(Adopted: 08/04/89; Amended: 12/07/95; Amended: 04/11/97; 

Amended: mm/dd/yy)

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RULE 1134 

Emissions Of Oxides Of Nitrogen From

Stationary Gas Turbines

(aA) ApplicabilityGeneral

(1) Purpose

(a) The purpose of this rule is to limit the emission of oxides of nitrogen (NOX) and 

carbon monoxide (CO) from Stationary Gas Turbines. 

(2) Applicability

(a) This rule applies to any new or existing Stationary Gas Turbine of 0.3 megawatt 

(MW) and larger unless the equipment is exempt from this rule pursuant to 

Section (D) of this rule. The provisions of this rule shall apply to all existing 

stationary gas turbines, 0.3 megawatt (MW) and larger, as of August 4, 1989. 

[Former rule provisions did not apply to stationary gas turbines in SEDAB

pursuant to former section (g)(1)(D), therefore, the proposed amendments 

expand rule applicability to a wider variety of sources.]

(bB) Definitions 

(1) “Air Pollution Control Officer (APCO)” – The person appointed to the position of Air 

Pollution Control Officer of the District pursuant to the provisions of California Health 

& Safety Code §40750, and his or her designee. [Derived from AVAQMD Rule 1133.]

(12) “Chemical Processing Gas Turbine Unit” – is a A gas turbine unit that vents its exhaust 

gases into the operating stream of a chemical process. 

(2) Cogeneration Cycle Gas Turbine Unit is a gas turbine unit that operates both for the 

simultaneous production of shaft work and for the recovery of useful thermal energy 

from the exhaust gases or waste steam as defined by Section 25134 of the California 

Public Resources Code. [Definition removed since it is not used in amended version of 

rule.]

(3) Combined Cycle Gas Turbine Unit is a gas turbine unit that operates both for the 

production of electrical energy from shaft work and the useful energy produced from
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heat recovered from its exhaust gases. [Definition removed since it is not used in 

amended version of rule.]

(3) “Continuous Emissions Monitoring System (CEMS)” – All of the equipment that may 

be required to meet the data acquisition and availability requirements of this rule, to 

sample, condition (if applicable), analyze, and provide a record of emissions on a 

continuous basis. [Derived from 40 CFR 51.165(a)(1)(xxxi)]

(4) “Digester Gas” – Fuel containing a minimum of 60 percent process gas, derived from a 

digester, by volume on a daily average. [Derived from previous rule version (C)(1)(a) 

and SCAQMD Rule 1134 (c)(1).]

(5) “Dry Low NOX Combustion Technology (DLN)” – Any turbine combustor design 

which uses multiple staging, air/fuel premixing or other modifications to achieve lower 

levels of NOX emissions as compared to conventional combustors. [Derived from 

SJVUAPCD Rule 4703 §3.7]

(46) “Emergency Standby Gas Turbine Unit” – Any Stationary Gas Turbine that operates as 

a mechanical or electrical power source for a facility only when the primary power 

source has been rendered inoperable due to failure beyond the reasonable control of the 

operator. A power interruption pursuant to a voluntary interruptible power supply 

agreement is not to be considered as an emergency loss of primary power. Electricity 

generated by such a unit cannot be soldis a gas turbine unit that operates only as a 

mechanical or electrical power source for a facility when the primary power source has 

been rendered inoperable, except due to power interruption pursuant to an interruptible 

power supply agreement. This does not include utility company electrical power plant 

units. [Derived from MDAQMD Rule 1159.]

(7) “Emission Control Equipment” – Add-on technologies which control the turbine's 

emissions, including, but not limited to, Selective Catalytic Control (SCR), water 

injection, steam injection, but excluding DLN. [Derived from MDAQMD Rule 1159.]

(58) “Emission Control Plan (ECP)” – is a A plan that shall contain at a minimum District 

permit or identification number; name of gas turbine manufacturer; model designation; 

rated brake horsepower; heat rate (BTU/KW-HR), corrected to the HHV for each type 

of fueling (liquid/gas); type of liquid fuel and/or type of gaseous fuel; hours of operation 

in the previous one-year period; fuel consumption (cubic feet of gas or gallons of liquid) 

for the previous one-year period; and a list of all gas turbine units required to be 

controlled identifying the type of emission control to be applied to such gas turbine units 

along with documentation showing existing emissions of NOx and CO.

