RULE 4320 ADVANCED EMISSION REDUCTIO N OPTIONS FOR BOILERS, STEAM GENERATORS, AND PROCESS HE ATERS GREATER THAN 5.0 MMBTU/HR (Adopted October 16, 2008)

1.0 Purpose

The purpose of this rule is to limit emissions of oxides of nitrogen (NOx), carbon monoxide (CO), oxides of sulfur (SO 2 ), and particulate matter 10 microns or less (PM10) from boilers, steam generators, and process heaters.

2.0 Applicability

This rule applies to any gaseous fuel or liquid fuel fired boile r, steam generator, or process heater with a total rated heat input greater than 5 million Btu per hour.

3.0 Definitions

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

3.2 Air Resources Board (ARB): as defined in Rule 1020 (Definitions).

3.3 Annual Capacity Factor: the ratio of the amount of fuel burned by the unit in a calendar year to the amount of fuel that the unit could have burned if it had operated at its maximum rated capacity for 8,760 hours during the calendar year.

3.4 Annual Heat Input: the actual, total h eat input of fuels burned by a unit in a calendar year, as determined from the hi gher heating value and cumulative annual usage of each fuel.

3.5 Boiler or Steam Generator: any external combustion equipment, fired with any fuel used to produce hot water or steam.

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

3.7 California Public Utility Commission (P UC) Quality Natural Gas: any gaseous fuel, gas-containing fuel where the sulfur content is no more than one-fourth (0.25) grain of hydrogen sulfide pe r one hundred (100) standard cubic feet and no more than five (5) grains of total sulfur pe r one hundred (100) sta ndard cubic feet. PUC quality natural gas also means high meth ane gas of at least 80% methane by
volume.

3.8 California PUC Quality Natural Gas Curta ilment: means a shor tage in the supply of California Public Utility Commission (PUC ) quality natural ga s, due solely to supply limitations or restricti ons in distribution pipelines by the utility supplying the gas, and not due to the cost of natural gas.

SJVUAPCD 4320 - 1 10/16/083.9 Dryer: any unit in which material is dried in direct contact with the products of

combustion.

3.10 EPA: United States E nvironmental Protection Agency.

3.11 Gaseous Fuel: any fuel which is a gas at standard conditions.

3.12 Gas Liquids Processing Facility: a fac ility that is engaged in the catalytic processing of gas liquids to produce finished products.

3.13 Heat Input: the heat (hhv basis) releas ed due to fuel combustion in a unit, not including the sensible heat of incoming combustion air and fuel.

3.14 Higher Heating Value (hhv): the total heat liberated per mass of fuel burned (expressed as Btu per pound), when fuel a nd dry air at standard conditions undergo complete combustion and all resulting products are brought to their standard states

at standard conditions.

3.15 Liquid Fuel: any fuel which is a liquid at standard conditions.

3.16 NOx Emissions: the sum of oxi des of nitrogen expressed as NO 2 in the flue gas.

3.17 Oilfield Steam Generator: an extern al combustion equipmen t which converts water to dry steam or to a mixture of water vapo r and steam, with an ab solute pressure of more than 30 psia, and which is used exclusively in th ermally enhanced crude oil production.

3.18 Parts Per Million by Volume (ppmv): the ratio of the number of gas molecules of a given species, or group of species, to the number of millions of total gas
molecules.

3.19 Process Heater: any combustion equipmen t fired with liquid and/or gaseous fuel and which transfers heat from combustion ga ses to water or process streams. This
definition excludes: kilns or ovens used for drying, baking, co oking, calcining, or vitrifying; and unfired waste heat recovery heaters used to r ecover sensible heat from the exhaust of combustion equipment.

3.20 Qualified Technician: a stationary s ource employee or any pe rsonnel contracted by a stationary source operato r who has a documented training and a demonstrated experience performing tune-ups on a unit to the satisfaction of the APCO. The documentation of tune-up trai ning and experience shall be made available to the APCO upon request.

3.21 Rated Heat Input (expre ssed as million Btu per hour): the heat input capacity specified on the nameplate of the unit.

SJVUAPCD 4320 - 2 10/16/083.22 Refinery Unit: a unit that is permanen tly installed and oper ated at a petroleum refinery or a gas liquids processing facility.

3.23 Re-ignition: the relighting of a un it after an unscheduled and unavoidable interruption or shut off of the fuel flow or electrical power, for a period of less than 30 minutes, due to reasons outsi de the control of the operator.

3.24 Seasonal Source: as defined in District Rule 2201 (New And Modified Stationary Source Review Rule)

3.25 Shutdown: the period of time during which a unit is taken from an operational to a non-operational status by allowing it to cool down from its operating temperature to ambient temp erature as the fuel supply to the unit is completely

turned off.

