HomeMy WebLinkAbout20163191.tiffCOLORADO
Department of Public
Health €t Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
Weld County - Clerk to the Board
1150O St
PO Box 758
Greeley, CO 80632
October 4, 2016
Dear Sir or Madam:
On October 6, 2016, the Air Pollution Control Division will begin a 30 -day public notice period for
Public Service Company of Colorado - Rocky Mountain Energy Center. A copy of this public notice and
the public comment packet are enclosed.
Thank you for assisting the Division by posting a copy of this public comment packet in your office.
Public copies of these documents are required by Colorado Air Quality Control Commission
regulations. The packet must be available for public inspection for a period of thirty (30) days from
the beginning of the public notice period. Please send any comment regarding this public notice to
the address below.
Colorado Dept. of Public Health Et Environment
APCD-SS-B1
4300 Cherry Creek Drive South
Denver, Colorado 80246-1530
Attention: Clara Gonzales
Regards,
Clara Gonzales
Public Notice Coordinator
Stationary Sources Program
Air Pollution Control Division
Enclosure
4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe
John W. Hickentooper, Governor
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Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer
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2016-3191
Air Pollution Control Division
Notice Of A Proposed Renewal Title V Operating Permit
Warranting Public Comment
Website Title: Public Service Company of Colorado - Rocky Mountain Energy Center - Weld County
Notice Period Begins: October 6, 2016
NOTICE is hereby given that an application to renew an Operating Permit has been submitted to the
Colorado Air Pollution Control Division, 4300 Cherry Creek Drive South, Denver, Colorado 80246-1530, for
the following source of air pollution:
Applicant: Public Service Company of Colorado
1800 Lorimer Street
Suited 1300
Denver, CO 80202
Facility: Rocky Mountain Energy Center
6211 Weld County Road 51
Keenesburg, CO 80643
Public Service Company of Colorado has applied to renew the Operating Permit for the Rocky Mountain
Energy Center in Weld County, CO. This facility consists of two combustion turbines, each equipped with a
heat recovery steam generator and a duct burner. Natural gas is the only fuel used in these turbines and
duct burners. A copy of the application, including supplemental information, the Division's analysis, and a
draft of the Renewal Operating Permit 05OPWE279 have been filed with the Weld County Clerk's office. A
copy of the draft permit and the Division's analysis are available on the Division's website at
https://www.colorado.gov/pacific/cdphe/air-permit-public-notices. The Division has made a preliminary
determination of approval of the application. Based on the information submitted by the applicant, the
Division has prepared the draft renewal operating permit for approval. Any interested person may contact
Jacqueline Joyce of the Division at 303-692-3267 to obtain additional information. Any interested person
may submit written comments to the Division concerning 1) the sufficiency of the preliminary analysis, 2)
whether the permit application should be approved or denied, 3) the ability of the proposed activity to
comply with applicable requirements, 4) the air quality impacts of, alternatives to, and control technology
required on the source or modification, and 5) any other appropriate air quality considerations. Any
interested person may submit a written request to the Division for a public comment hearing before the
Colorado Air Quality Control Commission (Commission) to receive comments regarding the concerns listed
above as well as the sufficiency of the preliminary analysis and whether the Division should approve or deny
the permit application. If requested, the hearing will be held before the Commission within 60 days of its
receipt of the request for a hearing unless a longer time period is agreed upon by the Division and the
applicant. The hearing request must: 1) identify the individual or group requesting the hearing, 2) state his
or her address and phone number, and 3) state the reason(s) for the request, the manner in which the
person is affected by the proceedings, and an explanation of why the person's interests are not already
adequately represented. The Division will receive and consider the written public comments and requests
for any hearing for thirty calendar days after the date of this Notice.
Colorado Department
of Public Health
and Environment
OPERATING PERMIT
Public Service Company of Colorado - Rocky Mountain
Energy Center
First Issued: July 1, 2007
Renewed: DRAFT
AIR POLLUTION CONTROL DIVISION
COLORADO OPERATING PERMIT
FACILITY NAME: Rocky Mountain
Energy Center
FACILITY ID: 1231342
RENEWED:
EXPIRATION DATE:
MODIFICATIONS: See Appendix F of Permit
OPERATING PERMIT NUMBER
05OPWE279
Issued in accordance with the provisions of Colorado Air Pollution Prevention and Control Act, 25-7-101 et
sec . and applicable rules and regulations.
ISSUED TO:
Public Service Company of Colorado
1800 Larimer Street
Denver. CO 80202
PLANT SITE LOCATION:
6211 Weld County Road 51
Keenesburg, CO 80643
Weld County
INFORMATION RELIED UPON
Operating Permit Application Received:
And Additional Information Received:
June 27, 2016
Nature of Business: Electric Power Generation
Primary SIC: 4911
RESPONSIBLE OFFICIAL
Name: Mark Fox
Title: General Manager — Power
Generation. Colorado
Phone: (303) 425-3779
FACILITY CONTACT PERSON
Name: Gary Magno
Title: Manager Environmental Services -
Air Quality Compliance
Phone: (303) 294-2177
SUBMITTAL DEADLINES
Semi -Annual Monitoring Period:
Semi -Annual Monitoring Report:
Annual Compliance Period:
Annual Compliance Certification:
Note that the Semi -Annual Monitoring Reports and Annual Compliance Certifications must be received
at the Division office by 5:00 p.m. on the due date. Postmarked dates will not be accepted for the
purposes of determining the timely receipt of those reports/certifications.
FOR ACID RAIN SUBMITTAL DEADLINES SEE SECTION III.4 OF THIS PERMIT
EXAMPLE (July 1 — December 31, January 1 — June 30)
EXAMPLE (Due on Feb. 1, 2013 & Aug. 1, 2013 & subsequent years)
EXAMPLE (July 1 — June 30)
EXAMPLE (Due on August 1, 2013 & subsequent years)
Table of Contents:
SECTION I - General Activities and Summary I
1. Permitted Activities 1
2. Alternative Operating Scenarios 2
3. Nonattainment Area New Source Review (NANSR) and Prevention Of Significant Deterioration
(PSD) 2
4. Accidental Release Prevention Program (112(r)) 7
5. Compliance Assurance Monitoring (CAM) 2
6. Summary of Emission Units 3
SECTION II - Specific Permit Terms 4
1. Units S001 & S002 — Two (2) Natural Gas Fired Combustion Turbines Each Equipped with a HRSG
and Duct Burner 4
2. Diesel Fuel Fired Emergency Engines 24
S005- Emergency Generator Rated at 1,810 hp 24
M003- Emergency Fire Pump Engine Rated at 182 hp 24
3. S004 —Rentech Natural Gas Fired Boiler Rated at 129 MMBtu/hr 32
4. S006 — Marley Cooling Water Tower 38
5. Facility Wide HAP Limits 40
6. Continuous Emission Monitoring Requirements 41
7. M001 - Gasoline Storage Tank, 500 gallons aboveground 46
SECTION III - Acid Rain Requirements 48
1. Designated Representative and Alternate Designated Representative 49
2. Sulfur Dioxide Emission Allowances and Nitrogen Oxide Emission Limitations 49
3. Standard Requirements 49
4. Reporting Requirements 53
5. Comments, Notes and Justifications 53
SECTION IV - Permit Shield 54
1. Specific Non -Applicable Requirements 54
2. General Conditions 54
3. Streamlined Conditions 54
SECTION V - General Permit Conditions 56
1. Administrative Changes 56
2. Certification Requirements 56
3. Common Provisions 56
4. Compliance Requirements 60
5. Emergency Provisions 61
6. Emission Controls for Asbestos 61
7. Emissions Trading, Marketable Permits, Economic Incentives 61
8. Fee Payment 61
9. Fugitive Particulate Emissions 62
10. Inspection and Entry 62
11. Minor Permit Modifications 62
12. New Source Review 62
13. No Property Rights Conveyed 62
14. Odor 63
Table of Contents:
15. Off -Permit Changes to the Source 63
16. Opacity 63
17. Open Burning 63
18. Ozone Depleting Compounds 63
19. Permit Expiration and Renewal 63
20. Portable Sources 64
21. Prompt Deviation Reporting 64
22. Record Keeping and Reporting Requirements 64
23. Reopenings for Cause 65
24. Section 502(b)(10) Changes 66
25. Severability Clause 66
26. Significant Permit Modifications 66
27. Special Provisions Concerning the Acid Rain Program 66
28. Transfer or Assignment of Ownership 66
29. Volatile Organic Compounds 67
30. Wood Stoves and Wood burning Appliances 67
APPENDIX A - Inspection Information 1
Directions to Plant 1
Safety Equipment Required 1
Facility Plot Plan 1
List of Insignificant Activities 1
APPENDIX B 1
Reporting Requirements and Definitions 1
Monitoring and Permit Deviation Report - Part I 5
Monitoring and Permit Deviation Report - Part II 7
Monitoring and Permit Deviation Report - Part III 9
APPENDIX C 1
Required Format for Annual Compliance Certification Report 1
APPENDIX D 1
Notification Addresses 1
APPENDIX E 1
Permit Acronyms 1
APPENDIX F 1
Permit Modifications 1
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 1
SECTION I - General Activities and Summary
1. Permitted Activities
1.1 The Rocky Mountain Energy Center (RMEC) is an electric generating facility as defined under
Standard Industrial Classification 4911. The facility consists of two natural gas fired combustion
turbines, two heat recovery steam generators (HRSG), each equipped with natural gas fired duct
burners, a steam turbine, cooling tower and auxiliary boiler. There are two diesel fired engines,
one driving an emergency generator and one driving a fire pump. There is also a gasoline
storage tank that is included in Section II of the permit. The RMEC has the capacity to generate
up to 630 MW of electricity. Each combustion turbine can generate approximately 152 MW,
with an additional 326 MW (at peak capacity) from the steam turbine. The turbines are not
equipped with a by-pass stack, therefore, the turbines only operate in combined cycle mode (i.e.
turbine plus HRSG).
The facility is located at 6211 Weld County Road 51, just east of the town of Hudson, in Weld
County Colorado (bounded by CR 49 to the west, CR 16 to the north and CR 51 to the east).
The area in which the plant operates is designated as attainment for all criteria pollutants except
ozone. It is classified as non -attainment for ozone and is part of the 8 -hr Ozone Control Area as
defined in Regulation No. 7, Section II.A.1.
There are no affected states within 50 miles of this facility. Rocky Mountain National Park, a
federal class I designated area is within 100 km of this facility.
1.2 Until such time as this permit expires or 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.
1.3 This Operating Permit incorporates the applicable requirements contained in the underlying
construction permits, and does not affect those applicable requirements, except as modified
during review of the application or as modified subsequent to permit issuance using the
modification procedures found in Regulation No. 3, Part C. These Part C procedures meet all
applicable substantive New Source Review Requirements of Part B. Any revisions made using
the provisions of Regulation No. 3, Part C shall become new applicable requirements for
purposes of this operating permit and shall survive reissuance. This permit incorporates the
applicable requirements (except as noted in Section II) from the following construction permit
(formerly issued to Rocky Mountain Energy Center, LLC): 02WE0228.
1.4 All conditions in this permit are enforceable by US Environmental Protection Agency, Colorado
Air Pollution Control Division (hereinafter Division) and its agents, and citizens unless
otherwise specified. State -only enforceable conditions are: Permit Condition Number(s):
Section II, Conditions 1.12.1 and 3.9.3 (opacity) and Section V - Conditions 3.g (last paragraph),
14 and 18 (as noted)
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 2
1.5 All information gathered pursuant to the requirements of this permit is subject to the
Recordkeeping and Reporting requirements listed under Condition 22 of the General Conditions
in Section V of this permit. Either electronic or hard copy records are acceptable.
2. Alternative Operating Scenarios
2.1 The permittee shall be allowed to make the following changes to its method of operation without
applying for a revision of this permit.
2.1.1 No separate operating scenarios have been specified.
3. Nonattainment Area New Source Review (NANSR) and Prevention Of Significant Deterioration
(PSD)
3.1 This facility is categorized as a PSD major stationary source (potential to emit of PM, PMio,
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.
3.2 This source is categorized as a NANSR major stationary source (Potential to Emit of NOx ≥100
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 > 100 tons/year of either VOC or NON) may result in the
application of the NANSR review requirements
3.3 There are no other Operating Permits associated with this facility for purposes of determining
applicability of Prevention of Significant Deterioration regulations.
4. Accidental Release Prevention Program (112(r))
4.1 Based on the information provided by the applicant, this facility is subject to the provisions of
the Accidental Release Prevention Program (section 112(r)) of the Federal Clean Air Act.
5. Compliance Assurance Monitoring (CAM)
5.1 The following emission points at this facility use a control device to achieve compliance with an
emission limitation or standard to which they are subject and have pre -control emissions that
exceed or are equivalent to the major source threshold. They are therefore subject to the
provisions of the CAM program as set forth in 40 CFR Part 64, as adopted by reference in
Colorado Regulation No. 3, Part C, Section XIV:
Units S001 and S002 — Combustion Turbines/HRSGs/Duct Burners
See Section II, Condition 1.13 for compliance assurance monitoring requirements.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 3
6. Summary of Emission Units
6.1 The emissions units regulated by this permit are the following:
Emission
Unit
No./
Facility ID
AIRS
Stack
Number
Description
Startup Date
Pollution Control
Device
S001 / CT-
01
001
One (1) Westinghouse, Model No. 501FD, Natural Gas-
Fired Combustion Turbine. Serial No. 37A8191. The
Turbine is Rated at 1785 MMBtu/hr (HHV at ISO
conditions). The turbine is operated in combined cycle
mode only and the heat recovery steam generator (HRSG)
is equipped with a duct burner rated at 675 MMBtu/hr.
The turbine drives a generator capable of generating 152
MW of power and the HRSG drives a steam generator
rated at 326 MW (at peak capacity).
March 2004
Dry Low NOx
(DLN) Combustion
Systems and
Selective Catalytic
Reduction (SCR)
for NOx and
Oxidation Catalyst
for CO and VOC.
S002 / CT-
02
002
One (1) Westinghouse, Model No. 501 FD, Natural Gas-
Fired Combustion Turbine, Serial No. 37A8196. The
Turbine is Rated at 1785 MMBtu/hr (HHV at ISO
conditions). The turbine is operated in combined cycle
mode only and the heat recovery steam generator (HRSG)
is equipped with a duct burner rated at 675 MN/Btu/hr.
The turbine drives a generator capable of generating 152
MW of power and the HRSG drives a steam generator
rated at 326 MW (at peak capacity).
March 2004
Dry Low NOx
(DLN) Combustion
Systems and
Selective Catalytic
Reduction (SCR)
for NOx and
Oxidation Catalyst
for CO and VOC.
S005
005'
Caterpillar, Model No. 3512B, Diesel Fired Internal
Combustion Engine Driving an Emergency Generator,
Serial No. 1GZ01360. The Engine is Diesel Fuel -Fired
and rated at 1810 hp and 12.2 MMBtu/hr.
March 2004
Uncontrolled
S004
004
Rentech, Natural Gas Fired Boiler, Rated at 129
MMBtu/hr, Serial No. 2002-49.
February 2004
Low NOx Burners
S006
006
Marley, Model No. F4910, 12 Cell Cooling Water Tower,
Rated at 176,000 gal/min.
March 2004
Drift Eliminators
M001
N/A
Gasoline Storage Tank, 500 gallons, aboveground
Uncontrolled
M003
0031
John Deere, Model No. 6081AF001, Serial No.
RG6081A159985, Diesel Fired Internal Combustion
Engine Driving an Emergency Fire Pump Engine, Rated
at 182 hp and 1.26 MMBtu/hr.
March 2004
Uncontrolled
APENs were previously filed for these engines. However, they are APEN exempt as long as actual, uncontrolled emissions are below
the APEN de minimis level. Cancellation notices were submitted for these APENs on September 27, 2016.
Operating Permit Number: 05OPWE279
First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 4
SECTION II - Specific Permit Terms
1. Units S001 & S002 — Two (2) Natural Gas Fired Combustion Turbines Each Equipped with a
HRSG and Duct Burner
Unless Otherwise Specified Limits are for Both Turbines/HRSGs/Duct Burners
Parameter
Permit
Condition
Number
Limitations
Short Term Long Term
Compliance
Emission
Factor
Monitoring
Method Interval
BACT
Requirements
1.1
See Condition 1.1.
N/A
See Condition 1.1
PIVI/PM10
1.2
N/A
126.8 tons/yr
CT -01:
PM 0.002
lb/MMBtu
PM10 0.002
lb/MMBtu
CT -02:
PM 0.001
lb/MMBtu
PM10 0.001
lb/MMBtu
Recordkeeping
and Calculation
Monthly
For Each Turbine/HRSG/duct
burner:
0.00735 lbs/MMBtu, the average of
three (3) test runs
N/A
See Condition 1.2
VOC
1.3
N/A
50.6 tons/yr
Unit 1 - 7.3 x
10-° lb/MMBtu
Unit 2-1.5x
10-' lb/IVLMBtu
Recordkeeping
and Calculation
Monthly
For Each Turbine/HRSG/duct
burner:
0.00293 lbs/MMBtu, the average of
three (3), test runs
N/A
See Condition 1.3
Operating Permit Number: 05OPWE279
First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 5
Parameter
Permit
Condition
Number
Limitations
Short Term Long Term
Compliance
Emission
Factor
Monitoring
Method Interval
SO2
1.4
N/A
11.8 tons/yr
N/A
40 CFR Part 75,
Appendix D
As specified in
40 CFR Part
75, Appendix D
For Each Turbine:
150 ppmvd @ 15% O. OR Use of
Fuel Which Contains Less than 0.8
Weight % Sulfur
N/A
Fuel Restriction
Only Pipeline
Quality Natural
Gas is Used as
Fuel
For Each Turbine: 0.35
lbs/MMBtu, on a 3 -hour rolling
average
For Each Duct Burner:
0.20 lbs/MMBtu, on a 30 -Day
Rolling Average
NOx
1.5
For Each Turbine/HRSG/Duct
Burner:
3 ppmvd @ 15% O, on a 1 -hr
average, except as provided for
below
During Startup and Shutdown: 300
ppmvd @ 15% O, averaged over
the startup and/or shutdown period.
During Combustion Tuning and
Testing (not to exceed 60 hrs/yr per
for both turbines/HRSGs/Duct
Burners combined):
300 ppmvd @ 15% O on a 1 -hr
average.
N/A
Continuous
Emission
Monitoring
System
Continuously
N/A
240.4 tons/yr
For Each Turbine:
102 ppmvd @ 15% O2, on a 4 -hr
rolling average
Operating Permit Number: 05OPWE279
First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 6
Parameter
Permit
Condition
Number
Limitations
Short Term Long Term
Compliance
Emission
Factor
Monitoring
Method Interval
CO
1.6
For Each Turbine/HRSG/Duct
Burner:
9 ppmvd @ 15% O2 on a 1 -hr
average, except as provided for
below
During Startup and Shutdown:
1,000 ppmvd @ 15% O-, averaged
over the startup and/or shutdown
period
During Combustion Tuning and
Testing (not to exceed 60 hrs/yr per
for both turbines/HRSGs/Duct
Burners combined):
1,000 ppmvd @ 15% O2 on a 1 -hr
average.
N/A
Continuous
Emission
Monitoring
System
Continuously
N/A
782.2 tons/yr
Natural Gas
Consumption
1.7
N/A
32,625 MMscf yr
N/A
Recordkeeping
Monthly
Continuous
Emission
Monitoring
System
Requirements
1.8
N/A
N/A
N/A
See Condition 1.8
Fuel Flow Meter
1.9
N/A
N/A
N/A
See Condition 1.9
Sulfur Content of
Fuel
1.10
Pipeline Quality Natural Gas (total
sulfur content not to exceed 0.5
grains/100 SCF)
N/A
See Condition 1.10
NSPS General
Provisions
1.11
N/A
N/A
N/A
As Required by
NSPS General
Provisions
Subject to
NSPS General
Provisions
Operating Permit Number: 05OPWE279
First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 7
Parameter
Permit
Condition
Number
Limitations
Short Term Long Term
Compliance
Emission
Factor
Monitoring
Method Interval
Opacity
1.12
State Only Requirement: Not to
Exceed 20%
N/A
Fuel Restriction
Only Natural
Gas is Used as
Fuel
Not to Exceed 20% (6 -minute
average), Except for One Six
Minute Average Not to Exceed
27% Per Hour
Not to Exceed 20% Except as
Provided for Below
For Certain Operational Activities -
Not to Exceed 30%, for a Period or
Periods Aggregating More than Six
(6) Minutes in any 60 Consecutive
Minutes
Compliance
Assurance
Monitoring
Requirements
1.13
N/A
N/A
N/A
See Condition 1.13
Acid Rain
Requirements
1.14
See Section III of this Permit
Certification
Annually
The turbines/HRSGs/duct burners are subject to the requirements of the Prevention of Significant
Deterioration (PSD) Program. Best Available Control Technology (BACT) shall be applied for
control of Nitrogen Oxides (NOx), Carbon Monoxide (CO), Particulate Matter (PM and PM»)
and Volatile Organic Compounds. BACT has been determined as follows:
1.1.1 BACT for NOx has been determined to be dry low NOx (DLN) combustion system
and selective catalytic reduction (SCR) with the emission limits identified in
Condition 1.5.1 (Colorado Construction Permit 02WE0228).
1.1.2 BACT for CO has been determined to be good combustion practices and an oxidation
catalyst with the emission limits identified in Condition 1.6.1 (Colorado Construction
Permit 02WE0228).
1.1.3 BACT for PM and PM10 has been determined to be use of pipeline quality natural gas
as fuel, good combustion practices with the emission limitations identified in
Condition 1.2.2 (Colorado Construction Permit 02WE0228).
1.1.4 BACT for VOC has been determined to be use of pipeline quality natural gas as fuel,
good combustion practices and an oxidation catalyst with the emission limitations
identified in Condition 1.3.2 (Colorado Construction Permit 02WE0228).
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 8
1.2 PM and PM10 emissions are subject to the following requirements:
1.2.1 Total Annual emissions of PM and PM10 from both turbines/HRSGs/duct burners
together shall not exceed 126.8 tons/yr (Colorado Construction Permit 02WE0228,
as modified under the provisions of Section I, Condition 1.3 to set emission units for
individual equipment instead of a facility wide total). Monthly emissions from each
turbine/HRSG/duct burner shall be calculated by the end of the subsequent month
using the above emission factors (from performance tests conducted October 6 and 7,
2015) and the heat input for the month as recorded on the data acquisition and
handling system (DAHS) for the continuous emission monitoring system (required by
Condition 1.8 in the following equation:
tons/mo = (EF, lbs/MMBtu) x heat input (IVEVIBM/mo)
2000 lbs/ton
Monthly emissions from each turbine/HRSG/duct burner shall be summed together
and used in a twelve month rolling total to monitor compliance with the annual
limitations. Each month a new twelve month total shall be calculated using the
previous twelve months data.
1.2.2 For purposes of BACT, Total (filterable plus condensable) Particulate Matter (PM)
and Particulate Matter less than 10 microns (PM10) emissions from each
turbine/HRSG/duct burner shall not exceed 0.00735 lbs/MMBtu, based on the
average of three (3) test runs (Colorado Construction Permit 02WE0228, as modified
under the provisions of Section I. Condition 1.3 to specify the averaging time).
Compliance with the PM and PM10 BACT limits shall be monitored as follows:
1.2.2.1 In the absence of credible evidence to the contrary, compliance with the
particulate matter emission limits is presumed since only pipeline quality
natural gas that meets the requirements in Condition 1.10 is permitted to
be used as fuel in the turbines and duct burners.
1.2.2.2 Performance tests shall be conducted every five (5) years to monitor
compliance with the PM and PM10 BACT emission limitations in
Condition 1.2.2. Performance test shall be conducted to measure total
(filterable plus condensable) PM and PM10 emissions in accordance with
the requirements and procedures in the appropriate EPA Test Methods.
Note that previous performance tests for these units were conducted on
October 6 and 7. 2015.
The test protocol, test. and test report must be in accordance with the
requirements of the APCD Compliance Test Manual
(https://www.colorado.g,ov/pacific/cdphe/inspections-and-enforcement). A
stack testing, protocol shall be submitted for Division approval at least
forty-five (45) calendar days prior to any performance of the test required
under this condition. No stack test required herein shall be performed
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 9
without prior approval of the protocol by the Division. The Division
reserves the right to witness the test. In order to facilitate the Division's
ability to make plans to witness the test, notice of the date(s) for the stack
test shall be submitted to the Division at least thirty (30) calendar days
prior to the test. The Division may for good cause shown, waive this
thirty (30) day notice requirement. In instances when a scheduling conflict
is presented, the Division shall immediately contact the permittee in order
to explore the possibility of making modifications to the stack test
schedule. The compliance test results shall be submitted to the Division
within forty-five (45) calendar days of the completion of the test unless a
longer period is approved by the Division.
1.3 VOC emissions are subject to the following requirements:
1.3.1 Total Annual emissions of VOC from both turbines/HRSGS/duct burners
together shall not exceed 50.6 tons/yr (Colorado Construction Permit 02WE0228, as
modified under the provisions of Section I, Condition 1.3 to set emission units for
individual equipment instead of a facility wide total). Monthly emissions from each
turbine/HRSG/duct burner shall be calculated by the end of the subsequent month
using the above emission factors (from performance tests conducted May and
September 2004) and the heat input for the month as recorded on the DAHS for the
continuous emission monitoring system (required by Condition 1.8) in the following
equation:
tons/mo = (EF, lbs/MMBtu) x heat input (MMBtu/mo)
2000 lbs/ton
Monthly emissions from each turbine/HRSG/duct burner shall be summed
together and used in a twelve month rolling total to monitor compliance with the
annual limitations. Each month a new twelve month total shall be calculated using
the previous twelve months data.
1.3.2 For purposes of BACT, VOC emissions from each turbine/HRSG/duct burner shall
not exceed 0.00293 lb/MMBtu, based on the average of three (3) test runs (Colorado
Construction Permit 02WE0228, as modified under the provisions of Section I.
Condition 1.3 to specify the averaging time). In the absence of credible evidence to
the contrary, compliance with the VOC BACT emission limit is presumed provided
the requirements in Condition 1.6.1 (CO BACT limits) are met.
1.4 Sulfur Dioxide (SO)) emissions shall not exceed the following limitations:
1.4.1 Total Annual Sulfur Dioxide (SO)) emissions from both turbines/HRSGs/Duct
Burner together shall not exceed 11.8 tons/yr (Colorado Construction Permit
02WE0228, as modified under the provisions of Section 1, Condition 1.3 to set
emission units for individual equipment instead of a facility wide total). Compliance
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Paue 10
with the annual SO2 emission limitations shall be monitored using the monitoring
method specified in 40 CFR Part 75 Appendix D.
Monthly emissions from each turbine/HRSG/duct burner shall be summed
together and used in a twelve month rolling total to monitor compliance with the
annual limitations. Each month a new twelve month total shall be calculated using
the previous twelve months data.
1.4.2 Each turbine shall meet one of the following requirements:
1.4.2.1 Sulfur Dioxide (SO?) emissions from each turbine shall not exceed 150
ppmvd at 15% O2 OR
1.4.2.2 No fuel, which contains sulfur in excess of 0.8 percent by weight, shall be
used in these combustion turbines (40 CFR Part 60 Subpart GG §§
60.333(a) & (b), as adopted by reference in Colorado Regulation No. 6,
Part A).
Compliance with the above requirements is presumed, in the absence of evidence to
the contrary, since only pipeline quality natural gas that meets the requirements in
Condition 1.10 is permitted to be used as fuel in these turbines.
1.4.3 Sulfur Dioxide (SO2) emissions from each turbine shall not exceed 0.35
lbs/MMBtu, on a 3 -hr 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 SO? limitations is presumed since only pipeline quality natural
gas that meets the requirements in Condition 1.10 is permitted to be used as fuel in
these turbines.
1.4.4 Sulfur Dioxide (SO2) emissions from each duct burner shall not exceed 0.20
lbs/MMBtu on a 30 -day rolling average (40 CFR Part 60 Subpart Da § 60.43a(b)(2),
as adopted by reference in Colorado Regulation No. 6, Part A). In the absence of
credible evidence to the contrary, compliance with the sulfur dioxide limitations is
presumed, since only pipeline quality natural gas that meets the requirements in
Condition 1.10 is permitted to be used as fuel in these duct burners.
1.5 Emissions of Nitrogen Oxides (NOx) shall not exceed the following limitations:
1.5.1 For purposes of BACT, Nitrogen Oxide (NOx) emissions from each
turbine/HRSG/duct burner shall not exceed the following limitations (Colorado
Construction Permit 02WE0228. as modified under the provisions of Section I,
Condition 1.3 to revise the definitions of startup and shutdown):
1.5.1.1 Except as provided for below, emissions of NOx shall not exceed 3 ppmvd
at 15% O,, on a 1 -hour average.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 11
1.5.1.2 During periods of startup and shutdown, emissions of NOx shall not
exceed 300 ppmvd at 15% O2, as averaged over the duration of the startup
and/or shutdown period.
1.5.1.3 During periods of combustion tuning and testing, emissions of NOx shall
not exceed 300 ppmvd at 15% O,, on a 1 -hour average. Use of this NOx
emission limit for purposes of combustion tuning and/or testing shall not
exceed 60 hours in any calendar year for both turbines/HRSGs/duct
burners combined. Records of the number of hours each
turbine/HRSG/duct burner undergoes combustion tuning and/or testing
shall be recorded and maintained and made available to the Division upon
request.
1.5.1.4 "Startup" means the setting in operation of any air pollution source for
any purpose. Setting in operation for these turbines begins when flame is
detected in the turbine. Setting in operation for these turbines ends 30
minutes after the turbine reaches Stage -C operation.
1.5.1.5 `'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.
1.5.1.6 "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 includes testing and tuning of the selective catalytic
reduction (SCR) system and can occur throughout the range of the
operating conditions.
Compliance with the NOx BACT emission limitations shall be monitored using the
continuous emission monitoring systems (CEMS) required by Condition 1.8, as
follows:
1.5.1.7 Except as provided for in Condition 1.5.1.8, 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 -hour average
NOx concentration in accordance with the requirements in 40 CFR Part 75
and Condition 6.1.1.4.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 6.5. Each clock hour
average NOx concentration shall be compared to the limitations in
Conditions 1.5.1.1 or 1.5.1.3, as appropriate.
1.5.1.8 All valid CEMS concentration (ppm) data points within the startup and/or
shutdown period shall be averaged together to generate the average NOx
concentration for a given startup and/or shutdown period. Data used to
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 12
generate the average NOx concentration during the startup and/or
shutdown period 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 6.5. The average NOx
concentration for each startup and shutdown period shall be compared to
the limitation in Condition 1.5.1.2.
