# Revised Proposed June 18, 2009

RULE 4311 FLARES (Adopted June 20, 2002; Amended June 15, 2006 ; Amended [ Rule adoption Date ] )

1.0 Purpose

The purpose of this rule is to l L imit the emissions of volatile organic compounds (VOC)

, and oxides of nitrogen (NOx) , and sulfur oxides (SOx) from the operation of flares.

2.0 Applicability

This rule is applicable to opera tions involving the use of flares.

3.0 Definitions

3.1 Air-Assisted Flare: a combustion device wh ere forced air is injected to promote turbulence for mixing and to provide combustion air.

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

3.3 Air Resources Board (ARB or CARB ): as defined in Ru le 1020 (Definitions).

3.4 British Thermal Unit (Btu): the amount of heat required to raise the temperature of one pound of water from 59 o F to 60 o F at one atmosphere.

3.5 Calendar Day: any day starting at twelve o’clock AM and ending at 11:59 PM.

3.6 3.4 Coanda Effect Flare: A flare in which the high pressure flare gas flows along a curved surface inspirating air into the gas to promote combustion.

3.7 3.5 Emergency: any situati on or a condition arising fr om a sudden and reasonably

unforeseeable and unpreventable event beyond the contro l of the operator. Examples include, but are not limited to, not preventabl e equipment failure, natural disaster, act of war or terrorism, or external power cu rtailment, excluding a power curtailment due to an interruptible powe r service agreement from a utility. A flaring event due to improperly designed equipmen t, lack of preventative maintenance, careless or improper operation, operato r error or willful misconduc t does not quality as an

emergency. An emergency situation requires imme diate corrective action to restore safe operation. A planned fl aring event shall not be cons idered as an emergency.

3.8 3.6 Enclosed Flare: a flare composed of multiple gas burne rs that are grouped in an

enclosure, and are staged to operate at a wide range of flow rates.

3.9 EPA: United States Envir onmental Protection Agency.

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3.10 Feasible: Capable of being accomplished in a successful manner within a reasonable period of time, taking into account economic , environmental, le gal, social, and technological factors.

3.11 .7 Flare: a direct combustion device in which air and all co mbustible gases react at the burner with the objective of complete and instantaneous oxidation of the combustible gases. Flares are used either continuously or intermittently and are not equipped with

devices for fuel-air mix control or for temperature control.

3.12 Flare Event: any intentional or unintentional combustion of vent gas in a flare. The flare event ends when the flow velocity dr ops below 0.12 feet pe r second or when the operator can demonstrate that no more vent gas was combusted based upon the monitoring records of the fl are water seal level and/or other parameters as approved by the APCO in the Flare Monitoring and Recording Plan. For a flare event that

continues for more than one calendar day, each calendar day or ven ting of gases shall constitute a separate flare event.

3.13 3.8 Flare Gas: gas burned in a flare.

3.14 Flare Minimization Plan (FMP): a document intended to meet the requirements of

Section 6.5 of this Rule.

3.15 Flare Monitoring System: all flare monitoring and record ing equipment used for the determination of flare operating parame ters. Flare monito ring and recording equipment includes, but is not limited to, sa mple systems, transducers, transmitters, data acquisition equipment, data recording equipmen t, and video monitoring equipment and video r ecording equipment.

3.16 Flexigas: a low BTU fuel gas produced by ga sifying coke produ ced in a fluid-bed Coker. Due to the air used in the gasify ing process, Flexigas is approximately 50% nitrogen.

3.17 3 .9 Gaseous Fuel: any gases used as co mbustion fuel which include, but are not limited to, any natural, process, synthetic, landfill, sewage digester , or waste gases. Gaseous fuels include produced gas, pilo t gas and, when bu rned, purge gas.

3.18 MMBtu: million British thermal units.

3.19 3. 10 Non-Assisted Flare: a combustion devi ce without any auxiliary provision for enhancing the mixing of air into its flame. This de finition does not include those flares that by design provide excess air at the flare tip.