(9) “Emission Control System Operating Parameters” – Any operating parameter(s) that the 

District deems necessary to analyze for the determination of compliance. Such 

parameters include, but are not limited to, the ammonia and gas flow rates, the exhaust 

temperature for the Selective Catalytic Reduction (SCR), humidity, water injection rate, 
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exhaust gas flow rate and the temperature for water injection. [Derived from 

MDAQMD Rule 1159.]

(10) “Enhanced Emissions Monitoring Device” – Any automated data recording device or 

system having both data gathering and retrieval capabilities. Such equipment includes, 

but is not limited to, Continuous Emissions Monitoring Systems (CEMS) and Predictive 

Emissions Monitoring Systems (PEMS). [Derived from MDAQMD Rule 1159.]

(6) Exhaust After-Treatment means a control method for the post-combustion reduction of 

NOx emissions, such as selective catalytic reduction (SCR). [Definition removed since 

it is not used in amended version of rule.]

(711) “Existing Gas Turbine Unit” – is aA stationary gas turbine unit that met the following

criteria prior to August 4, 1989(date of amendment): 

(Aa) Had been issued a valid permit to construct or operate by the District, or 

(Bb) Was in operation pursuant to the provisions of District Rule 219(b)(1).(D)(2)(a)

(812) “Higher Heating Value (HHV)” -– The higher Higher heating Heating value Value of

the fuel.

(13) “Landfill Gas” – Gas derived from a landfill gas extraction system.

(914) “Lower Heating Value (LHV)” -– The Lower Heating Value Of of the Fuel.

(15) “Measured NOX Emissions Concentration” – The concentration of oxides of nitrogen 

corrected to International Standards Organization (ISO) standard conditions: [Derived 

from MDAQMD Rule 1159.]

NOX = (NOX obs)(Pref/Pobs)0.5 (288 K/Tamb)1.53 (e19(Hobs-0.00633)) 

Where: NOX = emissions of NOX at 15 percent oxygen and ISO standard 

conditions on a dry basis, ppm.

NOX obs = measured NOX emissions corrected to 15 percent oxygen on a 

dry basis, ppm.

Pref = standard reference pressure, (14.696 psia).

Pobs = measured site ambient absolute pressure, psia.

Hobs = measured humidity of ambient air, pounds water per pound dry 

air.

e = transcendental constant (2.718)

Tamb = measured temperature of ambient air, degrees Kelvin.

or an alternate calculation that corrects to ISO standard conditions and is 

approved by the APCO.
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(10) Peaking Gas Turbine Unit is a gas turbine unit that is used intermittently to produce 

energy on a demand basis. [Definition removed since it is not used in amended version 

of rule.]

(11) Pipeline Gas Turbine Unit is a stationary gas turbine unit used to transport gases or 

liquids in a pipeline. [Definition removed since it is not used in amended version of 

rule.]

(1216) “Power Augmentation” – is theAn increase in the gas turbine shaft output and/or the 

decrease in gas turbine fuel consumption by the addition of energy recovered from 

exhaust heat.

(17) “Predictive Emissions Monitoring System (PEMS)” – All of the equipment necessary to 

monitor process and control device operational parameters (for example, control device 

secondary voltages and electric currents) and other information (for example, gas flow 

rate, oxygen or carbon dioxide concentrations), and calculate and record the mass 

emissions rate (for example, lb/hr) on a continuous basis. [Derived from 40 CFR 

51.165(a)(1)(xxxii)]

(18) “Public Service Unit” – A Stationary Gas Turbine used to generate electricity for sale or 

for use in serving the public. [Derived from MDAQMD Rule 1159.]

(1319) “Rating Of A Gas Turbine Unit” – is theThe continuous MW (megawatt) rating or 

mechanical equivalent by a manufacturer for gas turbine unit(s) without power Power 

augmentationAugmentation.

(20) “Reasonably Available Control Technology (RACT)” – The lowest emission limitation 

that a particular source is capable of meeting by the application of control technology 

that is reasonably available considering technological and economic feasibility. 

