The URL can be used to link to this page

Browse Search

Home My WebLink About20251241.tiffu,171c-- � V i i1AA J 5 1Iz1zr5 ig COLORADO Department of Public Health 8 Environment Weld County - Clerk to the Board 1150 O St PO Box 758 Greeley, CO 80632 May 7, 2025 To Whom It May Concern: RECEIVED MAY 0 7 2025 WELD COUNTY COMMISSIONERS On May 7, 2025, the Colorado Air Pollution Control Division will begin a 3O -day public comment period for Public Service Company of Colorado - Ft. St. Vrain Station. A copy of this public notice is enclosed. Thank you for assisting the division by posting a copy of this notice in your office. A public copy of this notice is required by Colorado Air Quality Control Commission regulations. The notice must be available for public inspection for a period of thirty (30) days from the beginning of the public comment period. Please reference the public notice for instructions on submitting comments. \90 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.Qov/cdphe j°) Jared Polls, Governor I Jill Hunsaker Ryan, MPH, Executive Director t; * r, ?L CDEI i4 L_ (Ds1� a�� ?w (gigI cx-by l v1.l5B ) o C 5 Z5 2025-1241 DRAFT Colorado Department of Public Health and Environment Public Service Company of Colorado Ft. St. Vrain CONSTRUCTION PERMIT 94WE609 Initial Approval / Modification 2 Date Issued: TBD COLORADO Air Pollution Control Division Depanment of Pubdc Health b Bmronment Page 1 of 41 DRAFT AIR POLLUTION CONTROL DIVISION COLORADO CONSTRUCTION PERMIT FACILITY NAME: FACILITY ID: Ft. St. Vrain Station CONSTRUCTION PERMIT NUMBER 123/0023 94WE609 ISSUE DATE: Initial Approval/ Modification 2 ISSUED TO: Public Service Company of Colorado 1800 Larimer Street Suite 1300 Denver, Co 80202 Nature of Business: Primary SIC: PLANT SITE LOCATION: Ft. St. Vrain Station 16805 County Road 19 Y: Platteville, CO 80651 Weld County Combustion Turbine Electric Generating Station 4911 Description of Modification 2: Modification 2 adds and SCR on to turbine 002 (AIRS ID 004) to control NOx. COLORADO Air Pollution Control Division Department of Publx Health 6 Environment Page 2 of 41 DRAFT TABLE OF CONTENTS: Section 1— General Activities and Summary 1. Permitted Activities 2. Alternative Operating Scenarios 3. Nonattainment Area New Source Review (NANSR) and Prevention of Significant Deterioration (PSD) 4. Summary of Emission Units Section II — Specific Permit Terms 1. T002 & T003 —Two (2) Combustion Turbines Capable of Simple or Combined Cycle Operation 2. Continuous Emission Monitoring Systems (CEMS) Section III — Additional Requirements & General Conditions Appendix A Permit Acronyms Appendix B VOC Correlation Equations COLORADO Air Pollution Control Division Department of Public Health b Enwotment Page 3 of 41 DRAFT Section I — General Activities and Summary 1. Permitted Activities This facility is a decommissioned nuclear power generating facility. Nuclear operations ceased at this facility in 1989 and decommissioning was completed in 1996. The repowering of this facility utilized a large portion of the non-nuclear assets such as the steam turbine, the cooling water system, condensate and feed water system, water treatment systems, and a substation. This facility consists of five (5) natural gas fired combustion turbines and three (3) heat recovery steam generators (HRSG). The capacity of the steam turbine is 330 megawatts (MW). The output rating of the entire plant varies based on ambient temperature with more generation in the winter and less generation in the summer. The facility generates approximately 965 MW (summer rating) of electricity. The turbines are numbered as follows: T001 (turbine No.1) is the steam turbine, T002 (turbine No. 2) is the No. 1 combustion turbine, T003 (turbine No. 3) is the No. 2 combustion turbine, T004 (turbine No. 4) is the No. 3 combustion turbine, T005 (turbine No. 5) is the No. 4 combustion turbine and T006 (turbine No. 6) is the No. 5 combustion turbine. Combustion turbines 2 and 3 each generate approximately 135 MW of electricity and each HSRG, which includes duct burners for supplemental firing, will add approximately 100 MW of electrical capacity. Combustion turbine 4, which commenced operation in April 2001, generates approximately 135 MW of electricity and the HRSG, which includes a duct burner for supplemental firing, will add approximately 100 MW of electrical capacity. T002 (Turbine No. 2) is controlled by a selective catalytic reduction (SCR) control. These combustion turbines and HRSG combinations can be run in three modes: simple cycle (combustion turbine only), combined cycle (combustion turbine with HRSG) with no fuel fired in the duct burners and combined cycle (combustion turbine with HRSG) with fuel fired in the duct burners. In simple cycle operation, exhaust from the combustion turbine is discharged through the bypass stack. In combined cycle operation, the exhaust gas from the turbine passes through the HRSG first and then exits out the HRSG stack. Combustion turbines No. 5 and 6, which commenced operation in April 2009, each generate approximately 146 MW. Turbines 5 and 6 can only operate in simple cycle mode. In addition to the combustion turbines, significant emission units at this facility consist of an auxiliary boiler fueled by natural gas, one cooling water tower, one service water tower, a 500 gal gasoline tank, cold cleaner solvent vats, two (2) diesel fuel -fired engines driving an emergency generator and one (1) diesel fuel -fired engine driving an emergency fire pump. The facility is located approximately three miles north and west of Platteville, Colorado. The area in which the plant operates is designated as attainment for all criteria pollutants except ozone. It is classified as non -attainment for the 8 -hr ozone standard and is part of the 8 -hr Ozone Control Area as defined in Regulation No. 26, Part A. The 8 -hr Ozone Control Area has been classified as a serious non -attainment area effective January 27, 2020. COLORADO An Pollution Control Division Department of public Health ft Environment Page 4 of 41 DRAFT There are no affected states within 50 miles of the plant. Rocky Mountain National Park, Eagle's Nest National Wilderness Area and Rawah National Wilderness Area, Federal Class I designated areas, are within 100 kilometers of the plant. b. Until such time as this permit is modified or revoked, the permittee is allowed to discharge air pollutants from this facility in accordance with the requirements, limitations, and conditions of this permit. 2. Alternative Operating Scenarios a. The permittee shall be allowed to make the following changes to its method of operation without applying for a revision of this permit. i. Turbines No. 2, and 3 may be operated as follows: 1. The combustion turbines may be operated as simple cycle combustion turbines as specified under Section II. 2. The combustion turbines may be operated as combined cycle combustion turbines with no supplemental fuel being fired in the duct burners as specified under Section II. 3. The combustion turbines may be operated as combined cycle combustion turbines with supplemental fuel being fired in the duct burners as specified under Section II. b. The facility must contemporaneously with making a change from one operating scenario to another, maintain records at the facility of the scenario under which it is operating (Colorado Regulation No. 3, Part A, Section IV.A.1). 3. Nonattainment Area New Source Review (NANSR) and Prevention of Significant Deterioration (PSD) a. This facility is categorized as a PSD major stationary source (potential to emit of PM, PM10, NOX and CO > 100 tons/year). Future modifications at this facility resulting in a significant net emissions increase (see Colorado Regulation No. 3, Part D, Sections II.A.27 and 44) or a modification which is major by itself (Potential to Emit > 100 tons/year) for any pollutant listed in Colorado Regulation 3, Part D, Section II.A.44 for which the area is in attainment or attainment/maintenance may result in the application of the PSD review requirements. b. This source is categorized as a NANSR major stationary source (Potential to Emit of NOX > 50 tons/year). Future modifications at this facility resulting in a significant net emissions increase (see Regulation No. 3, Part D, Sections II.A.27 and 44) for VOC or NOX or a modification which is major by itself (Potential to Emit > 50 tons/year of either VOC or NOX) may result in the application of the NANSR review requirements. 4. Summary of Emission Units a. The emission units regulated by this permit are the following: 4.4 COLORADO Air Pollution Control Division Department of Public Health b Environment Page 5 of 41 DRAFT Emission Unit No./Facility ID. AIRS Point Number Description Startup Date Pollution Control Device T002 004 General Electric Combustion Turbine, Model No. GE Frame 7FA, Serial No. 299480, rated at 1,899 MMBtu/hr (turbine 1,477 MMBtu/hr and duct burner 422 MMBtu/hr), Natural Gas Fired. Turbine May be Operated in Conjunction with a HRSG (combined cycle operation) Equipped with Natural Gas Fired Duct Burners. February 1996 (simple cycle operation) March 1998 (combined cycle operation) Turbine was modified Spring 2022 (Triggered NSPS KKKK) Dry Low NOx Burners & SCR T003 005 General Electric Combustion Turbine, Model No. GE Frame 7FA, Serial No. 297096, rated at 1,834 MMBtu/hr (turbine 1,412 MMBtu/hr and duct burner 422 MMBtu/hr), Natural Gas Fired. Turbine May be Operated in Conjunction with a HRSG (combined cycle operation) Equipped with Natural Gas Fired Duct Burners. January 1999 (simple cycle operation) April 1999 (combined cycle operation) Turbine was modified Fall 2021 (triggered NSPS KKKK) Dry Low NOx Burners ISO COLORADO Air Pollution Control Division Department of Public Health h Environment Page 6 of 41 DRAFT Section II — Specific Permit Terms 1. T002 & T003 — Two (2) Combustion Turbines Capable of Simple or Combined Cycle Operation Simple Cycle - Two (2) Combustion Turbines Combined Cycle (No Supplemental Fuel) - Two (2) Combustion Turbines & Two (2) Heat Recovery Steam Generators (HRSG) with No Fuel Fired in Duct Burners Combined Cycle (With Supplemental Fuel) — Two (2) Combustion Turbines & Two (2) Heat Recovery Steam Generators (HRSG) with Fuel Fired in Duct Burners Unless otherwise specified, the limitations identified are per combustion turbine/HRSG Parameter Permit Condition Number Limitations Short Term Limitations Long Term Compliance Emission Factor Monitoring Method Monitoring Interval BACT Requirements 1.1 N/A N/A N/A See Condition 1.1 See Condition 1.1 NOx 1.2 Simple Cycle Mode or Combined Cycle Mode — No Supplemental Fuel: 15 ppmvd @ 15%O2 