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Home My WebLink About20190721.tiffOperating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE EMISSION UNIT CRITERIA AIR POLLUTANTS FORM 201)0-601 09-94 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: F038 4. Unit identification code: P038 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached Air pollutant Particulates (TSP) PM -10 Nitrogen oxides Volatile organic compounds Carbon monoxide Lead Sulfur dioxide Total reduced sulfur Reduced sulfur compounds Hydrogen sulfide Sulfuric Acid Mist Fluorides Units (U) should be entered as follows: = lb/hr 2 = lb/mmBTU 3 = grains/dscf 4 = lb/ gallon 5 = ppmdv 6 = gram/HP-hour 7 = lb/mmscf 8 = other (specify) 9 = other (specify) 10 = other (specify) Potential to emit Quantity U TPY Maximum allowable U TPY 2019-0721 163 Operating Permit Application PLANT -WIDE HAZARDOUS AIR POLLUTANTS Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 FORM 2000-602 Rev 06-95 3. Complete the following emissions summary for all hazardous air emissions at this facility. Calculations attached. Attach a copy of all calculations to this form. Attached Pollutant CAS 71432 50000 75070 1330207 108883 Common or Generic Pollutant Name Benzene Xylene Toluene Allowable OR Potential to emit Quantity 4536.9 9240.2 3327.2 1906.8 NOTE: If there is a permit for this unit, the permit limits are the same as the potential to emit. Units lbs/yr lbs/yr lbs/yr lbs/yr lbs/yr 164 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant PLANT -WIDE CRITERIA AIR POLLUTANTS FORM 2000-603 09-94 2. Facility identification code: CO 1230049 3. Complete the following emissions summary for the listed emissions at this facility. Air pollutant Particulates (TSP) PM -10 Nitrogen oxides Volatile organic compounds Carbon monoxide Lead Sulfur dioxide Total reduced sulfur Reduced sulfur compounds Hydrogen sulfide Sulfuric acid mist Fluorides Potential to emit TPY Maximum allowable TPY Neg. Neg. 211.1 150.3 213.7 Neg. 165 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant APPLICABLE REQUIREMENTS AND FORM 2000.604 Rev 06-95 STATUS OF EMISSION UNIT 2. Facility identification code: CO 1230049 3. Stack identification code: S033 4. Unit identification code: P033 8. Limitation 9. Compliance Status IN OUT 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only Volatile Orgame Com unds 01WE0208 11.0 tons/yr X 10. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, hours of operation, etc.) State Only Compliance s IN OUT Regulation 3, Part A, II.C - APEN Requirements X Extended Gas Analysis X Emission Calculations and GLYCaic Model Runs X Dehydration Operational Parameters Recordkeeping X Natural Gas Throughput Recordkeeping X Flare fuel requirements and opacity X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 166 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE APPLICABLE REQUIREMENTS AND FORM 2000-604 STATUS OF EMISSION UNIT 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S001 4. Unit identification code: C-154 Rev 06-95 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT Nitrogen Oxides 97WE0340 22.3 tons/yr X Carbon Monoxide 97WE0340 22.3 tons/yr X Volatile Organic Compounds 97WE0340 10.6 tons/yr X Fuel Use 97WE0340 77.45 MMscf/yr X Opacity Reg 3, Part B, IV.E. 20% X 10. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, hours of operation, etc.) State Only Compliance Status IN OUT Fuel Consumption Limitations X BTU Content of Natural Gas Verification X Engine Maintenance X Engine Recordkeeping; including NSCR and AFR monitoring X Portable Monitoring Tri-annually X Regulation 3, Part A, II.C - APEN Requirements X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 167 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE APPLICABLE REQUIREMENTS AND FORM 2000-604 STATUS OF EMISSION UNIT 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S002 4. Unit identification code: C-155 Rev 06-95 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT Nitrogen Oxides 97WE0340 16.34 tons/yr X Carbon Monoxide 97WE0340 16.34 tons/yr X Volatile Organic Compounds 97WE0340 7.8 tons/yr X Fuel Use 97WE0340 65.84 MMscf/yr X Opacity Reg 3, Part B, IV.E. 20% X 10. Other requirements (e.g., malfunction reporting, special operating conditions existing permit such as material usage, hours of operation, etc.) from an State Only Compliance Status IN OUT Fuel Consumption Limitations X BTU Content of Natural Gas Verification X Engine Maintenance X Engine Recordkeeping; including NSCR and AFR monitoring X Portable Monitoring Tri-annually X Regulation 3, Part A, II.C - APEN Requirements X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 168 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE APPLICABLE REQUIREMENTS AND FORM 2000-604 STATUS OF EMISSION UNIT 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S003 4. Unit identification code: C-159 Rev 06-95 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT Nitrogen Oxides 97WE0340 27.38 tons/yr X Carbon Monoxide 97WE0340 27.38 tons/yr X Volatile Organic Compounds 97WE0340 13.04 tons/yr X Fuel Use 97WE0340 101.4 MMscf/yr X Opacity Reg 3, Part B, IV..E. 20% X 10. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, hours of operation, etc.) State Only Compliance Status IN OUT Fuel Consumption Limitations X BTU Content of Natural Gas Verification X Engine Maintenance X Engine Recordkeeping; including NSCR and AFR monitoring X Portable Monitoring Tri-annually X Regulation 3, Part A, II.C — APEN Requirements X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 169 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE APPLICABLE REQUIREMENTS AND FORM 2000-604 STATUS OF EMISSION UNIT 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S007 4. Unit identification code: C-157 Rev 06-95 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT Nitrogen Oxides 97WE0340 16.34 tons/yr X Carbon Monoxide 97WE0340 16.34 tons/yr X Volatile Organic Compounds 97WE0340 7.8 tons/yr X Fuel Use 97WE0340 65.84 MMscf/yr X Opacity Reg 3, Part B, IV.E. 20% X 10. Other requirements (e.g., malfunction reporting, special operating conditions existing permit such as material usage, hours of operation, etc.) from an State Only Compliance Status IN OUT Fuel Consumption Limitations X BTU Content of Natural Gas Verification X Engine Maintenance X Engine Recordkeeping; including NSCR and AFR monitoring X Portable Monitoring Tri-annually X Regulation 3, Part A, II.C - APEN Requirements X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 170 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE APPLICABLE REQUIREMENTS AND FORM 2000-604 STATUS OF EMISSION UNIT 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S008 4. Unit identification code: C-161 Rev 06-95 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT Nitrogen Oxides 97WE0340 27.38 tons/yr X Carbon Monoxide 97WE0340 27.38 tons/yr X Volatile Organic Compounds 97WE0340 13.04 tons/yr X Fuel Use 97WE0340 101.4 MMscf/yr X Opacity Reg 3, Part B, IV.E. 20% X 10. Other requirements (e.g., malfunction existing permit such as material reporting, special operating conditions usage, hours of operation, etc.) from an State Only Compliance Status IN OUT Fuel Consumption Limitations X BTU Content of Natural Gas Verification X Engine Maintenance X Engine Recordkeeping; including NSCR and AFR monitoring X Portable Monitoring Tri-annually X Regulation 3, Part A, II.C — APEN Requirements X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 171 Operating Permit Application Colorado Department of Public Health and Environment Mr Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE APPLICABLE REQUIREMENTS AND FORM 2000-604 STATUS OF EMISSION UNIT 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S010 4. Unit identification code: C-158 Rev 06-95 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT Nitrogen Oxides 97WE0340 18.60 tons/yr X Carbon Monoxide 97WE0340 18.60 tons/yr X Volatile Organic Compounds 97WE0340 8.84 tons/yr X Fuel Use 97WE0340 71.3 MMscf/yr X Opacity Reg 3, Part B, IV.E. 20% X W. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, hours of operation, etc.) State Only Compliance Status IN OUT Fuel Consumption Limitations X BTU Content of Natural Gas Verification X Engine Maintenance X Engine Recordkeeping; including NSCR and AFR monitoring X Portable Monitoring Tri-annually X Regulation 3, Part A, II.C - APEN Requirements X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 172 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE APPLICABLE REQUIREMENTS AND FORM 2000-604 STATUS OF EMISSION UNIT 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S013 4. Unit identification code: C-160 Rev 06-95 8. Limitation 9. Compliance Status IN OUT 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only Nitrogen Oxides 97WE0340 16.34 tons/yr X Carbon Monoxide 97WE0340 16.34 tons/yr X Volatile Organic Compounds 97WE0340 7.8 tons/yr X Fuel Use 97WE0340 65.84 MMscf/yr X Opacity Reg 3, Part B, IV.E. 20% X 10. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, hours of operation, etc.) State Only Compliance s IN OUT Fuel Consumption Limitations X BTU Content of Natural Gas Verification X Engine Maintenance X Engine Recordkeeping; including NSCR and AFR monitoring X Portable Monitoring Tri-annually X Regulation 3, Part A, II.C — APEN Requirements X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 173 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE APPLICABLE REQUIREMENTS AND FORM 2000-604 STATUS OF EMISSION UNIT 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S014 4. Unit identification code: C-156 Rev 06-95 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT Nitrogen Oxides 97WE0340 16.34 tons/yr X Carbon Monoxide 97WE0340 16.34 tons/yr X Volatile Organic Compounds 97WE0340 7.8 tons/yr X Fuel Use 97WE0340 65.84 MMscf/yr X Opacity Reg 3, Part B, IV.E. 20% X 1O. Other requirements (e.g., malfunction reporting, special operating conditions existing permit such as material usage, hours of operation, etc.) from an State Only Compliance Status IN OUT Fuel Consumption Limitations X BTU Content of Natural Gas Verification X Engine Maintenance X Engine Recordkeeping; including NSCR and AFR monitoring X Portable Monitoring Tri-annually X Regulation 3, Part A, II.C - APEN Requirements X s **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 174 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE APPLICABLE REQUIREMENTS AND FORM 2000-604 STATUS OF EMISSION UNIT 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S015 4. Unit identification code: C-223 Rev 06-95 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT Nitrogen Oxides 97WE0340 14.6 tons/yr X Carbon Monoxide 97WE0340 14.6 tons/yr X Volatile Organic Compounds 97WE0340 7.0 tons/yr X Fuel Use 97WE0340 56.69 MMscf/yr X Opacity Reg 3, Part B, IV.E. 20% X 10. Other requirements (e.g., malfunction reporting, special operating conditions existing permit such as material usage, hours of operation, etc.) from an State Only Compliance IN OUT Fuel Consumption Limitations X BTU Content of Natural Gas Verification X Engine Maintenance X Engine Recordkeeping; including NSCR and AFR monitoring X Portable Monitoring Tri-annually X Regulation 3, Part A, II.C — APEN Requirements X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 175 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE APPLICABLE REQUIREMENTS AND FORM 2000-604 STATUS OF EMISSION UNIT 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S017 4. Unit identification code: C-225 Rev 06-95 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT Nitrogen Oxides 97WE0340 16.2 tons/yr X Carbon Monoxide 97WE0340 16.2 tons/yr X Volatile Organic Compounds 97WE0340 7.7 tons/yr X Fuel Use 97WE0340 58.52 MMscf/yr X Opacity Reg 3, Part B, IV.E. 20% X .10. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, hours of operation, etc.) State Only Compliance Status IN OUT Fuel Consumption Limitations X BTU Content of Natural Gas Verification X Engine Maintenance X Engine Recordkeeping; including NSCR and AFR monitoring X Portable Monitoring Tri-annually X Regulation 3, Part A, II.C — APEN Requirements X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 176 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE APPLICABLE REQUIREMENTS AND FORM 2000-604 STATUS OF EMISSION UNIT 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S019 4. Unit identification code: C-227 Rev 06-95 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT Nitrogen Oxides 97WE0340 14.6 tons/yr X Carbon Monoxide 97WE0340 14.6 tons/yr X Volatile Organic Compounds 97WE0340 7.0 tons/yr X Fuel Use 97WE0340 56.69 MMscf/yr X Opacity Reg 3, Part B, IV.E. 20% X .10. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, hours of operation, etc.) State Only Compliance Status IN OUT Fuel Consumption Limitations X BTU Content of Natural Gas Verification X Engine Maintenance X Engine Recordkeeping; including NSCR and AFR monitoring X Portable Monitoring Tri-annually X Regulation 3, Part A, II.C - APEN Requirements X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 177 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE APPLICABLE REQUIREMENTS AND FORM 2000-604 STATUS OF EMISSION UNIT 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S037 4. Unit identification code: H037 Rev 06-95 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT Opacity Reg 3, Part B, IV.E. 20% X 10. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, hours of operation, etc.) State Only Compliance Status IN OUT Fuel Consumption Limitations X Regulation 3, Part A, II.C - APEN Requirements X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 178 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE APPLICABLE REQUIREMENTS AND FORM 2000-604 STATUS OF EMISSION UNIT 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S025 4. Unit identification code: F025 Rev 06-95 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT Volatile Organic Compounds 97WE0340 16.8 tons/yr X 10. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, hours of operation, etc.) State Only Compliance Status IN OUT Regulation 3, Part A, II.C - APEN Requirements X Physical Component Count Requirement X Plant Inlet Gas Analysis X Maintenance Plan X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 179 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE APPLICABLE REQUIREMENTS AND FORM 2000-604 STATUS OF EMISSION UNIT 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S028 4. Unit identification code: P028 Rev 06-95 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT Volatile Organic Compounds 3.4 tons/yr X 10. Other requirements (e.g., malfunction reporting, special operating conditions existing permit such as material usage, hours of operation, etc.) from an State Only Compliance Status IN OUT Regulation 3, Part A, II.C - APEN Requirements X Recordkeeping to track gallons of condensate X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 180 Operating Permit Application APPLICABLE REQUIREMENTS AND Colorado Department of Public Health and Environment STATUS OF EMISSION UNIT Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 FORM 2000-604 Rev 06-95 3. Stack identification code: S029 4. Unit identification code: F029 9. Compliance Status IN OUT 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation Volatile Organic Compounds 97WE0340 5.8 tons/yr X 10. Other requirements (e.g., malfunction reporting, special operating conditions existing permit such as material usage, hours of operation, etc.) from an State Only Compliance Status IN OUT Regulation 3, Part A, II.C — APEN Requirements X Recordkeeping to track gallons of condensate X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 181 Operating Permit Application APPLICABLE REQUIREMENTS AND Colorado Department of Public Health and Environment STATUS OF EMISSION UNIT Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE FORM 2000-604 Rev 06-95 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S038 4. Unit identification code: P038 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT Volatile Organic Compounds 97WE0340 9.86 tons/yr X Carbon Monoxide 97WE0340 3.94 tons/yr X 10. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, hours of operation, etc.) State Only Compliance Status IN OUT Regulation 3, Part A, 'LC - APEN Requirements X Recordkeeping to track propane sent to flare X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 182 Operating Permit Application APPLICABLE REQUIREMENTS AND Colorado Department of Public Health and Environment STATUS OF EMISSION UNIT Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE FORM 2000-604 Rev 06-95 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S031 4. Unit identification code: F031 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT Volatile Organic Compounds 97WE0340 5.0 tons/yr X 10. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, hours of operation, etc.) State Only Compliance Status IN OUT Regulation 3, Part A, II.C - APEN Requirements X Recordkeeping to track number of trucks loaded X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE 183 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant PERMIT SHIELD PROTECTION IDENTIFICATION FORM 2000-605 Rev 06-95 2. Facility identification code: CO 1230049 3. Specify Emission Source: C-154, C-155, C-159, C-223, C-225, C-227 C-157, C-161, C-158, C-160, C-156, 4. Do not use 5. Pollutant, Equipment, or Process 6. Colorado Air Quality Regulations 7. State Only C-154, C-155, C-159, C- 157, C-161, C-158,, C-160, C-156, C-223, C-225, C-227 Reg 1.III.A.1.b & Reg 1.VI.B.5.a - Internal combustion engines are not considered fuel burning equipment for the applicable requirements of Regulation 1. 8. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, operating hours, etc.) State Only NOTE: REQUESTS FOR THE SHIELD MUST BE FOR A SPECIFIC REQUIREMENT IN THE REGULATIONS. USE FORM 2000-700 TO PROVIDE AN EXPLANATION OF WHY THE SHIELD IS REQUESTED 184 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant PERMIT SHIELD PROTECTION FORM 2000-605 IDENTIFICATION Rev 06-95 2. Facility identification code: CO 1230049 3. Specify Emission Source: Station -Wide 8. Other requireme existing permit suc 4. Do not use 5. Pollutant, Equipment, or Process 6. Colorado Air Quality Regulations 7. State Only Facility Wide Reg. 3 B.IV.D.2 Non -attainment area requirements ✓ Facility Wide Reg. 3 B.IV.D.3 PSD Review requirements ✓ Facility Wide Reg. 3 B. X. Air Quality Modeling ✓ Facility Wide Reg. 3 B. XI Visibility requirements ✓ Facility Wide Reg. 4 - Wood Burning Stoves ✓ Facility Wide Reg. 6 Part A - Federal NSPS Requirements Facility Wide Reg. 6 Part B - State Only NSPS Requirements ✓ Facility Wide Reg. 7 V.C ✓ Facility Wide Reg. 7 VI.B.1 - Storage of Petroleum Distillates ✓ Facility Wide Reg. 7 VI.B.2 - Storage of Petroleum Distillates ✓ Facility Wide Reg. 7 VII. C - Crude Oil Storage ✓ Facility Wide Reg. 8 E.I - NESHAPS ✓ Facility Wide Reg. 8 E.III - NESHAPS ✓ Facility Wide Reg. 10 ✓ nts (e.g., malfunction reporting, special operating conditions from an i as material usage, operating hours, etc.) State Only NOTE: REQUESTS FOR THE SHIELD MUST BE FOR A SPECIFIC REQUIREMENT IN THE REGULATIONS. USE FORM 2000-700 TO PROVIDE AN EXPLANATION OF WHY THE SHIELD IS REQUESTED 185 Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S001 4. Unit identification code: C-154 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. /We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. it it 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter 186 Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S002 4. Unit identification code: C-155 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. ✓We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter 187 Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S003 4. Unit identification code: C-159 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. /We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter 188 Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S007 4. Unit identification code: C-157 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. /We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. 2. m 3. Progress reports will be submitted: Start date: and every six (6) months thereafter 189 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 COMMITMENTS AND SCHEDULE o9-94 2. Facility identification code: CO 1230049 3. Stack identification code: S008 4. Unit identification code: C-161 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. /We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter 190 Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 • Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: SO10 4. Unit identification code: C-158 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. /We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter 191 Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S013 4. Unit identification code: C-160 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. /We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter 192 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 COMMITMENTS AND SCHEDULE 09-94 2. Facility identification code: CO 1230049 3. Stack identification code: S014 4. Unit identification code: C-156 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. 1We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. 2. II 3. Progress reports will be submitted: Start date: and every six (6) months thereafter 193 Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S015 4. Unit identification code: C-223 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. ,(We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter 194 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 COMMITMENTS AND SCHEDULE 09-94 2. Facility identification code: CO 1230049 3. Stack identification code: S017 4. Unit identification code: C-225 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. /We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. ' I 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter 195 Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S019 4. Unit identification code: C-227 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. /We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. 2. 3. 1 Progress reports will be submitted: Start date: and every six (6) months thereafter 196 Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S037 4. Unit identification code: 11037 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. /We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. 2. 3. —I Progress reports will be submitted: Start date: and every six (6) months thereafter 197 Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S025 4. Unit identification code: F025 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. /We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline Progress reports will be submitted: Start date: and every six (6) months thereafter 198 Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S028 4. Unit identification code: P028 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. ✓We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter 199 Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S029 4. Unit identification code: F029 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. VWe will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter 200 Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S031 4. Unit identification code: F031 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. /We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter 201 Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S033 4. Unit identification code: P033 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. ✓We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1 1. 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter 202 Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO 1230049 3. Stack identification code: S038 4. Unit identification code: P038 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. /We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter 203 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SUPPLEMENTAL INFORMATION FORM 2000-700 09-94 SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049_ 3. This form supplements Form 2000 - 102B for Emission Unit (e.g. B001, C-154, etc.) Additional Information, Diagrams Item Number Insignificant Activities: Storage Tank - Pressurized NGL Storage Tanks (various sizes) Storage Tank - Methanol Storage Tanks Storage Tank - Ambitrol Tanks Storage Tank - Lube Oil Tanks Storage Tank - Triethylene Glycol Tank Storage Tank - Solvent Tanks Regeneration Heater Heater Treater 2 - 0.12 MMBtu/hr Office Furnaces 1 - 0.04 MMBtu/hr Office Water Heater 1 - 0.16 MMBtu/hr Shop Heater 1 - 20 hp John Deere Gator Tractor 204 Operating Permit Application TABULATION OF PERMIT APPLICATION FORMS FORM 2000-800 Colorado Department of Health 09-94 Air Pollution Control Division Facility Name: Roeeen Gas Plant I. ADMINISTRATION Facility Identification Code: CO 1230049 This application contains the following forms: Form 2000-100, Facility Identification Form 2000-101, Facility Plot Plan 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, printing Form 2000-200, Stack Identification 18 Form 2000-300, Boiler or Furnace Operation 1 Form 2000-301, Storage Tanks 1 Form 2000-302, Internal Combustion Engine 11 Form 2000-303, Incineration Form 2000-304, Printing Operations Form 2000-305, Painting and Coating Operations Form 2000-306, Miscellaneous Processes 4 Form 2000-307, Glycol Dehydration Unit 1 III. AIR POLLUTION CONTROL SYSTEM Total Number of This Form This application contains the following forms: Form 2000-400, Miscellaneous 12 Form 2000-401, Condensers Form 2000-402, Absorbers 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 Form 2000-500, Compliance Certification - Monitoring and Reporting 18 Form 2000-501, Continuous Emission Monitoring Form 2000-502, Periodic Emission Monitoring Using Portable Monitors 11 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 11 Form 2000-507, Recordkeeping 18 Form 2000-508, Other Methods 13 205 04/29/05 FRI 08:12 FAX 9184994230 PUKE ENERGY• 4 00 2 V. EMISSION SUMMARY AND COMPLIANCE CERTIFICATION This application contains the following farms quantifying emissions, certifying compliance with applicable requirements, and developing a compliance plan Form 2000-600, Emission Unit Hazardous Air Pollutants Total Number of This Form 18 Form 2000-601, Emission Unit Criteria Air Pollutants 18 Form 2006-602; €agility Ftaierdous Air Pollutants 1 Form 2000-603, Facility Criteria Air Pollutants 1 Form 2000-604, Applicable Requirements and Status of Emission Unit Form 2000.605, Permit Shield Protection Identification 18 2 Form 2000-606, Emission Unit Compliance Plan - Commitments and Schedule Form 2000-607, Plant -Wide Applicable Requirements 18 Form 2000-608, Plant -Wide Compliance Plan - Commimunts and Schedule VI. • SIGNATURE OF RESPONSIBLE OFFICIALFEDERAL/STATE CONDITIONS STATEMENT OF COMPLETENESS I have reviewed this application in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this application are true, accurate and complete. B. CERTIFICATION OF FACILITY COMPLIANCE STATUS - FEDERAL/STATE CONDITIONS (check one box only) I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements. I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements, except for the following emissions unit(s): (list all non -complying units) WARNING: Any person who knowingly, as defined in § 18-1-501(6), C.R.S., makes any false material statement, representation, or certification in, or omits material Information from this application Is guilty of a misdemeanor and may be punished in accordance with the provisions of § 2S-? 122.1, C.R.S. Printed or Typed Name Title Paul Brewer Vice President of Operations —Northern Division Signature cu.ti rs.kul.) Date Signed ‘•-l• aq-as Operating Penult Application CERTIFICATION FOR STATE -ONLY CONDITIONS Colorado pcparnnent of Health 09-94 Air Pollution Control Division Facility Name: Rogeen Gas Plant Facility Identification Code: CO 1230049 FORM 2000-800 VI SIGNATURE OF RESPONSIBLE OFFICIAL - STATE ONLY CONDITIONS STATEMENT OF COMPLETENESS I have reviewed this application in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this application are true, accurate and complete. CERTIFICATION OF FACILITY COMPLIANCE STATUS FOR STATE -ONLY CONDITIONS (check one box only) I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements. I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements, except for the following einissions.unit(s) (list all non -complying units) WARNING: Any person who knowingly, as defined in § 18-1-501(6), C.R.S., makes any false material statement, representation, or certification in, or omits Material information from this application is guilty of a misdemeanor and may be punished in accordance with the provisions of § 25-7122.1, C.R.S. Printed or Typed Name Paul Brewer Title Vice President of Operations— Northern Division Signature Pc -� JT:- Date Signed • ..g -Qs SEND ALL MATERIALS TO: COLORADO DEPARTMENT OF HEALTH APCD-SS-Bl 4300 CHERRY CREEK DRIVE SOUTH DENVER, CO 80246-1530 AIR POLLUTANT EMISSION NOTICE PERMIT No.: 95OPWE055 AIRS ID.: 123 /0049 /101 FIRM NAME: Duke Energy Field Services, LP MAIL ADDRESS: 370 170i Street. Suite 2500. Denver PLANT NAME & LOCATION Roggen Natural Gas Processing Plant, Section 24. R63W. T2N at 35409 County Road 18 O REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE: PERSON To CONTACT REGARDING THIS INFORMATION: Ashley Campsie STATE: CO TITLE: Environmental Engineer PHONE: 303-605-2023 E-MAIL ADDRESS: ek- ZIP: 80202 , COUNTY: Weld A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Throughput (% of Annual) ADDITIONAL INFORMATION OR REMARKS: Hours/Day 24 Days/Week 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or moreirefer to attached sketch of plant layout) Height 40 ft Diameter 0.83 ft Temperature 1037 F Flow Rate 1600 ACFM Velocity 2957 ft/min Moisture % Plant ID No. for Stack S-001 (C-154) C. FUEL INFORMATION Design Input Rate Annual Fuel Consumption Fuel Heating Value: (BTU/lb, BTU/gal, or BTU/scf) Percent by Weight Seasonal Fuel Use 5% of Annual Use) Space Htg (% Ann.) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov No. 7 Wet Gas Service Compressor Engine (106 BTU/hr) Kind of Fuel Burned Requested level Actual level (Data year level) Make: Waukesha 8.47 Natural Gas 77.45 MMscf 958 Btu/scf Neg. Neg. 25 25 25 25 Model: 1000 hp L7042GSI Serial No.360925 D. PROCESS INFORMATION Description of Processing Unit Raw Materials Used Raw Materials-Annua Consumption Design Process Rate (Specify Units/Hour) Finished Product Description Finished Product -Annual Output Requested level Actual level (Data year level) Description Requested level Actual level (Data year level) Make: Model: Serial No.: E. POLLUTION CONTROL EQUIPMENT Pollutant Type of Control Equipment Primary Secondary Overall Collection Efficiency ESTIMATED EMISSIONS ACTUAL (TONS/YEAR)TE THROUGHPUTS EMISSIONS CONTROLLED UNCONTROLLED ESTIMATION METHOD Particulate PM10 SOx NOx -NSCR AFR 22.31 2.1 g/hp-hr 1.0 g/hp-hr 2.1 g/hp-hr VOC NSCR AFR 10.62 CO PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. NSCR AFR 22.31 ❑ CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK. CHECK ALL BOXES THAT APPLY ❑ New or previously unreported source ❑ Requesting modification of existing permit ❑ Change in emissions, throughputs or equipment ❑ Transfer of ownership * ® No change; APEN update only ❑ Other (Specify) * * Note: For transfer of ownership or company name change of a permit, you must also submit a Construction Permit Application form. ITyped Name and Title: Ashley Campsie, Environmental En. • eer Signature of Person Legally Authorized to Supply Data: go°11-147 DATE: r�025...