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 6.1.1.4.b of this permit and
that average concentration shall be compared to the limitations in
Conditions 1.5.1.1 or 1.5.1.3, as appropriate.
1.5.1.9 The emission limitation in Condition 1.5.1.3 applies to any clock hour in
which combustion tuning and testing activities occur.
1.5.2 Total Annual emissions of NOx from both turbines/HRSGs/duct burners together
shall not exceed 240.4 tons/year (Colorado Construction Permit 02WE0228, as
modified under the provisions of Section I, Condition 1.3 to set emission units for
individual equipment instead of a facility wide total). Compliance with the annual
emission limitation shall be monitored using the continuous emission monitoring
systems (CEMS) required by Condition 1.8. For any hour in which fuel is combusted
in the turbines/HRSGs/duct burners, the permittee shall program the DAHs to
calculate lb/hr NOx emissions in accordance with the requirements in Condition
6.1.1.4.b of this permit and 40 CFR Part 75, including any replaced data and the data
shall be bias -adjusted, if warranted.
Specifically hourly mass NOx emissions (in lb/hr) shall be calculated by multiplying
the hourly NOx lb/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 lb/MMBtu and heat
input values shall be determined using equations F-5 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 lbs 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 turbine/HRSG/duct burner shall be
summed together and used in a twelve month rolling total to monitor compliance with
the annual emission limitation. Each month a new twelve month total shall be
calculated using the previous twelve months total.
1.5.3 Electric utility stationary gas turbines with a heat input at peak load greater than
107.2 gigajoules per hour (100 million Btu/hour) based on the lower heating value of
the fuel fired shall comply with the provisions of paragraph (a)(1) of this section. (40
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 13
CFR Part 60. Subpart GG § 60.334(b))) The NOx limit established by 60.334(a)(1) is
as follows:
1.5.3.1 NOx emissions from each turbine shall not exceed 102 ppmvd at 15% O2,
on a 4 -hour rolling average.
In accordance with § 60.335(b)(1), measured NOx emissions do not have
to be corrected to ISO standard conditions.
Compliance with the above limitation shall be monitored using the
continuous emission monitoring system required by Condition 1.8 except
that as specified in § 60.334(b)(3)(iii), the missing data substitution
methodology specified in 40 CFR Part 75 Subpart D, is not required for
purposes of identifying excess emissions. Instead, periods of missing
CEMS data are to be reported as monitor downtime in the excess
emissions and monitoring performance report required by Condition 6.5.
Note that the NOx emission limits in this Condition 1.5.3.1 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 6.5.
1.5.3.2 For each affected unit that elects to continuously monitor parameters or
emissions, or to periodically determine the fuel sulfur content or fuel
nitrogen content under this subpart, the owner or operator shall submit
reports of excess emissions and monitor downtime, in accordance with
§60.7(c) (Condition 6.5). Excess emissions shall be reported for all
periods of unit operation, including startup, shutdown and malfunction.
For the purpose of reports required under §60.7(c) (Condition 6.5), periods
of excess emissions and monitor downtime that shall be reported are
defined as follows:
a. An hour of excess emissions shall be any unit operating hour in
which the 4 -hour rolling average NOx concentration exceeds the
applicable emission limit in §60.332(a)(1) or (2) (Condition
1.5.3.1). For the purposes of this subpart, a "4 -hour rolling average
NOx concentration" is the arithmetic average of the average NOx
concentration measured by the CEMS for a given hour (corrected
to 15 percent O2 and, if required under §60.335(b)(1), to ISO
standard conditions) and the three unit operating hour average
NOx concentrations immediately preceding that unit operating
hour. (60.334(j)(1)(iii)(A))
b. A period of monitor downtime shall be any unit operating hour in
which sufficient data are not obtained to validate the hour, for
either NOx concentration or diluent (or both). (60.334(j)(1)(iii)(B))
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 14
1.6 Emissions of Carbon Monoxide (CO) shall not exceed the following limitations:
1.6.1 For purposes of BACT, Carbon Monoxide (CO) emissions from each
turbine/HRSG/duct burner shall not exceed the following limitations (Colorado
Construction Permit 02WE0228. as modified under the provisions of Section I,
Condition 1.3 to revise the definition of startup and shutdown and to remove the limit
for CO during the 1St hour of a cold startup):
1.6.1.1 Except as provided for below, emissions of CO shall not exceed 9 ppmvd
at 15% O,, on a 1 -hour average.
1.6.1.2 During periods of startup and shutdown, emissions of CO shall not exceed
1,000 ppmvd at 15% O2, as averaged over the duration of the startup
and/or shutdown period.
1.6.1.3 During periods of combustion tuning and testing, emissions of CO shall
not exceed 1,000 ppmvd at 15% O,, on a 1 -hour average. Use of this CO
emission limit for purposes of combustion tuning and/or testing shall not
exceed 60 hours in any calendar year for both turbines/HRSGs/duct
burners combined. Records of the number of hours each
turbine/HRSG/duct burner undergoes combustion tuning and/or testing
shall be recorded and maintained and made available to the Division upon
request.
1.6.1.4 "Startup" shall have the same definition as in Condition 1.5.1.4
1.6.1.5 `'Shutdown" shall have the same definition as in Condition 1.5.1.5.
1.6.1.6 "Combustion Tuning and Testing" shall have the same definition as
provided for in Condition 1.5.1.6.
Compliance with the CO BACT emission limitations shall be monitored using the
CEMS required by Condition 1.8, as follows:
1.6.1.7 Except as provided for in Condition 1.6.1.8, 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 -hour average
CO concentration in accordance with the requirements in 40 CFR Part 75
and Condition 6.1.1.4.b of this permit. Data used to generate the one -hour
average CO 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 6.5. Each clock hour
average CO concentration shall be compared to the limitations in
Conditions 1.6.1.1 or 1.6.1.3, as appropriate.
1.6.1.8 All valid CEMS concentration (ppm) data points within the startup and/or
shutdown period shall be averaged together to generate the average CO
concentration for a given startup and/or shutdown period. Data used to
generate the average CO concentration during the startup and/or shutdown
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 15
period 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 6.5. The average CO concentration for each
startup and shutdown period shall be compared to the limitation in
Condition 1.6.1.2.
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 CO concentration in accordance with the
requirements in 40 CFR Part 75 and Condition 6.1.1.4.b of this permit and
that average concentration shall be compared to the limitations in
Conditions 1.6.1.1 or 1.6.1.3, as appropriate.
1.6.1.9 The emission limitation in Condition 1.6.1.3 applies to any clock hour in
which combustion turning and testing activities occur.
1.6.2 Total Annual emissions of CO from both turbines/HRSGs/duct burners together
shall not exceed 782.2 tons/yr (Colorado Construction Permit 02WE0228. as
modified under the provisions of Section I, Condition 1.3, to set emission units for
individual equipment instead of a facility wide total). Compliance with the annual
emission limitation shall be monitored using the continuous emission monitoring
systems (CEMS) required by Condition 1.8 For any hour in which fuel is combusted
in the turbines/HRSGs/duct burners, the permittee shall program the DAHs to
calculate lb/hr CO emissions in accordance with the requirements in Condition
6.1.I.4.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 lb/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 includes replaced data from the stack flow measurement,
as applicable). The hourly CO lb/MMBtu and heat input values shall be determined
using equations F-5 (for NOx) and F-20 in Appendix F of 40 CFR Part 75. The
resulted CO lb/hr value is then multiplied by the unit operating time for that hour to
produce a CO lbs value. Hourly CO mass emissions (lbs) shall be summed and
divided by 2000 lb/ton to determine monthly CO emissions (in tons).
Monthly emissions (in tons) from each turbine/HRSG/duct burner shall be
summed together and 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 total.
1.7 Total natural gas consumption for both turbines/HRSGs/duct burners together shall not
exceed the above limitations (Colorado Construction Permit 02WE0228). The natural gas
consumption for each turbine/HRGS/duct burner shall be monitored and recorded monthly
using the fuel flow meters required by Condition 1.9. Monthly natural gas fuel consumption for
each turbine/HRSG/duct burner shall be summed together and used in a rolling twelve month
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 16
total to monitor compliance with the annual limitation. Each month a new twelve month rolling
total shall be calculated using the previous twelve months data.
1.8 Each of the turbine/HRSG/duct burner exhaust stacks shall be equipped with a continuous
emission monitoring system to measure and record the following:
1.8.1 Concentration of Oxides of Nitrogen; ppmvd corrected to 15 % O2, hourly average;
1.8.2 Emissions of Oxides of Nitrogen; pounds per hour, tons per month;
1.8.3 Concentration of Carbon Monoxide; ppmvd corrected to 15% O2, hourly average;
1.8.4 Emissions of Carbon Monoxide, pounds per hour, tons per month;
1.8.5 Concentration of Oxygen, percent hourly average;
1.8.6 Operating mode — startup, shutdown and/or standard operation; and
The continuous emission monitoring systems shall meet the requirements in Condition 6 of this
permit. Monthly emissions of NOx and CO from the continuous emission monitoring system
shall be used as specified by Conditions 1.5.2 and 1.6.2 to monitor compliance with the annual
NOx and CO emission limitations.
1.9 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 (Colorado Construction Permit 02WE0228).
1.10 The permittee shall maintain records demonstrating that the natural gas burned meets the
definition of pipeline quality natural gas as defined in 40 CFR Part 72. Specifically, the
permittee shall demonstrate that the natural gas burned has a total sulfur content less than 0.5
grains/100 SCF. The demonstration shall be made using any of the methods identified in 40
CFR Part 75 Appendix D. Section 2.3.1.4. These records shall be made available to the Division
upon request.
1.11 Regulation No. 6, Part A, Subpart A, General Provisions apply as follows:
No article, machine, equipment or process shall be used to conceal 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 gasses discharged to the atmosphere. (Colorado Construction Permit
01AD0575 and 40 CFR Part 60 Subpart A § 60.12, as adopted by reference in
Colorado Regulation No. 6. Part A)
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 17
1.1 1.2 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 (Colorado Construction Permit 01 AD0575
and 40 CFR Part 60 Subpart A § 60.11(d), as adopted by Regulation No. 6. Part A).
1.12 The turbines/HRSGs/duct burners are subject to the following opacity requirements:
1.12.1 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 turbine/HRGS/duct burner.
This opacity standard applies at all times except during periods of startup, shutdown
and malfunction (40 CFR Part 60 Subpart A § 60.11(c), as adopted by reference in
Colorado Regulation No. 6, Part B. Section 1.A).
Note that this opacity requirement is more stringent than the opacity requirement in
Conditions 1.12.2 and 1.12.4 during periods of building of a new fire, cleaning of fire
boxes, soot blowing, process modifications and adjustment or occasional cleaning of
control equipment.
1.12.2 No owner or operator of a source shall cause to be discharged into the atmosphere
from any affected facility any gases which exhibit greater than 20 percent opacity (6 -
minute average), except for one 6 -minute period per hour of not more than 27 percent
opacity ((40 CFR Part 60 Subpart Da § 60.42a(b), as adopted by reference in
Colorado Regulation No. 6, Part A and Colorado Construction Permit 99W E0762
PSD). This opacity standard applies to each duct burner.
This opacity standard applies at all times except during periods of startup, shutdown
and malfunction (40 CFR Part 60 Subpart A § 60.11(c), as adopted by reference in
Colorado Regulation No. 6, Part A).
Note that this opacity requirement is more stringent than the opacity requirement in
Condition 1.12.4 during periods of building of a new fire, cleaning of fire boxes, soot
blowing, process modifications and adjustment or occasional cleaning of control
equipment.
1.12.3 Except as provided for in Condition 1.12.4 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 (Colorado Construction Permit 02WE0228 and Colorado
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 18
Regulation No. 1, Section II.A.1). This opacity standard applies to each
turbine/HRGS/duct burner.
1.12.4 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 Construction Permit 02WE0228 and Colorado Regulation No. 1, Section
II.A.4). This opacity standard applies to each turbine/HRGS/duct burner.
In the absence of credible evidence to the contrary, compliance with the opacity limits shall be
presumed since only natural gas is permitted to be used as fuel in the turbines and duct buners.
1.13 The Compliance Assurance Monitoring (CAM) requirements in 40 CFR Part 64, as adopted by
reference in Colorado Regulation No. 3. Part C. Section XIV, apply with respect to the VOC,
NOx and CO emission limitations identified in Conditions 1.3, 1.5 and 1.6 as follows:
1.13.1 The permittee shall monitor the exhaust gas NOx and CO concentration (ppmvd at
15% O)) and mass (lbs/hr) emissions using the continuous emission monitoring
system required by Condition 1.8.
1.13.1.1 With respect to the NOx and CO emission limitations, exceedances, for
purposes of CAM, shall be
a. Any 1 -hr period that the NOx and/or CO concentration exceeds the
limits identified in Condition 1.5.1.1 and 1.6.1.1;
b. Any NOx and/or CO concentration average over either a startup
and/or shutdown period that exceeds the limits identified in
Conditions 1.5.1.2 and 1.6.1.2; and
c. Any twelve month period that NOx and/or CO emissions (tons/yr)
exceeds the limits identified in Condition 1.5.2 and 1.6.2.
1.13.1.2 With respect to the VOC emissions limitations, excursions for the
purposes of CAM, shall be:
a. Any 1 -hr period that the CO concentration exceeds the limit
identified in Condition 1.6.1.1;
b. Any CO concentration average over either a startup and/or
shutdown period that exceeds the limit identified in Condition
1.6.1.2; and
c. Any twelve month period that CO emissions (tons/yr) exceed the
limit identified in Condition 1.6.2.
1.13.1.3 Exceedances and/or excursions shall be reported as required by Section II,
Condition 6.5 and Section V. Conditions 21 and 22.d of this permit.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 19
1.13.2 Operation of Approved Monitoring
1.13.2.1 At all times, the owner or operator shall maintain the monitoring,
including but not limited to, maintaining necessary parts for routine
repairs of the monitoring equipment (40 CFR Part 64 § 64.7(b), as adopted
by reference in Colorado Regulation No. 3, Part C, Section XIV).
1.13.2.2 Except for, as applicable, monitoring malfunctions, associated repairs. and
required quality assurance or control activities (including, as applicable,
calibration checks and required zero and span adjustments), the owner or
operator shall conduct all monitoring in continuous operation (or shall
collect data at all required intervals) at all times that the pollutant -specific
emissions unit is operating. Data recorded during monitoring
malfunctions, associated repairs, and required quality assurance or control
activities shall not be used for purposes of these CAM requirements,
including data averages and calculations, or fulfilling a minimum data
availability requirement, if applicable. The owner or operator shall use all
the data collected during all other periods in assessing the operation of the
control device and associated control system. A monitoring malfunction
is any sudden, infrequent, not reasonably preventable failure of the
monitoring to provide valid data. Monitoring failures that are caused in
part by poor maintenance or careless operation are not malfunctions (40
CFR Part 64 § 64.7(c), as adopted by reference in Colorado Regulation
No. 3, Part C, Section XIV).
1.13.2.3 Response to excursions or exceedances
a. Upon detecting an excursion or exceedance, the owner or operator
shall restore operation of the pollutant -specific emissions unit
(including the control device and associated capture system) to its
normal or usual manner of operation as expeditiously as
practicable in accordance with good air pollution control practices
for minimizing emissions. The response shall include minimizing
the period of any startup, shutdown or malfunction and taking any
necessary corrective actions to restore normal operation and
prevent the likely recurrence of the cause of an excursion or
exceedance (other than those caused by excused startup or
shutdown conditions). Such actions may include initial inspection
and evaluation, recording that operations returned to normal
without operator action (such as through response by a
computerized distribution control system), or any necessary
follow-up actions to return operation to within the indicator range,
designated condition, or below the applicable emission limitation
or standard, as applicable (40 CFR Part 64 § 64.7(d)(1), as adopted
by reference in Colorado Regulation No. 3. Part C, Section XIV).
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 20
b. Determination of whether the owner of operator has used
acceptable procedures in response to an excursion or exceedance
will be based on information available, which may include but is
not limited to, monitoring results, review of operation and
maintenance procedures and records, and inspection of the control
device, associated capture system, and the process (40 CFR Part 64
§ 64.7(d)(2), as adopted by reference in Colorado Regulation No.
3. Part C. Section XIV).
1.13.2.4 After approval of the monitoring required under the CAM requirements, if
the owner or operator identifies a failure to achieve compliance with an
emission limitation or standard for which the approved monitoring did not
provide an indication of an excursion or exceedance while providing valid
data, or the results of compliance or performance testing document a need
to modify the existing indicator ranges or designated conditions, the owner
or operator shall promptly notify the Division and, if necessary submit a
proposed modification for this permit to address the necessary monitoring
changes. Such a modification may include, but is not limited to,
reestablishing indicator ranges or designated conditions, modifying the
frequency of conducting monitoring and collecting data, or the monitoring
of additional parameters (40 CFR Part 64 § 64.7(e), as adopted by
reference in Colorado Regulation No. 3. Part C, Section XIV).
1.13.3 Quality Improvement Plan (QIP) Requirements
1.13.3.1 Based on the results of a determination made under the provisions of
Condition 1.13.2.3.b, the Division may require the owner or operator to
develop and implement a QIP (40 CFR Part 64 § 64.8(a), as adopted by
reference in Colorado Regulation No. 3, Part C. Section XIV).
1.13.3.2 The owner or operator shall maintain a written QIP, if required, and have
it available for inspection (40 CFR Part 64 § 64.8(b)(1), as adopted by
reference in Colorado Regulation No. 3, Part C, Section XIV).
1.13.3.3 The QIP initially shall include procedures for evaluating the control
performance problems and, based on the results of the evaluation
procedures, the owner or operator shall modify the plan to include
procedures for conducting one or more of the following actions, as
appropriate:
a. Improved preventative maintenance practices (40 CFR Part 64 §
64.8(b)(2)(i), as adopted by reference in Colorado Regulation No.
3. Part C. Section XIV).
b. Process operation changes (40 CFR Part 64 § 64.8(b)(2)(ii), as
adopted by reference in Colorado Regulation No. 3, Part C,
Section XIV).
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 21
c. Appropriate improvements to control methods (40 CFR Part 64 §
64.8(b)(2)(iii), as adopted by reference in Colorado Regulation No.
3, Part C, Section XIV).
d. Other steps appropriate to correct control performance (40 CFR
Part 64 § 64.8(b)(2)(iv), as adopted by reference in Colorado
Regulation No. 3, Part C, Section XIV).
e. More frequent or improved monitoring (only in conjunction with
one or more steps under Conditions 1.13.3.3.a through d above)
(40 CFR Part 64 § 64.8(b)(2)(v), as adopted by reference in
Colorado Regulation No. 3, Part C, Section XIV).
1.13.3.4 If a QIP is required, the owner or operator shall develop and implement a
QIP as expeditiously as practicable and shall notify the Division if the
period for completing the improvements contained in the QIP exceeds 180
days from the date on which the need to implement the QIP was
determined (40 CFR Part 64 § 64.8(c), as adopted by reference in
Colorado Regulation No. 3, Part C, Section XIV).
1.13.3.5 Following implementation of a QIP, upon any subsequent determination
pursuant to Condition 1.13.2.3.b, the Division or the U.S. EPA may
require that an owner or operator make reasonable changes to the QIP if
the QIP is found to have:
a. Failed to address the cause of the control device performance
problems (40 CFR Part 64 § 64.8(d)(1), as adopted by reference in
Colorado Regulation No. 3, Part C, Section XIV); or
b. Failed to provide adequate procedures for correcting control device
performance problems as expeditiously as practicable in
accordance with good air pollution control practices for
minimizing emissions (40 CFR Part 64 § 64.8(d)(2), as adopted by
reference in Colorado Regulation No. 3, Part C, Section XIV).
1.13.3.6 Implementation of a QIP shall not excuse the owner or operator of a
source from compliance with any existing emission limitation or standard.
or any existing monitoring, testing, reporting or recordkeeping
requirement that may apply under federal, state, or local law, or any other
applicable requirements under the federal clean air act (40 CFR Part 64 §
64.8(e), as adopted by reference in Colorado Regulation No. 3, Part C,
Section XIV).
1.13.4 Reporting and Recordkeeping Requirements
1.13.4.1 Reporting Requirements: The reports required by Section V, Condition
22.d, shall contain the information specified in Appendix B of the permit
and the following information, as applicable:
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 22
a. Summary information on the number, duration and cause
(including unknown cause, if applicable), for monitor downtime
incidents (other than downtime associated with zero and span or
other daily calibration checks, if applicable) ((40 CFR Part 64 §
64.9(a)(2)(ii), as adopted by reference in Colorado Regulation No.
3, Part C, Section XIV); and
b. The owner or operator shall submit, if necessary, a description of
the actions taken to implement a QIP during the reporting period as
specified in Condition 1.13.3 of this permit. Upon completion of a
QIP, the owner or operator shall include in the next summary
report documentation that the implementation of the plan has been
completed and reduced the likelihood of similar levels of
excursions or exceedances occurring (40 CFR Part 64 §
64.9(a)(2)(iii), as adopted by reference in Colorado Regulation No.
3, Part C, Section XIV).
1.13.4.2 General Recordkeeping Requirements: In addition to the recordkeeping
requirements in Section V. Condition 22.a through c.
a. The owner or operator shall maintain records of any written QIP
required pursuant to Condition 1.13.3 and any activities undertaken
to implement a QIP, and any supporting information required to be
maintained under these CAM requirements (such as data used to
document the adequacy of monitoring, or records of monitoring
maintenance or corrective actions) (40 CFR Part 64 § 64.9(b)(1),
as adopted by reference in Colorado Regulation No. 3, Part C.
Section XIV).
b. Instead of paper records, the owner or operator may maintain
records on alternative media, such as microfilm, computer files,
magnetic tape disks, or microfiche, provided that the use of such
alternative media allows for expeditious inspection and review,
and does not conflict with other applicable recordkeeping
requirements (40 CFR Part 64 § 64.9(b)(2), as adopted by
reference in Colorado Regulation No. 3, Part C, Section XIV).
1.13.5 Savings Provisions
1.13.5.1 Nothing in these CAM requirements shall excuse the owner or operator of
a source from compliance with any existing emission limitation or
standard, or any existing monitoring, testing, reporting or recordkeeping
requirement that may apply under federal, state, or local law, or any other
applicable requirements under the federal clean air act. These CAM
requirements shall not be used to justify the approval of monitoring less
stringent than the monitoring which is required under separate legal
authority and are not intended to establish minimum requirements for the
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 23
purposes of determining the monitoring to be imposed under separate
authority under the federal clean air act, including monitoring in permits
issued pursuant to title I of the federal clean air act. The purpose of the
CAM requirements is to require, as part of the issuance of this Title V
operating permit, improved or new monitoring at those emissions units
where monitoring requirements do not exist or are inadequate to meet the
requirements of CAM (40 CFR Part 64 § 64.10(a)(1), as adopted by
reference in Colorado Regulation No. 3, Part C, Section XIV).
1.13.5.2 Nothing in these CAM requirements shall restrict or abrogate the authority
of the U.S. EPA or the Division to impose additional or more stringent
monitoring, recordkeeping, testing or reporting requirements on any owner
or operator of a source under any provision of the federal clean air act,
including but not limited to sections 114(a)(1) and 504(b), or state law, as
applicable (40 CFR Part 64 § 64.10(a)(2), as adopted by reference in
Colorado Regulation No. 3, Part C. Section XIV).
1.13.5.3 Nothing in these CAM requirements shall restrict or abrogate the authority
of the U.S. EPA or the Division to take any enforcement action under the
federal clean air act for any violation of an applicable requirement or of
any person to take action under section 304 of the federal clean air act (40
CFR Part 64 § 64.10(a)(2). as adopted by reference in Colorado
Regulation No. 3, Part C, Section XIV).
1 14 These units are subject to the Title IV Acid Rain Requirements. As specified in 40 CFR Part
72.72(b)(1)(viii), the acid rain permit requirements shall be complete and segregable portion of
the Operating Permit. As such the requirements are found in Section III of this permit.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 24
2. Diesel Fuel Fired Emergency Engines
S005- Emergency Generator Rated at 1,810 hp
Parameter
Permit
Condition
Number
Limitations
Short Term Long Term
Compliance
Emission Factor
Monitoring
Method Interval
Hours of
Operation
2.1
N/A
N/A
Recordkeeping
Annually
SO,
2.2
0.8 Ibs/NLNIBtu
N/A
Fuel Restriction
Only Diesel
Fuel is Used
as Fuel
Opacity
2.3
Not to Exceed 20% Except as
Provided for Below
N/A
EPA Method 9
See Condition
2.3
For Startup — Not to Exceed
30%, for a Period or Periods
Aggregating More than Six (6)
Minutes in any 60 Consecutive
Minutes
MACT ZZZZ
Requirements
2.4
Change Oil and Filter
Inspect Air Cleaner
Inspect all Hoses and Belts
N/A
See Condition 2.4
Note that this emission unit is exempt from the APEN reporting requirements in Regulation No. 3, Part A provided actual,
uncontrolled emissions do not exceed the APEN de minimis level (I ton/yr of NON) per Colorado Regulation No. 3, Part A,
Section II.D.I.a. Based on manufacturer's emission factors (6.9 g/hp-hr), and design rate (1,810 hp), emissions exceed the APEN
de minimis level at 73 hrs.
M003- Emergency Fire Pump Engine Rated at 182 hp
Parameter
Permit
Condition
Number
Limitations
Short Term
Long Term
Compliance
Emission Factor
Method
Monitoring
Interval
Hours of
Operation
2.1
N/A
N/A
Recordkeeping
Annually
SO2
2.2
0.8 lbs/MMBtu
N/A
Fuel Restriction
Only Diesel
Fuel is Used
as Fuel
Opacity
2.3
Not to Exceed 20% Except as
Provided for Below
N/A
EPA Method 9
See Condition
2.3
For Startup — Not to Exceed
30%, for a Period or Periods
Aggregating More than Six (6)
Minutes in any 60 Consecutive
Minutes
MACT ZZZZ
Requirements
2.4
Change Oil and Filter
Inspect Air Cleaner
Inspect all Hoses and Belts
N/A
See Condition 2.4
Operating Permit Number: 05OPWE279
First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 25
Note that this emission unit is exempt from the APEN reporting requirements in Regulation No. 3. Part A provided actual.
uncontrolled emissions do not exceed the APEN de minimis level (1 ton/yr of NON) per Colorado Regulation No. 3, Part A.
Section II.D.I.a. Based on manufacturer's emission factors (5.89 g/hp-hr), and design rate (182 hp), emissions exceed the APEN
de minimis level at 846 hrs.
2.1 Hours of operation for each engine shall be monitored annually (calendar year) and recorded in
a log to be made available to the Division upon request.
If annual hours of operation exceed 73 for the emergency generator or 846 hours for the
emergency fire pump engine, an APEN is required for that engine and an APEN shall be filed.
If annual hours of operation exceed 250 hours for the emergency generator, the engine is no
longer exempt from the permitting requirements in Colorado Regulation No.3, Part B and the
permittee shall submit an an application to revise this permit within 30 days in order to include
the appropriate applicable requirements.
2.2 Sulfur Dioxide (SO2) emissions from each engine shall not exceed 0.8 lbs/MMBtu (Colorado
Regulation No. 1, Section VI.B.4.b.(i)). In the absence of credible evidence to the contrary,
compliance with the SO2 emission limitation shall be presumed since only diesel fuel is
permitted to be used as fuel in these engines. The permittee shall maintain records that verify
that only diesel fuel is used as fuel in these engines.
2.3 Opacity of emissions from each engine shall not exceed the following:
2.3.1 Except as provided for in Condition 2.3.2 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 (Colorado Regulation No. 1, Section 11.A.I).
2.3.2 No owner or operator of a source shall allow or cause to be emitted into the
atmosphere any air pollutant resulting from startup 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).
Compliance with these limitations shall be monitored by conducting opacity observations in
accordance with EPA Reference Method 9 as follows:
2.3.3 As specified in Condition 2.4.8 engine startup shall not exceed 30 minutes. An
engine startup period of less than 30 minutes shall not require an opacity observation
to monitor compliance with the opacity limit in Condition 2.3.2. A record shall be
kept of the date and time each engine was started and when it was shutdown.
2.3.4 An opacity observation shall be conducted annually (calendar year period) on each
engine to monitor compliance with the opacity limit in Condition 2.3.1. Annual
opacity observations for an individual engine shall be separated by a period of four
(4) months.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 26
If an engine is operated more than 250 hours in any calendar year period, a second
opacity observation shall be conducted. If two opacity readings are conducted in the
annual (calendar year) period, such readings shall be conducted at least thirty days
apart.
2.3.5 If an engine is not operated during the annual (calendar year) period, then no opacity
observation is required.
2.3.6 Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible
evidence to the contrary, exceedance of the limit shall be considered to exist from the
time a Method 9 reading is taken that shows an exceedance of the opacity limit until a
Method 9 reading is taken that shows the opacity is less than the opacity limit.
2.3.7 All opacity observations shall be performed by an observer with current and valid
Method 9 certification. Results of Method 9 readings and a copy of the certified
Method 9 reader's certificate shall be kept on site and made available to the Division
upon request.
2.4 Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion
Engines", as follows:
The requirements below reflect the current rule language as of the revisions to 40 CFR Part 63
Subpart ZZZZ published in the Federal Register on January 30, 2013 (including the corrections
published March 6, 2013 and revisions to test methods published February 27, 2014). 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 63 Subpart ZZZZ.
The D. C. Circuit Court issued a mandate on May 4. 2016 for vacatur for certain requirements
allowing emergency engines to operate for limited hours for demand response. Upon issuance of
the mandate § 63.6640(f)(2)(ii)-(iii) (Conditions 2.4.11.2.b and 2.4.11.2.c) have no legal effect.
Operation of emergency engines is limited to emergency situations specified in 63.6640(O(1)
(Condition 2.4.11.1); maintenance checks and readiness testing for a limited number of hours
per year as specified in 63.6640(f)(2)(i) (Condition 2.4.11.2.a); and certain non -emergency
situations for a limited number of hours per year as specified in 63.6640(f)(3)—(4) (Condition
2.4.11.3). See EPA memorandum dated April 15, 2016 regarding "Guidance on Vacatur of RICE
NESHAP and NSPS Provisions for Emergency Engines" for more information.
It should be noted that additional revisions to the requirements in 40 CFR Part 63 Subpart ZZZZ
are expected to be made in response to issues related to legal action associated with the allowable
hours of operation provisions for emergency engines regarding engines used for demand
response. If such revisions are finalized prior to issuance of the permit, they will be included in
the permit.
As of the date of this permit issuance [DATE]. the requirements in 40 CFR Part 63 Subpart
ZZZZ promulgated after July 1, 2007 have not been adopted into Colorado Regulation No. 8,
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 27
Part E and are therefore not state -enforceable. In the event that these requirements are adopted
into Colorado Regulations, they will become state -enforceable.