3.20 3.11 NOx: any nitrogen oxide compounds

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3.21 3 .12 Open Flare: a vertically or horizontally oriented open pipe flare from which gases are released in to the air before combustion is commenced.

3.22 Operator: includes, but not limited to, a ny person who owns, leas es, supervises, or operates a facility.

3.23 Petroleum Refinery: a facility that processe s petroleum, as defi ned in the Standard

Industrial Classification Manua l as Industry No. 2911, Petr oleum Refining. For the purpose of this rule, all portions of the petroleum refining opera tion, including those at non-contiguous locations operating flares, shall be c onsidered as one petroleum refinery.

3.24 Pilot: an auxiliary burner used to ignite the vent gas routed to a flare.

3.25 Pilot Gas: the gas used to maintain the pres ence of a flame for ignition of vent gases.

3.26 3.13 Planned Flaring: a flaring operation that constitutes a designed a nd planned process at a source, and wh ich would have been reasona bly foreseen ahead of its actual occurrence, or is scheduled to occur. T he operation of a flare for the purpose of performing equipment maintenance provided it does not exceed 200 hours per calendar year, or during compliance source testing or visible emission inspections is not considered planned flaring. Planned flaring includes, but is not limited to, the following flaring activities:

3.26.1 3.13.1 Oil or gas well tests, well relate d work, tests ordered by a regulatory

agency.

3.26.2 3.13.2 Equipment depressurizati on for maintenance purposes.

3.26.3 3.13.3 Equipment start-up or shutdown.

3.26.4 3.13.4 Flaring of gas at production s ources where no gas handling, gas injection or gas transm ission facilities exists.

3.26.5 3.13.5 Flaring of off-specification gas (i .e. non PUC quality gas), unless the operator can demonstrate that the gas must be flared for engineering or safety reasons, e.g., under emergency.

3.26.6 The operation of a flare for th e purpose of performing equipment

maintenance.

3.27 Prevention Measure: a componen t, system, procedure, or program that will minimize or eliminate flaring.

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3.28 3.14 Public Utilities Commiss ion (PUC) Quality Gas: any gaseous fuel, gas containing fuel where the sulfur content is no more than one-four th (0.25) grain of hydrogen sulfide per one hundred (100) standard cubic feet and no more than five grains of total sulfur per one hundred (100) standard cubic feet . PUC quality gas shall also mean high methane (at least 80% by vo lume) gas as specifie d in PUC's General

Order 58-A.

3.29 3.15 Purge Gas: Nitrogen, carbon di oxide, liquefied petroleum gas, refinery fuel

gas, or natural gas, any of whic h can be used to maintain a non-explosive mixture of gases in the flare header or provide sufficient exit velocity to prev ent any regressive

flame travel back into the flare header.

3.30 Refinery Fuel Gas: a combus tible gas, which is a by-produc t of the refinery process.

3.31 Reportable Flaring Event: any flaring where more than 500,000 st andard cubic feet of vent gas is flared per calendar day, or where sulfur oxide emissions are greater than 500 pounds per calendar day. A reportable flaring event ends when it can be demonstrated by monitoring required in Secti on 6.8 that the integrity of the water seal

has been maintained sufficie ntly to prevent vent gas to the flare tip. For flares

without water seals or water seal monitors as required by Sec tion 6.8, a reportable flaring event ends when the ra te of flow of vent gas falls below 0.12 feet per second.

3.32 Representative Sample: a samp le of vent gas collected fr om the location as approved for flare monitoring and analyzed utilizing te st methods specified in Section 6.3.4.

3.33 Shutdown: the procedure by which the ope ration of a process unit or piece of equipment is stopped due to the end of a production run, or for the purpose of performing maintenance, repair and replacement of equipment. Stoppage caused by frequent breakdown due to poor maintenance or operator error shall not be deemed a

shutdown.