on a 1 -hr average, except as provided for below During Startup and Shutdown: 100 ppmvd @ 15% O2 on a 1 -hr average During Combustion Tuning and Testing (not to exceed 90 hrs/yr for turbines T002, T003 & T004 combined): 100 ppmvd @ 15% O2 on a 1 -hr average Combined Cycle Mode — With Supplemental Fuel: 17 ppmvd @ 15% O2 on a 1 -hr average, except as provided for below During Startup and Shutdown: 100 ppmvd @ 15% O2 on a 1 -hr average During Combustion Tuning and Testing (not to exceed 90 hrs/yr for turbines T002, T003 & T004 combined): See Short Term Limitations, AIRS Point 004 (Turbine 2) is limited by 85.01 tons/yr AIRS Point 005 (Turbine 3) is limited by 496.1 tons/yr N/A Continuous Emission Monitoring System Continuously COLORADO Air Pollution Control Division Department of Public Health fr Hm onment. Page 7 of 41 DRAFT Parameter Permit Condition Number Limitations Short Term Limitations Long Term Compliance Emission Factor Monitoring Method Monitoring Interval 100 ppmvd @ 15% O2 on a 1 -hr average On and After Modifications Applies to Both Simple and Combined Cycle Modes: 15 ppm @ 15% O2, except as provided for below: 96 ppm @ 15% O2 when operating at less than 75% of peak load 96 ppm @ 15% O2 when operating at temperatures less than 0°F Averaging time is 30 -day rolling. For periods when multiple standards apply, the applicable standard is the average of applicable standards CO 1.3 Simple Cycle Mode or Combined Cycle Mode — No Supplemental Fuel: 15 ppmvd @ 15% O2 on a 1 -hr average, except as provided for below During Startup and Shutdown: 1000 ppmvd @ 15% O2 on a 1 -hr average and 2,060 Ibs/hr During Combustion Tuning and Testing (not to exceed 90 hrs/yr for turbines T002, T003 & T004 combined): 1000 ppmvd @ 15% O2 on a 1 -hr average and 2,060 Ibs/hr Combined Cycle Mode — With Supplemental Fuel: 48 ppmvd @ 15% O2 on a 1 -hr average, except as provided for below During Startup and Shutdown: 1000 ppmvd @ 15% O2 on a 1 -hr average and 2,060 Ibs/hr During Combustion Tuning and Testing (not to exceed 90 hrs/yr for turbines T002, T003 & T004 combined): 1000 ppmvd @ 15% O2 on a 1 -hr average and 2,060 Ibs/hr See Short Term Limitations, Also limited by 465.4 tons/yr N/A Continuous Emission Monitoring System Continuously COLORADO Air Pollution Control Division Department of Public Health fr. Famronment Page 8 of 41 DRAFT Parameter Permit Condition Number Limitations Short Term Limitations Long Term Compliance Emission Factor Monitoring Method Monitoring Interval SO2 1.4 For Each Combustion Turbine: 0.35 Ibs/MMBtu, on a 3 -Hour Rolling Average On and After Modifications: For Each Combustion Turbine and Duct Burner: 0.06 Ib/MMBtu See Short Term Limitations, Also limited by 4.7 tons/yr N.A Fuel Restriction & Continuous Monitoring System Only Pipeline Quality Natural Gas is Used as fuel & Continuously VOC 1.5 Simple Cycle and Combined Cycle — No Supplemental Fuel: 1.4 ppmvd @ 15% O2, on a 1 -Hour Average Combined Cycle — With Supplemental Fuel: 1.7 ppmvd @ 15% O2, on a 1 -Hour Average See Short Term Limitations, Also limited by 21.4 tons/yr N/A Continuous Monitoring System Continuously PM 1.6 For Each Combustion Turbine: 0.1 Ibs/MMBtu, the average of three (3) 1 -hr tests For Each Combustion Turbine and Duct Burner Together: 0.1 Ibs/MMBtu, the average of three (3) 1 -hr tests See Short Term Limitations, Also limited by 39.4 tons/yr See Condition 1.6 Recordkeeping Calculation and Compliance Testing Monthly, Every Five (5) Years PM10 1.7 9 Ibs/hr 39.4 tons/yr See Condition 1.7 Recordkeeping Calculation and Compliance Testing Monthly, Every Five (5) Years Natural Gas Usage 1.8 N/A For AIRS Point 004 (Turbine 002): 10,899.75 MMscf/yr. For AIRS Point 005 (Turbine 003): Simple Cycle and/or Combined Cycle Without Supplemental Fuel: N/A Recordkeeping Monthly COLORADO Air Pollution Control Division Department of Public Health 6 Environment Page 9 of 41 DRAFT Parameter Permit Condition Number Limitations Short Term Limitations Long Term Compliance Emission Factor Monitoring Method Monitoring Interval 12,507 M Mscf/yr Combined Cycle With Supplemental Fuel: 16,090 M Mscf/yr Sulfur Content of Natural Gas 1.9 N/A N/A N/A See Condition 1.9 See Condition 1.9 Continuous Emission Monitoring System Requirements 1.10 N/A N/A N/A See Condition 1.10 See Condition 1.10 Fuel Flow Meter 1.11 N/A N/A N/A See Condition 1.11 See Condition 1.11 NSPS General Provisions 1.12 N/A N/A N/A As Required by NSPS General Provisions As Required by NSPS General Provisions Performance Test Requirements 1.13 N/A N/A N/A EPA Reference Method See Condition 1.13 Opacity— State Only 1.14 Not to Exceed 20% See Short Term Limitations N/A Fuel Restriction Only Pipeline Quality Natural Gas is Used as Fuel Opacity 1.15 Not to Exceed 20% Except as Provided for in 1.16 Below See Short Term Limitations N/A Fuel Restriction Only Pipeline Quality Natural Gas is Used as Fuel Opacity 1.16 For Certain Operational Activities — Not to Exceed 30%, for a Period of Periods Aggregating More than Six (6) Minutes in any 60 Consecutive Minutes See Short Term Limitations N/A Fuel Restriction Only Pipeline Quality Natural Gas is Used as Fuel Regulation No. 26, Part B, Section II.A Requirements 1.17 NOX Emissions from Each Turbine Not to Exceed: When burning natural gas (NG): 15 ppm @ 15% O2 When operating at < 75% peak load: 96 ppm @ 15% O2 When operating at temperatures < 0°F: 96 ppm @ 15% O2 See Short Term Limitations N/A Continuous Emission Monitoring System for Nox Emission & Calculation & See Condition 1.18 Continuously For NOx Emissions and Annually (Calendar Year) for Maintain Records of Capacity Factor COLORADO Air Pollution Control Division Department of Public Health b Environment Page 10 of 41 DRAFT Parameter Permit Condition Number Limitations Short Term Limitations Long Term Compliance Emission Factor Monitoring Method Monitoring Interval Compliance is based on a 30 -day rolling average as noted in Condition 1.18.3.1.d Maintain Records of Capacity Factor Combustion Process Adjustment and Recordkeeping Requirements NSPS Subpart KKKK General Requirements 1.18 See Condition 1.19 See Short Term Limitations N/A See Condition 1.19 See Condition 1.19 1.1 These combustion turbines/HRSGs/duct burners are subject to the requirements of the Prevention of Significant Deterioration (PSD) Program. 1.1.1 Best Available Control Technology (BACT) shall be applied for control of Nitrogen Oxides (NOX), Carbon Monoxide (CO), Volatile Organic Compounds (VOC) and Particulate Matter (PM and PM10). BACT has been determined as follows: 1.1.1.1 BACT for NOX has been determined to be Dry Low NOX (DLN) Combustion Systems with emission limits. The DLN combustion systems shall be operated and maintained in accordance with manufacturer's recommendations and good engineering practices. 1.1.1.2 BACT for CO has been determined to be good combustion practices/monitoring systems capable of meeting the emission limitations in Condition 1.3.1 1.1.1.3 BACT for VOC has been determined to be good combustion practices/monitoring systems capable of meeting the emission limitations in Condition 1.5.1 1.1.1.4 BACT for PM and PM10 has been determined to be use of pipeline quality natural gas. 1.2 Nitrogen Oxide (NOX) emissions shall not exceed the following limitations: 1.2.1 The BACT emission limits for each combustion turbine/HRSG/duct burner are as follows: 1.2.1.1 Except as provided for in Conditions 1.2.1.3 and 1.2.1.4 below, emissions of NOX shall not exceed 15 ppmvd at 15 % O2, on a 1 -hour average. This standard applies when operating in either simple cycle mode or combined cycle mode without supplemental fuel. 1.2.1.2 Except as provided for in Conditions 1.2.1.3 and 1.2.1.4 below, emissions of NOX shall not exceed 17 ppmvd at 15 % O2, on a 1 -hour average. This standard applies when operating in combined cycle mode with supplemental fuel. COLORADO Air Pollution Control Division Department of Public Health 6 Environment Page 11 of 41 DRAFT 1.2.1.3 During periods of startup and shutdown emissions of NOX shall not exceed 100 ppmvd at 15% O2, on a 1 -hr average. 1.2.1.4 During periods of combustion tuning and testing emissions of NOX shall not exceed 100 ppmvd at 15% O2, on a 1 -hour average. Use of this NOX emission limit for purposes of combustion tuning and testing shall not exceed 90 hours in any calendar year for turbines T002, T003 and T004 combined. Records of the number of hours each turbine undergoes combustion tuning and testing shall be recorded and maintained and made available to the Division upon request. 1.2.1.5 "Startup" means the setting in operation of any air pollution source for any purpose. Setting in operation for this turbine begins when fuel is first combusted in the turbine or when commencing a combined cycle startup from simple cycle operation (turbine drops out of L30 -Out combustion configuration) and ends 30 minutes after the turbine clears L30 -Out. L30 -Out refers to the condition where the unit is operating above the emissions compliance combustion reference temperature (CRT) curve and the L52G breaker is closed. The station control system and the unit's data acquisition and handling system (DAHS) utilized by the continuous emission monitoring systems indicates which mode the turbine is operating in. A record of when L30 -Out combustion configuration plus 30 minutes is achieved is stored in the unit's DAHS. 1.2.1.6 "Shutdown" means the cessation of operation of any air pollution source for any purpose. The cessation of operation for these turbines begins when the command signal is initiated to shutdown the unit and ends when fuel is no longer being fired in the turbine. 