RULE 4306 BOILERS, STEAM GENERATORS, AND PROCESS HEATERS – PHASE 3 (Adopted September 18, 2003; Amended March 17, 2005 ; Amended October 16, 2008)

1.0 Purpose

The purpose of this rule is to limit emissions of oxides of nitrogen (NOx) and carbon monoxide (CO) 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 Annual Capacity Factor: the ratio of the amount of fu el 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.

3.2 Annual Heat Input: the actual, total heat 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.

3.3 Boiler or Steam Generator: any extern al combustion equipment, except oilfield steam generators, fired with any fuel used to produce hot water or steam.

3.4 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.

3.5 Dryer: any unit in which material is dried in direct contact with the products of
combustion.

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

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

3.8 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.

3.9 Higher Heating Value (hhv): the total h eat liberated per mass of fuel burned (Btu per pound), when fuel and dry air at st andard conditions undergo complete combustion and all resulting products are brought to their standard states at
standard conditions.

SJVUAPCD 4306

- 1 10/16/083.10 Liquid Fuel: any fuel which is a liquid at standard conditions.

3.11 Load-following Unit: for the purposes of this rule, a load-follo wing unit is defined as a unit with normal operational load fluc tuations and requirements which exceed the operational response range of an Ultra-Low NOx burner system(s) operating at 9 ppmv NOx. The operator sh all designated load-following units on the Permit to Operate.

3.12 NOx Emissions: the sum of ox ides of nitrogen expressed as NO 2 in the flue gas.

3.13 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.

3.14 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.

3.15 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, c ooking, calcining, or vitrifying; and unfired waste heat recovery heaters used to r ecover sensible heat from the exhaust of combustion equipment.

3.16 Public Utilities Commission (PUC) Quality Natural Gas: any gaseous fuel, gascontaining 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 (5) grains of total sulfur per one hundred (100) standard cubic feet. PUC quality natural gas also means high methane ga s (at least 80% methane by volume) as specified in PUC General order 58-A.

3.17 PUC Quality Natural Gas Curtailment: means a shortage in the supply of Public Utility Commission (PUC) quality natural gas, due solely to supply limitations or
restrictions in distribution pipelines by the utility supplying the gas, and not due to the cost of natural gas.

3.18 Qualified Technician: a stationary s ource employee or any personnel 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.

3.19 Rated Heat Input (million Btu per hour): the heat input capac ity specified on the nameplate of the unit. If the unit has b een physically modified such that its

SJVUAPCD 4306

- 2 10/16/08maximum heat input differs from what is specified on the nameplate, the modified maximum heat input shall be considered as the rated heat input and made enforceable by Permit to Operate.

3.20 Refinery Unit: a unit that is permanen tly installed and oper ated at a petroleum refinery or a gas liquids processing facility.

3.21 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.

3.22 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.

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

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

3.25 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.

3.26 Unit: any boiler, steam gene rator, oilfield 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 S ections 5.1.1 and 5.1.2 sha ll not apply to a unit when burning any fuel other than PUC quality na tural gas during PUC quality natural gas curtailment provided all of the following conditions are met:

SJVUAPCD 4306

- 3 10/16/084.2.1 Fuels other than PUC quality na tural 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

All ppmv emission limits specified in this secti on are referenced at dr y 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.

5.1 NOx and CO Emission Limits

5.1.1 Except for units subject to Sec tions 5.2, NOx and carbon monoxide (CO) emissions shall not exceed the limits sp ecified in Table 1 on and after the dates specified in Tables 2 and 3.

Table 1 NOx and CO Limits Operated on Gaseous Fuel Operated on Liquid Fuel
NOx Limit Category

Standard Option Enhanced Option CO Limit (ppmv) NOx Limit CO Limit (ppmv)

A. Units with a rated heat input equal to or less than 20.0 MMBtu/hour, except for Categories C, D, E, F, G, H, and I units 15 ppmv or 0.018 lb/MMBtu 9 ppmv or 0.011 lb/MMBtu 400 40 ppmv or
0.052 lb/MMBtu 400

B. Units with a rated heat input greater than 20.0 MMBtu/hour, except for Categories C, D, E, F, G, H, and I units 9 ppmv or 0.011 lb/MMBtu 6 ppmv or 0.007 lb/MMBtu 400 40 ppmv or
0.052 lb/MMBtu 400