3.34 Startup: the procedure by which a process uni t or piece of equipment achieves normal operational status, as indicated by such parameters as temperature, pressure, feed rate and product quality.

3.35 3.16 Steam-Assisted Flare: a combustion de vice where steam is injected into the combustion zone to promote turbulence for the mixing of the combustion air before it

is introduced to the flame.

3.36 Thermal oxidizer: an enclosed or partially enclosed combustion de vice, other than a flare, that is used to oxidize combustible gases.

3.37 3.17 Total Organic Gases (TOG) : all hydrocarbon compounds containing hydrogen and carbon with or without other chemical elements.

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3.38 Turnaround: a planned activit y involving shutdown and st artup of one or several process units for the purpose of perf orming periodic main tenance, repair, replacement of equipment or in stallation of new equipment.

3.18 U.S. EPA: the United States Environmental Protection Agency.

3.39 Vent Gas: any gas directed into a flare, excluding assist ing air or steam, flare pilot gas, and any conti nuous purge gases.

3.40 3.19 Volatile Organic Compound (VOC): as de fined in Rule 10 20 (Definitions).

3.41 Water Seal: a liquid barrier, or seal, to prevent the passage of gas. Water seals provide a positive means of flash-back prevention in additi on to enabling the upstream flare system he ader to operate at a slight positive pr essure at all times.

4.0 Exemptions

4.1 Flares operated in municipal solid wast e landfills subject to the requirements of Rule 4642 (Solid Waste Disposal Site s) are exempt from this rule.

4.2 Flares that are subject to the re quirements of 40 CFR 60 Subpart WWW (Standards of Performance for Munici pal Waste Landfills), or Subpart Cc (Emission Guidelines and Compliance Times for Municipal Solid Waste Landfills) are exempt from this rule.

4.3 Except for the recordkeep ing requirements in Section 6.1.4 6.2.4 the requirements of this rule shall not apply to any sta tionary source that has the potential to emit, for all pro cesses, less than ten (10. 0) tons per year of VOC and less than ten (10.0) tons per year of NOx.

5.0 Requirements

The owner or operator of any source subject to this rule shall comply with the following requirements:

5.1 Flares that are permitted to operate only during an emergency are not subject to the requirements of Sec tions 5.6 and 5.7.

5.2 The flame shall be present at all times wh en combustible gases are vented through the

flare.

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5.3 The outlet shall be equipped with an automatic ignition system, or, shall operate with a pilot flame present at all tim es when combustible gases ar e vented through the flare, except during purge periods for au tomatic-ignition equipped flares.

5.4 Except for flares equipped with a flow-s ensing ignition system, a heat sensing device such as a thermocouple, ultr aviolet beam sensor, infrared sensor, or an alternative equivalent device, capable of continuously detecting at least one pilot flame or the flare flame is present shall be installed and operated.

5.5 Flares that use flow-sensing automa tic ignition systems a nd which do not use a continuous flame pilot shall use purge gas for purging.

5.6 Open flares (air-assiste d, steam-assisted, or non-assi sted) in which the flare gas pressure is less than 5 psig shall be operated in such a manner that meets the provisions of 40 CFR 60.18. The requirements of this section shall not apply to

Coanda effect flares.

5.7 Ground-level enclosed flares shall me et the following emission standards:

Type of Flare and Heat Release

Rate in MMBtu/hr VOC (lb/MMBtu) NOx (lb/MMBtu)

Without Steam-assist

<10 MMBtu 0.0051 0.0952

10-100 MMBtu 0.0027 0.1330

>100 MMBtu 0.0013 0.5240

With Steam-assist

All 0.14 as TOG 0.068

5.8 Flare Minimization Plan

Effective on and after July 1, 201 1, flaring is prohibited unles s it is consistent with an approved flare minimization plan (FMP ), pursuant to Section 6.5, and all commitments listed in that pl an have been met. This st andard shall not apply if the APCO determines that the flaring is caus ed by an emergency as defined by Section 3.7 and is necessary to preven t an accident, hazard or release of vent gas directly to the atmosphere.