1.2.1.7 "Combustion Tuning and Testing" means the operation of the unit for the purpose of performing combustion tuning and testing operations after a unit overhaul or as part of routine maintenance operations. Combustion tuning and testing can occur throughout the range of the operating conditions. Compliance with these NOX limitations shall be monitored using the continuous emission monitoring system (CEMS) required by Condition 1.10, as follows: 1.2.1.8 Except as provided for in Condition 1.2.1.10, all valid CEMS concentration (ppm) data points, excluding startup and shutdown data points shall, at the end of each clock hour, be summarized to generate the one -flour average NOX concentration in accordance with the requirements in 40 CFR Part 75 and Condition 5.2.1.3.b of this permit. Data used to generate the one -hour average NOX concentration shall not include replaced data, nor shall the data be bias - adjusted. Replaced data shall be reported as monitor down time in the quarterly reports required by Condition 5.5. Each clock hour average NOX concentration shall be compared to the limitations in Conditions 1.2.1.1, 1.2.1.2 or 1.2.1.4, as appropriate. COLORADO Air Pollution Control Division Department of Puhlk Health ft Environment Page 12 of 41 DRAFT 1.2.1.9 All valid CEMS concentration (ppm) data points, excluding non -startup and non - shutdown data points shall, at the end of each clock hour be summarized to generate the average NOX concentration in accordance with the requirements in 40 CFR Part 75 and Condition 5.2.1.3.b of this permit. Data used to generate the average NOX concentration shall not include replaced data, nor shall the data be bias -adjusted. Replaced data shall be reported as monitor down time in the quarterly reports required by Condition 5.5. Each clock hour average NOX concentration shall be compared to the limitation in Condition 1.2.1.3. In the event that the startup ends within a clock hour or the shutdown begins within a clock hour, all non -startup and/or non -shutdown concentration (ppm) data points within that clock hour shall be averaged together to generate the average NOX concentration in accordance with the requirements in 40 CFR Part 75 and Condition 5.2.1.3.b of this permit and that average concentration shall be compared to the limitations in Conditions 1.2.1.1, 1.2.1.2 or 1.2.1.4, as appropriate. 1.2.1.10 The emission limitation in Condition 1.2.1.4 applies to any clock hour in which combustion tuning and testing activities occur. 1.2.1.11 The emission limitation in Condition 1.2.1.2 applies to any clock hour in which fuel is fired in the duct burner. 1.2.2 For purposes of 40 CFR Part 60 Subpart KKKK, NOX emissions from each combustion turbine/HRSG/duct burner are subject to the following requirements: The requirements in this Condition 1.2.2, as well as Conditions 1.4.4 and 1.19 reflect the rule language in 40 CFR Part 60 Subpart KKKK as of the latest revisions to 40 CFR Part 60 Subpart KKKK published in the Federal Register on March 20, 2009 (including the revisions to test methods published October 7, 2020). However, if revisions to this Subpart are promulgated at a later date, the owner or operator is subject to the requirements contained in the revised version of 40 CFR Part 60 Subpart KKKK. Please note that proposed revisions to 40 CFR Part 63 Subpart KKKK were published in the Federal Register on August 29, 2012 to address a petition for reconsideration filed by the Utility Air Regulatory Group (UARG) on September 5, 2006 regarding the July 2006 final rule and to address other technical and editorial issues. Therefore, the requirements below may change in the future. You must meet the emission limits for NOX specified in Table 1 to this subpart. (§ 60.4320(a)). The requirements in Table 1 that apply to these units are as follows: 1.2.2.1 Except as provided for below, NOX emissions shall not exceed 15 ppm at 15 % O2. COLORADO Air Pollution Control Division Department of Public Health b Environment Page 13 of 41 DRAFT 1.2.2.2 When operating at less than 75% of the peak load, NOX emissions shall not exceed 96 ppm at 15% O2. 1.2.2.3 When operating at temperatures less than on 0 °F, NOX emissions shall not exceed 96 ppm at 15% O2. 1.2.2.4 For operating periods during which multiple emissions standards apply, the applicable standard is the average of the applicable standards during each hour. For hours with multiple emissions standards, the applicable limit for that hour is determined based on the condition that corresponded to the highest emissions standard. (§ 60.4380(b)(3)) Note that the NOX emission limits in this Condition 1.2.2 are not applicable during times of startup, shutdown and malfunction. However, those instances during startup, shutdown and malfunction when the NOX limitation is exceeded shall be identified in the excess emission reports required by Condition 5.5. Compliance with the above NSPS KKKK NOX emission shall be monitored using the continuous emission monitoring systems (CEMS) required by Condition 1.10, as follows: 1.2.2.5 All CEMS data must be reduced to hourly averages as specified in §60.13(h). (60.4350(a)) 1.2.2.6 For each unit operating hour in which a valid hourly average, as described in §60.4345(b), is obtained for both NOX and diluent monitors, the data acquisition and handling system must calculate and record the hourly NOX emission rate in units of ppm or Ib/MMBtu, using the appropriate equation from method 19 in appendix A of this part. For any hour in which the hourly average O2 concentration exceeds 19.0 percent O2 (or the hourly average C02 concentration is less than 1.0 percent C02), a diluent cap value of 19.0 percent O2 or 1.0 percent C02 (as applicable) may be used in the emission calculations. (60.4350(b)) 1.2.2.7 If you have installed and certified a NOX diluent CEMS to meet the requirements of part 75 of this chapter, states can approve that only quality assured data from the CEMS shall be used to identify excess emissions under this subpart. Periods where the missing data substitution procedures in subpart D of part 75 are applied are to be reported as monitor downtime in the excess emissions and monitoring performance report required under §60.7(c). (60.4350(d)) 1.2.2.8 Calculate the hourly average NOX emission rates, in units of the emission standards under §60.4320, using either ppm for units complying with the concentration limit or the equations in §60.4350(f) for units complying with the output based standard. (60.4350(f)) SG COLORADO Air Pollution Control Division Department of Public Health Er Environment Page 14 of 41 DRAFT 1.2.2.9 For combined cycle and combined heat and power units with heat recovery, use the calculated hourly average emission rates from 60.4350(f) to assess excess emissions on a 30 unit operating day rolling average basis, as described in §60.4380(b)(1). (60.4350(h)) 1.2.2.10 Further provisions regarding reporting excess emissions are provided for in Condition 5.6.3. Initial Performance Test Requirements 1.2.2.11 If you elect to install a CEMS, the performance evaluation of the CEMS may either be conducted separately or (as described in §60.4405) as part of the initial performance test of the affected unit. (60.4400(b)(5)) 1.2.2.12 If you elect to install and certify a NOX-diluent CEMS under §60.4345, then the initial performance test required under §60.8 may be performed in the following alternative manner (60.4405): a. Perform a minimum of nine RATA reference method runs, with a minimum time per run of 21 minutes, at a single load level, within plus or minus 25 percent of 100 percent of peak load. The ambient temperature must be greater than 0 °F during the RATA runs. (60.4405(a)) b. For each RATA run, concurrently measure the heat input to the unit using a fuel flow meter (or flow meters) and measure the electrical and thermal output from the unit. (60.4405(b)) c. Use the test data both to demonstrate compliance with the applicable NOX emission limit under §60.4320 and to provide the required reference method data for the RATA of the CEMS described under §60.4335. (60.4405(c)) d. Compliance with the applicable emission limit in §60.4320 is achieved if the arithmetic average of all of the NOX emission rates for the RATA runs, expressed in units of ppm or Ib/MWh, does not exceed the emission limit. (60.4405(d)) 1.2.3 Nitrogen Oxide (NOX) emissions from AIRS point 004 (T002) shall not exceed 85.01 tons/yr while Nitrogen Oxide (NOX) emissions from AIRS point 005 (T003) shall not exceed 496.1 tons/yr. Compliance with annual emission limitation shall be monitored using the Continuous Emission Monitoring System (CEMS) required by Condition 1.10. For any hour in which fuel is combusted in the turbines, including periods of startup, shutdown and malfunction, the permittee shall program the DAHs to calculate lb/hr NOX emissions in accordance with the requirements in Condition 5.2.1.3.b of this permit and 40 CFR Part 75, including any replaced data and the data shall be bias -adjusted, if warranted. Ate COLORADO Air Pollution Control Division Department of Public Health b Environment Page 15 of 41 DRAFT For AIRS point 004 (T002), the rolling twelve (12) -month emission total for compliance with annual process limits shall be restarted post SCR installation and operation. Therefore, SCR installation and operation will mark the separation of the previous rolling twelve (12) -month emission total record and will begin a new rolling twelve (12) -month emission total. The previous rolling twelve (12) -month emission total will not include any months post SCR installation and operation. Historical records of pre -SCR emission records must still be maintained to ensure compliance with previous emission limits that were pre -SCR installation and operation. Airs Point 004 shall have an SCR (selective catalytic reduction) to reduce the NOX emissions. The SCR must be maintained and operated to ensure satisfactory performance. The owner or operator must monitor compliance with this condition through the results of approved compliance tests (when required), compliance with the Operating and Maintenance Plan, compliance records, and other methods as approved by the Division. (Reference: Regulation Number 3, Part B, Section III.E.) Specifically hourly mass NOX emissions (in lb/hr) shall be calculated by multiplying the hourly NOX Ib/MMBtu value (which includes replaced or bias -adjusted data, as applicable) by the hourly heat input value (MMBtu/hr) (which includes replaced data from the fuel flow measurement, as applicable). The hourly NOX Ib/MMBtu and heat input values shall be determined using equations F-5 or F-6, as appropriate for the diluent monitored by the CEMS and F-20 in Appendix F of 40 CFR Part 75. The resulting NOX lb/hr value is then multiplied by the unit operating time for that hour to produce a NOX Ibs value. Hourly NOX mass emissions (lbs) shall be summed and divided by 2000 lb/ton to determine monthly NOX emissions (in tons). Monthly emissions (in tons) from each combustion turbine/HRSG/duct burner shall be used in a twelve month rolling total of emissions to monitor compliance with the annual emission limitation. Each month a new twelve month total shall be calculated using the previous twelve months data. 1.3 Carbon Monoxide (CO) emissions shall not exceed the following limitations: 1.3.1 The BACT Carbon Monoxide (CO) emission limit for each combustion turbine/HRSG/duct burner is as follows: 1.3.1.1 Except as provided for in Conditions 1.3.1.3 and 1.3.1.4 below, emissions of CO shall not exceed 15 ppmvd at 15% O2, on a 1 -hour average. This standard applies when operating in either simple cycle mode or combined cycle mode without supplemental fuel. �4 COLORADO Air Pollution Control Division Department of Pal. He. b Environment Page 16 of 41 DRAFT 1.3.1.2 Except as provided for in Conditions 1.3.1.3 and 1.3.1.4 below, emissions of CO shall not exceed 48 ppmvd at 15% O2, on a 1 -hour average. This standard applies when operating in combined cycle mode with supplemental fuel. 1.3.1.3 During periods of startup and shutdown emissions of CO shall not exceed 1,000 ppmvd at 15% O2, on a 1 -hr average and 2,060 Ibs/hr. In the event that emissions of CO exceed 1,000 ppmvd at 15% O2, it shall be considered a violation of the CO BACT emission limit if CO emissions exceed 2,060 Ibs/hr and not a violation if emissions are less than or equal to 2,060 Ibs/hr. 1.3.1.4 During periods of combustion tuning and testing emissions of CO shall not exceed 1,000 ppmvd at 15% O2, on a 1 -hour average and 2,060 Ibs/hr. In the event that emissions of CO exceed 1,000 ppmvd at 15% O2, it shall be considered a violation of the CO BACT emission limit if CO emissions exceed 2,060 Ibs/hr and not a violation if emissions are less than or equal to 2,060 Ibs/hr. Use of this CO emission limit for purposes of combustion tuning and testing shall not exceed 90 hours in any calendar year for turbines T002, T003 and T004 combined. Records of the number of hours each turbine undergoes combustion tuning and testing shall be recorded and maintained and made available to the Division upon request. 