When do I have to comply with this subpart (§ 60.6595)
2.4.1 If you have an existing stationary CI RICE located at an area source of HAP
emissions, you must comply with the applicable emission limitations and operating
limitations no later than May 3, 2013. (§ 63.6595(a)(1))
What emission limitations, operating limitations, and other requirements must I meet if I own or
operate an existing CI RICE located at an area source of HAP emissions (f 63.6603)
2.4.2 If you own or operate an existing stationary CI RICE located at an area source of
HAP emissions, you must comply with the requirements in Table 2d to this subpart
and the operating limitations in Table 2b to this subpart which apply to you. (§
63.6603(a)) The requirements in Table 2d that apply to these emergency CI RICE are
as follows:
2.4.2.1 Change oil and filter every 500 hours of operation or annually whichever
comes first. (Table 2d, item 4.a)
2.4.2.2 Inspect air cleaner every 1,000 hours of operation or annually whichever
comes first, and replace as necessary. (Table 2d, item 4.b)
2.4.2.3 Inspect all hoses and belts every 500 hours of operation or annually
whichever comes first, and replace as necessary. (Table 2d, item 4.c)
Notwithstanding the above requirements, the following applies:
2.4.2.4 Sources have the option to utilize an oil analysis program as described in
Condition 2.4.9 in order to extend the specified oil change requirement in
Condition 2.4.2.1. (Table 2d, footnote 1)
2.4.2.5 If an emergency engine is operating during an emergency and it is not
possible to shut down the engine in order to perform the management
practice requirements on the schedule required in Conditions 2.4.2.1
through 2.4.2.3, or if performing the management practice on the required
schedule would otherwise pose an unacceptable risk under federal, state,
or local law, the management practice can be delayed until the emergency
is over or the unacceptable risk under federal, state, or local law has
abated. The management practice should be performed as soon as
practicable after the emergency has ended or the unacceptable risk under
federal, state, or local law has abated. Sources must report any failure to
perform the management practice on the schedule required and the federal,
state or local law under which the risk was deemed unacceptable. (Table
2d, footnote 2)
What fuel requirements must I meet if I own or operate a stationary CI RICE? (f 63.6604)
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 28
2.4.3 Beginning January 1, 2015, if you own or operate an existing emergency CI
stationary RICE with a site rating of more than 100 brake HP and a displacement of
less than 30 liters per cylinder that uses diesel fuel and operates or is contractually
obligated to be available for more than 15 hours per calendar year for the purposes
specified in §63.6640(f)(2)(ii) and (iii) (Conditions 2.4.11.2.b and 2.4.11.2.c) or that
operates for the purpose specified in §63.6640(f)(4)(ii), you must use diesel fuel that
meets the requirements in 40 CFR 80.510(b) for nonroad diesel fuel, except that any
existing diesel fuel purchased (or otherwise obtained) prior to January 1, 2015, may
be used until depleted. (63.6604(b))
What are my general requirements for complying with this subpart? (7 63.6605)
2.4.4 You must be in compliance with the emission limitations, operating limitations, and
other requirements in this subpart that apply to you at all times. (§ 63.6605(a))
2.4.5 At all times you must operate and maintain any affected source, including associated
air pollution control equipment and monitoring equipment, in a manner consistent
with safety and good air pollution control practices for minimizing emissions. The
general duty to minimize emissions does not require you to make any further efforts
to reduce emissions if levels required by this standard have been achieved.
Determination of whether such operation and maintenance procedures are being used
will be based on information available to the Administrator which may include, but is
not limited to, monitoring results, review of operation and maintenance procedures,
review of operation and maintenance records, and inspection of the source. (§
63.6605(b))
What are my monitoring, installation, collection, operation, and maintenance requirements? ((
63.6625)
2.4.6 If you own or operate an existing emergency or black start stationary RICE located at
an area source of HAP emissions, you must operate and maintain the stationary RICE
and after -treatment control device (if any) according to the manufacturer's emission -
related written instructions or develop your own maintenance plan which must
provide to the extent practicable for the maintenance and operation of the engine in a
manner consistent with good air pollution control practice for minimizing emissions:
(§ 63.6625(e) and (e)(3))
2.4.7 If you own or operate an existing emergency stationary RICE with a site rating of less
than or equal to 500 brake HP located at a major source of HAP emissions or an
existing emergency stationary RICE located at an area source of HAP emissions, you
must install a non-resettable hour meter if one is not already installed. (§ 63.6625(f))
2.4.8 If you operate a new, reconstructed, or existing stationary engine, you must minimize
the engine's time spent at idle during startup and minimize the engine's startup time
to a period needed for appropriate and safe loading of the engine, not to exceed 30
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 29
minutes, after which time the emission standards applicable to all times other than
startup in Tables I a, 2a, 2c, and 2d to this subpart apply. (§ 63.6625(h))
2.4.9 If you own or operate a stationary CI engine that is subject to the work, operation or
management practices in Condition 2.4.2, you have the option of utilizing an oil
analysis program in order to extend the specified oil change requirement in Condition
2.4.2.1. The oil analysis must be performed at the same frequency specified for
changing the oil in Condition 2.4.2.1. The analysis program must at a minimum
analyze the following three parameters: Total Base Number, viscosity, and percent
water content. The condemning limits for these parameters are as follows: Total Base
Number is less than 30 percent of the Total Base Number of the oil when new;
viscosity of the oil has changed by more than 20 percent from the viscosity of the oil
when new; or percent water content (by volume) is greater than 0.5. If all of these
condemning limits are not exceeded, the engine owner or operator is not required to
change the oil. If any of the limits are exceeded, the engine owner or operator must
change the oil within 2 business days of receiving the results of the analysis; if the
engine is not in operation when the results of the analysis are received, the engine
owner or operator must change the oil within 2 business days or before commencing
operation, whichever is later. The owner or operator must keep records of the
parameters that are analyzed as part of the program, the results of the analysis, and
the oil changes for the engine. The analysis program must be part of the maintenance
plan for the engine. (§ 63.6625(i))
How do I demonstrate continuous compliance with the emission limitations, operating
limitations and other requirements? (' 63.6640)
2.4.10 You must demonstrate continuous compliance with each emission limitation,
operating limitation, and other requirements in Tables la and lb, Tables 2a and 2b,
Table 2c, and Table 2d [Condition 2.4.2] to this subpart that apply to you according to
methods specified in Table 6 to this subpart. (§ 63.6640(a)) The methods specified in
Table 6 of Subpart ZZZZ are as follows:
2.4.10.1 Operating and maintaining the stationary RICE according to the
manufacturer's emission -related operation and maintenance instructions
(Subpart ZZZZ, Table 6, item 9.a.i); or
2.4.10.2 Develop and follow your own maintenance plan which must provide to the
extent practicable for the maintenance and operation of the engine in a
manner consistent with good air pollution control practice for minimizing
emissions. (Subpart ZZZZ, Table 6, item 9.a.ii)
2.4.11 If you own or operate an emergency stationary RICE, you must operate the
emergency stationary RICE according to the requirements in Condition 2.4.11.1
through 2.4.1 1.3. In order for the engine to be considered an emergency stationary
RICE under this subpart, any operation other than emergency operation, maintenance
and testing, emergency demand response, and operation in non -emergency situations
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 30
for 50 hours per year, as described in Condition 2.4.11.1 through 2.4.11.3, is
prohibited. If you do not operate the engine according to the requirements in
Condition 2.4.11.1 through 2.4.11.3, the engine will not be considered an emergency
engine under this subpart and must meet all requirements for non -emergency engines.
(§ 63.6640(f))
2.4.11.1 There is no time limit on the use of emergency stationary RICE in
emergency situations. (§ 63.6640(f)(1))
2.4.11.2 You may operate your emergency stationary RICE for any combination of
the purposes specified in Conditions 2.4.11.2.a through c for a maximum
of 100 hours per calendar year. Any operation for non -emergency
situations as allowed by Condition 2.4.11.3 counts as part of the 100 hours
per calendar year allowed by this Condition 2.4.11.2. (§ 63.6640(f)(2))
a. Emergency stationary RICE may be operated for maintenance
checks and readiness testing. provided that the tests are
recommended by federal, state or local government, the
manufacturer, the vendor, the regional transmission organization or
equivalent balancing authority and transmission operator, or the
insurance company associated with the engine. The owner or
operator may petition the Administrator for approval of additional
hours to be used for maintenance checks and readiness testing. but
a petition is not required if the owner or operator maintains records
indicating that federal, state, or local standards require
maintenance and testing of emergency RICE beyond 100 hours per
calendar year. (§ 63.6640(f)(2)(i))
b. Emergency stationary RICE may be operated for emergency
demand response for periods in which the Reliability Coordinator
under the North American Electric Reliability Corporation
(NERC) Reliability Standard EOP-002-3, Capacity and Energy
Emergencies (incorporated by reference, see §63.14), or other
authorized entity as determined by the Reliability Coordinator, has
declared an Energy Emergency Alert Level 2 as defined in the
NERC Reliability Standard EOP-002-3. (§ 63.6640(f)(2)(ii))
c. Emergency stationary RICE may be operated for periods where
there is a deviation of voltage or frequency of 5 percent or greater
below standard voltage or frequency. (§ 63.6640(f)(2)(iii))
2.4.11.3 Emergency stationary RICE located at area sources of HAP may be
operated for up to 50 hours per calendar year in non -emergency situations.
The 50 hours of operation in non -emergency situations are counted as part
of the 100 hours per calendar year for maintenance and testing and
emergency demand response provided in Condition 2.4.11.2. Except as
provided in paragraphs (f)(4)(i) and (ii) of this section, the 50 hours per
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 31
year for non -emergency situations cannot be used for peak shaving or non -
emergency demand response, or to generate income for a facility to an
electric grid or otherwise supply power as part of a financial arrangement
with another entity. (§ 63.6640(0(4))
What reports must I submit and when? (" 63.6650)
2.4.12 If you own or operate an emergency stationary RICE with a site rating of more than
100 brake HP that operates or is contractually obligated to be available for more than
15 hours per calendar year for the purposes specified in Conditions 2.4.11.2.b and
2.4.11.2.c or that operates for the purpose specified in §63.6640(f)(4)(ii), you must
submit an annual report according to the requirements in paragraphs (h)(1) through
(3) of this section. (§ 63.6650(h))
What records must I keep? (' 63.6655)
2.4.13 You must keep records of the maintenance conducted on the stationary RICE in order
to demonstrate that you operated and maintained the stationary RICE and after -
treatment control device (if any) according to your own maintenance plan if you own
or operate an existing stationary emergency RICE. (§ 63.6655(e) and § 63.6655(e)(2))
2.4.14 If you own or operate an existing emergency stationary RICE located at an area
source of HAP emissions that does not meet the standards applicable to non -
emergency engines, you must keep records of the hours of operation of the engine
that is recorded through the non-resettable hour meter. The owner or operator must
document how many hours are spent for emergency operation, including what
classified the operation as emergency and how many hours are spent for non -
emergency operation. If the engine is used for the purposes specified in Conditions
2.4.11.2.b or 2.4.11.2.c or §63.6640(f)(4)(ii), the owner or operator must keep records
of the notification of the emergency situation, and the date, start time, and end time of
engine operation for these purposes. (§ 63.6655(0 and § 63.6655(0(2))
In what form and how long must I keep my records? (' 63.6660)
2.4.15 Records shall be kept in the form and for the duration specified in § 63.6660.
What parts of the General Provisions apply to me? (§ 63.6665)
2.4.16 Table 8 of Subpart ZZZZ shows which parts of the General Provisions in §§63.1
through 63.15 apply to you. (§ 63.6665) The general provisions that apply to these
engines include, but are not limited to the following:
2.4.16.1 Prohibited activities in § 63.4(a).
2.4.16.2 Circumvention in § 63.4(b).
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 32
3. S004 —Rentech Natural Gas Fired Boiler Rated at 129 MMBtu/hr
Parameter
Permit
Condition
Number
Limitations
Short Term Long Term
Compliance
Emission Factor
Monitoring
Method Interval
BACT
Requirements
3.1
See Condition 3.1
N/A
See Condition 3.1
PM
3.2
0.164 1bs/MMBtu
N/A
Fuel Restriction
Only Natural
Gas is Used
as Fuel
N/A
2.28 tons/yr
0.0186 lb/MMBtu
Recordkeeping
and Calculation
Monthly
PM10
N/A
2.28 tons/yr
0.0186 lb/MMBtu
NOx
3.3
0.038 lb/MIMMBtu, on a 3 -hr
rolling average
N/A
Continuous
Emission
Monitoring
System
Continuously
N/A
4.7 tons/yr
CO
3.4
0.039 lb/MMBtu, based on the
average of three (3) test runs
N/A
See Condition 3.4
N/A
4.75 tons/yr
0.039 lb/MMBtu
Recordkeeping
and Calculation
Monthly
Natural Gas
Consumption
3.5
N/A
231.9
MMscf/yr
Fuel Meter
Recordkeeping
Daily
NSPS General
Provisions
3.6
N/A
N/A
N/A
As required in the NSPS General
Provisions
NSPS
Recordkeeping
Requirement
3.7
Determination of Annual
Capacity Factor
N/A
Daily Recording
of Fuel
12 -Month
Rolling
Average
Continuous
Emission
Monitoring
Requirements
3.8
N/A
N/A
N/A
See Condition 3.8
Opacity
3.9.1
Not to Exceed 20%, Except as
Provided for in 3.10
N/A
Fuel Restriction
Only Natural
Gas is Used
as Fuel
For Certain Operational
Activities - Not to Exceed 30%,
for a Period or Periods
Aggregating More than Six (6)
Minutes in any 60 Consecutive
Minutes
State -Only Requirement: Not to
Exceed 20%
3.1 The auxiliary boiler is subject to the requirements of the prevention of Significant Deterioration
(PSD) Program. Best Available Control Technology (BACT) shall be applied for control of
Nitrogen Oxides (NOx), Carbon Monoxide (CO), Particulate Matter (PM and PM lo) and Volatile
Organic Compounds. BACT has been determined as follows:
Operating Permit Number: 05OPWE279
First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 33
3.1.1 BACT for NOx has been determined to be Low NOx burners with the emission limit
identified in Condition 3.3.1 (Colorado Construction Permit 02WE0228).
3.1.2 BACT for CO has been determined to be good combustion practices with the
emission limit identified in Condition 3.4.1 (Colorado Construction Permit
02WE0228).
3.1.3 BACT for PM and PM10 has been determined to be use of pipeline quality natural gas
as fuel.
3.1.4 BACT for VOC has been determined to be use of pipeline quality natural gas as fuel
and good combustion practices.
3.2 Particulate Matter (PM and PM10) emissions from the boiler are subject to the following
requirements:
3.2.1 PM emissions shall not exceed 0.164 lb/MMBtu (Colorado Construction Permit
02WE0228 and Colorado Regulation No. 1, Section III.A.I .b). In the absence of
credible evidence to the contrary, compliance with the particulate matter emission
limits is presumed is natural gas is the only fuel permitted for use as fuel in the boiler.
Note that the numeric PM standard was determined using the design heat input for the
boiler (129 MMBtu/hr) in the following equation:
PE = 0.5 x (FI)-° 26' where: PE = particulate standard in lbs/MMBtu
FI = fuel input in MMBtu/hr
3.2.2 Emissions of PM and PM10 shall not exceed the annual limitations listed above
(Colorado Construction Permit 02WE0228, as modified under the provisions of
Section I, Condition 1.3 to add the annual PM and PM10 emission limitations based
on requested emissions on the APEN submitted March 21, 2007). Monthly emissions
from the boiler shall be calculated by the end of the subsequent month using the
above emission factors (from manufacturer), the monthly natural gas consumption
and the heat content of the natural gas for the month as indicated in the DAHS in the
following equation:
Tons/mo = EF (lb/MMBtu) x natural gas use (MMscf/mo) x heat content of gas (MMBtu/MMscf)
2000 lbs/ton
Monthly emissions shall be used in a rolling twelve month total to monitor
compliance with the annual limitations. Each month a new twelve month total shall
calculated using the previous twelve months' data.
3.3 Nitrogen Oxide (NOx) emissions from the boiler are subject to the following requirements:
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 34
3.3.1 For purposes of BACT, NOx emissions from the boiler shall not exceed 0.038
lb/MMBtu, on a 3 -hour rolling average (Colorado Construction Permit 02WE0228, as
modified under the provisions of Section I, Condition 1.3 to specify the averaging
time). Compliance with the BACT NOx limit shall be monitored using the NOx
CEMS required by Condition 3.9.1. For any hour in which fuel is combusted in the
unit the permittee shall calculate the hourly average NOx concentration in units of
lb/MMBtu in accordance with the requirements in 40 CFR Part 60 and Condition 6.4
of this permit. Hourly averages shall be used in a 3 -hr rolling average to monitor
compliance with the NOx BACT limit.
3.3.2 Annual emissions of NOx from the boiler shall not exceed the above limitations
(Colorado Construction Permit 02WE0228). For any hour in which fuel is combusted
in the boiler, the permittee shall program the DAHs to calculate lb/hr NOx emissions
in accordance with the requirements in Condition 6.1.1.4.b of this permit and 40 CFR
Part 60. Specifically hourly mass NOx emissions (in lb/hr) shall be calculated by
multiplying the hourly NOx lb/MMBtu value by the hourly heat input value
(MMBtu/hr). The hourly NOx lb/MMBtu and heat input values shall be determined
using the appropriate equations in Method 19 of 40 CFR Part 60. Hourly emissions
shall be summed to determine monthly emissions (in tons). Monthly emissions shall
be used in a twelve month rolling total to monitor compliance with the annual
limitations. Each month a new twelve month total shall be calculated using the
previous twelve months' data.
3.4 Carbon Monoxide (CO) emissions from the boiler are subject to the following requirements:
3.4.1 For purposes of BACT, CO emissions from the boiler shall not exceed 0.039
lb/MMBtu, based on the average of three (3) test runs (Colorado Construction Permit
02WE0228, as modified under the provisions of Section I, Condition 1.3 to specify
the averaging time). Compliance with the CO BACT limit shall be monitored as
follows:
3.4.1.1 Compliance with the CO BACT emission limitation shall be presumed, in
the absence of credible evidence to the contrary, provided the boiler is
operated in accordance with manufacturer's recommendations and good
engineering practices. A copy of operating and maintenance procedures,
schedules for maintenance and/or inspection activities and records related
to maintenance of the boiler and good engineering practices such as
records of inspection, repair or replacement shall be made available to the
Division upon request.
3.4.1.2 Performance tests shall be conducted to monitor compliance with the CO
BACT limit in Condition 3.4.1.1. Performance tests shall be conducted to
measure CO emissions in accordance with the requirements and
procedures set forth in the appropriate EPA Test Methods. Frequency of
testing shall be annual (calendar year) except that: (1) if any test results
indicate emissions are less than or equal to 50% of the emission limit,
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 35
another test is required within five years; (2) if any test results indicate
emissions are more than 50%, but less than or equal to 75% of the
emission limit, another test is required within three years; (3) if any test
results indicate emissions are greater than 75% of the emission limit, an
annual test is required until the provisions of (1) or (2) are met. Test
results shall be converted to the applicable units and compliance will be
based on the average of three test runs.
Note that a performance test was conducted on May 24. 2016. The results
of the test indicate that CO emissions from the unit was less than 75% of
the limitation but more than 50% (results were 0.021 lb/MMBtu (53.8 %)),
therefore, the next test is required within 3 years of the May 2016 test
The test protocol, test, and test report must be in accordance with the
requirements of the APCD Compliance Test Manual
(https://wwvv.colorado.gov/pacific/cdphe/inspections-and-enforcement). A
stack testing protocol shall be submitted for Division approval at least
forty-five (45) calendar days prior to any performance of the test required
under this condition. No stack test required herein shall be performed
without prior approval of the protocol by the Division. The Division
reserves the right to witness the test. In order to facilitate the Division's
ability to make plans to witness the test, notice of the date(s) for the stack
test shall be submitted to the Division at least thirty (30) calendar days
prior to the test. The Division may for good cause shown, waive this
thirty (30) day notice requirement. In instances when a scheduling conflict
is presented, the Division shall immediately contact the permittee in order
to explore the possibility of making modifications to the stack test
schedule. The compliance test results shall be submitted to the Division
within forty-five (45) calendar days of the completion of the test unless a
longer period is approved by the Division.
3.4.2 Annual emissions CO from the boiler shall not exceed the limitation stated above
(Colorado Construction Permit 02W E0228. as modified under the provision of
Section I. Condition 1.3 to increase CO emissions to level requested on the APEN
received March 21, 2007). Monthly emissions from the boiler shall be calculated by
the end of the subsequent month using the emission factor above (from the
manufacturer), the monthly natural gas consumption and the heat content of the
natural gas for the month as indicated in the DAHS in the following equation:
Tons/mo = EF (Ib/MMBtu) x natural gas use (MMscf/mo) x heat content of gas (MMBtu/MMscf)
2000 lbs/ton
Monthly emissions shall be used in a rolling twelve month total to monitor
compliance with the annual limitations. Each month a new twelve month total shall
be calculated using the previous twelve months' data.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 36
3.5 Natural gas consumption from the boiler shall not exceed the limitation stated above
(Construction Permit 02WE0228). Natural gas consumed in the boiler shall be recorded
monthly, as required by 40 CFR Part 60 Subpart Db § 60.49b(d)(1), as adopted by reference in
Colorado Regulation No. 6, Part A. Daily quantities of natural gas consumed shall be summed
to determine the monthly natural gas consumption. Monthly quantities of natural gas
consumption for the boiler shall be used in a twelve month rolling total to monitor compliance
with the annual limitation. Each month a new twelve month total shall be calculated using the
previous twelve months data.
3.6 Regulation No. 6, Part A, Subpart A. General Provisions applies as follows:
3.6.1 No article, machine, equipment or process shall be used to conceal 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 gasses discharged to the atmosphere (§ 60.12)
3.6.2 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 (Colorado Construction Permit 91MR933,
initial approval, modification 4. dated October 26, 1999 and 40 CFR Subpart A §
60.11(d)).
3.7 The owner of operator of an affected facility shall record and maintain records of the amounts of
each fuel combusted during each day and calculate the annual capacity factor individually for
coal, distillate oil, residual, oil, natural gas, wood, and municipal -type solid waste for the
reporting period. The annual capacity factor is determined on a 12 -month rolling average basis
with a new annual capacity factor calculated at the end of each calendar month (40 CFR Part 60
Subpart Db § 60.49b(d)(1), as adopted by reference in Colorado Regulation No. 6, Part A).
3.8 The owner or operator of an affected facility subject to a NOx standard under 40 CFR Part 60
Subpart Db § 60.44b shall install, calibrate, maintain, and operate continuous emission
monitoring systems (CEMS) for measuring NOx and O, (or CO)), and shall record the output of
the system (40 CFR Part 60 Subpart Db § 60.48b(b)(1), as adopted by reference in Colorado
Regulation No. 6, Part A). The NOx CEMS shall meet the requirements in Condition 6 of this
permit. In addition, to recording the NOx concentration (1b/MMBtu), as required by Condition
6.4.2, the CEMS shall also record the NOx mass emission rate in lbs/hr and tons/month.
Monthly NOx emissions from the CEMS shall be used as specified by Condition 3.3.2 to
monitor compliance with the annual NOx emission limitation.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 37
3.9 This boiler is subject to the opacity to the following opacity requirements:
3.9.1 Except as provided for in Condition 3.9.2 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 (Colorado Construction Permit 02WE0228 and Colorado
Regulation No.1, Section ILA.I).
3.9.2 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).
3.9.3 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).
Note that this opacity standard applies at all times except during periods of startup,
shutdown and malfunction (40 CFR Part 60 Subpart A § 60.11(c), as adopted by
reference in Colorado Regulation No. 6, Part B. Section I.A).
Note that this opacity requirement is more stringent than the opacity requirement in
Condition 3.9.2 during periods of building of a new fire, cleaning of fire boxes, soot
blowing, process modifications and adjustment or occasional cleaning of control
equipment.
In the absence of credible evidence to the contrary, compliance with the opacity standards shall
be presumed since only natural gas is permitted to be used as fuel for this boiler.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 38
4. S006 — Marley Cooling Water Tower
Parameter
Permit
Condition
Number
Limitations
Short Term Long Term
Compliance
Emission Factor
Monitoring
Method Interval
BACT
Requirements
4.1
N/A
N/A
N/A
See Condition 4.1
PM
4.1
N/A
19.3 tons/yr
See Condition 4.2
Recordkeeping
and Calculation
Monthly
PM10
N/A
19.3 tons/yr
Water Circulated
4.3
N/A
92,505.6
mmgal/yr
N/A
Recordkeeping
Monthly
Total Solids
Concentration
4.4
N/A
N/A
N/A
Laboratory
Analysis
Quarterly
Opacity
4.5
Not to Exceed 20%
N/A
See Condition 4.5
4.1 The cooling water tower is subject to the requirements of the prevention of Significant
Deterioration (PSD) Program. Best Available Control Technology (BACT) shall be applied for
control of Particulate Matter (PM and PM10). BACT has been determined to be the use of drift
eliminators to achieve drift levels of 0.0005% (Colorado Construction Permit 02WE0228).
4.2 Particulate Matter (PM and PM10) emissions shall not exceed the limitations above (Colorado
Construction Permit 02WE0228, as modified under the provisions of Section I, Condition 1.3, to
include the requested PM and PM10 emissions indicated on the APEN submitted on March 21,
2007). Emissions shall be calculated monthly using the following equations:
PM = PM10 (tons/month) = Q x d x % drift x x total solids concentration
2000 lbs/ton
Where:
Q = water circulated, gal/month
d = density of water, lbs/gal (from T5 application d = 8.34 lbs/gal)
% drift = 0.0005% (BACT limitation)
Total solids = in ppm (lbs solids/106 lbs water) - to be determined by Condition 4.4. The most
recent analysis shall be used in the monthly calculation.
Monthly emissions shall be used in a twelve month rolling total to monitor compliance with the
annual limitation. Each month a new twelve month total shall be calculated using the previous
twelve months data.
4.3 The Water Circulated through the cooling water tower shall not exceed the limitation above
(Colorado Construction Permit 02WE0228, as modified under the provisions of Section 1,
Condition 1.3, to include the requested water circulation limit indicated on the APEN submitted
on March 21, 2007). The quantity of water circulated shall be determined each month by
multiplying the hours of operation of each pump (two pumps, each pump 88,000 gal/min) by the
design flow rate of each pump as follows:
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Pen -nit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 39
Water Circulation Rate = hours of operation (hrs/mo) x Design Flow Rate (Gal/min) x 60 min/hr
Monthly quantities of water shall be used in a twelve month rolling total to monitor compliance
with the annual limitation. Each month a new twelve month total shall be calculated using the
previous twelve months data.
4.4 Samples of water circulated through the tower shall be taken and analyzed quarterly.
Calculations of monthly emissions shall be made using the total solids concentration determined
from the most recent required analysis. A copy of the procedures used to obtain and to analyze
samples shall be maintained and made available to the Division upon request.
4.5 Opacity of emissions from the cooling water tower shall not exceed 20% (Colorado Regulation
No. 1, Section II.A.1). In the absence of credible evidence to the contrary, compliance with the
opacity standard shall be presumed, provided the drift eliminators on the tower are operated and
maintained in accordance with the manufacturers' recommendations and good engineering
practices. A copy of operating and maintenance procedures, schedules for maintenance and/or
inspection activities and records related to maintenance of the drift eliminators and good
engineering practices such as records of inspection, repair or replacement shall be made available
to the Division upon request.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 40
5. Facility Wide HAP Limits
Parameter
Permit
Condition
Number
Limitations
Short Term Long Term
Compliance
Emission Factor
Monitoring
Method Interval
Facility Wide
Formaldehyde
Emissions
5.1
N/A
2.44 tons/yr
See Condition 5.1
Recordkeeping and
Calculation
Monthly
Facility Wide
Total HAPs
N/A
13.1 tons/yr
See Condition 5.1
5.1 Emissions of HAPs shall not exceed the limitations stated above (Colorado Construction Permit
02WE0228, as modified under the provisions of Section I, Condition 1.3 to reflect requested
emissions on the APENS submitted on March 21, 2007). Emissions shall be calculated by the
end of the subsequent month using actual throughputs and the following compliance emission
factors.
Emission Unit
Pollutant
Emission Factor
Emission Factor Source
Turbines/HRSG/Duct
Burners
Formaldehyde
Unit 1 — 1.5 x 10-4 lb/MMBtu
Unit 2 — 1.3 x 10.4 lb/MMBtu
From performance tests
conducted May 8, 11, 12,
20 and September 16,
2004.
Acetaldehyde
1.37 x 10"' lb/MMscf
From California Air
Toxics Emission Factor
(databases) for natural
gas -fired turbines with
COC and SCR.
Acrolein
1.89 x 10-' lb/MMscf
Benzene
1.33 x 10' lb/MMscf
Ethylbenzene
1.79 x 10-2 lb/MMscf
Hexane
2.59 x 10-' lb/MMscf
Propylene Oxide
4.78 x 10-' lb/MMscf
Toluene
7.10 x 10_, lb/MMscf
Xylene
2.61 x 10_, Ib/M vlscf
Cooling Water Tower
Chloroform
2.3 kg/109 liters
from "Locating and
Estimating Air Emissions
from Sources of
Chloroform", EPA -450/4-
84-007c, March 1984, for
re -circulating units.
A twelve-month rolling total shall be maintained for demonstration of compliance with annual
limitations. Each month, a new twelve month total shall be calculated using the previous twelve
months data. Records of calculations shall be maintained for Division inspection upon request.
Operating Permit Number: 05OPWE279
First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 41
6. Continuous Emission Monitoring Requirements
The following requirements apply to the NON. CO and diluent (either O2 or CO2) continuous emission
monitoring systems (CEMS) required by Conditions 1.8 and 3.8. Note that the continuous emission
monitoring requirements identified in this Condition for each turbine/HRSG/duct burner, are in
addition to the continuous emission monitoring requirements required by the Acid Rain Program. which
are identified in Section III of this permit.
6.1 Equipment and QA/QC Requirements
6.1.1 The Continuous Emission Monitoring Systems (CEMS) are subject to the following
requirements:
6.1.1.1 The NOx (and diluent) monitors for the auxiliary boiler is 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 Specifications 2 and 3. 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 6.1.1.4
of this permit.
6.1.1.2 Except as provided for below, the CO monitors for the
turbines/HRSGS/duct burners are subject to the applicable
requirements of 40 CFR Part 60 (Colorado Construction Permit
02WE0228). 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 6.1.1.4of 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 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 60 Appendix F.
6.1.1.3 The NOx (and diluent) monitors for the turbines/HRSGs/duct burners
are subject to the applicable requirements of 40 CFR Part 75 (Colorado
Construction Permit 02WE0228). 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
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 42
assurance/quality control requirements in 40 CFR Part 75, Appendix B,
the conversion procedures of Appendix F and Condition 6.1.1.4 of this
permit.