3.26 Solid Fuel: any fuel which is a solid at standard conditions.

3.27 Small Producer: as defined in District Rule 1020 (Definitions)

3.28 Standard Conditions: standard conditions as define d in Rule 1020 (Definitions).

3.29 Start-up: the period of time during which a unit is brought from a shutdown status to its operating temperature a nd pressure, including the time required by the unit’s emission control system to reach full operation.

3.30 Unit: any boiler, steam generator or process heater as defined in this rule.

4.0 Exemptions

4.1 This rule shall not apply to:

4.1.1 Solid fuel fired units.

4.1.2 Dryers and glass melting furnaces.

4.1.3 Kilns and smelters where the pr oducts of combustion come into direct
contact with the material to be heated.

4.1.4 Unfired or fired wa ste heat recovery boilers th at are used to recover or augment heat from the exhaust of combustion turbines or internal combustion engines.

4.2 The requirements of Secti ons 5.2 shall not apply to a unit when burning any fuel other than California PUC quality natu ral gas during California PUC quality natural gas curtailment provided all of the following conditions are met:

SJVUAPCD 4320 - 3 10/16/084.2.1 Fuels other than California PU C quality natural gas are burned no more
than 168 cumulative hours in a calendar year plus 48 hours per calendar year for equipment testing, as limited by Permit to Operate.

4.2.2 NOx emission shall not exceed 150 ppmv or 0.215 lb/MMBtu. Demonstration of compliance with this limit shall be made by either source testing, continuous emission mon itoring system (CEMS), an APCO approved Alternate Monitoring System, or an APCO approved portable NOx analyzer.

5.0 Requirements

5.1 An operator of a unit(s) subject to this rule shall comply with all applicable requirements of the rule and one of the following, on a unit-by-unit basis:

5.1.1 Operate the unit to comp ly with the emission limits specified in Sections 5.2 and 5.4; or

5.1.2 Pay an annual emissions fee to the Dist rict as specified in Section 5.3 and comply with the control requirement s specified in Section 5.4; or

5.1.3 Comply with the applicab le Low-use Unit requirements of Section 5.5.

5.2 NOx and CO Emission Limits

5.2.1 On and after the indicated Complian ce Deadline, units shall not be operated
in a manner which exceeds the applicable NOx emi ssions limit specified in Table 1. On and after October 1, 20 08, units shall not be operated in a manner to which exceeds a carbon monoxide (CO) emissions limit of 400

ppmv.

5.2.2 No unit fired on liquid fuel sha ll be operated in a manner to exceed emissions of 40 ppmv NOx and 400 ppmv CO.

5.2.3 All ppmv emission limits specified in th is section are referenced at dry stack gas conditions and 3.00 percent by volume stack gas oxygen. Emission
concentrations shall be corrected to 3.00 percent oxygen in accordance with
Section 8.1.

SJVUAPCD 4320 - 4 10/16/08Table 1: NOx Emission Limits

Category NOx Limit Authority to
Construct Compliance
Deadline a) Standard Schedule 9 ppmv or 0.011 lb/MMBtu; or July 1, 2011 July 1, 2012 A. Units with a total rated heat input > 5.0 MMBtu/hr to < 20.0 MMBtu/hr, except for Categories C through G units b) Enhanced Schedule 6 ppmv or 0.007
lb/MMBtu January 1, 2013 January 1, 2014

a) Standard Schedule 7 ppmv or 0.008 lb/MMBtu; or July 1, 2009 July 1, 2010 B. Units with a total rated heat input > 20.0 MMBtu/hr, except for Categories C through
G units b) Enhanced Schedule 5 ppmv or 0.0062
lb/MMBtu January 1, 2013 January 1, 2014

C. Oilfield Steam Generators

a) Standard Schedule 9 ppmv or 0.011 lb/MMBtu; or July 1, 2011 July 1, 2012 1. Units with a total rated heat input > 5.0 MMBtu/hr to

< 20.0 MMBtu/hr b) Enhanced Schedule 6 ppmv or 0.007
lb/MMBtu January 1, 2013 January 1, 2014

a) Standard Schedule 7 ppmv or 0.008 lb/MMBtu; or July 1, 2009 July 1, 2010

b) Staged Enhanced
Schedule
Initial Limit 9 ppmv or 0.011 lb/MMBtu; and July 1, 2011 July 1, 2012 2. Units with a total rated heat input >20.0 MMBtu/hr

Final Limit 5 ppmv or 0.0062
lb/MMBtu January 1, 2013 January 1, 2014

Staged Enhanced
Schedule
Initial Limit 12 ppmv or 0.014 lb/MMBtu; and July 1, 2010 July 1, 2011 3. Units firing on less than 50%, by volume, PUC quality gas.