1.3.1.5 "Startup" shall have the same definitions as provided for in Conditions 1.2.1.5 and 1.2.1.6. 1.3.1.6 "Shutdown" shall have the same definition as provided for in Condition 1.2.1.7. 1.3.1.7 "Combustion Tuning and Testing" shall have the same definition as provided for in Condition 1.2.1.8. Compliance with these CO limitations shall be monitored using the continuous emission monitoring system (CEMS) required by Condition 1.10, as follows: 1.3.1.8 Except as provided for in Condition 1.3.1.9, all valid CEMS concentration (ppm) data points, excluding startup and shutdown data points shall, at the end of each clock hour be summarized to generate the average CO concentration in accordance with the requirements in 40 CFR Part 75 and Condition 5.2.1.3.b of this permit. Data used to generate the one - hour average CO concentration shall not include replaced data. Replaced data shall be reported as monitor down time in the quarterly reports required by Condition 5.5. Each clock hour average CO concentration shall be compared to the limitations in Conditions 1.3.1.1, 1.3.1.2 or 1.3.1.4, as appropriate. COLORADO Air Pollution Control Division Department of Public Health 6 Emnronment Page 17 of 41 DRAFT 1.3.1.9 All valid CEMS concentration (ppm) data points, excluding non -startup and non -shutdown data points shall, at the end of each clock hour be summarized to generate the average CO concentration in accordance with the requirements in 40 CFR Part 75 and Condition 5.2.1.3.b of this permit. Data used to generate the average CO concentration shall not include replaced data. Replaced data shall be reported as monitor down time in the quarterly reports required by Condition 5.5. Each clock hour average CO concentration shall be compared to the limit in Condition 1.3.1.3. In the event that a startup ends within a clock hour or shutdown begins within a clock hour, all non -startup and/or non -shutdown concentration (ppm) data points within that clock hour shall be averaged together to generate the average CO concentration in accordance with the requirements in 40 CFR Part 75 and Condition 5.2.1.3.b of this permit and that average concentration shall be compared to the limitations in Conditions 1.3.1.1, 1.3.1.2 or 1.3.1.4, as appropriate. 1.3.1.10 The emission limitation in Condition 1.3.1.4 applies to any clock hour in which combustion tuning and testing activities occur. 1.3.1.11 The emission limitation in Condition 1.3.1.2 applies to any clock hour in which fuel is fired in the duct burner. 1.3.2 Carbon Monoxide (CO) emissions from each combustion turbine/HRSG/duct burner shall not exceed 465.4 tons/yr. Compliance with this requirement shall be monitored using the Continuous Emission Monitoring System (CEMS) required by Condition 1.10. For any hour in which fuel is combusted in the turbines, including periods of startup, shutdown and malfunction, the permittee shall program the DAHs to calculate lb/hr CO emissions in accordance with the requirements in Condition 5.2.1.3.b of this permit and 40 CFR Part 75, including any replaced data, if warranted. Specifically hourly mass CO emissions (in lb/hr) shall be calculated by multiplying the hourly CO Ib/MMBtu value (which includes replaced date in accordance with the provisions in Part 75 for NOX replacement, as applicable) by the hourly heat input value (MMBtu/hr) (which indudes replaced data from the stack flow measurement, as applicable). The hourly CO Ib/MMBtu and heat input values shall be determined using equations F-5 or F-6 (for NOX), as appropriate for the diluent monitored by the CEMS and F-20 in Appendix F of 40 CFR Part 75. The resulting CO lb/hr value is then multiplied by the unit operating time for that hour to produce a CO Ibs value. Hourly CO mass emissions (lbs) shall be summed and divided by 2000 lb/ton to determine monthly CO emissions (in tons). Monthly emission (in tons) from each combustion turbine/HRSG/duct burner shall be used in a twelve month rolling total of emissions will be maintained to COLORADO Air Pollution Control Division Department of Public Health 6 Enwonment Page 18 of 41 DRAFT monitor compliance with the annual emission limitation. Each month a new twelve month total shall be calculated using the previous twelve months data. 1.4 Sulfur Dioxide (S02) emissions shall not exceed the following limitations: 1.4.1 Sulfur Dioxide (S02) emissions from each combustion turbine shall not exceed 0.35 Ibs/MMBtu, on a 3 -hour rolling average (Colorado Regulation No. 1, Section VI.B.4.c.(ii) and VI.B.2). In the absence of credible evidence to the contrary, compliance with the sulfur dioxide limitation is presumed since only pipeline quality natural gas is permitted to be used as fuel in the turbines. In the absence of credible evidence to the contrary, compliance with the above requirements is presumed since only pipeline quality natural gas is permitted to be used as fuel. The natural gas used as fuel shall meet the requirements in Condition 1.9. 1.4.4 For purposes of 40 CFR Part 60 Subpart KKKK, the combustion turbine/HRSG/duct burner is subject to the following requirements: If your turbine is located in a continental area, you must comply with either 60.4330(a)(1), (a)(2), or (a)(3). (60.4330(a)) You must not burn in the subject stationary combustion turbine any fuel which contains total potential sulfur emissions in excess of 26 ng S02/J (0.060 lb S02/MMBtu) heat input. If your turbine simultaneously fires multiple fuels, each fuel must meet this requirement. (60.4330(a)(2)) In the absence of credible evidence to the contrary, compliance with the fuel gas sulfur limit is presumed since only pipeline quality natural gas is permitted to be used as fuel in the turbine. The natural gas used as fuel shall meet the requirements in Condition 1.9. 1.4.5 Sulfur Dioxide (S02) emissions from each combustion turbine/HRSG/duct burner shall not exceed 4.7 tons/yr. Compliance with the annual limitation shall be monitored using the continuous monitoring system required by 40 CFR Part 75, as adopted by reference in Colorado Regulation No. 18. A twelve month rolling total of emissions will be maintained to monitor compliance with the annual emission limitation. Each month a new twelve month total shall be calculated using the previous twelve months data. 1.5 Volatile Organic Compound (VOC) emissions shall not exceed the following limitations: 1.5.1 The BACT Volatile Organic Compound (VOC) emission limit for each combustion turbine/HRSG/duct burner is as follows: tag COLORADO Air Pollution Control Division Department of Public Health 6 Environment Page 19 of 41 DRAFT 1.5.1.1 Emissions of VOC shall not exceed 1.4 ppmvd at 15% O2, on a 1 -hour average. This standard applies when operating in either simple cycle mode or combined cycle mode without supplemental fuel. 1.5.1.2 Emissions of VOC shall not exceed 1.7 ppmvd at 15% O2, on a 1 -hour average. This standard applies when operatitg in combined cycle mode with supplemental fuel. Compliance with the VOC limitations shall be monitored using the VOC correlation (VOC emissions vs. heat input) that has been approved by the Division and programmed into the data acquisition and handling system (DAHS). The data in the DAHS shall at the end of each hour, be summarized to generate the average VOC concentration. The emission limits in Condition 1.5.1.2 apply to any clock hour in which fuel is fired in the duct burner. The equations used in the VOC correlation are included in Appendix G of this permit. 1.5.2 Volatile Organic Compounds emissions from each combustion turbine/HRSG/duct burner shall not exceed 21.4 tons/yr. Compliance with the VOC limitation shall be monitored using the VOC correlation (VOC emissions vs. heat input) that has been approved by the Division and programmed into the data acquisition and handling system (DAHS). The equations used in the VOC correlation are included in Appendix G of this permit. A twelve month rolling total of emissions will be maintained to monitor compliance with the annual emission limitations. Each month a new twelve month total shall be calculated using the previous twelve months data. 1.6 Particulate Matter (PM) emissions shall not exceed the following limitations: 1.6.1 Particulate Matter (PM) emissions from each combustion turbine shall not exceed 0.1 Ibs/MMBtu, the average of three (3) 1 -hr tests (Colorado Regulation No. 1, Section III.A.1.c). In the absence of credible evidence to the contrary, compliance with the particulate matter limitation is presumed since only pipeline quality natural gas is permitted to be used as fuel in the turbines. 