[USEPA definition 44 FR 53761 (Sept. 17, 1979)]

(21) “Selective Catalytic Reduction (SCR)” – A noncombustion control technology that 

destroys NOX by injecting a reducing agent (e.g., ammonia) into the flue gas that, in the 

presence of a catalyst (e.g., vanadium, titanium, or zeolite), converts NOX into 

molecular nitrogen and water. [Derived from 40 CFR 76.2]

(22) “Shutdown Period” – 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 temperature as the fuel supply to the unit is completely turned off. [Derived from 

SJVUAPCD Rule 4703 3.26]

(23) “Startup Period” – The period of time during which a unit is brought from a Shutdown 

status to its operating temperature and pressure, including the time required by the unit’s 

emission control system to reach full operation. [Derived from SJVUAPCD Rule 4703 

3.29]
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(14) Sewage Digester Gas is any gas derived from anaerobic decomposition of organic 

sewage. [Definition removed since it is not used in amended version of rule.]

(15) Southeast Desert Air Basin (SEDAB) means the portion of the air basin containing 

specific desert portions of Los Angeles, Riverside and San Bernardino counties, as 

defined in Title 17, California Code of Regulations, Section 60109, within the 

jurisdiction of the District. [Definition removed since it is not used in amended version 

of rule.]

(1624) “Stationary Gas Turbine” or “ Unit” – is aAny gas turbine unit that is gas and/or liquid 

fueled with or without power augmentation. This gas turbine unit is either attached to a 

foundation at a facility or is portable equipment operated at a specific facility for more 

than 90 days in any 12twelve-month period. Two or more gas turbines units powering 

one shaft shall be treated as one gas turbine unit. 

(1725) “Thermal Stabilization Period” – The Startup or Shutdown Period necessary to bring the 

heat recovery steam generator to the proper operating temperature, not to exceed two 

hours.is the two-hour start up time necessary for NOx control purposes in cogeneration 

cycle, combined cycle, or any other applicable stationary gas turbine units.

(cC) Emissions LimitationsStandards 

(1) (1) The owner or operator of any affected stationary Stationary gas Gas turbine 

Turbine unit Unit shall not operate such unit Unit under load conditions, excluding the 

thermal Thermal stabilization Stabilization period Period and Startup and Shutdown 

Periodsor other time period specified in the Permit to Construct or the Permit to Operate 

issued prior to August 4, 1989, which result in the discharge of oxides ofMeasured 

nitrogen (NOx) emissionsEmissions Concentration exceeding the emissions limits set 

forth below., directly or indirectly, into the atmosphere at concentrations in excess of the 

following as measured pursuant to subdivision (e):

(a) For Stationary Gas Turbines the federal NOX and CO RACT limits in Table 1 

apply: [Former Table I provisions did not apply to SEDAB pursuant to former 

section (g)(1)(D).]

Compliance e Limit Limit Referenc EFF

25%

= ×

Where:

Compliance Limit = allowable NOx emissions (ppm by volume).

Reference Limit = the NOx emission limit (ppm by volume) is corrected
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to 15 percent oxygen on a dry basis, and averaged over 

15 consecutive minutes. These limits for various 

megawatt ratings (continuous rating by the 

manufacturer without power augmentation) are as 

follows:

REFERENCE NOx LIMITS, PPM

Unit Size Megawatt (MW) Rating Effective 12/31/95

0.3 to Less Than 2.9 MW 25

2.9 to Less Than 10.0 MW 9

2.9 to Less Than 10.0 MW No SCR 15

10.0 MW and Over 9

10.0 MW and Over No SCR 12

60 MW and Over Combined Cycle no SCR 15

60 MW and Over Combined Cycle 9

Effective 4/11/97

2.9 to Less Than 10.0 MW Utilizing Fuel containing a 

Minimum of 60% Sewage Digester Gas by volume on a 

Daily Average

25

And,

EFF = 3413 x 100%

Actual Heat Rate at HHV of Fuel (BTU/KW-HR)

or,

EFF LHV

HHV

= (Manufacturer' s Rated Efficiency at LHV) ×

or

EFF = the demonstrated percent efficiency of the gas turbine unit only as 

calculated without consideration of any downstream energy recovery from 

the actual heat rate, (BTU/KW HR) or 1.34 BTU/HP; corrected to the 

HHV (higher heating value) of the fuel, as measured at peak load for that 

facility; or the manufacturer's continuous rated percent efficiency 

(manufacturer's rated efficiency) of the gas turbine unit after correction 

from LHV (lower heating value) to the HHV of the fuel, whichever 

efficiency is higher. The value of EFF shall not be less than 25 percent. 