Final Limit 9 ppmv or 0.011
lb/MMBtu January 1, 2013 January 1, 2014

SJVUAPCD 4320 - 5 10/16/08Table 1 NOx Emission Limits (continued)

Category NOx Limit Authority to
Construct Compliance
Deadline

D. Refinery units

a) Standard Schedule 9 ppmv or 0.011 lb/MMBtu; or July 1, 2011 July 1, 2012 1. Units with a total rated heat input > 5.0 MMBtu/hr to <
20.0 MMBtu/hr b) Enhanced Schedule 6 ppmv or 0.007
lb/MMBtu January 1, 2013 January 1, 2014

a) Standard Schedule 6 ppmv or 0.007 lb/MMBtu; or July 1, 2010 July 1, 2011

b) Staged Enhanced
Schedule
Initial Limit 9 ppmv or 0.011 lb/MMBtu; and July 1, 2011 July 1, 2012 2. Units with a total rated heat input >20.0 MMBtu/hr to <
110.0 MMBtu/hr

Final Limit 5 ppmv or 0.0062
lb/MMBtu January 1, 2013 January 1, 2014

3. Units with a total rated heat input > 110.0 MMBtu/hr Standard Schedule 5 ppmv or 0.0062
lb/MMBtu N/A June 1, 2007

Staged Enhanced
Schedule
Initial Limit 12 ppmv or 0.014 lb/MMBtu; and July 1, 2010 July 1, 2011 4. Units firing on less than 50%, by volume, PUC quality gas.

Final Limit 9 ppmv or 0.011
lb/MMBtu January 1, 2013 January 1, 2014

E. Units, from any Category, that were installed prior to January 1, 2009 and limited by a Permit to Operate to an annual heat input >1.8 billion Btu/year but

< 30 billion Btu/year. Standard Schedule 9 ppmv or 0.011
lb/MMBtu Twelve months
before the next unit replacement but no later than January 1, 2013. At the next unit replacement but

no later than January 1, 2014

SJVUAPCD 4320 - 6 10/16/08Table 1 NOx Emission Limits (continued)

Category NOx Limit Authority to
Construct Compliance
Deadline Staged Enhanced
Schedule
Initial Limit 12 ppmv or 0.014 lb/MMBtu; and July 1, 2010 July 1, 2011 F. Units at a wastewater treatment facility firing on less than 50%, by volume, PUC quality gas. Final Limit 9 ppmv or 0.011
lb/MMBtu January 1, 2013 January 1, 2014

G. Units operated by a small producer in which the rated heat input of each burner is less than or equal to 5
MMBtu/hr but the total rated heat input of all the burners in

a unit is rated between 5
MMBtu/hr and 20 MMBtu/hr, as specified in the Permit to Operate, and in which the products of

combustion do not come in contact with the products of combustion of any other

burner. Standard Schedule 9 ppmv or 0.011
lb/MMBtu Twelve months
before the next unit replacement but no later than January 1, 2013. At the next unit replacement but

no later than January 1, 2014

5.2.4 When a unit is operated on combinati ons of gaseous fuel and liquid fuel, the NOx limit shall be the heat input weight ed average of the applicable limits specified in Sections 5.1.1, as calculated by the following equation:

LG )LxfuelliquidforlimitNOx()Gxfuelgaseousforlimit NOx( Limit Average Weighted

+ +

=

Where: G = annual heat input from gaseous fuel L = annual heat input from liquid fuel

5.2.5 Prior to January 1, 2014, if a unit was designated to comply with a Staged Enhanced Schedule, an ope rator may redesignate the unit for compliance under Section 5.1.2, provi ded the unit meets the Initial NOx Limit; emission fees are paid, at time of the application for redesignation, for all past emissions from the unit since January 1, 2009 through the calendar year prior to the calculation date; and the total annual fee is paid from that date fo rward. The past emissions fee shall

SJVUAPCD 4320 - 7 10/16/08be calculated using the equations in Section 5.3 and the Fee Rate in place
at the time of that calculation. Th e future total annual fees shall be calculated and paid according to Section 5.3.

5.3 Annual Fee Calculation

5.3.1 On and after January 1, 2010, an operator, with units that will comply under Section 5.1.2, shall pay a total a nnual fee to the District based on the
total NOx emissions from those units. That fee shall be calculated in the following manner.

5.3.1.1 The operator shall calculate the total emissions for all units operating at a stationary source that will comply with Section
5.1.2. The total NOx emissions shall be calculated in accordance
with Section 5.3.1.3.

5.3.1.2 The total annual emissions f ee shall be calculated in accordance
with Section 5.3.1.4. These cal culations include only the units
that have been identified to comply under Section 5.1.2.

5.3.1.3 Total Emissions (TE) Calculation

Total TE = ∑ E(unit)

Where: ∑ E(unit) = Sum of all NOx emi ssions from each unit, in tons

per year.