C. Oilfield Steam Generators 15 ppmv or 0.018 lb/MMBtu No option 400 40 ppmv or
0.052 lb/MMBtu 400

SJVUAPCD 4306

- 4 10/16/08Table 1 NOx and CO Limits (continued) Operated on Gaseous Fuel Operated on Liquid Fuel
NOx Limit Category

Standard Option Enhanced Option CO Limit (ppmv) NOx Limit CO Limit (ppmv)

D. Refinery units with a rated heat input greater than 5 MMBtu/hr up to 65 MMBtu/hr 30 ppmv or 0.036 lb/MMBtu No option 400 40 ppmv or
0.052 lb/MMBtu 400

E. Refinery units with a rated heat input greater than 65 MMBtu/hr up to 110 MMBtu/hr 25 ppmv or 0.031 lb/MMBtu No option 400 40 ppmv or
0.052 lb/MMBtu 400

F. Refinery units with a rated heat input greater than 110 MMBtu/hr 5 ppmv or
0.0062 lb/MMBtu No option 400 40 ppmv or
0.052 lb/MMBtu 400

G. Load-following units 15 ppmv or 0.018 lb/MMBtu 9 ppmv or
0.011 lb/MMbtu 400 40 ppmv or
0.052 lb/MMBtu 400

H. Units limited by a Permit to Operate to an annual heat input of 9 billion Btu/year to 30 billion Btu/year 30 ppmv or 0.036 lb/MMBtu No option 400 40 ppmv or
0.052 lb/MMBtu 400

I. Units 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 greater than 5 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. 30 ppmv or 0.036 lb/MMBtu No option 400 40 ppmv or
0.052 lb/MMBtu 400

5.1.2 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:

SJVUAPCD 4306

- 5 10/16/08LG )LxfuelliquidforlimitNOx()Gxfuelgaseousforlimit NOx( Limit Average Weighted
+ +

=

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

5.2 For each unit that is limited to less than 9 billion Btu per calendar year heat input pursuant to a Permit to Operate, the operator shall co mply with the requirement of Section 7.4 and one of the following:

5.2.1 tune the unit at least twice per calendar year, (from fo ur 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

5.2.2 operate the unit in a manner that maintains exhaust oxygen concentrations at less than or equal to 3.00 percent by volume on a dry basis; or

5.2.3 operate the unit in compliance w ith the applicable emission limits of
Sections 5.1.1 or 5.1.2.

5.3 On and after the full compliance schedule specified in Section 7.1, the applicable emission limits of Sections 5.1, 5.2.2 and 5.2.3 shall not apply during start-up or shutdown provided an operator comp lies with the requirements specified below.

5.3.1 The duration of each start-up or each shutdown shall not exceed two hours, except as provided in Section 5.3.3.

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

5.3.3 Notwithstanding the requiremen t of Section 5.3.1, an operator may submit an application for a Permit to Operate condition to allow more than two hours for each start-up or each shutdown provided the operator meets all of the conditions in speci fied in Sections 5.3.3.1 through
5.3.3.3.

SJVUAPCD 4306

- 6 10/16/085.3.3.1 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 an d the allowable duration of shutdown shall not exceed nine hours.

5.3.3.2 The APCO will only appr ove start-up or shutdown duration longer than two hours when the application meets the following
conditions:

5.3.3.2.1 clearly identif ies the control technologies or strategies to be utilized; and

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

5.3.3.2.3 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.

5.3.3.3 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:

5.3.3.3.1 a detailed list of activities to be performed during start-up or shutdown and a reasonable explanation for the length of time n eeded to complete each activity; and

5.3.3.3.2 a description of the material process flow rates and system operating paramete rs, etc., the operator plans to evaluate during the process optimization; and an explanation of how the activities and process flow affect the operation of the emissions control equipment; and

5.3.3.3.3 basis for the requested additional duration of startup or shutdown.

5.3.4 Permit to Operate (PTO) modifica tions solely to include start-up or shutdown conditions may be exempt from Best Available Control Technology (BACT) and emission offs et requirements if the PTO modifications meet the requirement s of Rule 2201 (New or Modified

SJVUAPCD 4306

- 7 10/16/08Stationary Source Review Rule) S ection 4.2 (BACT Exemptions) and Rule 2201 Section 4.6 (Offset Exemptions).