6.1.1.4 The NOx and CO CEMS for the turbines/HRSGs/duct burners and the
NOx CEMS for the auxiliary boiler are subject to the following
requirements:
a. Relative Accuracy Test Audits (RATAs): RATAs shall be
conducted in the units (e.g., lb/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., lb/MMBtu, ppm) of the emission limitation and meet
the reporting requriements for all for the emissions limitations that
are applicable to the emissions unit.
6.1.2 Quality assurance/quality control plans shall be prepared for the continuous emission
monitoring systems as follows:
6.1.2.1 The quality assurance/quality control plan for the NOx (and diluent)
monitors for the auxiliary boiler shall be prepared in accordance with
the applicable requirements in 40 CFR Part 60, Appendix F.
6.1.2.2 The quality assurance/quality control plan for the CO monitors for the
turbines/HRSG/duct burners shall be prepared in accordance with the
applicable requirements in 40 CFR Part 75, Appendix B.
6.1.2.3 The quality assurance /quality control plan for the NOx (and diluent)
monitors for the turbines/HRSG/duct burners 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.
6.2 General Provisions
6.2.1 CO monitors for turbines/HRSGs/duct burners and NOx (and diluent) monitors
for auxiliary boiler: The permittee shall ensure that all continuous emission
monitoring systems required are in operation and monitoring unit emissions at all
times except for monitoring system breakdowns. repairs. calibration checks and zero
and span adjustments required under 40 CFR Part 60 Subpart A § 60.13(d) (40 CFR
Part 60 Subpart A § 60.13(e)).
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 43
6.2.2 NOx (and diluent) monitors for turbines/HRSGs/duct burners: The permittee
shall ensure that all continuous emission monitoring systems required are in operation
and monitoring unit emissions at all times that the affected unit combusts any fuel
except as provided in 40 CFR § 75.1 1(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 the data
acquisition and handling system or recertification performed pursuant to 40 CFR §
75.20 (40 CFR Part 75 § 75.10(d)).
6.2.3 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 or continuous opacity monitoring systems must be certified in
accordance with the applicable requirements of 40 CFR Part 60 or 40 CFR Part 75
prior to use.
6.2.4 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 item 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.
6.2.5 A file 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.
6.2.6 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 during which a continuous monitoring system or
monitoring device is inoperative (40 CFR Part 60 Subpart A § 60.7(b) and Colorado
Construction Permit 02WE0228).
6.3 Data Replacement Requirements for each Turbine/HRSG/Duct Burner CEMS
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 CO emissions are not specifically referenced
in the Subpart D procedures, the CEMS data acquisition system is programmed to substitute CO
emissions using the same procedures specified for NOx. For purposes of monitoring compliance
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 44
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.
6.4 NSPS Subpart Db Provisions for the Auxiliary Boiler NOx CEMS
6.4.1 The continuous emission monitoring system required by Section IL Condition 3.8 of
this permit shall be operated and data recorded during all periods of operation of the
affected facility except for continuous monitoring system breakdowns and repairs.
Data is recorded during calibration checks, and zero and span adjustments (40 CFR
Part 60 Subpart Db § 60.48b(c)).
6.4.2 The 1 -hour average nitrogen oxides emission rates measured by the continuous
nitrogen oxides monitor required by Section I I, Condition 3.8 of the permit and
required under § 60.13(h) shall be expressed in ng/J or Ib/MMBtu heat input and shall
be used to calculate the average emission rates. The 1 -hour averages shall be
calculated using the data points required under § 60.13(h)(3) (40 CFR Part 60 Subpart
Db § 60.48b(d)).
6.4.3 The procedures under § 60.13 shall be followed for installation, evaluation and
operation of the continuous monitoring systems (40 CFR Part 60 Subpart Db §
60.48b(e)). The span value for nitrogen oxides is 100 ppm.
6.5 Recordkeeping and Reporting Requirements
6.5.1 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 6.5.2) 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. The source requested quarterly reporting to be consistent
with the Acid Rain reporting requirements). Written reports of excess emissions shall
include the information:
6.5.1.1 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))
6.5.1.2 Specific identification of each period of excess emissions that occurs
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))
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 45
6.5.1.3 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)).
6.5.1.4 When no excess emissions have occurred or the continuous monitoring
system(s) have not been inoperative, repaired, or adjusted, such
information shall be stated in the report (§ 60.7(c)(4)).
6.5.2 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 6.5.1 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 6.5.1 shall both be submitted. (§ 60.7(d)(2)).
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 46
7. M001 - Gasoline Storage Tank, 500 gallons aboveground
Parameter
Permit
Condition
Number
Limitations
Short Term Long Term
Compliance
Emission Factor
Monitoring
Method Interval
40 CFR Pat 63
Subpart
CCCCCC
Requirements
7.1
Work Practice Standards
N/A
See Condition 7.1
Note that this emission unit is exempt from the APEN reporting requirements in Regulation No. 3, Part A and the construction permit
requirements in Regulation No. 3, Part B, as long as actual, uncontrolled emissions do not exceed the APEN de minimis level (see
Regulation No. 3, Part B, Section II.D.1.a).
7.1 This tank is subject to the requirements in 40 CFR Part 63 Subpart CCCCCC, "National
Emission Standards for Hazardous Air Pollutants for Source Category: Gasoline Dispensing
Facilities", as follows:
The requirements below reflect the current rule language as of the revisions to 40 CFR Part 63
Subpart CCCCCC published in the Federal Register on January 24, 2011. However, if revisions
to this Subpart are published at a later date, the owner or operator is subject to the requirements
contained in the revised version of 40 CFR Part 63 Subpart CCCCCC.
These requirements have not been adopted into Colorado Regulation No. 8, Part E as of the date
of this permit issuance [DATE], and are therefore not state -enforceable. In the event that these
requirements are adopted into Colorado Regulations, they will become state -enforceable.
Am I subject to the requirements in this subpart? (( 63.11111)
7.1.1 If your GDF has a monthly throughput of less than 10,000 gallons of gasoline, you
must comply with the requirements in §63.11116. (Conditions 7.1.8 through 7.1.11).
(§ 63.11111(b))
7.1.2 An affected source shall, upon request by the Administrator, demonstrate that their
monthly throughput is less than the 10,000 -gallon or the 100,000 -gallon threshold
level, as applicable. For new or reconstructed affected sources, as specified in
§63.11112(b) and (c), recordkeeping to document monthly throughput must begin
upon startup of the affected source. For existing sources, as specified in
§63.11112(d), recordkeeping to document monthly throughput must begin on January
10, 2008. For existing sources that are subject to this subpart only because they load
gasoline into fuel tanks other than those in motor vehicles, as defined in §63.11132,
recordkeeping to document monthly throughput must begin on January 24, 2011.
Records required under this paragraph shall be kept for a period of 5 years. (§
63.11111(e)).
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 47
7.1.3 If your affected source's throughput ever exceeds an applicable throughput threshold.
the affected source will remain subject to the requirements for sources above the
threshold, even if the affected source throughput later falls below the applicable
throughput threshold. (§ 63.11111(i))
7.1.4 The dispensing of gasoline from a fixed gasoline storage tank at a GDF into a
portable gasoline tank for the on -site delivery and subsequent dispensing of the
gasoline into the fuel tank of a motor vehicle or other gasoline -fueled engine or
equipment used within the area source is only subject to §63.11116 of this subpart.
(Conditions 7.1.8 through 7.1.11). (§ 63.11111(j)
When do I have to comply with this subpart? (§ 63.11113)
7.1.5 If you have an existing affected source, you must comply with the standards in this
subpart no later than January 10, 2011. (§ 63.11113(b))
What are my general duties to minimize emissions? (§ 63.11115)
7.1.6 You must, at all times, operate and maintain any affected source, including associated
air pollution control equipment and monitoring equipment, in a manner consistent
with safety and good air pollution control practices for minimizing emissions.
Determination of whether such operation and maintenance procedures are being used
will be based on information available to the Administrator which may include, but is
not limited to, monitoring results, review of operation and maintenance procedures,
review of operation and maintenance records, and inspection of the source. (§
63.11115(a))
7.1.7 You must keep applicable records and submit reports as specified in §63.11125(d)
and §63.11126(b). (§ 63.1 1 1 15(b)) Records and reports noted in this permit
condition are related to malfunctions. Note that since this source is not subject to any
emission limitation and is specifically exempt from reporting requirements as
specified in Condition 7.1.9, the reporting requirements in §63.11125(d) do not apply
to this source.
Requirements for facilities with monthly throughput of less than 10,000 gallons of gasoline. ('
63.11116)
7.1.8 You must not allow gasoline to be handled in a manner that would result in vapor
releases to the atmosphere for extended periods of time. Measures to be taken
include, but are not limited to, the following (§ 63.11116(a)):
7.1.8.1 Minimize gasoline spills;
7.1.8.2 Clean up spills as expeditiously as practicable;
7.1.8.3 Cover all open gasoline containers and all gasoline storage tank fill -pipes
with a gasketed seal when not in use;
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 48
7.1.8.4 Minimize gasoline sent to open waste collection systems that collect and
transport gasoline to reclamation and recycling devices, such as oil/water
separators;
7.1.9 You are not required to submit notifications or reports as specified in §63.11125,
§63.11126, or subpart A of this part, but you must have records available within 24
hours of a request by the Administrator to document your gasoline throughput. (§
63.11116(b))
7.1.10 You must comply with the requirements of this subpart by the applicable date
specified in Condition 7.1.5 (§ 63.1 1 116(c)).
7.1.11 Portable gasoline containers that meet the requirements of 40 CFR part 59, subpart F,
are considered acceptable for compliance with Condition 7.1.8.3. (§ 63.11116(d))
What are my recordkeeping requirements? (3' 63.11125)
7.1.12 Each owner or operator of an affected source under this subpart shall keep records as
specified below. (§ 63.11125(d))
7.1.12.1 Records of the occurrence and duration of each malfunction of operation
(i.e., process equipment) or the air pollution control and monitoring
equipment. (§ 63.11125(d)(1))
7.1.12.2 Records of actions taken during periods of malfunction to minimize
emissions in accordance with §63.11115(a) (Condition 7.1.6), including
corrective actions to restore malfunctioning process and air pollution
control and monitoring equipment to its normal or usual manner of
operation. (§ 63.11125(d)(2))
What parts of the General Provisions apply to me? (sC 63.11125)
7.1.13 Table 3 to this subpart shows which parts of the General Provisions apply to you. (§
63.11130) The general provisions that apply to this GDF include, but are not limited
to the following:
7.1.13.1 Prohibited activities in § 63.4(a).
7.1.13.2 Circumvention in § 63.4(b).
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 49
SECTION III - Acid Rain Requirements
1. Designated Representative and Alternate Designated Representative
Designated Representative Alternate Designated Representative
Name: Mark Fox Name: Gary Magno
Title: General Manager— Power Title: Manager Environmental
Generation, Colorado Services, Air Quality
Compliance
Phone: (303) 294-2177
Phone: (303) 425-3779
2. Sulfur Dioxide Emission Allowances and Nitrogen Oxide Emission Limitations
Combustion Turbine
No. CT -01
2017
2018
2019
2020
2021
2022
SO2 Allowances, per
40 CFR Part 73.10(b),
Table 2
0*
0*
0*
0*
0*
0*
NOx Limits
This Unit Has No NOx Limits (See Section 5)
* Under the provisions of § 72.84(a) any allowance allocations to, transfers to and deductions from an affected unit's
Allowance Tracking System account is considered an automatic permit amendment and as such no revision to the permit is
necessary. Numerical allowances shown in this table are from the 1996 edition of the CFR.
Combustion Turbine
No. CT -02
2017
2018
2019
2020
2021
2022
SO2 Allowances, per
40 CFR Part 73.10(b),
Table 2
0*
0*
0*
0*
0*
0*
NOx Limits
This Unit Has No NOx Limits (See Section 5)
* Under the provisions of § 72.84(a) any allowance allocations to, transfers to and deductions from an affected unit's
Allowance Tracking System account is considered an automatic permit amendment and as such no revision to the permit is
necessary. Numerical allowances shown in this table are from the 1996 edition of the CFR.
3. Standard Requirements
Combustion Turbines CT -01 and CT -02 of this facility are subject to and the source has certified that they will
comply with the following standard conditions (from Acid Rain Permit Application, EPA Form 7610-16
(Revised 7-2014), with some clarifying language added (e.g. "permitting authority" replaced with `'Division"
and "Act" replaced with "Federal Clean Air Act").
Permit Requirements.
(1) The designated representative of each affected source and each affected unit at the source shall:
i) Submit a complete Acid Rain permit application (including a compliance plan) under 40 CFR
part 72 in accordance with the deadlines specified in 40 CFR 72.30; and
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 50
ii) Submit in a timely manner any supplemental information that the Division determines is
necessary in order to review an Acid Rain permit application and issue or deny an Acid Rain
permit;
(2) The owners and operators of each affected source and each affected unit at the source shall:
i) Operate the unit in compliance with a complete Acid Rain permit application or a superseding
Acid Rain permit issued by the Division; and
ii) Have an Acid Rain Permit.
Monitoring Requirements.
(1)
The owners and operators and, to the extent applicable, designated representative of each affected source
and each affected unit at the source shall comply with the monitoring requirements as provided in 40
CFR part 75.
(2) The emissions measurements recorded and reported in accordance with 40 CFR part 75 shall be used to
determine compliance by the source or unit, as appropriate, with the Acid Rain emissions limitations
and emissions reduction requirements for sulfur dioxide and nitrogen oxides under the Acid Rain
Program.
(3)
The requirements of 40 CFR part 75 shall not affect the responsibility of the owners and operators to
monitor emissions of other pollutants or other emissions characteristics at the unit under other applicable
requirements of the Federal Clean Air Act and other provisions of the operating permit for the source.
Sulfur Dioxide Requirements.
(1)
The owners and operators of each source and each affected unit at the source shall:
i) Hold allowances, as of the allowance transfer deadline, in the source's compliance account (after
deductions under 40 CFR 73.34(c)) not less than the total annual emissions of sulfur dioxide for
the previous calendar year from the unit; and
ii) Comply with the applicable Acid Rain emissions limitations for sulfur dioxide.
(2) Each ton of sulfur dioxide emitted in excess of the Acid Rain emissions limitations for sulfur dioxide
shall constitute a separate violation of the Federal Clean Air Act.
(3)
An affected unit shall be subject to the requirements under paragraph (1) of the sulfur dioxide
requirements as follows:
i) Starting January 1, 2000, an affected unit under 40 CFR 72.6(a)(2); or
ii) Starting on the later of January 1, 2000 or the deadline for monitor certification under 40 CFR
part 75, an affected unit under 40 CFR 72.6(a)(3).
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 51
(4) Allowances shall be held in, deducted from, or transferred among Allowance Tracking System accounts
in accordance with the Acid Rain Program.
(5)
An allowance shall not be deducted in order to comply with the requirements under paragraph (1) of the
sulfur dioxide requirements prior to the calendar year for which the allowance was allocated.
(6) An allowance allocated by the Administrator under the Acid Rain Program is a limited authorization to
emit sulfur dioxide in accordance with the Acid Rain Program. No provision of the Acid Rain Program,
the Acid Rain permit application, the Acid Rain permit, or an exemption under 40 CFR 72.7 or 72.8 and
no provision of law shall be construed to limit the authority of the United States to terminate or limit
such authorization.
(7)
An allowance allocated by the Administrator under the Acid Rain Program does not constitute a
property right.
Nitrogen Oxides Requirements. The owners and operators of the source and each affected unit at the source
shall comply with the applicable Acid Rain emissions limitation for nitrogen oxides.
Excess Emissions Requirements.
(1)
The designated representative of an affected source that has excess emissions in any calendar year shall
submit a proposed offset plan to the Administrator of the U. S. EPA, as required under 40 CFR part 77.
(2) The owners and operators of an affected unit that has excess emissions in any calendar year shall:
i) Pay without demand, to the Administrator of the U. S. EPA, the penalty required, and pay upon
demand the interest on that penalty, as required by 40 CFR part 77; and
ii) Comply with the terms of an approved offset plan, as required by 40 CFR part 77.
Recordkeeping and Reporting Requirements.
(1)
Unless otherwise provided, the owners and operators of the source and each affected unit at the source
shall keep on site at the source each of the following documents for a period of 5 years from the date the
document is created. This period may be extended for cause, at any time prior to the end of 5 years, in
writing by the Administrator or the Division:
i) The certificate of representation for the designated representative for the source and each
affected unit at the source and all documents that demonstrate the truth of the statements in the
certificate of representation, in accordance with 40 CFR 72.24; provided that the certificate and
documents shall be retained on site at the source beyond such 5 -year period until such documents
are superseded because of the submission of a new certificate of representation changing the
designated representative;
ii) All emissions monitoring information, in accordance with 40 CFR part 75, provided that to the
extent that 40 CFR part 75 provides for a 3 -year period for recordkeeping, the 3 -year period shall
apply.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 52
iii) Copies of all reports, compliance certifications, and other submissions and all records made or
required under the Acid Rain Program; and,
iv) Copies of all documents used to complete an Acid Rain permit application and any other
submission under the Acid Rain Program or to demonstrate compliance with the requirements of
the Acid Rain Program.
(2) The designated representative of an affected source and each affected unit at the source shall submit the
reports and compliance certifications required under the Acid Rain Program, including those under 40
CFR part 72 subpart I and 40 CFR part 75.
Liability.
(1)
Any person who knowingly violates any requirement or prohibition of the Acid Rain Program, a
complete Acid Rain permit application, an Acid Rain permit, or an exemption under 40 CFR 72.7 or
72.8, including any requirement for the payment of any penalty owed to the United States, shall be
subject to enforcement pursuant to section 113(c) of the Federal Clean Air Act.
(2) Any person who knowingly makes a false, material statement in any record, submission, or report under
the Acid Rain Program shall be subject to criminal enforcement pursuant to section 113(c) of the Federal
Clean Air Act and 18 U.S.C. 1001.
(3)
No permit revision shall excuse any violation of the requirements of the Acid Rain Program that occurs
prior to the date that the revision takes effect.
(4) Each affected source and each affected unit shall meet the requirements of the Acid Rain Program.
(5) Any provision of the Acid Rain Program that applies to an affected source (including a provision
applicable to the designated representative of an affected source) shall also apply to the owners and
operators of such source and of the affected units at the source.
(6) Any provision of the Acid Rain Program that applies to an affected unit (including a provision
applicable to the designated representative of an affected unit) shall also apply to the owners and
operators of such unit.
(7)
Each violation of a provision of 40 CFR parts 72, 73, 74, 75, 76, 77, and 78 by an affected source or
affected unit, or by an owner or operator or designated representative of such source or unit, shall be a
separate violation of the Federal Clean Air Act.
Effect on Other Authorities. No provision of the Acid Rain Program, an Acid Rain permit application, an Acid
Rain permit, or an exemption under 40 CFR 72.7 or 72.8 shall be construed as:
(1)
Except as expressly provided in title IV of the Federal Clean Air Act, exempting or excluding the
owners and operators and, to the extent applicable, the designated representative of an affected source or
affected unit from compliance with any other provision of the Federal Clean Air Act, including the
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 53
provisions of title I of the Federal Clean Air Act relating to applicable National Ambient Air Quality
Standards or State Implementation Plans;
(2) Limiting the number of allowances a unit can hold; provided, that the number of allowances held by the
source shall not affect the source's obligation to comply with any other provisions of the Federal Clean
Air Act;
(3)
Requiring a change of any kind in any State law regulating electric utility rates and charges, affecting
any State law regarding such State regulation, or limiting such State regulation, including any prudence
review requirements under such State law;
(4) Modifying the Federal Power Act or affecting the authority of the Federal Energy Regulatory
Commission under the Federal Power Act; or,
(5)
Interfering with or impairing any program for competitive bidding for power supply in a State in which
such program is established.
4. Reporting Requirements
Pursuant to 40 CFR Part 75.64 quarterly reports and compliance certification requirements shall be submitted to
the Administrator within 30 days after the end of the calendar quarter. The contents of these reports shall meet
the requirements of 40 CFR 75.64.
Revisions to this permit shall be made in accordance with 40 CFR Part 72, Subpart H. §§ 72.80 through 72.85
(as adopted by reference in Colorado Regulation 18). Permit modification requests shall be submitted to the
Division at the address identified in Appendix D.
Changes to the Designated Representative or Alternate Designated Representative shall be made in accordance
with 40 CFR 72.23.
5. Comments, Notes and Justifications
Combustion Turbines CT -01 and CT -02 burn natural gas as fuel. The NOx limitations in 40 CFR Part 76 are
only applicable to coal-fired utility units and thus do not apply to CT -01 and CT -02.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 54
SECTION IV - Permit Shield
Regulation No. 3, 5 CCR 1001-5. Part C. I.A.4. V.D., & XIII.B and S 25-7-1 14.4(3)(a). C.R.S.
1. Specific Non -Applicable Requirements
Based on the information available to the Division and supplied by the applicant, the following
parameters and requirements have been specifically identified as non -applicable to the facility to which
this permit has been issued. This shield does not protect the source from any violations that occurred
prior to or at the time of permit issuance. In addition, this shield does not protect the source from any
violations that occur as a result of any modifications or reconstruction on which construction
commenced prior to permit issuance.
The source did not specifically identify and justify any non -applicable requirements to be included in the
permit shield.
2. General Conditions
Compliance with this Operating Permit shall be deemed compliance with all applicable requirements
specifically identified in the permit and other requirements specifically identified in the permit as not
applicable to the source. This permit shield shall not alter or affect the following:
2.1 The provisions of §§ 25-7-112 and 25-7-113, C.R.S., or § 303 of the federal act, concerning
enforcement in cases of emergency;
2.2 The liability of an owner or operator of a source for any violation of applicable requirements
prior to or at the time of permit issuance;
2.3 The applicable requirements of the federal Acid Rain Program, consistent with § 408(a) of the
federal act;
2.4 The ability of the Air Pollution Control Division to obtain information from a source pursuant to
§ 25-7-111(2)(I), C.R.S., or the ability of the Administrator to obtain information pursuant to §
114 of the federal act;
2.5 The ability of the Air Pollution Control Division to reopen the Operating Permit for cause
pursuant to Regulation No. 3, Part C. § XIII.
2.6 Sources are not shielded from terms and conditions that become applicable to the source
subsequent to permit issuance.
3. Streamlined Conditions
The following applicable requirements have been subsumed within this operating permit using the pertinent
streamlining procedures approved by the U.S. EPA. For purposes of the permit shield, compliance with the
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 55
listed permit conditions will also serve as a compliance demonstration for purposes of the associated subsumed
requirements.
Permit Condition
Streamlined (Subsumed) Requirements
Turbines/HRSGs/Duct Burners
Section II, Condition
1.2.2
Regulation No. 1, Section II.A.1.c [PM emissions shall not exceed 0.1 lb/MMBtu, based on the
average of three (3) 1 -hr tests]
Section II, Condition
1.2.2
40 CFR Part 60 Subpart Da § 60.42a(a)(1), as adopted by reference in Colorado Regulation No.
6, Part A [PM emissions shall not exceed 0.03 lb/MMBtu, based on the average of three (3) 2 -hr
tests]]
Section II, Condition
1.5.1.1
40 CFR Part 60 Subpart Da § 60.44a(d)(1), as adopted by reference in Colorado Regulation No.
6, Part A [NOy emissions shall not exceed 1.6 lbs/MW-hr, on a 30 -boiler operating day rolling
average]
Section II, Condition
1.10
40 CFR Part 60 Subpart GG §§ 60.334(h)(3) and (i)(1), as adopted by reference in Colorado
Regulation No. 6, Part A [monitor sulfur and nitrogen content of fuel and test methods and
procedures for fuel sampling]
Section II, Condition
1.10
40 CFR Part 60 Subpart GG § 60.334(,j)(2), as adopted by reference in Colorado Regulation No.
6, Part A [excess emission reporting for sulfur content of fuel]
Section II, Condition
1.4.3
Regulation No. 6, Part B, Section II.D.3.b [SO, emissions not to exceed 0.35 lbs/MMBtu] -
State -only Requirement
Section II, Condition
1.11
Regulation No. 6, Part B, Section I [general provisions] - State -only Requirement
Auxiliary Boiler
Section II, Condition
3.3.1
40 CFR Part 60 Subpart Db § 60.44b(a)(I ), (h) and (i) [NOx emissions not to exceed 0.20
lb/MMBtu, limit applies at all times, including s/s/m and limit is on a 30 -day rolling average].
Section II, Condition
6.4.3
40 CFR Part 60 Subpart Db § 60.48b(e)(2) [NOx CEMS span value shall be 500 ppm].
Section II, Condition
6.5
40 CFR Part 60 Subpart Db §§ 60.49b(g), (h), (i), (v) and (w) [NOx records, excess emission
reports, CEMS reports, option to submit electronic reports and frequency for submitting reports].
Section V,
Conditions 22.b & c
40 CFR Part 60 Subpart Db § 60.49b(o) [retain records for 2 yrs]
Section II, Condition
3.6
Regulation No. 6, Part B, Section I [general provisions] - State -only Requirement
Section I1, Condition
3.2.1
Regulation No. 6, Part B, Section II.C.2 [particulate matter standard] - State -only Requirement
Operating Permit Number: 05OPWE279
First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 56
SECTION V - General Permit Conditions
5/22/12 version
1. Administrative Changes
Regulation No. 3, 5 CCR 1001-5, Part A, § Ill.
The permittee shall submit an application for an administrative permit amendment to the Division for those permit changes
that are described in Regulation No. 3, Part A, § I.B.1. The permittee may immediately make the change upon submission of
the application to the Division.
2. Certification Requirements
Regulation No. 3, 5 CCR 1001-5, Part C. §§ III.B.9.. V.C.16.a.& e. and V.C.17.
a. Any application, report, document and compliance certification submitted to the Air Pollution Control Division
pursuant to Regulation No. 3 or the Operating Permit shall contain a certification by a responsible official of the
truth, accuracy and completeness of such form, report or certification stating that, based on information and belief
formed after reasonable inquiry, the statements and information in the document are true, accurate and complete.
b. All compliance certifications for terms and conditions in the Operating Permit shall be submitted to the Air Pollution
Control Division at least annually unless a more frequent period is specified in the applicable requirement or by the
Division in the Operating Permit.
c. Compliance certifications shall contain:
(i) the identification of each permit term and condition that is the basis of the certification;
(ii) the compliance status of the source;
(iii) whether compliance was continuous or intermittent;
(iv) method(s) used for determining the compliance status of the source, currently and over the reporting
period; and
(v) such other facts as the Air Pollution Control Division may require to determine the compliance status of the
source.
d. All compliance certifications shall be submitted to the Air Pollution Control Division and to the Environmental
Protection Agency at the addresses listed in Appendix D of this Permit.
e. If the permittee is required to develop and register a risk management plan pursuant to § 112(r) of the federal act, the
permittee shall certify its compliance with that requirement; the Operating Permit shall not incorporate the contents
of the risk management plan as a permit term or condition.
3. Common Provisions
Common Provisions Regulation. 5 CCR 1001-2 $$ ILA.. II.B.. II.C.. II..E., B.F., 11.1, and II.J
a. To Control Emissions Leaving Colorado
When emissions generated from sources in Colorado cross the State boundary line, such emissions shall not cause
the air quality standards of the receiving State to be exceeded, provided reciprocal action is taken by the receiving
State.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 57
b. Emission Monitoring Requirements
The Division may require owners or operators of stationary air pollution sources to install, maintain, and use
instrumentation to monitor and record emission data as a basis for periodic reports to the Division.
c. Performance Testing -
The owner or operator of any air pollution source shall, upon request of the Division, conduct performance test(s)
and furnish the Division a written report of the results of such test(s) in order to determine compliance with
applicable emission control regulations.
Performance test(s) shall be conducted and the data reduced in accordance with the applicable reference test
methods unless the Division:
(i) specifies or approves, in specific cases, the use of a test method with minor changes in methodology;
(ii) approves the use of an equivalent method;
(iii) approves the use of an alternative method the results of which the Division has determined to be adequate
for indicating where a specific source is in compliance; or
(iv) waives the requirement for performance test(s) because the owner or operator of a source has demonstrated
by other means to the Division's satisfaction that the affected facility is in compliance with the standard.
Nothing in this paragraph shall be construed to abrogate the Commission's or Division's authority to
require testing under the Colorado Revised Statutes, Title 25, Article 7, and pursuant to regulations
promulgated by the Commission.
Compliance test(s) shall be conducted under such conditions as the Division shall specify to the plant operator based
on representative performance of the affected facility. The owner or operator shall make available to the Division
such records as may be necessary to determine the conditions of the performance test(s). Operations during period of
startup, shutdown, and malfunction shall not constitute representative conditions of performance test(s) unless
otherwise specified in the applicable standard.
The owner or operator of an affected facility shall provide the Division thirty days prior notice of the performance
test to afford the Division the opportunity to have an observer present. The Division may waive the thirty day notice
requirement provided that arrangements satisfactory to the Division are made for earlier testing.
The owner or operator of an affected facility shall provide, or cause to be provided, performance testing facilities as
follows:
(i) Sampling ports adequate for test methods applicable to such facility;
(ii) Safe sampling platform(s);
(iii) Safe access to sampling platform(s); and
(iv) Utilities for sampling and testing equipment.
Each performance test shall consist of at least three separate runs using the applicable test method. Each run shall be
conducted for the time and under the conditions specified in the applicable standard. For the purpose of determining
compliance with an applicable standard, the arithmetic mean of results of at least three runs shall apply. In the event
that a sample is accidentally lost or conditions occur in which one of the runs must be discontinued because of
forced shutdown, failure of an irreplaceable portion of the sample train, extreme meteorological conditions, or other
circumstances beyond the owner or operator's control, compliance may, upon the Division's approval, be
determined using the arithmetic mean of the results of the two other runs.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 58
Nothing in this section shall abrogate the Division's authority to conduct its own performance test(s) if so warranted.
d. Affirmative Defense Provision for Excess Emissions during Malfunctions
An affirmative defense to a claim of violation under these regulations is provided to owners and operators for civil
penalty actions for excess emissions during periods of malfunction. To establish the affirmative defense and to be
relieved of a civil penalty in any action to enforce an applicable requirement, the owner or operator of the facility
must meet the notification requirements below in a timely manner and prove by a preponderance of evidence that:
(i)
The excess emissions were caused by a sudden, unavoidable breakdown of equipment, or a sudden,
unavoidable failure of a process to operate in the normal or usual manner, beyond the reasonable control of
the owner or operator;
(ii) The excess emissions did not stem from any activity or event that could have reasonably been foreseen and
avoided, or planned for, and could not have been avoided by better operation and maintenance practices;
(iii) Repairs were made as expeditiously as possible when the applicable emission limitations were being
exceeded;
(iv) The amount and duration of the excess emissions (including any bypass) were minimized to the maximum
extent practicable during periods of such emissions;
(v) All reasonably possible steps were taken to minimize the impact of the excess emissions on ambient air
quality;
(vi) All emissions monitoring systems were kept in operation (if at all possible);
(vii) The owner or operator's actions during the period of excess emissions were documented by properly
signed, contemporaneous operating logs or other relevant evidence;
(viii) The excess emissions were not part of a recurring pattern indicative of inadequate design, operation, or
maintenance;
(ix) At all times, the facility was operated in a manner consistent with good practices for minimizing emissions.