Gas turbine units with lower efficiencies will be assigned a 25 percent 

efficiency for this calculation.

Table 1

NOX and CO Compliance Limits

Control

Operating 

hours per 

year

Rating NOX Compliance Limit, 

ppmv at 15% oxygen

CO

Compliance 

Limit, ppmv at 
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Gas Fuel Liquid 

Fuel

15% oxygen

SCR + DLN > 877 > 10 MW 5 25 200

DLN > 877 2 – 10 MW 25 65 200

SCR (no 

DLN 

available) 

> 877 2 – 10 MW 35 65 200

DLN > 877 < 2 MW 42 50 250

SCR or DLN < 877 > 10 MW 25 42 200

Any (fired on 

Digester Gas 

and/or 

Landfill Gas)

any 0.3 – 10 MW 25 N/A 200

[Former Table I provisions did not apply to SEDAB pursuant to former section 

(g)(1)(D). Therefore, the limits contained in this table are more stringent than the limits 

contained in the previous Table. A specific category for gas turbines which use digester 

gas was added to recognize the separate category, although the applicable limits do not 

change.]

(b) For the purposes of these emissions limits the following conventions are 

applicable: [Derived from MDAQMD Rule 1159.]

(i) Gas includes natural gas, Digester Gas and Landfill Gas.

(ii) Oil includes kerosene, jet fuel, and distillate. The sulfur content of the 

oil shall be less than 0.05 percent.

(iii) NOX = emissions of NOX, in ppmv, corrected to 15 percent oxygen and 

ISO standard conditions on a dry basis, averaged over any consecutive 15 

minute period.

(2) The owner or operator of any Stationary Gas Turbine subject to (C)(1)(a) shall submit to 

the APCO for approval, an Emission Control Plan (ECP) for the purpose of establishing 

compliance with provisions of this rule. [Derived from MDAQMD Rule 1159.]

(3) The owner or operator of any Stationary Gas Turbine subject to (C)(1) shall minimize 

emissions insofar as technologically feasible during Thermal Stabilization Periods. 

[Section added in response to MDAQMD Rule 1159 USEPA rule review comments 

received 7/9/09]

(2) The operator of any existing gas turbine unit subject to this rule shall also be subject to 

Regulation XIII if carbon monoxide (CO) emissions increase as a result of the 

application of NOx controls.
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(D) Exemptions [Exemption section relocated from previous section (g) for 

consistency with AVAQMD rule format.]

(1) The provisions of Section (C) of this rule shall not apply to the operation of:

(a) Laboratory gas turbine units used in research and testing for the advancement of 

gas turbine technology.

(b) Units operated exclusively for fire fighting and/or flood control.

(c) Chemical Processing Gas Turbine Units.

(d) All existing pipeline gas turbine units located in the Southeast Desert Air Basin 

(SEDAB). [AVAQMD is in the SEDAB and this exemption made rule 

inapplicable.]

(2) The provisions of subdivisions (c) and (d), and paragraphs (f)(3), (f)(4) and (f)(5) shall 

not apply to the following: The provisions of this rule, with the exception of Section 

(F)(2), shall not apply to the operation of Stationary Gas Turbines used under the 

following conditions:

(a) Emergency Standby Units, and Stationary Gas Turbine Units demonstrated to 

operate less than 200 hours per calendar year, which have installed and 

maintained in proper operation a non-resettable engine hour meter.

(b) Portable, turntable, or track mounted turbines whose operation generates 

intermittent, high velocity air flow for live fire sustainability, lethality, 

aerodynamic, cookoff, or remote control operation testing only. [Derived from 

MDAQMD Rule 1159. Equipment was formerly exempt pursuant to section 

(g)(1)(D). This provision retains that exemption. Please note that equipment is 

still required to have a permit (See Rule 219) and new or modified units will be 

subject to Reg. XIII.]

(c) Intra facility portable flight-line equipment used to support aircraft systems or 

start up aircraft power plants. [Equipment was formerly exempt pursuant to 

section (g)(1)(D). This provision retains that exemption. Please note that 

equipment is still required to have a permit (See Rule 219) and new or modified 

units will be subject to Reg. XIII.]

(B) All existing gas turbine units located in the Southeast Desert Air Basin 

(SEDAB) which are rated below 4 MW and operate less than 877 hours per year.