5.4 Monitoring Provisions

5.4.1 The operator of any unit which simultaneously fires gaseous and liquid fuels, and is subject to the requiremen ts of Section 5.1, shall install and maintain an operational non-resettable, totalizing mass or volumetric flow meter in each fuel line to each unit. Volumetric flow measurements shall be periodically compensated for temperature and pressure.

5.4.2 The operator of any unit subject to the ap plicable emission limits in Sections 5.1 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 Appe ndix F (Quality Assurance Procedures, and applicable provisions of Rule 1080 (Stack Monitoring). An APCO approved Alternate Monitoring System shall monitor one or more of the following:

5.4.2.1 periodic NOx and CO exhaust emission concentrations, 5.4.2.2 periodic exha ust oxygen concentration, 5.4.2.3 flow rate of re ducing agent added to exhaust, 5.4.2.4 catalyst inlet and exhaust temperature, 5.4.2.5 catalyst inlet and exhaust oxygen concentration, 5.4.2.6 periodic flue gas recirculation rate, 5.4.2.7 other opera tional characteristics.

5.4.3 For units subject to the requirement s of Section 5.2.1 or 5.2.2, the operator shall monitor, at least on a monthly basis, the operational characteristics recommended by the manufacturer and approved by the APCO.

5.4.4 The operator of any Category H unit liste d in Section 5.1. 1 Table 1 and any unit subject to Section 5.2.1 or 5. 2.2 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.

SJVUAPCD 4306

- 8 10/16/085.4.5 The APCO shall not approve an alternative monitoring system unless it is documented that continued operati on within ranges of specified emissions-related performance indi cators or operational characteristics provides a reasonable assurance of complia nce with applicable emission limits. The operator shall source test over the proposed range of surrogate operating para meters to demonstrat e compliance with the applicable emission standards.

5.5 Compliance Determination

5.5.1 The operator of any unit shall have the option of complying with either the applicable heat input (lb/MMBtu) em ission limits or the concentration (ppmv) emission limits specified in Section 5.1. The emission limits selected to demonstrate compliance sh all be specified in the source test proposal pursuant to Rule 1081 (Source Sampling).

5.5.2 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 Perm it 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.

5.5.3 All Continuous Emissions M onitoring System (CEMS) emissions measurements shall be av eraged over a period of 15 consecutive minutes to demonstrate compliance with the applicable emission limits of this rule. Any 15-consecutive-minute block aver age CEMS measurement exceeding the applicable emission limits of this ru le shall constitute a violation of this rule.

5.5.4 For emissions monitoring pursuant to Sections 5.4.2, 5.4.2.1, 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 e ither taking a cumulative 15- consecutive-minute sample reading or by taking at least five (5) readings evenly spaced out over the 15-consecutive-minute period.

5.5.5 For emissions source testi ng performed pursuant to Section 6.3.1 for the purpose of determining compliance w ith an applicable standard or numerical limitation of this rule, the arithmetic average of three (3) 30- consecutive-minute test runs shall apply. If two (2) of th ree (3) runs are above an applicable limit the test canno t be used to demonstrate compliance with an applicable limit.

SJVUAPCD 4306

- 9 10/16/086.0 Administrative Requirements

6.1 Recordkeeping

The records required by Sections 6.1.1 through 6.1. 4 shall be maintained for five calendar years and shall be made availabl e to the APCO upon re quest. 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 cumu lative annual hours of operation on each fuel other than natural gas duri ng periods of natural gas curtailment and equipment testing. The NOx emission concentration (in ppmv or lb/MMBtu) for each unit that is opera ted during periods of natural gas curtailment shall be recorded. Failu re to maintain 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 Secti on 7.0, any unit losing an exemption status shall be brought into full compliance with this rule as specified in Section 7.3.

6.1.2 The operator of a ny Category H unit listed in S ection 5.1.1 Ta ble 1 and any unit that is subject to the requireme nts of Section 5.2 shall record the amount of fuel use at least on a mont hly basis for each unit, or for a group of units as specified in Section 5.4.4. On and after the applicable compliance schedule specified in Secti on 7.0, in the even t that such unit exceeds the applicable annua l heat input limit specified in Sections 5.1.1 Table 1 Category H and S ection 5.2, the unit shall be brought into full compliance with this rule as specified in Section 7.4.