This section is intended solely to be a factor in determining whether an affirmative defense is available to
an owner or operator, and shall not constitute an additional applicable requirement; and
(x) During the period of excess emissions, there were no exceedances of the relevant ambient air quality
standards established in the Commissions' Regulations that could be attributed to the emitting source.
The owner or operator of the facility experiencing excess emissions during a malfunction shall notify the division
verbally as soon as possible, but no later than noon of the Division's next working day, and shall submit written
notification following the initial occurrence of the excess emissions by the end of the source's next reporting period.
The notification shall address the criteria set forth above.
The Affirmative Defense Provision contained in this section shall not be available to claims for injunctive relief.
The Affirmative Defense Provision does not apply to failures to meet federally promulgated performance standards
or emission limits, including, but not limited to, new source performance standards and national emission standards
for hazardous air pollutants. The affirmative defense provision does not apply to state implementation plan (sip)
limits or permit limits that have been set taking into account potential emissions during malfunctions, including, but
not necessarily limited to, certain limits with 30 -day or longer averaging times, limits that indicate they apply during
malfunctions, and limits that indicate they apply at all times or without exception.
e. Circumvention Clause
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 59
A person shall not build, erect, install, or use any article, machine, equipment, condition, or any contrivance, the use
of which, without resulting in a reduction in the total release of air pollutants to the atmosphere, reduces or conceals
an emission which would otherwise constitute a violation of this regulation. No person shall circumvent this
regulation by using more openings than is considered normal practice by the industry or activity in question.
f. Compliance Certifications
For the purpose of submitting compliance certifications or establishing whether or not a person has violated or is in
violation of any standard in the Colorado State Implementation Plan, nothing in the Colorado State Implementation
Plan shall preclude the use, including the exclusive use, of any credible evidence or information, relevant to whether
a source would have been in compliance with applicable requirements if the appropriate performance or compliance
test or procedure had been performed. Evidence that has the effect of making any relevant standard or permit term
more stringent shall not be credible for proving a violation of the standard or permit term.
When compliance or non-compliance is demonstrated by a test or procedure provided by permit or other applicable
requirement, the owner or operator shall be presumed to be in compliance or non-compliance unless other relevant
credible evidence overcomes that presumption.
g. Affirmative Defense Provision for Excess Emissions During Startup and Shutdown
An affirmative defense is provided to owners and operators for civil penalty actions for excess emissions during
periods of startup and shutdown. To establish the affirmative defense and to be relieved of a civil penalty in any
action to enforce an applicable requirement, the owner or operator of the facility must meet the notification
requirements below in a timely manner and prove by a preponderance of the evidence that:
(i)
The periods of excess emissions that occurred during startup and shutdown were short and infrequent and
could not have been prevented through careful planning and design;
(ii) The excess emissions were not part of a recurring pattern indicative of inadequate design, operation or
maintenance;
(iii) If the excess emissions were caused by a bypass (an intentional diversion of control equipment), then the
bypass was unavoidable to prevent loss of life, personal injury, or severe property damage;
(iv) The frequency and duration of operation in startup and shutdown periods were minimized to the maximum
extent practicable;
(v) All possible steps were taken to minimize the impact of excess emissions on ambient air quality;
(vi) All emissions monitoring systems were kept in operation (if at all possible);
(vii) The owner or operator's actions during the period of excess emissions were documented by properly
signed, contemporaneous operating logs or other relevant evidence; and,
(viii) At all times, the facility was operated in a manner consistent with good practices for minimizing emissions.
This subparagraph is intended solely to be a factor in determining whether an affirmative defense is
available to an owner or operator, and shall not constitute an additional applicable requirement.
The owner or operator of the facility experiencing excess emissions during startup and shutdown shall notify the
Division verbally as soon as possible, but no later than two (2) hours after the start of the next working day, and shall
submit written quarterly notification following the initial occurrence of the excess emissions. The notification shall
address the criteria set forth above.
The Affirmative Defense Provision contained in this section shall not be available to claims for injunctive relief.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 60
The Affirmative Defense Provision does not apply to State Implementation Plan provisions or other requirements
that derive from new source performance standards or national emissions standards for hazardous air pollutants, or
any other federally enforceable performance standard or emission limit with an averaging time greater than twenty-
four hours. In addition, an affirmative defense cannot be used by a single source or small group of sources where
the excess emissions have the potential to cause an exceedance of the ambient air quality standards or Prevention of
Significant Deterioration (PSD) increments.
In making any determination whether a source established an affirmative defense, the Division shall consider the
information within the notification required above and any other information the Division deems necessary, which
may include, but is not limited to, physical inspection of the facility and review of documentation pertaining to the
maintenance and operation of process and air pollution control equipment
4. Compliance Requirements
Regulation No. 3, 5 CCR 1001-5, Part C. III.C.9., V.C.11. & 16.d.. § 25-7-122.1(2), C.R.S.
a. The permittee must comply with all conditions of the Operating Permit. Any permit noncompliance relating to
federally -enforceable terms or conditions constitutes a violation of the federal act, as well as the state act and
Regulation No. 3. Any permit noncompliance relating to state -only terms or conditions constitutes a violation of the
state act and Regulation No. 3, shall be enforceable pursuant to state law, and shall not be enforceable by citizens
under § 304 of the federal act. Any such violation of the federal act, the state act or regulations implementing either
statute is grounds for enforcement action, for permit termination, revocation and reissuance or modification or for
denial of a permit renewal application.
b. It shall not be a defense for a permittee in an enforcement action or a consideration in favor of a permittee in a
permit termination, revocation or modification action or action denying a permit renewal application that it would
have been necessary to halt or reduce the permitted activity in order to maintain compliance with the conditions of
the permit.
c. The permit may be modified, revoked, reopened, and reissued, or terminated for cause. The filing of any request by
the permittee for a permit modification, revocation and reissuance, or termination, or any notification of planned
changes or anticipated noncompliance does not stay any permit condition, except as provided in §§ X. and XI. of
Regulation No. 3, Part C.
d. The permittee shall furnish to the Air Pollution Control Division, within a reasonable time as specified by the
Division, any information that the Division may request in writing to determine whether cause exists for modifying,
revoking and reissuing, or terminating the permit or to determine compliance with the permit. Upon request, the
permittee shall also furnish to the Division copies of records required to be kept by the permittee, including
information claimed to be confidential. Any information subject to a claim of confidentiality shall be specifically
identified and submitted separately from information not subject to the claim.
e. Any schedule for compliance for applicable requirements with which the source is not in compliance at the time of
permit issuance shall be supplemental, and shall not sanction noncompliance with, the applicable requirements on
which it is based.
f. For any compliance schedule for applicable requirements with which the source is not in compliance at the time of
permit issuance, the permittee shall submit, at least every 6 months unless a more frequent period is specified in the
applicable requirement or by the Air Pollution Control Division, progress reports which contain the following:
(i)
dates for achieving the activities, milestones, or compliance required in the schedule for compliance, and
dates when such activities, milestones, or compliance were achieved; and
(ii) an explanation of why any dates in the schedule of compliance were not or will not be met, and any
preventive or corrective measures adopted.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 61
g•
The permittee shall not knowingly falsify, tamper with, or render inaccurate any monitoring device or method
required to be maintained or followed under the terms and conditions of the Operating Permit.
5. Emergency Provisions
Regulation No. 3, 5 CCR 1001-5. Part C. § VII.
An emergency means any situation arising from sudden and reasonably unforeseeable events beyond the control of the
source, including acts of God, which situation requires immediate corrective action to restore normal operation, and that
causes the source to exceed the technology -based emission limitation under the permit due to unavoidable increases in
emissions attributable to the emergency. "Emergency" does not include noncompliance to the extent caused by improperly
designed equipment, lack of preventative maintenance, careless or improper operation, or operator error. An emergency
constitutes an affirmative defense to an enforcement action brought for noncompliance with a technology -based emission
limitation if the permittee demonstrates, through properly signed, contemporaneous operating logs, or other relevant evidence
that:
a. an emergency occurred and that the permittee can identify the cause(s) of the emergency;
b. the permitted facility was at the time being properly operated;
c. during the period of the emergency the permittee took all reasonable steps to minimize levels of emissions that
exceeded the emission standards, or other requirements in the permit; and
d. the permittee submitted oral notice of the emergency to the Air Pollution Control Division no later than noon of the
next working day following the emergency, and followed by written notice within one month of the time when
emissions limitations were exceeded due to the emergency. This notice must contain a description of the
emergency, any steps taken to mitigate emissions, and corrective actions taken.
This emergency provision is in addition to any emergency or malfunction provision contained in any applicable requirement.
6. Emission Controls for Asbestos
Regulation No. 8, 5 CCR 1001-10, Part B
The permittee shall not conduct any asbestos abatement activities except in accordance with the provisions of Regulation No.
8, Part B, "asbestos control."
7. Emissions Trading, Marketable Permits, Economic Incentives
Regulation No. 3, 5 CCR 1001-5, Part C, $ V.C.13.
No permit revision shall be required under any approved economic incentives, marketable permits, emissions trading and
other similar programs or processes for changes that are specifically provided for in the permit.
8. Fee Payment
C.R.S. 25-7-114.1(6) and 25-7-114.7
a. The permittee shall pay an annual emissions fee in accordance with the provisions of § 25-7-114.7. A 1% per
month late payment fee shall be assessed against any invoice amounts not paid in full on the 91st day after the date
of invoice, unless a permittee has filed a timely protest to the invoice amount.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 62
b. The permittee shall pay a permit processing fee in accordance with the provisions of § 25-7-114.7. If the Division
estimates that processing of the permit will take more than 30 hours, it will notify the permittee of its estimate of
what the actual charges may be prior to commencing any work exceeding the 30 hour limit.
c. The permittee shall pay an APEN fee in accordance with the provisions of § 25-7-1 14.1(6) for each APEN or
revised APEN filed.
9. Fugitive Particulate Emissions
Regulation No. 1, 5 CCR 1001-3. § III.D.1.
The permittee shall employ such control measures and operating procedures as are necessary to minimize fugitive particulate
emissions into the atmosphere, in accordance with the provisions of Regulation No. 1, § 111.D.1.
10. Inspection and Entry
Regulation No. 3, 5 CCR 1001-5, Part C, § V.C.16.b.
Upon presentation of credentials and other documents as may be required by law, the permittee shall allow the Air Pollution
Control Division, or any authorized representative, to perform the following:
a. enter upon the permittee's premises where an Operating Permit source is located, or emissions -related activity is
conducted, or where records must be kept under the terms of the permit;
b. have access to, and copy, at reasonable times, any records that must be kept under the conditions of the permit;
c. inspect at reasonable times any facilities, equipment (including monitoring and air pollution control equipment),
practices, or operations regulated or required under the Operating Permit;
d. sample or monitor at reasonable times, for the purposes of assuring compliance with the Operating Permit or
applicable requirements, any substances or parameters.
11. Minor Permit Modifications
Regulation No. 3, 5 CCR 1001-5, Part C. §§ X. & XI.
The permittee shall submit an application for a minor permit modification before making the change requested in the
application. The permit shield shall not extend to minor permit modifications.
12. New Source Review
Regulation No. 3, 5 CCR 1001-5. Part B
The permittee shall not commence construction or modification of a source required to be reviewed under the New Source
Review provisions of Regulation No. 3, Part B, without first receiving a construction permit.
13. No Property Rights Conveyed
Regulation No. 3, 5 CCR 1001-5. Part C. § V.C.1 I .d.
This permit does not convey any property rights of any sort, or any exclusive privilege.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 63
14. Odor
Regulation No. 2, 5 CCR 1001-4. Part A
As a matter of state law only, the permittee shall comply with the provisions of Regulation No. 2 concerning odorous
emissions.
15. Off -Permit Changes to the Source
Regulation No. 3. 5 CCR 1001-5, Part C, X11.B.
The permittee shall record any off -permit change to the source that causes the emissions of a regulated pollutant subject to an
applicable requirement, but not otherwise regulated under the permit, and the emissions resulting from the change, including
any other data necessary to show compliance with applicable ambient air quality standards. The permittee shall provide
contemporaneous notification to the Air Pollution Control Division and to the Environmental Protection Agency at the
addresses listed in Appendix D of this Permit. The permit shield shall not apply to any off -permit change.
16. Opacity
Regulation No. 1, 5 CCR 1001-3, §§ I.. II.
The permittee shall comply with the opacity emissions limitation set forth in Regulation No. 1, §§ 1.-lI.
17. Open Burning
Regulation No. 9, 5 CCR 1001-11
The permittee shall obtain a permit from the Division for any regulated open burning activities in accordance with provisions
of Regulation No. 9.
18. Ozone Depleting Compounds
Regulation No. 15, 5 CCR 1001-17
The permittee shall comply with the provisions of Regulation No. 15 concerning emissions of ozone depleting compounds.
Sections I., ILC., II.D., 11I. IV., and V. of Regulation No. 15 shall be enforced as a matter of state law only.
19. Permit Expiration and Renewal
Regulation No. 3, 5 CCR 1001-5, Part C, V.C.2.
a. The permit term shall be five (5) years. The permit shall expire at the end of its term. Permit expiration terminates
the permittee's right to operate unless a timely and complete renewal application is submitted.
b. Applications for renewal shall be submitted at least twelve months, but not more than 18 months, prior to the
expiration of the Operating Permit. An application for permit renewal may address only those portions of the permit
that require revision, supplementing, or deletion, incorporating the remaining permit terms by reference from the
previous permit. A copy of any materials incorporated by reference must be included with the application.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 64
20. Portable Sources
Regulation No. 3, 5 CCR 1001-5. Part C. § II.D.
Portable Source permittees shall notify the Air Pollution Control Division at least 10 days in advance of each change in
location.
21. Prompt Deviation Reporting
Regulation No. 3. 5 CCR 1001-5, Part C. $ V.C.7.b.
The permittee shall promptly report any deviation from permit requirements, including those attributable to malfunction
conditions as defined in the permit, the probable cause of such deviations, and any corrective actions or preventive measures
taken.
"Prompt" is defined as follows:
a. Any definition of"prompt" or a specific timeframe for reporting deviations provided in an underlying applicable
requirement as identified in this permit; or
b. Where the underlying applicable requirement fails to address the time frame for reporting deviations, reports of
deviations will be submitted based on the following schedule:
(i)
For emissions of a hazardous air pollutant or a toxic air pollutant (as identified in the applicable regulation)
that continue for more than an hour in excess of permit requirements, the report shall be made within 24
hours of the occurrence;
(ii) For emissions of any regulated air pollutant, excluding a hazardous air pollutant or a toxic air pollutant that
continue for more than two hours in excess of permit requirements, the report shall be made within 48
hours; and
(iii) For all other deviations from permit requirements, the report shall be submitted every six (6) months,
except as otherwise specified by the Division in the permit in accordance with paragraph 22.d. below.
c. If any of the conditions in paragraphs b.i or b.ii above are met, the source shall notify the Division by telephone
(303-692-3155) or facsimile (303-782-0278) based on the timetables listed above. [Explanatory note: Notification
by telephone or facsimile must specify that this notification is a deviation report for an Operating Permit.] A
written notice, certified consistent with General Condition 2.a. above (Certification Requirements), shall be
submitted within 10 working days of the occurrence. All deviations reported under this section shall also be
identified in the 6 -month report required above.
"Prompt reporting" does not constitute an exception to the requirements of "Emergency Provisions" for the purpose of
avoiding enforcement actions.
22. Record Keeping and Reporting Requirements
Regulation No. 3. 5 CCR 1001-5. Part A. § II.; Part C, §§ V.C.6., V.C.7.
a. Unless otherwise provided in the source specific conditions of this Operating Permit, the permittee shall maintain
compliance monitoring records that include the following information:
(i) date, place as defined in the Operating Permit, and time of sampling or measurements;
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 65
(ii) date(s) on which analyses were performed;
(iii) the company or entity that performed the analysis;
(iv) the analytical techniques or methods used;
(v) the results of such analysis; and
(vi) the operating conditions at the time of sampling or measurement.
b. The permittee shall retain records of all required monitoring data and support information for a period of at least five
(5) years from the date of the monitoring sample, measurement, report or application. Support information, for this
purpose, includes all calibration and maintenance records and all original strip -chart recordings for continuous
monitoring instrumentation, and copies of all reports required by the Operating Permit. With prior approval of the
Air Pollution Control Division, the permittee may maintain any of the above records in a computerized form.
c. Permittees must retain records of all required monitoring data and support information for the most recent twelve
(12) month period, as well as compliance certifications for the past five (5) years on -site at all times. A permittee
shall make available for the Air Pollution Control Division's review all other records of required monitoring data
and support information required to be retained by the permittee upon 48 hours advance notice by the Division.
d. The permittee shall submit to the Air Pollution Control Division all reports of any required monitoring at least every
six (6) months, unless an applicable requirement, the compliance assurance monitoring rule, or the Division requires
submission on a more frequent basis. All instances of deviations from any permit requirements must be clearly
identified in such reports.
e. The permittee shall file an Air Pollutant Emissions Notice ("APEN") prior to constructing, modifying, or altering
any facility, process, activity which constitutes a stationary source from which air pollutants are or are to be emitted,
unless such source is exempt from the APEN filing requirements of Regulation No. 3, Part A, § II.D. A revised
APEN shall be filed annually whenever a significant change in emissions, as defined in Regulation No. 3, Part A, §
II.C.2., occurs; whenever there is a change in owner or operator of any facility, process, or activity; whenever new
control equipment is installed; whenever a different type of control equipment replaces an existing type of control
equipment; whenever a permit limitation must be modified; or before the APEN expires. An APEN is valid for a
period of five years. The five-year period recommences when a revised APEN is received by the Air Pollution
Control Division. Revised APENs shall be submitted no later than 30 days before the five-year term expires.
Permittees submitting revised APENs to inform the Division of a change in actual emission rates must do so by
April 30 of the following year. Where a permit revision is required, the revised APEN must be filed along with a
request for permit revision. APENs for changes in control equipment must be submitted before the change occurs.
Annual fees are based on the most recent APEN on file with the Division.
23. Reopenings for Cause
Regulation No. 3, 5 CCR 1001-5, Part C. § XII1.
a. The Air Pollution Control Division shall reopen, revise, and reissue Operating Permits; permit reopenings and
reissuance shall be processed using the procedures set forth in Regulation No. 3, Part C, § III., except that
proceedings to reopen and reissue permits affect only those parts of the permit for which cause to reopen exists.
b. The Division shall reopen a permit whenever additional applicable requirements become applicable to a major
source with a remaining permit term of three or more years, unless the effective date of the requirements is later than
the date on which the permit expires, or unless a general permit is obtained to address the new requirements;
whenever additional requirements (including excess emissions requirements) become applicable to an affected
source under the acid rain program; whenever the Division determines the permit contains a material mistake or that
inaccurate statements were made in establishing the emissions standards or other terms or conditions of the permit;
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 66
or whenever the Division determines that the permit must be revised or revoked to assure compliance with an
applicable requirement.
c. The Division shall provide 30 days' advance notice to the permittee of its intent to reopen the permit, except that a
shorter notice may be provided in the case of an emergency.
d. The permit shield shall extend to those parts of the permit that have been changed pursuant to the reopening and
reissuance procedure.
24. Section 502(b)(10) Changes
Regulation No. 3, 5 CCR 1001-5, Part C. MLA.
The permittee shall provide a minimum 7 -day advance notification to the Air Pollution Control Division and to the
Environmental Protection Agency at the addresses listed in Appendix D of this Permit. The permittee shall attach a copy of
each such notice given to its Operating Permit.
25. Severability Clause
Regulation No. 3. 5 CCR 1001-5, Part C. § V.C.10.
In the event of a challenge to any portion of the permit, all emissions limits, specific and general conditions, monitoring,
record keeping and reporting requirements of the permit, except those being challenged, remain valid and enforceable.
26. Significant Permit Modifications
Regulation No. 3. 5 CCR 1001-5, Part C. § 11I.B.2.
The permittee shall not make a significant modification required to be reviewed under Regulation No. 3, Part B
("Construction Permit" requirements) without first receiving a construction permit. The permittee shall submit a complete
Operating Permit application or application for an Operating Permit revision for any new or modified source within twelve
months of commencing operation, to the address listed in Item 1 in Appendix D of this permit. If the permittee chooses to
use the "Combined Construction/Operating Permit" application procedures of Regulation No. 3, Part C, then the Operating
Permit must be received prior to commencing construction of the new or modified source.
27. Special Provisions Concerning the Acid Rain Program
Regulation No. 3. 5 CCR 1001-5, Part C, $5 V.C.1.b. & 8
a. Where an applicable requirement of the federal act is more stringent than an applicable requirement of regulations
promulgated under Title IV of the federal act, 40 Code of Federal Regulations (CFR) Part 72, both provisions shall
be incorporated into the permit and shall be federally enforceable.
b. Emissions exceeding any allowances that the source lawfully holds under Title IV of the federal act or the
regulations promulgated thereunder, 40 CFR Part 72, are expressly prohibited.
28. Transfer or Assignment of Ownership
Regulation No. 3. 5 CCR 1001-5, Part C. § II.C.
No transfer or assignment of ownership of the Operating Permit source will be effective unless the prospective owner or
operator applies to the Air Pollution Control Division on Division -supplied Administrative Permit Amendment forms, for
reissuance of the existing Operating Permit. No administrative permit shall be complete until a written agreement containing
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit # 05OPWE279
Public Service Company of Colorado
Rocky Mountain Energy Center
Page 67
a specific date for transfer of permit, responsibility, coverage, and liability between the permittee and the prospective owner
or operator has been submitted to the Division.
29. Volatile Organic Compounds
Regulation No. 7, 5 CCR 1001-9, 5 III & V.
The requirements in paragraphs a, b and e apply to sources located in an ozone non -attainment area or the Denver 1 -hour
ozone attainment/maintenance area. The requirements in paragraphs c and d apply statewide.
a. All storage tank gauging devices, anti -rotation devices, accesses, seals, hatches, roof drainage systems, support
structures, and pressure relief valves shall be maintained and operated to prevent detectable vapor loss except when
opened, actuated, or used for necessary and proper activities (e.g. maintenance). Such opening, actuation, or use
shall be limited so as to minimize vapor loss.
Detectable vapor loss shall be determined visually, by touch, by presence of odor, or using a portable hydrocarbon
analyzer. When an analyzer is used, detectable vapor loss means a V0C concentration exceeding 10,000 ppm.
Testing shall be conducted as in Regulation No. 7, Section VIII.C.3.
b. Except when otherwise provided by Regulation No. 7, all volatile organic compounds, excluding petroleum liquids,
transferred to any tank, container, or vehicle compartment with a capacity exceeding 212 liters (56 gallons), shall be
transferred using submerged or bottom filling equipment. For top loading, the fill tube shall reach within six inches
of the bottom of the tank compartment. For bottom -fill operations, the inlet shall be flush with the tank bottom.
c. The permittee shall not dispose of volatile organic compounds by evaporation or spillage unless Reasonably
Available Control Technology (RACT) is utilized.
d. No owner or operator of a bulk gasoline terminal, bulk gasoline plant, or gasoline dispensing facility as defined in
Colorado Regulation No. 7, Section VI, shall permit gasoline to be intentionally spilled, discarded in sewers, stored
in open containers, or disposed of in any other manner that would result in evaporation.
e. Beer production and associated beer container storage and transfer operations involving volatile organic compounds
with a true vapor pressure of less than 1.5 PSIA actual conditions are exempt from the provisions of paragraph b,
above.
30. Wood Stoves and Wood burning Appliances
Regulation No. 4, 5 CCR 1001-6
The permittee shall comply with the provisions of Regulation No. 4 concerning the advertisement, sale, installation, and use
of wood stoves and wood burning appliances.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Appendices
OPERATING PERMIT APPENDICES
A - INSPECTION INFORMATION
B - MONITORING AND PERMIT DEVIATION REPORT
C COMPLIANCE CERTIFICATION REPORT
D - NOTIFICATION ADDRESSES
E - PERMIT ACRONYMS
F - PERMIT MODIFICATIONS
*DISCLAIMER:
None of the information found in these Appendices shall be considered to be State or
Federally enforceable, except as otherwise provided in the permit, and is presented to
assist the source, permitting authority, inspectors, and citizens.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Inspection Information
Appendix A
Page 1
APPENDIX A - Inspection Information
Directions to Plant
The facility is located at 6211 Weld County Road 51 (between Hudson and Keenesburg, east of 1-76,
accessible from the Kersey Rd exit).
Safety Equipment Required
Eye Protection, Hard Hat, Safety Shoes and Hearing Protection
Facility Plot Plan
Figure 1 (following page) shows the plot plan as submitted on March 14, 2005 with the source's Title V
Operating Permit Application.
List of Insignificant Activities
The following list of insignificant activities was provided by the source to assist in the understanding of
the facility layout. Since there is no requirement to update such a list, activities may have changed since
the last filing.
The asterisk (*) denotes an insignificant activity source category based on the size of the activity,
emissions levels from the activity or the production rate of the activity. The owner or operator of
individual emission points in insignificant activity source categories marked with an asterisk (*) must
maintain sufficient record keeping verifying that the exemption applies. Such records shall be made
available for Division review upon request. (Colorado Regulation No. 3, Part C, Section II.E):
Units with emissions less than APEN de minimis — criteria pollutants (Reg 3, Part C.II.E.3.a)*
Units with emissions less than APEN de minimis —non-criteria reportable pollutants (Reg 3. Part
C.II.E.3. b)
Two (2) 14,200 gal anhydrous ammonia storage tanks
Landscaping and site housekeeping devices < 10 hp (Reg 3. Part C.II.E.3.bb)*
Garden tractor
Weed trimmer
Storage tanks with annual throughput less than 400.000 gal and meeting content specifications (Reg 3.
Part C.II.E.3.fff)*
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Inspection Information
Appendix A
Page 2
500 gallon above ground diesel fuel tank
100 gallon portable diesel fuel tank mounted in the back of a facility vehicle
Forklifts (Rev. 3. Part C.II.E.3.kkk)
Forklift
Not a source of emissions
8,400 gallon condensate (water) tank
Non -Road Engines
Snow blower (gasoline engine rated at 11.0 hp)
Portable Hotsy pressure washer (engine rated at 11.5 hp)
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Inspection Information
Appendix A
Page 3
,00'00 L
Figure 1: Facility Plot Plan
Rocky Mountain Energy Center
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Monitoring and Permit Deviation Report
Appendix B
Page 1
APPENDIX B
Reporting Requirements and Definitions
with codes ver 8/20/1.1
Please note that, pursuant to 113(c)(2) of the federal Clean Air Act, any person who knowingly:
(A) makes any false material statement, representation, or certification in, or omits material information
from, or knowingly alters, conceals, or fails to file or maintain any notice, application, record, report,
plan, or other document required pursuant to the Act to be either filed or maintained (whether with
respect to the requirements imposed by the Administrator or by a State);
(B) fails to notify or report as required under the Act; or
(C) falsifies, tampers with, renders inaccurate, or fails to install any monitoring device or method required to
be maintained or followed under the Act shall, upon conviction, be punished by a fine pursuant to title
18 of the United States Code, or by imprisonment for not more than 2 years, or both. If a conviction of
any person under this paragraph is for a violation committed after a first conviction of such person under
this paragraph, the maximum punishment shall be doubled with respect to both the fine and
imprisonment.
The permittee must comply with all conditions of this operating permit. Any permit noncompliance constitutes
a violation of the Act and is grounds for enforcement action; for peinlit termination, revocation and reissuance,
or modification; or for denial of a permit renewal application.
The Part 70 Operating Permit program requires three types of reports to be filed for all permits.
All required reports must be certified by a responsible official.
Report #1: Monitoring Deviation Report (due at least every six months)
For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six
months unless otherwise noted in the permit. All instances of deviations from peintit monitoring requirements
must be clearly identified in such reports.
For purposes of this operating permit, monitoring means any condition determined by observation, by data from
any monitoring protocol, or by any other monitoring which is required by the permit as well as the
recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate
monitoring, fuel analyses, and operational or control device parameter monitoring.
Report #2: Permit Deviation Report (must be reported "promptly")
In addition to the monitoring requirements set forth in the permits as discussed above, each and every
requirement of the permit is subject to deviation reporting. The reports must address deviations from permit
requirements, including those attributable to malfunctions as defined in this Appendix, the probable cause of
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Monitoring and Permit Deviation Report
Appendix B
Page 2
such deviations, and any corrective actions or preventive measures taken. All deviations from any term or
condition of the permit are required to be summarized or referenced in the annual compliance certification.
For purposes of this operating permit, "malfunction" shall refer to both emergency conditions and malfunctions.
Additional discussion on these conditions is provided later in this Appendix.
For purposes of this operating permit, the Division is requiring that the permit deviation reports are due as set
forth in General Condition 21. Where the underlying applicable requirement contains a definition of prompt or
otherwise specifies a time frame for reporting deviations, that definition or time frame shall govern. For
example, quarterly Excess Emission Reports required by an NSPS or Regulation No. 1, Section IV.
In addition to the monitoring deviations discussed above, included in the meaning of deviation for the purposes
of this operating permit are any of the following:
(1) A situation where emissions exceed an emission limitation or standard contained in the permit;
(2) A situation where process or control device parameter values demonstrate that an emission limitation
or standard contained in the permit has not been met;
A situation in which observations or data collected demonstrates noncompliance with an emission
limitation or standard or any work practice or operating condition required by the permit; or.
(4) A situation in which an excursion or exceedance as defined in 40CFR Part 64 (the Compliance
Assurance Monitoring (CAM) Rule) has occurred. (only if the emission point is subject to CAM)
For reporting purposes. the Division has combined the Monitoring Deviation Report with the Permit Deviation
Report. All deviations shall be reported using the following codes:
(3)
1 = Standard:
2 = Process:
3 = Monitor:
4 = Test:
5 = Maintenance:
6 = Record:
7 = Report:
8 = CAM:
9 = Other:
When the requirement is an emission limit or standard
When the requirement is a production/process limit
When the requirement is monitoring
When the requirement is testing
When required maintenance is not performed
When the requirement is recordkeeping
When the requirement is reporting
A situation in which an excursion or exceedance as defined in 40CFR Part 64 (the
Compliance Assurance Monitoring (CAM) Rule) has occurred.