1.6.2 Particulate Matter (PM) emissions from each combustion turbine and duct burner together shall not exceed 0.1 Ibs/MMBtu, the average of three (3) 1 -hr tests (Colorado Regulation No. 1, Sections II.A.1.b, c and d). In the absence of credible evidence to the contrary, compliance with the particulate matter limitation is presumed since only pipeline quality natural gas is permitted to be used as fuel in the turbines and duct burners. Note that the numeric PM standards for combined cycle operation were determined using the design heat input for the turbines (1,323 MMBtu/hr for Turbine 2 and 1,373 MMBtu/hr for Turbine 3) and duct burners (each 450 MMBtu) in the following equation: a to COLORADO Air Pollution Control Division Department of Public Health b Emnronmenc Page 20 of 41 DRAFT PE (turbine + duct burner) = PET x FIT+ PEDB x FIDB FIT+ FIDB Where PE = particulate standard in Ibs/MMBtu PEDB = 0.5 x (F0-0.26 Ibs/MMBtu PET = 0.1 Ibs/MMBtu Fl = fuel input in MMBtu/hr 1.6.3 Particulate Matter (PM) emissions from each combustion turbine/HRSG/duct burner shall not exceed 39.4 tons/yr. The annual emission limitation includes both filterable and condensable particulate matter. Compliance with this limitation shall be monitored as follows: 1.6.3.1 Monthly emissions of PM shall be calculated using the emission factors identified in the table below in the following equation: Unit Emission Factor (Ib/MMBtu) for PM Emission Factor (Ib/MMBtu) for PM10 Source of Emission Factor Unit 2 —Simple Cycle 0.003 0.003 February 28, 2019 Unit 2 —Combined Cycle 0.004 0.004 February 26 & 27, 2019 Unit 3- Simple Cycle 0.002 0.002 March 6, 2019 Unit 3 — Combined Cycle 0.002 0.002 March 5. 2019 Tons/month = (EF (Ibs/MMBtu) x monthly heat input to turbine (MMBtu/mo)l 2000 Ibs/to n The monthly heat input to the turbine/HRSG/duct burner shall be determined using the data acquisition and handling system (DAHS) for the CEMS required by Condition 1.10. A twelve month rolling total of emissions will be maintained to monitor compliance with the annual emission limitation. Each month a new twelve month total shall be calculated using the previous twelve months data. 1.6.3.2 Performance testing shall be conducted in accordance with the requirements in Condition 1.13. 1.7 Particulate Matter less than 10 microns (PM10) emissions from each combustion turbine/HRSG/duct burner shall not exceed 9 Ibs/hr and 39.4 tons/yr. The hourly and annual emission limitations include both filterable and condensable particulate matter. Compliance with these limitations shall be monitored as follows: 1.7.1 Monthly emissions of PM10 shall be calculated using the emission factors identified in the table in Condition 1.6.3.1 in the following equation: Tons/month = (EF (Ibs/MMBtu) x monthly heat input to turbine (MMBtu/mo)l COLORADO Air Pollution Control Division Department of Pub. Health b Environment. Page 21 of 41 DRAFT 2000 Ibs/ton The monthly heat input to the turbine/duct burner shall be determined using the data acquisition and handling systems (DAHS) for the CEMS required by Condition 1.10. A twelve month rolling total of emissions will be maintained to monitor compliance with the annual emission limitations. Each month a new twelve month total shall be calculated using the previous twelve months data. Compliance with the hourly limitation shall be monitored by dividing the monthly emissions by the number of hours operated each month. 1.7.2 Performance testing shall be conducted in accordance with the requirements in Condition 1.13. 1.8 Natural Gas Consumption for each T002 (AIRS 004) turbine/HRSG/duct burner shall not exceed the following limitations: 1.8.1 The total fuel consumption shall not exceed exceed 10,889.75 MMscf/yr. Natural Gas Consumption for each T003 (AIRS 005) turbine/HRSG/duct burner shall not exceed the following limitations: 1.8.2 When operating in either simple cycle mode or combined cycle mode without supplemental fuel natural gas consumption shall not exceed 12,507 MMscf/yr. 1.8.3 When operating in combined cycle mode with supplemental fuel natural gas consumption shall not exceed 16,090 MMscf/yr. The natural gas consumption for each combustion turbine/duct burners shall be monitored using the data acquisition and handling systems (DAHS) for the continuous emission monitoring system (CEMS) required by Condition 1.10. Monthly natural gas consumption from each turbine/duct burner shall be used in rolling twelve month total to monitor compliance with the annual natural gas consumption limitations. Each month a new twelve month total shall be calculated using the previous twelve months data. Note that if any time during the 12 -month rolling period natural gas has been fired in the duct burners, the 16,090 MMscf/yr natural gas consumption limit shall apply for T003 (AIRS 005), while the 10,889.75 MMscf/yr natural gas consumption limit shall continue to apply for T002 (AIRS 004). The permitteee shall maintain records of the operating mode (simple cycle or combined cycle without fuel fired in the duct burners versus combined cycle with fuel fired in the duct burners) of each turbine/HRSG/duct burner. 1.9 The permittee shall maintain records demonstrating that the natural gas burned has a total sulfur content less than 0.5 grains/100 SCF. Natural gas that meets this sulfur limitation is considered pipeline quality natural gas as defined in 40 CFR Part 72. The demonstration shall be made using any of the methods identified in 40 CFR Part 75 Appendix D, Section 2.3.1.4.(a). These records shall be made available to the Division upon request. 1.10 For each combustion turbine/HRSG/duct burner, continuous emission monitoring systems (CEMS) shall be installed, certified, calibrated, maintained and operated for measuring NOX (including diluent gas either C02 or O2) and CO emissions. The CEMS shall meet the COLORADO Air Pollution Control Division Department of Public Health b Ermronment Page 22 of 41 DRAFT requirements in Condition 5 of this permit. Monthly emissions of NOX and CO from the continuous emission monitoring system shall be used as specified by Conditions 1.2.3 and 1.3.2 to monitor compliance with the annual NOX and CO emission limitations. 1.11 Each turbine/HRSG/duct burner shall be equipped with an in -line fuel flow meter that meets the requirements in 40 CFR Part 75 Appendix D to measure fuel combusted in each turbine. Fuel flow data shall be recorded on a data acquisition and handling system as specified in 40 CFR Part 75 Appendix D. 1.12 These combustion turbines/HRSGs/duct burners are subject to 40 CFR Part 60, Subpart A - General Provisions, as adopted by reference in Colorado Regulation No. 6, Part A. Specifically, these units are subject to the following requirements: 1.12.1 No owner or operator subject to the provisions of this part shall build, erect, install, or use any article, machine, equipment or process, the use of which conceals an emission which would otherwise constitute a violation of an applicable standard. Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance with an opacity standard or with a standard which is based on the concentration of a pollutant in the gases discharged to the atmosphere. 1.12.2 At all times, including periods of startup, shutdown, and malfunction owners and operators shall to the extent practicable, maintain and operate any affected facility including associated air pollution control equipment in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Division which may include, but is not limited to monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. 1.13 The source shall conduct compliance tests for each combustion turbine/HRSG/duct burner, when operating in simple cycle mode and combined cycle mode with supplemental fuel every five (5) years to monitor compliance with the PM and PM10 emission limitations in Conditions 1.6.3 and 1.7. The compliance tests shall be conducted in accordance with the requirements of 40 CFR Part 60 Subpart A § 60.8 using EPA Test Methods 5 and 202. Note that the previous compliance tests for these units were completed as follows: Unit Source of Emission Factor Unit 2 —Simple Cycle February 28, 2019 Unit 2 — Combined February 26 & 27, 2019 Cycle Unit 3- Simple Cycle March 6, 2019 Unit 3 — Combined March 5. 2019 Cycle COLORADO Air Pollution Control Division Department of Public Health b Environment Page 23 of 41 DRAFT The compliance test must be conducted in accordance with the APCD Compliance Test Manual (as updated and amended by the Division, see at https://cdphe.colorado.gov/compliance-and- enforcement), including deadlines for preparation and submittal of the protocol for Division review and approval and for submittal of the test report. All compliance testing must be approved by the Division prior to conducting the test. 1.14 State -only Requirement: No owner or operator may discharge, or cause the discharge into the atmosphere of any particulate matter which is greater than 20% opacity (Colorado Regulation No. 6, Part B, Section II.C.3). This opacity standard applies to each combustion turbine/HRSG/duct burner. In the absence of credible evidence to the contrary, compliance with the opacity limitation shall be presumed since only pipeline quality natural gas is permitted to be used as fuel in the turbines and duct burners. 1.15 Except as provided for in Condition 1.16 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This opacity standard applies to each combustion turbine/HRSG/duct burner. In the absence of credible evidence to the contrary, compliance with the opacity limitation shall be presumed since only pipeline quality natural gas is permitted to be used as fuel in the turbines and duct burners. 1.16 No owner or operator of a source shall allow or cause to be emitted into the atmosphere any air pollutant resulting from the building of a new fire, cleaning of fire boxes, soot blowing, start-up, process modifications, or adjustment or occasional cleaning of control equipment which is in excess of 30% opacity for a period or periods aggregating more than six (6) minutes in any sixty (60) consecutive minutes (Colorado Regulation No. 1, Section II.A.4). This opacity standard applies to each combustion turbine/HRSG/duct burner. In the absence of credible evidence to the contrary, compliance with the opacity limitation shall be presumed since only pipeline quality natural gas is permitted to be used as fuel in the turbines and duct burners. 