E(unit) = tonperlb UnitAFUxUnitEF

000,2 )()(

Where: E(unit) = Annual NOx emissions for each unit, in tons/year.

EF(Unit) = NOx Emission Limit for the Permit to Operate, in
lb/MMBtu

AFU(Unit) = actual amount of fuel, in MMBTU , used by each unit during the previous calendar year.

5.3.1.4 Total Annual Fee Calculation

Total Annual Fee = (Total TE x FR) + Administrative Fee

Where: FR (Fee Rate) = The cost of NOx reductions, in dollars per ton, as established pursuant to Sections 7.2 and 7.6 of District Rule 9510, as adopted on December 15, 2005. Under no ci rcumstances shall the

SJVUAPCD 4320 - 8 10/16/08cost of NOx reductions exceed the cost
effectiveness threshold fo r the Carl Moyer Cost
Effectiveness as establis hed by the applicable
state law.

Administrative Fee = 4% x (Total TE x FR)

5.3.1.5 The operator shall pay the tota l annual fee to the District, no later than July 1 of each year, for the emissions of the previous calendar year. The first payment is due to the District no later than July 1, 2010. Should July 1 fall on a day when the District is closed, the payment shall be made by the next District working day after July 1.

5.3.2 Payments shall continue annually until the unit either is permanently removed from use in the San Joaqui n Valley Air Basin and the Permit to Operate is surrendered or the opera tor demonstrates compliance with applicable NOx emissions limits shown in Table 2:

Table 2 Applicable NOx Emission Limits for Section 5.3.2

Category Date of Compliance
Demonstration Applicable NOx Emissions
Limit from Table 1

A. Units with only a Standard
Schedule in Table 1. Either prior to or after the Standard Compliance
Deadline Standard NOx Limit

Prior to the Enhanced Compliance Deadline Standard NOx Limit B. Units with both Standard and
Enhanced Schedules in Table

1. After the Enhanced Compliance Deadline Enhanced NOx Limit

Prior to the Initial Limit Compliance Deadline Standard NOx Limit

After the Initial Limit
Deadline but before the
Final Limit Deadline Initial NOx Limit then the Final NOx Limit by the applicable Compliance Deadline C. Units with both Standard and Staged Enhanced
Schedules in Table 1.

After the Final Limit
Deadline Final NOx Limit

5.3.2.1 The emissions fee for units that operate for less than the full calendar year before demonstr ating compliance under Section

SJVUAPCD 4320 - 9 10/16/085.3.2, shall be based on the actua l fuel used during the portion of the calendar year prior to demo nstrating that compliance or removing the unit from operation within the San Joaquin Valley
Air Basin.

5.3.3 Operators of units for which an a nnual emissions fee is provided must also certify that the units meet federal RA CT control requirements at the time the annual fee is provided.

5.4 Particulate Matter Control Requirements

5.4.1 To limit particulate matter emissions, an operator shall co mply with one of the following requirements:

5.4.1.1 On and after the applicable NOx Compliance D eadline specified in Section 5.2 Table 1, operators shall fire units exclusively on PUC-quality natural gas, commercial propane, butane, or liquefied petroleum gas, or a combination of such gases;

5.4.1.2 On and after the applicable NOx Compliance D eadline specified in Section 5.2 Table 1, operators shall limit fuel sulfur content to no more than five (5) grains of total sulfur per one hundred (100) standard cubic feet; or

5.4.1.3 On and after the applicab le NOx Compliance Deadline specified in Section 5.2 Table 1, operato rs shall install and properly operate an emission control system that reduces SO 2 emissions by at least 95% by wei ght; or limit exhaust SO 2 to less than or equal to 9 ppmv corrected to 3.0% O2.

5.4.1.4 Notwithstanding the complian ce deadlines indicat ed in Sections 5.4.1.1 through 5.4. 1.3, refinery units, which require modification of refinery equipmen t to reduce sulfur emissions, shall be in complian ce with the applicab le requirement in Section 5.4.1 no later than July 1, 2013.

5.4.2 Liquid fuel shall be used only during PUC quality natural gas curtailment periods, provided the requi rements of Sections 4. 2 and 6.1.5 are met and the fuel contains no more than 15 ppm sulfur, as determined by the test method specified in Section 6.2.

SJVUAPCD 4320 - 10 10/16/085.5 Low-use Unit

For each unit that was installed prior to January 1, 2009 and is limited to less than or equal to 1.8 billion Btu per calendar year heat input pursuant to a District Permit to Operate, the operator sha ll comply with the requirement of Sections 5.7 and 7.3 and one of the following:

5.5.1 Tune the unit at least twice per calendar year, (from four to eight months apart) by a qualified technician in acco rdance with the procedure described in Rule 4304 (Equipment Tuning Proced ure for Boilers, Steam Generators, and Process Heaters). If the unit doe s not operate throughout a continuous six-month period within a calendar year , only one tune- up is required for that calendar year. No tune-up is re quired for any unit th at is not operated during that calendar year; this unit may be test fired to verify availability of the unit for its intended use, but once the test firing is completed the unit shall be shutdown; or

5.5.2 Operate the unit in a manner th at maintains exhaust oxygen concentrations at less than or equal to 3.00 percent by volume on a dry basis.

