SJVUAPCD 4306 - 1 10/16/08

RULE 4306 BOILERS, STEAM GENERATORS, AND PROCESS HE ATERS – 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 p rocess heaters.

2.0 Applicability

This rule applies to any gaseous fuel or liquid fu el fired boiler, 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 amoun t of fuel burned by the unit in a calendar year to the amount of fuel that the unit c ould have burned if it had operated at its maximum rated capacity for 8,760 hours durin g the calendar year.

3.2 Annual Heat Input: the actual, total heat inpu t of fuels burned by a unit in a calendar year, as determined from the higher heatin g value and cumulative annual usage of each fuel.

3.3 Boiler or Steam Generator: any external combus tion equipment, except oilfield steam generators, fired with any fuel used to produ ce 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 atmosph ere.

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 stand ard conditions.

3.7 Gas Liquids Processing Facility: a facility th at is engaged in the catalytic processing of gas liquids to produce finished products.

3.8 Heat Input: the heat (hhv basis) released 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 heat lib erated per mass of fuel burned (Btu per pound), when fuel and dry air at standard condi tions undergo complete combustion and all resulting products are brought t o their standard states at standard

conditions.SJVUAPCD 4306 - 2 10/16/08

3.10 Liquid Fuel: any fuel which is a liquid at st andard conditions.

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

3.12 NOx Emissions: the sum of oxides of nitrogen expressed as NO

2 in the flue gas.

3.13 Oilfield Steam Generator: an external combust ion equipment which converts water to dry steam or to a mixture of water vapor and ste am, with an absolute pressure of more than 30 psia, and which is used exclusively in thermally 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 o f millions of total gas molecules.

3.15 Process Heater: any combustion equipment fire d with liquid and/or gaseous fuel and which transfers heat from combustion gases to w ater or process streams. This definition excludes: kilns or ovens used for drying , baking, cooking, calcining, or vitrifying; and unfired waste heat recovery heaters used to recover sensible heat from the exhaust of combustion equipment.

3.16 Public Utilities Commission (PUC) Quality Natu ral Gas: any gaseous fuel, gascontaining fuel where the sulfur content is no more than one-fourth (0.25) grain of hydrogen sulfide per one hundred (100) standard cub ic feet and no more than five (5) grains of total sulfur per one hundred (100) st andard cubic feet. PUC quality natural gas also means high methane gas (at least 8 0% 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 s olely to supply limitations or restrictions in distribution pipelines by the utili ty supplying the gas, and not due to the cost of natural gas.

3.18 Qualified Technician: a stationary source emp loyee or any personnel contracted by a stationary source operator who has a documented t raining and a demonstrated experience performing tune-ups on a unit to the sat isfaction of the APCO. The documentation of tune-up training and experience sh all be made available to the APCO upon request.

3.19 Rated Heat Input (million Btu per hour): the heat input capacity specified on the nameplate of the unit. If the unit has been physic ally modified such that its maximum heat input differs from what is specified o n the nameplate, the modifiedSJVUAPCD 4306 - 3 10/16/08 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 permanently ins talled and operated at a petroleum refinery or a gas liquids processing facility.

3.21 Re-ignition: the relighting of a unit after a n unscheduled and unavoidable interruption or shut off of the fuel flow or electr ical power, for a period of less than 30 minutes, due to reasons outside the control of the operator.

3.22 Shutdown: the period of time during which a u nit is taken from an operational to a non-operational status by allowing it to cool dow n from its operating temperature to ambient temperature as the fuel supp ly to the unit is completely

turned off.

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

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

3.25 Start-up: the period of time during which a u nit is brought from a shutdown status to its operating temperature and pressure, includin g the time required by the unit’s emission control system to reach full operation.

3.26 Unit: any boiler, steam generator, oilfield s team 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 products of co mbustion come into direct

contact with the material to be heated.

4.1.4 Unfired or fired waste heat recovery boiler s that are used to recover or

augment heat from the exhaust of combustion turbine s or internal combustion engines.

4.2 The requirements of Sections 5.1.1 and 5.1.2 s hall not apply to a unit when burning

any fuel other than PUC quality natural gas during PUC quality natural gas curtailment provided all of the following condition s are met:SJVUAPCD 4306 - 4 10/16/08

4.2.1 Fuels other than PUC quality natural gas ar e burned no more than 168

cumulative hours in a calendar year plus 48 hours p er calendar year for equipment testing, as limited by Permit to Operate.