When the deviation is not covered by any of the above categories
Report #3: Compliance Certification (annually, as defined in the permit)
Submission of compliance certifications with terms and conditions in the permit, including emission limitations.
standards, or work practices, is required not less than annually.
Compliance Certifications are intended to state the compliance status of each requirement of the permit over the
certification period. They must be based, at a minimum, on the testing and monitoring methods specified in the
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Monitoring and Permit Deviation Report
Appendix B
Page 3
permit that were conducted during the relevant time period. In addition, if the owner or operator knows of other
material information (i.e. information beyond required monitoring that has been specifically assessed in relation
to how the information potentially affects compliance status). that information must be identified and addressed
in the compliance certification. The compliance certification must include the following:
• The identification of each term or condition of the permit that is the basis of the certification;
• Whether or not the method(s) used by the owner or operator for determining the compliance
status with each permit term and condition during the certification period was the method(s)
specified in the permit. Such methods and other means shall include, at a minimum, the methods
and means required in the permit. If necessary, the owner or operator also shall identify any
other material information that must be included in the certification to comply with section
113(c)(2) of the Federal Clean Air Act, which prohibits knowingly making a false certification or
omitting material information;
• The status of compliance with the terms and conditions of the permit, and whether compliance
was continuous or intermittent. The certification shall identify each deviation and take it into
account in the compliance certification. Note that not all deviations are considered violations.1
• Such other facts as the Division may require, consistent with the applicable requirements to
which the source is subject, to determine the compliance status of the source.
The Certification shall also identify as possible exceptions to compliance any periods during which compliance
is required and in which an excursion or exceedance as defined under 40 CFR Part 64 (the Compliance
Assurance Monitoring (CAM) Rule) has occurred. (only for emission points subject to CAM)
Note the requirement that the certification shall identify each deviation and take it into account in the
compliance certification. Previously submitted deviation reports, including the deviation report submitted at the
time of the annual certification, may be referenced in the compliance certification.
Startup, Shutdown, Malfunctions and Emergencies
Understanding the application of Startup, Shutdown, Malfunctions and Emergency Provisions, is very important
in both the deviation reports and the annual compliance certifications.
Startup, Shutdown, and Malfunctions
Please note that exceedances of some New Source Performance Standards (NSPS) and Maximum Achievable
Control Technology (MACT) standards that occur during Startup. Shutdown or Malfunctions may not be
considered to be non-compliance since emission limits or standards often do not apply unless specifically stated
in the NSPS. Such exceedances must, however, be reported as excess emissions per the NSPS/MACT rules and
1 For example, given the various emissions limitations and monitoring requirements to which a source may be
subject, a deviation from one requirement may not be a deviation under another requirement which recognizes
an exception and/or special circumstances relating to that same event.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Monitoring and Permit Deviation Report
Appendix B
Page 4
would still be noted in the deviation report. In regard to compliance certifications, the permittee should be
confident of the information related to those deviations when making compliance determinations since they are
subject to Division review. The concepts of Startup, Shutdown and Malfunctions also exist for Best Available
Control Technology (BACT) sources, but are not applied in the same fashion as for NSPS and MACT sources.
Emergency Provisions
Under the Emergency provisions of Part 70 certain operational conditions may act as an affirmative defense
against enforcement action if they are properly reported.
DEFINITIONS
Malfunction (NSPS) means any sudden, infrequent, and not reasonably preventable failure of air pollution
control equipment, process equipment, or a process to operate in a normal or usual manner. Failures that are
caused in part by poor maintenance or careless operation are not malfunctions.
Malfunction (SIP) means any sudden and unavoidable failure of air pollution control equipment or process
equipment or unintended failure of a process to operate in a normal or usual manner. Failures that are primarily
caused by poor maintenance, careless operation, or any other preventable upset condition or preventable
equipment breakdown shall not be considered malfunctions.
Emergency means any situation arising from sudden and reasonably unforeseeable events beyond the control of
the source, including acts of God, which situation requires immediate corrective action to restore normal
operation, and that causes the source to exceed a technology -based emission limitation under the permit, due to
unavoidable increases in emissions attributable to the emergency. An emergency shall not include
noncompliance to the extent caused by improperly designed equipment, lack of preventative maintenance,
careless or improper operation, or operator error.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Monitoring and Permit Deviation Report
Appendix B
Page 5
Monitoring and Permit Deviation Report - Part I
1. Following is the required format for the Monitoring and Permit Deviation report to be submitted to the
Division as set forth in General Condition 21. The Table below must be completed for all equipment or
processes for which specific Operating Permit terms exist.
2. Part II of this Appendix B shows the format and information the Division will require for describing
periods of monitoring and permit deviations, or malfunction or emergency conditions as indicated in the
Table below. One Part II Form must be completed for each Deviation. Previously submitted reports
(e.g. EER's or malfunctions) may be referenced and the form need not be filled out in its entirety.
FACILITY NAME: Public Service Company of Colorado - Rocky Mountain Energy Center
OPERATING PERMIT NO: 05OPWE279
REPORTING PERIOD: (see first page of the permit for specific reporting period and dates)
Operating
Permit Unit
ID
Unit Description
Deviations Noted
During Period?'
Deviation
Code2
Malfunction/
Emergency
Condition Reported
During Period?
YES
NO
YES
NO
CT -01
One (1) Westinghouse, Model No. 501FD,
Natural Gas -Fired Combustion Turbine, Serial
No. 37A8191. The Turbine is Rated at 1785
MMBtu/hr (HHV at ISO conditions). The turbine
is operated in combined cycle mode only and the
heat recovery steam generator (HRSG) is
equipped with a duct burner rated at 675
IVIMBtu/hr. The turbine drives a generator
capable of generating 152 MW of power and the
HRSG drives a steam generator rated at 326 MW
(at peak capacity).
CT -02
One (1) Westinghouse, Model No. 501FD.
Natural Gas -Fired Combustion Turbine, Serial
No. 37A8196. The Turbine is Rated at 1785
IVIMBtu/hr (HHV at ISO conditions). The turbine
is operated in combined cycle mode only and the
heat recovery steam generator (HRSG) is
equipped with a duct burner rated at 675
MMBtu/hr. The turbine drives a generator
capable of generating 152 MW of power and the
HRSG drives a steam generator rated at 326 MW
(at peak capacity).
S005
Caterpillar, Model No. 3512B, Internal
Combustion Engine Driving an Emergency
Generator, Serial No. 1GZ01360. The Engine is
Diesel Fuel -Fired and rated at 1810 hp and 12.2
MMBtu/hr.
Operating Permit Number: 05OPWE279
First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Monitoring and Permit Deviation Report
Appendix B
Page 6
Operating
Permit Unit
ID
Unit Description
Deviations Noted
During Period?'
Deviation
Code2
Malfunction/
Emergency
Condition Reported
During Period?
YES
NO
YES
NO
S004
Rentech, Natural Gas Fired Boiler, Rated at 129
MMBtu/hr, Serial No. 2002-49.
S006
Marley, Model No. F4910, 12 Cell Cooling Water
Tower, Rated at 176,000 gal/min.
M001
Gasoline Storage Tank, 500 gallons, aboveground
M003
John Deere, Model No. 6081AF001, Serial No.
RG6081A159985, Diesel Fired Internal
Combustion Engine Driving an Emergency Fire
Pump Engine, Rated at 182 hp and 1.26
MMBtu/hr.
General Conditions
Insignificant Activities
See previous discussion regarding what is considered to be a deviation. Determination of whether or not a deviation has occurre
shall be based on a reasonable inquiry using readily available information.
Use the following entries, as appropriate:
1 = Standard: When the requirement is an emission limit or standard
2 = Process: When the requirement is a production/process limit
3 = Monitor: When the requirement is monitoring
4 = Test: When the requirement is testing
5 = Maintenance: When required maintenance is not performed
6 = Record: When the requirement is recordkeeping
7 = Report: When the requirement is reporting
8 = CAM: A situation in which an excursion or exceedance as defined in 40CFR Part 64 (the Compliance Assurance
Monitoring (CAM) Rule) has occurred.
9 = Other: When the deviation is not covered by any of the above categories
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Monitoring and Permit Deviation Report
Appendix B
Page 7
Monitoring and Permit Deviation Report - Part II
FACILITY NAME: Public Service Company of Colorado - Rocky Mountain Energy Center
OPERATING PERMIT NO: 05OPWE279
REPORTING PERIOD:
Is the deviation being claimed as an:
Emergency Malfunction N/A
(For NSPS/MACT) Did the deviation occur during: Startup Shutdown
Normal Operation
OPERATING PERMIT UNIT IDENTIFICATION:
Operating Permit Condition Number Citation
Explanation of Period of Deviation
Duration (start/stop date & time)
Action Taken to Correct the Problem
Measures Taken to Prevent a Reoccurrence of the Problem
Dates of Malfunctions/Emerencies Reported (if applicable)
Deviation Code
Division Code QA:
SEE EXAMPLE ON THE NEXT PAGE
Malfunction
Operating Permit Number: 05OPWE279
First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Monitoring and Permit Deviation Report
EXAMPLE
FACILITY NAME: Acme Corp.
OPERATING PERMIT NO: 96OPZZXXX
REPORTING PERIOD: 1/1/04 - 6/30/06
Appendix B
Page 8
Is the deviation being claimed as an: Emergency Malfunction XX N/A
(For NSPS/MACT) Did the deviation occur during: Startup Shutdown
Normal Operation
OPERATING PERMIT UNIT IDENTIFICATION:
Asphalt Plant with a Scrubber for Particulate Control - Unit XXX
Operating Permit Condition Number Citation
Section IL Condition 3.1 - Opacity Limitation
Explanation of Period of Deviation
Slurry Line Feed Plugged
Duration
START- 1730 4/10/06
END- 1800 4/10/06
Malfunction
Action Taken to Correct the Problem
Line Blown Out
Measures Taken to Prevent Reoccurrence of the Problem
Replaced Line Filter
Dates of Malfunction/Emergencies Reported (if applicable)
5/30/06 to A. Einstein, APCD
Deviation Code Division Code QA:
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Monitoring and Permit Deviation Report
Appendix B
Page 9
Monitoring and Permit Deviation Report - Part III
REPORT CERTIFICATION
SOURCE NAME: Public Service Company of Colorado - Rocky Mountain Energy Center
FACILITY IDENTIFICATION NUMBER: 1231342
PERMIT NUMBER: 05OPWE279
REPORTING PERIOD: (see first page of the permit for specific reporting period and dates)
All information for the Title V Semi -Annual Deviation Reports must be certified by a responsible official as
defined in Colorado Regulation No. 3, Part A, Section I.B. This signed certification document must be
packaged with the documents being submitted.
STATEMENT OF COMPLETENESS
I have reviewed the information being submitted in its entirety and, based on information and belief
formed after reasonable inquiry, I certify that the statements and information contained in this submittal
are true, accurate and complete.
Please note that the Colorado Statutes state that any person who knowingly, as defined in Sub -Section 18-
1-501(6), C.R.S., makes any false material statement, representation, or certification in this document is
guilty of a misdemeanor and may be punished in accordance with the provisions of Sub -Section 25-7
122.1, C.R.S.
Printed or Typed Name Title
Signature of Responsible Official Date Signed
Note: Deviation reports shall be submitted to the Division at the address given in Appendix D of this
permit. No copies need be sent to the U.S. EPA.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Compliance Certification Report
Appendix C
Page 1
APPENDIX C
Required Format for Annual Compliance Certification Report
with codes ver 8/20/14
Following is the format for the Compliance Certification report to be submitted to the Division and the U.S.
EPA annually based on the effective date of the permit. The Table below must be completed for all equipment
or processes for which specific Operating Permit terms exist.
FACILITY NAME: Public Service Company of Colorado - Rocky Mountain Energy Center
OPERATING PERMIT NO: 05OPWE279
REPORTING PERIOD:
I. Facility Status
During the entire reporting period, this source was in compliance with ALL terms and conditions contained
in the Permit, each term and condition of which is identified and included by this reference. The method(s)
used to determine compliance is/are the method(s) specified in the Permit.
With the possible exception of the deviations identified in the table below, this source was in compliance
with all terms and conditions contained in the Permit, each term and condition of which is identified and
included by this reference, during the entire reporting period. The method used to determine compliance for
each term and condition is the method specified in the Permit, unless otherwise indicated and described in the
deviation report(s). Note that not all deviations are considered violations.
Operating
Permit
Unit ID
Unit Description
Deviations
Reported 1
Monitoring
Method per
Permit?-
Was Compliance
Continuous or
Intermittent?3
Previous
Current
YES
NO
Continuous
Intermittent
CT -0I
One (I) Westinghouse, Model No. 501FD,
Natural Gas -Fired Combustion Turbine,
Serial No. 37A8191. The Turbine is Rated
at 1785 MMBtu/hr (HHV at ISO
conditions). The turbine is operated in
combined cycle mode only and the heat
recovery steam generator (HRSG) is
equipped with a duct burner rated at 675
MMBtu/hr. The turbine drives a generator
capable of generating 152 MW of power
and the HRSG drives a steam generator
rated at 326 MW (at peak capacity).
Operating Permit Number: 05OPWE279
First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Compliance Certification Report
Appendix C
Page 2
Operating
Permit
Unit ID
Unit Description
Deviations
Reported'
Monitoring
Method per
Permit?-
Was Compliance
Continuous or
Intermittent?3
Previous
Current
YES
NO
Continuous
Intermittent
CT -02
One (1) Westinghouse, Model No. 501FD,
Natural Gas -Fired Combustion Turbine,
Serial No. 37A8196. The Turbine is Rated
at 1785 MMBtu/hr (HHV at ISO
conditions). The turbine is operated in
combined cycle mode only and the heat
recovery steam generator (HRSG) is
equipped with a duct burner rated at 675
MMBtu/hr. The turbine drives a generator
capable of generating 152 MW of power
and the HRSG drives a steam generator
rated at 326 MW (at peak capacity).
S005
Caterpillar, Model No. 3512B, Internal
Combustion Engine Driving an Emergency
Generator, Serial No. 1GZ01360. The
Engine is Diesel Fuel -Fired and rated at
1810 hp and 12.2 MMBtu/hr.
S004
Rentech, Natural Gas Fired Boiler, Rated at
129 MMBtu/hr, Serial No. 2002-49.
S006
Marley, Model No. F4910, 12 Cell Cooling
Water Tower, Rated at 176,000 gal/min.
M001
Gasoline Storage Tank, 500 gallons,
aboveground
M003
John Deere, Model No. 6081AF001, Serial
No. RG6081A159985, Diesel Fired
Internal Combustion Engine Driving an
Emergency Fire Pump Engine, Rated at
182 hp and 1.26 MMBtu/hr.
General Conditions
Insignificant Activities 4
If deviations were noted in a previous deviation report , put an "X" under "previous". If deviations were noted in the current
deviation report (i.e. for the last six months of the annual reporting period), put an "X" under "current". Mark both columns if both
apply.
2 Note whether the method(s) used to determine the compliance status with each term and condition was the method(s) specified in the
permit. If it was not, mark "no" and attach additional information/explanation.
3 Note whether the compliance status with of each term and condition provided was continuous or intermittent. "Intermittent
Compliance" can mean either that noncompliance has occurred or that the owner or operator has data sufficient to certify compliance
only on an intermittent basis. Certification of intermittent compliance therefore does not necessarily mean that any noncompliance
has occurred.
NOTE:
The Periodic Monitoring requirements of the Operating Permit program rule are intended to provide assurance that even in the
absence of a continuous system of monitoring the Title V source can demonstrate whether it has operated in continuous compliance
for the duration of the reporting period. Therefore, if a source 1) conducts all of the monitoring and recordkeeping required in its
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Compliance Certification Report
Appendix C
Page 3
permit. even if such activities are done periodically and not continuously, and if 2) such monitoring and recordkeeping does not
indicate non-compliance, and if 3) the Responsible Official is not aware of any credible evidence that indicates non-compliance, then
the Responsible Official can certify that the emission point(s) in question were in continuous compliance during the applicable time
period.
' Compliance status for these sources shall be based on a reasonable inquiry using readily available information.
II. Status for Accidental Release Prevention Program:
A. This facility is subject is not subject to the provisions of the Accidental
Release Prevention Program (Section 112(r) of the Federal Clean Air Act)
B. If subject: The facility
requirements of section 112(r).
is is not in compliance with all the
1. A Risk Management Plan will be has been submitted to the
appropriate authority and/or the designated central location by the required date.
III. Certification
All information for the Annual Compliance Certification must be certified by a responsible official as defined in
Colorado Regulation No. 3, Part A, Section I.B. This signed certification document must be packaged with the
documents being submitted.
I have reviewed this certification in its entirety and, based on information and belief formed after
reasonable inquiry, I certify that the statements and information contained in this certification are true,
accurate and complete.
Please note that the Colorado Statutes state that any person who knowingly, as defined in § 18-1-501(6),
C.R.S., makes any false material statement, representation, or certification in this document is guilty of a
misdemeanor and may be punished in accordance with the provisions of § 25-7 122.1, C.R.S.
Printed or Typed Name Title
Signature Date Signed
NOTE: All compliance certifications shall be submitted to the Air Pollution Control Division and to the
Environmental Protection Agency at the addresses listed in Appendix D of this Permit.
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Notification Addresses
Appendix D
Page 1
APPENDIX D
Notification Addresses
1. Air Pollution Control Division
Colorado Department of Public Health and Environment
Air Pollution Control Division
Operating Permits Unit
APCD-SS-B 1
4300 Cherry Creek Drive S.
Denver. CO 80246-1530
ATTN: Matt Burgett
2. United States Environmental Protection Agency
Compliance Notifications:
Office of Enforcement. Compliance and Environmental Justice
Mail Code 8ENF-AT
U.S. Environmental Protection Agency, Region VIII
1595 Wynkoop Street
Denver, CO 80202-1129
502(b)(10) Changes, Off Permit Changes:
Office of Partnerships and Regulatory Assistance
Air and Radiation Programs, 8P -AR
U.S. Environmental Protection Agency, Region VIII
1595 Wynkoop Street
Denver, CO 80202-1129
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit Acronyms
Appendix E
Page l
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 - Normal Operation, as referenced in permit limitation table in Section 11.1
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
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit Acronyms
Appendix E
Page 2
PMIo - Particulate Matter Under 10 Microns
PPM - Parts Per Million
PPMV - Parts Per Million, by Volume
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
SD - Shutdown, as referenced in permit limitation table in Section II.I
SIC - Standard Industrial Classification
SO2 - Sulfur Dioxide
SU - Start -Up, as referenced in permit limitation table in Section II.1
TPY - Tons Per Year
TSP - Total Suspended Particulate
VOC - Volatile Organic Compounds
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
Air Pollution Control Division
Colorado Operating Permit
Permit Modifications
Appendix F
Page 1
APPENDIX F
Permit Modifications
DATE OF
REVISION
MODIFICATION
TYPE
SECTION NUMBER,
CONDITION
NUMBER
DESCRIPTION OF REVISION
Operating Permit Number: 05OPWE279 First Issued: 7/1/07
Renewed: DRAFT
TECHNICAL REVIEW DOCUMENT
For
RENEWAL TO OPERATING PERMIT 05OPWE279
Public Service Company of Colorado — Rock Mountain Energy Center
Weld County
Source ID 1231342
Prepared by Jacqueline Joyce
July and August 2016
Revised September 2016
Reviewed by:
Operating Permit Supervisor:
Field Services Unit:
I. Purpose:
Matt Burgett
Jeffrey Bishop
This document will establish the basis for decisions made regarding the
applicable requirements, emission factors, monitoring plan and compliance
status of emission units covered by the renewed operating permit proposed for
this site. The current Operating Permit was issued July 1, 2012. The expiration
date for the permit is July 1, 2017. This document is designed for reference
during the review of the proposed permit by the EPA, the public, and other
interested parties. The conclusions made in this report are based on information
provided in the renewal application submitted June 27, 2016, comments on the
draft permit and technical review document received on September 27, 2016,
previous inspection reports and various e-mail correspondence, as well as
telephone conversations with the applicant. Please note that copies of the
Technical Review Document for the original permit and any Technical Review
Documents associated with subsequent modifications of the original Operating
Permit may be found in the Division files as well as on the Division website at
www.colorado.gov/cdphe/airTitleV. This narrative is intended only as an adjunct
for the reviewer and has no legal standing.
Any revisions made to the underlying construction permits associated with this
facility made in conjunction with the processing of this operating permit
application have been reviewed in accordance with the requirements of
Regulation No. 3, Part B, Construction Permits, and have been found to meet all
applicable substantive and procedural requirements. This operating permit
incorporates and shall be considered to be a combined construction/operating
permit for any such revision, and the permittee shall be allowed to operate under
the revised conditions upon issuance of this operating permit without applying for
a revision to this permit or for an additional or revised construction permit.
Page 1
II. Description of Source
The facility consists of two natural gas fired combustion turbines, two heat
recovery steam generators (HRSG), each equipped with natural gas fired duct
burners, a steam turbine, cooling tower and auxiliary boiler. There are two diesel
fired engines, one driving an emergency generator and one driving a fire pump.
There is also a gasoline storage tank that is included in Section II of the permit.
The Rocky Mountain Energy Center (RMEC) has the capacity to generate up to
630 MW of electricity. Each combustion turbine can generate approximately 152
MW, with an additional 326 MW (at peak capacity) from the steam turbine. The
turbines are not equipped with a by-pass stack, therefore, the turbines only
operate in combined cycle mode (i.e. turbine plus HRSG).
The facility is located at 6211 Weld County Road 51, just east of the town of
Hudson, in Weld County Colorado (bounded by CR 49 to the west, CR 16 to the
north and CR 51 to the east). The area in which the plant operates is designated
as attainment for all criteria pollutants except ozone. It is classified as non -
attainment for ozone and is part of the 8 -hr Ozone Control Area as defined in
Regulation No. 7, Section II.A.1.
There are no affected states within 50 miles of this facility. Rocky Mountain
National Park, a federal class I designated area is within 100 km of this facility.
Based on the information provided in the renewal application, no changes have
been made to any of the significant emission units.
The summary of emissions that was presented in the Technical Review
Document (TRD) for the first renewal permit has been reproduced here. Since
there have been no changes to permitted emission and/or fuel consumption
limitations and no new emission units have been added to the facility, the
potential to emit (PTE) has not changed. Potential emissions (in tons per year)
at the facility are as follows:
Page 2
Potential To Emit
Emission Unit
PM
PM10
SO2
NOx
CO
VOC
HAPS
Turbines/HRSGs
126.8
126.8
11.8
240.4
782.2
50.6
See
Table on
Page 16
Aux. Boiler'
2.28
2.28
0.07
4.7
4.75
0.64
Emergency
Generator
0.40
0.40
0.16
6.88
8.48
1.00
Fire Water
Pump3
0.02
0.02
0.02
0.60
0.36
0.07
Cooling Tower4
19.3
19.3
0.89
Total
148.8
148.8
12.06
252.58
795.79
53.20
13.01
1SO2 and VOC emissions are based on the permitted fuel limit and AP -42 emissions factors
(Section 1.4, dated 3/98, Table 1.4-2).
Emissions based on 500 hours/year of operation (per September 6, 1995 EPA Memo,
"Calculating Potential to Emit (PTE) for Emergency Generators"), maximum hp and for all but SO2
manufacturer's emission factors, SO2 based on sulfur content of 0.05 wt % (fuel density 7.05
lb/gal).
3Emissions based on 500 hours/year of operation, maximum hp and for all but SO2
manufacturer's emission factors, SO2 based on sulfur content of 0.05 wt % (fuel density 7.05
lb/gal). 500 hours per year of operation was used in accordance with EPA's September 6, 1995
memo. Although that memo addresses emergency generators only, the Division considers the
memo is appropriate to use for emergency fire pump engines.
4VOC emissions are based on the permitted water circulation rate and the emission factor from
"Locating and Estimating Air Emissions from Sources of Chloroform", EPA-450/4-84-007c,March
1984, for re -circulating units. All VOC is chloroform.
Except as indicated in the footnotes in the above table, the potential to emit of
criteria pollutants and total HAPs is based on permitted emission limits.
Note that actual emissions are typically less than potential emissions and actual
emissions are shown in the table below:
Emission Unit
Data
Year'
PM
PM13/PM2.5
SO2
NOx
CO
VOC
HAPS
CT -01
2015
13.2
13.2
2.3
34.4
132
2.7
3.04
CT -02
2015
17.4
17.4
2.3
87
96.7
0.6
3.15
Emerg. Gen
2014
0.33
0.09
Aux Blr
2013
Cooling Twr
2013
6.3
6.3
0.20
Total
36.9
36.9
4.6
121.73
228.7
3.59
6.19
'Actual emissions from data year 2015 based on APENs submitted on 4/27/16. Actual emissions
from data year 2014 based on APENs submitted 4/29/15. Actual emissions from data year 2013
based on APENs submitted on April 29, 2014.
Page 3
The breakdown of HAP emissions by emission unit and individual HAP is
provided on page 16 of this document. The method of estimating HAP emissions
is indicated in the footnotes on this table.
National Emission Standards for Hazardous Air Pollutants (NESHAP) for
Source Categories
As indicated in the above table summarizing potential to emit, the facility is not a
major source for HAPS. The applicability of various NESHAPs (also referred to
as "MACT requirements") that apply to area sources was discussed in the TRD
to support the first renewal permit (issued July 1, 2012). That discussion has
been updated to reflect changes to the various MACT standards and the
promulgation of any new standards that may apply.
Paint Stripping and Miscellaneous Surface Coating at Area Sources (40 CFR
Part 63 Subpart HHHHHH)
As discussed in the technical review document for the renewal permit (issued
July 1, 2012), these requirements do not apply for the following reasons. The
Division considers that any spray coatings of motor vehicles and mobile
equipment and spray application of coatings that contain the target HAP at this
facility would meet the definition of facility maintenance and none of the paint
stripping chemicals used at the facility contain methylene chloride.
Gasoline Dispensing Facilities (40 CFR Part 63 Subpart CCCCCC)
These requirements apply to each gasoline dispensing facility (any stationary
facility which dispenses gasoline into the fuel tank of a motor vehicle) located at
an area source of HAPs. The requirements in 40 CFR Part 63 Subpart CCCCCC
apply to any gasoline dispensing facility (GDF) located at this facility and the
relevant requirements are included in the current Title V permit (last revised
August 8, 2012) to address an existing GDF.
Reciprocating Internal Combustion Engines (RICE) (40 CFR Part 63 Subpart
ZZZZ)
Final revisions to the RICE MACT were published in the Federal Register on
March 3, 2010 and these revisions address existing (commenced construction
prior to June 12, 2006) compression ignition engines at area sources. Two
diesel fuel -fired emergency engines (one driving an emergency generator and
one driving a fire pump) are subject to requirements in the RICE MACT and are
included in Section II of the current Title V permit (last revised August 8, 2012).
Revisions were made on January 30, 2013 to the RICE MACT (primarily
changed the requirements for engines greater than 500 hp located at area
sources and the operating requirements for emergency engines).
Page 4
The revisions to the RICE MACT that are applicable to these engines will be
included in the renewal permit.
It should be noted that additional revisions to the requirements in 40 CFR Part 63
Subpart ZZZZ are expected to be made in response to issues related to legal
action associated with the allowable hours of operation provisions for emergency
engines regarding engines used for demand response. If such revisions are
finalized prior to issuance of the permit, they will be included in the permit.
Industrial, Commercial and Institutional Boilers at Area Sources (40 CFR Part 63
Subpart JJJJJJ)
Gas fired boilers are not subject to the requirements in 40 CFR Part 63 Subpart
JJJJJJ in accordance with § 63.11195(e). In addition, unlike the NESHAP for
major sources (40 CFR Part 63 Subpart DDDDD), these requirements only apply
to boilers, not process heaters. The only boiler at this facility is natural gas -fired,
therefore, the requirements in 40 CFR Part 63 Subpart JJJJJJ do not apply.
New Source Performance Standards (NSPS)
EPA has promulgated NSPS requirements for new source categories since the
issuance of the first renewal permit (issued July 1, 2012) for this facility. NSPS
requirements generally only apply to new or modified equipment and the Division
is not aware of any modifications to existing equipment or additions of new
equipment that would render equipment at this facility subject to NSPS
requirements. However, because the recently promulgated NSPS requirements
address equipment that may not be subject to APEN reporting or minor source
construction permit requirements, the applicability of some of the newly
promulgated requirements are being addressed here.
NSPS Subpart JJJJ — Stationary Spark Ignition Engines
NSPS Subpart JJJJ applies to stationary spark ignition engines that commenced
construction, reconstruction or modification after June 12, 2006 and were
manufactured after specified dates. The date the engine commenced
construction is the date the engine was ordered by the owner/operator. There are
no spark ignition engines located at this facility, therefore, the requirements in
Subpart JJJJ do not apply.
NSPS Subpart 1111— Stationary Compression Ignition Engines
NSPS Subpart 1111 applies to stationary compression ignition engines that
commenced construction, reconstruction or modification after July 11, 2005 and
were manufactured after specified dates. The date the engine commenced
construction is the date the engine was ordered by the owner/operator. The only
Page 5
compression ignition engines that are located at this facility are the two engines
driving the emergency generator and the emergency fire pump engine, all of
which commenced operation prior to July 11, 2005 and therefore, the
requirements in Subpart 1111 do not apply.
New and/or Revised Colorado Regulations
The following Colorado Regulations have been revised since the issuance of the
first renewal permit (issued July 1, 2012), thus the applicability of these
requirements is being addressed here
Colorado Regulation No. 7, Sections XII — Requirements for Oil and Gas
Operations in the 8 -hour Ozone Control Area or any Ozone Non -Attainment or
Attainment/Maintenance Areas and Section XVIII - Natural Gas -Actuated
Pneumatic Controllers Associated with Oil and Gas Operations (Statewide)
These requirements do not apply since oil and gas operations do not occur at
this facility.
Colorado Regulation No. 7, Section XVI - Requirements for Engines in the 8 -
Hour Ozone Control Area and Section XVII — Statewide Requirements for Oil and
Gas Operations and Natural Gas -Fired Engines
The requirements in Section XVI were adopted in March 2004 and apply to the 8 -
hour ozone control area. The requirements in Section XVII were first adopted in
December 2006 (last revised February 2014) and apply statewide. The
requirements in Section XVI apply to natural gas fired engines. The requirements
in Section XVII include requirements for storage tanks, leak detection and repair
programs, glycol dehydrators and well operations at oil and gas facilities and
natural gas fired engines.
Requirements for storage tanks, leak detection and repair programs, well
operations and glycol dehydrators at oil and gas facilities
These requirements do not apply since oil and gas operations do not occur at
this facility.
Engine requirements
These requirements do not apply since there are no natural gas -fired engines at
this facility.