5.6 Start-up and Shutdown Provision

On and after the Compliance Deadline specified in Sec tion 5.0, the applicable
emission limits of Sections 5.2 Table 1 and 5.5.2 shall not apply during start-up or shutdown, provided an operator comp lies with the requirements specified
below.

5.6.1 The duration of each start-up or each shutdown shall not exceed two hours, except as provided in Section 5.6.3.

5.6.2 The emission control system shall be in operation and emissions shall be minimized insofar as technologica lly feasible during start-up or
shutdown.

5.6.3 Notwithstanding the re quirement of Section 5.6. 1, an operator may submit an application for a Perm it to Operate condition to allow more than two hours for each start-up or each shutdown provided the operator meets all of the conditions specified in Sec tions 5.6.3.1 th rough 5.6.3.3.

5.6.3.1 The maximum allowable dura tion of start-up or shutdown will be determined by the APCO. The allowable duration of start-up
shall not exceed twelve hours and the allowable duration of
shutdown shall not exceed nine hours.

SJVUAPCD 4320 - 11 10/16/085.6.3.2 The APCO will only appr ove start-up or shutdown duration longer than two hours when the application meets the following

conditions:

5.6.3.2.1 Clearly identif ies the control technologies or strategies to be utilized; and

5.6.3.2.2 Describes what physical conditions prevail during start-up or shutdown peri ods that prevent the controls from being effective; and

5.6.3.2.3 Provides a reasona bly precise estimate as to when the physical conditions w ill have reached a state
that allows for the effective control of emissions.

5.6.3.3 The operator shall submit to the APCO any information deemed necessary by the APCO to determ ine the appropriate length of start-up or shutdown. The inform ation shall include, but is not limited to the following:

5.6.3.3.1 A detailed list of activities to be performed during start-up or shut down and a reasonable explanation for the lengt h of time needed to complete each activity; and

5.6.3.3.2 A description of the material process flow rates and system operating pa rameters, etc., the operator plans to evalua te during the process optimization; and an e xplanation of how the activities and process flow affect the operation of the emissions control equipment; and

5.6.3.3.3 The basis fo r the requested add itional duration of start-up or shutdown.

5.6.4 Permit to Operate (PTO) modifica tions solely to c onditions to comply with the provisions of this rule ma y be exempt from Best Available Control Technology (BACT) and emission offset requirements if the PTO modifications meet the requirements of Rule 2201 (New and Modified Stationary Source Review Rule) S ection 4.2 (BACT Exemptions) and Rule 2201 Section 4.6 (Emission Offset Exemptions).

5.6.5 For existing facilities, a repl acement unit installed for the sole purpose of complying with the requirements of this rule shall be considered to be an emission control technique a nd may be exempt from the Best Available Control Technology (BAC T) and Offsets requirements of

SJVUAPCD 4320 - 12 10/16/08District Rule 2201 (New and Modified Stationary Source Review Rule) provided that all other require ments of Rule 2201 are met.

5.7 Monitoring Provisions

5.7.1 The operator of any unit subject to the applicable emission limits in Sections
5.2 shall install and maintain an operational APCO approved Continuous Emissions Monitoring System (CEM S) for NOx, CO, and oxygen, or implement an APCO-approved Alternat e Monitoring System. An APCO approved CEMS shall comply with the requirements of 40 Code of Federal Regulations (CFR) Part 51, 40 CFR Parts 60.7 and 60.13 (except subsection h), 40 CFR Part 60 Appe ndix B (Performance Specifications) and 40 CFR Part 60 Appendix F (Q uality Assurance Procedures), and applicable provisions of Rule 1080 (Stack Monitoring). An APCOapproved Alternate Monitoring System shall monitor one or more of the following:

5.7.1.1 Periodic NOx and CO exhaust emission concentrations,
5.7.1.2 Periodic exha ust oxygen concentration,
5.7.1.3 Flow rate of re ducing agent added to exhaust, 5.7.1.4 Catalyst inle t and exhaust temperature, 5.7.1.5 Catalyst inlet and exhaust oxygen concentration, 5.7.1.6 Periodic flue gas recirculation rate, or 5.7.1.7 Other operational characteristics.

5.7.2 For units subject to the requiremen ts of Sections 5. 5.1 or 5.5.2, the operator shall monitor, at least on a monthly basis, the operational characteristic(s) recommended by the ma nufacturer and approved by the
APCO.

