1. 

5.2.2.1 Existence of an open-ended line or a valve located at the end of 

the line that is not sealed with a blind flange, plug, cap, or a 

second closed valve that is not closed at all times, except during 

attended operations requiring process fluid flow through the 

open-ended lines. Attended operations include draining or 

degassing operations, connection of temporary process 

equipment, sampling of process streams, emergency venting, 

and other normal operational needs, provided such operations 
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are done as expeditiously as possible and with minimal spillage 

of material and VOC emissions to the atmosphere. 

5.2.2.2 Existence of a component with a major liquid leak as defined in 

Section 3.0. 

5.2.2.3 Existence of a component with a gas leak greater than 50,000 

ppmv. 

5.2.2.4 Existence of a component leak described in Section 5.2.2.4.1 

through Section 5.2.2.4.3 in excess of the allowable number of 

leaks specified in Table 2. 

5.2.2.4.1 A minor liquid leak, or 

5.2.2.4.2 A minor gas leak, or 

5.2.2.4.3 A gas leak greater than 10,000 ppmv up to 50,000 

ppmv. 

Table 2 Number of Allowable Leaks 

Number of Steam-Enhanced Crude Oil 

Production Wells Connected to a VOC 

Collection and Control System 

Number of Allowable Leaks 

1 to 25 3 

26 to 50 6 

51 to 100 8 

101 to 250 10 

251 to 500 15 

More than 500 

One (1) for each 20 wells 

tested with a minimum of 50 

wells tested. 

5.3 An operator shall comply with the following operating requirements: 

5.3.1 An operator shall not use any component with a leak as defined in Section 

3.0, or that is found to be in violation of the provisions of Section 5.2.2. 

However, components that were found leaking may be used provided such 

leaking components have been identified with a tag for repair, are 

repaired, or awaiting re-inspection after being repaired within the 

applicable time frame specified in Section 5.5 of this rule. 
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5.3.2 Each hatch shall be closed at all times except during sampling or adding 

of process material through the hatch, or during attended repair, 

replacement, or maintenance operations, provided such activities are 

done as expeditiously as possible with minimal spillage of material and 

VOC emissions to the atmosphere. 

5.3.3 An operator shall comply with the requirements of Section 6.7 if there is 

any change in the description of major components or critical components. 

5.4 Inspection and Re-inspection Requirements 

Unless otherwise specified, an operator shall perform all component inspections 

and gas leak measurements pursuant to the requirements of Section 6.3.3. 

5.4.1 Except for pipes and unsafe-to-monitor components, an operator shall 

inspect all other components pursuant to the requirements of Section 6.3.3 

at least once every year. 

5.4.2 An operator shall visually inspect all pipes at least once every year. Any 

visual inspection of pipes that indicates a leak that cannot be immediately 

repaired to meet the leak standards of this rule shall be inspected within 24 

hours after detecting the leak. If a leak is found, the leak shall be repaired 

as soon as practicable but not later than the time frame specified in Table 3 

of this rule. 

5.4.3 In addition to the inspections required by Section 5.4.1, an operator shall 

inspect for leaks all accessible operating pumps, compressors, and PRDs 

in service as follows: 

5.4.3.1 An operator shall audio-visually (by hearing and by sight) 

inspect for leaks all accessible operating pumps, compressors, 

and PRDs in service at least once each calendar week. 

5.4.3.2 Any audio-visual inspection of an accessible operating pump, 

compressor, and PRD performed by an operator that indicates a 

leak that cannot be immediately repaired to meet the leak 

standards of this rule shall be inspected not later than 24 hours 

after conducting the audio-visual inspection. If a leak is found, 

the leak shall be repaired as soon as practicable but not later 

than the time frame specified in Table 3 of this rule. 

5.4.4 In addition to the inspections required by Section 5.4.1, Section 5.4.2 and 

Section 5.4.3, an operator shall perform the following inspections: 
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5.4.4.1 An operator shall initially inspect a PRD that releases to the 

atmosphere as soon as practicable but not later than 24 hours 

after the discovery of the release. An operator shall re-inspect 

the PRD not earlier than 24 hours after the initial inspection but 

not later than 15 calendar days after the initial inspection. 

5.4.4.2 An operator shall inspect all new, replaced, or repaired fittings, 

flanges, and threaded connections within 72 hours of placing the 

component in service. 

5.4.4.3 Except for PRDs subject to the requirements of Section 5.4.4.1, 

an operator shall inspect a component that has been repaired or 

replaced not later than 15 calendar days after the component 

was repaired or replaced. 

5.4.7 An operator shall inspect all unsafe-to-monitor components during each 

turnaround. 