1.17 The turbines and duct burners are subject to the requirements in Colorado Regulation No. 26, Part B, Section II.A as follows: Note that the language below is from Colorado Regulation No. 26, adopted by the Colorado Air Quality Control Commissions (AQCC) on December 2, 2024 (effective February 14, 2025). However, if revisions to Colorado Regulation No. 26, Part B, Section II.A are published at a later date, the owner or operator is subject to the requirements contained in the revised version of Section II.A. 1.18.1 Applicability (Regulation No. 26, Part B, Section II.A.1) 1.18.1.1 Except as provided in Section II.A.2., the requirements of this Section II. apply to owners and operators of any stationary combustion equipment that existed at a major source of NOx (greater than or equal to 100 tpy NOx) as of June 3, 2016, located in the 8 -Hour Ozone Control Area. (Regulation No. 26, Part E, Section II.A.1.a) 1.18.2 Exemptions (Regulation No. 26, Part B, Section II.A.2) COLORADO Air Pollution Control Division Department of Pubic Health b Ermronment Page 24 of 41 DRAFT The following stationary combustion equipment are exempt from the emission limitation requirements of Section II.A.4., the compliance demonstration requirements in Section II.A.5., and the related recordkeeping and reporting requirements of Sections II.A.7.a-e. and II.A.B, but these sources must maintain any and all records necessary to demonstrate that an exemption applies. These records must be maintained for a minimum of five years and made available to the Division upon request. Qualifying for an exemption in this section does not preclude the combustion process adjustment requirements of Section II.A.6., when required by II.A.6.a. Once stationary combustion equipment no longer qualifies for any exemption, the owner or operator must comply with the applicable requirements of this Section II.A. as expeditiously as practicable but no later than 36 months after any exemption no longer applies. Additionally, once stationary combustion equipment that is not equipped with CEMS or CERMS no longer qualifies for any exemption, the owner or operator must conduct a performance test using EPA test methods within 180 days and notify the Division of the results and whether emission controls will be required to comply with the emission limitations of Section II.A.4. (Regulation No. 26, Part B, Section II.A.2) 1.18.2.1 Any stationary combustion equipment whose utilization is less than 10% of its capacity factor on an annual average basis over a 3 -year rolling period for stationary combustion turbines and compression ignition reciprocating internal combustion engines. (Regulation No. 26, Part B, Section II.A.2.a.(ii)) 1.18.2.2 Any stationary combustion equipment with total uncontrolled actual emissions less than 5 tpy NOx on a calendar year basis. (Regulation No. 26, Part B, Section II.A.2.d) 1.18.3 Emission Limitations (Regulation No.26, Part B, Section II.A.4) By October 1, 2021, no owner or operator of stationary combustion equipment specified in Section II.A.1.a. may cause, allow, or permit NOx to be emitted in excess of the following emission limitations. When demonstrating compliance using continuous emissions monitoring pursuant to Section II.A.5.c.(i), the following emission limitations are on a 30 -day rolling average basis, unless otherwise specified. (Regulation No. 26, Part B, Section II.A.4. 1st paragraph) 1.18.3.1 Stationary combustion turbines with a maximum design heat input capacity equal to or greater than 10 MMBtu/hr and which commenced construction on or before February 18, 2005 must comply with the following NOx emission limits (Regulation No. 26, Part B, Section II.A.4.b.(i)) a. 15 ppm at 15 percent O2 or 54 ng/J of useful output (0.43 Ib/MWh). COLORADO Air Poilution Control Division Department of Public Health b Environment Page 25 of 41 DRAFT b. Turbines operating at less than 75 percent of peak load 96 ppm at 15 percent O2 or 590 ng/1 of useful output (4.7 Ib/MWh). c. Turbines operating at temperatures less than 0 °F 96 ppm at 15 percent O2 or 590 ng/J of useful output (4.7 Ib/MWh). d. For units with heat recovery and CEMS, determine compliance on a 30 -day rolling average. (Regulation No. 26, Part B, Section II.A.4.b.(i)(A)) e. For operating periods during which multiple emissions standards apply, the applicable standard is the average of the applicable standards during each hour. For hours with multiple emissions standards, the applicable limit for that hour is determined based on the condition that corresponded to the highest emissions standard. (Regulation No. 26, Part B, Section II.A.4.b.(i)(C)) f. Emissions exceeding the NOx emission limits in Section II.A.4.b.(i) at any time, including during times of startup, shutdown, malfunction, fuel switching, tuning, and testing must be reported as specified in Section II.A.8.a.(i). (Regulation No. 26, Part B, Section II.A.4.b.(i)(D)) 1.18.3.2 Stationary combustion turbines subject to the categorical limits in Section II.A.4.b.(i) or (ii) (Condition 1.18.3.1) above and stationary combustion turbines with a maximum design heat input capacity less than 10 MMBtu/hr must comply with the combustion process adjustment requirements contained in Section II.A.6. while burning gaseous fuel, liquid fuel, or any combination thereof, when required by Section II.A.6.a. (Regulation No. 26, Part B, Section II.A.4.b.(iii)) 1.18.4 Compliance (Regulation No. 26, Part B, Section II.A.5) 1.18.4.1 By October 1, 2021, for stationary combustion equipment that existed at a major source of NOx (greater than or equal to 100 tpy NOx) as of June 3, 2016, the owner or operator of an affected unit must determine compliance with the applicable emission limitations contained in Section II.A.4. according to the applicable methods contained in this Section II.A.5. (Regulation NO. 26, Part B, Section II.A.5.a) 1.18.4.2 Compliance with the NOX limits in Condition 1.18.3.1 shall be monitored using the NOX CEMS required by Condition 1.10. COLORADO Air Pollution Control Division Department of Public Health b Environment Page 26 of 41 L DRAFT J 1.18.5 The combustion process adjustment and associated recordkeeping requirements in Condition 10 apply to any turbine or duct burner with actual, uncontrolled emissions equal to or greater than 5 tons per year of NOX. (Colorado Regulation No. 26, Part B, Section II.A.6.a.(i)) 1.18.6 Recordkeeping. (Regulation No. 26, Part B, Section II.A.7) The following records must be kept for a period of five years and made available to the Division upon request (Regulation No, 26, Part B, Section II.A.7): 1.18.6.1 The stationary combustion equipment's (turbines) annual capacity factor on a calendar year basis. (Regulation No. 26, Part B, Section II.A.7.d) 1.18.6.2 All sources qualifying for an exemption under Section II.A.2. must maintain all records necessary to demonstrate that an exemption applies. (Regulation No. 26, Part B, Section II.A.7.g) 1.18 You must operate and maintain your stationary combustion turbine, air pollution control equipment, and monitoring equipment in a manner consistent with good air pollution control practices for minimizing emissions at all times including during startup, shutdown, and malfunction. (60.4333(a)) COLORADO Air Pollution Control Division Department of PuCdc Health b Environment. Page 27 of 41 DRAFT 2. Continuous Emission Monitoring Systems (CEMS) The following requirements apply to the NOX, CO and diluent (either O2 or C02) continuous emission monitoring systems (CEMS) required by Conditions 1.10, 2.8 and 8.10. 2.1 Monitoring Requirements For each turbine (i.e., combustion turbine or combustion turbine/HRSG/duct burner), a continuous emission monitoring system shall be installed, calibrated, and operated on the exhaust stack to determine and record the following. 2.1.1 Concentration of Oxides of Nitrogen; ppmvd corrected to 15% O2, hourly average and 24 -hour average (Turbine 4 only), in the exhaust; 2.1.2 Emissions of Oxides of Nitrogen; tons/month, rolling twelve month; 2.1.3 Concentration of Carbon Monoxide; ppmvd corrected to 15% O2, hourly average, in the exhaust; 2.1.4 Emissions of Carbon Monoxide; Ibs/hr, tons/month, rolling twelve month; 2.1.5 Average combustion turbine load; 2.1.6 Load at which steam turbine is operating; and 2.1.7 Operating mode — startup, shutdown and/or standard operation. 2.2 Equipment and QA/QC Requirements 2.2.1 The Continuous Emission Monitoring Systems are subject to the following requirements: 2.2.1.1 Except as provided for below, the CO monitors are subject to the applicable requirements of 40 CFR Part 60. The monitoring systems shall meet the equipment, installation and performance specifications of 40 CFR Part 60 Appendix B, Performance Specification 4/4A. These CEMS are subject to the quality assurance/quality control requirements in 40 CFR Part 60 Appendix F and Subpart A § 60.13 and Condition 5.2.1.3 of this permit. a. The CO CEMS data shall meet the applicable "primary equipment hourly operating requirements" for hourly average calculation methodology specified in 40 CFR Part 75 Subpart B § 75.10(d). b. Annual CO monitor relative accuracy (RA) testing will be performed in ppm @ 15% O2 measurement units, and COPHE COLORADO Air Pollution Control Division Department of Public Health b Environment Page 28 of 41 DRAFT will be performed according to 40 CFR Part 60, Appendix B, Performance Specification 4A. c. Relative accuracy test audit (RATA) frequency will be determined according to 40 CFR Part 75 Appendix B. 2.2.1.2 Except as provided for below, the NOX (and diluent) monitors are subject to the applicable requirements of 40 CFR Part 75. The monitoring systems shall meet the equipment, installation and performance specification requirements in 40 CFR Part 75, Appendix A. These CEMS shall meet the quality assurance/quality control requirements in 40 CFR Part 75, Appendix B, the conversion procedures of Appendix F and Condition 5.2.1.3 of this permit. 2.2.1.3 The NOX and CO CEMS are subject to the following requirements: Relative Accuracy Test Audits (RATAs): RATAs shall be conducted in the units (e.g., Ib/MMBtu, ppm) of the emission limitation for all of the emission limitations that are applicable to the emissions unit. The RATAs for emissions units that have annual emission limitations (tons/yr) will be conducted in terms of pounds per hour (lb/hr). b. The DAHS shall be able to record and manipulate the data in the units (e.g., Ib/MMBtu, ppm) of the emission limitation and meet the reporting requirements for all for the emissions limitations that are applicable to the emissions unit. 2.2.2 Quality assurance/quality control plans shall be prepared for the continuous emission monitoring systems as follows: 5.2.2.1 The quality assurance/quality control plan for the CO monitors shall be prepared in accordance with the applicable requirements in 40 CFR Part 60, Appendix F, except that gas cylinder audit (GCA) testing is not required during quarters with less than 168 hours of operating time. 2.2.2.2 The quality assurance /quality control plan for the NOX (and diluent) monitors shall be prepared in accordance with the applicable requirements in 40 CFR Part 75, Appendix B. The quality assurance/quality control plans shall be made available to the Division upon request. Revisions shall be made to the plans at the request of the Division. COLORADO Air Pollution Control Division Department of Public Health 6 DIVOOnntertt Page 29 of 41 DRAFT 2.3 General Provisions 2.3.1 NOX (and diluent) monitors: The permittee shall ensure that all continuous emission monitoring systems required are in operation and monitoring unit emissions at all times that the unit combusts any fuel except as provided in 40 CFR Part 75 § 75.11(e) and during periods of calibration, quality assurance, or preventative maintenance performed pursuant to 40 CFR Part 75 § 75.21 and Appendix B, periods of repair, periods of backups of data from a data acquisition and handling system or recertification performed pursuant to 40 CFR Part 75 § 75.20. (40 CFR Part 75 § 75.10(d)). 