- YEAR FOR WHICH THE ACTUAL DATA APPLIES: Date source began or will begin operation: 1976 THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details s+ Regulation 3, Part A, H.C.1. A $119.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send completed forms with fees to: Colorado Dept. of Public Health & Environment APEN # of Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-Bl For Information, Call _ Denver, Colorado 802464530 (303) 692-3150 _ http://www.cdphe.state.co.us/ap/stationary.asp Revised September 2004 NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM* (Instructions on reverse side) Permit Number 95OPWE055 Company Name: Duke Energy Field Services, LP Plant Location: Section 24, R63W, T2N at 35409 County Road 18 AIRS Number 123/0049/101 Person to Contact: Ashley Campsie E -Mail Address: alcampsie@duek-energy.com County Weld Zip Code 80652 Phone 303-605-2023 Fax 303-605-1957 Chemical Abstract Service Number Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (Include units) Emission Factor Source Requested Emissions (lbs/yr) Actual Emissions from the Data Year (ibs/yr) 71432 Benzene A None 1.81% VOC SPECIATE 384.5 50000 Formaldehyde A None 0.047 g/hp-hr 998.5 75070 Acetaldehyde A None 0.32% VOC SPECIATE 68 * Use this form for reporting Hazardous Air Pollutants, Ozone Depleting Compounds, and other Non -Criteria Reportable Pollutant Year For Which The Actual Data Applies: Date Signature of Legall Authorized Person (not a vendor or consultant) Ashley Campsie Name of a Responsible Official (please print) Environmental Engineer Title http://www.cdphe.state.co.us/ap/stationary.asp Revised September 2004 AIR POLLUTANT EMISSION NOTICE PERMIT No.: 95OPWE055 AIRS ID.: 123 /0049 /102 FIRM NAME: Duke Energy Field Services. LP MAIL ADDRESS: 370 17th Street. Suite 2500. Denver PLANT NAME & LOCATION Roggen Natural Gas Processing Plant. Section 24. R63 W. T2N at 35409 County Road 18 O REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE: TITLE: Environmental Engineer PERSON To CONTACT REGARDING THIS INFORMATION: Ashley Campsie STATE: Co PHONE: 303-605-2023 ZIP: 80202 , COUNTY: Weld E-MAIL ADDRESS: alcampsiduek-energy.com Urh.N.MAr, IJraldcu' 11VAN '.Jr aru. r..,.au.ua.,.ay... — A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Throughput (% of Annual) ADDITIONAL INFORMATION OR REMARKS: Hours/Day 24 Days/Week 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of plant layout) Height 20 ft Diameter 0.83 ft Temperature 1033 F Flow Rate 4188 ACFM Velocity 7679 ft/min Moisture % Plant ID No. for Stack S-002 (C-155) C. FUEL INFORMATION Design Input Rate Annual Fuel Consumption Fuel Heating Value: (BTU/lb, BTU/gal, or BTU/scf) Percent by Weight Seasonal Fuel Use (% of Annual Use) Space Htg (% Arm.) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov No. 1 Residue Service Compressor Engine (106 BTU/hr) Kind of Fuel Burned Requested level Actual level (Data year level) Make: Waukesha 7.2 Natural Gas 65.84 MIvIscf 958 Btu/scf Neg. Neg. 25 25 25 25 Model: 806 hp L7042G Serial No.253828 D. PROCESS INFORMATION Description of Processing Unit Raw Materials Used Raw Materials -Annual Consumption Design Process Rate (Specify Units/Hour) Finished Product Description Finished Product -Annual Output Requested level Actual level (Data year level) Description Requested level Actual level (Data year level) Make: Model: Serial No.: CHECK ALL BOXES THAT APPLY O New or previously unreported source • Requesting modification of existing permit • Change in emissions, throughputs or equipment O Transfer of ownership * O No change; APEN update only O Other (Specify) * E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS ACTUAL ESTIMATION Pollutant Type of Control Equipment Collection Efficiency (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE EMISSIONS METHOD Primary Secondary CONTROLLED UNCONTROLLED Particulate PMio SO„ NO„ NSCR AFR 16.34 2.1 g/hp-hr Note: For transfer of ownership or company name change of a permit, you must also submit a Construction Permit Application form. VOC NSCR AFR 7.78 1.0 g/hp-hr CO NSCR AFR 16.34 2 1 g/hp-hr* PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. ❑ CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK. DATE: /��4 ._YEAR / FOR WHICH THE ACTUAL DATA APPI .�C: Signature of Person Legally Authorized to Supply Data: ) / �� /j (-•a•111,47 Typed Name and Title: Ashlev Campsie Environmental Engineer Date source began or will begin operation: 1975 THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details see Regulation 3, Part A, H.C.1. $119.96 FILING FEE IS REQUIRED OR EACH NOTICE FILED. end completed forms with fees to: Colorado Dept of Public Health & Environment APEN # of Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-BI For Information, Call _ Denver, Colorado 80246-1530 (303) 692-3150 _ http://www.cdphe.state.co.us/ap/stationarv.asp Revised September 2004 NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM* (Instructions on reverse side► Permit Number 95OPWE055 Company Name: Duke Energy Field Services, LP AIRS Number 123/0049/102 Plant Location: Section 24, R63W, T2N at 35409 County Road 18 Person to Contact: Ashley Campsie E -Mail Address: alcampsie@duek-energy.com County Weld Zip Code 80652 Phone 303-605-2023 Fax 303-605-1957 Chemical Abstract Service Number Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (Include units) Emission Factor Source Requested Emissions (lbs/yr) Actual Emissions from the Data Year (lbs/yr) 71432 Benzene A None 1.81% VOC SPECIATE 281.7 50000 Formaldehyde A None 0.047 g/hp-hr 731.6 75070 Acetaldehyde A None 0.32% VOC SPECIATE 49.8 * Use this form for reporting Hazardous Air Pollutants, Ozone Depleting Compounds, and other Non -Criteria Reportable Pollutant Year For Which The Actual Data Applies: Si �Le all uthonzeor Legallyconsultant) Ashley Campsie Name of a Responsible Official (please print) ai d Person ��endor Date Environmental Engineer Title http://www.cdphe.state.co.us/ap/stationary.asp Revised September 2004 AIR POLLUTANT EMISSION NOTICE PERMIT No.: 95OPWE055 AIRS ID.: 123 /0049 /110 FIRM NAME: Duke Energy Field Services. LP MAIL ADDRESS: 370 17th Street. Suite 2500. Denver PLANT NAME & LOCATION Roggen Natural Gas Processing Plant, Section 24. R63W. T2N at 35409 County Road 18 O REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE: PERSON TO CONTACT REGARDING THIS INFORMATION: Ashley Campsie GENERAL DESCRIPTION OF THIS PLANT'S FUNCTION: STATE: CO A. GENERAL INFORMATION Normal Operation of This Source Hours/Day 24 TrrLE: Environmental Engineer Process Seasonal Throughput (% of Annual) Dec -Feb 25 Days/Week 7 Weeks/Year 52 Mar -May Jun -Aug 25 25 25 Sep Nov PHONE: 303-605-2023 ZIP: 80202 ; COUNTY: Weld E-MAIL ADDRESS: alcampsie@duek-energy.com ADDITIONAL INFORMATION OR REMARKS: B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of plant layout) Height 20 ft Diameter 0.83 ft Temperature 1060 F Flow Rate 5153 ACFM Velocity 9524 ft/min Moisture Plant ID No. for Stack S-010 (C-158) C. FUEL INFORMATION No. 6 Residue Service Compressor Engine Design Input Rate (106 BTU/hr) Kind of Fuel Burned Annual Fuel Consumption Requested level Actual level (Data year level) Fuel Heating Value: (BTU/lb, BTU/gal, or BTU/scf) Percent by Weight Sulfur Ash Seasonal Fuel Use 5% of Annual Use) Dec -Feb Mar -May Jun -Aug Sep -Nov Space Htg (/o Ann.) Make: Waukesha 7.8 Natural Gas 71.3 MMscf 958 Btu/scf Neg. Neg. 25 25 25 25 Model: 916 hp L7042G Serial No.13008/1 D. PROCESS INFORMATION Description of Processing Unit Make: Raw Materials Used Raw Materials -Annual Consumption Description Requested level Actual level (Data year level) Design Process Rate (Specify Units/Hour) Finisher! Product Description Finished Product -Annual Output Requested level Actual level (Data year level) Model: Serial No.: E. POLLUTION CONTROL EQUIPMENT Pollutant Type of Control Equipment Primary Secondary Overall Collection Efficiency ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE CONTROLLED UNCONTROLLED ACTUAL EMISSIONS ESTIMATION METHOD Particulate PM1a Sox .NO. NSCR AFR 18.60 2.1 g/hp-hr 1.0 g/hp-hr 2.1 g/hp-hr VOC NSCR AFR 8.84 CO PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. NSCR AFR 18.60 ❑ CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK. CHECK ALL BOXES THAT APPLY ❑ New or previously unreported source ❑ Requesting modification of existing permit ❑ Change in emissions, throughputs or. equipment ❑ Transfer of ownership * ® No change; APEN update only ❑ Other (Specify) * * Note: For transfer of ownership or company name change of a permit, you must also submit a Construction Permit Application form. Signature of Person Legally Authorized to Supply Data: yped Name and Title: e, Environmental En 4,2-4,7a2i _ DATE: Y%2 72 YEAR FOR WHICH THE ACTUAL DATA APPLIES: Date source began or will begin operation: 2000 THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this A $119.96 FILING FEE IS REQUIRED Colorado Dept. of Public Health & Environment APEN # of expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details see Regulation 3, Part A, H.C.1. FOR EACH NOTICE FILED. Send completed forms with fees to: Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-BI Denver, Colorado 80246-1530 For Information, Call (303) 692-3150 http://www.cdphe.state.co.us/ap/stationarv.aso Revised September 2004 NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM; (instructions on reverse side) Permit Number 95OPWE055 Company Name: Duke Energy Field Services, LP AIRS Number 123/0049/110 Plant Location: Section 24, R63W, T2N at 35409 County Road 18 Person to Contact: Ashley Campsie E -Mail Address: alcampsie@duek-energy.com County Weld Zip Code 80652 Phone 303-605-2023 Fax 303-605-1957 Chemical Abstract Service Number Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (Include units) Emission Factor Source Requested Emissions (lbs/yr) Actual Emissions from the Data Year (lbs/yr) 71432 Benzene A None 1.81% VOC SPECIATE 320.2 50000 Formaldehyde A None 0.047 g/hp-hr 831.4 75070 Acetaldehyde A None 0.32% VOC SPECIATE 56.6 * Use this form for reporting Hazardous Air Pollutants, Ozone Depleting Compounds, and other Non -Criteria Reportable Pollutant Year For Which The Actual Data Applies: Signature of Legally Authod Person (not a (endor or consultant) Ashley Campsie Name of a Responsible Official (please print) Date Environmental Engineer Title http://www.cdphe.state.co.us/ap/stationary.asp Revised September 2004 AIR POLLUTANT EMISSION NOTICE PERMIT No.: 95OPWE055 AIRS ID.: 123 /0049 /113 FIRM NAME: Duke Energy Field Services. LP MAIL ADDRESS: 370 17th Street. Suite 2500. Denver PLANT NAME & LOCATION Roggen Natural Gas Processing Plant. Section 24. R63W. T2N at 35409 County Road 18 0 REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE: PERSON TO CONTACT REGARDING THIS INFORMATION: Ashley Campsie GENERAL DESCRIPTION OF THIS PLANT'S FUNCTION: A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Through (% of Annual) ADDITIONAL INFORMATION OR REMARKS: Hours/Day 24 Days/Week 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of plant layout) Height 20 ft Diameter 0.66 ft Temperature 1033 F Flow Rate 4188 ACFM Velocity 12145 ft/min Moisture % Plant ID No. for Stack S-013 (C-160) C. FUEL INFORMATION No. 4 Refrigeration Compressor Engine Design Input Rate (106 BTU/hr) Kind of Fuel Burned Annual Fuel Consumption Fuel Heating Value: (BTU/lb, BTU/gal, or BTU/scf) Percent by Weight Seasonal Fuel Use (% of Annual Use) Space Htg (% Ann.) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep Nov Requested level Actual level (Data year level) Make: Waukesha 7.2 Natural Gas 65.84 MMscf 958 Btu/scf Neg. Neg. 25 25 25 25 Model: 806 hp L7042G Serial No.361724 D. PROCESS INFORMATION Raw Materials Used Raw Materials -Annual Consumption Design Process Rate (Specify Units/Hour) Finished Product Description Finished Product -Annual Output Requested level Actual level (Data year level) Description of Processing Unit Description Requested level Actual level (Data year level) Make: Model: Serial No.: E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE ACTUAL EMISSIONS ESTIMATION METHOD CHECK ALL BOXES THAT APPLY 0 New or previously unreported source 0 Requesting modification of existing permit ■ Change in emissions, throughputs or equipment • Transfer of ownership * • No change; APEN update only 0 Other (Specify) * Pollutant Type of Control Equipment Collection Efficiency Primary Secondary CONTROLLED UNCONTROLLED Particulate PM to SO. NO NSCR AFR 16.34 2.1 g/hp-hr * Note: For transfer of ownership or company name change of a permit, you must also submit a Construction Permit Application form. VOC NSCR AFR 7.78 1.0 g/hp-hr CO NSCR AFR 16.34 2.1 g/hp hr PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. 0 CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK. Signature of Person Legally Authorized to Supply Data: (:A311 -1-47/J u+ DATE:5(/7 7175' YEAR FOR WHICH THE ACTUAL DATA APPLIES: IT yped Name and Title: Ashley Campsie, Environmental Engineer Date source began or will begin operation: 1975 THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this A $119.96 FILING FEE IS REQUIRED Colorado Dept. of Public Health & Environment APEN # of expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details s Regulation 3, Part A, II.C.1. FOR EACH NOTICE FILED. Send completed forms with fees to: Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-Bl For Information, Call Denver, Colorado 80246-1530 (303) 692-3150 TITLE: Environmental Engineer STATE: CO PHONE: 303-605-2023 ZIP: 80202 , COUNTY: Weld E-MAIL ADDRESS: alcampsie@duek-energy.com http://www.cdphe.state.co.us/ap/stationary.asp Revised September 2004 NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM' (Instructions on reverse side) Permit Number 95OPWE055 Company Name: Duke Energy Field Services, LP AIRS Number 123/0049/113 Plant Location: Section 24, R63W, T2N at 35409 County Road 18 Person to Contact: Ashley Campsie E -Mail Address: alcampsie@duek-energy.com County Weld Zip Code 80652 Phone 303-605-2023 Fax 303-605-1957 Chemical Abstract Service Number Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (Include units) Emission Factor Source Requested Emissions (lbs/yr) Actual Emissions from the Data Year (lbs/yr) 71432 Benzene A None 1.81% VOC SPECIATE 281.7 50000 Formaldehyde A None 0.047 g/hp-hr 731.6 75070 Acetaldehyde A None 0.32% VOC SPECIATE 49.8 * Use this form for reporting Hazardous Air Pollutants, Ozone Depleting Compounds, and other Non -Criteria Reportable Pollutant GCS Signature of Legally Authorized erson (not a vend r or consultant) Ashley Campsie Name of a Responsible Official (please print) Year For Which The Actual Data Applies: Date Environmental Engineer Title http://www.cdphe.state.co.us/ap/stationary.asp Revised September 2004 AIR POLLUTANT EMISSION NOTICE PERMIT No.: 95OPWE055 AIRS ID.: 123 /0049 /119 FIRM NAME: Duke Energy Field Services, LP MAIL ADDRESS: 370 17ei Street. Suite 2500. Denver PLANT NAME & LOCATION Roggen Natural Gas Processing Plant. Section 24. R63W T2N at 35409 County Road 18 O REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE: PERSON TO CONTACT REGARDING THIS INFORMATION: Ashley Campsie GENERAL DESCRIPTION OF THIS PLANT'S FUNCTION: A. GENERAL INFORMATION Normal Operation of This Source Hours/Day 24 Days/Week 7 Weeks/Year 52 TITLE: Environmental Engineer Process Seasonal Throughput (% of Annual) Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep Nov 25 STATE: CO PHONE: 303-605-2023 ZIP: 80202 ; COUNTY: Weld E-MAIL ADDRESS: alcampsie@duek-energy.com ADDITIONAL INFORMATION OR REMARKS: B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of plant layout) Height 40 ft Diameter 0.83 ft Temperature 1340 F Flow Rate 4608 ACFM Velocity 8455 ft/min Moisture Plant ID No. for Stack S-019 (C-227) C. FUEL INFORMATION No. 5 Wet Gas Service Compressor Engine Design Input Rate (106 BTU/hr) Kind of Fuel Burned Annual Fuel Consumption Requested level Actual level (Data year level) Fuel Heating Value: (BTU/lb, BTU/gal, or BTU/scf) Percent by Weight Sulfur Ash Seasonal Fuel Use 5% of Annual Use) Dec -Feb Mar -May Jun -Aug Sep -Nov Space Htg (% Ann.) Make: Cooper Superior 6.2 Natural Gas 56.69 MMscf 958 Btu/scf Neg. Neg. 25 25 25 25 Model: 720 hp 8G825 Serial No.264009 D. PROCESS INFORMATION Description of Processing Unit Make: Raw Materials Used Raw Materials -Annual Consumption Description Requested level Actual level (Data year level) Design Process Rate (Specify Units/Hour) Finished Product Description Finished Product -Annual Output Requested level Actual level (Data year level) Model: Serial No.: E. POLLUTION CONTROL EQUIPMENT Pollutant Type of Control Equipment Primary Secondary Overall Collection Efficiency ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS - REQUESTED ABOVE CONTROLLED UNCONTROLLED ACTUAL EMISSIONS ESTIMATION METHOD Particulate PMIO SO, NO, NSCR AFR 14.60 2.1 g/hp-hr 1.0 g/hp-hr 2.1 g/hp-hr VOC NSCR AFR 7.0 CO NSCR AFR 14.60 PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. Signature of Person Legally Authorized to Supply Data: yped Name and Title: Ashley Campsie. Environmental Engineer ❑ CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK. CHECK ALL BOXES THAT APPLY ❑ New or previously unreported source ❑ Requesting modification of existing permit ❑ Change in emissions, throughputs or equipment ❑ Transfer of ownership * ® No change; APEN update only ❑ Other (Specify) * * Note: For transfer of ownership or company name change of a permit, you must also submit a Construction Pennit Application form. DATE: YEAR FOR WHICH THE ACTUAL DATA APPLIES: Date source began or will begin operation: THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details s Regulation 3, Part A, ILC.1. A $119.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send completed forms with fees to: Colorado Dept. of Public Health & Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-BI Denver, Colorado 80246-1530 APEN # of For Information, Call (303) 692-3150 _ httv://www.cdphe.state.co.us/aD/stationary.asp Revised September 2004 NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM" (Instructions on reverse side) Permit Number 95OPWE055 Company Name: Duke Energy Field Services, LP AIRS Number 123/0049/119 Plant Location: Section 24, R63 W, T2N at 35409 County Road 18 Person to Contact: Ashley Campsie E -Mail Address: alcampsie@duek-energy.com County Weld Zip Code 80652 Phone 303-605-2023 Fax 303-605-1957 Chemical Abstract Service Number Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (Include units) Emission Factor Source Requested Emissions (Ibs/yr) Actual Emissions from the Data Year (lbs/yr) 71432 Benzene A None 1.81% VOC SPECIATE 251.7 50000 Formaldehyde A None 0.047 g/hp-hr 653.5 * Use this form for reporting Hazardous Air Pollutants, Ozone Depleting Compounds, and other Non -Criteria Reportable Pollutant Year For Which The Actual Data Applies: ea127-%46 Signature of Legally Authorize (not a ve dor or consultant) Ashley Campsie Name of a Responsible Official (please print) l%74 - Date Environmental Engineer Title http://www.cdphe.state.co.us/ap/stationary.asp Revised September 2004 AIR POLLUTANT EMISSION NOTICE PERMIT No.: 95OPWE055 AIRS ID.: 123 /0049 / IT Ashley Campsie, Environmental Engineer THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details a� Regulation 3, Part A, H -C.1. FIRM NAME: Duke Energy Field Services, LP MAIL ADDRESS: 370 17th Street, Suite 2500. Denver PLANT NAME & LOCATION RoSgen Natural Gas Processing Plant. Section 24, R63W. T2N at 35409 County Road 18 ❑ REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE: PERSON To CONTACT REGARDING THIS INFORMATION: Ashley Campsie GENERAL DESCRIPTION OF THIS PLANT'S FUNCTION: A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Through t (% of Annual) ADDITIONAL INFORMATION OR REMARKS: Hours/Day 24 Days/Week 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of plant layout) Height 40 ft Diameter 1.67 ft Temperature 600 F Flow Rate 1344 ACFM Velocity 616 ft/min Moisture % Plant ID No. for Stack S-037 C. FUEL INFORMATION Hot Oil Heater Design Input Rate (106 BTU/hr) Kind of Fuel Burned Annual Fuel Consumption Fuel Heating Value: Percent by Weight Seasonal Fuel Use(% of Annual Use) Space Htg Requested level Actual level (Data year level) (BTU/lb, BTU/gal, or BTU/scf) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov (% Ann.) Make: Heat Recovery Corp 8.735 Natural Gas 79.87 MMsof 958 Btu/scf Neg. Neg. 25 25 25 25 Model: Serial No.H80273A D. PROCESS INFORMATION Description of Processing Unit Raw Materials Used Raw Materials -Annual Consumption Design Process Rate (Specify Units/Hour) Finished Product Description Finished Product -Annual Output Description Requested level Actual level (Data year level) Requested level Actual level (Data year level) Make: Model: Serial No.: TITLE: Environmental Engineer STATE: CO PHONE: 303-605-2023 ZIP: 80202 ; COUNTY: Weld E-MAIL ADDRESS: alcampsie@duek-energycom E. POLLUTION CONTROL EQUIPMENT Pollutant Type of Control Equipment Primary Secondary Overall Collection Efficiency ESTIMATED EMISSIONS ACTUAL AT THROUGHPUTS EMISSIONS CONTROLLED UNCONTROLLED 0.30 ESTIMATION METHOD Particulate 7.6 lb/mmscf PMto 0.30 7.6 lb/mmscf SO. 0.02 0.6 lb/mmscf N% VOC 3.99 100 lb/nunscf 0.22 5.5 lb/mmscf CO 3.35 84 lb/mmscf PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. ❑ CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK Signature of Person Legally Authorized to Supply Data: 4� S ,17 yped Name and Title: DATE: CHECK ALL BOXES THAT APPLY ❑ New or previously unreported source ❑ Requesting modification of existing permit ❑ Change in emissions, throughputs or equipment ❑ Transfer of ownership * ® No change; APEN update only ❑ Other (Specify) * * Note: For transfer of ownership or company name change of a permit, you must also submit a Construction Permit Application form. YEAR FOR WHICH THE ACTUAL DATA APPLIES: Date source began or will begin operation: 2000 A $119.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send completed forms with fees to: Colorado Dept. of Public Health & Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 APEN # of For Information, Call (303) 692-3150 http://www.cdphe.state.co.us/an/stationary.aso Revised September 2004 Appendix C Existing APENs AIR POLLUTANT EMISSION NOTICE FIRM NAME Duke Energy Field Services, LP — Roggen Natural Gas Processing Plant MAIL ADDRESS P.O. Box 5493. Denver PLANT NAME & LOCATION Roggen Natural Gas Processing Plant. Section 24. R63 W. T2N at 35409 County Road 18 HOME -BASE FOR PORTABLE SOURCES TITLE Environmental Engineer PHONE 720-944-9386 FEDERAL TAX LD. NO. 84-1041166 PERMIT No.: 95OPWE055 AIRS ID.: 123/0049/103 STATE: CO ZIP: 80217 COUNTY Weld PERSON TO CONTACT REGARDING THIS INFORMATION Ashley Campsie a A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Throughout (% of Annual) ADDITIONAL INFORMATION OR REMARKS: AOS Engine Replacement No. of Employees 12 Land Area 20 acres Hours/Day 24 Days/Week 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 B. STACK OR VENT INFORMATION (Identify below which stack if p ant has two or more; refer to attached sketch of plant layout) Height 40 ft Diameter 0.83 ft Temperature 1118 °F Flow Rate 7100 ACFM Velocity 13028 ft/min Moisture Ambient % Plant ID No. for Stack S-003 (C-159) C. FUEL INFORMATION Description of Combustion Unit Desip Input (10° BTU/HR) Rae Kind of Fuel Burned Annual Fuel Consumption Fuel Heating (BTU/lb, BTU/gal, BTU/SCF) Value: or Per Cent by Weight Seasonal Fuel Use (% of Annual Use) Space Htg (% Ann.) . Sulfur (X.XX%) Ash (XX.X%) Dec -Feb Mar -May Jun -Aug Sep -Nov Requested level First year level Data year level Compressor Engine 11.09 Natural Gas 101.4 MMSCF 958 BTU/SCF Neg. Neg. 25 25 25 25 Make/Model: 1350 hp Waukesha 7042 GSI Serial No. 337569 D. PROCESS INFORMATION Raw Materials Used Raw Materials -Annual Consumption Design Process Rate Finished Product Description Finished Product -Annual Output Requested level Data year level Description of Processing Unit Description Requested level Data year level (Specify Units/Hour) Make/Model: Serial No.: E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE ACTUAL EMISSIONS (DATA YEAR) ESTIMATION METHOD CHECK ALL BOXES THAT APPLY O New or previously unreported source* O Requesting modification of existingpennitj: ■ Change in emissions, throughputs or equipment: O Transfer of ownership (List previous owner in REMARKS section of box A.): O Previous APEN is expiring: O Request for Emission Reduction Creditt: O (Specify) Pollutant Type of Control Equipment Collection Efficiency CONTROLLED UNCONTROLLED Primary Secondary Particulate PM,o So. NO. NSCR 27.38 2.1 g/hp-hr * Complete all applicable portions of APEN t Complete "Requested Level" values for permit limits : Complete all information above box A, and those remaining portions which reflect changes VOC NSCR 13.04 1.0 g/hp-hr CO NSCR 27.38 2.1 g/hp-hr PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. CHECK HERE IONSINSTRUCTIONS EMISSIONS. SEE ' BACK. IF YOU WISH THE CALCULATE YOUR EMISSION ESTIMATES" N ON Asnminssom Signature of Person Legally Authorized to Su /Jt gay Supply (/f/J01/7 ( - DATE: g�i� 3 v- r DATA YEAR (See Instructions on Reverse): 2003 DATA yped Name and Title: Ashley Campsie, Environmental Engineer Ir Date source began or will begin operation: August 7.2003 THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this •A expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details see #egniation 3, Part A, § II.C.1. I.:\CPUFORMS.98A\GEN APEN.98A $100 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send completed forms with fees to: Colorado Dept. of Public Health & Environment APEN /1 1 of 1 Air Pollution Control Division ,s 4300 Cherry Creek Drive South, APCD-SS-B I For informal.° ,n, Call Denver, Colorado 80246-1530 (303) X32-3150 NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM FORM (instructions on reverse side) FIRM NAME: Duke Energy Field Services, LP — Roggen Natural Gas Processing Plant PROCESS DESCRIPTION: Natural Gas Processing Distance to nearest property line from stack (or release point)? <300 feet Stack height (or release point height)? 40 feet Chemical Abstract Service Number Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions (lbs/yr) Data Year Actual Emissions (Ibs/yr) 71432 Benzene A None 1.81% of VOC SPECIATE 471.9 50000 Formaldehyde A None 0.047 g/hp-hr 1225.4 75070 Acetaldehyde A None 0.32% of VOC SPECIATE 83.4 * Use this form for reporting Hazardous Air Pollutants, Ozone Deplet ng Compounds, and other Non -Criteria Reportable Pollutant THIS FORM IS AN ADDENDUM TO APEN # 1 (APPLICANT -PLEASE FILL IN APEN # IN THE LOWER RIGHT HAND CORNER OF APEN AND IN THE SPACE ABOVE) Signature: Date: 0/43 ❑ I would like the Division to calculate emissions of Non -Criteria Reportable Air Pollutants based on the production/consumption information listed on the APEN form. I:\CPUFORMS.98A\NCRP ADD.98A AIR POLLUTANT EMISSION NOTICE I PERMIT No.: 95OPWE055 FIRM NAME Duke Energy Field Services, LP — Roggen Natural Gas Processing Plant MAIL ADDRESS 370 17th Street, Suite 2500, Denver PLANT NAME & LOCATION Rogeen Natural Gas Processing Plant. Section 24. R63 W, T2N at 35409 County Road 18 HOME -BASE FOR PORTABLE SOURCES AIRS ID.:23/0049/107 STATE: CO Zip: 80202 COUNTY Weld PERSON TO CONTACT REGARDING THIS INFORMATION Ashley Campsie GENERAL DESCRIPTION OF THIS PLANTS FUNCTION TITLE Environmental Engineer PHONE 303-605-2023 FEDERAL TAX LD. NO. 84-1041166 A. GENERAL INFORMATION No. of Employees 12 Land Area 20 acres Normal Operation of This Source Hours/Day 24 Days/Week 7 Weeks/Year 52 Process Seasonal Throughiut (% of Annual) Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 ADDITIONAL INFORMATION OR REMARKS: AOS Engine Replacement B. STACK OR VENT INFORMATION (Identify below which stack if p ant has two or more; refer to attached sketch of plant layout) Height 20 ft Diameter 0.83 ft Temperature 1033 °F Flow Rate 4188 ACFM Velocity 7679 ft/min Moisture Ambient Plant ID No. for Stack S-007 (C-157) FUEL INFORMATION escription of Combustion Unit Design Input Rate (10° BTU/HR) Kind of Fuel Burned Annual Fuel Consumption Requested level First year level 65.84 MMSCF Data year level Fuel Heating Value: (BTU/lb, BTU/gal, or BTU/SCF) ompressor Engine 7.2 Natural Gas 958 BTU/SCF Per Cent by Weight Sulfur (X.XX%) Neg. Ash (XX.X%) Seasonal Fuel Use (% of Annual Use) Dec -Feb Mar -May Jun -Aug Sep -Nov Space Htg (% Ann.) Neg. 25 25 25 25 ake/Model: 806 hp Waukesha 7042 GU erial No. 319397 PROCESS INFORMATION cription of Processing Unit ake/Model: enal No.: Raw Materials Used Description Raw Materials -Annual Consumption Requested level Data year level Design Process Rate (Specify Units/Hour) Finished Product Description Finished Product -Annual Output Requested level Data year level E. POLLUTION CONTROL EQUIPMENT Pollutant Particulate Type of Control Equipment Primary Secondary Overall Collection Efficiency ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE CONTROLLED UNCONTROLLED ACTUAL EMISSIONS (DATA YEAR) ESTIMATION METHOD Mio So, Ox NSCR 16.34 VOC NSCR 7.78 2.1 g/hp-hr 1.0 g/hp-hr 2.1 g/hp-hr CO NSCR PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH OLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. 16.34 ❑ CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK. CHECK ALL BOXES THAT APPLY O New or previously unreported source* O Requesting modification of existing permit: • Change in emissions, throughputs or equipment$ O Transfer of ownership (List previous owner in REMARKS section of box A.)$ ❑ Previous APEN is expiring$ ❑ Request for Emission Reduction Creditfn O (Specify) * Complete all applicable portions of APEN t. Complete "Requested Level" values for permit limits $ Complete all information above box A, and those remaining portions which reflect changes gnature o erson Legally Authorized to Supply Data d Name and Title: Ashley Campsie, Environmental Engineer DATE: 7/zi/Q DATA YEAR (See Instructions on Reverse): 2004 Date source began or will begin operation: July 14, 2004 NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this ration date, whenever a permit limitation must be modified, whenever control equipment is an ed, and annually whenever a significant emission change occurs. For specific details see Regulation 3, Part A, § ILC.1. I:\CPUFORMS.98A\GEN APEN.98A A S100 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send completed forms with fees to: Colorado Dept of Public Health & Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 APEN #_j_ of For Information, Cal (303) 692-315 NON -CRITERIA REPORTABLE AIR POLLU'1r.dT EMISSION NOTICE ADDENDUM FORM* (instructions on reverse side) FIRM NAME: Duke Energy Field Services, LP — Roggen Natural Gas Processing Plant PROCESS DESCRIPTION: Natural Gas Processing Distance to nearest property line from stack (or release point)? <300 feet Stack height (or release point height)? 