[AVAQMD is in the SEDAB and this exemption made rule inapplicable.]

(C) All existing gas turbine units located on San Clemente Island which are rated 

below 4 MW and operate less than 877 hours per year. [San Clemente Island is 

not in the AVAQMD. Therefore, this provision is not applicable.]
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However, if the hour-per-year limit is exceeded, the exemption shall be automatically 

and permanently withdrawn. The operator of any stationary gas turbine exempt under 

this subparagraph must notify the Executive Officer within seven days if the hour-peryear limit is exceeded. Within 30 days after the date the hour-per-year limit is 

exceeded, the operator must submit a permit application for modification to equipment 

to meet the applicable compliance limit within 24 months of the date the hour-per-year 

limit is exceeded. Included with this permit application, the operator must submit an 

emission control plan including a schedule of increments of progress for the installation 

of the required control equipment. This plan and schedule shall be subject to the review 

and approval of the Executive Officer. [Restated from previous section (g)(2)] section 

(G) – Notification Requirements for Exempt and Emergency Standby Units.]

(E) Administrative Requirements [Derived from MDAQMD Rule 1159.]

(1) The ECP required pursuant to section (C)(2) shall, at a minimum, include the following 

information if such information is applicable:

(a) A list of all Stationary Gas Turbines required to be controlled pursuant to this 

rule.

(b) For each Stationary Gas Turbine listed:

(i) District identification number, and District permit to operate number;

(ii) Name of the gas turbine manufacturer;

(iii) Equipment model number;

(iv) Manufacturer's rated shaft power output (MW); 

(v) Type of liquid fuel and/or type of gaseous fuel;

(vi) HHV for each fuel;

(vii) Heat rate ((Btu/kW-hr), corrected to the HHV) for each type of fuel (gas 

or liquid) for each turbine;

(viii) Monthly fuel consumption for the previous twelve-month period (cubic 

feet for gas; gallons for liquid);

(ix) Monthly hours of operation in the previous twelve-month period;

(x) The type of NOX Emission Control Equipment, including any auxiliary 

equipment related to the control of emissions, to be applied; 

(xi) Documentation showing the current (existing) concentration and mass 

rate of emissions of NOx from the unit;

(xii) A schedule with specified increments of progress dates for construction 

of Emission Control Equipment, operational milestones for 

implementation of emissions control and/or installation of monitoring 

equipment; and

(xiii) A final compliance date.
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(dF) Monitoring and Recordkeeping RequirementsSource Testing

(1) The owner or operator of any Stationary Gas Turbine required to install Emission 

Control Equipment for compliance with this rule shall:

(a) Install, operate, and maintain in calibration, the following monitoring 

equipment, as approved by the APCO:

(i) Continuous measurement and recording of Emissions Control System 

Operating Parameters;

(ii) Continuous measurement and recording of elapsed time of operation; and

(iii) An Enhanced Emissions Monitoring Device.

(b) Notify the APCO, in writing, before issuance of the permit to operate, such 

information which correlates the Emission Control System Operating 

Parameters, and PEMS if present, to the associated measured NOX emissions 

output. This information will be used to determine compliance with applicable 

provisions of this rule for non-CEMS-equipped turbines and CEMS-equipped 

units when the CEMS is not operating properly. 

(c) Provide, on an annual basis, compliance testing data and information regarding 

NOX emissions. The data shall be corrected to ISO conditions and at 15 percent 

oxygen on a dry basis; and the percent efficiency (EFF) of each turbine unit.

(2) The owner/operator of any Stationary Gas Turbine shall:

(a) On a daily basis, maintain a turbine operating log that includes, as a minimum, 

the following information: 

(i) The total hours of operation per day; 

(ii) The accumulated hours of operation per calendar month; 

(iii) The type and quantity of fuel used; and

(iv) The nature of operation of the unit (exempt or non-exempt).

(b) The operating log required to be kept pursuant to this rule shall be kept current 

and on site for a minimum of two years; and provided to District or state 

personnel on request. 

The operator of any stationary gas turbine unit subject to the provisions of this rule shall 

perform the following actions: [These provisions did not apply to SEDAB pursuant to former 

section (g)(1)(D). Therefore, the requirements contained in the amended section (F) are more 

stringent than the provisions contained in the previous rule.]