5.4.8 A District inspection in no way fulfills any of the mandatory inspection 

requirements that are placed upon operators and cannot be used or counted 

as an inspection required of an operator. 

5.5 Leak Repair Requirements 

5.5.1 An operator shall affix a readily visible weatherproof tag to a leaking 

component upon detection of the leak. An operator shall include the 

following information on the tag: 

5.5.1.1 The date and time of leak detection. 

5.5.1.2 The date and time of leak measurement. 

5.5.1.3 For a gaseous leak, the leak concentration in ppmv. 

5.5.1.4 For a liquid leak, whether it is a major liquid leak or a minor 

liquid leak. 

5.5.1.5 Whether the component is an essential component, an unsafe-tomonitor component, or a critical component. 

5.5.2 An operator shall keep the tag affixed to the component until an operator 

has met all of the following conditions: 

5.5.2.1 Repaired or replaced the leaking component, and 
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5.5.2.2 Re-inspected the component using the test method in Section 

6.3.3, and 

5.5.2.3 The component is found to be in compliance with the 

requirements of this rule. 

5.5.3 An operator shall minimize a component leak in order to stop or reduce 

leakage to the atmosphere immediately to the extent possible, but not later 

than one (1) hour after detection of the leak. 

5.5.4 Except for leaking critical components or leaking essential components 

subject to the requirements of Section 5.5.7, if an operator has minimized 

a leak but the leak still exceeds the applicable leak limits as defined in 

Section 3.0, an operator shall comply with at least one of the requirements 

of Section 5.5.4.1, Section 5.5.4.2, or Section 5.5.4.3 as soon as 

practicable but not later than the time period specified in Table 3. 

5.5.4.1 Repair or replace the leaking component; or

5.5.4.2 Vent the leaking component to a VOC collection and control 

system as defined in Section 3.0, or 

5.5.4.3 Remove the leaking component from operation. 

 	  

Type of Leak Repair Period in Calendar Days 

Gas Leaks 

Minor Gas Leak 14 

Major Gas Leak less than or equal 

to 50,000 ppmv 

5 

Gas Leak greater than 50,000 ppmv 2 

Liquid Leaks 

Minor Liquid Leak 3 

Major Liquid Leak 2 

5.5.5 The leak rate measured after leak minimization has been performed shall 

be the leak rate used to determine the applicable repair period specified in 

Table 3. 

5.5.6 The time of the initial leak detection shall be the start of the repair period 

specified in Table 3. 
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5.5.7 If the leaking component is an essential component or a critical 

component that cannot be immediately shut down for repairs, and if the 

leak has been minimized but the leak still exceeds the applicable leak 

standard of this rule, the operator shall repair or replace the essential 

component or critical component to eliminate the leak during the next 

process unit turnaround, but in no case later than one year from the date of 

the original leak detection, whichever comes earlier. 

6.0 Administrative Requirements 

6.1 Recordkeeping and Submissions 

An operator shall maintain the records required by Section 6.1 and Section 6.2 for 

a period of five (5) years. These records shall be made available to the APCO, 

California Air Resources Board (ARB), and EPA upon request. 

6.1.1 The operator of any steam-enhanced crude oil production well shall 

maintain records of the date and well identification where steam injection 

or well stimulation occurs. 

6.1.2 A small producer shall maintain monthly records of county-specific crude 

oil production. For the purpose of this rule, the monthly crude oil 

production records required by the California Division of Oil, Gas, and 

Geothermal Resources may be used to satisfy Section 6.1.2. 

6.1.3 An operator of any steam-enhanced crude oil production well shall keep 

source test records which demonstrate compliance with the control 

efficiency requirements of the VOC collection and control system as 

defined in Section 3.0. 

6.1.4 The inspection log maintained pursuant to Section 6.4. 

6.1.5 Records of each calibration of the portable hydrocarbon detection 

instrument utilized for inspecting components, including a copy of current 

calibration gas certification from the vendor of said calibration gas 

cylinder, the date of calibration, concentration of calibration gas, 

instrument reading of calibration gas before adjustment, instrument 

reading of calibration gas after adjustment, calibration gas expiration date, 

and calibration gas cylinder pressure at the time of calibration. 

6.1.6 An operator shall maintain copies at the facility of the training records of 

the training program operated pursuant to Section 6.5. 

6.1.7 An operator shall keep a copy of the APCO-approved Operator 

Management Plan at the facility. 
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6.1.8 An operator shall keep a list of all gauge tanks, as defined in Section 3.0. 

 The list shall contain the size, identification number, the location of 

each gauge tank and specify whether the gauge tank is upstream of all 

front line production equipment. 