20 feet Chemical Abstract Service Number Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions (lbs/yr) Data Year Actual Emissions (Ibs/yr) 71432 - Benzene A None 1.81% of VOC SPECIATE 281.7 50000 Formaldehyde A None 0.047 g/hp-hr 731.6 75070 Acetaldehyde A None 0.32% VOC of SPECIATE 49.8 is corm for reporting Hazardous Air Pollutants, Ozone Depleting Compounds, and other Non -Criteria Reportable Pollutant THIS FORM IS AN ADDENDUM TO APEN # 1 (APPLICANT -PLEASE FILL IN APEN # IN THE LOWER RIGHT HAND CORNER OF APEN AND IN THE SPACE ABOVE) 416(f l Signature:Date: —lin /p y O I would like the Division to calculate emissions of Non -Criteria Reportable Air Pollutants based on the production/consumption information listed on the APEN form. I:ICPUFORMS.98ANCRP ADD.98A AIR POLLUTANT EMISSION NOTICE FIRM NAME Duke Energy Field Services. LP — Rbggen Natural, Gas Processing Plant PERMIT No.: 95OPWE055 - AIRS ID.: 123/0049/408 MAIL ADDRESS 370 17th Street. Suite 2500. Denver PLANT NAME & LOCATION Roggen Natural Gas Processing Plant. Section 24. R63 W. T2N at -5409 County Road 18 HOME -BASE FOR PORTABLE SOURCES STATE: CO 27P: 80202 COUNTY Weld PERSON TO CONTACT REGARDING THIS INFORMATION Ashley Campsie TITLE Environmental Engineer GENERAL DESCRIPTION OF THIS PLANTS FUNCTION PHONE 303-605-2023 A. GENERAL INFORMATION No. of Employees 12 Land Area 20 acres Normal Operation of This Source Hours/Day 24 Days/Week 7 Weeks/Year 52 Process Seasonal Throughout (% of Annual) Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 FEDERAL TAX LD. NO. 84-1041166 ADDITIONAL INFORMATION OR REMARKS: AOS Engine Replacement B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of plant layout) Height • 40 • ft Diameter 0.83 ft Temperature 1118 OF Flow Rate 7100 ACFM Velocity 13028 ft/min Moisture Ambient % Plant ID No. for Stack S-008 (C-161) C. FUEL INFORMATION Description of Combustion Unit Compressor Engine Design Input Rate (10° BTU/HR) Kind of Fuel Burned Annual Fuel Consumption Requested level First year level 101.4 MMSCF Data year level Fuel Heating Value: (BTU/lb, U , or BT/ CF) Make/Model: 1350 hp Waukesha 7042 GSI Serial No. 277154 11.09 Natural Gas 958 BTU/SCF Per Cent by Weight Sulfur (X.XX%) Neg. Ash ()O{.X%) Neg. Seasonal Fuel Use (% of Annual Use) Dec -Feb Mar -May Jun -Aug Sep -Nov Space Htg (% Ann.) 25 25 25 25 D. PROCESS INFORMATION Description of Processing Unit Make/Model: Serial No.: Raw Materials Used Description Raw Materials -Annual Consumption Requested level Data year level Design Process Rate (Specify Units/Hour) Finished Product Description Finished Product -Annual Output Requested level Data year level E. POLLUTION CONTROL EQUIPMENT Pollutant Particulate Type of Control Equipment Primary Secondary Overall Collection Efficiency ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE CONTROLLED UNCONTROLLED ACTUAL EMISSIONS (DATA YEAR) ESTIMATION METHOD PM,0 So, O, NSCR 27.38 OC NSCR 13.04 2.1 g/hp-hr 1.0 g/hp-hr 2.1 @/hp -hr CO NSCR 27.38 PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. ❑ CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK CHECK ALL BOXES THAT APPLY ❑ New or previously unreported source' ❑ Requesting modification of existing permitt$ • Change in emissions, throughputs or equipment$ ❑ Transfer of ownership (List previous owner in REMARKS section of box A.)$ ❑ Previous APEN is expiring: ❑ Request for Emission Reduction Creditt$ ❑ (Specify) * Complete all applicable portions of APEN t Complete "Requested Level" values for permit limits $ Complete all information above box A, and those remaining portions which reflect changes gnature of Person Legally Authorized to Supply Data G kge, y �o Name and Title: Ashley Campsie, Environmental Engineer DATE 1 DATA YEAR (See Instructions on Reverse): 2004 Date source began or will begin operation: February 11, 2004 HIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this rpiration date, whenever a permit limitation must be modified, whenever control equipment is tganged, and annually whenever a significant emission change occurs. For specific details see egulat on 3, Part A, § ILC.I. 1\CPUFORMS.98AtGEN APEN.98A A $100 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send completed forms with fees to: Colorado Dept. of Public Health & Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 802464530 APEN #_]_ ofd For Informatio; , Call (303) 692'3151 NON -CRITERIA. REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM FORM* (instructions on reverse side) FIRM NAME: Duke Energy Field Services, LP — Roggen Natural Gas Processing Plant PROCESS DESCRIPTION: Natural Gas Processing Distance to nearest property line from stack (or release point)? <300 feet Stack height (or release point height)? 40 feet Chemical Abstract Service Number Chemical Name Repotting Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions fibs/yr) Data Year Actual Emissions (Ibs/yr) 71432 Benzene A None 1.81% of VOC SPECTATE 471.9 I 50000 Formaldehyde A None 0.047 g/hp-hr 1225.4 75070 Acetaldehyde A ' None 0.32% of VOC SPECTATE 83.4 * Use this form for reporting Hazardous Air Pollutants, Ozone Depleting Compounds, and other Non -Criteria Reportable Pollutant THIS FORM IS AN ADDENDUM TO APEN # 1 (APPLICANT -PLEASE FILL IN APEN # IN THE LOWER RIGHT HAND CORNER OF APEN AND IN THE SPACE ABOVE) Signature: edov-Au Date: ZAZVe y ❑ I would liloe the Division to calculate emissions of Non -Criteria Reportable Air Pollutants based on the production/consumption information listed on the APEN form. I:\CPUFORMS.98A\NCRP ADD.98A AIR POLLUTANT EMISSION NOTICE PERMIT No::95OPWE055 AIRS ID.: 123/0`049/114 FIRM NAME: Duke Enerzv Field Services. LP MAn. ADDRESS: 370 17th Street, Suite 2500 STATE: Denver ZIP: $Q2Q2 PLANT NAME &LOCATION Roggen Natural Gas Processine_Plant_Section 24, T2N, R63W at 35409 County Road 18 COUNTY: Weld; O REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE: PERSON To CONTACT REGARDING THIS INFORMATION: Dirk Wold TITLE: Environmental Scientist PHONE: 303.605.2034 GENERAL DESCRIPTION OF THIS PLANT'S FUNCTION: Process Natural Gas E-MAn. ADDRESS: A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Throu (% of Annual) ADDITIONAL INFORMATION OR REMARKS: Hours/Day 24 Days/Week 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of plant layout) Height 20 ft Diameter 0.66 ft Temperature 1033 F Flow Rate 4188 ACFM Velocity 12145 ft/min Moisture Ambient % Plant ID No. for Stack S-014 (C156) C. FUEL INFORMATION Description of Combustion Unit Destigg Input Rate Annual Fuel Consumption Fuel Heating Value: Percent by Weight Seasonal Fuel Use r/o of Annual Use) Space Htg (10° B/hr) Kind of Fuel Burned Requested level Actual level (Data year level) (BTU/lb, BTU/gal, or BTU/scf) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov (% Ann.) Make: 806 hp Co1,Ip„asor Engine (P-014) 7.2 Natural Gas 65.84 958 Neg. Neg. 25 25 25 25 Model: Waukesha L-7042 C) Serial No. 335512 D. PROCESS INFORMATION Description of Processing Unit Raw Materials Used Raw Materials -Annual Consumption Design Process Rate Finished Product Finished Product -Annual Output Description Requested level (Data aye level level)Description (Specify Units/Hour) Requested level Actual year level) (Data level) Make: Model: Serial No.: E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS ACTUAL ESTIMATION CHECK ALL BOXES Pollutant Type of Control Equipment Collection Efficiency (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE EMISSIONS METHOD THAT APPLY ■ New Primary Secondary CONTROLLED UNCONTROLLED or previously unreported source ■ Requesting modification of existing permit Particulate �4 Change in emissions, throughputs or equipment PMuo • Transfer of ownership * SO, • No change; APEN update only ■ Other * NOx NSCR 16.34 2.1 g/bp-hr (Specify) VOC NSCR 7.78 1.0 g/hp-hr CO NSCR 16.34 2.1 g/hp-hr * Note: For transfer of ownership or company name change of a PLEASE USE APCNON-CRITERIA REPORTABLE AIR ,POLLUTANT ADDENDUM FORM TO REPORT SUCHM POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. 'Signature CHECK IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK permit, you must also submit a Construction Permit Application form. of Person Legally Authorized to Supply Data: a �� [ n DATE• / 9!/� y= YEAR FOR WHICH THE ACTUAL DATA APPLIES: 20oa Typed Name and Title: t Ashley Cantpsie, Environmental Engineer Date source began or will begin operation: September 16 2004 THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details see Regulation 3, Part A, ILC.1. A $119.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send completed forms with fees to: Colorado Dept of Public Health & Environment APEN #_ 1 of I Air Pollution Control Division — _.-=. — 4300 Cherry Creek Drive South, APCD-SS-B 1 For Info . Call Denver, Colorado 80146-1530 (303k u�2--3150 I,,+M•/4fn,Ilf. rr4nl,P C+a*P urn 11¢/nn/Ctatirmar\ AM'1 DAnne NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM* (Instructions on reverse side) Permit Number 95OPWE055 Company Name: Duke Energy Field Services, LP Plant Location: 35409 County Road 18 AIRS Number 123/0049/114 Person to Contact Dirk Wold E -Mail Address: dlwold@duke-energy.com County Weld Zip Code Phone 303-605-2034 Fax 303-605-1957 - Chemical Abstract Service ' Number Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (Include Emission Factor Requested Emissions Actual Emissions from the units) Source (lbs/yr) Data Year (lbs/yr) 71432 Benzene A None 1.81 % of VOC SPECTATE 281.7 50000 Formaldehyde A None 0.047 g/hp-hr 731.6 75070 Acetaldehyde A None 0.32 % of VOC SPECTATE 49.8 * Use this form for reporting Hazardous Air Pollutants, Ozone Depleting Compounds, and other Non -Criteria Reportable Pollutant Signature of Le Authorized Per on (not a vendor or consultant) Ashley Cainpsie Name of a Responsible Official (please print) httn://www.cdphe.state.co.us/ap/stationary.asp Year For Which The Actual Data Applies: 2004 Date Environmental Engineer Title Revised September 2004 AIR POLLUTANT EMISSION NOTICE FIRM NAME Duke Energy Field Services. LP — Rouen Natural Gas Processinli Plant MAIL ADDRESS P.O. Box 5493. Denver PLANT NAME & LOCATION Rogaen Natural Gas Processing Plant. Section 24. R6 W. T2N at 35409 County Road 18 HOME -BASE FOR PORTABLE SOURCES PERSON TO CONTACT REGARDING THIS INFORMATION GENERAL DESCRIPTION OF THIS PLANTS FUNCTION PERMIT No.: 95OPWE055 AIRS ID.:123/0049/115 STATE: CO ZIP: 80217 COUNTY Weld Ashley Camnsie TITLE Environmental Engineer PHONE 720-9449386 FEDERAL TAX LD. NO. 844041166 A. GENERAL INFORMATION No. of Employees 12 Land Area 20 acres Normal Operation of This Source Hours/Day 24 7 Days/Week Weeks/Year 52 Process Annual) Dec -Feb 25 25 Sep -Nov ADDITIONAL INFORMATION OR REMARKS: AOS Engine Replacement B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of plant layout) Height 40 ft Diameter 0.83 ft Temperature 1340 'F Flow Rate 4608 ACFM Velocity 8455 ft/min Moisture Ambient Plant ID No. for Stack S-015 (C-223) C. FUEL INFORMATION Description of Combustion Unit No. i Wet Gas Service Compressor Engine Design input Rate (10° BTU/HR) Kind of Fuel Burned Annual Fuel Consumption Requested level First year level 56.69 MMSCF Data year level Fuel Heating Value: (BTU/lb, , or BTU/SCF) Make/Model: 720 hp Cooper Superior 8G825 Serial No. 20669 6.2 Natural Gas 958 BTU/SCF Per Cent by Weight Sulfur (X.XX%) Neg. Ash 00 X%) Neg. Seasonal Fuel Use (% of Annual Use) Dec -Feb Mar -May Jun -Aug Sep -Nov Space Htg (o/o Ann.) 25 25 25 25 D. PROCESS INFORMATION Description of Processing Unit Make/Model: Serial No.: Raw Materials Used Description Raw Materials -Annual Consumption Requested level Data year level Design Process Rate (Specify Units/Hour) Finished Product Description Finished Product -Annual Output Requested level Data year level E. POLLUTION CONTROL EQUIPMENT Pollutant Particulate Type of Control Equipment Primary Secondary Overall Collection Efficiency ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE CONTROLLED UNCONTROLLED ACTUAL EMISSIONS (DATA YEAR) ESTIMATION METHOD PMio So, NO, NSCR 14.6 VOC NSCR 7.0 2.1 g/hp-hr 1.0 g/hp-hr 2.1 g/hp-hr CO NSCR PLEASE USEAPCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. Signature of Person Legally Authorized to Supply Data: 14.6 Typed Name and Title: Ashley Campsie, Environmental Engineer ❑ CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK '1Pr eliyn(hc - THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed and annually whenever a significant emission change occurs. For specific details see Regulation 3, Part A, § H.C.1. 1 \CPUFORMS.98A\GEN APEN.98A sianismaiminammos CHECK ALL BOXES THAT APPLY ❑ New or previously unreported source' O Requesting modification of existing permits • Change in emissions, throughputs or equipment ❑ Transfer of ownership (List previous owner in REMARKS section of box A.)$ ❑ Previous APEN is expiring$ O Request for Emission Reduction Credit -ft ❑ (Specify) * Complete all applicable portions of APEN t Complete "Requested Level" values for permit limits $ Complete all information above box A, and those remaining portions which reflect changes (DATE:.7/z/O3 DATA YEAR (See Instructions on Reverse): 2003 Date source began or will begin operation: June 26, 2003 A S100 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send completed forms with fees to: Colorado Dept. of Public Health & Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B 1 Denver, Colorado 80246-1530 APEN #_j_ ofd For Information, Celli (303) 692-3,I"'i9 Seasonal Throughput (% of Mar -May 1 Jun -Aug 25 25 NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM FORM* (instructions on reverse side) FIRM NAME: Duke Energy Field Services, LP — Roggen Natural Gas Processing Plant PROCESS DESCRIPTION: Natural Gas Processing Distance to nearest property line from stack (or release point)? <300 feet Stack height (or release point height)? 40 feet a Chemical Abstract Service Number Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions (ibs/yr) Data Year Actual Emissions (lbslyr) 71432 Benzene A None 1.81% of VOC SPECIATE 251.7 50000 Formaldehyde A None 0.047 g/hp-hr 653.5 * Use this form for reporting Hazardous Air Pollutants, Ozone Depleting Compounds, and other Non -Criteria Reportable Pollutant THIS FORM IS AN ADDENDUM TO APEN # 1 (APPLICANT -PLEASE FILL IN APEN # IN THE LOWER RIGHT HAND CORNER OF APEN AND IN THE SPACE ABOVE) Date: 7/Z. k3 ❑ I would like the Division to calculate emissions of Non -Criteria Reportable Air Pollutants based on the production/consumption information listed on the APEN form. I:\CPUFORMS.98A NCRP ADD.98A AIR POLLUTANT EMISSION NOTICE IRM NAME Duke Energy Field Services, LP — Roggen Natural Gas Processing Plant v1AIL ADDRESS P.O. Box 5493, Denver >LANT NAME & LOCATION Roggen Natural Gas Processing Plant, Section 24, R63 W, T2N at 35409 County Road 18 4O14E-BASE FOR PORTABLE SOURCES >ERSON TO CONTACT REGARDING THIS INFORMATION Ashley Campsie GENERAL DESCRIPTION OF THIS PLANTS FUNCTION PERMIT No.: 95OPWE055 AIRS ID.:123/0049/117 STATE: CO ZIP: 80217 COUNTY Weld TITLE Environmental Engineer PHONE 720-944-9386 A. GENERAL INFORMATION No. of Employees 12 Land Area 20 acres Normal • Hours/Day 24 eration of This Source Process Seasonal Through • /o of Annual) Dec -Feb 25 Days/Week 7 Weeks/Year 52 Mar -May 25 Jun -Aug 25 Sep -Nov 25 FEDERAL TAX LD. NO. 84-1041166 ADDITIONAL INFORMATION OR REMARKS: Engine Replacement B. STACK OR VENT INFORMATION (Identify below which stack if Height lant has two or more; refer to attached sketch of 40 Diameter 0.83 ft C. FUEL INFORMATION Description of Combustion Unit No. 3 Wet Gas Service Compressor Engine .fake/Model: 800 hp Superior 8G825 Serial No. 270269 D. PROCESS INFORMATION Descri . tion of Processin Unit sena ' o.: E. POLLUTION CONTROL EQUIPMENT Pollutant PM10 So, NO,, VOC CO Type of Control Equipment NSCR NSCR NSCR Temperature 1340 Secondary eF Flow Rate 4608 ACFM Design Input Rate (10 BTU/HR) Kind of Fuel Burned 6.4 Natural Gas Raw Materials Used Overall Collection Efficiency PLEASE IV APCD NON -CRITERIA REPORTABLE AIR POLLUTAW ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. Signature o Person Legally Authorize. to Supply Data: Typed Name and Title: Ashley Campsie, Environmental Engineer Descri .lion Velocity 8455 ft/min ant layout Moisture Ambient % Annual Fuel Consum. +on Requested level Data year level First year level Raw Materials -Annual Consumption Reuested level Data year level Plant ID No. for Stack S-017 (C-225) Fuel Heating Value: Per Cent by Weight (BTU/lb, BTU/gal, or BTU/SCF) Sulfur Ash (X.XX%) (XX.X%) 958 BTU/SCF Design Process Rate ESTIMATED EMISSIONS ACTUAL (TONS/YEAR) AT THROUGHPUTS EMISSIONS RE . UESTED ABOVE (DATA YEAR) CONTROLLED UNCONTROLLED S.eci Units/Hour 16.2 7.7 16.2 ESTIMATION METHOD 2.1 g/hp-hr 1.0 g/hp-hr 2.1 g,/hp-hr ❑ CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK. CMS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this :xpiration date, whenever a permit limitation must be modified, whenever control equipment s changed, and annually whenever a significant emission change occurs. For specific details lee Regulation 3, Part A, § ILC.1. I:\CPUFORMS.98A\GEN APEN.98A A $100 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send completed forms with fees to: Seasonal Fuel Use (% of Annual Use) Space Htg (/o Ann.) Dec- Mar -May Jun -Aug Sep Nov Feb Finished Product Description Finished Product -Annual Ou .. t Re uested level Data year level CHECK ALL BOXES THAT APPLY Cl New or previously unreported source* ❑ Requesting modification of existing pemtitt$ IN Change in emissions, throughputs or equipment$ ❑ Transfer of ownership (List previous owner in REMARKS section of box A.)$ ❑ Previous APEN is expiring$ . ❑ Request for Emission Reduction Creditt$ ❑ (Specify) * Complete all applicable portions of APEN t Complete "Requested Level" values for permit limits $ Complete all information above box A, and those remaining portions which reflect changes Date source began or will begin operation: May 2002 Colorado Dept of Public Health & Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 For Information, Call (303y 692-3150 NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM FORM (instructions on reverse side) FIRM NAME: Duke Energy Field Services, LP — Roggen Natural Gas Processing Plant PROCESS DESCRIPTION: Natural Gas Processing Distance to nearest property line from stack (or release point)? <300 feet Stack height (or release point height)? 40 feet Chemical Abstract Service Number Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions (Ibs/yr) Data Year Actual Emissions (Ibs/yr) 71432 Benzene A None 1.81% of VOC SPECIATE 279.6 50000 Formaldehyde A None 0.047 g/hp-hr 726.1 * Use this form for reporting Hazardous Air Pollutants, Ozone Depleting Compounds, and other Non -Criteria Reportable Pollutant THIS FORM IS AN ADDENDUM TO APEN # 1 (APPLICANT -PLEASE FILL IN APEN # IN THE LOWER RIGHT HAND CORNER OF APEN AND IN THE SPACE ABOVE) signature: I would like the Division to calculate emissions of Non -Criteria Reportable Air Pollutants based on the production/consumption information listed on the APEN form. :\CPUFORMS.98ANCRP ADD.98A AIR POLO' TTTANT EMISSION NOTICE PERMIT No.: AIRS ID.:_1^''0049/125 FIRM NAME: ' Duke Energy Field Services -LP MAIL ADDRESS: 370 17th Street, Suite 2500 PLANT NAME & LOCATION Roggen Natural Gas Processing Plant, 35409 County Road 18 HOME -BASE FOR PORTABLE SOURCE: PERSON TO CONTACT REGARDING THIS INFORMATION: Dirk Wold GENERAL DESCRIPTION OF THIS PLANT'S FUNCTION: Natural gas gathering and processing STATE: Colorado ZIP: 80202 ; COUNTY: Weld ; O REQUEST PORTABLE SOURCE PERMIT TITLE: Environmental Scientist PHONE: 303-605-2034 E-MAIL ADDRESS: dlwold@duke-energv.com A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Throug ut (% of Annual) ADDITIONAL INFORMATION OR REMARKS: Hours/Day 24 Days/Week 7 Weeks/Year 52 . Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of plant layout) Height ft Diameter ft Temperature F Flow Rate ACFM Velocity ft/min Moisture % Plant ID No. for Stack S-028 C. FUEL INFORMATION Description of Combustion Unit Design nnput Rate (10 BTU/hr) Kind of Fuel Burned Annual Fuel Consumption Fuel Heating Value: Percent by Weight Seasonal Fuel Use S% of Annual Use) Space Htg Requested level Actual level (Data year level) (BTU/lb, BTU/gal, or BTU/scf) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov (a/„ Ann) Make: Model: Serial No. D. PROCESS INFORMATION Description of Processing Unit Make: Four, Raw Materials Used Raw Materials -Annual Consumption Design Process Rate Finished Product Finished Product -Annual Output Description Requested level Actual level (Data year level) (Specify Units/Hour) Description Requested level Actual level (Data level) 300 bbl Condensate Tanks, P-028 Model: Condensate 2,000,000 year Serial No.: E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE ACTUAL EMISSIONS ESTIMATION METHOD CHECK ALL BOXES THAT APPLY ■ New or previously unreported source • Requesting modification of existing permit CA Change in emissions, throughputs or equipment ■ Transfer of ownership * ■ No change; APEN update only 0 Other (Specify) Pollutant Type of Control Equipment Collection Efficiency Primary Secondary CONTROLLED UNCONTROLLED Particulate PM to SO. NO, VOC 3.4 TANKS 4.0 * Note: For transfer of ownership or company name change of a permit, you must also submit a Construction Permit Application form. CO PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. In CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK. Signature of Person Legally Authorized to Supply Data: G DATE: /Wig*/ . YEARFOR WHICH THE ACTUAL DATA APPLIES: yped Name and Title: Ashley Campsie, Environmental En ineer --- - -- Date source b or will be egan gm operation: ] 974 THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be tiled prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever s significant emission change occurs. For specific details see Regulation 3, Part A, II.C.1. A $119.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send completed forms with fees to: Colorado Dept. of Public Health & Environment APEN # 1 of_1 Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B] For Information, Call Denver, Colorado 80246-1530 (303) 692-3150 _- httn'/Iuninv f•lrtlrla CM+. n .. i,,..j..r..a:_..---...... --- ...uuv..a w w. v V. uJ/ alJ/ J t4UV 11Q1 v Revised September 2004 AIR POI). T TTANT EMISSION NOTICE PERMIT No.: 95OPWE055 AIRS ID.: ' "0049/126 FIRM NAME: MAIL ADDRESS: Duke Energy Field Services, LP 370 17th Street, Suite 2500 PLANT NAME & LOCATION Roggen Natural Gas Processing Plant, 35409 County Road 18 HOME -BASE FOR PORTABLE SOURCE: PERSON TO CONTACT REGARDING THIS INFORMATION: Dirk Wold GENERAL DESCRIPTION OF THIS PLANT'S FUNCTION: Natural gas gathering and processing STATE: Colorado ZIP: 80202 ; COUNTY: Weld ; O REQUEST PORTABLE SOURCE PERMIT TITLE: Environmental Scientist PHONE: 303-605-2034 E-MAIL ADDRESS: dlwoldfaduke-enerttv.cor A. GENERAL INFORMATION Normal Operation of This Source Hours/Day 24 Days/Week 7 Weeks/Year 52 Process Seasonal Throug Dec -Feb Mar -May ut (% of Annual) Jun -Aug I Sep -Nov ADDITIONAL INFORMATION OR REMARKS: -- 1. l I B. STACK OR VENT Height INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of plant layout) ft Diameter ft Temperature F Flow Rate ACFM Velocity ft/min Moisture % Plant ID No. for Stack S-029 C. FUEL INFORMATION Description of Combustion Unit Make: Design Input Rate (106 BTU/hr) Annual Fuel Consumption Fuel Heating Value: Percent by Weight Seasonal Fuel Use (% of Annual Use) Space Htg Kind of Fuel Requested level Burned Actual level (Data year level) (BTU/lb, BTU/gal, or BTU/scf) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov (% Ann.) Model: Serial No. D. PROCESS INFORMATION Description of Processing Unit Make: Condensate Loadout, Raw Materials Used Raw Materials -Annual Consumption Design Process Rate Finished Product Finished Description Actual level Product -Annual Output Requested level (Data year level) (Specify Units/Hour) Description Requested level Actual level ruck F-029 Model: Condensate 2,000,000 (Data year level) Senal No.: E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONSESTIMATION Pollutant Type of Control yp Equipment Collection Efficiency (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE ACTUAL EMISSIONS METHOD CHECK ALL BOXES THAT APPLY Primary Secondary CONTROLLED UNCONTROLLED II New or previously unreported source Requesting modification of existing Particulate permit ►_ Change in emissions, throughputs or equipment PMio • Transfer of ownership * SO, ■ No change; APEN update only NO. IIIOther (Specify) VOC 5.8 AP -42 CO * Note: For transfer of ownership or company name change of a PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK. permit, you must also submit a Construction Permit Application form. Signature of Person Legally Authorized to Supply Data:DATE: �ify7�C 'Q ( A�a/6v 2ooa YEAR FOR WHICH THE ACTUAL DATA APPLIES: Typed Name and Title: Ashley Campsie, Environmental Engineer / Date source began or will begin operation: 1992 THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details see Regulation 3, Part A, MCA.Send A $119.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. completed forms with fees to: Colorado Dept. of Public Health & Environment APEN # 1 of 3 Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-Bl For Information, Call Denver, Colorado 80246-1530 (303) 692-3150 http://www.cdphe.state.co.us/an/ctatinnary acn _ _ evised September ;ON -CRITERIA REPORTABLE AIR POLL' ._,,,, ANT EMISSION NOTICE ADDENDUM" (Instructions on reverse side) Permit Number 95OPWE055 Company Name: Duke Energy Field Services, LP Plant Location: 35409 County Road 18 AIRS Number 123/0049/126 Person to Contact: Dirk Wold E -Mail Address: dlwold@duke-energy.com County Weld Zip Code Phone 303-605-2034 Fax 303-605-1957 Chemical Abstract Service Chemical Name Reporting Control Number Bin Equipment/ Efficiency Emission Factor Emission Factor Requested Emissions Actual Emissions from the (Include units) Source (lbs/yr) Data Year (lbs/yr) 71432 Benzene A None 2.0 % of V0C Mass balance 230 * Use this' form for reporting Hazardous Air Pollutants, Ozone Depleting Compounds, and other Non -Criteria Reportable Pollutant U' Signature of Legally Autjcorized Person (trot a vendor or consultant) . Ashley Campsie Name of a Responsible Official (please print) Year For Which The Actual Data Applies: 2004 ate Environmental Engineer Title htt");//www.cdphe.state.com.s/ap/stationarv.ast Revised September 2004 AIR POLY =UTANT EMISSION NOTICE PERMIT No.: 95OPWE055 AIRS ID- - 13/0049/ FIRM NAME: • Duke Energy Field Services, LP MAIL ADDRESS: 370 17th Street, Suite 2500 STATE: Colorado ZIP: 80202 ; PLANT NAME & LOCATION Roggen Natural Gas Processing Plant, 35409 County Road 18 COUNTY: Weld ; O REQUEST PORTABLE SOURCE PERMIT HOME -BASE FOR PORTABLE SOURCE: PERSON TO CONTACT REGARDING THIS INFORMATION: Dirk Wold GENERAL DESCRIPTION OF THIS PLANT'S FUNCTION: Natural gas gathering and processing E-MAIL ADDRESS: dlwold@duke-eneray.conl TITLE: Environmental Scientist PHONE: 303-605-2034 A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Throug ut (% of Annual) ADDITIONAL INFORMATION OR REMARKS: Hours/Day 24 Days/Week 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun -Aug 25 Sep -Nov 25 STACK OR VENT INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of plant layout) LB. Height - ft Diameter ft Temperature F Flow Rate ACFM Velocity ft/min Moisture % Plant ID No. for Stack S-031 C. FUEL INFORMATION Description of Combustion Unit Design Input Rate (106 BTU/hr) Kind of Fuel Burned Annual Fuel Consumption Fuel Heating Value: (BTU/lb, BTU/gal, or BTU/scf) Percent by Weight Seasonal Fuel Use (% of Annual Use) Space Htg (% Ann.) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov Requested level Actual level (Data year level) Make: Model: Serial No. D. PROCESS INFORMATION Raw Materials Used Raw Materials -Annual Consumption Design Process Rate (Specify Units/Hour) Finished Product Finished Product-Annua Output Description Requested level Actual level (Data year level) Description of Processing Unit Description Requested level Actual level (Data year level) Make: Pressurized liquids Loadout, P-031 Propane/Butane/Gasoline ,4 , 131,400,000 000 Model: Serial No.: E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE ACTUAL EMISSIONS ESTIMATION METHOD CHECK ALL BOXES THAT APPLY IN New or previously unreported source U Requesting modification of existing permit ■ Change in emissions, throughputs or equipment IN Transfer of ownership * No change; APEN update only ■ Other (Specify) * Pollutant Type of Control Equipment Collection Efficiency Primary Secondary CONTROLLED UNCONTROLLED Particulate PM to SO,,® NO. * Note: For transfer of ownership or company name change of a permit, you must also submit a Construction Permit Application form. VOC 5.0 Mass Balance CO PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. ■ CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK. Signature of Person Legally Authorized to Supply Data: n - n� J DATE:, /,, j6 y • ' sAPPLIES: 2004 yped Name and Title: Ashley Campsie, Environmental Engineer or will begin operation: 2000 THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details see Regulation 3, Part A, H.C.I. A $119.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. • Send completed forms with fees to: Colorado Dept. of Public Health & Environment APEN #_3_of 3 Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B1 For Information, Call _ Denver, Colorado 80246-1530 (303) 692-3150 _ http://www.cdphe.state.co.us/ap/stationary.asp Revised September 2004 AIR POLLUTANT EMISSION N( LICE AND APPLICATION FORM FOR GLYCOL DEHYDRATION UNITS (SEE REQUIREMENTS AND INSTRUCTIONS ON REVERSE SIDE) FIRM NAME Duke Energy Field Services, LP — Roggen Natural Gas Processing Plant MAIL ADDRESS P.O. Box 5493, Denver. CO 80217 GATHERING FIELD NAME Weld County PERSON TO CONTACT REGARDING THIS INFORMATION Ashley Campsie TITLE Environmental Engineer GENERAL DESCRIPTION OF THIS FACILITY'S FUNCTION Natural Gas Processing Plant PERMIT NO. COUNTY Weld PHONE 720-944-9386 FEDERAL TAX I.D. NO. 841041166 LEGAL AGENT FOR SERVICE Year installed 1976 Lease Name, Well Number Location (UTM), Lat, Long Unit ID or Serial # P-033 Manufacturer Unknown Design Capacity (MMSCFPD) 20.0 Acutal Thruput (MMSCFPD) 2.5 (requesting) Gas Pressure (psig) 880 Gas Temp. Wet Gas Water Content (lbs/MMSCF) Dry Gas Water Content (lbs/MMSCF) Glycol Recirculation Rate (gal/min.) Estimated Emissions VOC's- Tons/yr. Requested Emissions Voc's- Tons/year New, existing, or grandfathered source. 90-120 Saturated 7 lbs H20/MMSCF 1.998 gal/min 10.9 11.0 Existing Glycol Recirculation Pump powered by: ■ gas O electricity STARTING WITH DATA YEAR 1994, PLEASE USE APCD HAP ADDENDUM FORM TO REPORT HAZARDOUS AIR POLLUTANT EMISSIONS OR OTHER POLLUTANTS NOT LIS 1 b) ABOVE. O CHECK HERE IF YOU WISH 1'HJ _ . DIVISION TO CALCULATE YOUR EMISSIONS. Signature of Person Legally Authorized to Supply Data: Typed Name and Title: Ashley Campsie, Environmental Engineer l _ fr//?�.�e-Z DATE:2/2/ 0/ DATA YEAR (See Instructions on Reverse): Date source began or will begin operation: 1976 A SEPARATE APEN AND ADDENDUM FORM MUST BE FILED FOR EACH EMISSION POINT OR GROUP OF MULTIPLE EMISSION POINTS FOR ALL DEHYDRATORS WITH UNCONTROLLED ACTUAL EMISSIONS OF FIVE TONS PER YEAR OR MORE IN ATTAINMENT AREAS, OR TWO TONS PER YEAR OR MORE IN NONATTAINMENT AREAS, A CONSTRUCTION PERMIT IS REQUIRED. COMMENTS: OVER I:\CPUFORMS.98A\GLY DEHY.98A NON -CRITERIA REPORTABLE AIR POLLUINT EMISSION NOTICE ADDENDUM FORM 4 (instructions on reverse side) FIRM NAME: Duke Energy Field Services, LP — Roggen Natural Gas Processing Plant PROCESS DESCRIPTION: Triethylene Glycol Regenerator (S-034) Distance to nearest property line from stack (or release point)? <300 feet Stack height (or release point height)? 