(1) Install, operate, and maintain in calibration a continuous in-stack NOx and oxygen 

monitoring system which meets the requirements of 40 CFR Part 60, Appendix B, Spec. 

2, for NOx , Spec 3 for oxygen (except the alternative RA procedures for Spec. 2 shall 
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not apply), the 2 and 24 -hour calibration spec. of Rule 218, and 40 CFR Part 60, 

Appendix F to demonstrate compliance with the emission limits of this rule. The 

continuous emissions monitoring system shall have data gathering and retrieval 

capability which meets the reporting requirements of 40 CFR part 60.7(c), 60.7(d), and 

60.13. This system shall include equipment that measures and records the following:

(A) Flow rate of liquids or gases and the ratio of water or steam to fuel added to the 

combustion chamber or to the exhaust for the reduction of NOx emissions, as 

applicable.

(B) Elapsed time of operation.

(2) Source Testing

(A) Provide source test information regarding the gas turbine unit’s exhaust gas NOx 

concentration, and the demonstrated percent efficiency (EFF), or the 

manufacturer’s rated EFF, if the Executive Officer determines that it is 

representative of the unit’s EFF, and the carbon monoxide concentration as 

specified pursuant to paragraph (e)(1). NOx and carbon monoxide 

concentrations shall be in ppm by volume, corrected to 15 percent oxygen on a 

dry basis.

(B) Source Test Frequency

(i) Units emitting 25 tons or more of NOx per calendar year shall be source 

tested, at least once every 12 months.

(ii) All other existing units shall be source tested within 90 days after every 

8,400 hours of operation.

(G) Notification Requirements for Exempt and Emergency Standby Units [Derived 

from MDAQMD Rule 1159]

(1) Any Stationary Gas Turbine unit which is exempt or claimed to be exempt pursuant to 

subsection (D)(2) shall:

(a) Notify the APCO within seven (7) days if the hour-per-year threshold is 

exceeded. 

(i) If the hour-per-year threshold is exceeded, the exemption pursuant to 

subsection (D)(2) shall be permanently withdrawn. 

(ii) If the hour-per-year threshold is exceeded the owner/operator shall, 

within 30 days of the notification, submit an application for a permit to 

operate to the District. Such application shall including a plan detailing 

actions and a schedule of progress to meet the applicable RACT limits 
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and provisions of this rule within 18 months after the date of the 

notification; an ECP conforming to the requirements of Section (E) for 

the Emission Control Equipment. 

(2) Notwithstanding the provisions of Sections (F)(2) and (G)(1) above, A Public Service 

Unit shall not be subject to the hour-per-year threshold when:

(a) Such unit is operating during a state of emergency declared by a proclamation of 

the Governor of the State of California; and 

(b) Such unit is located within the specific geographic location identified in the state 

of emergency proclamation.

(eH) Test Methods 

(1) Compliance testing shall be subject to the protocols prescribed in the District's 

Compliance Procedural Manual.

(2) The following test methods shall be used to determine compliance with the provisions 

of this rule. 

(a) NOX emissions shall be determined by EPA Test Method 20.

(b) The Higher Heating Value (HHV) and the Lower Heating Value (LHV) shall be 

determined by the appropriate method for the fuel type listed below: 

(i) For liquid fuels: 

a. ASTM Test Method D 240-87 (Standard Test Method for Heat of 

Combustion of Liquid Hydrocarbon Fuels by Bomb Calorimeter). 

(ii) For distillate fuel: 

a. ASTM Test Method D 2382-88 (Standard Test Method for Heat 

of Combustion of Hydrocarbon Fuels by Bomb Calorimeter -

High Precision Method); or,

(iii) For gaseous fuels: 

a. ASTM Test Method D 3588-91 (Standard Practice for 

Calculation Heat Value, Compressibility Factor, and Relative 

Density (Specific Gravity) of Gaseous Fuels); or 

b. ASTM Test Method D 1826-88 (Standard test Method for Caloric 

(Heating) Value of Gases in Natural Gas Range by Continuous 

Recording Calorimeter); or 

c. ASTM Test Method D 1945-81 (Standard Method for Analysis of 

Natural Gas by Gas Chromatography).
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The following may be used by the Executive Officer to verify the concentrations of NOx, CO 

and oxygen subject to the provisions of this rule. Emissions determined to exceed any limits 

established by this rule through either of the following shall constitute a violation of this rule.

