RULE43 1 1 FLARES (Adopted June 20, 2002; Amended June 15, 2006; Amended June 18, 2009) 1.0 Purpose To limit the emissions of volatile organic compounds (VOC), oxides of nitrogen (NOx), and sulfuroxides (SOX) fromthe operationofflares. 2.0 Applicability This rule is applicableto operationsinvolving the use offlares. 3.0 Definitions 3.1 Air-Assisted Flare: a combustion device where forced air is injected to promote turbulence formixing and to provide combustionair. 3.2 Air Pollution Control Officer (APCO): as defined in Rule 1020 (Definitions). 3.3 Air Resources Board 

### (ARB): as defined in Rule 1020(Definitions). 3.4 British Thermal Unit 

### (Btu): the amount of heat required to raise the temperature of onepound ofwater from 59°Fto 60°Fat one atmosphere. 3.5 Calendar Day: any day starting attwelve o'clock AM and ending at 1 1: 59PM



### . 3.6 Coanda Effect Flare: A flare in which the high pressure flare gas flows along a curved surfaceinspirating air intothe gas topromote combustion. 3.7 Emergency: any situation or a condition arising from a sudden and reasonably unforeseeableand unpreventable eventbeyond the control of the operator. Examples include,but arenot limited to, not preventableequipment failure, natural disaster, act of war or terrorism, or external power curtailment, excluding a power curtailment dueto an interruptiblepower serviceagreement from a utility. A flaring event due to improperly designed equipment, lack of preventative maintenance, careless or improper operation, operator error or willful misconduct does not quality as an emergency. An emergency situation requires immediate corrective action to restore safe operation. Aplanned flaring event shallnot be considered as an emergency. 3.8 Enclosed Flare: a flare composed of multiple gas burners that are grouped in an enclosure, and are stagedto operate at a wide range offlow rates.

SNUAPCD3.9 EPA: United States EnvironmentalProtection Agency. 3.10 Feasible: Capable ofbeing accomplished in a successful manner within a reasonable period of time, taking into account economic, environmental, legal, social, and technologicalfactors. 3.11 Flare: a direct combustion device in which air and 

### all combustible gases react at the burner with the objective of complete and instantaneous oxidation of the combustible gases. Flares areused 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 dropsbelow 0.12 feet per second or when the operator can demonstrate that no more vent gas was combusted based upon the monitoring records of the flare 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 calendarday, each calendar day or venting of gases shall constitutea separate flare event. 3.13 Flare Gas: gas burned in a flare. 3.14 Flare Minimization Plan (FMP): a document intended to meet the requirements of Section6.5 ofthis Rule. 3.15 Flare Monitoring System: 

### all flare monitoring and recording equipmentused for the determination of flare operating parameters. Flare monitoring and recording equipment includes, but is not limited to, sample systems, transducers, transmitters, data acquisition equipment, data recording equipment, and video monitoring equipment and video recording equipment. 3.16 Flexigas: a low BTU fuel gas produced by gasifying coke produced in a fluid-bed Coker. Due to the air used in the gasifying process, Flexigas is approximately 50% nitrogen. 3.17 Gaseous Fuel: any gases used as combustion fuel which include, but are not limited to, any natural, process, synthetic, landfill, sewage digester, or waste gases. Gaseous fuels include produced gas,pilot gas and, when burned, purge gas. 3.1 8 MMBtu: million British thermal units. 3.19 Non-Assisted Flare: a combustion device without any auxiliary provision for enhancing the mixing of air into its flame. This defition does not include those flaresthatby designprovide excess air at the flaretip.