6.1.3 The operator of any un it subject to Section 5.2. 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.

SJVUAPCD 4306

- 10 10/16/086.2 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. 6.2.5 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.

6.3 Compliance Testing

6.3.1 Each unit subject to the requirements in Secti ons 5.1 or 5.2.3 shall be source tested to determine compliance w ith the applicable emission limits at least once every 12 months, (no more th an 30 days before or after the required annual source test date). Units that demonstrate compliance on two consecutive 12-month source test s may defer the following 12-month source test for up to 36 months (no more than 30 days before or after the required 36-month source test date). During the 36-month source testing interval, the operator shall tune the unit in accordance with the provisions of Section 5.2.1, and shall monito r, on a monthly basis, the unit’s operational characteristics recommended by the manufacturer to ensure compliance with the appli cable emission limits specified in Sections 5.1 or 5.2.3. Tune-ups required by Sections 5.2.1 a nd 6.3.1 do not need to be performed for units that operate and maintain an APCO approved CEMS or an APCO approved Alternate Monitori ng System where the applicable emission limits are periodically monito red. If the result of the 36-month source test demonstrates that the unit does not meet the applicable emission limits specified in Sections 5.1 or 5. 2.3, the source testing frequency shall revert to at least once every 12 mont hs. Failure to comply with the requirements Section 6.3. 1, or any source test results that exceed the applicable emission limits in Sectio ns 5.1 or 5.2.3 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 Sections 5.1 or 5. 2.3 shall be demonstrated by submittal of annual emissions test results to th e District from a unit or units that represents a group of units, provided:

SJVUAPCD 4306

- 11 10/16/086.3.2.1 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 Permit 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 included 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,

SJVUAPCD 4306

- 12 10/16/08subsequent 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 The operator of any unit sha ll submit to the APCO for approval an Emissions Control 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 consumption (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, either St andard Option or Enhanced Option, 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.

6.4.2 The operator shall submit to the APCO for approval, as part of the ECP, a list of units which are to be designa ted as load-following units. The APCO shall only designate, as load-followi ng, units for which the following information has been provided to demons trate that the units qualify as loadfollowing:

6.4.2.1 Technical data such as steam demand charts or other information to demonstrate the normal opera tional load fluctuations and requirements of the unit,
6.4.2.2 Technical data about the operationa l response range of an Ultra- Low NOx burner system(s) operating at 9 ppmv NOx, and
6.4.2.3 Technical data demonstrating that the unit(s) are designed and operated to optimize the use of base-loaded units in conjunction with the load-following unit(s).

7.0 Compliance Schedule

7.1 An operator with multiple units at a stati onary source shall comply with this rule in accordance with the schedule sp ecified in Table 2. A stationary source with only one unit shall comply with the schedule sp ecified in Table 2 Group 1 for standard option or Table 3 Group 1 for enhanced option.

SJVUAPCD 4306

- 13 10/16/08TABLE 2 – Standard Option Compliance Schedule

Units to be in Compliance at a Stationary Source Emission Control Plan Authority to
Construct Full Compliance

Group 1: 25% or more of the total number of units subject to this rule on June 1, 2005, excluding Group 4 June 1, 2004 June 1, 2004 June 1, 2005

Group 2: 62.5% or more of the total number of units subject to this rule on June 1, 2006, excluding Group 4 June 1, 2004 January 2, 2005 June 1, 2006

Group 3: 100% of the total number of units subject to this rule on June 1, 2007 June 1, 2004 January 2, 2006 June 1, 2007

Group 4: A. Load-following units B. Units limited by Permit to Operate to an annual capacity factor of 10% or less as of June 1, 2005 C. Category I units at any stationary source that has no more than two units subject to this rule. June 1, 2004 January 2, 2006 June 1, 2007

Units are considered to be subject to this rule if the rule is a pplicable to the units pursuant to Section 2.0 and the units are not ex empt pursuant to Section 4.1.