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5.9 Petroleum Refinery SO 2 Performance Targets

5.9.1 Effective on and after Janua ry 1, 2011, the operator of a petroleum refinery

shall minimize sulfur dioxide flare emissions to less than 1.50 tons per million barrels of crude processing capacity, calculated as an average over one calendar year.

5.9.2 Effective on and after Janua ry 1, 2017, the operator of a petroleum refinery

shall minimize sulfur dioxide flare emissions to less than 0.50 tons per million barrels of crude processing capacity, calculated as an average over one calendar year.

5.10 Effective on and after July 1, 2011, th e operator of a flare subject to flare minimization requirements pursuan t to Section 5.8 shall mon itor the vent gas flow to the flare with a flow measuring device or ot her parameters as specified in the Permit to Operate. The operator sha ll maintain records pursuant to Section 6.1.7. Flares that the operator can verify, based on permit conditions, are not capable of producing reportable flare events pursuant to Section 6.2.2 shall not be required to monitor vent gas flow to the flare.

5.11 Effective on and after July 1, 2011, the ope rator of a petroleum refinery or a flare with a flaring capacity equal to or greater than 50 MMBtu/hr sha ll monitor the flare pursuant to Sections 6.6, 6.7, 6.8, 6.9, and 6.10.

6.0 Administrative Requirements

6.1 Compliance Determination

6.1.1 Upon request the operator of flares that are subject to Section 5.6 shall make

available to the AP CO the compliance determination records that demonstrate compliance with the provisions of 40 CFR 60.18, (c)(3) through (c)(5).

6.1.2 The operator of ground

- level enclosed flares shal l conduct source testing at least once every 12 months to demonstrate c ompliance with Section 5.7. The operator shall submit a copy of the testi ng protocol to the APCO at least 30 days in advance of the scheduled tes ting. The operator shall submit the

source test results not later than 45 days after completion of the sourc e testing.

6.1 6.2 Recordkeeping

The following records shall be maintained, retained on-site for a minimum of five years, and made ava ilable to the APCO, ARB, and U.S. EPA upon request:

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6.1.1 6.2.1 Copy of the compliance determina tion conducted pursuant to Section

6.1.1 6.4.1.

6.1. 2 6.2.2 Copy of the source testing result conducted pursuant to Section 6.1.2

6.4.2.

6.1.3 6.2.3 For flares used during an emergenc y, record of the duration of flare operation, amount of gas burned, and the nature of the emergency situation.

6.1.4 6.2.4 Beginning January 1, 2007, facilities Operators claiming an exemption pursuant to Section 4.3 sh all record annual throughput, material usage, or other information necessary to demonstrate an exemption under that

section.

6.1.5 Effective on and after July 1, 2011, a copy of the approved flare minimization plan pursuant to Section 6.5.

6.1.6 Effective on and after July 1, 2012, where applicable, a copy of annual reports submitted to the APCO pursuant to Section 6.2.

6.1.7 Effective on and after July 1, 2011, where applicable, monitoring data collected pursuant to Sections 5.10, 6.6, 6.7, 6.8, 6.9, and 6.10.

6.2 Flare Reporting

6.2.1 Unplanned Flaring Event

Effective on and after July 1, 2011, th e operator of a flare subject to flare minimization plans pursuant to Section 5. 8 of this rule shall notify the APCO of an unplanned flaring event within 24 hours after the start of the next business day or within 24 hours of their discovery, which ever occurs first. The notification shall include the flare source identification, the start date and time, and the end date and time.