SJVUAPCD3-20 NOx: any nitrogen oxidecompounds 3.21 Open Flare: a vertically or horizontally oriented open pipe flare from which gases arereleased into the airbefore combustionis commenced. 3.22 Operator: includes, but not limited to, any person who owns, leases, supervises, or operates a facility. 3.23 Petroleum Refinery: a facility that processes petroleum, as defined in the Standard Industrial Classification Manual as Industry No. 2911, Petroleum Refining. For the purpose of this rule, all portions of the petroleum refining operation, including those at non-contiguous locations operating flares, shall be considered as one petroleum refinery. 3.24 Pilot: an auxiliaryburnerused to ignite the vent gas routedto a flare. 3.25 Pilot Gas: the gas used to maintainthe presenceof a flame for ignition ofvent gases. 3.26 Planned Flaring: a flaring operationthat constitutes a designed and planned process at a source, and which would have been reasonably foreseen ahead of its actual occurrence, or is scheduled to occur. Planned flaring includes, but is not limited to, the followingflaring activities: 3.26.1 Oil or gas well tests, well related work, tests orderedby a regulatory agency. 3.26.2 Equipmentdepressurizationformaintenancepurposes. 3.26.3 Equipment start-upor shutdown. 3.26.4 Flaring of gas at production sources where no gas handling, gas injection or gas transmission facilities exists. 3.26.5 Flaring of off-specification gas (i.e. non-PUC quality gas), unless the operatorcan 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 the purpose of performing equipment maintenance. 3.27 Prevention Measure: a component, system, procedure, orprogramthat will minimize or eliminateflaring.

SJVUAPCDPublic Utilities Commission (PUC) Quality Gas: any gaseous fuel, gas containing fuel where the sulfur content is no more than one-fourth (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 volume) gas as specified in PUC's General Order 58-A. Purge Gas: Nitrogen, carbon dioxide, liquefied petroleum gas, refinery fuel gas, or natural gas, any of which can be used to maintain a non-explosivemixture of gases in the flare header or provide sufficient exit velocity to prevent any regressive flame travel back into the flareheader. Refinery Fuel Gas: a combustible gas, which is aby-product ofthe refinery process. Reportable Flaring Event: any flaring where more than 500,000 standard 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 demonstratedby monitoring required in Section6.8that the integrity ofthe water seal has been maintained sufficiently to prevent vent gas to the flare tip. For flares without water seals or water seal monitors as required by Section 6.8, a reportable flaring event endswhen the rate of flow of vent gas falls below 0.12 feetper second. Representative Sample: a sample of vent gas collected from the location as approved for flaremonitoring and analyzed utilizingtest methods specified in Section6.3.4. Shutdown: the procedure by which the operation 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 maintenanceor operator error shall not be deemed a shutdown. Startup: the procedureby which aprocess unit orpiece ofequipment achieves normal operational status, as indicated by such parameters as temperature,pressure, feed rate and product quality. Steam-Assisted Flare: a combustion device where steam is injected into the combustion zone to promoteturbulence for the mixing ofthe combustion air before it is introducedto the flame. Thermal oxidizer: an enclosed or partially enclosed combustion device, other than a flare,that isused to oxidize combustiblegases.

SJVUAPCD3.37 Total Organic Gases (TOG): all hydrocarbon compounds containing hydrogen and carbon with or without other chemical elements. 3.38 Turnaround: a planned activity involving shutdown and startup of one or several process units for the purpose of performing periodic maintenance, repair, replacementof equipment or installationof new equipment. 3.39 Vent Gas: any gas directed into a flare, excluding assisting air or steam, flare pilot gas, and any continuouspurge gases. 3.40 Volatile Organic Compound (VOC): as defined in Rule 1020 (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 addition to enabling the upstream flare system header to operate at a slightpositivepressure at all times. 4.0 Exemptions 4.1 Flares operated in municipal solid waste landfills subject to the requirements of Rule 4642 (Solid Waste Disposal Sites)are exempt from this rule. 4.2 Flares that are subject to the requirements of 40 CFR 60 Subpart 

### WWW (Standards of Performance for Municipal Waste Landfills), or Subpart Cc (Emission Guidelines and Compliance Times for Municipal Solid Waste Landfills) are exempt fromthis rule. 4.3 Except for the recordkeeping requirements in Section 6.1.4 the requirements of this rule shall not apply to any stationary source that has the potential to emit, for all processes, less than ten (10.0) tons per year of VOC and less than ten (10.0)tons per year of NOx.