TABLE 3 – Enhanced Option Compliance Schedule Units to be in Compliance at a Stationary Source Emission Control Plan Authority to
Construct Full Compliance

Group 1: 25% or more of the total number of units subject to this rule on June 1, 2005, excluding Group 4 December 1, 2005 December 1, 2005 December 1, 2006

Group 2: 62.5% or more of the total number of units subject to this rule on June 1, 2006, excluding Group 4 December 1, 2005 July 1, 2006 December 1, 2007

Group 3: 100% of the total number of units subject to this rule on June 1, 2007 December 1, 2005 July 1, 2007 December 1, 2008

SJVUAPCD 4306

- 14 10/16/08TABLE 3 – Enhanced Option Compliance Schedule (Continued) Units to be in Compliance at a Stationary Source Emission Control Plan Authority to
Construct Full Compliance

Group 4: A. Load-following units December 1, 2005 July 1, 2007 December 1,
2008

Units are considered to be subject to this rule if the rule is applicable to the units pursuant to Section 2.0 and the units are not ex empt pursuant to Section 4.1.

7.2 As shown in Table 2 and Table 3, the column labeled:

7.2.1 "Emission Control Plan" identifie s the date by which the operator shall submit an Emission Control Plan pursu ant to Section 6.4. The Emission Control Plan shall identif y all units subject to this rule. The Emission Control Plan shall identify steps to be taken to comply with this rule.

7.2.2 “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.

7.2.3 "Full Compliance" identifies the date by which the owne r shall demonstrate that each unit is in comp liance with this rule.

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

7.4 Any unit that becomes subject to the em ission limits of this rule as a result of exceeding the applicable annual heat input limit specified in either Section 5.1.1 Table 1 Category H or Section 5.2, shall be in compliance w ith the applicable standard option emission limits for Category A and B units in S ection 5.1.1 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 5.1 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[

− =

SJVUAPCD 4306

- 15 10/16/088.2 All pounds per million Btu NOx emission rates shall be calculated as pounds of nitrogen dioxide per million Btu of heat input (hhv).

9.0 Alternative Emission Control

9.1 General

The single owner of two or more units may comply with Section 5.1 by controlling units in operation at the same stationary source, or at two contiguous stationary sources, to achieve an aggregated NOx emi ssion factor no higher than 90 percent of the aggregated NOx emission factor limit th at would result if each unit in operation were individually in compliance with the a pplicable NOx emission limits in Section 5.1. An operator that is subject to the AECP requirements belo w shall also comply with the applicable requirements of S ections 5.0, 6.0, 7.0 and 8.0.

9.2 Eligibility

A unit not subject to Section 5.1 or Secti on 5.2.3 is not eligible for inclusion in an
AECP.

9.3 Exclusion

No unit subject to Sections 5.2.1 or 5.2.2 shall be included in an AECP.

9.4 AECP Definitions

For the purposes of Section 9.0, the following definitions shall apply:

9.4.1 Aggregated NOx emission factor lim it: the sum of the NOx emissions, over seven consecutive calendar days, that w ould result if all units in the AECP were in compliance with the lb/MMBtu limits in S ection 5.1 and operating at their actual firing rates, divided by the su m of the heat input of all units in the AECP over seven consecutive cale ndar days. Aggregated emission factor limit is calculated as:

F FL

= L

i ii A Σ Σ

where: L A

is the aggregated NOx emission factor limit (lb/MMBtu)

L i is the applicable NOx emission factor limit (lb/MMBtu) specified in Section 5.1.1 Table 1 or Sec tion 5.1.2 for each category of unit in the AECP,

SJVUAPCD 4306

- 16 10/16/08F i is the total heat input (hhv basi s) of fuel (MMBtu) combusted in each unit during seven consecutive calendar days, and

i identifies each unit in the AECP.

9.4.2 Aggregated NOx emission factor: th e sum of the actual NOx emissions during seven consecutive calen dar days from all units in the AECP, divided by the sum of the heat input of a ll units in the AECP during seven consecutive calendar days. The aggregat ed emission factor is calculated as:

F FE

= E

i ii A Σ Σ

where: E A

is the aggregated NOx emission factor (lb/MMBtu),

E i is the NOx emission factor (lb/MMBtu) for each unit in the AECP, established and verified by source te sting, or continuous emission monitors,

F i is the total heat input (hhv basi s) of fuel (MMBtu) combusted in each unit during seven consecutive calendar days, and

i identifies each unit in the AECP.