2.3.2 CO monitors: Except for system breakdowns, repairs, calibration checks, and zero and span adjustments required under § 60.13(d), all continuous monitoring systems shall be in continuous operation and shall meet minimum frequency of operation requirements as set forth in § 60.13(e)(2). (40 CFR Part 60 Subpart A § 60.13(e)). 2.3.3 Alternative monitoring systems, alternative reference methods, or any other alternatives for the required continuous emission monitoring systems shall not be used without having obtained prior written approval from the appropriate agency, either the Division or the U.S. EPA, depending on which agency is authorized to approve such alternative under applicable law. Any alternative continuous emission monitoring systems must be certified in accordance with the requirements of 40 CFR Part 75 prior to use. 2.3.4 All test and monitoring equipment, methods, procedures and reporting shall be subject to the review and approval by the appropriate agency, either the Division or the U.S. EPA, depending on which agency is authorized to approve such alternative under applicable law, prior to any official use. The Division shall have the right to inspect such equipment, methods and procedures and data obtained at any time. The Division may provide a witness(s) for any and all tests as Division resources permit. 2.3.5 A file suitable for inspection shall be maintained of all measurements, including continuous monitoring system, monitoring device, and performance testing measurements; all continuous monitoring system performance evaluations; all continuous monitoring system or monitoring device calibration checks; adjustments and maintenance performed on these systems or devices; and all other information required by applicable portions of 40 CFR Part 60 Subpart A and Appendices B and F and 40 CFR Part 75. 2.3.6 Records shall be maintained of the occurrence and duration of any startup, shutdown, or malfunction in the operation of the source; any malfunction of the air pollution control equipment; or any periods COLORADO Air Pollution Control Division Department of Pubt. Health b Enwonment Page 30 of 41 DRAFT during which a continuous monitoring system or monitoring device is inoperative (40 CFR Part 60 Subpart A § 60.7(b), as adopted by reference in Colorado Regulation No. 6, Part A). 2.4 Data Replacement Requirements For periods when quality assured data is not available from the continuous emission monitoring systems the data replacement procedures in 40 CFR Part 75 Subpart D shall be used for determining the total (annual) emissions. Although carbon monoxide emissions are not specifically referenced in the Subpart D procedures, the CEM data acquisition system will be programmed to substitute carbon monoxide emissions using the same procedures specified for oxides of nitrogen. For purposes of monitoring compliance with the annual emission limitations (tons/yr) replaced and bias -adjusted data shall be included when assessing compliance with the annual limitations. Note that since CO emissions are not subject to requirements in 40 CFR Part 75 the CO emission data is not required to be bias -adjusted. 2.5 Recordkeeping and Reporting Requirements 2.5.1 Each owner or operator required to install a continuous monitoring device shall submit excess emissions and monitoring systems performance report (excess emissions are defined in applicable subparts and this permit) and/or summary report form (see Condition 5.5.2) to the Division quarterly. All reports shall be postmarked by the 30th day following the end of each calendar quarter. (§ 60.7(c), revised to stipulate quarterly reporting. Written reports of excess emissions shall include the following information: 5.5.1.1 The magnitude of excess emissions computed in accordance with 40 CFR Part 60 Subpart A § 60.13(h) and Division guidelines, as applicable, any conversion factor(s) used, and the date and time of commencement and completion of each time period of excess emissions and the process operating time during the reporting period. (§ 60.7(c)(1)) 2.5.1.2 Specific identification of each period of excess emissions that occurs during startups, shutdowns, and malfunctions of the affected facility. The nature and cause of any malfunction (if known), the corrective action taken or preventative measures adopted. (§ 60.7(c)(2)) 2.5.1.3 The date and time identifying each period during which the continuous monitoring system was inoperative except for zero and span checks and the nature of the system repairs or adjustments (§ 60.7(c)(3)). 2.5.1.4 When no excess emissions have occurred or the continuous monitoring system(s) have not been inoperative, repaired, or 48 COLORADO Air Pollution Control Division Department of public Health & Emnronment Page 31 of 41 DRAFT adjusted, such information shall be stated in the report (§ 60.7(c)(4)). 2.5.2 The summary report form shall contain the information and be in the format shown in figure 1 of § 60.7 unless otherwise specified by the Division. One summary report form shall be submitted for each pollutant monitored at each affected facility. (§ 60.7(d)) If the total duration of excess emissions for the reporting period is less than 1 percent of the total operating time for the reporting period and CMS downtime for the reporting period is less than 5 percent of the total operating time for the reporting period, only the summary report form shall be submitted and the excess emission report described in Condition 5.5.1 need not be submitted unless requested by the Division. (§ 60.7(d)(1)). If the total duration of excess emissions for the reporting period is 1 percent or greater of the total operating time for the reporting period or the total CMS downtime for the reporting period is 5 percent or greater of the total operating time for the reporting period, the summary report form and the excess emission report described in Condition 5.5.1 shall both be submitted. (§ 60.7(d)(2)) 2.6 Specific Provisions for NSPS Subpart KKKK The requirements in this Condition 5.6 reflect the rule language in 40 CFR Part 60 Subpart KKKK as of the latest revisions to 40 CFR Part 60 Subpart KKKK published in the Federal Register on March 20, 2009. However, if revisions to this Subpart are promulgated at a later date, the owner or operator is subject to the requirements contained in the revised version of 40 CFR Part 60 Subpart KKKK. Please note that proposed revisions to 40 CFR Part 63 Subpart KKKK were published in the Federal Register on August 29, 2012 to address a petition for reconsideration filed by the Utility Air Regulatory Group (UARG) on September 5, 2006 regarding the July 2006 final rule and to address other technical and editorial issues. Therefore, the requirements below may change in the future. 2.6.1 As specified in 40 CFR Part 60 Subpart KKKK § 60.4345(a), if a Part 75 NOX CEMS is used, the RATA shall be performed on a Ib/MMBtu basis. 2.6.2 As specified in 40 CFR Part 60 Subpart KKKK § 60.4350(d) (Conditions 2.5.2.7 and 8.2.2.7) and approved by the Division, only quality assured data from the CEMS shall be used to identify excess emissions. Periods where the missing data substitution procedures in Subpart D of Part 75 are applied are to be reported as monitor downtime in the excess emission reports specified in Condition 5.5. COLORADO Air Pollution Control Division Department of Public Health b Environment Page 32 of 41 DRAFT 2.6.3 For the purpose of reports required under Condition 5.5, periods of excess emissions and monitor downtime that must be reported are defined as follows: 5.6.3.1 An excess emissions is any unit operating period in which the 4 -hour or 30 -day rolling average NOX emission rate exceeds the applicable emission limit in §60.4320. For the purposes of this subpart, a "4 -hour rolling average NOX emission rate" is the arithmetic average of the average NOX emission rate in ppm or ng/J (Ib/MWh) measured by the continuous emission monitoring equipment for a given hour and the three unit operating hour average NOX emission rates immediately preceding that unit operating hour. Calculate the rolling average if a valid NOX emission rate is obtained for at least 3 of the 4 hours. For the purposes of this subpart, a "30 -day rolling average NOX emission rate" is the arithmetic average of all hourly NOX emission data in ppm or ng/J (Ib/MWh) measured by the continuous emission monitoring equipment for a given day and the twenty-nine unit operating days immediately preceding that unit operating day. A new 30 -day average is calculated each unit operating day as the average of all hourly NOX emissions rates for the preceding 30 unit operating days if a valid NOX emission rate is obtained for at least 75 percent of all operating hours. (§ 60.4380(b)(1)) 2.6.3.2 A period of monitor downtime is any unit operating hour in which the data for any of the following parameters are either missing or invalid: NOX concentration, CO2 or O2 concentration, fuel flow rate, steam flow rate, steam temperature, steam pressure, or megawatts. The steam flow rate, steam temperature, and steam pressure are only required if you will use this information for compliance purposes. (§ 60.4380(b)(2)) 2.6.3.3 For operating periods during which multiple emissions standards apply, the applicable standard is the average of the applicable standards during each hour. For hours with multiple emissions standards, the applicable limit for that hour is determined based on the condition that corresponded to the highest emissions standard. (§ 60.4380(b)(3)) Section III — Additional Requirements & General Conditions ADDITIONAL REQUIREMENTS 1. All previous versions of this permit are superseded upon issuance of this permit. 