8 feet Chemical Abstract Service Number Chemical Name Reporting Bin Control Equipment/ Efficiency Emission Factor (include units) Emission Factor Source Requested Emissions (lbs/yr) Data Year Actual Emissions (Ibs/yr) 71432 Benzene A None GLYCaic 748.6 108883 Toluene C None GLYCalc 1906.8 1330207 Xylene C None GLYCaic 3327.2 * Use this form for reporting Hazardous Air Pollutants, Ozone Depleting Compounds, and other Non -Criteria Reportable Pollutant THIS FORM IS AN ADDENDUM TO APEN # 1 (APPLICANT PLEASE FILL IN APEN # IN THE LOWER RIGHT HAND CORNER OF APEN AND IN THE SPACE ABOVE) Signature: �..j99 a- Date: ❑ I would like the Division to calculate emissions of Non -Criteria Reportable Air Pollutants based on the production/consumption information listed on the APEN form. I:ICPUFORMS.98AW CRP_ADD.98A Page: 1 GRI-GLYCalc VERSION 4.0 - SUMMARY OF INPUT VALUES Case Name: Roggen Regen TEG File Name: \\dennas00\data\Environmental\Weld County\Title V Facilities\Roggen\Cool PTE.ddf Date: April 25, 2005 DESCRIPTION: Description: PTE w/ 3 MMSCFD - Cooling Cycle December 2004 Extended Gas Analysis Annual Hours of Operation: 4380.0 hours/yr WET GAS: Temperature: Pressure: 110.00 deg. F 925.00 psig Wet Gas Water Content: Saturated Component Conc. (vol %) Carbon Dioxide 3.0160 Nitrogen 0.5250 Methane 85.3510 Ethane 9.9340 Propane 1.0860 Isobutane 0.0310 n -Butane 0.0410 Isopentane 0.0060 n -Pentane 0.0070 n -Hexane 0.0010 Other Hexanes 0.0020 DRY GAS: Flow Rate: 3.0 MMSCF/day Water Content: 7.0 lbs. H2O/MMSCF LEAN GLYCOL: Glycol Type: TEG Water Content: Flow Rate: PUMP: 1.5 wt% H2O 2.0 gpm Glycol Pump Type: Gas Injection Gas Injection Pump Volume Ratio: 0.030 acfm gas/gpm glycol Page: 2 FLASH TANK: Flash Control: Vented to atmosphere Temperature: 75.0 deg. F Pressure: 80.0 psig Page: 1 GRI-GLYCalc VERSION 4.0 - AGGREGATE CALCULATIONS REPORT Case Name: Roggen Regen TEG File Name: \\dennas00\data\Environmental\Weld Facilities\Roggen\Cool PTE.ddf Date: April 25, 2005 DESCRIPTION: County\Title V Description: PTE w/ 3 MMSCFD - Cooling Cycle December 2004 Extended Gas Analysis Annual Hours of Operation: EMISSIONS REPORTS: 4380.0 hours/yr UNCONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane n -Hexane Other Hexanes 0.3071 0.4136 0.1755 0.0119 0.0234 0.0047 0.0076 0.0025 0.0036 7.370 9.928 4.213 0.286 0.561 0.113 0.183 0.059 0.086 0.6725 0.9059 0.3844 0.0261 0.0512 0.0104 0.0167 0.0054 0.0079 Total Emissions Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions FLASH TANK OFF GAS 0.9499 0.9499 0.2292 0.0025 22.798 22.798 5.501 0.059 2.0804 2.0804 0.5020 0.0054 Component lbs/hr lbs/day tons/yr Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane n -Hexane Other Hexanes 11.1649 3.4506 0.6095 0.0237 0.0333 0.0053 0.0064 0.0010 0.0020 267.958 82.814 14.627 0.569 0.798 0.128 0.155 0.024 0.048 24.4511 7.5568 1.3347 0.0519 0.0729 0.0116 0.0141 0.0022 0.0044 Total Emissions Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions 15.2967 15.2967 0.6812 0.0010 367.121 367.121 16.349 0.024 33.4998 33.4998 1.4919 0.0022 Page: 2 EQUIPMENT REPORTS: ABSORBER NOTE: Because the Calculated Absorber Stages was below the allowed, GRI-GLYCalc has set the number of Absorber Stages and has calculated a revised Dry Gas Dew Point. Calculated Absorber Stages: Calculated Dry Gas Dew Point: Temperature: Pressure: Dry Gas Flow Rate: Glycol Losses with Dry Gas: Wet Gas Water Content: Calculated Wet Gas Water Content: Calculated Lean Glycol Recirc. Ratio: Component minimum to 1.25 1.25 3.37 lbs. H2O/MMSCF 110.0 deg. F 925.0 psig 3.0000 MMSCF/day 0.0619 lb/hr Saturated 82.38 12.15 gal/lb H2O Remaining in. Dry Gas lbs. H2O/MMSCF Absorbed in Glycol Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane n -Hexane Other Hexanes FLASH TANK 4.07% 99.18% 99.92% 99.93% 99.79% 99.69% 99.59% 99.47% 99.48% 99.34% 98.97% 99.20% 95.93% 0.82% 0.08% 0.07% 0.21% 0.31% 0.41% 0.53% 0.52% 0.66% 1.03% 0.80% Flash Control: Flash Temperature: Flash Pressure: Component Vented to atmosphere 75.0 deg. F 80.0 psig Left in Glycol Removed in Flash Gas Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane 99.99% 33.24% 2.62% 2.68% 10.70% 22.36% 33.47% 41.27% 0.01% 66.76% 97.38% 97.32% 89.30% 77.64% 66.53% 58.73% Isopentane n -Pentane n -Hexane Other Hexanes REGENERATOR 47.28% 54.32% 71.46% 64.40% Page: 3 52.72% 45.68% 28.54% 35.60% No Stripping Gas used in regenerator. Component Remaining Distilled in Glycol Overhead Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane n -Hexane Other Hexanes STREAM REPORTS: 63.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.78% 0.72% 0.59% 1.26% 37.00% 100.00% 100.00% 100.00% 100.00% 100.00% 100.00% 100.00% 99.22% 99.28% 99.41% 98.74% WET GAS STREAM Temperature: Pressure: Flow Rate: 110.00 deg. F 939.70 psia 1.25e+005 scfh Component Conc. (vol%) Loading (lb/hr) Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane 1.74e-001 1.03e+001 3.01e+000 4.38e+002 5.24e-001 4.85e+001 8.52e+001 4.51e+003 9.92e+000 9.85e+002 1.08e+000 1.58e+002 3.09e-002 5.94e+000 4.09e-002 7.86e+000 5.99e-003 1.43e+000 6.99e-003 1.67e+000 n -Hexane 9.98e-004 2.84e-001 Other Hexanes 2.00e-003 5.68e-001 Total Components 100.00 6.17e+003 Page: 4 DRY GAS STREAM Temperature: Pressure: Flow Rate: 110.00 deg. F 939.70 psia 1.25e+005 scfh Component Conc. (vol%) Loading (lb/hr) Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane 7. 2. 5. 8. 9. 09e-003 99e+000 25e-001 54e+001 92e+000 1.08e+000 3.09e-002 4.08e-002 5.97e-003 6.96e-003 4.21e-001 4.34e+002 4.85e+001 4.51e+003 9.83e+002 1.57e+002 5.92e+000 7.82e+000 1.42e+000 1.65e+000 n -Hexane 9.91e-004 2 Other Hexanes 1.99e-003 5 .81e-001 .64e-001 Total Components LEAN.GLYCOL STREAM 100.00 6.15e+003 Temperature: 110.00 deg. F Flow Rate: 2.00e+000 gpm Component Conc. (wt%) Loading (lb/hr) TEG 9.85e+001 1.11e+003 Water 1.50e+000 1.69e+001 Carbon Dioxide 3.19e-011 3.60e-010 Nitrogen 3.33e-013 3.75e-012 Methane 9.14e-018 1.03e-016 Ethane Propane Isobutane n -Butane Isopentane n -Pentane n -Hexane Other Hexanes 8.51e-008 1.77e-009 6.55e-011 9.25e-011 3.30e-006 4.89e-006 1.30e-006 4.08e-006 9.58e-007 2.00e-008 7.38e-010 1.04e-009 3.7le-005 5.51e-005 1.47e-005 4.59e-005 Total Components 100.00 1.13e+003 RICH GLYCOL AND PUMP GAS STREAM Temperature: 110.00 deg. F Pressure: 939.70 psia Flow Rate: 2.07e+000 gpm NOTE: Stream has more than one phase. Component Conc. (wt%) Loading (lb/hr) Page: 5 TEG Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane n -Hexane Other Hexanes 9.59e+001 2.32e+000 3.81e-001 1.10e-002 9.92e-001 3.34e-001 6.79e-002 3.08e-003 4.90e-003 8.71e-004 1.22e-003 3.00e-004 4.88e-004 1.11e+003 2.68e+001 4.41e+000 1.28e-001 1.15e+001 3.86e+000 7.85e-001 3.57e-002 5.66e-002 1.01e-002 1.41e-002 3.46e-003 5.65e-003 Total Components 100.00 1.16e+003 FLASH TANK OFF GAS STREAM Temperature: Pressure: Flow Rate: 75.00 deg. F 94.70 psia 3.40e+002 scfh Component Conc. Loading (vol%) (lb/hr) Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane 2.31e-002 7.45e+000 4.94e-001 7.76e+001 1.28e+001 1.54e+000 4.55e-002 6.38e-002 8.21e-003 9.96e-003 3.74e-003 2.94e+000 1.24e-001 1.12e+001 3.45e+000 6.09e-001 2.37e-002 3.33e-002 5.31e-003 6.45e-003 n -Hexane 1.28e-003 9.89e-004 Other Hexanes 2.60e-003 2.01e-003 Total Components 100.00 1.84e+001 FLASH TANK GLYCOL STREAM Temperature: Flow Rate: 75.00 deg. F 2.02e+000 gpm Component Conc. (wt%) Loading (lb/hr) TEG Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane 9.74e+001 1.11e+003 2.36e+000 2.68e+001 1.29e-001 1.47e+000 2.94e-004 3.35e-003 2.70e-002 3.07e-001 3.63e-002 4.14e-001 1.54e-002 1.76e-001 1.05e-003 1.19e-002 Page: 6 n -Butane 2.05e-003 2.34e-002 Isopentane 4.19e-004 4.77e-003 n -Pentane n -Hexane Other Hexanes 6.74e-004 7.67e-003 2.18e-004 2.48e-003 3.20e-004 3.64e-003 Total Components 100.00 1.14e+003 REGENERATOR OVERHEADS STREAM Temperature: Pressure: Flow Rate: 212.00 deg. F 14.70 psia 2.36e+002 scfh Component Conc. Loading (volt) (lb/hr) Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane ..n -Butane Isopentane n -Pentane 8.86e+001 5.35e+000 1.92e-002 3.08e+000 2.21e+000 6.40e-001 3.30e-002 6.47e-002 1.05e-002 1.70e-002 9.92e+000 1.47e+000 3.35e-003 3.07e-001 4.14e-001 1.76e-001 1.19e-002 2.34e-002 4.73e-003 7.61e-003 n -Hexane 4.59e-003 2.46e-003 Other Hexanes 6.70e-003 3.59e-003 Total Components 100.00 1.23e+001 Page: 1 GRI-GLYCalc VERSION 4.0 - SUMMARY OF INPUT VALUES Case Name: Roggen Regen TEG File Name: \\dennas00\data\Environmental\Weld County\Title V Facilities\Roggen\Heat PTE.ddf Date: April 25, 2005 DESCRIPTION: Description: PTE w/3MMSCFD - Heating Cycle December 2004 Extended Gas Analysis Annual Hours of Operation: 4380.0 hours/yr WET GAS: Temperature: Pressure: 110.00 deg. F 925.00 psig Wet Gas Water Content: Saturated Component Conc. (vol %) Carbon Dioxide 2.9650 Nitrogen 0.5280 Methane 85.1460 Ethane 9.9070 Propane 1.2500 Isobutane 0.0640 n -Butane 0.0920 Isopentane 0.0230 n -Pentane 0.0160 Cyclopentane 0.0010 n -Hexane 0.0020 Cyclohexane 0.0010 Other Hexanes 0.0040 Benzene 0.0010 DRY GAS: Flow Rate: 3.0 MMSCF/day Water Content: 7.0 lbs. H2O/MMSCF LEAN GLYCOL: Glycol Type: TEG Water Content: Flow Rate: PUMP: 1.5 wt% H2O 2.0 gpm Glycol Pump Type: Gas Injection Page: 2 Gas Injection Pump Volume Ratio: 0.030 acfm gas/gpm glycol FLASH TANK: Flash Control: Vented to atmosphere Temperature: 75.0 deg. F Pressure: 80.0 psig Page: 1 GRI-GLYCalc VERSION 4.0 - AGGREGATE CALCULATIONS REPORT Case Name: Roggen Regen TEG File Name: \\dennas00\data\Environmental\Weld Facilities\Roggen\Heat PTE.ddf Date: April 25, 2005 DESCRIPTION: County\Title V Description: PTE w/3MMSCFD - Heating Cycle December 2004 Extended Gas Analysis Annual Hours of Operation: EMISSIONS REPORTS: 4380.0 hours/yr UNCONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Benzene 0.3066 0.4124 0.2017 0.0246 0.0523. 0.0181 0.0173 0.0058 0.0049 0.0121 0.0072 0.0775 7.358 9.898 4.840 0.590 1.255 0.434 0.416 0.140 0.118 0.289 0.172 1.859 0.6714 0.9032 0.4417 0.0538 0.1145 0.0396 0.0380 0.0127 0.0107 0.0264 0.0157 0.1696 Total Emissions Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions FLASH TANK OFF GAS 1.1403 1.1403 0.4213 0.0824 0.0775 27.368 27.368 10.112 1.976 1.859 2.4973 2.4973 0.9227 0.1803 0.1696 Component lbs/hr lbs/day tons/yr Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane 11.1600 3.4447 0.7015 0.0489 0.0746 0.0203 0.0147 0.0012 0.0020 0.0012 267.840 82.673 16.836 1.174 1.790 0.488 0.353 0.029 0.047 0.028 24.4404 7.5440 1.5363 0.1072 0.1633 0.0445 0.0322 0.0026 0.0043 0.0025 Other Hexanes Benzene 0.0040 0.0008 0.096 0.019 Page: 2 0.0088 0.0017 Total Emissions Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions EQUIPMENT REPORTS: 15.4739 15.4739 0.8692 0.0028 0.0008 371.374 33.8879 371.374 20.860 0.066 0.019 33.8879 1.9035 0.0061 0.0017 ABSORBER NOTE: Because the Calculated Absorber Stages was below the minimum allowed, GRI-GLYCalc has set the number of Absorber Stages to 1.25 and has calculated a revised Dry Gas Dew Point. Calculated Absorber Stages: Calculated Dry Gas Dew Point: Temperature: Pressure: Dry Gas Flow Rate: Glycol Losses with Dry Gas: Wet Gas Water Content: Calculated Wet Gas Water Content: Calculated Lean Glycol Recirc. Ratio: Component 1.25 3.37 lbs. H2O/MMSCF 110.0 deg. .F 925.0 psig 3.0000 MMSCF/day 0.0627 lb/hr Saturated 82.40 12.15 gal/lb H2O lbs. H2O/MMSCF Remaining Absorbed in Dry Gas in Glycol Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Benzene FLASH TANK 4.07% 99.18% 99.92% 99.93% 99.79% 99.69% 99.59% 99.47% 99.48% 99.34% 97.15% 98.98% 95.43% 99.20% 69.81% 95.93% 0.82% 0.08% 0.07% 0.21% 0.31% 0.41% 0.53% 0.52% 0.66% 2.85% 1.02% 4.57% 0.80% 30.19% Flash Control: Flash Temperature: Flash Pressure: Vented to atmosphere 75.0 deg. F 80.0 psig Page: 3 Component Left in Glycol Removed in Flash Gas Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Benzene REGENERATOR 99.99% 33.21% 2.62% 2.67% 10.69% 22.33% 33.43% 41.23% 47.23% 54.28% 82.90% 71.42% 91.51% 64.36% 99.04% 0.01% 66.79% 97.38% 97.33% 89.31% 77.67% 66.57% 58.77% 52.77% 45.72% 17.10% 28.58% 8.49% 35.64% 0.96% No Stripping Gas used in regenerator. Component Remaining in Glycol Distilled Overhead Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Benzene STREAM REPORTS: 62.99% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.78% 0.72% 0.57% 0.59% 3.37% 1.26% 5.02% 37.01% 100.00% 100.00% 100.00% 100.00% 100.00% 100.00% 100.00% 99.22% 99.28% 99.43% 99.41% 96.63% 98.74% 94.98% WET GAS STREAM Temperature: Pressure: Flow Rate: 110.00 deg. F 939.70 psia 1.25e+005 scfh Component Conc. (vol%) Loading (lb/hr) Page: 4 Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Benzene 1.74e-001 2.96e+000 5.27e-001 8.50e+001 9.89e+000 1.25e+000 6.39e-002 9.18e-002 2.30e-002 1.60e-002 1.03e+001 4.30e+002 4.88e+001 4.50e+003 9.82e+002 1.82e+002 1.23e+001 1.76e+001 5.47e+000 3.81e+000 9.98e-004 2.31e-001 2.00e-003 5.68e-001 9.98e-004 2.78e-001 3.99e-003 1.14e+000 9.98e-004 2.58e-001 Total Components 100.00 6.20e+003 DRY GAS STREAM Temperature: Pressure: Flow Rate: 110.00 deg. F 939.70 psia 1.25e+005 scfh Component Conc. (vol%) Loading (lb/hr) Water 7. Carbon Dioxide 2. Nitrogen 5. Methane 8. Ethane 9. Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Benzene 09e-003 4.21e-001 94e+000 4.27e+002 28e-001 4.87e+001 52e+001 4.50e+003 90e+000 9.80e+002 1.25e+000 1.81e+002 6.38e-002 1.22e+001 9.16e-002 1.75e+001 2.29e-002 5.44e+000 1.59e-002 3.78e+000 9.72e-004 2.25e-001 1.98e-003 5.63e-001 9.55e-004 2.65e-001 3.97e-003 1.13e+000 6.99e-004 1.80e-001 Total Components LEAN GLYCOL STREAM 100.00 6.18e+003 Temperature: 110.00 deg. F Flow Rate: 2.00e+000 gpm Component Conc. (wt%) Loading (lb/hr) TEG 9.85e+001 1.11e+003 Water 1.50e+000 1.69e+001 Carbon Dioxide 3.14e-011 3.54e-010 Nitrogen 3.35e-013 3.77e-012 Page: 5 Methane 9.13e-018 1.03e-016 Ethane 8.48e-008 9.55e-007 Propane 2.04e-009 2.29e-008 Isobutane 1.35e-010 1.52e-009 n -Butane 2.07e-010 2.33e-009 Isopentane 1.26e-005 1.42e-004 n -Pentane 1.11e-005 1.25e-004 Cyclopentane 2.94e-006 3.31e-005 n -Hexane 2.59e-006 2.92e-005 Cyclohexane 3.73e-005 4.20e-004 Other Hexanes 8.11e-006 9.14e-005 Benzene 3.63e-004 4.09e-003 Total Components 100.00 1.13e+003 RICH GLYCOL AND PUMP GAS STREAM Temperature: 110.00 deg. F Pressure: 939.70 psia Flow Rate: 2.07e+000 gpm NOTE: Stream has more than one phase. Component Conc. Loading (wt%) (lb/hr) TEG 9.59e+001 1.11e+003 Water 2.32e+000 2.68e+OO1 Carbon Dioxide 3.75e-001 4.34e+000 Nitrogen 1.11e-002 1.29e-001 Methane 9.91e-001 1.15e+001 Ethane 3.33e-001 3.86e+000 Propane 7.81e-002 9.03e-001 Isobutane 6.35e-003 7.35e-002 n -Butane 1.10e-002 1.27e-001 Isopentane 3.33e-003 3.85e-002 n -Pentane 2.78e-003 3.22e-002 Cyclopentane 6.10e-004 7.06e-003 n -Hexane 5.96e-004 6.90e-003 Cyclohexane 1.18e-003 1.36e-002 Other Hexanes 9.73e-004 1.13e-002 Benzene 7.12e-003 8.23e-002 Total Components 100.00 1.16e+003 FLASH TANK OFF GAS STREAM Temperature: Pressure: Flow Rate: 75.00 deg. F 94.70 psia 3.41e+002 scfh Component Conc. (vol%) Loading (lb/hr) Water 2.31e-002 3.75e-003 Carbon Dioxide 7.32e+000 2.90e+000 Nitrogen 4.97e-001 1.25e-001 Page: 6 Methane 7.74e+001 1.12e+001 Ethane 1.27e+001 3.44e+000 Propane Isobutane n -Butane Isopentane n -Pentane 1.77e+000 9.36e-002 1.43e-001 3.13e-002 2.27e-002 7.01e-001 4.89e-002 7.46e-002 2.03e-002 1.47e-002 Cyclopentane 1.91e-003 1.21e-003 n -Hexane 2.54e-003 1.97e-003 Cyclohexane 1.53e-003 1.16e-003 Other Hexanes 5.18e-003 4.01e-003 Benzene 1.13e-003 7.93e-004 Total Components 100.00 1.85e+001 FLASH TANK GLYCOL STREAM Temperature: Flow Rate: 75.00 deg. F 2.03e+000 gpm Component Conc. Loading (wt%) (lb/hr) TEG 9.74e+001 1.11e+003 Water 2.36e+000 2.68e+001 Carbon Dioxide 1.26e-001 1.44e+000 Nitrogen 2.96e-004 3.37e-003 Methane 2.69e-002 3.07e-001 Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes 3.62e-002 1.77e-002 2.16e-003 4.59e-003 1.60e-003 1.53e-003 5.14e-004 4.33e-004 1.10e-003 6.36e-004 4.12e-001 2.02e-001 2.46e-002 5.23e-002 1.82e-002 1.75e-002 5.85e-003 4.93e-003 1.25e-002 7.24e-003 Benzene 7.16e-003 8.15e-002 Total Components 100.00 1.14e+003 REGENERATOR OVERHEADS STREAM Temperature: Pressure: Flow Rate: 212.00 deg. F 14.70 psia 2.37e+002 scfh Component Conc. (vol%) Loading (lb/hr) Water Carbon Dioxide Nitrogen Methane Ethane 8.82e+001 9.92e+000 5.24e+000 1.44e+d00 1.93e-002 3.37e-003 3.06e+000 3.07e-001 2.20e+000 4.12e-001 Page: 7 Propane 7.32e-001 2.02e-001 Isobutane 6.77e-002 2.46e-002 n -Butane 1.44e-001 5.23e-002 Isopentane 4.01e-002 1.81e-002 n -Pentane 3.85e-002 1.73e-002 Cyclopentane 1.33e-002 5.82e-003 n -Hexane 9.10e-003 4.90e-003 Cyclohexane 2.29e-002 1.21e-002 Other Hexanes 1.33e-002 7.15e-003 Benzene 1.59e-001 7.75e-002 Total Components 100.00 1.25e+001 AIR PC_ LJUTANT EMISSION NOTICE I PERMIT No.: 95OPWE055 AIRS III,- _23/0049/ _ FIRM NAME Duke Energy Field Services, LP — Roggen Natural Gas Processing Plant MAIL ADDRESS P.O. Box 5493, Denver PLANT NAME & LOCATION Roggen Natural Gas Processing Plant, Section 24, R63 W, .T2N at 35409 County Road 18 HOME -BASE FOR PORTABLE SOURCES STATE: CO ZIP: 80217 COUNTY Weld PERSON TO CONTACT REGARDING THIS INFORMATION Ashley Campsie GENERAL DESCRIPTION OF THIS PLANTS FUNCTION TITLE Environmental Engineer PHONE 720-944-9386 A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Throughput (% of Annual) ADDITIONAL INFORMATION OR REMARKS: No. of Employees 12 Land Area 20 acres Hours/Day 24 , Days/Week 7 Weeks/Year 52 Dec -Feb 25 Mar -May L 25 Jun -Aug 25 Sep -Nov 25 B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of plant layout) Height 70 ft Diameter 1.0 ft Temperature °F Flow Rate ACFM Velocity ft/min Moisture Ambient % Plant ID No. for Stack S-0 f C. FUEL INFORMATION Description of Combustion Unit Design Input Rate (10 BTU/HR) Kind of Fuel Burned Annual Fuel Consumption Fuel Heating Value: (BTU/lb, BTU/gal, or BTU/SCF) Per Cent by Weight Seasonal Fuel Use (% of Annual Use) Space Htg Requested level First year level Data year level Sulfur (X.XX%) Ash (XX.X%) Dec- Feb Mar -May Jun -Aug Sep -Nov (% Ann.) Truck Blowdown to Flare 0.1 MMBtu/hr (pilot) Natural Gas 958 Btu/scf Neg. Neg. 25 25 25 25 Make/Model: INDAIR I -24 -HP -VS Flare Propane 1.464 MMsc 'yr 21365Btu/ib Serial No. NA D. PROCESS INFORMATION Raw Materials Used Raw Materials -Annual Consumption Design Process Rate . Finished Product Finished Product Annual Output Description of Processing Unit Description Requested level Data year level (Specify Units/Hour) Description Requested level Data year level Make/Model: Senal No.: E. POLLUTION CONTROL EQUIPMENT Overall ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE ACTUAL EMISSIONS (DATA YEAR) ESTIMATION METHOD CHECK ALL BOXES THAT APPLY • New or previously unreported•source* ■ Requesting modification of existing permitt$ Pollutant Type of Control Equipment Collection Efficiency Primary Secondary CONTROLLED UNCONTROLLED O Change in emissions, throughputs or equipment$ Particulate O Transfer of ownership PM,0 (List previous owner in REMARKS section of box A.)1 O Previous APEN is expiring So, O- '7Z— ❑ Request for Emission Reduction Credit -ft NO,, 9.16 AP -42 O (Specify) �l o 98 /o destruction * Complete all applicable portions of APEN t Complete "Requested Level" values for permit limits VOC Flare CO 31X193 3,gc/ AP -42 t Complete all information above box A, and those remaining PLEASE USE POLLUTANT POLLUTANTS APCD NON -CRITERIA REPORTABLE AIR ADDENDUM FORM TO REPORT SUCH OR POLLUTANTS NOT LISTED ABOVE. •portions CHECK S. SEE EMISSIONS. BACK. YOU WISH SITHE DIVISION INSTRUCTIONSTO YOUR "EMISSION ESTIMATES" ON which reflect changes Signature of Person Legally Authorized to Supply Data: �� I DATE: / /g/oz DATA YEAR (See Instructions on Reverse): 2002 Typed Name and Title: Ashley Campsie, Environmental Engineer Date source began or will begin operation: 2002 THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details see Regulation 3, Part A, § II.C.1. I:\CPUFORMS.98A\GEN APEN.98A A $100 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send completed forms with fees to: Colorado Dept. of Public Health & Environment APEN # 1 of 1 Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B I For Information, Call Denver, Colorado 80246-1530 (303) 692-3150 AIR POLL u TANT EMISSION NOTICE FIRM NAME Duke Energy Field Services, LP — Roggen Natural Gas Processing Plant MAIL ADDRESS P.O. Box 5493. Denver PLANT NAME & LOCATION Roggen Natural Gas Processing Plant Section 24. R63 W. T2N at 35409 County Road 18 HOME -BASE FOR PORTABLE SOURCES PERSON TO CONTACT REGARDING THIS Ii•rFORMATION Ashley Campsie GENERAL DESCRIPTION OF THIS PLANTS FUNCTION A. GENERAL INFORMATION Normal Operation of This Source Process Seasonal Through (% of Annual) ADDITIONAL INFORMATION OR REMARKS: No. of Employees 12 Land Area 20 acres Hours/Day 24 Days/Week 7 Weeks/Year 52 Dec -Feb 25 Mar -May 25 Jun Aug 25 Sep -Nov 25 PERMIT No.: 95OPWE055 AIRS ID.: 123/0049/122 STATE: CO ZIP: 80217 COUNTY Weld TITLE Environmental Engineer PHONE 720-944-9386 B. STACK OR VENT INFORMATION (Identify below which stack if p ant has two or more; refer to attached sketch of plant layout) Height NA ft Diameter NA ft Temperature NA °F Flow Rate NA ACM Velocity NA ft/min Moisture Ambient Plant ID No. for Stack S-025 C. FUEL INFORMATION Description of Combustion Unit Design Input Rate (10° BTU/HR) Kind of Fuel Burned Annual Fuel Consumption Requested level First year level Data year level Fuel Heating Value: (BBB � BTU/gal, or Per Cent by Weight Sulfur (X XX%) Ash (JOCX%) Seasonal Fuel Use (% of Annual Use) Dec -Feb Mar -May Jun -Aug Sep -Nov Space /• Ann.) e Make/Model: Serial No. D. PROCESS INFORMATION Description of Processing Unit ugitive VOC Emissions from equipment Leaks, NGL Skids P-025 ake/Model: Serial No.: Raw Materials Used Description Natural Gas Raw Materials -Annual Consumption Requested level Data year level Design Process Rate (Specify Units/Hour) Finished Product Description NGL/Residue Gas Finished Product -Annual Output Requested level Data year level E. POLLUTION CONTROL EQUIPMENT Pollutant Type of Control Equipment Primary Secondary Overall Collection Efficiency ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE CONTROLLED UNCONTROLLED ACTUAL EMISSIONS (DATA YEAR) ESTIMATION METHOD Particulate 0 Sox • Ox OC IDAR 16.8 EPA Protocol CO LEASE USE APCD NON -CRITERIA REPORTABLE AIR LLUTANT ADDENDUM FORM TO REPORT SUCH LLUTANTS OR POLLUTANTS NOT LISTED ABOVE. ignature of Person Legally Authorized to Supply Data: o CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSION& SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK. CHECK ALL BOXES THAT APPLY O New or previously unreported source* ■ Requesting modification of existing permitt: ■ Change in emissions, throughputs or equipment) O Transfer of ownership (List previous owner in REMARKS section of box A.)t 0 Previous APEN is expiring O Request for Emission Reduction Credits: ❑ (Specify) - * Complete all applicable portions of APEN t Complete "Requested Level" values for permit limits Complete all information above box A, and those remaining portions which reflect changes Name and The: Ashley Campsie, Environmental Engineer Ateli DATE: 4 > e fAz DATA YEAR (See Instructions on Reverse): Date source began or will begin operation: 1981 NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this iration date, whenever a permit limitation must be modified, whenever control equipment is anted, and annually whenever a significant emission change occurs. For specific details ins egulation 3, Part A, § II.C.1. I:`CPUFORMS.98A\GEN APEN.98A A S100 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send completed forms with fees to: Colorado Dept. of Public Health & Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-BI Denver, Colorado 80246-1530 APEN #j_ of 3 For Information, Call (303) 692-3150 Appendix D Portable Testing Monitor User's Manual and Manufacturer's Information 1 f, el c; e'er e; e; J' tri (E'I 1 '3 r • ei 1. ECOM - AC+ UsER.. MANUAL, ECOM AMERICA, LTD. 3075 Breckinridge Blvd., Suite 420 Duluth, Georgia 30136 Tel (770) 8060120- tf O 03 06 Fax (770) 806-0120 WebSite: www.ecomusa.com Version 97-1 -i- =ter •r-:�r0:xre { - IL≥ Table of contents l Section 1- Introduction Introduction 1 List of Abbreviations Optimal Performance 2 Unpacking 2 a 7 I Section 2 - Operation & Front Panel Features Getting Started on the ECOM-AC 3 Auto Zero / Auto Span 3 Fuel Selection 3 Contrast 4 Backlight 4 Zoom Feature 4 Printing S Draft Measurement 6 Smoke Measurement 6 Section 3 - Program Settings Unit of Measurement 7 O, Correction (Undiluted) 7 1 Boiler Water Temp. - 7 Air Pressure 7 Pistol Grip Probe Heating 7 Fuel Selection 7 I Clock Settings 8 Fuel Type Upload<PC 8 i RAM Card Time Settings 8 Datalogger On/Off 8 Section 4 - RAM Card Operation Formatting 9 1 Datalogger On/Off 9 i RAM Card Data Transfer to PC 10 a t a i Section S - Turning the analyzer off 13 Section 6 - Calibration of the ECOM-AC • Introduction 15 Calibration Principles 15 Auto Span and Auto Zero 15 Calibration Methods 15 Calibration Gas 17 Getting into Calibration Mode 17 Applying Cal ration Gas 18 Calibration yrotocols 18 Appendices I. Front Display Features 19 II. Technical Specifications 19 Ill. Trouble Shooting 22 IV. Change Name on Printout 23 V. Factory Service Records 24 -iv- Section . 1 INTRODUCTION 1.1 Introduction • The ECOM-AC is a microprocessor -based portable emission -analyzer that incorporates the latest technology for•accurate stack gas analysis. The ECOM-AC is suited for a variety of applications: Boiler/Burner Flue Gas Analysis; Engine Emissions Analysis; Source Testing; and Environmental Reporting of Stack Gas Parameters, among others. It also pro- vides measurements for O,, CO low (0-4,000 ppm), CO high (0-40,000 ppm), NO, NO,, SO,, and Combustibles, as well as Gas and Ambient Temperatures, Stack Draft, and Smoke. The calculated parame- ters indude CO,, Effdency, Excess Air, and Losses. An on -board printer allows for the memorization and printing of vital stack parameters at the touch of a button, while an RS232 interface streamlines communi- cation between the ECOM-AC and the optional remote digital display or a computer. One of the most reliable analyzers on the market, each ECOM-AC instrument is fully tested to strict quality control standards for performance and repeatability. 1.2 List of Abbreviations listed below are some abbreviations that are used throughout this manual. O2 Oxygen CO Carbon Monoxide Carbon Dioxide Nitric Oxide Nitrogen Dioxide Nitrogen Oxides Sulfur Dioxide Temperature Effidency Battery Room Temperature Flue Gas Temperature Boiler Water Temperature Percent of Losses of Efficiency Excess Air Inches of water gauge —for the draft sensor percent by volume Parts Per Million Milligrams Millivolts Volts Maximum CO, Value Signal indicating that the battery voltage for the NO sensor is low CO2 NO NO2 NO, SO2 Temp EFF Batt T.Room T.Gas T.Boiler Losses Lambda in w.g. ppm mg my V CO, Max NO -Limit Aorisrei -1- 1.3 Optimal Performance This section describes the general operation of the ECOM-AC and should help you understand the basic operation of the unit. The ECOM-AC is a portable gas measurement analyzer that enables qualified person- nel to collect accurate data for the servicing and maintenance of a variety of combustign sources. Designed as a portable analyzer only, the ECOM-AC is not recommended for continuous operation. Semi - continuous operation can be performed providing that all filters and the water trap receive general mainte- nance on a consistent basis. Upon receipt of your instrument, you should find the following components and accessory items contained 1.4 Unpacking within the carry case: 1. ECOM-AC analyzer with digital display, integral printer, and simple keypad control panel 2. 15 ft AC power cord and slot for smoke test 3. 12" coaxial probe assembly with connections for draft, gas, temperature gas, filter (other probe lengths available upon request) 4. -2 rolls of printer paper S. 50 smoke paper test discs 6. 10 spare filters for in -line sample hose 7. 15 ft. sample hose with pistol grip probe connection 8. single water trap assembly 9. ambient thermocouple with magnet 10. 2 keys for case latches 11. carry strap 12. user operational manual 13. rbr note pad 14. Quick Reference Guide -2- Section 2 OPERATION i FRONT PANEL FEATURES 2.1 Getting Started • To begin ECOM-AC operation, open the case by releasing the two latches located on the top panel next to Ithe carry handle, making sure that the instrument is lying flat so that the top of the case opens upward to I expose the internal components. Remove the water trap assembly and mount it on the slot provided on the top edge of the right side of the unit. The water trap (the bottle itself) should hang on the inside of the case with the tubing un- kinked and feeding directly into the instrument. Once the water trap is secured to the side of the unit, plug in the supplied power cord to an appropriate power outlet. To turn the instrument on, press the rocker switch marked I/O (for Instrument ON) until the display acknowledges power ON and reads: I i _ Fuel Type Function Confirm By <E> Calibrate. 3:00 For units with the optional RAM Card Data Processing Package, position the cursor on Gas Analysis and wait for the screen to read as follows: —> Press to Select Gas Analysis Data Bank/RAM Service Card Then select —>N0< —at the next screen. I--> AO< — YES 2.2 Auto Zero/Auto Span Once the ECOM-AC reaches full power, the instrument begins its automatic calibration procedure. The analyzer should be in fresh air during this period. During this process, the Oxygen sensor is automatically calibrated to ambient air, while the other sensors are zeroed and checked for proper signal outputs. The ECOM-AC will require approximately 180 seconds to complete the Auto Zero/Auto Span warm up period. 2.3 Fuel Selection During.the initial calibration and warm-up, you can select the type of fuel being used for this test. By pressing the up or down arrow keys, you can designate your desired fuel selection. The fuel selection only affects calculated parameters. ... ^L:U'�.. �.'a.'�. , 4'..'`,.Tr s,.�a�,�rFi;i.�F :`.`��'�r� a'��r. �'`,�'�ir�,.�i-iti^,'i.�.. � .. �.i�-•�,� Screen 1 Fuel Type Function, confirm by <E> Natural gas CO2 max = 11.7, Al/K = 0.35 After you view your fuel selection on the display, press the D button to enter. You may now insert the probe into the stack. • 2.4 Normal Measurement Mode After the instrument has completed its 180 -second calibration cycle, the display will read real-time emission values. The parameters displayed on the digital read-out and their corresponding rariges are as follows-. Screen 2 02 21.0% Eff. - C02 — % Losses -- CO 0 ppm Exc. air — % WO 0 ppm T. Gas 75 F NO2 0 ppm T. Air 75 F NOx 0 ppm Draft 0.09 i.w.g SO2 0 ppm Dew p• — F 2.5 Contrast Once the unit is up and running, you can adjust the contrast of the display by pressing and holding the button, on the keyboard until the desired contrast level is obtained. 2.6 Backlight gl The ECOM-AC is equipped with a backlit digital display for easy go yff. viewing. Simply press light to illumi- nate the display. To turn off, press again and the light will L7 Zoom Feature The O Key can double the display size. Pressing this key once changes the display from 8 lines to 4 lines. (See Screen 13) You may scroll through the different values being displayed by pressing the arrow keys. The up arrow key will allow you to view values for the 3rd line of display. The down arrow key will allow you to view values for the 4th line of display. Pressing the ©+ key again will change the display from 4 lines to 2 lines. (See Screen #4) You may scroll through the values being displayed by again pressing the arrow keys. The up arrow key will allow you to view values for the 1st line of the display. The down arrow key will allow you to view values for the 2nd line of display. -4- I 3 :a I 1 Screen 2 02 21.01 Eff. — 1 CO2 — 1 Losses — 1 CO 0 ppm Exc. air — 1 NO 0 ppm T. Gas 75 F NO2 0 ppm T. Air 75 F N0x 0 ppm Draft 0.09 i.w.g S02 0 ppm Dew p. — F Screen 3 02 21.0 % CO 0 ppm NOx 0 ppm T. Gas75 F Screen 4 02 21.0 CO .0 ppm Pressing again will return the display back to the initial 8 line display. (See Screen #2) 2.8 Printing To utilize the print facility of the ECOM-AC, you must press the key for the instrument to memorize a particular reading. When the memory function is activated, an a will appear on the LCD Display. Screen 5 02 21.01 Eff. — 1 m CO2 — 1 Losses - 1 CO 0 ppm Exc. air — 1 NO 0 ppm T. Gas 75 F NO2 0 ppm T. Air 75 F NOx 0 ppm Draft 0.09 i.w.g SO2 0 ppm Dew p. — F -5- After pressing the button, press the button located on the instrument key pad, then use the arrow keys to select "Start Printing". Press then key to print the memorized emission values.. After printing is complete, the display will again show real- time emission values. Remember to press the l :d again to dear the memory for the next test (this will removtr'the "m" from the top right corner of the LCD Display.) It is important to clear the memory before you begin the next test to ensure that only new information is entered into the memory when the next printing is performed. - 2.9 Draft Measurement The ECOM-AC is equipped with a high quality piezoresistive sensor for differential pressure measurements that are used to measure stack draft. To perform this function during normal operation, press the button on the front panel of the analyzer. The pump will shut off and the display will read: reset zero point: release draft hose then press mode At this point, remove the draft hose, then press B. The sensor will now auto -zero. Keep the probe in the stack for 15 seconds for reading to stabilize, then replace the draft hose. The display will now show the exact value for draft in inches of water from 0 to +1- 40.00 inches. Press the button to memorize the number, then press �S; (Escape) to return to the normal test mode. The memory has now stored the Draft reading which can be printed on the next test Once the display has returned to the normal operating mode, press the button to confirm the next gas test; all parameters, including draft, will be printed when the button is pressed. 