6.1.9 The results of gauge tank TVP testing conducted pursuant to Section 6.2.3 

shall be submitted to the APCO within 60 days after the completion of the 

testing. 

6.1.10 An operator that discovers that a PRD has released shall record the date 

that the release was discovered, and the identity and location of the PRD 

that released. An operator shall submit such information recorded 

during the calendar year of the release to the APCO no later than 60 days 

after the end of the calendar year. 

6.2 Compliance Source Testing 

6.2.1 An operator shall source test annually all VOC collection and control 

systems used to control emissions from steam-enhanced crude oil 

production well vents to determine the control efficiency of the device(s) 

used for destruction or removal of VOC. Compliance testing shall be 

performed annually by source testers certified by ARB. Testing shall be 

performed during June, July, August, or September of each year if the 

system's control efficiency is dependent upon ambient air temperature. A 

process system is not subject to compliance source testing requirements. 

6.2.2 If approved by the APCO, a VOC collection and control system is not 

subject to Section 6.2.1 if all uncondensed VOC emissions collected by the 

system are controlled by a device meeting one of the requirements in 

Sections 6.2.2.1 through 6.2.2.3. 

 

6.2.2.1 An internal combustion engine subject to District Rule 4702 

(Internal Combustion Engines – Phase 2); or 

6.2.2.2 A combustion device subject to District Rule 4320 (Advanced 

Emission Reduction Options for Boilers, Steam Generators, 

and Process Heaters Greater than 5.0 MMBtu/hr); District Rule 

4307 (Boilers, Steam Generators, and Process Heaters – 2.0 

MMBtu/hr to 5.0 MMBtu/hr); or District Rule 4308 (Boilers, 

Steam Generators, and Process Heaters – 0.075 MMBtu/hr to 

2.0 MMBtu/hr); or 

6.2.2.3 A unit subject to District Rule 4311 (Flares). 
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6.2.3 An operator shall comply with the following requirements for each gauge 

tank, as defined in Section 3.0: 

6.2.3.1 An operator shall conduct periodic TVP testing of each gauge 

tank at least once every 24 months during summer (July – 

September), and whenever there is a change in the source or 

type of produced fluid in the gauge tank. 

6.2.3.2 The TVP testing shall be conducted at the actual storage 

temperature of the produced fluid in the gauge tank using the 

applicable TVP test method specified in Section 6.4 of Rule 

4623 (Storage of Organic Liquids). The operator shall submit 

the TVP testing results to the APCO as specified in Section 

6.1.9. 

6.3 Test Methods 

Test methods that are equivalent to those test methods specified in Section 6.3.1 

through Section 6.3.4 may be used provided that such equivalent test methods 

have been previously approved, in writing, by the EPA, ARB, and the APCO. 

6.3.1 The control efficiency of any VOC control device, measured and 

calculated as carbon, shall be determined by EPA Method 25, except 

when the outlet concentration must be below 50 ppm in order to meet the 

standard, in which case EPA Method 25a may be used. EPA Method 18 

may be used in lieu of EPA Method 25 or EPA Method 25a provided the 

identity and approximate concentrations of the analytes/compounds in the 

sample gas stream are known before analysis with the gas chromatograph 

and the gas chromatograph is calibrated for each of those known 

analyte/compound to ensure that the VOC concentrations are neither 

under- or over-reported. 

6.3.2 VOC content shall be analyzed by using the latest revision of ASTM 

Method E168, E169, or E260 as applicable. Analysis of halogenated 

exempt compounds shall be performed by using ARB Method 432. 

6.3.3 Leak inspection, other than audio-visual, and measurements of gaseous 

leak concentrations shall be conducted according to EPA Method 21 using 

an appropriate portable hydrocarbon detection instrument calibrated with 

methane. The instrument shall be calibrated in accordance with the 

procedures specified in EPA Method 21 or the manufacturer’s instruction, 

as appropriate, not more than 30 days prior to its use. The operator shall 

record the calibration date of the instrument. Where safety is a concern, 

such as measuring leaks from compressor seals or pump seals when the 

shaft is rotating, a person shall measure leaks by placing the instrument 
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probe inlet at a distance of one (1) centimeter or less from the surface of 

the component interface. 

6.3.4 The VOC content by weight percent (wt.%) shall be determined using 

American Society of Testing and Materials (ASTM) D1945 for gases and 

South Coast Air Quality Management District (SCAQMD) Method 304-91 

or the latest revision of ASTM Method E168, E169 or E260 for liquids. 