9.5 AECP Requirements

9.5.1 The aggregated NOx emission factor (E A ) shall not exceed 90 percent of the aggreg ated emission limit (L A ). The owner of any unit in an AECP shall notify th e APCO within 24 hours of any violation of this section.

E

A

must be< 0.90 x L A

9.5.2 Only units in the AECP which were operated during seven consecutive calendar days shall be included in the calculations of the aggregated NOx emission factor (L A ) and the aggregated NOx emission limit (E A ).

9.5.3 During each seve n consecutive calendar days of operation that the AECP is used, the operator sh all calculate and record the aggregated NOx emission factor (L A ) and the aggregate NOx emission limit (E A ).

SJVUAPCD 4306

- 17 10/16/089.5.4 The operator shall submit a NOx emission factor for each unit that is included in the AECP. The es tablished NOx emission factor of the unit shall be no less than the em ission factor of the unit from the
most recent source test conducte d pursuant to Section 6.3 and approved by the APCO. The opera tor shall not operate any AECP unit in such a manner that the NO x emissions exceed the established NOx emission factor of the unit.

9.5.5 The operator shall submit th e AECP, for approval by the APCO, by June 1, 2004 or at least 24 mont hs before compliance with the applicable emission limits in Sectio n 5.1 is required pursuant to the Section 7.1, whichever is later. The AECP shall be submitted with an application for an Authority to Construct pursuant to complying with Section 7.1 as applicable. The operator shall obtain a written approval of the AECP from the APCO prior to implementation.

9.6 AECP Administrative Requirements

9.6.1 The AECP shall:

9.6.1.1 Contain all data, records, and other information necessary to determine eligibility of the units for alternative emission control, including but not limited to:

9.6.1.1.1 A list of units subj ect to alternative emission control, 9.6.1.1.2 Daily average a nd maximum hours of utilization for each unit, 9.6.1.1.3 Rated heat input of each unit, and 9.6.1.1.4 Fuel type for each unit.

9.6.1.2 Present the methodology for recordkeeping and reporting required by Sections 9.6.4 and 9.6.5.

9.6.1.3 Specify which NOx limit, either Standard Option or Enhanced Option, will be satisfied by the units under the AECP.

9.6.1.4 Demonstrate that the aggregated emission factor will meet the requirements of Section 9.5.

9.6.1.5 Demonstrate that th e schedule for achieving AECP NOx emission levels is at least as expeditious as the schedule if applicable units were to comply individually with the applicable emission levels in Section 5.1 a nd the increments of progress in
Section 7.0.

SJVUAPCD 4306

- 18 10/16/089.6.2 Revision of AECP

Owners shall demonstrate APCO a pproval of the AECP prior to applying
for a modification to said AECP.

9.6.3 AECP Recordkeeping

In addition to the records kept pur suant to Section 6.1, the operator shall maintain records, on a daily basis, of the parameters needed to demonstrate compliance with the app licable NOx emission limits when operating under the AECP. The reco rds shall be retained for at least five years and shall be made available to the APCO upon request . The records shall include, but are not limited to, the following:

9.6.3.1 For each unit included in the AECP the owner shall maintain the following records for each day:

9.6.3.1.1 fuel type and amount used for each unit (F i ), 9.6.3.1.2 the actual emission factor for each unit (E i ), 9.6.3.1.3 the total emissions for all units ( Σ E i F i ), 9.6.3.1.4 the aggregated emission factor (E A ), 9.6.3.1.5 the aggregated emission factor limit (L A ), and
9.6.3.1.6 any other parameters needed to demonstrate daily compliance with the appli cable NOx emissions when operating the units under the AECP.

9.6.4 Reporting and Annual Updates

Notifications of a ny violation pursuant to Section 9.5 shall include:
9.6.4.1 name a nd location of facility, 9.6.4.2 list of applicable units, 9.6.4.3 cause and exp ected duration of exceedance, 9.6.4.4 the amount of excess emissions, and 9.6.4.5 proposed correc tive actions and schedule.

9.7 Compliance Schedule

The AECP schedule for achieving reduced NO x emission levels shall be at least as expeditious as the schedule if applicable un its were to comply individually with the emissions limits specified in Sections 5.1. 1 and 5.1.2 and the a pplicable compliance schedule required by Section 7.0.

SJVUAPCD 4306

- 19 10/16/08This page intentionally blank

SJVUAPCD 4306

- 20 10/16/08