6.2.2 Reportable Flaring Event

Effective on and after July 1, 2012, and annually thereafter, the operator of a flare subject to flare mini mization plans pursuant to Section 5.8 shall submit an annual report to the APCO that su mmarizes all Reportable Flaring Events

as defined in Section 3.0 that occurred during the previous 12 month period. The report shall be submitted within 30 days following the end of the twelve month period of the previous year. The report shall include, but is not limited to all of the following:

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6.2.2.1 The results of an investigation to determine the primary cause and contributing factors of the flaring event;

6.2.2.2 Any prevention measures consider ed or implemented to prevent recurrence together with a justification for re jecting any measures

that were considered but not implemented;

6.2.2.3 If appropriate, an explanation of why the flaring was an emergency and necessary to prevent accident, hazard or release of vent gas to the atmosphere, or where, due to a regulatory manda te to vent a flare, it cannot be rec overed, treated and used as a fuel gas at the facility; and

6.2.2.4 The date, time, and dura tion of the flaring event.

6.2.3 Annual Monitoring Report

Effective on and after July 1, 2012, and annually thereafter, the operator of a flare subject to flare monitoring require ments pursuant to Sections 5.10, 6.6,

6.7, 6.8, 6.9, a nd 6.10, as appropriate, shall submit an annual report to the APCO within 30 days following the e nd of each 12 month period. The report shall include the following:

6.2.3.1 The total volumetric flow of vent gas in standard cubic feet for each day.

6.2.3.2 Hydrogen sulfide content, methan e content, and hydrocarbon content of vent gas composition pu rsuant to Section 6.6.

6.2.3.3 If vent gas composition is monito red by a continuous analyzer or analyzers pursuant to Section 5.11, average total hydrocarbon content by volume, average methane conten t by volume, and depending upon the analytical method used pursuant to Section 6.3.4, total reduced sulfur content by volume or hydrog en sulfide content by volume of vent gas flared for each hour of the month.

6.2.3.4 If the flow monitor used pursuant to Section 5.10 measures molecular weight, the average molecular wei ght for each hour of each month.

6.2.3.5 For any pilot and purge gas used, th e type of gas used, the volumetric flow for each day and for each month, and the means used to

determine flow.

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6.2.3.6 Flare monitoring system down time periods, including dates and

times.

6.2.3.7 For each day and for each month pr ovide calculated sulfur dioxide

emissions.

6.2.3.8 A flow verification report for each flare subject to this rule. The flow verification report shall include flow verificati on testing pursuant to

Section 6.3.5.

6.3 Test Methods

The test methods listed below shall be used to demonstrate complian ce with this rule. Alternate equivalent test me thods may be used provided th e test methods have been approved by the APCO and EPA.

6.3.1 VOC, 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 whic h case Method 25a may be used, and analysis of halogenated ex empt compounds shall be analyzed by EPA Method

18 or ARB Method 422 “Determination of Volatile organic Compounds in Emission from Stationary Sources”. The VOC concentration in ppmv shall be converted to pounds per million Bt u (lb/MMBtu) by using the following equation:

VOC in lb/MMBtu = )%9 )/

2 O MMBtu

− .20()10135.1( ,()(

6 xx dscfFxdryppmv

Where: F = As determined by EPA Method 19

6.3.2 NOx emissions in pounds per million BTU shall be determined by using EPA

Method 19.

6.3.3 NOx and O 2 concentrations shall be determ ined by using EPA Method 3A, EPA Method 7E, or ARB 100.

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6.3.4 Testing and Sampling Methods for Flare Monitoring

Effective on and after July 1, 2011 op erators subject to vent gas composition monitoring requirements pursuant to S ection 6.6 shall use the following test methods as appropriate, or by an a lternative method approved by the APCO,

ARB and EPA:

6.3.4.1 Total hydrocarbon content and methan e content of vent gas shall be determined using ASTM Method D 1945-96, ASTM Method UOP 539-97, EPA Method 18, or EPA Method 25A or 25B,

6.3.4.2 Hydrogen sulfide content of vent gas shall be de termined using ASTM Method D 1945-96, AS TM Method UOP 539-97, ASTM Method D 4084-94, or AS TM Method D 4810-88.