(1) District Test Methods 3.1, 7.1, 10.1 and 100.1 and EPA Test Method 10 or any method 

deemed to be equivalent by the Executive Officer and approved by CARB and EPA.

(2) Data obtained from a continuous emissions monitoring system, which is installed and 

properly operated according to paragraph (d)(1) of this rule and as approved by the 

Executive Officer.

(fI) Recordkeeping Compliance Schedule [Recordkeeping requirements in section 

(F)]

(1) The owner/operator of any Existing Stationary Gas Turbine subject to the provisions of 

Section (C)(1)(a) above shall comply with the following increments of progress:

(a) An ECP shall be submitted to the District within 90 days of rule adoption. The 

District shall approve the ECP within 30 days of submission. 

(b) Any affected turbine shall be in full compliance with all applicable provisions of 

the rule within twelve months of rule adoption. 

(c) Demonstrate final compliance with all applicable standards and requirements of 

the rule within six months of the installation of the NOX reduction technology.

(2) The owner/operator of any new Stationary Gas Turbine subject to the provisions of 

Section (C) shall comply as of the date of adoption of this rule. Recordkeeping

The facility operator shall comply with the following provisions:

(1) All records shall be maintained at the facility for a period of two years and made 

available to District staff upon request.

(2) Maintain a gas turbine operating log that includes, on a daily basis, the actual Pacific 

Standard Time start-up and stop time, total hours of operation; type and quantity of fuel 

used (liquid/gas), cumulative hours of operation to date for the calendar year; and if 

applicable the cumulative hours of operation since the last source test required by 

subparagraph (d)(2)(A).

(3) A monthly summary of emissions pursuant to paragraph (d)(1) shall be submitted to the 

District on or before the last day of the following calendar month.
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(4) The results of source tests shall be submitted to the District in a form and manner as 

specified by the Executive Officer within 30 days after testing is completed.

(5) Any person using an emission control system as a means of complying with this rule 

shall maintain daily records of system operation and maintenance which will 

demonstrate proper operation and compliance of the emission control device during 

periods of emission producing activities.

(g) Exemptions [Relocated to section (D) for consistency]

Any person seeking to qualify for any one of the following exemptions has the burden of 

proving its existing gas turbine unit meets the applicable specified criteria.

(1) All provisions of this rule shall not apply to the following:

(A) Laboratory gas turbine units used in research and testing.

(B) Gas turbine units operated exclusively for fire fighting and/or flood control.

(C) Chemical processing gas turbine units.

(D) All existing pipeline gas turbine units located in the Southeast Desert Air Basin 

(SEDAB).

(2) The provisions of subdivisions (c) and (d), and paragraphs (f)(3), (f)(4) and (f)(5) shall 

not apply to the following:

(A) Emergency standby and peaking gas turbine units demonstrated to operate less 

than 200 hours per calendar year, which have installed and maintained in proper 

operation a non-resettable engine hour meter.

(B) All existing gas turbine units located in the Southeast Desert Air Basin 

(SEDAB) which are rated below 4 MW and operate less than 877 hours per year.

(C) All existing gas turbine units located on San Clemente Island which are rated 

below 4 MW and operate less than 877 hours per year.

However, if the hour-per-year limit is exceeded, the exemption shall be automatically 

and permanently withdrawn. The operator of any stationary gas turbine exempt under 

this subparagraph must notify the Executive Officer within seven days if the hour-peryear limit is exceeded. Within 30 days after the date the hour-per-year limit is 

exceeded, the operator must submit a permit application for modification to equipment 

to meet the applicable compliance limit within 24 months of the date the hour-per-year 

limit is exceeded. Included with this permit application, the operator must submit an 

emission control plan including a schedule of increments of progress for the installation 
AVAQMD Rule 1134 1134-15

Stationary Gas Turbines 

D3, 12/14/09

of the required control equipment. This plan and schedule shall be subject to the review 

and approval of the Executive Officer. [Restated in section (G) – Notification 

Requirements for Exempt and Emergency Standby Units.]

[SIP: Submitted as amended 01/19/10 on mm/dd/yy; Submitted as amended 4/11/97 on 8/1/97; 

Approved _______, _______, 40 CFR 52.220(c)(230)(i)(B)(1)]