SJVU APCD5.0 Requirements The operatorof any source subjectto 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 requirementsof Sections 5.6 and 5.7. 5.2 The flame shall be present at all times when combustible gases are vented through the flare. 5.3 The outlet shall be equipped with an automatic ignition system, or, shall operate with a pilot flame present at all times when combustiblegases are vented through the flare, exceptduring purge periods for automatic-ignitionequipped flares. 5.4 Except for flares equipped with a flow-sensing ignition system, a heat sensing device such as a thermocouple, ultraviolet beam sensor, infrared sensor, or an alternative equivalent device, capable of continuously detecting at least one pilot flame or the flareflame is present shall be installed and operated. 5.5 Flares that use flow-sensing automatic ignition systems and which do not use a continuous flamepilot shalluse purge gas forpurging. 5.6 Open flares (air-assisted, steam-assisted, or non-assisted) 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 effectflares. 5.7 Ground-levelenclosed flares shall meet the following emission standards:

Without Steam-assist <lOMMBtu I 

# 1- 0.1330 

# 1

>100MMBtu 0.5240 With Steam-assist 

## 1 All 

## I 0.14 as TOG 

## I 0.068 

## 11

Type ofFlare and Heat Release Rate inMMBtuthr

SNUAPCD VOC (IbiMMBtu)5.8 Flare MinimizationPlan Effective on and afterJuly 1,2011,flaring is prohibited unless it is consistentwith an approved flare minimization plan (FMP), pursuant to Section 6.5, and all commitments listed in that plan have been met. This standard shall not apply if the APCO determines that the flaring is caused by an emergency as defined by Section 3.7 and is necessary to prevent an accident, hazard or release of vent gas directly to the atmosphere. 5.9 Petroleum Refinery SO2PerformanceTargets 5.9.1 Effective on and after January 1, 2011,the operator of a petroleum refinery shall minimize sulfur dioxideflareemissionsto less than 1.50tonsper million barrels of crude processing capacity, calculated as an average over one calendaryear. 5.9.2 Effective on and after January 1, 2017, the operator of a petroleum refinery shall minimize sulfur dioxideflareemissionsto less than 0.50tons per million barrels of crude processing capacity, calculated as an average over one calendaryear. 5.10 Effective on and after July 1, 2011, the operator of a flare subject to flare minimization requirements pursuant to Section 5.8 shall monitor the vent gas flow to the flare with a flow measuring device or other parameters as specified in the Permit to Operate. The operator shall maintain records pursuant to Section6.1.7. Flaresthat the operator can verify, based on permit conditions, are not capable of producing reportable flare eventspursuant to Section6.2.2 shall not be required to monitor vent gas flow to the flare. 5.11 Effective on and after July 1,2011, the operator of a petroleum refinery or a flare with a flaring capacity equal to or greater than 50 

### MMBtuthr shall monitor the flare pursuantto Sections6.6, 6.7, 6.8, 6.9, and 6.10. 6.0 AdministrativeRequirements 6.1 Recordkeeping The following records shall be maintained, retained on-site for a minimum of five years, and made availableto the APCO, ARB, and EPA upon request: 6.1.1 Copy ofthe compliance determinationconductedpursuantto Section6.4.1 6.1.2 Copy ofthe sourcetesting result conductedpursuantto Section6.4.2.