5.7.3 The operator of any unit subject to S ection 5.5 shall install and maintain an operational non-resettable, totalizing mass or volumet ric flow meter in each
fuel line to each unit. Vo lumetric flow measurements shall be periodically compensated for temperature and pr essure. A master meter, which measures fuel to all units in a gro up of similar units, may satisfy these requirements if approved by the APCO in writing. The cumulative annual fuel usage may be verified from utility service meters, purchase or tank fill records, or other acceptable methods, as approved by the APCO.

5.7.4 Units operated at seasonal sources that are subject to the requirements of 40 CFR 60, Subpart Db (Standards of Performance for IndustrialCommercial-Institutional Steam Gene rating Units) may implement an APCO approved parametric monitoring system (PMS) in lieu of a CEMS for compliance with federal emission limits provided all of the following apply:

SJVUAPCD 4320 - 13 10/16/085.7.4.1 The boiler is fired solely on California PUC quality natural gas, and

5.7.4.2 The applicable District em ission limit for NOx is more stringent than the limit specified in 40 CFR Part 60, Subpart
Db.

5.7.5 The APCO shall not approve an a lternative monitoring system or parametric monitoring system unless it is documented that continued operation within ranges of specified emissions-related performance indicators or operational characteristics provides a reasonable assurance of compliance with applicable emi ssion limits. The operator shall source test over the proposed range of su rrogate operating parameters to demonstrate compliance with the applicable emission standards.

5.7.5.1 The predictive or parame tric monitoring system shall continuously monitor the key pa rameters which affect the

emissions and demonstrate the compliance within the established key paramete rs operating envelope.

5.7.5.2 Initial and annual real time modeling shall be performed to verify the key parame ters operational range.

5.7.6 Monitoring SOx Emissions

5.7.6.1 Operators complying with S ections 5.4.1.1 or 5.4.1.2 shall provide an annual fuel analysis to the District unless a more frequent sampling and reporti ng period is included in the Permit To Operate. Sulfur an alysis shall be performed in
accordance with the test methods in Section 6.2.

5.7.6.2 Operators complying with Section 5.4.1.3 by installing and operating a control device w ith 95% SOx reduction shall propose the key system operating parameters and frequency of the monitoring and recordi ng. The monitoring option proposed shall be submitted for approval by the APCO.

5.7.6.3 Operators complying with Section 5.4.1.3 shall perform an
annual source test unless a mo re frequent sampling and reporting period is included in the Permit To Operate. Source tests shall be performed in accord ance with the test methods in
Section 6.2.

SJVUAPCD 4320 - 14 10/16/085.8 Compliance Determination

5.8.1 The operator of any unit shall have the option of complying with either the applicable heat input, in lb/MMBtu, emission limits or the concentration, in ppmv, emission limits specified in Secti on 5.2. The emission limits selected to demonstrate compliance shall be specified in the source test proposal pursuant to Rule 1081 (Source Sampling).

5.8.2 All emissions measurements shall be made with the unit operating either at conditions representative of normal operations or conditions specified in the Permit to Operate. Unless otherwise sp ecified in the Permit to Operate, no determination of compliance shall be established within two hours after a continuous period in which fuel flow to the unit is shut off for 30 minutes or longer, or within 30 minutes after a re-ignition as define d in Section 3.0.

5.8.3 Continuous Emissions Mon itoring System (CEMS) emissions
measurements shall be av eraged over a period of 15 consecutive minutes to demonstrate compliance with the a pplicable emission limits. Any 15- consecutive-minute block average CEMS measurement exceeding the applicable emission limits shall constitute a violation.

5.8.4 For emissions monitoring pursuant to Sections 5.7.1, and 6.3.1 using a portable NOx analyzer as part of an APCO approved Alternate Emissions Monitoring System, emission readings shall be averaged over a 15 consecutive-minute period by either taking a cumulative 15-consecutiveminute sample reading or by taking at least five readings evenly spaced out over the 15-consecutive-minute period.

5.8.5 For emissions source te sting performed pursuant to Section 6.3.1 for the purpose of determining compliance w ith an applicable standard or numerical limitation of this rule, th e arithmetic averag e of three 30- consecutive-minute test runs shall apply. If two of three runs are above an applicable limit the test cannot be used to demonstrate co mpliance with an applicable limit.