2.10 Smoke Measurement The ECOM-AC probe is equipped with the fadlity to utilize a smoke paper test. When the trigger of the pistol grip handle is depressed, an opening in the sample line is exposed to allow for the insertion of the smoke test paper. To begin the smoke measurement, press the B key, then depress the trigger and place a piece of the supplied smoke test paper in the slot on the probe handle. To ensure a strong sample to be extracted for proper gas analysis and smoke test measurements, allow the pump to draw for 30 seconds continuously against the smoke test paper. To remove the smoke test paper, depress the trigger one more time and remove the paper from the slot in the probe. You can now determine the smoke level by comparing the smoke spot number with any standard smoke chart (e.g., Bacharach). To determine the smoke test num- ber, find the corresponding number that best matches your results. -6- 1' Section 3 PROGRAM SETTINGS You may alter the calculated and measured values by changing certain options via the ECOM-.AC s default settings. Press the button when in the flue gas measurement mode to access the option menu, then move the cursor to the relevant position and press CI . Screen 6 Adjustments Units ppm Fuel Type. Undiluted No Clock Set Ref. 02 3.0% Fuel Type, -PC Boil.temp. Air pres. 9.50psi Probe heat. No The following settings are possible: Units Factor for calculating gas concentration in: ppm = volume concentration (parts per million) mg/m, = mass concentration per volume #/mBtu = lbs. pollutant per mm/Btu Undiluted Calculation of gas concentration using reference oxygen. Undiluted: YES will correct toxic gas values (CO, NO, NO2) to a theoretical 0, level (i.e., 3%) selectedbelow under the Reference 02 section. When Undiluted: YES is activated, a U will appear after the toxic readings'on the display. Undiluted: NO will provide normal toxic readings to the actual 0, concentration. Formula for calculation: £rel =Emeas *(21 -0, rel) 21 - 02 meas Reference 0, Reference oxygen value for 0, correction (i.e., 3%). this will only calculate if Undiluted: YES is activated. Boiler temp Boiler feed water temperature as reference value Air pressure Barometric air pressure used in the dew point calculation Probe heating Probe heating on/off for Smoke Test Fuel Change fuel types without turning unit off -7- Clock Set the internal clock Fuel type<PC Upload fuel program from software Times Set the memory and output options for sending data to: RAM Card (set time intervals for storage, i.e., .02 to store every 2 seconds to the RAM Card): Data logger•must be YES to store. Centronics Port (direct parallel printer output) Data logger Press CI key to change YES/NO for Storage of data to RAM Card -8- i I 1 Section 4 RAM CARD OPERATION 4.1 Formatting the RAM Card (Optional) To format the RAM Card, erasing old data from RAM Card after downloading to a PC, follow this proce- dure: 1. Insert RAM Card into RAM Card slot. 2. From Normal Gas Measurement Mode, Press FE (See Screen #2) 3. Position cursor on Data Bank/RAM. Press n to select. (See Screen #7) 4. Position cursor on RAM Card. Press ® to select. (See Screen #8) S. Position cursor on Format. Press ® to select. (See Screen #9) 6. The display will read, Are you sure? (See Screen #9a) Position cursor on <Yes>. Press @I to select (kB counts down). 7. Formatting is now complete. Old data has been erased. 8. Press f5� twice and position cursor on Gas Analysis (See Screen #7) 9. Press to return to Normal Gas Measurement Mode. (See Screen #2) 4.2 Oatalogger On/Off To turn the RAM Card datalogger on/off, follow this procedure: 1. From the Normal Gas Measurement Mode (See Screen #2), Press Prog (Program from the front panel of the unit. 2. Position cursor on Times and Press ® to select. (See Screen #6) 3. Position cursor on RAM Card and Press to select. (See Screen #10) 4. Enter the desired data storage interval (e.g., .02 to store every 2 seconds). (See Screen #10a) S. Press ® (Escape) to return to Program screen. (See Screen #6) 6. Position cursor on Datalogger. NO. Press ® to change to Datalogger. YES 7. Press- FE (Escape) to return to Normal Gas Measurement Mode. (See Screen #2) 8. Unit is now storing data to the RAM Card. 9. To turn off the RAM Card datalogger, from Normal Gas Measurement Mode, press E . (See Screen #6) 10. Position cursor on Datalogger. YES and Press © to switch to Datalogger. NO NOTE: Each time Datalogger.YES/NO is switched on, a new storage file is stacked on top of any other data storage files until the RAM Card is reformatted, as described above. The number of data storage files will appear on screen as General Data. -9- f tl 4.3 RAM Card Data Transfer to PC To transfer RAM Card data to your PC, follow this procedure: 1. Make sure that the datalogger is switched off (Dataloggec NO) before beginning (from Section 2.11). 2. From Normal Measurement Mode (See Screen #2), Press and position cursor on Select Data Bank/RAM. Press to select. (See Screen #7) 3. Position cursor on Communication, and Press Q® to select. (See Screen 118) 4. Position cursor on Send General Data, and press to select (See Screen #11) S. Display will read: Get your PC ready for reception. Start the transmission by <E>. (See Screen #11 a) When using the ECOM Software package, go to the Main Menu of the ECOM Software program on your PC and select RAM Card Data Transfer to prepare it for the transmission of data from the RAM Card. Follow the instructions for PC Data Retrieval. 6. Once the PC is ready, return to the ECOM A+, and press n to send data to PC. 7. PC screen will count upward for information received, and ECOM-A+ screen will count downward for information downloading. Return to Data Processing on the ECOM Software program to set up a new file and to import from rbr into the Data Processing (ECOMX) formal Follow the instructions for Data Processing. Screen 1 Fuel Type Function, confirm by <E> Natural gas CO2 max = 11.7, Al/K = 0.35 Screen 2 02 CO2 CO NO NO2 NOx SO2 21.01 — _ 0 0 0 0 0. ppm ppm ppm ppm ppm Eff. — I Losses — 3 Exc. air — 1 T. Gas 75 F T. Air 75 F Draft 0.09 i.w.g Dew p. — F Screen 3 02 21.0 1 CO 0 ppm NOx 0 ppm T. Gas 75 F -10- Screen 4 02 21.0 1 CO 0 ppm Screen 5 02 21.01 Eff. — 2 m CO2 — i Losses — 1 CO 0 ppm Exc. air — NO 0 ppm T. Gas 75 F NO2 0 ppm T. Air 75 F NOx 0 ppm Draft 0.09 i.w.g SO2 0 ppm Dew p. — F Screen 6 Adjustments Units ppm Fuel Type Undiluted No Clock Set Ref. 02 3.05 Fuel Type, -PC Boil.temp. Air pres. 9.50psi Probe heat. No • :c„amiear,..• iy sy :4 f A ZI 4 •'r M.f .'4 ti Screen 7 Gas analysis Data bank/RAM Service card Select function, confirm by <E>! Screen 8 Select Visualize/Print Communication RAM Card Screen 9 Format Cancer Files Configurate Capacity: 512kB General data: 0 Reserved: 64kB Free: 448kB Screen 9a Format are you sure? NO > YES . <— Screen 10 Times Ram card 30 sec. Screen 10a RAM Card eq. 0.05 = 5 sec., 1.00 = 1 min. Input: _ -11- Screen 11 Communication Load data bank Send data bank Send general data Screen ila Send general data Get your PC ready for reception and start the transmission by <E>1 Terminate by <ESC>! Screen 12 Control V1.3 02 18256mV Run.time 20.28 hrs Co -17 mV NO -21 mV Serial no.AC 7722 NO2 -6 mV SO2 3 mV Service tel. <0770>806-0220 Screen 13 CO 0 ppm T.Gas 75.0 F NO 0 ppm T.Air 75.0 F. NO2 0 ppm Draft 0.00 i.w.g. S02 0. ppm Soot Measurement CO -1 — ppm 02 21.0 Screen 14 Co 100 ppm Input: - ppm N r Section S TURNING THE INSTRUMENT OFF 5.1 Turning the Instrument Off When turning the instrument off, remove the probe from the stack and allow any moisture that has gath- ered to drain into the water trap. Allow all toxic readings to return to zero and O, to 20.9% before switch- ing the ECOM-AC off. Upon being switched off, the instrument will automatically start a purging cycle that continues until the gas values reach zero, a process that prevents the instrument from being stored with gas in the line. The unit will not shut off until readings fall below 15 ppm. Replace the probe and hose into the supplied compartments. Make sure the water bottle is placed back in the supplied compartment for storage. Plug in the instrument and let it charge overnight. (the instrurrient must be turned off for the best charge to take place.) If the instrument is to be stored in excess of 1 month, it must be fully charged before storage and charged again for approximately 24 hours when taken out of storage. t 1 -13- r''- ,ti, ,+TS.eirAl%.%+YO��`'4.J. }r15!.b's:. 1...-,, ;...Fr 1 1 1 ��yy��..yl�wil+w.• Section 6 CALIBRATION OF THE ECOM-AC 6.1 Introduction Calibration is a distinctive feature of the ECOM AC. To guarantee accurate performance of the analyzer, the instrument uses microprocessor technology and quality sources of gas. The ECOM AC automatically calibrates to ambient Oxygen at 20.9%, and zeroes the appropriate toxic gas scales during its initial calibra- tion and warm-up phase. To guarantee accuracy, it is imperative that the instrument is turned on in dean air only prior to placing the probe in the stack. Span calibration for the sensors is described below. To Vibrate the ECOM-AC, you will need a Calibration Kit accessory, available separately from ECOM AMERICA, Ltd. You will also need Certified Calibration gas for CO, NO, NO2, and SO2, depending upon the type.of sensors your analyzer is equipped with. Although the toxic sensors are linear within their respective nominal ranges, the recommended calibrations levels should be as dose to the expected readings as possi- ble to achieve best results. IT IS VERY IMPORTANT THAT THE SENSORS ARE NOT OVER- OR UNDER -PRESSURIZED, THE FLOW OF THE GAS MUST EQUAL THE PULL OF THE PUMP, OR THE PUMP MUST BE ALLOWED TO PULL THE GAS AT ITS OWN RATE. The ECOM AC may be configured with 4-6 electrochemical sensors inducing Oxygen (0,), Carbon Monoxide (CO), Nitric Oxide (NO), Nitrogen Dioxide (NO,), Sulfur Dioxide (SO2), and Combustibles (C,H). Note: There are two sensors available for CO with ranges of 0-4,000 ppm (1 ppm resolution) and 0-40,000 ppm (S ppm resolution). 6.2 Calibration Principles Calibration of the sensors in the ECOM-AC is a quick and simple process. The analyzer is configured with an individual sensor for each specific gas to be measured. Sensors indude 0,, CO, with optional sensors for NO, NO2, SO2, and Combustibles. If you have any question as to the configuration of your instrument, check the printout or LCD to confirm the actual sensors found in the analyzes Note: There are no sensors for CO, or NO. as they are calculated values. 6.3 Auto Span and Auto Zero When the ECOM AC is switched on, it will perform a three -minute auto -zero of the toxic sensors (CO, NO, NO2, SO, and Combustibles) and auto -span for the O, sensor. The auto- spanning of the Oxygen sensor sets the calibration/span for the sensor. No calibration gas is used for calibrating the O, sensor. The auto - zero function sets the baseline or zero point for the toxic sensors. 6.4 Calibration Methods There are three recommended methods of calibration for the ECOM AC. In each method, the gas line should be connected to the instrument by placing the tubing over the end of the probe or by connecting it to the gas inlet of the instrument (Fittings for calibration are supplied in the ECOM calibration accessory kit) When checking for air leaks, it is best to connect the gas line to the probe. -15- 1. The first and most common method employs a regulated flow meter that is used as a vent in the gas line to ensure that the sensors are not over- or under -pressurized. This process connects the instrument, the gas cylinder and the flow meter using a "T" connector. Step T: Opel the an raw esdr Me lbw meta seals 1 U TFmWq Excess gat a mated ough r t Step 2: The how meter %mesa small amount dm wpiM payees arnomemuiq the sasaeml and ahem tie vamp to ambulate ieWwmaa'sidamtpesswe. 4AarreY mr1 2. The second method uses a regulated flow meter that is attached to the probe using an appropriately sized section of tubing. By connecting one end of the flow meter to the ECOM-AC, and leaving the other end open, you can first measure the flow rate of the pump, then connect the other end of the flow meter to the gas cylinder with the regulator opened to match the pull of the pump. 3W Connect rmaeo lbw meter to meas."a now or peep. -i- Caro tgas4Waave epee Rotator ente Pow meleeeWsswears poem .as mine —ewe toSeer smsa 3. A gas calibration bag can be used ,to draw gas into the instrument for calibration. By allowing gas to be drawn from the bag, rather than a cylinder, this method ensures the maintenance of the correct flow rate. We recommend that you use a gas bag 15 -liter or larger to ensure that enough gas is pre sent for the instrument to stabilize. -16- h9� Ird 1:. it atlio :.„„ GYM/N�bw.. ri _ Slap 1: NI the pas mg beau exelal as m**wadmleak infom bap. a 1 AMlowShe Wawa* to drawlne pas *mow bsp addr realms* SWAM 6.5 Calibration Gas During calibration, use a different calibration gas for each sensor (0, exduded) to ensure accuracy for each parameter, keeping in mind that accuracy standards for calibration gases can vary depending on the type • or dassification of the gas. Individual cylinders or certain blends can also be used for instrument calibra- tion. Some types include: a) Small disposable cylinders 6) . Larger refillable cylinders--NIST traceable c) larger refillable cylinders —EPA Protocol Gas Your application or instrument requirements may dictate which type of calibration gas to use, and your gas supplier can recommend which type to use for the balance of the gas (generally Nitrogen). Non -absorbing materials such as stainless steel regulators and non- absorbing tubing should be used to eliminate the loss of the gas sample —primarily NO, NO„ or SO,. For best results, the gas concentration should be as close to the expected levels of emissions as possible. Because each sensor is linear through a nominal range, one calibration gas concentration can often be used fora reasonably wide range of emission levels. For applications with extremely low or extremely high levels of emissions, with respect to the sensors operating range, the sensors should be calibrated as dose as pos- sible to the desired levels to be measured. 6.6 Getting into Calibration Mode From the normal measurement screen, press the CONTR button IS and the display will show the milli- volt signals for the sensors, as well as other instrument data. Take the magnet portion of the Ambient Temperature Thermocouple and place it just above the CAL HERE label on the analyzer. The unit will beep and enter into calibration mode. Screen 12 Control V1.3 02 18256mV Run time 20.28 hrs CO -17 mV NO -21 mV Serial no.AC 7722 NO2 -6 mV SO2 3 mV Service tel. <0770>806-0220 -1 7- • ;k 1 »sue ran 6.7 Applying Calibration Gas Position ,the cursor on the gas you wish to calibrate first and apply the gas at the correct flow rate by using any of the three methods mentioned earlier. Allow the reading to stabilize for a short period of time. Response time will vary depending on the sensor being calibrated. Generally, the reading will reach 90- 95% of full span very quickly, and the remaining 5-10% will then level off and stabilize. Screen 13 CO 0 ppm T.Gas 75.0 F NO 0 ppm T.Air 75.0 F NO2 0 ppm Draft 0.00 i.v.g. SO2 0 ppm Soot Measurement CO -1 — ppm 02 21.0 1 Once the reading has stabilized, press E to select the gas, and a new display will appear with the reading Jor the gas to be calibrated. Input the correct numerical value of the calibration gas via the analyzers key- pad. The sensor may be calibrated up or down. Screen 14 CO 100 ppm Input: - ppm Press E to confirm and the unit will return to the previous screen. That sensor has now been calibrated. Position the cursor on the next sensor to be calibrated, and repeat these steps with the appropriate calibra- tion gas for each sensor. Note: The O, level should fall to near 0.0% when applying a gas with a Nitrogen balance as the O, is being displaced by the N,. An excellent method for checking air leaks and calibration is to apply the gas throughout the entire sampling system, induding the probe and sample line. After calibration of each sen- sor is completed, press ESC (Escape) twice to return to normal measurement mode. 6.8 Calibration Protocol Verification of the portable analyzer for calibration, drift, span, interference, and other parameters, before and after an emissions compliance test may be required by the local regulatory agency. You can ensure accurate and repeatable results by following an established protocol. Check with the agency for any exist- ing protocols they may prefer or acknowledge. -18- Appendix I FRONT PANEL DISPLAY FEATURES Contrast Control Mummy for Printing Illuminate Oisolar Zoom Display co seed Print Options Prink( Paper Advance P� Pressure soot Oodles V) Measurement Mode Ateasurement Special CO Mode Cursor Up Cursor Down Escape Enter Appendix II TECHNICAL SPECIFICATIONS PHYSICAL Instrument: 19' x 16' x 6.5" Aluminum Carry Case with locks Probe: 13' length x 3/8" O0 Inconel Probe with aluminum handle, pistol grip handle with threaded quick disconnect probe connection Hose: 15' high temperature flex hose with thermocouple wire. Additional lengths available. Weight 28 lbs. ELECTRICAL: AC: 110 V 60 Hz/220V 50 Hz Standard. User selectable on panel. 1 Amp. Batteries. Lead acid rechargeable —life 1.5-2.0 hours MISCELLANEOUS: Pump Draw: Flow rate 2.5 LPM (approximately) Display 24 Character, full fine backlit display with adjustable display contrast and zoom. Displays all parameters simultaneously. OPERATING 'TEMPERATURE: Instrument: 20 F to 122 F Probe: 0 F to 1800 F MEASURED PARAMETERS: 1. OXYGEN Range- 0-21% -19- Sensor Type - Sensor Life - Accuracy - Resolution - Electrochemical 2 years 2% of reading .1% 2k CARBON MONOXIDE Range - Sensor Type - Sensor Life - Accuracy - Resolution - 0 -4000 ppm Electrochemical 3 years* 4% of reading 1 ppm 28. CARBON MONOXIDE Range - Sensor Type - Sensor Life- Accuracy- Resolution - 3. NITRIC OXIDE Range - Sensor Type - Sensor Life- Accuracy- Resolution - 0 -40,000 ppm Electrochemical 3 years+ 4% of reading 5 ppm 0-4000 ppm Electrochemical 3 years* 4% of reading 1 ppm 4. NITROGEN DIOXIDE Range- 0-500 ppm Sensor Type- Electrochemical Sensor Life- 3 years* Accuracy- 4% of reading Resolution- 1 ppm 5. SULFUR DIOXIDE Range- • 0-5000 ppm Sensor Type- Electrochemical Sensor Life- 3 years* Accuracy- 4% of reading Resolution- 1 ppm • i -2O- 6. COMBUSTIBLES Range- 0-6% Sensor Type- Pellister Sensor Life- , 3 years Resolution- .01% 7. AMBIENT TEMPERATURE Range- 0-250 Degrees F Sensor Type- IC Sensor Sensor Life- 10 years Accuracy- 3 F Resolution- 1 F 8. STACK TEMPERATURE Range- 0-1800 F Sensor Type- Type K Thermocouple Sensor life- 10 years Accuracy- 3 F Resolution- 1 F 9. STACK DRAFT Range- 0-40.00" I -1,O Sensor Type- Piezoresistive Electronic Sensor Sensor Life- 10 years Accuracy- 2% of Reading Resolution- .01 1-120 10. SMOKE MEASUREMENT Scale- 0-9 spot method 11. TIME/DATE - Time in hours, minutes, and seconds Date in day, month, year * Depends on usage and gas concentration CALCULATED PARAMETERS: 1. CARBON DIOXIDE (CO2) Range- 0-40% Resolution- .1% Formula: CO, = CO, max * (1 - O, meas.) 21 2. COMBUSTION EFFICIENCY Range- 0-100% Resolution- • 1% Formula: ETA = 100 - q, 3. EXCESS AIR Range- Resolution - Formula: 4. LOSSES Range- Resolution - Formula: (LAMBDA) 0-50% .01% Lambda =1 + 02 21- 02 0-100% 1% q, = (A2+ B) * (f gas - T air) 21 - 02 Appendix II! TROUBLE SHOOTING 1. Purple beads are for removal of NO,/S02 for the CO sensor only. When replacement is necessary, they will turn brown, then white. 2. A high Oxygen reading could be the result of an air leak somewhere in the sampling system. Check all tubing, connections, 0 rings, water trap assembly, sample line, and probe. 3. By using a calibration gas with a Nitrogen balance, the O2 will be displaced or purged to a reading of near 0.0%. This serves as an excellent method of checking the integrity of the sampling system for leaks. 4. A low or high reading on calibration gas could be the result of improper flow. Be sure not to over/under pressurize the sensors: Follow all calibration instructions for applying gas. 5. The filter on top of the water trap can be saturated with water. Be sure to check this periodically as it will. cause the pump to work against this blockage. 6. After a printout has finished, be sure to press m again to remove the prior test from the short term memory. 7. When connecting a unit to a PC via an RS232 cable, the pins of the cable must be modified or a null modem used in order for the two to be compatible. 8. Use the trigger on the pistol grip probe only for inserting the smoke dot paper. Pulling the trigger during a normal emission test will result in an air leak causing diluted toxic readings and high 02. -22- or aa fC � r 4 eywill .atl )f near coder kwill' II luring a 9. A small magnet used for accessing calibration is located at the end of the Ambient Thermocouple. 10. A proper pre -calibration test will result in correct emission readings. An improper pre-test calibration will result in incorrect stack/exhaust readings and may invalidate any subsequent testing. Appendix IV CHANGING NAME ON PRINTOUT Equipment required: 1. ECOM-AC+ analyzer . 2. Computer (PC) 3. RS232 cable w/ null modem or modify pin connections 2-3, 3-2, 5-5 4. EC0M Software Instructions: 1. Connect the RS232 cable to the PC and to the ECOM analyzer 2. Install the ECOM Software to the PC 3. Start the ECOM Software program and go to Main Menu 4. Position cursor on Name to Printout and stop. S. Turn the ECOM AC+analyzer on. 6. Before 10 seconds has elapsed, place magnet on "Cal Here" label (same as calibration position). 7. The analyzer will _ read Gas Analysis. 8. Return to PC and select Name to Printout 9. PC screen will read: Zeile 1: (enter information) Zeile 2: Zeile 8: Note: If only two lines of information are needed, use the first two lines (Zeile 1&2), and "Return" through the other lines leaving them blank. 10. Once "return" is entered on Zeile 8, the PC will show "OK" in a few seconds. 11. To test the name, turn the ECOM-AC+ off and then back on, allowing the unit to complete its 3 -minute calibration cycle. 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( 1 r ` , /, R• i/1 r 11 tic / Hi .....• 4 Rands I n\ I I 1 I c C 1 I I \ : ,7 / V ....1 II Cr1/411 ' ' I - - w t • 0 / . 1 1 S .T ........(\if 4. - - all - l'. vet P t 1 ' t _ t499 Ntiili ge i J5 E ! . i A 6- -''dc) � . (4.4_ pemit• la I op, irx. i_ . . , IS` • • --: A iierrasbtir : 4 , 'DO a, \n.4 I !� ' Mb SAND ?Mkt �`♦ re . %S I ' • Farm ' f, L. 7.8 _ t ' A.„ to ,I at i � l- I -er �� " • 1 I VA _ • .,7 lir 0 ,.... .• i Farm1 1 •-/ •• I \ ' s. i 4Id ,? w, •IT t _ 7+ ,t all 0,ht .. e• I • SdBf �s, 12 jet Pros IIQv� ,' _.I is all :LP' fl : ' % k i 4658♦ I ) 049 2 J11 Zit j `,, 4 • I L tr - —�--- r Driving Directions: Hwy 76 East to exit 4 423 5 • 1 i Al ,ti 2li : for city of Roggen (CR 73). Exit and go i _ �-- — _ • f a _ .. . . .__ right on 73 approx. 4-5 miles to CR 18. . . 4 f3�ly ' �-4 - • — I •,4 Turn right andplant is approx. 3/4 mile on Farm Far ' �i PP • �� 1.15224trt ;; the right. 14 N. 11 life , f 1 Re oir intui\ - -ri A (440 I -cg e t -les. ' ... , _ _ __ , a • i U Smiles view( 0 5 kilometers 40104A1 Greeley Roggen - - E Source: USGS 1 :250,000 scale N Weld County, Colorado Drawn by: JMW Mk Duke Enemy Zone 13 UTMH 552242m UTMV 4440800m Revised by: DKP '' B I Field Services., Date 03-27-00 _ ENVIRONMENTAL s A Duke Energy Company AFFAIRS DEPARTMENT . 1 i . 1 . . , ? . . . 6 . . . i . .. . i , V _, , 17 . ._ i3 . . 14 '? . . 18 . . . 1i . 18 . . 1i . . 3' , . T , . . 2i . Z4 . . . 25 0A1E x X X manna • • E▪ 436 ED• _ KIR idraG w SA N0PSS'IYE 1.31 NEI CAN SANE S.Na t eum C—sl1111 1111 lillIllil III 1 • • • B ]aa2 fill - n to iii I ® aq_ o -AN REMI III LEK E ■ Nam TIT j .94=20.21 TVIWISPIGFIGI II ■ SATE ANS 12 20 217 Z6 S 0r er 17 6 I.oa$ . 30 -. . i1 , . . I . . , W KIP SEER 109![ rase • a • • D O • ■ ❑ . • 1 _ •1 a C 1.1111111111 SNE am ME ESE UNPIN • . .r •S .4=is - • • ge, _ ■ ■ 1i■■t IIIIIII llllliR I ASF7 IN -0 Lim IB�m sa v •. r ItOI . I0' POT111MO81 _. r BOUNCIER -w! REMAKE SA1AE WgEE 0'-1 —1 0 0 0. fa _ 6POWB1*VIt: 111111111r717 1 1 1 1 1 1 1 1■��■U■■►■■■■■JI■ E■a lum.ol0 .EN�N. --La I f E / I0 EEE O EM Em▪ E YE S EE EBI ENT SOS _ NOT POSE EVDI , E E E E Mew a s• OM won SNIT NW INS IN 1010 M1 DPW AE ,MINE 1A0 NEO(s SP .. L •�'• '• N1O°°56u19 �� ❑ It] Na NENE 1010Nr 1010 MI 0 0BERME RON SfA I1010N RN IlEC OMEN WOE wriatalilrIE NU (WO raw WM SWAM9N0 1N NEC X 1OOOO _1N' P SA. NS MT -3 11-4 NEM01 NUR M OW Ill mm� 02 x X run SE NN IF X 4( 61 Sr 00' 00' E_ _1,342.4_ 1 1aY_ _ - e - e _ e ---_—_—_—e 0 SW CNN. SEC. 24 W.C.R. 18 ti SEG a 4101. - s -o -P _0 -N 41 - K -1 Ce HG 1-F -E N09: 11181 .11M)80111 - MNUMfIENT OF CHANCE - Duke 'Energy® Field Services 3 2/1/08 12/2/03 04/02/03 REL OEIERFL MILAN WELD COUNTY, COLORADO ROGGEN GAS PROCESSING PLANT PLOT PLAN 2 RRO AIMED uca ECIU MENT ADDED PIM N110NA. RACK DRAFTED BY: Rao DATE 09/26/02 CHECKED BY: SCALE NONE - D 1 NMC A tabl ly: 1dm. * 01. 4.OBNn1F«�6.0bigalmig 03/29/02 GENERA. REM ICK APPROVAL BY: DATE 0 am NO. DATE 8Y 0ESIXPI0N Nob . I . . . 1 . . . . . . . . . 1 . . . 1 . . 1 . . . 1 . 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 ISSUE DWG NO, D-03406—of—ooi ' 25 28 27 28 29 30 31 32 PERT DATE: ACAO RWCA ISSUE 3 AO 33 Compliance Assurance Monitoring Plan Roggen Gas Plant Background This portion of the operating permit application is included to meet the requirements of the compliance assurance monitoring (CAM) regulation (40 CFR Part 64) as it applies to pollutant -specific emission units (PSEU) at the Roggen Gas Plant. To be subject to the CAM regulations, a PSEU must meet the following three criteria: (1) it is subject to a federally -enforceable limitation on a regulated air pollutant or pollutant surrogate; (2) it uses an emission control device to comply with the limitation or standard; and (3) its potential pre -control device emissions of the pollutant are "major" as defined by 40 CFR Part 70. Duke Energy Field Services (DEFS) operates eleven I/C compressor engines at the Roggen Gas Plant. These eleven engines are subject to limits on emissions of nitrogen oxides (NON) and carbon monoxide (CO) and are equipped with nonselective catalytic reduction (NSCR) units that lower NON, CO and hydrocarbon emissions. Four of the engines, (engines C-154, C-159, C-161 and C-158) have pre -control device potential emissions that are "major" as defined by Part 70. The remaining seven engines, qualify for exemption from CAM by any of the criteria listed at 40 CFR 64.2(b). Hence, these four engines are subject to CAM requirements and are addressed by this monitoring plan. The CAM regulation specifies the information that an owner/operator must submit with a Part 70 application for subject PSEUs. The basic elements required of a source subject to CAM are listed below. • Proposed indicators of performance relevant to compliance; • Indicator ranges or conditions, or the process by which such indicators will be established; • Performance criteria that satisfy 40 CFR 64.3(b); • Indicator ranges and performance criteria for any CEM, COM or predictive emission monitoring (PEM). At a minimum, the rule requires a source to select for monitoring at least one indicator of performance per control device and to make at least one observation per 24 hours of the relevant parameter. A source is required to submit information that justifies its proposed monitoring for compliance. This portion of the operating permit application identifies the subject emission units and the federally - enforceable emission limits applicable to each unit. Table 1 presents the CAM that DEFS will perform for the NSCR units on the seven engines as required by 40 CFR 64. DEFS also presents justification for the proposed elements of its monitoring, as required by section 64.4(b). Current Operating Permit Number: 95OPWE055 CAM -Subject Emission Units and Control Devices: Emission Unit Description Emission Control Device (NO„, CO) C-154 Waukesha Model L-7042GSI, 1100 hp engine NSCR on exhaust stack C-159 Waukesha Model L-7042GSI, 1350 hp engine NSCR on exhaust stack C-161 Waukesha Model L-7042GS1, 1350 hp engine NSCR on exhaust stack C-158 Waukesha Model L -7042G, 916 hp engine NSCR on exhaust stack Applicable Emission Limitations: Emission Unit Description Emission Limit, Tons per Year NO. CO C-154 Waukesha Model L-7042GSI, 1100 hp engine 22.3 22.3 C-159 Waukesha Model L-7042GSI, 1350 hp engine 27.4 27.4 C-161 Waukesha Model L-7042GSI, 1350 hp engine 27.4 27.4 C-158 Waukesha Model L -7042G, 916 hp engine 18.6 18.6 Current Monitoring Requirements: Tri-annual portable flue gas analyzer testing to measure the engine exhaust gas concentrations of nitrogen oxides and carbon monoxide for comparison with emission limits. Compliance Assurance Monitoring Plan: The key elements of DEFS' compliance assurance monitoring approach are presented in Table 1 on the following page. DEFS plans to measure daily one indicator of NSCR performance: 1. temperature of the exhaust gas at the inlet to the catalyst 2. oxygen concentration (indicated in volts) in the stack gas entering the catalyst. The justification for monitoring these particular parameters as indicators of continuing NSCR performance and assurance of continued compliance with emission limits is explained following Table 1. TABLE 1. ROGGEN GAS PLANT - CAM APPROACH Indicator No. 1 I. NSCR Performance Indicator Measurement Approach Temperature of exhaust gas into catalyst. * Exhaust gas temperature is measured continuously using an in -line thermocouple. II. Indicator Range Acceptable catalyst inlet temperature range is 650°F to 1350°F, as specified by the manufacturer. Excursions above 1350°F trigger engine shutdown. Excursions below 650°F trigger notification of excursion. Excursions trigger investigation, corrective action, logging, and reporting in semiannual report. III. Performance Criteria A. Data Representativeness Temperature is measured at the inlet to the catalyst by a thermocouple. The minimum accuracy is +1- 5 °F. B. Verification of Operational Status Guarantee from the thermocouple manufacturer C. QA/QC Practices and Criteria Thermocouple scanner or other end device will be calibrated annually. D. Monitoring