Colorado Regulation No. 7 — applicability to 8 -hour ozone nonattainment areas
Revisions to Colorado Regulation No. 7 were adopted by the Colorado Air
Quality Control Commission (AQCC) on December 12, 2008 (effective January
30, 2009) that specified that all provisions in Colorado Regulation No. 7 applied
Page 6
in any ozone nonattainment area, which includes areas designated
nonattainment for either the 1 -hour or 8 -hour ozone standard. Prior to that date,
all provisions of Regulation No. 7 only applied to areas designated as
attainment/maintenance or nonattainment for the 1 -hour ozone standard. Note
that some sections of Regulation No. 7 apply state-wide.
The area in which this facility is located is outside of the 1 -hour ozone
attainment/maintenance area and within the 8 -hour ozone nonattainment area,
thus prior to January 30, 2009, all provisions of Regulation No. 7 did not apply to
this facility.
The applicability of some requirements under Regulation No. 7 were addressed
in the TRD for the first renewal permit (issued July 1, 2012) in that the cold
cleaner solvent vat was included in Section II of the permit because it was
subject to requirements in Colorado Regulation No. 7, Section X.
The TRD did not specifically address the 500 gallon gasoline storage tank and
whether Regulation No. 7 requirements applied to that tank. The requirements in
Regulation No. 7, Section IV.B.3 apply to petroleum liquid storage in tanks
40,000 gallons or less. However, since the storage tank is less than 550 gallons
the tank is exempt from the requirements in Section VI.B.3 as specified in
Section IV.B.3.b.(i).
Repealed APEN Exemptions
Revisions to Regulation No. 3 were adopted by the AQCC in October 2011 to
repeal the APEN exemptions for engines — limited size and hours (Reg 3, Part A,
Section II.D.1.sss) and emergency generators — limited size and hours (Reg 3,
Part A, Section II.D.1.ttt) as EPA would not approve these exemptions. Although
the exemptions were repealed, any engine is exempt from the APEN reporting
requirements if actual, uncontrolled emissions are below the APEN de minimis
level. There is one diesel fuel -fired engine driving an emergency generator and
one diesel fuel -fired engine driving an emergency fire pump included in Section II
of the permit (the fire pump engine is indicated to be APEN exempt based on the
repealed exemption). The source submitted information indicating that actual,
uncontrolled emissions from these engines were below the APEN de minimis
level.
Compliance Assurance Monitoring (CAM) requirements
CAM applies to any emission unit that is subject to an emission limitation, uses a
control device to achieve compliance with that emission limitation and has
potential pre -control emissions greater than major source levels. The current Title
V permit (last revised August 8, 2012) includes CAM requirements for both
turbines with respect to NOx, CO and VOC emissions. There are no other
emission units at the facility that are equipped with control devices.
Page 7
Greenhouse Gases
The potential -to -emit of greenhouse gas (GHG) emissions from this facility is
greater than 100,000 TPY CO2e. Future modifications greater than 75,000 tons
per year CO2e may be subject to regulation (Regulation No. 3, Part A, 1.B.44).
Ill. Discussion of Modifications Made
The following discussion related to modifications is with respect to the current
active permit (last revised August 8, 2012) and unless specifically noted as
"new", the condition numbers identified in this document reflect the condition
numbers in the current permit (last revised August 8, 2012). Because some
permit conditions in the current Title V permit have been removed, reorganized
and/or reformatted as part of this permitting process, the condition numbers
discussed in this document may not reflect the condition numbers in the draft
Title V permit.
Source Requested Modifications
June 27, 2016 Renewal Application
Based on the source's requested changes included in their renewal application,
the following changes were made to the permit:
Page Following Cover Page and Section III (Acid Rain Requirements)
• The Responsible Official and Designated Representative were revised.
Section 11.1 - Turbines
• The results from the latest PM performance test were included in the
summary table and the performance test dates in Conditions 1.2.1 and 1.2.2
were revised.
• Revised Condition 1.5.1.6 to indicate that "combustion tuning and testing"
includes testing and tuning of the selective catalytic reduction (SCR) system.
• The references to "semi-annual" were replaced with "quarterly" in Conditions
1.5.1.7, 1.5.1.8, 1.6.1.7 and 1.6.1.8. In the renewal application, the source
requested that the frequency of excess emission reports be revised from
semi-annual to quarterly.
Section 11.3 — Auxiliary Boiler
• The first two sentences in Condition 3.4.1.2 were removed, since the boiler
was re -started and the performance test was completed.
Page 8
• Condition 3.4.1.2 was revised to include a specific frequency for testing after
the initial test following start-up of the boiler, rather than relying on hours of
operation to determine when/if a subsequent test would be required. The
performance test frequency is annual, with provisions for less frequent testing
depending on the results of the test.
Section 11.6 — CEMS Requirements
• The frequency of reporting In Condition 6.5.1 was changed from semi-annual
to quarterly. In the renewal application, the source requested that the
frequency be increased to be consistent with the Acid Rain reporting
frequency and the frequency with which other PSCo facilities are required to
report excess emissions.
Section 11.8 — Cold Cleaner Solvent Vat
• This section was removed. In the renewal application, the source indicated
that the vat has been decommissioned and removed from the facility (it was
replaced with a unit that uses pressurized water and soap solution, rather
than solvent).
Appendix A — Insignificant Activity List
• The water bath fuel heater was removed from the insignificant activity list.
According to the renewal application, the facility does not have a fuel line
heater (plant steam is used to maintain fuel temperatures).
September 27, 2016 Comments on the Draft Permit and Technical Review
Document
Based on the source's September 27, 2016 comments on the draft permit and
technical review document, the following changes were made to the permit:
Section l— General Activities and Summary
• Added a note to the table in Condition 6.1 indicating that the emergency fire
pump and generator engines are APEN exempt and the date the APEN
cancellation form was submitted.
Appendix A — Insignificant Activity List
• Included the size of the Portable Hotsy pressure washer engine.
• Added a snow blow under the category for "non -road engines" and a weed
trimmer under the category for "site landscaping and housekeeping devices."
Page 9
Other Modifications
In addition to the source requested modifications, the Division has included
changes to make the permit more consistent with recently issued permits, include
comments made by EPA on other Operating Permits, as well as correct errors or
omissions identified during inspections and/or discrepancies identified during
review of this renewal.
The Division has made the following revisions, based on recent internal permit
processing decisions and EPA comments to the Rocky Mountain Energy Center
Renewal Operating Permit. These changes are as follows:
Page Following Cover Page
• The monitoring and compliance periods and report and certification due dates
are shown as examples. The appropriate monitoring and compliance periods
and report and certification due dates will be filled in after permit issuance and
will be based on permit issuance date. Note that the source may request to
keep the same monitoring and compliance periods and report and certification
due dates as were provided in the original permit. However, it should be
noted that with this option, depending on the permit issuance date, the first
monitoring period and compliance period may be short (i.e. less than 6
months and less than 1 year).
Section I — General Activities and Summary
• Condition 1.1 was revised to remove the cold cleaner solvent vat.
• Added a statement to Condition 1.5 indicating that either electronic or hard
copy records are acceptable.
• Revised the reg citations for the definitions of "net emissions increase" and
"significant" in Conditions 3.1 and 3.2. These citations were revised due to
revisions to Reg 3.
• The cold cleaner solvent vat was removed from the table in Condition 6.1.
Section 11.1 - Turbines CT -01 and CT02
• Revised the language in Conditions 1.2.2 and 1.3.2 to state "the average to
three (3) test runs".
• Revised the performance test language in Condition 1.2.2.2 to reflect current
language. In addition, language was added to clarify that testing is for total
(filterable plus condensable) PM and PM10 and removed the specific test
methods (revise to say use appropriate test methods).
Page 10
• Included the NSPS GG NOx limits in Condition 1.5 (these requirements were
previously included in the permit shield for streamlined conditions, Section
IV.3 of the permit). The NSPS GG NOx limit should not have been
streamlined as discussed below.
The source submitted comments during the pre -public comment review
period for the first renewal permit (issued July 1, 2012), requesting that an
alternative BACT limit for periods of combustion tuning and testing be
included in the permit and that limit was set at the level of the start-up BACT
limit (300 ppmvd @ 15% O2, on a 1 -hr average) to be consistent with the
levels set in other permits. The previous version of the permit had included in
NSPS GG limit in the permit shield for streamlined conditions and this was not
changed in the first renewal permit.
The turbine/HRSG/duct burner combinations are typically subject to a
standard BACT NOx limit of 3 ppmvd @ 15% O2, on a 1 -hr average. The
NSPS GG NOx limit is 102 ppmvd @ 15% O2, on a 4 -hour rolling average. So
clearly the standard BACT limit is more stringent than the NSPS GG limit,
based on both the value and the averaging time and as a result the NSPS GG
NOx limit was streamlined from the original permit (included in the permit
shield). Note that as stated in the technical review document for the original
Title V permit (issued July 1, 2007), the Division considers that the NSPS GG
limits do not apply during periods of startup, shutdown and malfunction, thus
streamlining the NSPS GG NOx limit was appropriate in the original permit.
However, during periods of combustion tuning and testing the NSPS GG NOx
limit is more stringent (102 ppmvd vs 300 ppmvd) than the BACT limit,
although the averaging time for the combustion tuning and testing BACT limit
is more stringent (1 hr vs 4 -hr). Since the Division cannot determine that one
NOx limit is more stringent than the other at all times, both the BACT and
NSPS NOx limits are included in the operating permit.
• Minor revisions were made to the monitoring language in Conditions 1.5.1.7,
1.5.1.8, 1.6.1.7 and 1.6.1.8 to clarify that valid CEMS data be used and to
refer to Condition 6.1.1.4.b.
• Added a sentence to conditions 1.5.2 and 1.6.2 indicating that compliance
with the annual limits would be monitored using the GEMS.
• Revised the last sentence in Condition 1.12 (opacity) to reflect that the
turbines are only permitted to burn natural gas as fuel.
Section 11.2 — Diesel Fuel Fired Emergency Engines
The current permit does not appear to reflect the repeal of the APEN exemption
for engines. Based on the manufacturer's emission factors for the engines,
emissions would exceed the APEN de minimis level (1 ton/yr) after 73 hours of
Page 11
operation for the emergency generator and 846 hours of operation for the
emergency fire pump engine. Previous technical review documents for this
facility have indicated that the emergency fire pump engine is APEN exempt and
based on information from APEN submittals and/or inspection reports, the
emergency generator typically operates at levels below the APEN de minimis
level.
The RMEC was subject to the prevention of significant deterioration (PSD)
review requirements when it was initially permitted in 2002. The July 15, 2002
initial approval construction permit (02WE0228) included both the emergency
generator and emergency fire pump engines. The initial approval construction
permit did not include specific BACT limitations for either engine, although BACT
was identified as proper operation and maintenance of the engines, as well as
limited operation.
The requirements in 40 CFR Part 63 Subpart ZZZZ apply to both engines and
impose limitations on the operation of emergency engines, as well as proper
operation and maintenance requirements.
Therefore, since these engines were addressed during the permitting process for
this facility, and emissions are subsequently below the APEN de minimis level,
the Division considers that the APENS for both engines can be cancelled. The
source submitted a cancellation request on [DATE]. The engines will remain in
Section II of the permit since they are subject to requirements in 40 CFR Part 63
Subpart ZZZZ and requirements for the emergency generator will be revised to
more appropriately reflect that it is exempt from the APEN reporting
requirements.
• Minor changes were made to the note under the summary table for the
emergency fire pump engine and a note was added under the summary table
for the emergency generator.
• Removed the Condition 2.1 (calculate NOx and CO emission for emergency
generator).
• Revised Condition 2.2 (hours of operation for the emergency generator) to
trigger emission calculations based on hours of operation.
• Included a requirement to record hours of operation for the emergency fire
pump engine.
• Added language to the opacity monitoring language (Condition 2.4) to
indicate that if an engine is not operated during the year, a Method 9
observation is not required. Also added language indicating that the annual
opacity observations for an engine must be separated by a period of four (4)
months.
Page 12
• The following changes were made to Condition 2.5 (40 CFR Part 63 Subpart
ZZZZ requirements):
o Revised the statement under this condition to indicate more specifically
which version of the requirements have been included in the permit.
o Removed the note indicating that if the Division adopts the March 3, 2010
requirements in Subpart ZZZZ that the engines will be subject to APEN
reporting and minor source construction permit requirements, as the
"catch-all" in Regulation No. 3, Parts A and B has been removed.
o Removed the note regarding proposed revisions published on June 7,
2012 as these revisions were finalized.
o Added a note regarding vacated provisions and potential future proposed
revisions to address those.
o The language was updated to correct the Subpart ZZZZ requirements
(current permit includes requirements for major sources) and include the
revisions for Subpart ZZZZ.
• Condition 2.6 (40 CFR Part 63 Subpart A — general provisions) was removed,
these requirements have been included in Condition 2.5.
Section 11.3 — Auxiliary Boiler
• Based on EPA's response to a petition on another Title V operating permit,
language changes were made to Condition 3.4.1.1 to require that records be
maintained since this condition relies on good engineering practices (GEP)
• Revised the performance test language in Condition 3.4.1.2 to reflect current
language.
• The opacity requirements in Conditions 3.9 through 3.11 were combined into
one condition.
Section 11.4 — Cooling Tower
• Based on EPA's response to a petition on another Title V operating permit,
language changes were made to Condition 4.5 to require that records be
maintained since this condition relies on GEP.
Section 11.6 — Continuous Emission Monitoring Systems (GEMS)
• The reporting requirements in Condition 6.5 (NSPS reporting) was revised to
reflect the language in 40 CFR Part 60 Subpart A § 60.7(c) and (d). Note that
as requested by the source, reports will be required quarterly rather than
semi-annual as noted in 60.7(c).
Section 11.7 — Gasoline Storage Tank
Page 13
• Minor changes were made to the short note directly under the summary table.
• The requirement to record the amount of gasoline dispensed (Condition 7.1)
was removed since 40 CFR Part 63 Subpart CCCCCC requires that records
of gasoline dispensed be maintained.
• The following changes were made to Condition 7.2 (40 CFR Part 63 Subpart
CCCCCC requirements:
o Revised the statement under this condition to indicate more specifically
which version of the requirements have been included in the permit
o Removed the note indicating that if the Division adopts the requirements in
Subpart CCCCCC that the tank will be subject to APEN reporting and
minor source construction permit requirements, as the "catch-all" in
Regulation No. 3, Parts A and B has been removed.
o The Subpart CCCCCC requirements were reorganized somewhat, section
descriptions were added and some new requirements were included,
which included the recordkeeping requirements (63.11125) and the
general provisions (63.11130). Note that since this unit is just subject to
work practice standards, the only general provisions that are considered
to apply are the prohibited activities and circumvention requirements in
63.4.
Section III — Acid Rain Permit
• Revised the table in Section 2 to include calendar years corresponding to the
relevant permit term for the renewal.
• Added the source and date for the standard requirements (Section 111.3).
Section IV — Permit Shield
• The following changes were made to the requirements in the streamlined
conditions (Table in Section IV.3):
o Removed the NSPS GG NOx limits.
o Added the NSPS GG excess emission reporting requirements for sulfur
content of fuel (60.334(j)(2).
o Added the NSPS GG test methods and procedures for fuel sampling
(60.334(i)(1)).
• Corrected the condition numbers listed in the column labeled "permit
condition" in the Table in Section IV.3 (streamlined conditions), as follows:
o Condition 6.5.1 in the second row under "Auxiliary Boiler" was changed to
Condition 6.4.3.
Page 14
o Condition 6.4.3 in the third row under "Auxiliary Boiler" was changed to
Condition 6.5.
o Condition 3.7 in the second to the last row under "Auxiliary Boiler" was
changed to Condition 3.6.
Appendices
• The following changes were made to the insignificant activity list in Appendix
A:
o Language was added to the insignificant activity list in Appendix A to
indicate those insignificant activity categories for which records should be
available to verify insignificant activity status.
o Moved the hotsy pressure washer under a category labeled "non -road
engines" as the pressure washer if powered by an engine.
o Moved the 8,400 gallon condensate tank under a category labeled "not a
source of emissions" since the condensate stored is water condensate.
o The 100 gallon portable diesel tank was listed under the category for tanks
with annual throughput less than 400,000 gal meeting content
specifications, as the previous category (fuel dispensing equipment) is
intended more for gasoline storage tanks. The category for fuel
dispensing equipment was removed.
• The following changes were made to appendices B and C:
o The Reg 3 citation for the Responsible Official on the certifications in
Appendices B and C were revised (the version date was also changed).
o The cold cleaner solvent vat was removed from the tables.
• Revised Appendix D to correct EPA address (compliance notifications) and to
clarify permit mods sent to EPA.
• Cleared the table in Appendix F.
Page 15
Rocky Mountain Energy Center Potential HAP Emissions (tons/yr)
Emission Unit
a)
-o
T
-c
a)
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U
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c
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0
9
a)
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a)
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a)
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v
C
N
To
O
Turbines/
HRSGs'
auxiliary
boiler2
emergency
water pump'
emergency
generator'
cooling
tower4
2.23
1.04E-04
7.98E-06
7.74E-05
0.31
9.28E-05
2.46E-06
2.39E-05
0.22
1.97E-04
4.44E-04
4.30E-03
2.07E-03
0.29
2.32E-04
2.44
4.17E-04
1.17E-04
1.14E-03
4.22
1.51E-04
3.20E-06
3.10E-05
2.71E-02
3.80E-05
3.68E-05
3.57E-04
1.08E-02
1.16E-05
0.89
0.78
1.16
9.04E-04
1.40E-04
1.36E-03
0.43
6.72E-04
4.83E-05
4.68E-04
5.15E-05
5.00E-04
12.11
2.82E-03
8.51E-04
8.26E-03
0.89
Total
2.23
0.31
0.22
2.07E-03
0.29
2.44
4.22
2.75E-02
1.08E-02
0.89
0.78
1.16
0.43
5.52E-04
13.01
'Per application, emission factors from air toxics are from Ventura County APCD and CATEF databases. The formaldehyde emission factors are from the 2004
performance test, emissions are based on the unit with higher emissions burning 8760 and the other for the remainder of the time.
2Per application, HAP emission factors from Ventura county APCD
'Per application, HAP emission factors from CATEF (diesel engines < 13 % O2) and Ventura county APCD (metals), based on 500 hrs/yr for both the fires pump
and emergency generator (per September 6, 1995 EPA Memo, "Calculating Potential to Emit (PTE) for Emergency Generators"). Although the Sept 1995 memo
addresses emergency generators only, the Division considers the memo is appropriate to use for emergency fire pump engines.
°chloroform emission factor from "Locating and Estimating Air Emissions from Sources of Chloroform", EPA -450/4-84-007c, March 1984 for re -circulating units
Page 16
COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT
AIR POLLUTION CONTROL DIVISION
OPERATING PERMIT RENEWAL SUMMARY
PERMIT NUMBER: 05OPWE279
AIRS ID #: 1231342 DATE: September 30, 2016
APPLICANT: Public Service Company of Colorado — Rocky Mountain Energy Center
REVIEW ENGINEER: Jacqueline Joyce
SOURCE DESCRIPTION
Public Service Company of Colorado has applied for renewal of their Operating Permit issued for the Rocky Mountain
Energy Center located at 6211 Weld County Road 51 in Keenesburg, Colorado in Weld County. This facility consists of
two combustion turbines, each equipped with a heat recovery steam generator (HRSG) and duct burner used to generate
electricity and is classified under SIC 4911. Natural gas is the only fuel used in these turbines and duct burners. There is
also a natural gas -fire auxiliary boiler, a cooling tower and two diesel fuel -fired emergency engines included in Section II of
the permit. This facility is located in an area classified as attainment for all pollutants except ozone. It is classified as non -
attainment for ozone and is part of the 8 -hr Ozone Control Area as defined in Regulation No. 7, Section II.A.1. There are
no affected states within 50 miles of this facility. Rocky Mountain National Park, a Federal Class I designated area, is
within 100 km of this facility. This source is subject to the Accidental Release provisions of section 112(r) of the Federal
Clean Air Act. The turbines are subject to the compliance assurance monitoring (CAM) requirements in 40 CFR Part 64
with respect to NON, CO and VOC emissions.
FACILITY EMISSION SUMMARY
Potential To Emit
Emission Unit
PM
PM10
SO2
NON
CO
VOC
HAPS
Turbines/HRSGs
126.8
126.8
11.8
240.4
782.2
50.6
12.11
Aux. Boiler'
2.28
2.28
0.07
4.7
4.75
0.64
2.82E-03
Emergency
Generator
0.40
0.40
0.16
6.88
8.48
1.00
8.51E-04
Fire Water Pump3
0.02
0.02
0.02
0.60
0.36
0.07
8.26E-03
Cooling Tower4
19.3
19.3
0.89
0.89
Total
148.8
148.8
12.06
252.58
795.79
53.20
13.01
SO2 and VOC emissions are based on the permitted fuel limit and AP -42 emissions factors (Section 1.4, dated 3/98, Table 1.4-2).
2Emissions based on 500 hours/year of operation (per September 6, 1995 EPA Memo, 'Calculating Potential to Emit (PTE) for
Emergency Generators"), maximum hp and for all but SO2 manufacturer's emission factors, SO2 based on sulfur content of 0.05 wt
fuel density 7.05 lb/gal).
Emissions based on 500 hours/year of operation, maximum hp and for all but SO2 manufacturer's emission factors, SO2 based on
sulfur content of 0.05 wt % (fuel density 7.05 lb/gal). 500 hours per year of operation was used in accordance with EPA's September
6, 1995 memo. Although that memo addresses emergency generators only, the Division considers the memo is appropriate to use for
emergency fire pump engines.
4VOC emissions are based on the permitted water circulation rate and the emission factor from "Locating and Estimating Air Emissions
from Sources of Chloroform", EPA-450/4-84-007c,March 1984, for re -circulating units. All VOC is chloroform.
Actual emissions are as follows:
Emission Unit
Data Year'
PM
PM10/PM2.5
SO2
NON
CO
VOC
HAPS
CT -01
2015
13.2
13.2
2.3
34.4
132
2.7
3.04
CT -02
2015
17.4
17.4
2.3
87
96.7
0.6
3.15
Emerg. Gen
2014
0.33
0.09
Aux Blr
2013
Cooling Twr
2013
6.3
6.3
0.20
Total
36.9
36.9
4.6
121.73
228.7
3.59
6.19
'Actual emissions from data year 2015 based on APENs submitted on 4/27/16. Actual emissions from data year 2014 based on
APENs submitted 4/29/15. Actual emissions from data year 2013 based on APENs submitted on April 29, 2014.
EMISSION SOURCES
The following discussion identifies the more significant changes that were made in the renewal permit. Other minor
language changes were made to other permit conditions.
Turbines, HRSGs and Duct Burners (Section 11.1) — The definition of combustion tuning and testing was revised to include
testing and tuning of the selective catalytic reduction (SCR). The NSPS GG NOx limits were included (they were previously
stream -lined) since they are more stringent than the alternate NOx BACT limit for combustion tuning and testing.
Emergency Fire Pump Engine (Section 11.2) — The requirements in 40 CFR Part 63 Subpart ZZZZ were revised to reflect
updates to the regulation and correct the requirements. Language changes were made to indicate which version of the
Subpart ZZZZ requirements are included and the notes regarding potential APEN and permitting requirements and
proposed revisions to Subpart ZZZZ were removed. The requirement to calculate NOx and CO emissions from the diesel
generator was removed and a requirement was added to record hours of operation for the emergency fire pump engine.
Auxiliary Boiler (Section 11.3) — The performance test requirement for CO was revised to include a specific frequency of
testing rather than relying on hours of operation to determine if/when a test is required. Added language to Condition
3.4.1.1 to require that records of good engineering practices (GEP) be kept since the condition relies on GEP.
Cooling Tower (Section 11.4) - Language was added to Condition 4.5 to keep records of GEP since the condition relies on
GEP.
Continuous emission Monitoring System (Section 11.6) — The frequency of submittal of excess emission reports was
changed from semi-annually to quarterly.
Gasoline Storage Tank (Section 11.7) — The requirement to record the amount of gasoline dispensed was removed. The 40
CFR Part 63 Subpart CCCCCC requirements were revised to reflect revisions to the regulation.
Cold Cleaner Solvent Vat (Section 11.8) — This section was removed since the vat has been decommissioned and removed
from the facility.
Permit Shield (Section III) — Removed the NSPS GG NOx requirements from the table in Section 111.3 (streamlined
conditions).
Appendix A — insignificant activity list - Language was added to indicate those insignificant activity categories for which
records should be available to verify insignificant activity status. In addition, some activities have been added, removed,
moved to different categores or the descriptions revised
COLORADO
Department of Public
Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
September 29, 2016
Mr. Josh Korth
Environmental Services
Xcel Energy
1800 Larimer Street
Suited 1300
Denver, CO 80202
REF: Public Service Company of Colorado - Rocky Mountain Energy Center, FID
# 1231342, OP # 05OPWE279
SUBJECT: Response to Comments on Draft Operating Permit
Dear Mr. Korth:
The comments you provided on the draft renewal Operating Permit (05OPWE279) and
Technical Review Document for your facility were received on September 27, 2016,
via email. The Division has reviewed and addressed your comments as follows:
Comment 1: On Page 11, Conditions 1.5.1.6 abbreviates the control device as SNCR
when it should be SCR.
Response: The change will be made as requested.
Comment 2:
Response:
Comment 3:
Response:
There is a snow blower at the plant that should be listed in the
insignificant activities under non -road engines as well. It has a gasoline
engine rated at 11.0 hp.
The snow blower, will be added to the insignificant activity list in
Appendix A of the permit.
There is a weed trimmer at the facility that should be listed in the
insignificant activities list under landscaping and site housekeeping
devices < 10 hp.
The weed trimmer will be added to the insignificant activity list in
Appendix A of the permit.,
4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe
John W. Hickenlooper, Governor Larry Wolk, MD, ,MSPH, Executive Director and Chief Medical Officer
Mr. Josh Korth, Xcel Energy September 29, 2016
Response to Comments on Draft Permit Page 2
In addition, thank you for providing responses to the seven questions noted in the
transmittal letter. Except for the following, no changes to the technical review
document or permit were necessary based on the response to these questions:
• Based on the response to question 3 and submittal of cancellation notices for
the two diesel -fired emergency engines, the technical review document was
revised to indicate the submittal date of the cancellation notices and Section I,
Condition 6.1 of the permit was revised to indicate that the APENs were
cancelled for the engines.
• Based on the response to question 5, the size of the hotsy pressure washer
engine was noted in the insignificant activity list.
The next step for this draft renewal permit will be to put it out for a 30 -day Public
Comment period. After that, the proposed permit will go to EPA Region VIM for a 45 -
day review period. The regulations also require that the applicant receive written
notice of their right to a formal hearing before the Air Quality Control Commission at
the same time that the Public Comment packet goes out. You will receive a separate
letter containing that information.
We appreciate that you took the time to thoroughly review this draft. Please feel
free to contact me at (303) 692-3267 or jackie.joyce®state.co.us if you have any
further questions.
Sincerely,
Jacqueline Joyce
Operating Permit Unit
Stationary Sources Program
Air Pollution Control Division
Xcel Energy=
Environmental Services Department
1800 Larimer Street, Suite 1300
Denver, CO 80202
September 27, 2016
Ms. Jacqueline Joyce
Colorado Department of Public Health & Environment
Air Pollution Control Division, APCD-SS-B1
Operating Permit Unit
4300 Cherry Creek Drive South
Denver, CO 80246-1530
RE: Rocky Mountain Energy Center
Operating Permit No. 05OPWE279
Draft Permit Renewal Comments
Dear Ms. Joyce:
We have reviewed the draft permit and don't have any significant comments. It appears that all of
our requested modifications from the renewal application were made.
We did find a couple of minor items that I would like to provide comments on:
1. On page 11, Condition 1.5.1.6 abbreviates the control device as SNCR when it should be
SCR.
2. There is a snow blower at the plant that should be listed in the insignificant activities
under non -road engines as well. It has a gasoline engine rated at 11.0 hp.
3. There is a weed trimmer at the facility that should be listed in the insignificant activities
list under landscaping and site housekeeping devices < 10 hp.
In the transmittal letter, a number of questions and/or verification items were asked and
responses to those items are as follows:
1. Have any additional stationary internal combustion engines been installed at
the facility that are not already identified in the Title V permit? If so, please
indicate the dates each engine was manufactured, relocated into Colorado,
commenced construction and commenced operation. In addition, if applicable,
please provide the manufacturer, model and serial number, and design rating
(hp and fuel consumption) for the engine(s). No new stationary engines
have been installed at the RMEC facility.
2. Please confirm that actual, uncontrolled emissions from the emergency fire
pump and emergency generator engine are below the APEN de minimis level
(1 ton/yr of NOX and 2 tons/year of CO).
ROCKY
MOUNTAIN ENERGY
CENTER
Emergency
Generator
(S005)
TSF
0.01
2015 Emissions
PM -10
0.01
PM -2.5
0.01
SOx
0.05
NOx
0.33
VOC
0.01
CO
0.09
ROCKY
MOUNTAIN ENERGY
CENTER
Emergency
Fire Pump
Engine
(M003)
TSP
0.01
2015 Emissions
PM -10
0.01
PM -2.5
0.01
SOx
0.01
NOx
0.08
VOC
0.00
CO
0.02
tons
tons
tons
tons
tons
tons
tons
tons
tons
tons
tons
tons
tons
tons
3. As long as emissions from both the emergency fire pump and emergency generator
are below the APEN de minimis level (1 ton/yr of NOX and 2 tons/year of CO), the
APENs for these engines may be cancelled. Therefore, if you would like to cancel the
APENs, please submit an APEN cancellation form. APEN Cancellation forms are
attached with this letter.
4. Please verify that the gasoline storage tank is a 500 gallon tank. Yes, this is correct.
5. There is a portable hotsy pressure washer listed in the current Title V permit. Is this
pressure washer powered by an engine? If so, please indicate whether the engine
qualifies as a non -road engine (see Colorado Regulation No. 3, Part A, Section
I.B.31) and what size (hp) the engine is. The hotsy is powered with a gasoline
non -road engine, rated at 11.5 hp.
6. There is a 8,400 gallon gas condensate tank listed in the current Title V permit.
Does this tank store water condensate or hydrocarbon condensate (as defined in
Colorado's Common Provisions Regulation, Section I.G)? Water Condensate
7. The renewal application indicates that the facility does not have a gas fired fuel
heater, as plant steam is used to maintain fuel temperatures. Since the auxiliary
boiler is not operated much and did not operate for many years, how is/was fuel
temperature maintained during startup of the turbines? Electric heaters are used
during CT startup uni H RSC steam temperatures are adequate to control fuel
line temperature.
If you have any questions please call me at 303-294-2187 or joshua.r.korth@xcelenergy.com.