SJVUAPCD6.1.3 For flares used during an emergency, record of the duration of flare operation, amount ofgas burned, and the nature ofthe emergency situation. 6.1.4 Operators claiming an exemption pursuant to Section4.3 shall 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 minimizationplan pursuantto Section6.5. 6.1.6 Effective on and after July 1, 2012, where applicable, a copy of annual reports submitted to the APCO pursuantto Section6.2. 6.1.7 Effective on and after July 1, 2011, where applicable, monitoring data collected pursuantto Sections5.10, 6.6, 6.7, 6.8, 6.9, and 6.10. 6.2 FlareReporting 6.2.1 Unplanned Flaring Event Effective on and after July 1, 2011, the operator of a flare subject to flare minimizationplans pursuant to Section5.8of 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 afterJuly 1, 2012, and annuallythereafter, the operatorof a flare subject to flare minimization plans pursuant to Section 5.8 shall submit 

### an annual report to the APCO that summarizes all Reportable Flaring Events as defined in Section 3.0that 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 limitedto all ofthe following: 6.2.2.1 The results of an investigation to determine the primary cause and contributing factors ofthe flaring event;

SJVUAPCD 6.2.2.2 Any prevention measures considered or implemented to prevent recurrence together with a justification for rejecting any measures that were consideredbut 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 mandate to vent a flare, it cannot be recovered, treated and used as a fuel gas at the facility; and 6.2.2.4 The date, time, and durationofthe flaring event. 6.2.3 Annual Monitoring Report Effective on and afterJuly 1, 2012, and annually thereafter, the operator of a flare subject to flare monitoring requirements pursuant to Sections5.10, 6.6, 6.7, 6.8, 6.9, and 6.10, as appropriate, shall submit an annual report to the 

### APCO within 30days following the end ofeach 12monthperiod. The report shall includethe following: 6.2.3.1 The total volumetric flow ofvent gas in standard cubic feet for each day. 6.2.3.2 Hydrogen sulfide content, methane content, and hydrocarbon content ofvent gas composition pursuantto Section6.6. 6.2.3.3 If vent gas composition is monitored by a continuous analyzer or analyzers pursuant to Section 5.11, average total hydrocarbon content by volume, average methane content by volume, and depending upon the analytical method used pursuant to Section 6.3.4, total reduced sulfur content by volume or hydrogen sulfide contentby volume ofvent gas flared for each hour ofthe month. 6.2.3.4 If the flow monitor used pursuant to Section 5.10 measures molecular weight, the average molecular weight for each hour of each month. 6.2.3.5 For any pilot and purge gas used, the type of gas used, the volumetric flow for each day and for each month, and the means used to determine flow. 6.2.3.6 Flare monitoring system downtime periods, including dates and times.

SJVUAPCD 6.2.3.7 For each day and for each month provide 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 verification testing pursuantto Section 6.3.5. 6.3 Test Methods The test methods listed below shall be used to demonstratecompliancewith this rule. Alternate equivalent test methods may be used provided the test methods have been approvedby the APCO and EPA. 6.3.1 VOC, measured and calculated as carbon, shall be determined by EPA Method 25, except when the outlet concentrationmust be below 50 ppm in order to meet the standard, in which case Method 25a may be used, and analysis ofhalogenated exempt compounds shall be analyzedby 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 Btu (IbIMMBtu) by using the following equation: (ppmvdry) x (F, dscf /MMBtu) VOCinlb/MMBtu = (1.135x106)x(20.9-%02) Where:F = As determinedby EPA Method 19 6.3.2 NOx emissions in pounds per million BTU shallbe determinedby using EPA Method 19. 6.3.3 NOx and 02 concentrations shall be determined by using EPA Method 3A, EPA Method 7E, or ARB 100. 6.3.4 Testing and Sampling Methods for Flare Monitoring Effective on and after July 1, 2011operators subject to vent gas composition monitoring requirements pursuant to Section 6.6 shall use the following test methods as appropriate, or by an alternativemethod approvedby the APCO, 

### ARB and EPA: 6.3.4.1 Total hydrocarbon content and methane 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,

SNUAPCD 6.3.4.2 Hydrogen sulfide content of vent gas shall be determined using ASTM Method D 1945-96, ASTM Method UOP 539-97, ASTM Method D 4084-94, or ASTM Method D 4810-88.6.3.4.3 If vent gas composition is monitored with a continuous analyzer employing gas chromatography the 