6.4 Inspection Log 

An operator shall maintain an inspection log in which an operator records, at a 

minimum, all of the following information for each inspection performed: 

6.4.1 The total number of components inspected, and the total number and 

percentage of leaking components found by component type. 

6.4.2 The location, type, and name or description of each leaking component 

and description of any unit where the leaking component is found. 

6.4.3 The date of leak detection and the method of leak detection. 

6.4.4 For gaseous leaks, the leak concentration in ppmv, and for liquid leaks 

record whether the leak is a major liquid leak or a minor liquid leak. 

6.4.5 The date of repair, replacement, or removal from operation of leaking 

components. 

6.4.6 The identify and location of essential components and critical components 

found leaking that cannot be repaired until the next process unit turnaround 

or not later than one year after leak detection, whichever comes earlier. 

6.4.7 The methods used to minimize the leak from essential components and 

critical components found leaking that cannot be repaired until the next 

process unit turnaround or not later than one year after leak detection, 

whichever comes earlier. 

6.4.8 The date of re-inspection and the leak concentration in ppmv after the 

component is repaired or is replaced. 

6.4.9 The inspector’s name, business mailing address, and business telephone 

number. 

6.4.10 The date and signature of the facility operator responsible for the 

inspection and repair program certifying the accuracy of the information 

recorded in the log. 
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6.5 Employee Training Program 

An operator shall establish and implement an employee training program for 

inspecting and repairing components and recordkeeping procedures, as necessary. 

6.6 Operator Management Plan 

By June 30, 2008, an operator whose existing wells are subject to this rule or 

whose existing wells are exempt pursuant to Section 4.0 of this rule on or before 

December 14, 2006 shall prepare and submit an Operator Management Plan for 

approval by the APCO. An operator may use diagrams, charts, spreadsheets, or 

other methods approved by the APCO to describe the information required by 

Section 6.6.4 through Section 6.6.7 below. The Operator Management Plan shall 

include, at a minimum, all of the following information: 

6.6.1 A description of all wells and all associated VOC collection and control 

systems subject to this rule, and all wells and all associated VOC collection 

and control systems that are exempt pursuant to Section 4.0 of this rule. 

6.6.2 Identification and description of any known hazard that might affect the 

safety of an inspector. 

6.6.3 Except for pipes, the number of components that are subject to this rule by 

component type. 

6.6.4 Except for pipes, the number and types of major components, inaccessible 

components, unsafe-to-monitor components, critical components, and 

essential components that are subject to this rule and the reason(s) for such 

designation. 

6.6.5 Except for pipes, the location of components subject to the rule 

(components may be grouped together functionally by process unit or 

facility description). 

6.6.6 Except for pipes, components exempt pursuant to Section 4.6 (except for 

components buried below ground) may be described in the Operator 

Management Plan by grouping them functionally by process unit or 

facility description. The results of any laboratory testing or other 

pertinent information to demonstrate compliance with the applicable 

exemption criteria for components for which an exemption is being 

claimed pursuant to Section 4.6 shall be submitted with the Operator 

Management Plan. 

6.6.7 A detailed schedule of an operator’s inspections of components to be 

conducted as required by this rule and whether the operator inspections of 
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components required by this rule will be performed by a qualified 

contractor or by an in-house team. 

6.6.8 A description of the training standards for personnel that inspect and repair 

components. 

6.6.9 A description of the leak detection training for conducting the test method 

specified in Section 6.3.3 for new operators, and for experienced 

operators, as necessary. 

6.7 By January 30 of each year, an operator shall submit to the APCO for approval, 

in writing, an annual report indicating any changes to an existing Operator 

Management Plan. 

6.8 The APCO shall provide written notice to the operator of the approval or 

incompleteness of a new or revised Operator Management Plan within 60 days of 

receiving such Operator Management Plan. If the APCO fails to respond in 

writing within 60 days after the date of receiving the Operator Management Plan, 

it shall be deemed approved. No provision of the Operator Management Plan, 

approved or not, shall conflict with or take precedence over any provision of this 

rule. 

7.0 Compliance Schedule 

7.1 The operator of any new steam-enhanced crude oil production well, or any nonsteam-enhanced crude oil production well converted to a steam-enhanced crude oil 

production well shall comply with the requirements of this rule and the applicable 

permit requirements of Rule 2201 (New and Modified Stationary Source Review 

Rule) before steam injection and no later than the first detectable flow at the 

casing vent. 

7.2 Steam-enhanced crude oil production wells and components that are exempt 

pursuant to Section 4.2, 4.3, 4.4, 4.6, or 4.7 that become subject to this rule 

through loss of exemption status shall not be operated until such time that they 

are in full compliance with the requirements of this rule. 
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