Sincerely,
Josh Korth
Environmental Services
Xcel Energy
Att: APEN Cancellation Forms (2)
cc: RMEC Electronic Files
Colorado Air Pollution Control Division
EMISSION PERMIT/APEN CANCELLATION REQUEST
Permit Number 02WE0228
Colorado Department
of Public Health
and Environment
and/or AIRS ID: 1231342005
Source or Equipment Name: Emergency Generator Engine
Rocky Mountain Energy Center,6211 Weld County Rd 51
Source or Equipment Address: xeenesburq, CO 80643
This cancellation request is based on the following: Please circle the appropriate item,
1. The facility and/or source addressed by the permit or APEN no longer exists.
2. The facility has been sold to another party and I do not wish to transfer the permit.
New owners name:
New owners address:
New owners phone number:
3. The emissions from the permitted source no longer is above the threshold required for
maintaining an APEN or permit with the Division and the source does not want to maintain an
active APEN or permit with the Division.
4. Other:
Date Equipment or Operations Ceased/Sold or Below Reporting Thresholds: 12 / 31 / 2015
Company Name: Public Service Company of ColoradoPhone Number: 303 .294. 2177
Company Address: 1800 Larimer Street, Suite 1300
City: Denver
Sit of Legal/ Authorized rson
Gary Magno
Print Name
State: CO Zip: 80202
/z?/
Date
Manager Air Quality Compliance
Title
Colorado Air Pollution Control Division
EMISSION PERMIT/APEN CANCELLATION REQUEST
Permit Number 02WE0228
Colorado Department
of Public Health
and Environment
and/or AIRS ID: 1231342003
Source or Equipment Name: Emergency Fire Pump Engine
Rocky Mountain Energy Center,6211 Weld County Rd 51
Source or Equipment Address: Keenesburq, Co 80643
This cancellation request is based on the following: Please circle the appropriate item.
1. The facility and/or source addressed by the permit or APEN no longer exists.
2. The facility has been sold to another party and I do not wish to transfer the permit.
New owners name:
New owners address:
New owners phone number:
3. The emissions from the permitted source no longer is above the threshold required for
maintaining an APEN or permit with the, Division and the source does not want to maintain an
active APEN or permit with the; Division.
4. Other:
Date Equipment or Operations Ceased/Sold or Below Reporting Thresholds: 12 / 31 /2015
Company Name: Public Service Company of ColoradoPhone Number: 303 .294 .2177
Company Address: 1800 Larimer Street, Suite 1300
City: Denver
Signature Legally
Gary Magno
Print Name
For Department Use Only
Version May, 18, 201.1
uthorized Perso
State: CO Zip: 80202
7
/ _
Date
Manager - Air Quality Compliance
Title
] Administration Scanned
] Invehtory -
] Administration Filed;,
COLORADO
Department of Pubtie
Health & Environment
Dedicated to protecting and improving the health and environment of the people of Colorado
August 26, 2016
Mr. Josh Korth
Environmental Services
Xcel Energy
1800 Larimer Street
Suite 1300
Denver, CO 80202
SUBJECT: Draft Renewal Operating Permit for Public Service Company of Colorado
— Rocky Mountain Energy Center
Dear Mr. Korth:
Enclosed please find a draft of the renewal operating permit for your facility as well as a
copy of the technical review summary document. Please review and submit any
comments you may have concerning the modified draft operating permit. Following our
review of your comments, we will send the draft permit out for a 30 -day Public Comment
period and then to EPA for their 45 -day review period. The regulations also require that
the applicant receive written notice of their right to a formal hearing before the Colorado
Air Quality Control Commission at the same time that the Public Comment packet goes
out. You will receive a separate letter containing that information.
This draft renewal permit contains the modifications that you requested in your renewal
application received on June 27, 2016. The permit was also revised to be more
consistent with recently issued permits, correct errors, omissions and discrepancies
identified during inspections and/or review of the renewal application and incorporate
EPA comments made on other operating permits for similar sources. The changes are
summarized in the technical review document for the renewal permit.
While you are reviewing this permit, please be aware of the following:
Have any additional stationary internal combustion engines been installed at the
facility that are not already identified in the Title V permit? If so, please indicate
the dates each engine was manufactured, relocated into Colorado, commenced
construction and commenced operation. In addition, if applicable, please provide
the manufacturer, model and serial number, and design rating (hp and fuel
consumption) for the engine(s).
2. Please confirm that actual, uncontrolled emissions from the emergency fire pump
and emergency generator engine are below the APEN de minimis level (1 ton/yr
of NOx and 2 tons/year of CO).
4300 Cherry Creek Drive S.. Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe
John W. Hickenlooper, Governor Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer
Mr. Josh Korth, Xcel Energy August 26, 2016
Draft Renewal Permit for Rocky Mountain Energy Center Page 2
3. As long as emissions from both the emergency fire pump and emergency
generator are below the APEN de minimis level (1 ton/yr of NOx and 2 tons/year
of CO), the APENs for these engines may be cancelled. Therefore, if you would
like to cancel the APENs, please submit an APEN cancellation form.
4. Please verify that the gasoline storage tank is a 500 gallon tank.
5. There is a portable hotsy pressure washer listed in the current Title V permit. Is
this pressure washer powered by an engine? If so, please indicate whether the
engine qualifies as a non -road engine (see Colorado Regulation No. 3, Part A,
Section I.B.31) and what size (hp) the engine is.
6. There is a 8,400 gallon gas condensate tank listed in the current Title V permit.
Does this tank store water condensate or hydrocarbon condensate (as defined in
Colorado's Common Provisions Regulation, Section I.G)?
7. The renewal application indicates that the facility does not have a gas fired fuel
heater, as plant steam is used to maintain fuel temperatures. Since the auxiliary
boiler is not operated much and did not operate for many years, how is/was fuel
temperature maintained during startup of the turbines?
We would like you to review this permit and respond to the items identified above by
September 27, 2016. Feel free to give me a call at (303) 692-3267 if you have any
questions or concerns.
Sincerely,
Jacqueline Joyce,
Permit Engineer
Operating Permit Unit
Stationary Sources Program
Air Pollution Control Division
Enclosures
Xcel Energy -
Environmental Services
1800 Larimer Street, Suite 1300
Denver, CO 80202
June 27, 2016
Ms. Jacqueline Joyce
Colorado Department of Public Health & Environment
Air Pollution Control Division, APCD-SS-B1
Operating Permit Unit
4300 Cherry Creek Drive South
Denver, CO 80246-1530
Re: Rocky Mountain Energy Center
Permit #05OPWE279
Title V Operating Permit Renewal Application
Dear Ms. Joyce:
In accordance with the requirements of Colorado Air Quality Control Commission Regulation
No. 3, Part C, Section III.B.6, Public Service Company of Colorado (PSCo) is hereby submitting
a renewal application for the PSCo Rocky Mountain Energy Center Title V Operating Permit
#05OPWE279. This submittal package includes:
• This cover letter signed by the Company's Responsible Official which contains,
• Identification of the facility's status for Greenhouse Gas (GHG) emissions
• Applicability confirmation of the Federal Compliance Assurance Monitoring
(CAM) provisions, and
■ Summary of changes being requested during this renewal process
• Attachment of the required Colorado operating permit application forms (Forms 2000-
100 and 2000-800)
• Attachment of the Acid Rain Program Permit Application
Greenhouse Gas Status Assessment
An evaluation of the emission sources at the Rocky Mountain Energy Center facility was done to
assess the Potential to Emit (PTE) for GHG emissions. Based on the analysis, Rocky Mountain
Energy Center is major for GHG emissions. The evaluation was based on Acid Rain Program
data and calculations according to the requirements of Title 40 Part 98 Subpart C and D.
Compliance Assurance Monitoring Review
Each emission source at the Rocky Mountain Energy Center facility was evaluated for CAM
applicability as part of the May 10, 2011 permit renewal application. The evaluation during that
renewal process determined that the two combustion turbines at the facility were subject to CAM
requirements for NOx, CO, and VOC. No new sources or additional control devices have been
installed since the 2011 application was submitted so the determination from that evaluation
remains appropriate.
Requested Changes
No changes are being requested for the operating permit except as identified below or attached.
PSCo requests that an additional sentence be added at the end of Section II, Condition 1.5.1.6.
The additional sentence should read, "Testing and tuning of the Selective Catalytic Reduction
(SCR) system shall also be allowed under this condition and the hours included in the annual
total."
PSCo requests that results from the 2015 particulate matter compliance tests be included in
Section II, Summary Table and Conditions 1.2.1 and 1.2.2.2. Testing results for each of the
stacks are as follows:
Unit 1: 10/6/2015 - PM = 0.002, PM 10 = 0.002
Unit2: 10/7/2015-PM=0.001,PM10=0.001
PSCo is requesting that the first paragraph of Section II, Condition 3.4.1.2 be removed from the
permit during this renewal process. The Aux Boiler was recommissioned in 2015 and completed
the required compliance test within the specified time period. A subsequent test was performed
on 5/24/2016 based on the unit operating 1200 hours combined between 2015 and early 2016.
PSCo is requesting that a new paragraph be added to Section II, Condition 3.4.1.2 with the
following language. The annual compliance test would typically be performed concurrently with
the annual NOx RATA, unless test results allowed for a longer duration between tests.
Stack testing for carbon monoxide shall be performed annually (calendar year), except that:
(1) if any test result indicates emissions are less than or equal to 50% of the emission limit,
the next subsequent test is required within five years; (2) if any test results indicate emissions
are more than 50%, but less than or equal to 75% of the emission limit, the next subsequent
test is required within three years; and (3) if any test results indicate emissions are greater
than 75% of the emission limit, an annual test is required until the provisions of (1) or (2) are
met. Test results shall be converted to the applicable units of the permit limit and
compliance will be based on the average of the three test runs.
PSCo is requesting that source M001, Cold Cleaner Solvent Vat be removed from the peiinit.
The source has been decommissioned and removed from the facility. It was replaced with a unit
that uses pressurized water and soap solution rather than solvent and has no VOC emissions.
PSCo is requesting that the reporting frequency specified in Section II, Condition 6.5.1 be
quarterly rather than semi-annually. This is consistent with the frequency that reports are
submitted for the Acid Rain Program and the frequency that PSCo submits Excess Emissions
Reports to the CDPHE for our other generating facilities.
PSCo is requesting that the water bath fuel heater be removed from the insignificant activities
list. This facility does not have a gas fired fuel line heater and uses plant steam to maintain fuel
temperatures.
PSCo is requesting an update to the Responsible Official listed for this facility. This change in
information has been reflected on Form 2000-100 that is included with this submittal. The same
update should also be made in Section III for the Designated Representative.
Responsible Official
Name: Mark Fox
Title: General Manager — Power Generation, Colorado
Phone: (303) 425-3779
If you have any questions concerning the attached permit application forms or information
provided, please contact Josh Korth of PSCo's Environmental Services staff, at
joshua.r.korth@xcelenergy.com or (303) 294-2187.
Sincerely,
Mark Fox
General Manager — Power Generation, Colorado
att: As Stated
cc: D. Robb — Director, Rocky Mountain Energy Center
D. Rains — Environmental Analyst, Rocky Mountain Energy Center Station
G. Magno — Manager, Air Quality Compliance
RMEC Electronic Files
Operating Permit Application FACILITY IDENTIFICATION
Colorado Department of Public Health and Environment
Air Pollution Control Division
SEE INSTRUCTIONS ON REVERSE SIDE
FORM 2000-100
Rev 06-95
1. Facility name and Name Rocky Mountain Energy Center
mailing address
Street or Route 6211 Weld County Road Si
City, State, Zip Code Keenesburg, CO 80643
2.
Facility location Street Address
(No P.O. Box) City, County, Zip Code
6211 Weld County Road 51
Keenesburg, CO 80643
3. Parent corporation Name
Street or Route
City, State, Zip Code
Country (if not U.S.)
Public Service Company of Colorado
1800 Larimer Street
Denver, CO 80802
4. Responsible
official
Name
Title
Telephone
Mark Fox
General Manager — Power Generation, Colorado
(303) 425-3779
5. Pet mit contact person Name
Title
(If Different than 4) Telephone
Gary Magno
Manager, Air Quality Compliance
(303) 294-2177
6. Facility SIC code: 4911
7. Facility identification code: CO 1231342
8. Federal Tax I. D. Number: 84-6015506
9. Primary activity of the operating establishment: Natural Gas -Fired Electric Generating Station
10. Type of operating per uit O New
O Modified ❑x Renewal
11. Is the facility located in a "nonattainment" area: (] Yes ❑No
If "Yes", check the designated "non -attainment" pollutant(s):
O Carbon Monoxide ❑x Ozone O PM10 O Other (specify)
12. List all (Federal and State) air pollution petmits (including grandfathered units), plan approvals and exemptions issued to
this facility. List the number, date and what unit/process is covered by each permit. For a Modified Operating Permit, do not
complete this item.
Operating Permit Application
Colorado Department of Health
Air Pollution Control Division
Facility Name: Rocky Mountain Energy Center
I. ADMINISTRATION
TABULATION OF PERMIT APPLICATION FORMS
09-94
Facility Identification Code: CO 1231342
FORM 2000-800
This application contains the following forms:
Li
Form 2000-100, Facility Identification
❑
Form 2000-101, Facility Plot Plan
0
Forms 2000-102, -102A, and -102B, Source and Site Descriptions
II. EMISSIONS SOURCE
DESCRIPTION
Total Number
of This Form
This application contains the following forms
(one form for each facility boiler. nrintine
0
Form 2000-200, Stack Identification
❑
Form 2000-300, Boiler or Furnace Operation
❑
Form 2000-301, Storage Tanks
❑
Form 2000-302, Intemal Combustion Engine
❑
Form 2000-303, Incineration
❑
Form 2000-304, Printing Operations
❑
Form 2000-305, Painting and Coating Operations
❑
Form 2000-306, Miscellaneous Processes
0
Form 2000-307, Glycol Dehydration Unit
III. AIR POLLUTION CONTROL
SYSTEM
Total Number
of This Form
This application contains the following forms:
0
Form 2000-400, Miscellaneous
❑
Form 2000-401, Condensers
❑
Form 2000-402, Adsorbers
❑
Form 2000-403, Catalytic or Thermal Oxidation
❑
Form 2000-404, Cyclones/Settling Chambers
❑
Form 2000-405, Electrostatic Precipitators
❑
Form 2000-406, Wet Collection Systems
❑
Form 2000-407, Baghouses/Fabric Filters
IV. COMPLIANCE
DEMONSTRATION
Total Number
of This Form
This application contains the following forms
(one for each facility boiler. Printing operation.
0
Form 2000-500, Compliance Certification - Monitoring and Reporting
❑
Form 2000-501, Continuous Emission Monitoring
❑
Form 2000-502, Periodic Emission Monitoring Using Portable Monitors
❑
Form 2000-503, Control System Parameters or Operation Parameters of a Process
❑
Form 2000-504, Monitoring Maintenance Procedures
❑
Form 2000-505, Stack Testing
❑
Form 2000-506, Fuel Sampling and Analysis
❑
Form 2000-507, Recordkceping
0
Form 2000-508, Other Methods
2
V. EMISSION SUMMARY AND
COMPLIANCE CERTIFICATION
Total Number
of This Form
This application contains the following forms
quantifying emissions, certifying compliance
with applicable requirements, and developing a
compliance plan
❑ Form 2000-600, Emission Unit Hazardous Air Pollutants
❑ Form 2000-601, Emission Unit Criteria Air Pollutants
❑ Form 2000-602, Facility Hazardous Air Pollutants
❑ Form 2000-603, Facility Criteria Air Pollutants
❑ Form 2000-604, Applicable Requirements and Status of Emission Unit
❑ Form 2000-605, Permit Shield Protection Identification
❑ Form 2000-606, Emission Unit Compliance Plan - Commitments and Schedule
❑ Form 2000-607, Plant -Wide Applicable Requirements
❑ Form 2000-608, Plant -Wide Compliance Plan - Commitments and Schedule
VI. SIGNATURE OF RESPONSIBLE OFFICIAL - FEDERAL/STATE CONDITIONS
A. STATEMENT OF COMPLETENESS
I have reviewed this application in its entirety and, based on information and belief
the statements and information contained in this application are true, accurate and
B. CERTIFICATION OF FACILITY COMPLIANCE STATUS - FEDERAL/STATE
0 Icertify that the facility described in this air pollution permit application
requirements.
O I certify that the facility described in this air pollution permit application
requirements, except for the following emissions unit(s):
formed after reasonable inquiry, I certify that
complete.
CONDITIONS (check one box only)
is fully in compliance with all applicable
is fully in compliance with all applicable
any false material statement, representation,
misdemeanor and may be punished in
(list all non -complying units)
WARNING: Any person who knowingly, as defined in § 18-1-501(6), C.R.S., makes
or certification in, or omits material information from this application is guilty of a
accordance with the provisions of § 25-7 122.1, C.R.S.
Printed or Typed Name
Mark Fox
Title
General Manager — Power Generation, Colorado
Signature ,.-
Date Signed
3
Operating Permit Application
Colorado Department of Health
Air Pollution Control Division
CERTIFICATION FOR STATE -ONLY CONDITIONS FORM 2000-800
09-94
Facility Name: Rocky Mountain Energy Center
Facility Identification Code: CO 1231342
VI. SIGNATURE OF RESPONSIBLE OFFICIAL - STATE ONLY CONDITIONS
A. STATEMENT OF COMPLETENESS
I have reviewed this application in its entirety and, based on information and belief
the statements and infoituation contained in this application are true, accurate and
B. CERTIFICATION OF FACILITY COMPLIANCE STATUS FOR STATE -ONLY
❑x I certify that the facility described in this air pollution permit application
requirements.
O I certify that the facility described in this air pollution permit application
requirements, except for the following emissions unit(s):
formed after reasonable inquiry, I certify that
complete.
CONDITIONS (check one box only)
is fully in compliance with all applicable
is fully in compliance with all applicable
any false material statement, representation,
misdemeanor and may be punished in
(list all non -complying units)
WARNING: Any person who knowingly, as defined in § 18-1-501(6), C.R.S., makes
or certification in, or omits material information from this application is guilty of a
accordance with the provisions of § 25-7 122.1, C.R.S.
Printed or Typed Name
Mark Fox
Title
General Manager — Power Generation, Colorado
Signature
Date Signed
—i
SEND ALL MATERIALS TO:
COLORADO DEPARTMENT OF HEALTH
APCD-SS-B 1
4300 CHERRY CREEK DRIVE SOUTH
DENVER, CO 80246-1530
4
6EPA Acid Rain Permit Application
United States
Environmental Protection Agency
Acid Rain Program
OMB No. 2060-0258
STEP 1
Identify the facility name,
State, and plant (ORIS)
code.
STEP 2
Enter the unit ID#
for every affected
unit at the affected
source in column "a."
EPA Form 7610-16 (rev. 07-08)
For more information, see instructions and 40 CFR 72.30 and 72.31.
This submission is: • flew • evised • )or Acid Rain permit renewal
Rocky Mountain
Energy
Center
CO
55835
Facility (Source) Name
State
Plant Code
a
b
Unit ID#
Unit Will Hold Allowances
in Accordance with 40 CFR 72.9(c)(1)
1
Yes
2
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Rocky Mountain Energy Center
Acid Rain - Page 2
STEP 3
Read the standard
requirements.
Facility (Source) Name (from STEP 1)
Permit Requirements
(1) The designated representative of each affected source and each affected
unit at the source shall:
(i) Submit a complete Acid Rain permit application (including a compliance
plan) under 40 CFR part 72 in accordance with the deadlines specified in
40 CFR 72.30; and
(ii) Submit in a timely manner any supplemental information that the
permitting authority determines is necessary in order to review an Acid Rain
permit application and issue or deny an Acid Rain permit;
(2) The owners and operators of each affected source and each affected unit
at the source shall:
(i) Operate the unit in compliance with a complete Acid Rain permit
application or a superseding Acid Rain permit issued by the permitting
authority; and
(ii) Have an Acid Rain Permit.
Monitoring Requirements
(1) The owners and operators and, to the extent applicable, designated
representative of each affected source and each affected unit at the source
shall comply with the monitoring requirements as provided in 40 CFR part 75.
(2) The emissions measurements recorded and reported in accordance with
40 CFR part 75 shall be used to determine compliance by the source or unit,
as appropriate, with the Acid Rain emissions limitations and emissions
reduction requirements for sulfur dioxide and nitrogen oxides under the Acid
Rain Program.
(3) The requirements of 40 CFR part 75 shall not affect the responsibility of
the owners and operators to monitor emissions of other pollutants or other
emissions characteristics at the unit under other applicable requirements of
the Act and other provisions of the operating permit for the source.
Sulfur Dioxide Requirements
(1) The owners and operators of each source and each affected unit at the
source shall:
(i) Hold allowances, as of the allowance transfer deadline, in the source's
compliance account (after deductions under 40 CFR 73.34(c)), not less
than the total annual emissions of sulfur dioxide for the previous calendar
year from the affected units at the source; and
(ii) Comply with the applicable Acid Rain emissions limitations for sulfur
dioxide.
(2) Each ton of sulfur dioxide emitted in excess of the Acid Rain emissions
limitations for sulfur dioxide shall constitute a separate violation of the Act.
(3) An affected unit shall be subject to the requirements under paragraph (1)
of the sulfur dioxide requirements as follows:
(i) Starting January 1, 2000, an affected unit under 40 CFR 72.6(a)(2); or
(ii) Starting on the later of January 1, 2000 or the deadline for monitor
certification under 40 CFR part 75, an affected unit under 40 CFR
72.6(a)(3).
EPA Form 7610-16 (rev. 07-08)
STEP 3, Cont'd.
Rocky Mountain Energy Center
Facility (Source) Name (from STEP 1)
Sulfur Dioxide Requirements, Cont'd.
Acid Rain - Page 3
(4) Allowances shall be held in, deducted from, or transferred among
Allowance Tracking System accounts in accordance with the Acid Rain
Program.
(5) An allowance shall not be deducted in order to comply with the
requirements under paragraph (1) of the sulfur dioxide requirements prior to
the calendar year for which the allowance was allocated.
(6) An allowance allocated by the Administrator under the Acid Rain Program
is a limited authorization to emit sulfur dioxide in accordance with the Acid
Rain Program. No provision of the Acid Rain Program, the Acid Rain permit
application, the Acid Rain permit, or an exemption under 40 CFR 72.7 or 72.8
and no provision of law shall be construed to limit the authority of the United
States to terminate or limit such authorization.
(7) An allowance allocated by the Administrator under the Acid Rain Program
does not constitute a property right.
Nitrogen Oxides Requirements
The owners and operators of the source and each affected unit at the source
shall comply with the applicable Acid Rain emissions limitation for nitrogen
oxides.
Excess Emissions Requirements
(1) The designated representative of an affected source that has excess
emissions in any calendar year shall submit a proposed offset plan, as
required under 40 CFR part 77.
(2) The owners and operators of an affected source that has excess emissions
in any calendar year shall:
(i) Pay without demand the penalty required, and pay upon demand the
interest on that penalty, as required by 40 CFR part 77; and
(ii) Comply with the terms of an approved offset plan, as required by 40
CFR part 77.
Recordkeepinq and Reporting Requirements
(1) Unless otherwise provided, the owners and operators of the source and
each affected unit at the source shall keep on site at the source each of the
following documents for a period of 5 years from the date the document is
created. This period may be extended for cause, at any time prior to the end
of 5 years, in writing by the Administrator or permitting
authority:
(i) The certificate of representation for the designated representative for the
source and each affected unit at the source and all documents that
demonstrate the truth of the statements in the certificate of representation,
in accordance with 40 CFR 72.24; provided that the certificate and
documents shall be retained on site at the source beyond such 5 -year
period until such documents are superseded because of the submission of
a new certificate of representation changing the designated representative;
EPA Form 7610-16 (rev. 07-08)
STEP 3, Cont'd.
Rocky Mountain Energy Center
Facility (Source) Name (from STEP 1)
Acid Rain - Page 4
Recordkeepinq and Reporting Requirements, Cont'd.
(ii) All emissions monitoring information, in accordance with 40 CFR part
75, provided that to the extent that 40 CFR part 75 provides for a 3 -year
period for recordkeeping, the 3 -year period shall apply.
(iii) Copies of all reports, compliance certifications, and other submissions
and all records made or required under the Acid Rain Program; and,
(iv) Copies of all documents used to complete an Acid Rain permit
application and any other submission under the Acid Rain Program or to
demonstrate compliance with the requirements of the Acid Rain Program.
(2) The designated representative of an affected source and each affected unit
at the source shall submit the reports and compliance certifications required
under the Acid Rain Program, including those under 40 CFR part 72 subpart I
and 40 CFR part 75.
Liability
(1) Any person who knowingly violates any requirement or prohibition of the
Acid Rain Program, a complete Acid Rain permit application, an Acid Rain
permit, or an exemption under 40 CFR 72.7 or 72.8, including any requirement
for the payment of any penalty owed to the United States, shall be subject to
enforcement pursuant to section 113(c) of the Act.
(2) Any person who knowingly makes a false, material statement in any
record, submission, or report under the Acid Rain Program shall be subject to
criminal enforcement pursuant to section 113(c) of the Act and 18 U.S.C.
1001.
(3) No permit revision shall excuse any violation of the requirements of the
Acid Rain Program that occurs prior to the date that the revision takes effect.
(4) Each affected source and each affected unit shall meet the requirements of
the Acid Rain Program.
(5) Any provision of the Acid Rain Program that applies to an affected source
(including a provision applicable to the designated representative of an
affected source) shall also apply to the owners and operators of such source
and of the affected units at the source.
(6) Any provision of the Acid Rain Program that applies to an affected unit
(including a provision applicable to the designated representative of an
affected unit) shall also apply to the owners and operators of such unit.
(7) Each violation of a provision of 40 CFR parts 72, 73, 74, 75, 76, 77, and 78
by an affected source or affected unit, or by an owner or operator or
designated representative of such source or unit, shall be a separate violation
of the Act.
Effect on Other Authorities
No provision of the Acid Rain Program, an Acid Rain permit application, an
Acid Rain permit, or an exemption under 40 CFR 72.7 or 72.8 shall be
construed as:
(1) Except as expressly provided in title IV of the Act, exempting or excluding
the owners and operators and, to the extent applicable, the designated
representative of an affected source or affected unit from compliance with any
other provision of the Act, including the provisions of title I of the Act relating
EPA Form 7610-16 (rev. 07-08)
Rocky Mountain Energy Center
Facility (Source) Name (from STEP 1)
Acid Rain - Page 5
Effect on Other Authorities, Cont'd.
to applicable National Ambient Air Quality Standards or State Implementation
STEP 3, Cont'd. Plans;
(2) Limiting the number of allowances a source can hold; provided, that the
number of allowances held by the source shall not affect the source's
obligation to comply with any other provisions of the Act;
(3) Requiring a change of any kind in any State law regulating electric utility
rates and charges, affecting any State law regarding such State regulation, or
limiting such State regulation, including any prudence review requirements
under such State law;
(4) Modifying the Federal Power Act or affecting the authority of the Federal
Energy Regulatory Commission under the Federal Power Act; or,
(5) Interfering with or impairing any program for competitive bidding for power
supply in a State in which such program is established.
STEP 4
Read the
certification
statement,
sign, and date.
Certification
I am authorized to make this submission on behalf of the owners and
operators of the affected source or affected units for which the submission is
made. I certify under penalty of law that I have personally examined, and am
familiar with, the statements and information submitted in this document and
all its attachments. Based on my inquiry of those individuals with primary
responsibility for obtaining the information, I certify that the statements and
information are to the best of my knowledge and belief true, accurate, and
complete. I am aware that there are significant penalties for submitting false
statements and information or omitting required statements and information,
including the possibility of fine or imprisonment.
Mark Fox
Name
Designated Representative
Signature
EPA Form 7610-16 (rev. 07-08)
Date
EPA
Instructions for the Acid Rain Program
Permit Application
The Acid Rain Program requires the designated representative to submit an Acid Rain permit application for
each source with an affected unit. A complete Certificate of Representation must be received by EPA before the
permit application is submitted to the title V permitting authority. A complete Acid Rain permit application, once
submitted, is binding on the owners and operators of the affected source and is enforceable in the absence of a
permit until the title V permitting authority either issues a permit to the source or disapproves the application.
Please type or print. If assistance is needed, contact the title V permitting authority.
STEP 1 A Plant Code is a 4 or 5 digit number assigned by the Department of Energy's (DOE) Energy
Information Administration (EIA) to facilities that generate electricity. For older facilities, "Plant Code" is
synonymous with "ORISPL" and "Facility" codes. If the facility generates electricity but no Plant Code
has been assigned, or if there is uncertainty regarding what the Plant Code is, contact EIA at (202)
586-4325 or (202) 586-2402.
STEP 2 In column "a," identify each unit at the facility by providing the appropriate unit identification number,
consistent with the identifiers used in the Certificate of Representation and with submissions made to
DOE and/or EIA. Do not list duct burners. For new units without identification numbers, owners and
operators must assign identifiers consistent with EIA and DOE requirements. Each Acid Rain Program
submission that includes the unit identification number(s) (e.g., Acid Rain permit applications,
monitoring plans, quarterly reports, etc.) should reference those unit identification numbers in exactly
the same way that they are referenced on the Certificate of Representation.
Submission Deadlines
For new units, an initial Acid Rain permit application must be submitted to the title V permitting authority 24
months before the date the unit commences operation. Acid Rain permit renewal applications must be submitted
at least 6 months in advance of the expiration of the acid rain portion of a title V permit, or such longer time as
provided for under the title V permitting authority's operating permits regulation.
Submission Instructions
Submit this form to the appropriate title V permitting authority. If you have questions regarding this form, contact
your local, State, or EPA Regional Acid Rain contact, or call EPA's Acid Rain Hotline at (202) 343-9620.
Paperwork Burden Estimate
The public reporting and record keeping burden for this collection of information is estimated to average 8 hours
per response. Burden means the total time, effort, or financial resources expended by persons to generate,
maintain, retain, or disclose or provide information to or for a Federal agency. This includes the time needed to
review instructions; develop, acquire, install, and utilize technology and systems for the purposes of collecting,
validating, and verifying information, processing and maintaining information, and disclosing and providing
information; adjust the existing ways to comply with any previously applicable instructions and requirements; train
personnel to be able to respond to a collection of information; search data sources; complete and review the
collection of information; and transmit or otherwise disclose the information. An agency may not conduct or
sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid
OMB control number.
Send comments on the Agency's need for this information, the accuracy of the provided burden estimates, and
any suggested methods for minimizing respondent burden, including through the use of automated collection
techniques to the Director, Collection Strategies Division, U.S. Environmental Protection Agency (2822T), 1200
Pennsylvania Ave., NW., Washington, D.C. 20460. Include the OMB control number in any correspondence. Do
not send the completed form to this address.
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