### minimum sampling frequency shall be one sample every 30minutes. 6.3.4.4 If vent gas composition is monitored using continuous analyzers not employing gas chromatography, the total reduced sulfur content of vent gas shall be determinedby using EPA Method D4468-85. 6.3.5 Flow Verification TestMethods For purposes of the flow verification report required by Section 6.2.3.9,vent gas flow shall be determinedusing one or more of the following methods, or by any alternativemethod approvedby the APCO, 

### ARB, and EPA : 6.3.5.1 EPA Methods 1and2; 6.3.5.2 A verificationmethod recommendedby the manufacturer of the flow monitoring equipment installed pursuant to Section5.10. 6.3.5.3 Tracergas dilution or velocity. 6.3.5.4 Other flow monitors or process monitors that can provide comparison data on a vent stream that is being directed past the ultrasonicflow meter. 6.4 Compliance Determination 6.4.1 Upon request the operator of flares that are subject to Section 5.6 shall make available to the APCO the compliancedetermination records that demonstrate compliancewith theprovisionsof40 CFR 60.18, (c)(3)through (c)(5). 6.4.2 The operator of ground-level enclosed flares shall conduct source testing at least once every 12months to demonstrate compliancewith Section5.7. 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 completion of the source testing.

SJVUAPCD6.5 Flare Minimization Plan 6.5.1 By July 1, 2010, the operator of a petroleum 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 limitedto: 6.5.1.1 A description and technical specifications for each flare and associated knock-out pots, surge drums, 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, processes, or procedures the operator plans to install or implement to eliminate or minimize flaring and planned date ofinstallationor implementation. 6.5.1.4 An evaluation of prevention measures to reduce flaring that has occurred or may be expected to occur during planned major maintenance activities, including startupand shutdown. 6.5.1.5 An evaluationofpreventative measures 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 capacity available for excess vent gases, and the scrubbing capacity available for vent gases including any limitations associatedwith scrubbingvent gases foruse as a fuel; and shall determine the feasibility of reducing flaring though the recovery, treatment and use ofthe gas or other means. 6.5.1.6 An evaluation of preventative measures to reduce flaring caused by the recurrent failure of air pollution control equipment, process equipment, or a process to operate in a normal or usual manner. The evaluation shall determinethe adequacy of existing maintenance schedules and protocols for such equipment. 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 accordancewith Section6.2.2. 6.5.1.7 Any other information requested by the APCO as necessary for determination of compliancewith applicable provisions ofthis rule.

SJVUAPCD6.5.2 Every five years after the initial FMP submittal, the operator shall submit an updated FMP for each flare to the APCO for approval. The current FMP shall remain in effect until the updated FMP is approved by the APCO. If the operator fails to submit an updated FMP as required by this section, the existing FMP shallno longer be considered an approvedplan. 6.5.3 An updated FMP shall be submitted by the operator pursuant to Section 6.5 addressing new or modified equipment, prior to installing the equipment. Updated FMP submittalsare only required if: 6.5.3.1 The equipment change would require an authority to construct (ATC) and would impact the emissions fromthe 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 increasein flareemissions. 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 Public Records Act, Government Code Section 6250 et seq. If a document is submitted that contains information designated confidential, the operator shall provide a justification for this designation and shall submit a separate copy of the document with the informationdesignated confidential redacted. 6.6 Vent Gas CompositionMonitoring Effective on and afterJuly 1, 2011, the operator of a petroleum refinery flare or any flare that has a flaring capacity equal to or greater than 50 

### MMBtu per hour shall monitor vent gas compositionusing one of the five.methodspursuantto Section6.6.1 through Section6.6.5as 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 standard cubic feet per minute (SCFM), a sample shall be taken within 15minutes. The sampling frequency thereafter shall be one sample every three hours and shall continueuntil the flow rate ofvent gas flared in any consecutive 15- minute period is continuously 330 SCFM or less. 