2. The permit number and AIRS ID number must be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, Section III.E.) (State -only enforceable) 3. A Revised Air Pollutant Emission Notice (APEN) must be filed: (Reference: Regulation Number 3, Part A, Section II.C.) COLORADO Air Pollution Control Division Department or Public Health b Ermronment Page 33 of 41 DRAFT a. By April 30 of the year following a significant increase in emissions. A significant increase in emissions is defined as follows: For any criteria pollutant: For sources emitting less than one hundred (100) tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN submitted; or For volatile organic compounds (VOC) and nitrogen oxide (NOx) sources in an ozone non -attainment area emitting less than one hundred (100) tons of VOC or nitrogen oxides per year, a change in actual emissions of one (1) ton per year or more or five percent (5%), whichever is greater, above the level reported on the last APEN submitted; or For sources emitting one hundred (100) tons per year or more of a criteria pollutant, a change in actual emissions of five percent (5%) or fifty (50) tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For sources emitting any amount of lead, a change in actual emissions, above the level reported on the last APEN submitted, of fifty (50) pounds of lead For any non -criteria reportable pollutant: If the emissions increase by fifty percent (50%) or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity. c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment. d. Whenever a permit limitation must be modified. e. No later than thirty (30) days before the existing APEN expires. 4. The permit holder must construct and maintain exhaust stack heights as listed in the table below. Facility Equipment ID AIRS Point Minimum stack height above ground level (m) T007 014 30.48 T008 015 30.48 T002_CC 004 53.34 T002_SC 004 31.7 T003_CC 005 53.34 T003_SC 005 31.7 T004_CC 008 53.34 T004_SC 008 31.7 T005 010 41.15 T006 011 41.15 AUXBLR 001 31.09 COLORADO Air Pollution Control Division Department of Public Heaiut b Environment Page 34 of 41 DRAFT ENG01 N/A 31.39 ENG02 N/A 5.18 5. Public access must be precluded in all areas within the modeling receptor exclusion zone as submitted with the modeling in the application. The exclusion zone must be fenced and posted with no trespassing signs. (Reference: Regulation Number 3, Part B, Section III.6.5.) 6. All equipment currently covered by an existing Title V permit must comply with all monitoring, reporting, and record keeping requirements outlined in the current Title V Operating Permit. (Reference: Regulation Number 3, Part B, Section III.E.) General Terms and Conditions 7. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the Division as provided in Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 8. If this permit specifically states that final approval has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit is considered initial approval and does not provide "final" approval for this activity or operation of this source. Final approval of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final approval cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final approval. Details for obtaining final approval to operate are located in the "Requirements to Self -Certify for Final Approval" section of this permit. The operator must retain the permit final approval letter issued by the Division after completion of self -certification with the most current construction permit. 9. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity(ies) specifically identified in this permit. If subsequent operations or testing at the source indicate the information supplied to obtain this permit and relied upon in the creation and issuance of this permit is inaccurate, the source must submit an application to modify the permit to address the inaccuracy(ies). (Reference: Regulation Number 3, Part B, Section III.E.) Permit Histo Issuance Date Description Issuance 1 May 26, 1995 Issued to Public Service Company of Colorado. Issuance 2 This Issuance Addition of SCR to turbine 002 (AIRS ID 004) to control NOx. Updating permit to incorporate title V operating permit language since all updates for this source have gone through title V before this modification. NOTES TO PERMIT HOLDER (AS OF DATE OF PERMIT ISSUANCE) 1) The production or raw material processing limits and emission limits contained in this permit are based on the production/processing rates requested in the permit application. These limits 6 - COLORADO Air Pollution Control Division Department of Fabric Health 6 Enwonment Page 35 of 41 DRAFT may be revised upon request of the permittee providing there is no exceedence of any specific emission control regulation or any ambient air quality standard. A revised air pollutant emission notice (APEN) and application form must be submitted with a request for a permit revision. (Reference: Regulation Number 3, Part B, Section II.A.4.) 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The permittee must notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation. 3) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the souroe(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emission Rate (lb/year) Are the emissions reportable? Controlled Emission Rate (lb/year) 004 a 005 Acetaldehyde 75070 2320 YES N/A 004 a 005 Formaldehyde 50000 8260 YES N/A 004 R 005 Toluene 108883 3360 YES N/A 004 5 005 Xylene 1300207 1640 YES N/A 004 it 005 Nickel N/A 2920 YES N/A 004 EtManganese 00505 N/A 2040 YES N/A 4) The emission levels contained in this permit are based on the following emission factors: Emission Factors for AIRS Point 004 Ft 005: CAS Pollutant Uncontrolled Unit Source PM, . 8 PM25 0.0066 lb/MMBTU AP -42 SO2 0.0034 lb/MMBTU AP -42 CO 0.082 lb/MMBTU AP -42 VOC 0.0021 lb/MMBTU AP -42 75070 Acetaldehyde 0.0000912 lb/MMBTU ICCR 50000 Formaldehyde 0.000318 lb/MMBTU Stack Test 108883 Toluene 0.00013 lb/MMBTU AP -42 1300207 Xylene 0.000064 lb/MMBTU AP -42 5) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five (5) years from the date it was received by the Division. A revised APEN must be submitted no later than thirty (30) days before the five-year COLORADO Air Pollution Control Division Department of Public Health b Environment Page 36 of 41 DRAFT term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 6) This facility is classified as follows: Applicable Requirement Status Operating Permit Major Source: NOx, VOC NANSR Major Source: NOx, VOC 7) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the Code of Federal Regulations Website. Part 60: Standards of Performance for New Stationary Sources Regulation Type CFR Citation Subpart Name NSPS 60.1 -End Subpart A - Subpart KKKK 8) The permit holder is required to pay fees for the processing time for this permit. An invoice for The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. Failure to pay the invoice will result in revocation of this permit. The permit holder must pay the invoice within thirty (30) days of receipt of the invoice. (Reference: Regulation Number 3, Part A, Section VI.B.) 9) Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the Division to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 10) Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof must constitute a rejection of the entire permit and upon such occurrence, this permit must be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Division on grounds set forth in the Colorado Air Pollution Prevention and Control Act and regulations of the AQCC including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. (Reference: Regulation Number 3, Part B, Section III.F.) 11) Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollutant Emission Notice (APEN) must pay an annual emission fee. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 12) Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. COLORADO Air Pollution Control Division Department of Public Health Fr Enwonment Page 37 of 41 DRAFT APPENDIX E Permit Acronyms Listed Alphabetically: AIRS - Aerometric Information Retrieval System AP -42 - EPA Document Compiling Air Pollutant Emission Factors APEN - Air Pollution Emission Notice (State of Colorado) APCD - Air Pollution Control Division (State of Colorado) ASTM - American Society for Testing and Materials BACT - Best Available Control Technology BTU - British Thermal Unit CAA - Clean Air Act (CAAA = Clean Air Act Amendments) CCR - Colorado Code of Regulations CEM - Continuous Emissions Monitor CF - Cubic Feet (SCF = Standard Cubic Feet) CFR - Code of Federal Regulations CO - Carbon Monoxide COM - Continuous Opacity Monitor CRS - Colorado Revised Statute EF - Emission Factor EPA - Environmental Protection Agency FI - Fuel Input Rate in MMBtu/hr FR - Federal Register G - Grams Gal - Gallon GPM - Gallons per Minute HAPs - Hazardous Air Pollutants HP - Horsepower HP -HR - Horsepower Hour (G/HP-HR = Grams per Horsepower Hour) LAER - Lowest Achievable Emission Rate LBS - Pounds M - Thousand MM - Million MMscf - Million Standard Cubic Feet MMscfd - Million Standard Cubic Feet per Day N/A or NA - Not Applicable NOx - Nitrogen Oxides NESHAP - National Emission Standards for Hazardous Air Pollutants NSPS - New Source Performance Standards P - Process Weight Rate in Tons/Hr PE - Particulate Emissions PM - Particulate Matter PMio - Particulate Matter Under 10 Microns PPM Parts Per Million PPMV Parts Per Million, by Volume COLORADO Air Pollution Control Division Department of Public Health 6 frmronment Page 38 of 41 DRAFT PPMVD Parts Per Million, by Volume, Dry PSD - Prevention of Significant Deterioration PTE - Potential To Emit RACT - Reasonably Available Control Technology SCC - Source Classification Code SCF - Standard Cubic Feet SIC - Standard Industrial Classification SO2 - Sulfur Dioxide TPY - Tons Per Year TSP - Total Suspended Particulate VOC - Volatile Organic Compounds fte COLORADO Air Pollution Control Division Department of Public Health b Environment Page 39 of 41 DRAFT APPENDIX C VOC Correlation Equations Turbine 2 Revision 1- May 2000 For all Turbine 2 Equations: y= VOC (lb/hr or ppm) x= Heat Input (MMBtu, CT: simple cycle, Duct Burners: combined cycle) Simple Cycle, ppm MMF Model: y=(a*b+c*x^d)/(b+x^d) Coefficient Data: a = -10.70408 b = 29.46769 c= 1.859911 d = 0.808016 Simple Cycle, lbs/hr MMF Model: y=(a*b+c*x^d)/(b+x^d) Coefficient Data: a=-17013.15 b = 934.6225 c = 7.491049 d = 2.20199 Turbine 3 Revision 1 — May 2000 For all Turbine 3 equations: y= VOC (Ib/hr or ppm) x= Heat Input (MMBtu, CT: simple cycle, Duct Burners: combined cycle) Simple Cycle, ppm Richards Model: y=a/(1+exp(b-cx)^(1/d)) Coefficient Data: a= 0.51302 b = 0.555636 c = -0.004311 d = 29.75011 Simple Cycle, lbs/hr a COLORADO Air Pollution Control Division Department of public Health b Enwonment Page 40 of 41 DRAFT MMF Model: y=(a*b+c*x^d)/(b+x^d) Coefficient Data: a = -849.1986 b = 228.2923 c = 3.014795 d = 1.807953 ate COLORADO Air Pollution Control Division Department of Public Health b Dweonment Page 41 of 41 Hello