6.3.4.3 If vent gas composition is monito red with a continuous analyzer employing gas chromatography the minimum sampling frequency shall be one sample every 30 minutes.

6.3.4.3 If vent gas composition is monito red using continuous analyzers not employing gas chromatography, the to tal reduced sulfur content of vent gas shall be determined by using EPA Me thod D4468-85.

6.3.5 Flow Verification Test Methods

For purposes of the flow verification report required by Sec tion 6.2.3.9, vent gas flow shall be determin ed using one or more of the following methods, or by any alternative method approve d by the APCO, ARB, and EPA :

6.3.5.1 EPA Methods 1 and 2;

6.3.5.2 A verification method recommended by the manufacturer of the flow monitoring equipment installed pursuant to Section 5.10.

6.3.5.3 Tracer gas dilution or velocity.

6.3.5.4 Other flow monitors or process monitors that can provide comparison data on a vent stream th at is being directed past the

ultrasonic flow meter.

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6.4 6.1 Compliance Determination

6.4.1 6 .1.1 Upon request the operator of flares that are subject to Section 5.6

shall make available to the APCO the compliance determination records that demonstrate compliance with the provisions of 40 CFR 60.18, (c)(3) through
(c)(5).

6.4. 2 6.1.2 The operator of ground-level enclosed flares shall conduct source testing at least once every 12 months to demonstrate compliance with Section 5.7. The operator shall submit a copy of the testing protocol to the APCO at least 30 days in advance of the scheduled testing. The operator shall submit

the source test results not later than 45 days after comp letion of the source testing.

6.5 Flare Minimization Plan

6.5.1 By July 1, 2010, the operator of a petr oleum refinery flare or any flare that has a flaring capacity of greater than or equal to 5.0 MMBtu per hour shall submit a flare minimization plan (FMP ) to the APCO for approval. The FMP shall include, but not be limited to:

6.5.1.1 A description and technical sp ecifications for each flare and associated knock-out pots, surge dr ums, water seals and flare gas

recovery systems.

6.5.1.2 Detailed process flow diagrams of all upstream equipment and process units venting to each flare, identifying the type and location of all control equipment.

6.5.1.3 A description of equipment, pro cesses or procedures the operator plans to install or implement to eliminate or minimize flaring and planned date of installa tion or implementation.

6.5.1.4 An evaluation of prevention meas ures to reduce flaring that has occurred or may be expected to occur during planned major maintenance activities, incl uding startup and shutdown.

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6.5.1.5 An evaluation of preventative measur es to reduce flaring that may be expected to occur due to issues of gas quantity and quality. The

evaluation shall include an audit of the vent gas recovery capacity of each flare system, the storage cap acity available for excess vent gases, and the scrubbing capacity av ailable for vent gases including any limitations associated with scrubbing vent ga ses for use as a fuel; and shall determine the feasibility of reducing flaring though the recovery, treatment and use of the gas or other means.

6.5.1.6 An evaluation of preventative me asures to reduce flaring caused by the recurrent failure of air pollu tion control equipment, process equipment, or a process to operate in a normal or usual manner.

The evaluation shall determine the adequacy of existing maintenance schedules and protocols for such eq uipment. For purposes of this Section, a failure is recurrent if it occurs more than twice during any five year period as a result of the same cause as identified in

accordance with Section 6.2.2.

6.5.1.7 Any other information requested by the APCO as necessary for determination of compliance with a pplicable provisions of this rule.

6.5.2 Every five years after the initial FMP submittal, the operator shall submit an updated FMP for each flar e to the APCO for appr oval. The current FMP shall remain in effect until the update d FMP is approved by the APCO. If the operator fails to subm it an updated FMP as require d by this section, the existing FMP shall no longer be c onsidered an approved plan.