4.2.2 NOx emission shall not exceed 150 ppmv or 0.2 15 lb/MMBtu. Demonstration of compliance with this limit shall b e made by either source testing, continuous emission monitoring system (CEM S), an APCO approved Alternate Monitoring System, or an APCO ap proved portable NOx analyzer.

5.0 Requirements

All ppmv emission limits specified in this section are referenced at dry stack gas conditions and 3.00 percent by volume stack gas oxygen. Emiss ion 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 Sections 5.2, NO x and carbon monoxide (CO)

emissions shall not exceed the limits specified 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

Table 1 NOx and CO Limits (continued)SJVUAPCD 4306 - 5 10/16/08 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 combinations of ga seous fuel and liquid fuel, the NOx limit shall be the heat input weighted average of the applicable limits specified in Sections 5.1.1, as calculated by the f ollowing equation:

L G )L x fuel liquid for limit NOx ( ) G x fuel gaseous for limit NOx ( Limit Average Weighted

+ +

=SJVUAPCD 4306 - 6 10/16/08

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 b illion Btu per calendar year heat input

pursuant to a Permit to Operate, the operator shall comply with the requirement of Section 7.4 and one of the following:

5.2.1 tune the unit at least twice per calendar y ear, (from four to eight months

apart) by a qualified technician in accordance with the procedure described in Rule 4304 (Equipment Tuning Procedure for Boiler s, Steam Generators, and Process Heaters). If the unit does not operate throughout a continuous six-month period within a calendar year, only one t une-up is required for that calendar year. No tune-up is required for any unit that is not operated during that calendar year; this unit may be test fi red to verify availability of the unit for its intended use, but once the test fi ring 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 d ry basis; or

5.2.3 operate the unit in compliance with the app licable emission limits of

Sections 5.1.1 or 5.1.2.

5.3 On and after the full compliance schedule speci fied in Section 7.1, the applicable emission limits of Sections 5.1, 5.2.2 and 5.2.3 sh all not apply during start-up or shutdown provided an operator complies with the req uirements specified below.

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

5.3.2 The emission control system shall be in opera tion and emissions shall be minimized insofar as technologically feasible durin g start-up or shutdown.

5.3.3 Notwithstanding the requirement 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 t he operator meets all of the conditions in specified in Sections 5.3.3.1 through 5.3.3.3.

5.3.3.1 The maximum allowable duration 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 dur ation of

shutdown shall not exceed nine hours.

5.3.3.2 The APCO will only approve start-up or shu tdown duration longer than two hours when the application meets the follo wing

conditions:SJVUAPCD 4306 - 7 10/16/08 5.3.3.2.1 clearly identifies the control techn ologies or strategies to be utilized; and

5.3.3.2.2 describes what physical conditions pr evail during start-up or shutdown periods that prevent the controls from being effective; and

5.3.3.2.3 provides a reasonably precise estimat e as to when the physical conditions will have reached a state

that allows for the effective control of emissions

.

5.3.3.3 The operator shall submit to the APCO a ny information deemed necessary by the APCO to determine the appropriate length of start-up or shutdown. The information shall includ e, 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 needed to complete each activity; and

5.3.3.3.2 a description of the material proc ess flow rates and

system operating parameters, etc., the operator pla ns 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 additiona l duration of startup or shutdown.

5.3.4 Permit to Operate (PTO) modifications solely to include start-up or shutdown conditions may be exempt from Best Availab le Control Technology (BACT) and emission offset requirements if the PTO modifications meet the requirements of Rule 2201 (N ew or Modified Stationary Source Review Rule) Section 4.2 (BACT Ex emptions) and Rule 2201 Section 4.6 (Offset Exemptions).

5.4 Monitoring Provisions

5.4.1 The operator of any unit which simultaneous ly fires gaseous and liquid

fuels, and is subject to the requirements of Sectio n 5.1, shall install and maintain an operational non-resettable, totalizing mass or volumetric flowSJVUAPCD 4306 - 8 10/16/08 meter in each fuel line to each unit. Volumetric f low measurements shall be periodically compensated for temperature and pressu re.