6.0 Administrative Requirements

6.1 Recordkeeping

The records required by Sec tions 6.1.1 through 6.1.5 sha ll be maintained for five calendar years and shall be made availa ble to the APCO and EPA upon request.
Failure to maintain records or information contained in the records that demonstrate noncompliance with the applicable require ments of this rule shall constitute a
violation of this rule. 6.1.1 The operator of any unit operated under the exemption of Section 4.2 shall monitor and record, for each unit, the cumulative annual hours of operation

SJVUAPCD 4320 - 15 10/16/08on each fuel other than natural gas duri ng periods of natural gas curtailment and equipment testing. The NOx emi ssion concentration, expressed in ppmv or lb/MMBtu, for each unit that is operated during pe riods of natural gas curtailment shall be r ecorded. Failure to mainta in records required by
Section 6.1.1 or informa tion contained in the records that demonstrates noncompliance with the conditions fo r exemption under Section 4.2 will result in loss of exemption status. On and after the applicable compliance schedule specified in Section 5.2 Tabl e 1, any unit losing an exemption status shall be brought into full compliance with this rule as specified in
Section 7.2.

6.1.2 The operator of any unit that is subject to the require ments of Section 5.5
shall record the amount of fuel use at least on a monthly basis for each unit. On and after the applicable complian ce schedule specified in Section 7.0,
in the event that such unit exceeds the applicable annual heat input limit specified in Section 5.5, the unit shall be brought into full compliance with this rule as specified in Section 5.2 Table 1.

6.1.3 The operator of any unit s ubject to Section 5.5.1 or Section 6.3.1 shall

maintain records to veri fy that the required t une-up and the required monitoring of the operational charact eristics of the unit have been performed.

6.1.4 The operator performing start-up or shutdown of a unit shall keep records of the duration of start-up or shutdown.

6.1.5 The operator of any unit firing on liquid fuel during a PUC-quality natural gas curtailment period pur suant to Section 5.4.2 sh all record the sulfur content of the fuel, amount of fuel used, and duration of the natural gas curtailment period.

6.2 Test Methods

The following test methods shall be used unless otherwise approved by the APCO
and EPA.

6.2.1 Fuel hhv shall be certified by thir d party fuel supplier or determined by:

6.2.1.1 ASTM D 240-87 or D 2382-88 for liquid hydrocarbon fuels;

6.2.1.2 ASTM D 1826-88 or D 1945-81 in conjunction with ASTM D 3588-89 for gaseous fuels.

6.2.2 Oxides of nitrogen (ppmv) - EPA Method 7E, or ARB Method 100. 6.2.3 Carbon monoxide (ppmv) - EPA Method 10, or ARB Method 100. 6.2.4 Stack gas oxygen - EPA Met hod 3 or 3A, or ARB Method 100.

SJVUAPCD 4320 - 16 10/16/086.2.5 NOx Emission Rate (Heat Input Basis) - EPA Method 19. 6.2.6 Stack gas velocities - EPA Method 2. 6.2.7 Stack gas moisture content - EPA Method 4.

6.2.8 SOx Test Methods

6.2.8.1 Oxides of sulfur – EPA Method 6C, EPA Me thod 8, or ARB
Method 100

6.2.8.2 The SOx emission control system efficiency shall be determined using the following:

% Control Efficiency = [(C SO2, inlet

**–** C SO2, outlet ) / C SO2, inlet ] X 100
Where:

C SO2, inlet = concentration of SOx (expressed as SO 2 ) at the
inlet side of the SOx em ission control system, in
lb/dscf

C SO2, outlet = concentration of SOx (expressed as SO 2 ) at the outlet side of the SOx emission control system,
in lb/dscf

6.2.9 Determination of total sulfur as hydrogen sulfide (H 2 S) content – EPA
Method 11 or EPA Method 15, as appropriate.

6.2.10 Sulfur content of liquid fuel – Am erican Society for Testing and Materials (ASTM) D 6920-03 or ASTM D 5453-99

6.3 Compliance Testing

6.3.1 Each unit subject to the requirement s in Section 5.2 shall be source tested to determine compliance with the applicable emission limits at least once every 12 months, (no more than 30 days be fore or after th e required annual source test date).

6.3.1.1 Units that demonstrate co mpliance on two consecutive 12-month source tests may defer the follo wing 12-month source test for up to 36 months (no more than 30 da ys before or af ter the required 36-month source test date). Duri ng the 36-month source testing interval, the operator shall tune the unit in acco rdance with the provisions of Section 5.5.1, a nd shall monitor, on a monthly basis, the unit’s operational ch aracteristics recommended by the manufacturer to ensure complian ce with the applicable emission limits specified in Section 5.2.

SJVUAPCD 4320 - 17 10/16/086.3.1.2 Tune-ups re quired by Sections 5.5.1 and 6.3.1 do not need to be performed for units that operate and maintain an APCO approved CEMS or an APCO approved Alte rnate Monitoring System where the applicable emission limits are periodically monitored.

6.3.1.3 If the result of the 36-month s ource test demonstrat es that the unit does not meet the applicable emi ssion limits specified in Section 5.2, the source testing frequency sh all revert to at least once every
12 months.