6.5.3 An updated FMP shall be submitted by the operator pursuant to Section 6.5 addressing new or modified equipment, prior to in stalling the equipment. Updated FMP submittals are only required if:

6.5.3.1 The equipment change would requi re an authority to construct (ATC) and would impact the em issions from the flare, and

6.5.3.2 The ATC is deemed complete after June 18, 2009, and

6.5.3.3 The modification is not solely the removal or decommissioning of equipment that is listed in the FMP, and has no associated increase in

flare emissions.

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6.5.4 When submitting the initial FMP, or updated FMP, the operator shall designate as confidential any information claimed to be exempt from public

disclosure under the California Pub lic Records Act, Government Code Section 6250 et seq. If a document is submitted that contains information designated confidential, th e operator shall provide a justification for this designation and shall submit a separa te copy of the document with the information designated confidential redacted.

6.6 Vent Gas Composition Monitoring

Effective on and after July 1, 2011, the operator of a petroleum refinery flare or any flare that has a flaring cap acity equal to or greater than 50 MMBtu per hour shall monitor vent gas composition us ing one of the five methods pursuant to Section 6.6.1 through Section 6.6. 5 as appropriate.

6.6.1 Sampling that meets the following requirements:

6.6.1.1 If the flow rate of vent gas flared in any consecutive 15-minute period continuously exceeds 330 st andard cubic feet per minute (SCFM), a sample shall be taken w ithin 15 minutes. The sampling frequency thereafter shall be one sample every three hours and shall continue until the flow rate of vent gas flared in any consecutive 15- minute period is continuously 330 SCFM or less. In no case shall a sample be required more frequently than once every 3 hours.

6.6.1.2 Samples shall be analyzed pursuant to Section 6.3.4.

6.6.2 Integrated sampling that meet s the following requirements:

6.6.2.1 If the flow rate of vent gas flared in any consecutive 15 minute period continuously exceeds 330 SC FM, integrated sampling shall begin within 15 minutes and shall continue until the flow rate of vent gas flared in any consecutiv e 15 minute period is continuously

330 SCFM or less.

6.6.2.2 Integrated sampling shall consis t of a minimum of one aliquot for each 15-minute period until the samp le container is full. If sampling is still required pursuant to Section 6.6.2.1, a new sample container shall be placed in se rvice within one hour after the previous sample was filled. A sa mple container shall not be used for a sampling period that exceeds 24 hours.

6.6.2.3 Samples shall be analyzed pursuant to Section 6.3.4.

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6.6.3 Continuous analyzers that meet the following requirements:

6.6.3.1 The analyzers shall continuously monitor for total hydrocarbon methane, and depending upon the an alytical method used pursuant to Section 6.3.4, hydrogen sulfid e or total reduced sulfur.

6.6.3.2 The hydrocarbon analyzer shall have a full-scale range of 100% total hydrocarbon.

6.6.3.3 Each analyzer shall be maintained to be ac curate to within 20% when compared to any fi eld accuracy tests or to within 5% of full

scale.

6.6.4 Continuous analyzers employing gas ch romatography that meet the following requirements:

6.6.4.1 The gas chromatography syst em shall monitor for total hydrocarbon, methane, a nd hydrogen sulfide.

6.6.4.2 The gas chromatography system sh all be maintained to be accurate

within 5% of full scale.

6.6.5 Monitor sulfur content using a colorime tric tube system on a daily basis, and monitor vent gas hydrocarbon on a week ly basis by collecting samples and having them tested pursuant to a method in Section 6.3.4.

6.6.6 If flares share a common header, a samp le from the header will be deemed representative of vent gas composition for all flares served by the header.

6.6.7 The operator shall provide the APCO w ith access to the m onitoring system to collect vent gas samples to verify the analysis requi red by Section 5.11.