5.4.2 The operator of any unit subject to the app licable emission limits in Sections

5.1 shall install and maintain an operational APCO approved Continuous Emissions Monitoring System (CEMS) for NOx, CO, and oxygen, or implement an APCO-approved Alternate Monitoring Sys tem. 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 Appendix B (Performance Specific ations) and 40 CFR Part 60 Appendix F (Quality Assurance Procedures, a nd applicable provisions of Rule 1080 (Stack Monitoring). An APC O approved Alternate Monitoring System shall monitor one or more of the following:

5.4.2.1 periodic NOx and CO exhaust emission co ncentrations, 5.4.2.2 periodic exhaust oxygen concentration, 5.4.2.3 flow rate of reducing agent added to exh aust, 5.4.2.4 catalyst inlet and exhaust temperature, 5.4.2.5 catalyst inlet and exhaust oxygen concen tration, 5.4.2.6 periodic flue gas recirculation rate, 5.4.2.7 other operational characteristics.

5.4.3 For units subject to the requirements of Se ction 5.2.1 or 5.2.2, the operator

shall monitor, at least on a monthly basis, the ope rational characteristics recommended by the manufacturer and approved by the APCO.

5.4.4 The operator of any Category H unit listed in Secti on 5.1.1 Table 1 and any unit subject to Section 5.2.1 or 5.2.2 shall instal l and maintain an operational non-resettable, totalizing mass or volumetric flow meter in each fuel line to each unit. Volumetric flow measurements shall be pe riodically compensated for temperature and pressure. A master meter, whic h measures fuel to all units in a group of similar units, may satisfy thes e 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. 5.4.5 The APCO shall not approve an alternative mon itoring system unless it is documented that continued operation within ranges o f specified emissionsrelated performance indicators or operational chara cteristics provides a reasonable assurance of compliance with applicable emission limits. The operator shall source test over the proposed range of surrogate operating parameters to demonstrate compliance with the appli cable emission

standards.

5.5 Compliance DeterminationSJVUAPCD 4306 - 9 10/16/08

5.5.1 The operator of any unit shall have the opt ion of complying with either the

applicable heat input (lb/MMBtu) emission limits or the concentration (ppmv) emission limits specified in Section 5.1. T he emission limits selected to demonstrate compliance shall be specifi ed 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 c onditions specified in the Permit to Operate. Unless otherwise specified in t he Permit to Operate no determination of compliance shall be established wi thin 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 defined in Section 3.0.

5.5.3 All Continuous Emissions Monitoring System (CEMS) emissions

measurements shall be averaged over a period of 15 consecutive minutes to demonstrate compliance with the applicable emission limits of this rule. Any 15-consecutive-minute block average CEMS measur ement exceeding the applicable emission limits of this rule shall c onstitute 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 avera ged over a 15 consecutive-minute period by either taking a cumula tive 15-consecutiveminute 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 testing performed pursuant to Section 6.3.1 for the purpose of determining compliance with an applicabl e standard or numerical limitation of this rule, the arithmetic average of three (3) 30-consecutiveminute test runs shall apply. If two (2) of three (3) runs are above an applicable limit the test cannot be used to demonst rate compliance with an applicable limit.

6.0 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 available to the A PCO upon request. Failure to

maintain records or information contained in the re cords that demonstrate noncompliance with the applicable requirements of t his rule shall constitute a

violation of this rule.SJVUAPCD 4306 - 10 10/16/08

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 ann ual hours of operation on each fuel other than natural gas during periods of natural gas curtailment and equipment testing. The NOx emission concentrat ion (in ppmv or lb/MMBtu) for each unit that is operated during per iods of natural gas

curtailment shall be recorded. Failure to maintain records required by

Section 6.1.1 or information contained in the recor ds that demonstrates noncompliance with the conditions for exemption und er Section 4.2 will result in loss of exemption status. On and after t he applicable compliance schedule specified in Section 7.0, any unit losing an exemption status shall be brought into full compliance with this rule as s pecified in Section 7.3.