### In no case shall a samplebe required more frequently than once every 3 hours.

SNUAPCD6.6.1.2 Samples shall be analyzed pursuant to Section6.3.4. 6.6.2 Integrated sampling that meets the following requirements: 6.6.2.1 If the flow rate of vent gas flared in any consecutive 15 minute period continuously exceeds 330 SCFM, integrated sampling shall begin within 15 minutes and shall continue until the flow rate of vent gas flared in any consecutive 15 minute period is continuously 330 SCFMor less. 6.6.2.2 Integrated sampling shall consist of a minimum of one aliquot for each 15-minute period until the sample container is full. If sampling is still required pursuant to Section 6.6.2.1,a new sample container shall be placed in service within one hour after the previous sample was filled. A sample container shall not be used for a sampling period that exceeds24 hours. 6.6.2.3 Samples shallbe analyzed pursuantto Section6.3.4. 6.6.3 Continuous analyzers that meetthe following requirements: 6.6.3.1 The analyzers shall continuously monitor for total hydrocarbon methane, and depending upon the analytical method used pursuant to Section6.3.4,hydrogen sulfideor 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 accurate to within 20% when compared to any field accuracy tests or to within 5%of full scale. 6.6.4 Continuous analyzers employing gas chromatography that meet the following requirements: 6.6.4.1 The gas chromatography system shall monitor for total hydrocarbon, methane, and hydrogen sulfide. 6.6.4.2 The gas chromatography system shall be maintained to be accurate within 5% offull scale. 6.6.5 Monitor sulfur content using a colorimetrictube system on a daily basis, and monitor vent gas hydrocarbon on a weekly basis by collecting samples and having themtested pursuantto a method in Section6.3.4.

SJVUAPCD6.6.6 If flares share a common header, a sample from the header will be deemed representative ofvent gas composition for 

### all flares servedby the header. 6.6.7 The operator shallprovide the APCO with access to the monitoring systemto collectvent gas samplesto verify the analysis required by Section5.11. 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 capacity equal to or greater than 50 MMBtu per hour shall monitor the volumetric flows ofpurge and pilot gaseswith flowmeasuring 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. 6.8 Water Seal Monitoring Effective on and after July 1,2011,the operator of apetroleum refinery flare or any flare that has a flaring capacity equal to or greater than 50 MMBtu per hour with a water seal shall monitor and record the water level and pressure ofthe water sealthat serviceseach flaredaily 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 capacity equal to or greater than 50 MMBtu per hour shall comply with the following, as applicable: 6.9.1 Periods of flare monitoring system inoperation greater than 24 continuous hours shall be reported by the following working day, followed by notification of resumption of monitoring. Periods of inoperation of monitoring equipment shall not exceed 14days per any 18-consecutive-month period. Periods of flare monitoring system inoperation do not include the periods when the systemfeeding the flare is not operating. 6.9.2 During periods of inoperation of continuous analyzers or auto-samplers installed pursuant to Section 6.6, operators responsible for monitoring shall take one sample within 30 minutes of the commencementof flaring, fromthe flare header or from an alternate location at which samples are representative ofvent gas composition and have samples analyzed pursuant to Section6.3.4. During periods of inoperation of flow monitors required by Section 5.10, flow shall be calculatedusing good engineeringpractices.

SJVUAPCD6.9.3 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 specification 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 writtenpolicy must explain and justify the difference between the written procedure and the manufacturer's procedure. 6.9.4 All in-line continuous analyzer and flow monitoring data must be continuously recorded by an electronic data acquisition system capable of one-minute averages. Flow monitoring data shall be recorded as one-minute averages. 6.10 Video Monitoring Effective on and after July 1, 2011,the operator of a petroleum refinery flare shall install and maintain equipment that records a real-time digital 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, contrast, and resolution to be readily apparent in the overall image or frame. The image shall include an embedded 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 offlaring events. 7.0 Compliance Schedule Operators of flares, that are exempt under Section 4.0 and that lose exemption status, shall not operate flares until in full compliance with all applicable requirements of this rule effective onthe date the exemption status is lost.

SJVUAPCD