6.3.1.4 Failure to comply with the requirements of Sec tion 6.3.1 or any
source test results th at exceed the applicable emission limits in
Section 5.2 shall constitute a violation of this rule.

6.3.2 In lieu of compliance with Section 6. 3.1, compliance with the applicable
emission limits in Section 5.2 shall be demonstrated by submittal of annual
emissions test results to the District from a unit or units that represents a group of units, provided:

6.3.2.1 All units in the group are initially source tested. The emissions
from all test runs from units within the group are less than 90% of the permitted value, and the emissions do not vary greater than 25% from the averag e of all test runs; and

6.3.2.2 All units in a group are si milar in terms of rated heat input, make and series, operational cond itions, fuel used, and control
method. No unit with a rated heat input greater than 100
MMBtu shall be considered as part of the group; and

6.3.2.3 The group is owned by a si ngle owner and is located at a single stationary source; and

6.3.2.4 Selection of the represen tative unit(s) is approved by the APCO prior to testing; and

6.3.2.5 The number of representative units source tested shall be at least
30% of the total number of units in the group. The representative tests shall rotate each year so that within three years all units in the group have been tested at least once.

6.3.2.6 All units in the group sh all have received the similar maintenance and tune-up procedures as the representative unit(s) as listed in the Permit to Operate. The operator shall submit to the APCO the specific maintenan ce procedures to be performed
on each unit that will be included in the group for representative testing. Such maintenance proced ures shall be sp ecified in the

SJVUAPCD 4320 - 18 10/16/08Permit to Operate for units that are included in the group for representative testing. Any ma intenance work on a unit which
has no effect on emissions standa rds and which is not specified in the maintenance procedures shall be submitted to the APCO for approval before such unit can be included as part of the group for representative testing. Any unit that necessitates any
maintenance work which has an effect on emission standards and is beyond the maintenance procedures identified in the Permit to Operate, shall not be in cluded as part of the group for representative testing. The un it shall be source tested in accordance with the provisions of Section 6.3.1; and

6.3.2.7 Should any of the repr esentative units exceed the required emission limits, each of the units in the group shall demonstrate compliance by emissions testing. Failure to complete emissions testing within 90 days of the failed test shall result in the untested units being in violation of this rule. After compliance with the requirements of Section 6.3.2.7 has been demonstrated, subsequent source testing sha ll be performed pursuant to Sections 6.3.1 or 6.3.2.

6.4 Emission Control Plan (ECP)

6.4.1 No later than January 1, 2010, th e operator of any unit shall submit to the APCO for approval an Emissions Cont rol Plan according to the compliance schedule in Section 7.0. For each unit, the plan shall contain the following:

6.4.1.1 Permit to Operate number, 6.4.1.2 Fuel type and hhv,
6.4.1.3 Annual fuel cons umption (expressed as Btu/yr),

6.4.1.4 Current emission level, incl uding method used to determine emission level,

6.4.1.5 NOx limit to be satisfied pursuant to Section 5.2 Table 1 or emission fee payment to be made pursuant to Section 5.3, and 6.4.1.6 Plan of actions, including a schedule of increments of progress, which will be taken to satisfy th e requirements of Section 5.0 and the compliance schedule in Section 7.0.

SJVUAPCD 4320 - 19 10/16/087.0 Compliance Schedule

7.1 As shown in Section 5.2 Ta ble 1, the column labeled:

7.1.1 “Authority to Construct” identifies the date by with the operator shall submit an Application for Authority to Constr uct for each unit subject to the rule.

7.1.2 “Compliance Deadline” identifie s the date by whic h the owner shall demonstrate that each unit is in complia nce with the applicable requirements
of this rule.

7.2 Any unit that is exempted under Secti on 4.2 that becomes subject to the emission limits of this rule through th e loss of exemption status shall be in full compliance
with this rule on and after the da te the exemption status is lost.

7.3 Any unit that becomes subject to the em ission limits of this rule as a result of exceeding the applicable annual heat input lim it specified in Section 5.5 shall be in compliance with the applicab le emission limits in Sectio n 5.2 Table 1 and Section 5.4 on and after the date the annual heat input limit is exceeded.

8.0 Calculations

8.1 All ppmv emission limits specified in S ection 5.2 are referenced at dry stack gas conditions and 3.00 percent by volume stack gas oxygen. Emissi on concentrations shall be corrected to 3.00 percent oxygen as follows:

measured measured corrected ]NOxppm[x ]2O[%%95.20 %95.17 ]NOxppm[

− =

measured

measured corrected ]COppm[x ]2O[%%95.20 %95.17 ]COppm[

− =

8.2 All pounds per million Btu NOx emission rates shall be calculated as pounds of nitrogen dioxide per million Btu of heat input (expressed as hhv).

SJVUAPCD 4320 - 20 10/16/08