6.1.2 The operator of any Category H unit listed in Section 5.1.1 Table 1 and any

unit that is subject to the requirements of Section 5.2 shall record the amount of fuel use at least on a monthly basis for each un it, or for a group of units as specified in Section 5.4.4. On and after the appli cable compliance schedule specified in Section 7.0, in the event that such un it exceeds the applicable annual heat input limit specified in Sections 5.1.1 Table 1 Category H and Section 5.2, the unit shall be brought into full co mpliance with this rule as specified in Section 7.4.

6.1.3 The operator of any unit subject to Section 5.2.1 or Section 6.3.1 shall

maintain records to verify that the required tune-u p and the required monitoring of the operational characteristics of th e unit have been performed.

6.1.4 The operator performing start-up or shutdow n of a unit shall keep records of

the duration of start-up or shutdown.

6.2 Test Methods

The following test methods shall be used unless oth erwise approved by the APCO

and EPA.

6.2.1 Fuel hhv shall be certified by third party fuel supplier or determined by: 6.2.1.1 ASTM D 240-87 or D 2382-88 for liquid hydr ocarbon fuels; 6.2.1.2 ASTM D 1826-88 or D 1945-81 in conjuncti on 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.SJVUAPCD 4306 - 11 10/16/08

6.2.4 Stack gas oxygen - EPA Method 3 or 3A, or A RB 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 Se ctions 5.1 or 5.2.3 shall be source

tested to determine compliance with the applicable emission limits at least once every 12 months, (no more than 30 days before or after the required annual source test date). Units that demonstrate c ompliance on two consecutive 12-month source tests may defer the fol lowing 12-month source test for up to 36 months (no more than 30 days befo re or after the required 36-month source test date). During the 36-month s ource testing interval, the operator shall tune the unit in accordance with the provisions of Section 5.2.1, and shall monitor, on a monthly basis, the u nit’s operational characteristics recommended by the manufacturer to ensure compliance with the applicable emission limits specified in Section s 5.1 or 5.2.3. Tune-ups required by Sections 5.2.1 and 6.3.1 do not need to be performed for units that operate and maintain an APCO approved CEMS or an APCO approved Alternate Monitoring System where the applicable em ission limits are periodically monitored. If the result of the 36-mo nth source test demonstrates that the unit does not meet the applic able emission limits specified in Sections 5.1 or 5.2.3, the source test ing frequency shall revert to at least once every 12 months. Failure to comply w ith the requirements Section 6.3.1, or any source test results that exce ed the applicable emission

limits in Sections 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, complianc e with the applicable

emission limits in Sections 5.1 or 5.2.3 shall be d emonstrated by submittal

of annual emissions test results to the District fr om a unit or units that represents a group of units, provided:

6.3.2.1 All units in the group are initially sou rce 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 va ry greater than 25% from the average of all test runs; and

6.3.2.2 All units in a group are similar in term s of rated heat input, make and series, operational conditions, fuel used, and control method. No unit with a rated heat input greater than 100 MM Btu shall be considered as part of the group; and

6.3.2.3 The group is owned by a single owner and is located at a single stationary source; andSJVUAPCD 4306 - 12 10/16/08

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

6.3.2.5 The number of representative units sourc e 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 le ast once.

6.3.2.6 All units in the group shall have received the s imilar

maintenance and tune-up procedures as the represent ative unit(s) as listed in the Permit to Operate. The operator s hall submit to the APCO the specific maintenance procedures to be performed on each unit that will be included in the group for representative testing. Such maintenance procedures shall be spec ified in the Permit to Operate for units that are included in th e group for representative testing. Any maintenance work on a unit which

has no effect on emissions standards and which is n ot specified in the maintenance procedures shall be submitted to the APCO for approval before such unit can be included as pa rt of the group for representative testing. Any unit that necessit ates any
maintenance work which has an effect on emission st andards 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 unit shall be source t ested in accordance with the provisions of Section 6.3.1; an d

6.3.2.7 Should any of the representative units e xceed the required emission limits, each of the units in the group sha ll demonstrate compliance by emissions testing. Failure to comple te emissions testing within 90 days of the failed test shall res ult in the untested units being in violation of this rule. After compl iance with the requirements of Section 6.3.2.7 has been demonstrat ed, subsequent source testing shall be performed pursua nt to
Sections 6.3.1 or 6.3.2.