6.7 Pilot and Purge Gas Monitoring

Effective on and after July 1, 2011, the operator of a petroleum refinery flare or any flare that has a flaring cap acity equal to or greater than 50 MMBtu per hour shall monitor the volumetric flows of purge and p ilot gases with flow measuring devices or other parameters as specified on the Permit to Operate so that volumetric flows of pilot and purge gas may be calculated based on pilot design and the parameters

monitored.

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6.8 Water Seal Monitoring

Effective on and after July 1, 2011, the operator of a petroleum refinery flare or any flare that has a flaring capacity equal to or greater th an 50 MMBtu per hour with a

water seal shall monitor and r ecord the water level and pressu re of the water seal that services each flare daily or as specified on the Permit to Operate.

6.9 General Monitoring

Effective on and after July 1, 2011, the operator of a petroleum refinery flare or any flare that has a flaring cap acity equal to or greater than 50 MMBtu per hour shall comply with the follo wing, as applicable:

6.9.1 Periods of flare monitoring system inoperation greater than 24 continuous hours shall be reported by the fo llowing working day, followed by notification of resumpti on of monitoring. Periods of inoperation of monitoring equipment shall not exceed 14 days per any 18 consecutive month period. Periods of flare monitoring system inoperation do not include the periods when the system feeding the flare is not operating.

6.9.2 During periods of inop eration of continuous an alyzers or auto-samplers installed pursuant to Section 6.6, opera tors responsible for monitoring shall take one sample within 30 minutes of the commencement of flaring, from the

flare header or from an alternate location at which samples are representative of vent gas composition and have samples analyzed purs uant to Section 6.3.4. During periods of inopera tion of flow monitors required by Section 5.10,

flow shall be calculated usi ng good engineering practices.

6.9.3 Maintain and calibrate all required monitors and recording devices in

accordance with the applicable manufacturer’s specifications. In order to claim that a manufacturer’s specifica tion is not applicable, the person responsible for emissions must have, and follow, a written maintenance policy that was developed for the device in question. The written policy must explain and justify the difference between the written procedure and the manufacturer’s procedure.

6.9.4 All in-line continuous analyzer a nd flow monitoring data must be continuously recorded by an electronic data acquisition sy stem capable of one-minute averages. Flow monitoring da ta shall be recorded as one-minute

averages.

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Amendments to Rule 4311

# Revised Proposed June 18, 2009

6.10 Video Monitoring

Effective on and after July 1, 2011, the opera tor of a petroleum refinery flare shall install and maintain equipmen t that records a real-time di gital image of the flare and

flame at a frame rate of no less than one frame per minute. The recorded image of the flare shall be of sufficient size, contra st, and resolution to be readily apparent in the overall image or frame. The image shall include an em bedded date and time stamp. The equipment shall archive the images for each 24-hour period. In lieu of video monitoring the operator may use an alternative monitoring method that provides data to verify date, time, vent gas flow, and duration of flaring events.

7.0 Compliance Schedule

Operators of flares that are exempt under Section 4.0 that lo se exemption status shall not operate flares until in full comp liance with all applicable require ments of this rule effective on the date the exempti on status is lost.

7. 1 Flares at facilities with a poten tial to emit more than 25 t ons per year of VOC or

NOx that are installed and in operation befo re June 20, 2002 shal l be in compliance with this rule by December 20, 2003.

7.2 Flares, at facilities w ith a potential to emit m ore than 25 tons per year of VOCs or NOx, that are installed or constructed on or after June 20, 20 02, shall be in compliance with this rule upon initial operation and thereafter.

7.3 Flares that are installed before June 15, 2006 at facilities, which have th e potential to emit between 10 tons per year and 25 t ons per year of VOC or NOX shall demonstrate compliance with th is rule by January 1, 2008.

7.4 Flares, at facilities with a potential to emit between 10 tons per year and 25 tons per year of VOC or NOx that are installed or constructed on or after June 15, 2006, shall be in compliance with this rule upon initial operation and thereafter.

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# Revised Proposed June 18, 2009

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4311 – 18 Revised Proposed

Amendments to Rule 4311