6.4 Emission Control Plan (ECP)

6.4.1 The operator of any unit shall submit to th e APCO for approval an

Emissions Control Plan according to the compliance schedule in Section 7.0. For each unit, the plan shall contain the followin g:

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),SJVUAPCD 4306 - 13 10/16/08 6.4.1.4 Current emission level, including method used to determine emission level,

6.4.1.5 NOx limit to be satisfied, either Standard 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 the requirements of Section 5.0 and the compliance schedule in Section 7.0.

6.4.2 The operator shall submit to the APCO for app roval, as part of the ECP, a list of units which are to be designated as load-fo llowing units. The APCO shall only designate, as load-following, units for which the following information has been provided to demonstrate that t he units qualify as loadfollowing:

6.4.2.1 Technical data such as steam demand charts or other information to demonstrate the normal operational load fluctuat ions and requirements of the unit,

6.4.2.2 Technical data about the operational response ra nge of an UltraLow NOx burner system(s) operating at 9 ppmv NOx, a nd

6.4.2.3 Technical data demonstrating that the unit(s) ar e 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 stationary source shall comply with this rule in accordance with the schedule specified in Table 2. A stationary source with only one unit shall comply with the schedule specified i n Table 2 Group 1 for standard option or Table 3 Group 1 for enhanced option.

TABLE 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, 2006SJVUAPCD 4306 - 14 10/16/08

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 applicable to the units pursuant to Section 2.0 and the units are not exempt pursuant t o 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

TABLE 3 – Enhanced Option Compliance Schedule (Cont inued)
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 exempt pursuant t o Section 4.1.

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

7.2.1 "Emission Control Plan" identifies the date by which the operator shall

submit an Emission Control Plan pursuant to Section 6.4. The EmissionSJVUAPCD 4306 - 15 10/16/08 Control Plan shall identify all units subject to th is rule. The Emission Control Plan shall identify steps to be taken to comply wit h this rule.

7.2.2 “Authority to Construct” identifies the dat e by with the operator shall submit

an Application for Authority to Construct for each unit subject to the rule.

7.2.3 "Full Compliance" identifies the date by wh ich the owner shall demonstrate

that each unit is in compliance with this rule.

7.3 Any unit that is exempted under Section 4.2 th at becomes subject to the emission

limits of this rule through the loss of exemption s tatus, shall be in full compliance with this rule on and after the date the exemption status is lost.

7.4 Any unit that becomes subject to the emission limits of this rule as a result of

exceeding the applicable annual heat input limit sp ecified in either Section 5.1.1 Table 1 Category H or Section 5.2, shall be in comp liance with the applicable standard option emission limits for Category A and B units in Section 5.1.1 on and after the date the annual heat input limit is excee ded.

8.0 Calculations

8.1 All ppmv emission limits specified in Section 5.1 are referenced at dry stack gas

conditions and 3.00 percent by volume stack gas oxy gen. Emission concentrations shall be corrected to 3.00 percent oxygen as follow s:

measured measured corrected ] NOx ppm [ x ]2 O [% % 95. 20 %

95. 17 ] NOx ppm [

−

=

measured

measured corrected ] CO ppm [ x ]2 O [% % 95. 20 %

95. 17 ] CO ppm [

−

=

8.2 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, o r at two contiguous stationary sources, to achieve an aggregated NOx emission fact or no higher than 90 percent of the aggregated NOx emission factor limit that would result if each unit in operation were individually in compliance with the applicable NOx emission limits in Section 5.1. An operator that is subject to the AECP requi rements below shall also comply with the applicable requirements of Sections 5.0, 6 .0, 7.0 and 8.0.SJVUAPCD 4306 - 16 10/16/08

9.2 Eligibility

A unit not subject to Section 5.1 or Section 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 de finitions shall apply:

9.4.1 Aggregated NOx emission factor limit: the sum of the NOx emissions, over seven consecutive calendar days, that would result if all units in the AECP were in compliance with the lb/MMBtu limits in Sect ion 5.1 and operating at their actual firing rates, divided by the sum of th e heat input of all units in the AECP over seven consecutive calendar days. Aggrega ted emission factor

limit is calculated as:

F F L

= L

i i

i
A Σ Σ

where: L

A is the aggregated NOx emission factor limit (lb/MM Btu)

L

i is the applicable NOx emission factor limit (lb/MM Btu) specified

in Section 5.1.1 Table 1 or Section 5.1.2 for each category of unit in the AECP,

F

i is the total heat input (hhv basis) of fuel (MMBtu ) combusted in each unit during seven consecutive calendar days, a nd

i identifies each unit in the AECP.

9.4.2 Aggregated NOx emission factor: the sum of the actu al NOx emissions during seven consecutive calendar days from all uni ts in the AECP, divided by the sum of the heat input of all units in the AE CP during seven consecutive calendar days. The aggregated emission factor is calculated as:

F F E

= E

i i

i
A Σ Σ

where: E

A is the aggregated NOx emission factor (lb/MMBtu),SJVUAPCD 4306 - 17 10/16/08

E

i is the NOx emission factor (lb/MMBtu) for each uni t in the AECP, established and verified by source testing, o r continuous emission monitors,

F

i is the total heat input (hhv basis) of fuel (MMBtu ) combusted in each unit during seven consecutive calendar days, a nd

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 aggregated emission limit (L

A ). The owner of any unit in an AECP shall notify the 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 d uring 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 seven consecutive calendar day s of operation that the AECP is used, the operator shall calculate and reco rd the aggregated NOx emission factor (L

A ) and the aggregate NOx emission limit (E

A ).

9.5.4 The operator shall submit a NOx emission f actor for each unit that is

included in the AECP. The established NOx emission factor of the

unit shall be no less than the emission factor of t he unit from the most recent source test conducted pursuant to Secti on 6.3 and approved by the APCO. The operator shall not opera te any AECP

unit in such a manner that the NOx emissions exceed the established

NOx emission factor of the unit.

9.5.5 The operator shall submit the AECP, for ap proval by the APCO, by June 1, 2004 or at least 24 months before complianc e with the applicable emission limits in Section 5.1 is requir ed pursuant to the Section 7.1, whichever is later. The AECP shall be submitted with an application for an Authority to Construct pursua nt to complying with Section 7.1 as applicable. The operator shall obtain a written approval of the AECP from the APCO prior to impleme ntation.

9.6 AECP Administrative RequirementsSJVUAPCD 4306 - 18 10/16/08

9.6.1 The AECP shall:

9.6.1.1 Contain all data, records, and other inf ormation 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 subject to alternativ e emission control, 9.6.1.1.2 Daily average and maximum hours of ut ilization 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 recordkeepin g and reporting required by Sections 9.6.4 and 9.6.5.

9.6.1.3 Specify which NOx limit, either Standard Option o r Enhanced Option, will be satisfied by the units under the A ECP.

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

9.6.1.5 Demonstrate that the schedule for achiev ing AECP NOx emission levels is at least as expeditious as the s chedule if applicable units were to comply individually with t he applicable

emission levels in Section 5.1 and the increments o f progress in

Section 7.0.

9.6.2 Revision of AECP

Owners shall demonstrate APCO approval of the AE CP prior to applying

for a modification to said AECP.

9.6.3 AECP Recordkeeping

In addition to the records kept pursuant to Sect ion 6.1, the operator shall

maintain records, on a daily basis, of the paramete rs needed to demonstrate compliance with the applicable NOx emission limits when operating under

the AECP. The records shall be retained for at le ast five years and shall be made available to the APCO upon request. The recor ds shall include, but are not limited to, the following:

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

9.6.3.1.1 fuel type and amount used for each un it (F

i ),SJVUAPCD 4306 - 19 10/16/08

9.6.3.1.2 the actual emission factor for each u nit (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 demonstra te daily compliance with the applicable NOx emissions when operating the units under the AECP.

9.6.4 Reporting and Annual Updates

Notifications of any violation pursuant to Secti on 9.5 shall include: 9.6.4.1 name and location of facility, 9.6.4.2 list of applicable units, 9.6.4.3 cause and expected duration of exceedanc e, 9.6.4.4 the amount of excess emissions, and 9.6.4.5 proposed corrective actions and schedule

.

9.7 Compliance Schedule

The AECP schedule for achieving reduced NOx emiss ion levels shall be at least as

expeditious as the schedule if applicable units wer e to comply individually with the emissions limits specified in Sections 5.1.1 and 5. 1.2 and the applicable compliance schedule required by Section 7.0.SJVUAPCD 4306 - 20 10/16/08 This page intentionally blank