Frequency Data logger — a minimum of once per day. E. Data Collection Procedures Temperature data will be automatically recorded with a data logger six times per day. No observation required for days when engine is not operated. F. Averaging Period None, unless more than one reading is taken and then a daily average. * Proper ranges for the parametric monitoring in this plan will need to be verified through actual testing data. Ranges may need to be revised in the future. Monitoring Approach Justification Rationale for Using Temperature as a Performance Indicator The temperature into the NSCR unit is measured because the catalytic reactions that destroy the three pollutants are temperature -dependent. The reduction reactions occur favorably if the engine exhaust gas temperature into the catalyst is greater than 650 °F (per the manufacturer's specification), but begin to decrease significantly if that temperature drops below 650 °F. Exhaust temperature typically exceeds 650°F if the engine is operating properly. Catalyst damage will occur if the inlet temperature is too high. Deterioration of the catalyst would , reduce emission destruction efficiency. To protect the catalyst, the engine is equipped with an automatic shutdown that will stop engine operation if the exhaust gas temperature exceeds 1350°F (as specified by the manufacturer). Either excessive or inadequate temperature indicates possible problems with engine operation that may be correctable after investigation. Monitoring of the temperature -sensing device (thermocouple) of the inlet exhaust gas into the catalyst will ensure the presence of optimum conditions for the catalytic reaction. CAM Implementation Temperature Monitoring The control panel on each engine has a digital readout that displays the engine exhaust temperature at the NSCR unit inlet. A data logger will record the temperature indicator at least once daily and record the displayed temperature. To ensure ongoing catalyst integrity, the control panel is programmed to automatically shutdown the engine if the exhaust gas temperature exceeds 1350°F. The control panel will be programmed to notify an operator if the exhaust gas temperature at the NSCR inlet is less than 650°F. If no shutdowns or notifications occur, compliance with the emission limits is presumed based on the known optimal conditions for performance of the catalyst unit. DEFS will investigate all compressor engine shutdowns and alarms and will record whatever corrective action is taken to return the engine exhaust temperature to its normal range. DEFS will investigate all notification and will record whatever corrective action is taken to return the engine exhaust temperature to its normal range. Establishing the Temperature Sensor Indicator Range The indicator ranges in Table 1 for the temperature into the catalyst was selected based on available operational data from compliance tests, observation, and manufacturer data for rich burn engines equipped with AFR and catalytic control. The values at either end of the indicator range, therefore, do not necessarily represent a point beyond which the engine is emitting NOX or CO at rates that would exceed their respective emission limits. dcp Midstream. March 30, 2007 UPS Next Day Air (Tracking Number 1ZF469150196063397) Mr. Jim King Colorado Department of Public Health and Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Dear Mr. King: SUBJECT: Minor Modification Request Roggen Natural Gas Processing Plant Operating Permit 95OPWE055 DCP Midstream 370 17th Street, Suite 250O Denver, CO 80202 303-595-3331 DCP Midstream, LP (DCP Midstream), formerly Duke Energy Field Services, LP, would like to make the following changes to the Title V Operating Permit 95OPWE055 for the Roggen Natural Gas Processing Plant (Roggen). Operating Permit Minor Modification Application forms have not been developed, therefore, this letter and attachments serve as the application. Production has increased and is anticipated to continue to increase in the Weld County area which will subsequently increase condensate production at our facilities. DCP Midstream would like to increase the throughput and associated emission limits for the working and breathing loses (stabilized condensate) and the truck loadout emissions at Roggen. To accommodate the additional condensate, four more 300 bbl condensate tanks will be added to the facility resulting in a total of eight, 300 bbl atmospheric condensate tanks located at Roggen. Draft changes to the permits can be found below: Section II, Condition 8 (table) titled F029 _ Condensate Truck Loadout VOC Emissions: Change VOC limit to 30/84 tpy, the Condensate Loaded limit to 12.00 MMgal/yr, and the emission factor to 5.14 lb/Mgal. Section II, Condition 14 (table) titled P028 - Stabilized Condensate Tanks: (changes requested in previously submitted minor modification dated 11/22/2004 not yet in permit) Change VOC limit to 11.42 tpy, the Condensate Throughput limit to 12.00 MMgal/yr, and the emission factor to 1.90 lb/Mgal. To qualify as a minor modification to the Title V Operating Permit, the modification must be less than significant levels, not significantly change monitoring or recordkeeping, and not trigger new applicable requirements. This modification qualifies as a minor modification because the total increase in emissions is less than 40 tpy VOC, does not significantly change monitoring or recordkeeping, and does not trigger any new applicable requirements (e.g. control requirements under Regulation No. 7 are applicable to tanks with emissions of 20 tpy or more). The APENs associated with the above changes, supporting data, and a check (number 15330) in the amount of $239.92 for the APEN filing fees are attached. www.dcpmidstream.com dcp Midstream. Mr. Jim King March 16, 2007 Page 2 of 2 Should you have any questions regarding this request for minor modification, please contact me at (303) 605-1717 or kakimura@dcpmidstream.com. Sincerely, DCP Midstream, LP Karin Kimura Senior Environmental Specialist Attachments I have reviewed this Minor Modification application supplied under authority of Regulation No. 3, Part C, Section X (5 CCR 1001-5) in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the proposed modification meets the criteria for use of minor permit modification procedures and request that such procedures be used to process this application. This certification conforms with Regulation No. 3, Part C, Section X.D.3 (5 CCR 1001-5). Paul Brewer Vice President of Operations — Northern Division Printed or Typed Name Title Signature of Responsible Official Date AIR POLLUTANT EMISSION NOTICE COMPANY NAME: DCP Midstream, LP MAIL ADDRESS: 370 17th Street, Suite 2500, Denver PLANT NAME & LOCATION: Natural Gas Processing Plant, 35409 County Road 18 HOME BASE LOCATION FOR PORTABLE SOURCE: PERSON TO CONTACT REGARDING THIS INFORMATION Karin Kimura GENERAL DESCRIPTION OF THIS PLANT'S FUNCTION: Natural Gas Processing 1533 0 Si tia PERMIT No.: 95OPWE055 AIRS ID: 123 / 0049 / 125 STATE: CO ZIP: 80202 COUNTY: Weld A. GENERAL INFORMATION Normal Operation of This Source Hours/Day 24 Days/Week 7 Weeks/Year 52 TITLE: Senior Environmental Specialist Process Seasonal Throughput (% of Animal) Dec -Feb 25 Mar -May Jun -Aug 25 25 Sep -Nov 25 ❑ CHECK TO REQUEST PORTABLE SOURCE PERMIT PHONE NUMBER: 303-605-1717 E-MAIL: lcalcimura@dcpmidstream.com ADDITIONAL INFORMATION OR REMARKS: B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of p ant layout) Height ft Diameter ft Temperature F Flow Rate ACFM Velocity ft/min Moisture % Plant ID No. for Stack S-028 C. FUEL INFORMATION Description of Combustion Unit Design Heat Input Rate (10 BTU/tu) Kind of Fuel Burned Annual Fuel Consumption Fuel Heating Value: Percent by Weight Seasonal Fuel Use % of Annual Use) Space Htg Requested level Actual level (Data year level) (BTU/lb, BTU/gal, or BTU/scf) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov (% Ann.) Make: Model: Serial No. D. PROCESS INFORMATION Description of Processing Unit Raw Materials Used Raw Materials -Annual Consumption Design Process Rate Finished Product Finished Product -Annual Output Description Requested level Actual level (Data year level) (Specify Units/Hour) Description Requested level Actual level (Data year level) Make: Eight 300 bbl Condensate Tanks, P-028 Condensate 12.00 MMGal Model: Serial No.: E. POLLUTION CONTROL EQUIPMENT Pollutant Particulate Type of Control Equipment Primary Secondary Overall Collection Efficiency ESTIMATED EMISSIONS (TONS/YEAR) AT THROUGHPUTS REQUESTED ABOVE CONTROLLED UNCONTROLLED ACTUAL EMISSIONS (firn,n data ,,pail ESTIMATION METHOD PM,0 SOx NO, VOC 11.42 1.90 Ib/Mgal CO PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. ❑ CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK. CHECK ALL BOXES THAT APPLY ❑ New or previously unreported source E Requesting modification of existing pe ® Change in emissions, throughputs or eq pment °i .. ❑ Transfer of ownership * cpr 1 ❑ No only update APEN change; ' `-. s, gY v y ❑ Other (Specify) * ", -; * Note: For transfer of ownership or company name change of a permit, you must also submit a Construction Permit Application form. Signature of Person Legally Authorized to Supply Data: DATE: 03/3'%7 YEAR FOR WHICH THE ACTUAL DATA APPLIES: 2007 Typed Name and Title: Karin Kimura, Senior Environmental Specialist Date source began or will begin operation: 1974 THIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details see Regulation 3, Part A, II.C.1. A $119.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send completed forms with fees to: Colorado Dept. of Public Health & Environment APEN # of _ Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 For Information, Call (303) 692-3150 http://wwvv.cdphe.state.co.us/ap/stationary.html Revised January 5, 2006 NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM (See reverse side for guidance on completing this form) Permit Number: Company Name: Plant Location: Person to Contact: E-mail Address: 95OPWE055 DCP Midstream, LP AIRS ID Number: 123/0049/125 Roggen Natural Gas Processing Plant, 35409 County Rd 18 Karin Kimura, Senior Environmental Specialist kakimura@dcpmidstream.com County: Phone Number: Fax Number: Weld Zip Code: 303-605-1717 303-605-1957 Chemical Abstract Service (CAS) Number Chemical Name Reporting BIN Control Equipment / Reduction C/0) Emission Factor (Include Units) Emission Factor Source Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions (lbs/year) 71432 Benzene A None 2% of VOC Mass Balance 456.71 Reporting Scenario (1, 2 or 3): 1 Calendar Year for which Actual Data Applies: 2007 Signature of Responsible Official (not vendor or consultant) Karin Kimura Name of Responsible Official (Please print) O,5/3O,k7 Date Senior Environmental Specialist Title of Responsible Official Form Revision Date: January 5, 2006 TANKS 4.0 Report Page 1 of 6 TANKS 4.0.9d Emissions Report - Detail Format Tank Indentification and Physical Characteristics Identification User Identification: City: State: Company: Type of Tank: Description: Tank Dimensions Shell Height (ft): Diameter (ft): Liquid Height (ft) : Avg. Liquid Height (ft): Volume (gallons): Turnovers: Net Throughput(gal/yr): Is Tank Heated (y/n): Paint Characteristics Shell Color/Shade: Shell Condition Roof Color/Shade: Roof Condition: Roof Characteristics Type: Height (ft) Slope (ft/ft) (Cone Roof) Breather Vent Settings Vacuum Settings (psig): Pressure Settings (psig) P028 Denver Colorado Roggen Gas Plant Vertical Fixed Roof Tank Eight, 300 bbl Stabilized Condensate Tanks N Gray/Light Good Gray/Light Good Cone 15.00 12.00 15.00 7.50 12,690.44 945.59 12,000,000.00 0.00 0.06 -0.03 0.03 Meterological Data used in Emissions Calculations: Denver, Colorado (Avg Atmospheric Pressure = 12.12 psia) file://C:\Program Files\Tanks409d\summarydisplay.htm 3/30/2007 TANKS 4.0 Report Page 2 of 6 TANKS 4.0.9d Emissions Report - Detail Format Liquid Contents of Storage Tank P028 - Vertical Fixed Roof Tank Denver, Colorado Mixture/Component Liquid Daily Liquid Surf. Bulk Vapor Liquid Vapor Temperature (deg F) Temp Vapor Pressure (psia) Mol. Mass Mass Mol. Basis for Vapor Pressure Month Avg. Min. Max. (deg F) Avg. Min. Max. Weight. Fract. Fract. Weight Calculations Stabilzed Condensate All 58.16 47.20 69.12 52.45 5.1058 4.0548 6.3567 69.7100 84.76 Option 1: VP50 = 4.29 VP60 = 5.29 file://C:\Program Files\Tanks409d\summarydisplay.htm 3/30/2007 TANKS 4.0 Report Page 3 of 6 PO28 - Vertical Fixed Roof Tank Denver, Colorado Annual Emission Calcaulations Standing Losses (lb): Vapor Space Volume (cu ft): Vapor Density (lb/cu ft): Vapor Space Expansion Factor: Vented Vapor Saturation Factor: Tank Vapor Space Volume: Vapor Space Volume (cu ft): Tank Diameter (ft): Vapor Space Outage (ft): Tank Shell Height (ft): Average Liquid Height (ft): Roof Outage (ft): Roof Outage (Cone Roof) Roof Outage (ft): Roof Height (ft): Roof Slope (ft/ft): Shell Radius (ft): Vapor Density Vapor Density (lb/cu ft): Vapor Molecular Weight (lb/lb-mole): Vapor Pressure at Daily Average Liquid Surface Temperature (psia): Daily Avg. Liquid Surface Temp. (deg. R): Daily Average Ambient Temp. (deg. F): Ideal Gas Constant R (psia cuft / (lb-mol-deg R)): Liquid Bulk Temperature (deg. R): Tank Paint Solar Absorptance (Shell): Tank Paint Solar Absorptance (Roof): Daily Total Solar Insulation Factor (Btu/sqft day): Vapor Space Expansion Factor Vapor Space Expansion Factor: Daily Vapor Temperature Range (deg. R): Daily Vapor Pressure Range (psia): Breather Vent Press. Setting Range(psia): Vapor Pressure at Daily Average Liquid Surface Temperature (psia): Vapor Pressure at Daily Minimum Liquid Surface Temperature (psia): Vapor Pressure at Daily Maximum Liquid Surface Temperature (psia): Daily Avg. Liquid Surface Temp. (deg R): Daily Min. Liquid Surface Temp. (deg R): Daily Max. LiquidSurfaceTemp. (deg R): Daily Ambient Temp. Range (deg. R): Vented Vapor Saturation Factor Vented Vapor Saturation Factor: Vapor Pressure at Daily Average Liquid: Surface Temperature (psia): 2,660.1414 862.3672 0.0641 0.4042 0.3264 862.3672 12.0000 7.6250 15.0000 7.5000 0.1250 0.1250 0.0000 0.0625 6.0000 0.0641 69.7100 5.1058 517.8285 50.2125 10.731 512.1225 0.5400 0.5400 1,568.5833 0.4042 43.8350 2.3019 0.0600 5.1058 4.0548 6.3567 517.8285 506.8697 628.7872 27.9417 0.3264 5.1058 TANKS 4.0.9d Emissions Report - Detail Format Detail Calculations (AP -42) file://C:\Program Files\Tanks409d\summarydisplay.htm 3/30/2007 TANKS 4.0 Report Page 4 of 6 Vapor Space Outage (ft): 7.6250 Working Losses (Ib): Vapor Molecular Weight (lb/lb-mole): Vapor Pressure at Daily Average Liquid Surface Temperature (psia): Annual Net Throughput (gal/yr.): Annual Turnovers: Turnover Factor: Maximum Liquid Volume (gal): Maximum Liquid Height (ft): Tank Diameter (ft): Working Loss Product Factor: 20,175.3347 69.7100 5.1058 12,000,000.0000 945.5934 0.1984 12,690.4443 15.0000 12.0000 1.0000 Total Losses (Ib): 22,835.4761 file://C:\Program Files\Tanks409d\summarydisplay.htm 3/30/2007 TANKS 4.0 Report Page 5 of 6 TANKS 4.0.9d Emissions Report - Detail Format Individual Tank Emission Totals Emissions Report for: Annual P028 - Vertical Fixed Roof Tank Denver, Colorado Components Stabilzed Condensate Losses(lbs) Working Loss 20,175.33 Breathing Loss 2,660.14 Total Emissions 22,835.48 file://C:\Program Files\Tanks409thsummarydisplay.htm 3/30/2007 COMPANY NAME: DCP Midstream, LP AIR POLLUTANT EMISSION NOTICE PERMIT No.: 15330 MAIL ADDRESS: 370 17 Street, Suite 2500, Denver PLANT NAME & LOCATION: Roggen Natural Gas Processing Plant, 35409 County Road 18 HOME BASE LOCATION FOR PORTABLE SOURCE: PERSON TO CONTACT REGARDING THIS INFORMATION Karin Kimura GENERAL DESCRIPTION OF THIS PLANT'S FUNCTION: Natural Gas Processing 95OPWE055 AIRS ID: 123 / 0049 / 126 STATE: CO ZIP: 80202 COUNTY: Weld TITLE: Senior Environmental Specialist ❑ CHECK TO REQUEST PORTABLE SOURCE PERMIT PHONE NUMBER: 303-605-1717 E-MAIL: kakimura@dcpmidstream.com A. GENERAL INFORMATION Normal Operation of This Source Hours/Day 24 Days/Week 7 Weeks/Year 52 Process Seasonal Through ut (% of Annual) Dec -Feb Mar -May Jun -Aug Sep -Nov 25 25 25 25 ADDITIONAL INFORMATION OR REMARKS: B. STACK OR VENT INFORMATION (Identify below which stack if plant has two or more; refer to attached sketch of plant layout) Height ft Diameter ft Temperature F Flow Rate ACFM Velocity ft/min Moisture % Plant ID No. for Stack S-029 C. FUEL INFORMATION Design Heat Annual Fuel Consumption Fuel Heating Value: Percent by Weight Seasonal Fuel Use (% of Annual Use) Space Htg Description of Combustion Unit Input Rate (10 BTU/hr) Kind of Fuel Burned Requested level Actual level (Data year level) (BTU/lb, BTU/gal, or BTU/scf) Sulfur Ash Dec -Feb Mar -May Jun -Aug Sep -Nov (% Ann.) Make: Model: Serial No. D. PROCESS INFORMATION Description of Processing Unit Raw Materials Used Raw Materials -Annual Consumption Design Process Rate Finished Product Finished Product -Annual Output Description Requested level Actual level (Data year level) (Specify Units/Hour) Description Requested level Actual level (Data year level) Make: Condensate Truck Loadout, F-029 Condensate 12.00 MMGal Model: Serial No.: E. POLLUTION CONTROL EQUIPMENT Pollutant Type of Control Equipment Primary Secondary Overall ESTIMATED EMISSIONS Collection (TONS/YEAR) AT THROUGHPUTS Efficiency REQUESTED ABOVE CONTROLLED UNCONTROLLED ACTUAL EMISSIONS (frnn, data vaar\ ESTIMATION METHOD Particulate PMin SO„ NOx VOC 30.84 5.14 lb/Mgal CO PLEASE USE APCD NON -CRITERIA REPORTABLE AIR POLLUTANT ADDENDUM FORM TO REPORT SUCH POLLUTANTS OR POLLUTANTS NOT LISTED ABOVE. ❑ CHECK HERE IF YOU WISH THE DIVISION TO CALCULATE YOUR EMISSIONS. SEE "EMISSION ESTIMATES" INSTRUCTIONS ON BACK. CHECK ALL BOXES THAT APPLY ❑ New or previously unreported source E Requesting modification of existing perm E Change in emissions, throughputs or equipment -.F._; ❑ Transfer of ownership *a ❑ No change; APEN update only (/) N (J) N ❑ Other (Specify) * o O. oof CJ -- 0' ,2- * Note: For transfer of ownership or compan acne change ofpa permit, you must also submit a Construction P ni Application form. Signature of Person Legally Authorized to Supply Data: Typed Name and Title: Karin Kimura, Senior Environmental Specialist DATE: 03/30,47 "7 YEAR FOR WHICH THE ACTUAL DATA APPLIES: 2007 Date source began or will begin operation: 1992 HIS NOTICE IS VALID FOR FIVE YEARS. A revised notice shall be filed prior to this expiration date, whenever a permit limitation must be modified, whenever control equipment is changed, and annually whenever a significant emission change occurs. For specific details see Regulation 3, Part A, II.C.1. A $119.96 FILING FEE IS REQUIRED FOR EACH NOTICE FILED. Send completed forms with fees to: Colorado Dept. of Public Health & Environment APEN II of _ Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-BI Denver, Colorado 80246-1530 For Information, Call (303) 692-3150 _ http://www.cdphe.state.co.us/ap/stationary.html Revised January 5, 2006 NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM (See reverse side for guidance on completing this form) Permit Number: Company Name: Plant Location: Person to Contact: E-mail Address: 95OPWE055 DCP Midstream, LP AIRS ID Number: 123/0049/126 Roggen Natural Gas Processing Plant, 35409 County Rd 18 Karin Kimura, Senior Environmental Specialist kakimura@dcpmidstream.com County: Phone Number: Fax Number: Weld Zip Code: 303-605-1717 303-605-1957 Chemical Abstract Service (CAS) Number Chemical Name Reporting BIN Control Equipment / Reduction (%) Emission Factor (Include Units) Emission Factor Source Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions (lbs/year) 71432 Benzene A None 2% of VOC Mass Balance 1233.6 100414 Ethylbenzene C None 2% of VOC Mass Balance 1233.6 108883 Toluene C None 2% of VOC Mass Balance 1233.6 1330207 Xylenes C None 2% of VOC Mass Balance 1233.6 110543 n -Hexane C None 2% of VOC Mass Balance 1233.6 Reporting Scenario (1, 2 or 3): 1 Calendar Year for which Actual Data Applies: 2007 Signature of Responsible Official (not vendor or consultant) Karin Kimura Name of Responsible Official (Please print) - d3407, 7 Date Senior Environmental Specialist Title of Responsible Official Form Revision Date: January 5, 2006 Emission Units Include m in the 2015 construction permit modifications: ermit number 95OPWE055 s • Issuance 1 arch • Fugitive equipment leaks (P025). permit Midstream; March 17, 2016 Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Re: Roggen Natural Gas Processing Plant Operating Permit 950PWE055 Title V Modification Application AIRS ID 123/0049 DCP Midstream 370 17th St., Suite 2500 Denver, CO 80202 (303) 605-2039 www.dcpmidstream.com g5aPWEtsI5S Mott JS UPS Trackin No. 1Z F46 915 02 9243 0058 1a,R 21 2016 Page 1 of 2 • Increase throughput of P033 to 4.0 MMscfd. • Increase fugitive emissions from equipment leaks (P025) based on the most recent component count and a recent gas analysis, and include a 20% buffer to account for any additional fugitive components or gas analysis variability that may be related to the equipment and configuration changes described in the permit application. The resulting potential to emit VOCs increased by approximately 2.14 tons per year above current previously permitted levels. The installation of the enclosed combustor was planned to allow the facility to operate in any one of the following three scenarios: • Scenario 1: The amine unit (P-137) is out of service and bypassed while the inlet TEG dehydrator (P-136) and the regen gas TEG dehydrator (P033) are in service. The emissions from the still vents from both dehydration units are routed to the new enclosed combustor with a minimum control efficiency of 97%. • Scenario 2: This operation will take place when all three units are in service, inlet TEG (P-136), regen gas TEG (P033), and the amine unit (P-137). During this operation, emissions from all still vents will be routed to the existing RTO. • Scenario 3: This scenario will only take place if there are complications with the first two. In this operation, all three units are in service. The emissions from the two TEG dehydration unit still vents (P-136 and P033) are routed to the enclosed combustor while the emissions from the amine unit (P-137) will be routed to the RTO. Emissions from the scenarios described above did not exceed permitted limits for P-136 or P-137 and the permitted limit for P033 was lowered to account for a control device. The 2014 construction permit modification application requested configuration changes for P-136 while the emission limits remained the same. The amine unit (P-137) is routed to the existing RTO under all three configurations; therefore, there were no changes requested for that unit. Modification of Operating Permit 95OPWE055 Attached please fmd forms and attachments needed to make the requested changes to operating permit 95OPWE055, as well as the required certifications signed by the Responsible Official, William L. Johnson, Vice President of Operations. If you have any questions or require any additional information about this submittal, please contact me at (303) 605-2039 or RShankaran@dcpmidstream.com. Sincerely, DCP Midstream, LP Roshini Shankaran Environmental Engineer Attachments Page 2 of 2 Attachment A Title V Modification Forms Roggen Gas Plant Page 3 of 2 Operating Permit Application FACILITY IDENTIFICATION Colorado Department of Public Health and Environment Air Pollution Control Division 1. Facility name and Name SEE INSTRUCTIONS ON REVERSE SIDE Roggen Gas Plant mailing address Street or Route City, State, Zip Code FORM 2000-100 Rev 06-95 35409 Weld County Road 18 Roggen, Colorado 80652 2. Facility location Street Address 35409 Weld County Road 18 (No P.O. Box) City, County, Zip Code Roggen, Colorado 80652 3. Parent corporation Name Street or Route City, State, Zip Code Country (if not U.S.) DCP Midstream, LP 370 17th Street, Suite 2500 Denver, Colorado 80202 4. Responsible Name official Title Telephone William L. Johnson Vice President of Operations 303-605-1752 5. Permit contact person Name Title (If Different than 4) Telephone 6. Facility SIC code: 1321 7. Facility identification code: CO 1230049 Roshini Shankaran Environmental Engineer 303-605-2039 8. Federal Tax I. D. Number: 841041166 9. Primary activity of the operating establishment: Natural gas processing 10. Type of operating permit ❑ New X Modified ❑ Renewal 11. Is the facility located in a "nonattainment" area: X Yes ❑ No If "Yes", check the designated "non -attainment" pollutant(s): ❑ Carbon Monoxide x Ozone ❑ PM10 ❑ Other (specify) 12. List all (Federal and State) air pollution permits (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 Public Health and Environment Air Pollution Control Division FACILITY PLOT PLAN FORM 2000-101 Rev 06-95 Facility Name: Roggen Gas Plant Facility Identification Code: CO1230049 The operating permit must be prepared and submitted on forms supplied by the Division. Use of this form is required for all operating permit applications. The Division will not consider or act upon your application unless each form used has been entirely completed. Completion of the information in the shaded area of this form is optional. Use "NA" where necessary to identify an information request that does not apply and is not in the optional shaded area. In order for a comprehensive air quality analysis to be accomplished, a facility plot plan MUST be included with the permit application. Drawings provided must fit on generic paper sizes of 8 1/2" X 11", 8 1/2" X 14" or 11" X 15", as appropriate to display the information being provided. Include the facility name and facility identification code on all sheets. For facilities with large areas, sketches of individual buildings, on separate drawings, may be needed to allow easy identification of stacks or vents. Insignificant activities do not need to be shown. X 1. A plant layout (plan view) including all buildings occupied by or located on the site of the facility and any outdoor process layout. ❑ 2. The maximum height of each building (excluding stack height). X 3. The location and coded designation of each stack. Please ensure these designations correspond to the appropriate stacks listed on the other permit forms in this application. The drawings need not be to scale if pertinent dimensions are annotated, including positional distances of structures, outdoor processes and free standing stacks to each other and the property boundaries. Only stacks affected by this modification are Labeled ❑ 4. The location of property boundary lines. X 5. Identify direction "North" on all submittals. Are there any outdoor storage piles on the facility site with air pollution emissions that need to be reported? ❑ Yes X No If "Yes", what is the material in the storage pile(s)? Are there any unpaved roads or unpaved parking lots on the facility site? X Yes❑ No List the name(s) of any neighboring state(s) within a 50 mile radius of your facility: NA Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SOURCE AND SITE DESCRIPTIONS FORM 2000-102 Rev 06-95 Facility Name: Roggen Gas Plant Facility Identification Code: CO1230049 The operating permit must be prepared and submitted on forms supplied by the Division. Use of this form is required for all operating permit applications. The Division will not consider or act upon your application unless each form used has been entirely completed. Completion of the information in the shaded area of this form is optional . Use "NA" where necessary to identify an information request that does not apply and is not in the optional shaded area. 1. Briefly describe the existing Unit(s) to be permitted. Attach copies of Form 2000-700 as needed to provide the information. Process flowsheets or line diagrams showing major features and locations of air pollution control equipment can be most effective in showing the location and relationships of the units. Providing mass flowrates/balances at critical points on the diagrams is very helpful when developing an understanding of the processes involved. The Roggen Gas Plant uses cryogenic processes to separate liquid hydrocarbons from high and low pressure natural gas streams. The operations at the facility include: inlet compression, gas dehydration, gas processing (cryogenic plant skids), product storage and transfer, and residue gas compression. This modification makes the following changes to incorporate construction permit modifications 01WE0208, Issuance 1, March 18, 2015 and 10WE1659, Issuance 5, March 18, 2015: P025 (F025): Fugitive equipment leaks from natural gas processing. Increased emissions based on hard count of components and recent gas analysis. P033: Dehydration unit. Increase capacity of dehydration unit to 4 MR/Iscf/d. Add enclosed combustor control device and allow additional scenarios of operation such that still vent emissions will either be routed to new enclosed combustor (ECD-1) or to existing RTO (RTO-1). Reduced emissions due to control. P136: Dehydration unit. Allow additional scenarios of operation so that under some conditions, emissions from P136 still vent are routed to a new enclosed combustor rather than existing RTO (RTO-1). No change in emissions. New enclosed combustor: Control device (ECD-1) for P033 and P-136. 2. Site Location and Description (Include instructions needed to drive to remote sites not identified by street addresses) The facility is located at 35409 Weld County Road 18, Roggen, Colorado. It is located in Section 24, Township 2 North, Range 63 West, about 5 miles south of the town of Roggen in Weld County. 3. Safety Equipment Identify safety equipment required for performing an inspection of the facility: Protection x Other, specify Eye protection Flame retardant outerwear (shirt or jacket) X Hard Hat x Safety shoes X Hearing Protection 0 Gloves Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division Facility Name: Roggen Gas Plant SOURCE DESCRIPTION - APENS FORM 2000-102A Rev 06-95 Facility Identification Code: C01230049 NOTE: Each new or updated Air Pollutant Emission Notice (APEN) submitted must be accompanied by payment of $100 per APEN. 1. For each emission unit enclose a copy of the most current complete Air Pollutant Emission Notice (APEN) on file with the Division. If the most current APEN was not completely and correctly filled out, a revised APEN is required. List an APEN number, date, and a brief description of the unit/process covered by the APEN. (No filing fees are needed for these copies) P025 (123/0049/122) Fugitive emissions from equipment leaks P033 (123/0049/130) TEG dehydration unit (4 MMscf/d) P-136 (123/0049/136) TEG dehydration unit (85 MMscf/d) 7/25/2014 4/30/2015 4/30/2015 2. No APEN exists for an emission unit. List the new APEN and the appropriate descriptive information here. Submit the APEN with a construction permit application. New APEN and permit application submitted NA ❑ with this application OR ❑ under separate cover to Construction Permits Section 3. A revised APEN was prepared and enclosed for an emission unit. List the APEN and the appropriate descriptive information here. A revised APEN is needed where a significant increase in emissions has occurred, or is planned; or a major modification of the unit has occurred or is planned; or the existing information needs correction or completion. A construction permit application may need to be submitted. Revised APEN submitted as part of this application: ❑ Yes X No ❑ Filing Fee Enclosed ❑ Yes X No New permit application enclosed: Permit modification application enclosed: ❑ Yes X No Note: this application is a request to modify operating permit to incorporate recent construction permit modifications, issued March 18, 2015 for Roggen Gas Plant) NOTE: Use additional copies of Form 2000-700 as needed to provide the above information. Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division STACK IDENTIFICATION FORM 2000-200 Rev 06-95 Circular SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: ECD-1 (enclosed combustor) 3a. Construction Permit Number: 01WE0208, 10WE1659 4. Exhausting Unit(s), use Unit identification code from appropriate Form(s) 2000-300, 301, 302, 303, 304, 305, 306, 307 2000-300 2000-301 2000-302 2000-303 2000-304 2000-305 2000-306 2000-307 P033, P-136 5. Stack identified on the plot plan required on Form 2000-101 X 6. Indicate by checking: X This stack has an actual exhaust point. The parameters are entered in Items 7-13. (Note: control device is exhaust point) ❑ This stack serves to identify fugitive emissions. Skip items 7-13. Go to next form. ❑ When stack height Good Engineering Practice (GEP) exceeds 65 meters (Colorado Air Quality Reg 3.A.VIII.D) data entry is required for Item 7. 7. Discharge height above ground level: (feet) Inside dimensions at outlet (check one and complete): ❑ Rectangular (feet) length (feet) width (feet) " 10. Exhaust gas temperature (normal): (EF) r 11. Does process modify ambient air moisture content? ❑- Yes If "Yes", exhaust gas moisture content: Normal percent ❑ Horizontal Maximum percent 12. Exhaust gas discharge direction: ❑ Up 0 Down 13. Is this stack equipped with a rainhat or any obstruction to the free flow of the exhaust gases from the stack? ❑ Yes ❑ No *****Complete the appropriate Air Permit Application Forms(s) 2000-300, 301, 302, 303, 304, ***** 305, 306, or 307 for each Unit exhausting through this stack. Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 3. Stack identification code: RTO-1 (Regenerative thermal 3a. Construction Permit Number: 01WE0208, oxidizer) aW 4. Exhausting Unit(s), use Unit identification code from appropriate Form(s) 2000-300, 301, 302, 303, 304, 305, 306, 307 STACK IDENTIFICATION FORM 2000-200 Rev 06-95 2000-300 2000-301 2. Facility identification code: CO1230049 2000-302 2000-303 2000-304 2000-305 2000-306 P-137 2000-307 P033 P-136 5. Stack identified on the plot plan required on Form 2000-101 X 6. Indicate by checking: X This stack has an actual exhaust point. The parameters are entered in Items 7-13. (Note: control device is exhaust point) ❑ This stack serves to identify fugitive emissions. Skip items 7-13. Go to next form. ❑ When stack height Good Engineering Practice (GEP) exceeds 65 meters (Colorado Air Quality Reg 3.A.VIII.D) data entry is required for Item 7. 7. Discharge height above ground level: (feet) 8. Inside dimensions at outlet (check one and complete): ❑ Circular Exhaust flow rate: Velocity _ ❑ Rectangular Normal (FPS) ❑ Calculated ❑ Stack Test 1 Exhaust gas temperature (normal): (EF) 11. Does process modify ambient air moisture content? ❑ If "Yes", exhaust gas moisture content: Normal percent 0 Horizontal 12. Exhaust gas discharge direction: 0 Up' ❑ Down 13. Is this stack equipped with a rainhat or any obstruction to the free flow of the exhaust gases from the stack? ❑ Yes ❑ No *****Complete the appropriate Air Permit Application Forms(s) 2000-300, 301, 302, 303, 304, 305, 306, or 307 for each Unit exhausting through this stack. ***** Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant STACK IDENTIFICATION FORM 2000-200 Rev 06-95 2. Facility identification code: CO1230049 3. Stack identification code: S025 3a. Construction Permit Number: 10WE1659 4. Exhausting Unit(s), use Unit identification code from appropriate Form(s) 2000-300, 301, 302, 303, 304, 305, 306, 307 2000-300 2000-301 2000-302 2000-303 2000-304 2000-305 2000-306 P025 2000-307 5. Stack identified on the plot plan required on Form 2000-101 NA 6. Indicate by checking: ❑ This stack has an actual exhaust point. The parameters are entered in Items 7-13. (Note: control device is exhaust point) X This stack serves to identify fugitive emissions. Skip items 7-13. Go to next form. ❑ When stack height Good Engineering Practice (GEP) exceeds 65 meters (Colorado Air Quality Reg 3.A.VIII.D) data entry is required for Item 7. 7. Discharge height above ground level:, (feet) 8. Inside dimensions at outlet (check one and complete): ❑ Circular 9. Exhaust flow rate: ❑ Rectangular length (feet) Normal (ACFM) Velocity (FPS) ❑ Calculated. ❑ Stack Test_ 10. Exhaust gas temperature (normal): (EF) 11 Does process modify ambient air moisture content? 1=1 El N° If "Yes", exhaust gas moisture content: Normal percent Maximum percent width (feet) Maximum (ACFM) 12. Exhaust gas discharge direction: ❑ Up ❑ Down O Horizontal 13. Is this stack equipped with a rainhat or any obstruction to the free flow of the exhaust gases from the stack? ❑ Yes ❑ No *****Complete the appropriate Air Permit Application Forms(s) 2000-300, 301, 302, 303, 304, ***** 305, 306, or 307 for each Unit exhausting through this stack. Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE MISCELLANEOUS PROCESSES FORM 2000-306 Rev 06-95 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: S025 4. Process (Unit) code: P025 5. Unit description: Equipment leaks (fugitive VOCs) from a natural gas processing facility 6. Indicate the control technology status. ❑ Uncontrolled X Controlled If the process is controlled, enter the control device code(s) from the appropriate form(s): 2000-400 LDAR 2000-401 2000-402 2000-404 2000-405 2000-406 2000-403 2000-407 7. Actual annual process rates for 19 8. Date first placed in service: 1981 Date of last modification: 3/18/2015 10WE1659, Issuance 5 9. Normal operating schedule: 24 hrs./day 7 days/wk. 8760 hours/yr. 10. Describe this process (please attach a flow diagram of the process). Leaks from components in the normal operations of the facility Attached? ❑ 11. List the types and amounts of raw materials used in this process: Material Storage/material handling process Actual usage Units Maximum usage NA NA NA Units NA Clean-up solvents NA Other (specify) NA 12. List the types and amounts of finished products: Material Storage/material handling process Actual amount Units produced Maximum Units amount produced NA NA " NA NA 13. Process fuel usage: Type of fuel Maximum heat input to process million BTU/hr. Actual usage Units Maximum usage Units NA NA NA NA 14. Describe any fugitive emissions associated with this process, such as outdoor storage piles, unpaved roads, open conveyors, etc.: Fugitive emissions from leaking equipment at the facility ***** For this emissions unit, identify the method(s) of compliance demonstration by completing Form 2000-500, ***** DESCRIPTION OF METHODS USED FOR DETERMINING COMPLIANCE. Attach Form 2000-500 and its attachment(s) to this form. ***** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit. ***** 8 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant GLYCOL DEHYDRATION UNIT FORM 2000-307 Rev 06-95 2. Facility identification code: CO1230049 3. Stack identification code: ECD-1, RTO-1 4. Dehydrator (Unit) code: P033 5. Unit description: Regen TEG dehydration system 6. Indicate the dehydrator control technology status. ❑ Uncontrolled X Controlled If the dehydrator is controlled, enter the control device number(s) from the appropriate forms: 2000-400 ECD-1 2000-403 RTO-1 7. Manufacturer: Custom 8. Model & serial number: NA 9. Regenerator heater design rate or maximum continuous rating (mmBTU/hr): NA 10. Date first placed in service: 1976 Date of last modification: 3/18/2015 (01WE0208, Issuance 1) 11. Flash Tank: X Yes ❑ No Flash tank vented to: ❑ atmosphere x process Low pressure inlet 12. Glycol Circulation rate: 3.5 gallons per minute OR 13. Pipeline Capacity: (mmscf/day): 4.0 gallon per pound of H2O 14. Glycol Type: X Triethylene Glycol ❑ Ethylene Glycol ❑ Other (specify) 15. Glycol Make-up Rate (gallons/year): 16. Computer model input & output printout attached ❑ 17. Gas Pressure (psi): 850 18. Gas Temperature (❑F): 80 19. Gas composition test result Test date: 11/20/2013, 11/26/201: Heating Cooling s 3 VOC BTEX HEXANE (Total Hexanes) value units value units value units 4.1 Mole% 0.0073 Mole% 0.063 Mole% 3.3 Mole% 0.0016 Mole% 0.025 Mole% *****For this emissions unit, identify the method of compliance demonstration by completing norm LUUu-Duu, DESCRIPTION OF METHODS USED FOR DETERMINING COMPLIANCE. Attach Form 2000-500 and its attachment(s) to this form. ***** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit. ***** NOTE: '1111: SPECIALIZED APEN FOR A GLYCOL DEHYDRATION UNIT MUST BE COMPLETED AND SUBMITTED IF THE STILL VENT EMISSIONS HAVE NOT BEEN REPORTED BEFORE 9 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant GLYCOL DEHYDRATION UNIT FORM 2000-307 Rev 06-95 2. Facility identification code: CO1230049 3. Stack identification code: ECD-1, RTO-1 4. Dehydrator (Unit) code: P-136 5. Unit description: Inlet TEG dehydration system 6. Indicate the dehydrator control technology status. ❑ Uncontrolled X Controlled If the dehydrator is controlled, enter the control device number(s) from the appropriate forms: 2000-400 ECD-1 2000-403 RTO-1 7. Manufacturer: Evco Fabrication 8. Model & serial number: T-901 SN 2090 9. Regenerator heater design rate or maximum continuous rating (mmBTU/hr): NA 10. Date first placed in service: 7/1/2011 Date of last modification: 3/18/2015 (10WE1659, Issuance 5) 11. Flash Tank: X Yes ❑ No Flash tank vented to: ❑ atmosphere x process Low pressure inlet 12. Glycol Circulation rate: 24 gallons per minute OR 13. Pipeline Capacity: (mmscf/day): 85 gallon per pound of H2O 14. Glycol Type: X Triethylene Glycol ❑ Ethylene Glycol ❑ Other (specify) 15. Glycol Make-up Rate (gallons/year): 16. Computer model input & output printout attached ❑ 17. Gas Pressure (psi): 830 18. Gas Temperature (❑F): 116 19. Gas composition test results Test date: 8/11/2015 VOC BTEX HEXANE (Total Hexanes) value units value units value units 11.8 Moles- 0.0256 Moles- 0.27 Molel *****For this emissions unit, identify the method of compliance demonstration by completing Form 2000-500, ***** DESCRIPTION OF METHODS USED FOR DETERMINING COMPLIANCE. Attach Form 2000-500 and its attachment(s) to this form. ***** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit. ***** NOTE: 'IHE SPECIALIZED APEN FOR A GLYCOL DEHYDRATION UNIT MUST BE COMPLETED AND SUBMITTED IF THE STILL VENT EMISSIONS HAVE NOT BEEN REPORTED BEFORE 10 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE CONTROL EQUIPMENT - MISCELLANEOUS FORM 2000-400 Rev 06-95 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: S025 4. Unit identification code: P025 5. Control device code: LDAR 6. Manufacturer and model number: NA 7. Date placed in service: Date of last modification: 8. Describe the device being used. Attach a diagram of the system. Leak Detection and Repair program implemented under NSPS 40 CFR 60, Subpart KKK 9. List the pollutants to be controlled by this equipment and the expected control efficiency for each pollutant on the table below. ❑ Documentation attached EITHER the outlet pollutant concentration OR the control efficiency must be provided. Pollutant Inlet pollutant concentration gr/acf VOC ppmv Emission capture efficiency (%) Outlet pollutant concentration gr/acf ppmv Control Efficiency (%) 30o tor connectors and flanges, 75% - for rest 10. Discuss how the collected material will be handled for reuse or disposal. 11. Prepare a malfunction prevention and abatement plan for this pollution control system. The plan does not have to be submitted with the application. It is suggested the plan include, but not be limited to the following: a. Identification of the individual(s), by title, responsible for inspecting, maintaining and repairing this device. b. Operation variables such as temperature that will be monitored in order to detect a malfunction or breakthrough, the correct operating range of these variables, and a detailed description of monitoring or surveillance procedures that will be used to show compliance. What type of monitoring equipment will be provided (temperature sensors, pressure sensors, CEMs). d An inspection schedule and items or conditions that will be inspected. f Where is this plan available for review? c. NOTE: COMPLETION OF INFORMATION IN SHADED AREA OF THIS FORM IS OPTIONAL 11 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE CONTROL EQUIPMENT - MISCELLANEOUS FORM 2000-400 Rev 06-95 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: ECD-1 4. Unit identification code: P033, P-136 5. Control device code: ECD-1 6. Manufacturer and model number: John Zink ZTOF Enclosed Combustor 7. Date placed in service: 3/18/2015 Date of last modification: 3/18/2015 (10WE1659, Issuance 5; 01WE0208, Issuance 1) 8. Describe the device being used. Attach a diagram of the system. Enclosed combustor 9. List the pollutants to be controlled by this equipment and the expected control efficiency for each pollutant on the table below. X Documentation attached E1'1'HER the outlet pollutant concentration OR the control efficiency must be provided. Pollutant Inlet pollutant concentration gr/acf pmv Emission capture efficiency (%) Outlet pollutant concentration gr/acf ppmv Control Efficiency (%) VOC ≥970 Organic HAPs ≥97% 10. Discuss how the collected material will be handled for reuse or disposal. 11. Prepare a malfunction prevention and abatement plan for this pollution control system. The plan does not have to be submitted with the application. It is suggested the plan include, but not be limited to the following: a. Identification of the individual(s), by title, responsible for inspecting, maintaining and repairing this device. b. Operation variables such as temperature that will be monitored in order to detect a malfunction or breakthrough, the correct operating range of these variables, and a detailed description of monitoring or surveillance procedures that will be used to show compliance. c. What type of monitoring equipment will be provided (temperature sensors, pressure sensors, CEMs). d. An inspection schedule and items or conditions that will be inspected. f. Where is this plan available for review? NOTE: COMPLETION OF INFORMATION IN SHADED AREA OF THIS FORM IS OPTIONAL 12 Operating Permit Application CONTROL EQUIPMENT - CATALYTIC OR THERMAL OXIDATION Form 2000-403 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE Section A 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: RTO-1 4. Unit identification code: P033, P-136, P-137 5. Control device code: RTO-1 6. Manufacturer and model number: Anguil Model 150 SN AES 97225 7. Date placed in service: 2011 Date last modified: 3/18/2015 (10WE1659, Issuance 5; 01WE0208, Issuance 1) 8. Describe the oxidation system. Attach a diagram of the system. Regenerative thermal oxidation 9. List the pollutants to be controlled by this equipment and the expected control efficiency for each pollutant on the table below. ❑ Documentation attached EITHER the outlet pollutant concentration OR the control efficiency must be provided. Pollutant Inlet pollutant concentration Outlet pollutant concentration Control Efficiency (%) VOC gr/acf ppmv tmission Capture. Pollutant Destruction Organic HAPs ≥97O ≥970 10: Check one: ❑ Catalytic 11. Discuss how_ the spent catalyst will be handled for reuse or disposal. X Thermal oxidizer 12. Prepare a malfunction prevention and abatement plan for this pollution control system. The plan does not have to be submitted with the application. It is suggested the plan include, but not be limited to the following: a. Identification of the individuals(s), by title, responsible for inspecting, maintaining and repairing this device. b. Operation variables such as temperature that will be monitored in order to detect a malfunction or breakthrough, the correct operating range of these variables, and a detailed description of monitoring or surveillance procedures that will be used to show compliance. c. An inspection schedule and items or conditions that will be inspected. For catalytic oxidizers, discuss the replacement and/or regeneration schedule for the bed and steps you have taken to ensure the bed's proper functioning throughout its expected lifetime. d. Where is this plan available for review? Section B The following questions must be answered by sources installing new equipment or existing Units which cannot document control efficiency of this device by other means. (Catalytic/Thermal dependent on item 10) Catalytic oxidation Thermal oxidation 13a. Max Operating temperature (EF): Min b. Max Operating temperature (EF): Min 1,450 14a. Catalyst bed volume (ft3): b. Combustion chamber volume (ft3): 15a. Gas volumetric flow rate at combustion conditions (ACFM): b. Maximum gas velocity through the device (ft./sec): 16a. Type of fuel used: b. Type of fuel used: 17a. Max fuel use rate (BTU/Hr): b. Maximum fuel used (BTU/Hr): 18a. Type and volume of catalyst used (ft3): 19a. Residence time (seconds): b. Residence time (seconds): NOTE: COMPLETION OF INFORMATION IN SHADED AREA OF THIS FORM IS OPTIONAL 13 Operating Permit Application COMPLIANCE CERTIFICATION - MONITORING AND REPORTING FORM 2000-500 Colorado Department of Public Health and Environment DESCRIPTION OF METHODS USED Rev 06-95 Air Pollution Control Division FOR DETERMINING COMPLIANCE All applicants are required to certify compliance with all applicable air pollution permit requirements by including a statement within the permit application of the methods used for determining compliance. This statement must include a description of the monitoring, recordkeeping, and reporting requirements and test methods. In addition, the application must include a schedule for compliance certification submittals during the permit term. These submittals must be no less frequent than annually, and may need to be more frequent if specified by the underlying applicable requirement or by the Division. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: S025 4. Unit identification code: P025 5. For this Unit the following method(s) for determining compliance with the requirements of the permit will be used (check all that apply and attach the appropriate form(s) to this form). ❑ Continuous Emission Monitoring (CEM) - Form 2000-501 Pollutant(s): ❑ Periodic Emission Monitoring Using Portable Monitors - Form 2000-502 Pollutant(s): ❑ Monitoring Control System Parameters or Operating Parameters of a Process - Form 2000-503 Pollutant(s): ❑ Monitoring Maintenance Procedures - Form 2000-504 Pollutant(s): ❑ Stack Testing - Form 2000-505 Pollutant(s): ❑ Fuel Sampling and Analysis (FSA) - Form 2000-506 Pollutant(s): X Recordkeeping - Form 2000-507 Pollutant(s): VOCs, HAPs X Other (please describe) - Form 2000-508 Pollutant(s): Leak detection and repair per 40 CFR 60, Subpart KKK 6. Compliance certification reports will be submitted to the Division according to the following schedule: Start date: February 1, 2002 and every 12 months thereafter. (12 month maximum interval) Compliance monitoring reports will be submitted to the Division according to the following schedule: Start date: August 1, 2001 and every 6 months thereafter. (6 month maximum interval) NOTE: EACH APPLICABLE REQUIREMENT ON FORM 2000-604 NEEDS TO BE SPECIFICALLY ADDRESSED IN ITEM 5. 14 Operating Permit Application COMPLIANCE CERTIFICATION - MONITORING AND REPORTING FORM 2000-500 Colorado Department of Public Health and Environment DESCRIPTION OF METHODS USED Rev 06-95 Air Pollution Control Division FOR DETERMINING COMPLIANCE All applicants are required to certify compliance with all applicable air pollution permit requirements by including a statement within the permit application of the methods used for determining compliance. This statement must include a description of the monitoring, recordkeeping, and reporting requirements and test methods. In addition, the application must include a schedule for compliance certification submittals during the permit term. These submittals must be no less frequent than annually, and may need to be more frequent if specified by the underlying applicable requirement or by the Division. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: ECD-1, RTO-1 4. Unit identification code: P033 5. For this Unit the following method(s) for determining compliance with the requirements of the permit will be used (check all that apply and attach the appropriate form(s) to this form). ❑ Continuous Emission Monitoring (CEM) - Form 2000-501 Pollutant(s): ❑ Periodic Emission Monitoring Using Portable Monitors - Form 2000-502 Pollutant(s): X Monitoring Control System Parameters or Operating Parameters of a Process - Form 2000-503 Pollutant(s): VOCs, HAPs ❑ Monitoring Maintenance Procedures - Form 2000-504 Pollutant(s): X Stack Testing - Form 2000-505 Pollutant(s): RTO: Destruction efficiency for VOCs, outlet testing for VOC, SO2 ❑ Fuel Sampling and Analysis (FSA) - Form 2000-506 Pollutant(s): X Recordkeeping - Form 2000-507 Pollutant(s): VOCs/HAPs X Other (please describe) - Form 2000-508 Pollutant(s): Opacity 6. Compliance certification reports will be submitted to the Division according to the following schedule: Start date: February 1, 2002 and every 12 months thereafter. (12 month maximum interval) Compliance monitoring reports will be submitted to the Division according to the following schedule: Start date: August 1, 2001 and every 6 months thereafter. (6 month maximum interval) NOTE: EACH APPLICABLE REQUIREMENT ON FORM 2000-604 NEEDS TO BE SPECIFICALLY ADDRESSED IN ITEM 5. 15 Operating Permit Application COMPLIANCE CERTIFICATION - MONITORING AND REPORTING FORM 2000-500 Colorado Department of Public Health and Environment DESCRIPTION OF METHODS USED Rev 06-95 Air Pollution Control Division FOR DETERMINING COMPLIANCE All applicants are required to certify compliance with all applicable air pollution permit requirements by including a statement within the permit application of the methods used for determining compliance. This statement must include a description of the monitoring, recordkeeping, and reporting requirements and test methods. In addition, the application must include a schedule for compliance certification submittals during the permit term. These submittals must be no less frequent than annually, and may need to be more frequent if specified by the underlying applicable requirement or by the Division. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: ECD-1, RTO-1 4. Unit identification code: P-136 5. For this Unit the following method(s) for determining compliance with the requirements of the permit will be used (check all that apply and attach the appropriate form(s) to this form). ❑ Continuous Emission Monitoring (CEM) - Form 2000-501 Pollutant(s): ❑ Periodic Emission Monitoring Using Portable Monitors - Form 2000-502 Pollutant(s): X Monitoring Control System Parameters or Operating Parameters of a Process - Form 2000-503 Pollutant(s): VOCs, HAPs ❑ Monitoring Maintenance Procedures - Form 2000-504 Pollutant(s): X Stack Testing - Form 2000-505 Pollutant(s): RTO: destruction efficiency for VOCs , outlet testing for SO2 ❑ Fuel Sampling and Analysis (FSA) - Form 2000-506 Pollutant(s): x Recordkeeping - Form 2000-507 Pollutant(s): VOCs/HAPs x Other (please describe) - Form 2000-508 Pollutant(s): Opacity 6. Compliance certification reports will be submitted to the Division according to the following schedule: Start date: February 1, 2002 and every 12 months thereafter. (12 month maximum interval) Compliance monitoring reports will be submitted to the Division according to the following schedule: Start date: August 1, 2001 and every 6 months thereafter. (6 month maximum interval) NOTE: EACH APPLICABLE REQUIREMENT ON FORM 2000-604 NEEDS TO BE SPECIFICALLY ADDRESSED IN ITEM 5. 16 Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-503 Colorado Department of Public Health and Environment MONITORING CONTROL SYSTEM PARAMETERS OR Rev 06-95 Air Pollution Control Division OPERATING PARAMETERS OF A PROCESS The monitoring of a control system parameter or a process may be acceptable as a compliance demonstration method provided that a correlation between the parameter value and the emission rate of a particular pollutant is established in the form of a curve of emission rate versus parameter values. Ideally stack test data that bracket the emission limit, if possible, could be used to define the emission curve. This correlation shall constitute the certification of the system. It should be attached for Division approval. If it is not attached, please submit it within 60 days of the startup of the system. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: ECD-1, RTO-1 4. Unit identification code: P033 5. Pollutant(s) being monitored: VOC, HAPs 6. Name of manufacturer: 7. Model number: 8. Is this an existing system? X Yes ❑ No 9. Reserved for future use 10. Describe the method of monitoring: Per O&M Plan, lean glycol recirculation rate is monitored by recording the strokes per minute daily and converting to circulation rate, inlet gas volume is metered, combustion chamber temperature of RTO is recorded daily, and pilot light of enclosed combustor is monitored by thermocouple daily with visual inspection backup 11. Backup system: 12. Quality Assurance/Quality Control: Any monitoring system used with the record keeping shall be subject to appropriate performance specifications, calibration requirements and quality assurance procedures. ❑ A quality assurance/quality control plan for the monitoring system is attached for Division review. ❑ The plan is not attached, but will be submitted to the Division by Parameter monitoring is conducted as specitied in O&M Plan approved by Division as part of construction permit process. 13. The applicant shall propose an appropriate averaging period, (i.e., a particular number of continuous hours) for the purpose of defining excess emissions. The Division may approve the proposed averaging period, or other period which the Division determines to be appropriate. Provide the proposed averaging period(s) below. Parameter Averaging Period 17 Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-503 Colorado Department of Public Health and Environment MONITORING CONTROL SYSTEM PARAMETERS OR Rev 06-95 Air Pollution Control Division OPERATING PARAMETERS OF A PROCESS The monitoring of a control system parameter or a process may be acceptable as a compliance demonstration method provided that a correlation between the parameter value and the emission rate of a particular pollutant is established in the form of a curve of emission rate versus parameter values. Ideally stack test data that bracket the emission limit, if possible, could be used to define the emission curve. This correlation shall constitute the certification of the system. It should be attached for Division approval. If it is not attached, please submit it within 60 days of the startup of the system. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: ECD-1, RTO-1 4. Unit identification code: P-136 5. Pollutant(s) being monitored: VOC, HAPs 6. Name of manufacturer: 7. Model number: 8. Is this an existing system? X Yes ❑ No 9. Reserved for future use 10. Describe the method of monitoring: Per O&M Plan, lean glycol recirculation rate is monitored by recording the strokes per minute daily and converting to circulation rate, inlet gas volume is metered, combustion chamber temperature of RTO is recorded daily, and pilot light of enclosed combustor is monitored by thermocouple daily with visual inspection backup 11. Backup system: 12. Quality Assurance/Quality Control: Any monitoring system used with the record keeping shall be subject to appropriate performance specifications, calibration requirements and quality assurance procedures. ❑ A quality assurance/quality control plan for the monitoring system is attached for Division review. ❑ The plan is not attached, but will be submitted to the Division by Parameter monitoring is conducted as specified in O&M Plan approved by Division as part ot construction permit process. 13. The applicant shall propose an appropriate averaging period, (i.e., a particular number of continuous hours) for the purpose of defining excess emissions. The Division may approve the proposed averaging period, or other period which the Division determines to be appropriate. Provide the proposed averaging period(s) below. Parameter Averaging Period 18 Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-507 Colorado Department of Public Health and Environment BY RECORDKEEPING Rev 06-95 Air Pollution Control Division Recordkeeping may be acceptable as a compliance demonstration method provided that a correlation between the parameter value recorded and the emission rate of a particular pollutant is established in the form of a curve or chart of emission rate versus parameter values. This correlation may constitute the certification of the system. For an existing program, the correlation demonstration must be attached for Division consideration for approval. If the correlation information has not yet been developed, please submit it within 60 days of the startup of the system. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: S025 4. Unit identification code: P025 5. Pollutant(s) being monitored: VOCs/HAPs 6. Material or parameter being monitored and recorded: Component count 7. Method of monitoring and recording (see information on back of this page): A record of all components is maintained. A plant inlet gas analysis is performed according to appropriate ASTM or EPA approved methods annually. VOC emissions are calculated by multiplying the component count, the VOC/HAP percentages, the EPA emission factors, and 8760 hours/year. 8. List any EPA methods used: Protocol for Equipment Leak Emission Estimates, EPA, November 1995, EPA -453/R-95-017 9. Is this an existing method of demonstrating compliance? X Yes ❑ No 10. Start date: 11. Backup system: 12 a. Data collection frequency: ❑ Daily ❑ Weekly ❑ Monthly ❑ Batch (not to exceed monthly) X Other — specify Annual extended gas analysis 12 b. Compliance shall be demonstrated: ❑ Daily ❑ Weekly X Monthly ❑ Batch (not to exceed monthly) ❑ Other - specify 13. Quality Control/Quality Assurance: The monitoring system shall be subject to appropriate performance specifications, calibration requirements, and quality assurance procedures. A quality assurance/quality control plan for the recordkeeping system is attached for Division review. The plan is not attached, but will be submitted to the Division by DCP currently conducts recordkeeping associated with this facility. DCP uses an internal database to ensure the recordkeeping is being conducted on the proper frequency and that the correct information is being gathered. 14. ❑ A proposed format for the compliance certification report and excess emission report is attached. DCP currently submits compliance certification reports and excess emission reports to CDPHE/APCD as required. The format for these submittals can be found in the previous submittals from DCP. ***** The compliance records shall be available for Division inspection. ***** . The source shall record any malfunction that causes or may cause an emission limit to be exceeded. Malfunctions shall be reported to the Division the next business day. Hazardous air releases shall be reported to the Division immediately. ***** 19 Operating Permit Application BY RECORDKEEPING EPING Rev 06 95 Colorado Department of Public Health and Environment Recordkeeping may be acceptable as a compliance demonstration method provided that a correlation between the parameter value recorded and Pollution Control Division the emission rate of a particular pollutant is established in the form of a curve or chart of emission rate versus parameter values. This correlation may constitute the certification of the system. For an existing program, the correlation demonstration must be attached for Division consideration for approval. If the correlation information has not yet been developed, please submit it within 60 days of the startup of the system. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant COMPLIANCE DEMONSTRATION FORM 2000-507 2. Facility identification code: CO1230049 3. Stack identification code: ECD-1, RTO-1 5. Pollutant(s) being monitored: 6. Material or parameter being monitored and recorded: VOCs /HAPs Inlet gas volume, glycol recirculation rate, inlet gas temperature & pressure, RTO combustion chamber temperature, enclosed combustor pilot light, inlet gas composition 7. Method of monitoring and recording (see information on back of this page): Compliance is demonstrated by running GLYCALC on a monthly basis using the most recent wet gas analysis and recorded operational values (gas volume processed, lean glycol recirculation rate, and other operational values in O&M Plan). With the exception of inlet gas volume, recorded operational values are averaged monthly for use in GLYCALC. 4. Unit identification code: P033 8. List any EPA methods used: 9. Is this an existing method of demonstrating compliance? X Yes ❑ No 10. Start date: 11. Backup system: 12 a. Data collection frequency: X Daily x Weekly X Monthly ❑ Batch (not to exceed monthly) X Other — specify Annual extended gas analysis, daily lean glycol recirculation rate, monthly gas processed, weekly inlet gas temperature and pressure, daily RTO combustion chamber temperature, daily enclosed combustor pilot light monitoring (see O&M Plan) 12 b. Compliance shall be demonstrated: ❑ Daily ❑ Weekly X Monthly ❑ Batch (not to exceed monthly) ❑ Other - specify 13. Quality Control/Quality Assurance: The monitoring system shall be subject to appropriate performance specifications, calibration requirements, and quality assurance procedures. A quality assurance/quality control plan for the recordkeeping system is attached for Division review. The plan is not attached, but will be submitted to the Division by DCP currently conducts recordkeeping associated with this facility. DCP uses an internal database to ensure the recordkeeping is being conducted on the proper frequency and that the correct information is being gathered. 14. ❑ A proposed format for the compliance certification report and excess emission report is attached. DCP currently submits compliance certification reports and excess emission reports to CDPHE/APCD as required. The format for these submittals can be found in the previous submittals from DCP. ***** The compliance records shall be available for Division inspection. ***** The source shall record any malfunction that causes or may cause an emission limit to be exceeded. Malfunctions shall be reported to the Division the next business day. Hazardous air releases shall be reported to the Division immediately. ***** 20 Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-507 Colorado Department of Public Health and Environment BY RECORDKEEPING Rev 06-95 Air Pollution Control Division Recordkeeping may be acceptable as a compliance demonstration method provided that a correlation between the parameter value recorded and the emission rate of a particular pollutant is established in the form of a curve or chart of emission rate versus parameter values. This correlation may constitute the certification of the system. For an existing program, the correlation demonstration must be attached for Division consideration for approval. If the correlation information has not yet been developed, please submit it within 60 days of the startup of the system. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: ECD-1, RTO-1 4. Unit identification code: P-136 5. Pollutant(s) being monitored: 6. Material or parameter being monitored and recorded: VOCs /HAPs Inlet gas volume, glycol recirculation rate, inlet gas temperature & pressure, RTO combustion chamber temperature, enclosed combustor pilot light, inlet gas composition 7. Method of monitoring and recording (see information on back of this page): Compliance is demonstrated by running either PROMAX or GLYCALC on a monthly basis using the most recent wet gas analysis and recorded operational values (gas volume processed, lean glycol recirculation rate, and other operational values in O&M Plan). With the exception of inlet gas volume, recorded operational values are averaged monthly for use in GLYCALC/PROMAX. 8. List any EPA methods used: 9. Is this an existing method of demonstrating compliance? XYes No 10. Start date: 11. Backup system: 12 a. Data collection frequency: X Daily x Weekly X Monthly ❑ Batch (not to exceed monthly) X Other - specify Annual extended gas analysis, daily lean glycol recirculation rate, monthly gas processed, weekly inlet gas temperature and pressure, daily RTO combustion chamber temperature, daily enclosed combustor pilot light monitoring (see O&M Plan) 12 b. Compliance shall be demonstrated: ❑ Daily ❑ Weekly X Monthly ❑ Batch (not to exceed monthly) ❑ Other - specify 13. Quality Control/Quality Assurance: The monitoring system shall be subject to appropriate performance specifications, calibration requirements, and quality assurance procedures. A quality assurance/quality control plan for the recordkeeping system is attached for Division review. The plan is not attached, but will be submitted to the Division by DCP currently conducts recordkeeping associated with this facility. DCP uses an internal database to ensure the recordkeeping is being conducted on the proper frequency and that the correct information is being gathered. 14. ❑ A proposed format for the compliance certification report and excess emission report is attached. DCP currently submits compliance certification reports and excess emission reports to CDPHE/APCD as required. The format for these submittals can be found in the previous submittals from DCP. ***** ***** The compliance records shall be available for Division inspection. The source shall record any malfunction that causes or may cause an emission limit to be exceeded. ***** Malfunctions shall be reported to the Division the next business day. Hazardous air releases shall be reported to the Division immediately. 21 Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-508 Rev 06-95 Colorado Department of Public Health and Environment BY OTHER METHODS Air Pollution Control Division 1. Facility Name: Roggen Gas Plant 2. Facility identification code: CO1230049 4. Unit Identification code: P025 3. Stack identification code: S025 5. Pollutant(s) or Parameter(s) being monitored: Number of leaking components 6. Description of the method of monitoring: Leak detection and repair (LDAR) program established and implemented under NSPS 40 CFR 60, Subpart KKK 7. Compliance shall be demonstrated: (Specify the frequency with which compliance will be demonstrated) Compliance is demonstrated by submission of semi-annual reports required under Subpart KKK 22 Operating Permit Application COMPLIANCE DEMONS'! RATION FORM 2000-508 Colorado Department of Public Health and Environment BY OTHER METHODS Rev 06-95 Air Pollution Control Division 1. Facility Name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: ECD-1, RTO-1 4. Unit Identification code: P033 5. Pollutant(s) or Parameter(s) being monitored: Opacity 6. Description of the method of monitoring: Opacity of the effluent from the enclosed combustor is monitored by daily Method 22 readings. Opacity of the effluent from the RTO was monitored by a one-time Method 22 reading. 7. Compliance shall be demonstrated: (Specify the frequency with which compliance will be demonstrated) Compliance will be demonstrated by submission of annual compliance reports 23 Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-508 Colorado Department of Public Health and Environment BY OTHER METHODS Rev 06-95 Air Pollution Control Division 1. Facility Name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: ECD-1, RTO-1 4. Unit Identification code: P-136 5. Pollutant(s) or Parameter(s) being monitored: Opacity 6. Description of the method of monitoring: Opacity of the effluent from the enclosed combustor is monitored by daily Method 22 readings. Opacity of the effluent from the RTO was monitored by a one-time Method 22 reading. 7. Compliance shall be demonstrated: (Specify the frequency with which compliance will be demonstrated) Compliance will be demonstrated by submission of annual compliance reports 24 Operating Permit Application COMPLIANCE DEMONSTRATION BY STACK TESTING FORM 2000-505 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division The performance of an EPA stack test method is acceptable for demonstrating compliance with an emission limitation. EPA test methods contain quality assurance procedures that shall be strictly adhered to by the source. The applicant shall propose an appropriate program of stack testing for compliance demonstration. The stack testing program shall correlate with the corresponding emission limitation in terms of the frequency and duration of the stack tests. The Division may approve the proposed stack testing program, or other programs which the Division determines to be appropriate. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: RTO-1 4. Unit identification code: P033 5. Pollutant being monitored: VOCs and SO2 6. Procedure being monitored: Inlet and outlet testing of RTO to demonstrate minimum destruction efficiency and compliance with construction permit (10WE1659) emission limits 7. Is this an existing method of demonstrating compliance? X Yes ❑ No 8. Program start date: 9. EPA or Division approved test method: Air Pollution Control Division Compliance Test Manual 10. Backup system 11. Compliance shall be demonstrated: ❑ Daily ❑ Weekly compliance test ***** ❑ Monthly x Other - specify One time, initial Any measured emission rate that exceeds an emission limitation established by the permit shall be ***** reported as an excess emission. 25 Operating Permit Application COMPLIANCE DEMONSTRATION BY STACK TESTING FORM 2000-505 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division The performance of an EPA stack test method is acceptable for demonstrating compliance with an emission limitation. EPA test methods contain quality assurance procedures that shall be strictly adhered to by the source. The applicant shall propose an appropriate program of stack testing for compliance demonstration. The stack testing program shall correlate with the corresponding emission limitation in terms of the frequency and duration of the stack tests. The Division may approve the proposed stack testing program, or other programs which the Division determines to be appropriate. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: RTO-1 4. Unit identification code: P-136 5. Pollutant being monitored: VOCs and SO2 6. Procedure being monitored: Inlet and outlet testing of RTO to demonstrate minimum destruction efficiency and compliance with construction permit (10WE1659) emission limits 7. Is this an existing method of demonstrating compliance? XYes ON 8. Program start date: 9. EPA or Division approved test method: Air Pollution Control Division Compliance Test Manual 10. Backup system 11. Compliance shall be demonstrated: ❑ Daily ❑ Weekly compliance test ❑ Monthly X Other - specify One time, initial ***** Any measured emission rate that exceeds an emission limitation established by the permit shall be ***** reported as an excess emission. 26 Operating Permit Application EMISSION UNIT CRITERIA AIR POLLUTANTS Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE FORM 2000-601 09-94 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: S025 4. Unit identification code: P025 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached ❑ Emissions listed are emission limits from construction permit 10WE1659, Issuance 5 Air pollutant Actual Potential to emit Maximum allowable Quantity U TPY U TPY Particulates (TSP) TPY PM -10 TPY Nitrogen oxides TPY Volatile organic compounds 33.5 TPY 33.5 Carbon monoxide TPY Lead TPY Sulfur dioxide TPY Total reduced sulfur TPY Reduced sulfur compounds TPY Hydrogen sulfide TPY Sulfuric Acid Mist TPY Fluorides TPY TPY TPY TPY TPY Units (U) should be entered as follows: 1 = lb/hr 2 = lb/mmBTU 3 = grains/dscf 4 = lb/ gallon 5 = ppmdv 6 = gram/HP-hour 7 = Ib/mmscf 8 = other (specify) 9 = other (specify) 10 = other (specify) 27 EMISSION UNIT CRITERIA AIR POLLUTANTS -- Form 2000-601 Operating Permit Application EMISSION UNIT CRITERIA AIR POLLUTANTS FORM 2000-601 Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 09-94 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: ECD-1, RTO-1 4. Unit identification code: P033 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached 0 Emissions listed are emission limits from construction permit 01WE0208, Issuance 1 Air pollutant Actual Potential to emit Maximum allowable Quantity U TPY U TPY Particulates (TSP) TPY PM -10 TPY Nitrogen oxides TPY Volatile organic compounds 0 . 6 TPY 0 . 6 Carbon monoxide TPY Lead TPY Sulfur dioxide TPY Total reduced sulfur TPY Reduced sulfur compounds TPY Hydrogen sulfide TPY Sulfuric Acid Mist TPY Fluorides TPY TPY TPY TPY TPY Units (U) should be entered as follows: 1 = lb/hr 2 = lb/mmBTU 3 = grains/dscf 4 = lb/ gallon 5 = ppmdv 6 = gram/HP-hour 7 = lb/mmscf 8 = other (specify) 9 = other (specify) 10 = other (specify) 28 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant EMISSION UNIT CRITERIA AIR POLLUTANTS -- Form 2000-601 EMISSION UNIT CRITERIA AIR POLLUTANTS FORM 2O00-601 09-94 3. Stack identification code: ECD-1, RTO-1 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached ❑ Emissions listed are emission limits from construction permit 10WE1659, 2. Facility identification code: CO1230049 Issuance 5 4. Unit identification code: P-136 Air pollutant Actual Potential to emit Maximum allowable Quantity Particulates (TSP) PM -10 Nitrogen oxides Volatile organic compounds Carbon monoxide Lead Sulfur dioxide Total reduced sulfur Reduced sulfur compounds Hydrogen sulfide Sulfuric Acid Mist Fluorides U Units (U) should be entered as follows: 1 = lb/hr 2 = lb/mmBTU 3 = grains/dscf 4 = lb/ gallon 5 = ppmdv 6 = gram/HP-hour 7 = lb/mmscf 8 = other (specify) 9 = other (specify) 10 = other (specify) TPY U TPY 29 EMISSION UNIT CRITERIA AIR POLLUTANTS -- Form 2OOO-6O1 Operating Permit Application PLANT -WIDE HAZARDOUS AIR POLLUTANTS Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE FORM 2000-602 Rev 06-95 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Complete the following emissions summary for all hazardous air emissions at this facility. Calculations attached. Attach a copy of all calculations to this form. Attached 0 Emissions listed are limits from Roggen Gas Plant construction permits, including 01WE0208, Issuance 1 and 10WE1659, Issuance 5 Pollutant CAS Common or Generic Pollutant Name Actual emissions Allowable OR Potential to emit Quantity Units Quantity Units All HAPs 20.0 TPY Any individual HAP 8.0 TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY NOTE: If there is a permit for this unit, the permit limits are the same as the potential to emit. 30 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: ECD-1, RTO-1 4. Unit identification code: P-136 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT NOx 10WE1659, Issuance 5, Condition 5 Annual emissions shall not exceed 2.6 tpy X CO 10WE1659, Issuance 5, Condition 5 Annual emissions shall not exceed 14.3 tpy X VOC l0WE1659, Issuance 5, Condition 5 Annual emissions shall not exceed 21.6 tpy X 10. Other requirements (e.g., malfunction existing permit such as material reporting, special operating conditions usage, hours of operation, etc.) from an State Only Compliance Status IN OUT l0WE1659, Issuance 5, Condition most current construction 4: Retain final authorization permit letter with X l0WE1659, Issuance 5, Condition NOx, CO, and VOC limits of each month 5: Demonstrate compliance by calculating a new 12 month total with annual by the end X l0WE1659, Issuance 5, Condition running either PROMAX or gas analysis and recorded lean glycol recirculation in the O&M Plan). Recorded shall be averaged on a monthly 7: Compliance shall be demonstrated GLYCalc monthly using most recent operational values (including gas rate, and other operational values operational values, except gas basis. by plant inlet throughput, specified throughput, X l0WE1659, Issuance 5, Condition RTO or an enclosed combustor. emissions of VOC from the listed in Condition 5. The minimum destruction efficiency 8: Route still vent vapors to The RTO or enclosed combustor TEG dehydration unit to the emission RTO or enclosed combustor shall of 97%. either the shall reduce levels achieve a X 10WE1659, Issuance 5, Condition be recycled to the plant 9: 100% of flash tank emissions inlet and recompressed. shall X l0WE1659, Issuance 5, Condition exceed 31,025 MMscf/yr 13: Natural gas throughput shall not X 10WE1659, Issuance 5, Condition gas throughput 13: Maintain monthly records of actual x l0WE1659, Issuance 5, Condition a new 12 month total. 13: By the end of each month, calculate X l0WE1659, Issuance 5, Condition rate to 24 gallons per minute. in a log and make available 14: Limit maximum lean glycol Record lean glycol circulation upon request. circulation rate daily X l0WE1659, Issuance 5, Condition number and AIRS ID. 16: Mark subject equipment with permit X l0WE1659, Issuance 5, Condition 20% opacity during normal modification, or adjustment not exceed 30% for more 17. Visible emissions shall operation. During startup, process of control equipment visible emissions than 6 minutes in any 60 consecutive not exceed shall minutes. X l0WE1659, Issuance 5, Condition actual emissions of VOCs reduced by at least 90% equipment. Comply with the X11.H. 21: Beginning May 1, 2005, form the still vent and flash tank through the use of air pollution general provisions of Regulation uncontrolled shall be control 7, Section X APPLICABLE REQUIREMENTS AND STATUS OF EMISSION UNIT FORM 2000-604 Rev 06-95 31 **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 32 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant SUPPLEMENTAL INFORMATION FORM 2000-700 09-94 2. Facility identification code: CO1230049 3. This form supplements Form 2000 - 604 for Emission Unit (e.g. B001, P001, etc.) P-136 Additional Information, Diagrams Item Number 10 10. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, hours of operation, etc.) State Only Compliance Status IN OUT 10WE1659, Issuance 5, Condition 22: The RTO is subject to Regulation No. 7, Sections XVII.B.1.a and XVII.B.l.c General Provisions. Combustion device used to control emissions of VOCs, shall be enclosed, have no visible emissions during normal operations, and be designed so that observer can, by means of visual observation form outside of the combustion device, or other convenient means approved by the Division, determine whether it is operating properly. Comply with all requirements of Sections XVII.B.l.a and XVII.B.l.c. 10WE1659, Issuance 5, Condition 23: The enclosed combustor is subject to Regulation No. 7, Sections XVII.B.1.a and XVII.B.l.c General Provisions. Combustion device used to control emissions of VOCs, shall be enclosed, have no visible emissions during normal operations, and be designed so that observer can, by means of visual observation form outside of the combustion device, or other convenient means approved by the Division, determine whether it is operating properly. Comply with all requirements of Sections XVII.B.l.a and XVII.B.l.c. l0WE1659, Issuance 5, Condition 23: All combustion devices used to control emissions of hydrocarbons must be equipped with and operate an auto -igniter. 10WE1659, Issuance 5, Condition 24: The equipment is subject to the control requirements under Regulation No. 7, Section XVII.D. Beginning May 1, 2008, uncontrolled actual emissions of VOCs from the still vent and flash tank shall be reduced by an average of at least 90; through the use of air pollution control equipment. l0WE1659, Issuance 5, Condition 24: The equipment is subject to the control requirements under Regulation No. 7, Section XVII.D. Beginning May 1, 2015, uncontrolled actual emissions of VOCs from the still vent and flash tank shall be reduced by an average of at least 9595 on a 12 -month rolling basis through the use of air pollution control equipment. 10WE1659, Issuance 5, Condition 24: If a combustion device is used, it shall have a design destruction efficiency of at least 986 for hydrocarbons. Comply with all applicable general provisions of Regulation No. 7, Section XVII. 10WE1659, Issuance 5, Condition 25: Comply with all applicable provisions of 40 CFR 63, Subpart HH, including, for source not located in an Urban -1 county, the construction or reconstruction of which commences on or after July 8, 2005, achieve compliance with provisions of subpart upon initial startup or by January 3, 2007, whichever is later. 10WE1659, Issuance 5, Condition 25: Comply with all applicable provisions of 40 CFR 63, Subpart HH, including General Standards. Calculate optimum glycol circulation rate and operate so that actual glycol circulation rate does not exceed the optimum rate. 10WE1659, Issuance 5, Condition 25: Maintain a record of the optimum glycol circulation rate determination and submit an Initial Notification including the information required by 63.775(c)(7). 10WE1659, Issuance 5, Condition 25: Maintain records of all information required by Subpart HH and retain for at least 5 years. X X X X X X X X X X X X X X X X 33 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SUPPLEMENTAL INFORMATION FORM 2000-700 09-94 SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. This form supplements Form 2000 - 604 for Emission Unit (e.g. B001, P001, etc.) P-136 Additional Information, Diagrams Item Number 10 10. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, hours of operation, etc.) State Only Compliance Status IN OUT lOWE1659, Issuance 5, Condition 25: Submit notification of process change if applicable X lOWE1659, Issuance 5, Condition 25: If not subject to the optimum glycol circulation requirements, comply with the area source requirements of Subpart HH, including General Standards, Test Methods, Compliance Procedures, Compliance Demonstration, Recordkeeping, and Reporting X lOWE1659, Issuance 5, Condition 29: Follow O&M Plan and recordkeeping format approved by the Division X lOWE1659, Issuance 5, Condition 30: When RTO is used to control emissions, the combustion chamber temperature shall be recorded daily and information maintained in log on site X lOWE1659, Issuance 5, Condition 30: When RTO is used to control emissions, the operating temperature shall be >1450 deg F at all times emissions are vented to the RTO X lOWE1659, Issuance 5, Condition 33: Complete initial annual extended wet gas analysis and submit to Division as part of self -certification X lOWE1659, Issuance 5, Condition 34: Initial Testing: Demonstrate compliance with opacity standards for RTO/enclosed combustor using EPA Method 22 X lOWE1659, Issuance 5, Condition 35: Initial compliance test shall be performed on combined streams routed to RTO to measure emissions rate for VOCs and SO2 to demonstrate compliance with emission limits in permit. Test shall include inlet and outlet testing for VOC to demonstrate minimum destruction efficiency of 97% as well as outlet testing for 502. Test protocol in accordance with Air Pollution Control Division Compliance Test Manual shall be submitted for review/approval at least 30 days prior to test. X lOWE1659, Issuance 5, Condition 38: Complete annual extended wet gas analysis of plant inlet. Use results to calculate emissions of criteria pollutants and HAPs per Condition 7. X 10WE1659, Issuance 5, Condition 39: Demonstrate compliance with opacity standards for enclosed combustor using EPA Method 22 daily. X 10WE1659, Issuance 5, Condition 43: Submit revised APEN annually if there is a significant increase in emissions, when there is an owner/operator change, whenever there is a control equipment change, whenever a permit limit must be modified, no later than 30 days before existing APEN expires X lOWE1659, Issuance 5, Condition 47: Retain permit and attachments, make available upon request X lOWE1659, Issuance 5, Condition 52: Pay annual fees as required X 34 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SUPPLEMENTAL INFORMATION FORM 2000-700 09-94 SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. This form supplements Form 2000 - 604 for Emission Unit (e.g. B001, P001, etc.) P-136 Additional Information, Diagrams Item Number Compliance demonstration methods Requirement lOWE1659, Issuance 5, Conditions 5: Emission limits lOWE1659, Issuance letter/permit lOWE1659, Issuance by the end of each lOWE1659, Issuance monthly lOWE1659, Issuance either the RTO or an enclosed combustor with minimum destruction efficiency of 97%. 10WE1659, Issuance 5, Condition 9: Flash tank emissions recycled to the plant inlet. lOWE1659, Issuance 5, Condition 13: Natural gas throughput shall not exceed 31,025 MMscf/yr lOWE1659, Issuance 5, Condition 13: Maintain monthly records of actual gas throughput 10WE1659, Issuance 5, Condition 13: Calculate new 12 month totals monthly. lOWE1659, Issuance 5, Condition 14: Limit maximum lean glycol circulation rate to 24 gallons per minute; record daily. 5, Condition 4: Retain authorization 5, Condition 5: Calculate new 12 month total month 5, Condition 7: Run either PROMAX or GLYCalc 5, Condition 8: Route still vent vapors to 10WE1659, Issuance 5, Condition 16: Mark equipment with permit number and AIRS ID. 10WE1659, Issuance 5, Condition 17. Visible emissions shall not exceed 20% opacity during normal operation; 30% during startup, process modification, or adjustment of control equipment lOWE1659, Issuance 5, Condition 21: Reduce emissions of VOCs from still vent & flash tank shall by at least 90%. lOWE1659, Issuance 5, Condition 22: RTO shall be enclosed, no visible emissions during normal operations, and designed so that observer can determine whether it is operating properly. 10WE1659, Issuance 5, Condition 23: Enclosed combustor shall be enclosed, no visible emissions during normal operations, and designed so that observer can determine whether it is operating properly. l0WE1659, Issuance 5, Condition 23: Equip/operate enclosed combustor with auto -igniter. lOWE1659, Issuance 5, Condition 24: Reduce VOC emissions from still vent & flash by at least 90% by May 1, 2005 and by at least 95% by May 1, 2015. lOWE1659, Issuance 5, Condition 24: RTO/enclosed combustor shall have a design destruction efficiency of at least 98% for hydrocarbons. 10WE1659, Issuance 5, Condition 25: Comply with all applicable provisions of 40 CFR 63, Subpart HH 10WE1659, Issuance 5, Condition 29: Follow O&M Plan and recordkeeping format approved by the Division lOWE1659, Issuance 5, Condition 30: RTO combustion chamber temperature shall be recorded daily in log Compliance Method One time stack test, monthly records and calculations kept in DCP compliance database Recordkeeping/file system Records and calculations in DCP compliance database Records and calculations in DCP compliance database Vendor specifications, one-time stack test RTO Plant/unit design specifications Records and calculations compliance database Records and calculations compliance database Records and calculations compliance database Records and calculations compliance database/log Visual inspection in DCP in DCP in DCP in DCP Initial Method 22 RTO & enclosed combustor; daily Method 22 enclosed combustor Vendor specifications/one-time stack test RTO RTO specifications Enclosed combustor specifications Specifications Vendor specifications/one-time stack test RTO Vendor specifications/one-time stack test RTO Optimum glycol circulation rate calculation, location designation, Initial Notification on file. Actual glycol circulation rate in DCP compliance database Records kept in DCP compliance database, log Records kept in DCP compliance database, log 35 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant SUPPLEMENTAL INFORMATION FORM 2000-700 09-94 2. Facility identification code: CO1230049 3. This form supplements Form 2000 - 604 for Emission Unit (e.g. B001, P001, etc.) P-136 Additional Information, Diagrams Item Number: Compliance demonstration methods Requirement l0WE1659, Issuance 5, Condition 30: RTO operating temperature shall be >1450 deg F at all times emissions are vented to the RTO l0WE1659, Issuance 5, Condition 33: Complete initial annual extended wet gas analysis l0WE1659, Issuance 5, Condition 34: Initial Testing: Demonstrate compliance with opacity standards for RTO/enclosed combustor using EPA Method 22 l0WE1659, Issuance 5, Condition 35: Initial compliance test on combined streams routed to RTO to demonstrate compliance with emission limits and demonstrate minimum destruction efficiency of 970. Test protocol shall be submitted at least 30 days prior to test. l0WE1659, Issuance 5, Condition 38: Complete annual extended wet gas analysis of plant inlet. l0WE1659, Issuance 5, Condition 39: Demonstrate compliance with opacity standards for enclosed combustor using EPA Method 22 daily. 10WE1659, Issuance 5, Condition 43: Submit revised APEN as required l0WE1659, Issuance 5, Condition 47: Retain permit and attachments, make available upon request 10WE1659, Issuance 5, Condition 52: Pay annual fees as required Compliance Method Records kept in DCP compliance database, log Recordkeeping/file system Recordkeeping/file system Recordkeeping/file system Recordkeeping/file system Recordkeeping/file system Recordkeeping/file system Recordkeeping/file system Recordkeeping/file system 36 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant APPLICABLE REQUIREMENTS AND STATUS OF EMISSION UNIT Rev 06-95 2. Facility identification code: CO1230049 FORM 2000-604 3. Stack identification code: S025 4. Unit identification code: P025 5. Pollutant V0C 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT 10WE1659, Issuance 5, Condition 5 Annual emissions shall not exceed 33.5 tpy X 10. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, hours of operation, etc.) State Only Compliance Status IN OUT l0WE1659, Issuance 5, Condition 4: Retain final authorization letter with most current construction permit l0WE1659, Issuance 5, Condition 5: Demonstrate compliance with annual V0C limits by calculating a new 12 month total by the end of each month l0WE1659, Issuance 5, Condition 6: Calculate actual emissions using representative actual component counts and most recent gas analysis l0WE1659, Issuance 5, Condition 19-20, 37: Comply with LDAR requirements of Regulation 6, Part A, Subpart KKK, including standards 10WE1659, Issuance 5, Condition 19-20, 37: Keep records required by Regulation 6, Part A, Subpart KKK and 40 CFR 60, Subpart A for at least 2 years 10WE1659, Issuance 5, Condition 19-20, 37: Submit semi-annual reports required by Regulation 6, Part A, Subpart KKK l0WE1659, Issuance 5, Condition 29: Follow recordkeePing format approved x X X X X by APCD l0WE1659, Issuance 5, Condition 36: Complete an annual extended gas analysis representative of V0Cs/HAPs released as fugitive emissions and use in compliance demonstrations l0WE1659, Issuance 5, Condition 43: Submit revised APEN annually if there is a significant increase in emissions, when there is an owner/operator change, whenever there is a control equipment change, whenever a permit limit must be modified, no later than 30 days before existing APEN expires 10WE1659, Issuance 5, Condition 47: Retain permit and attachments, make available upon request l0WE1659, Issuance 5, Condition 52: Pay annual fees as required **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 37 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SUPPLEMENTAL INFORMATION FORM 2000-700 09-94 SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: C01230049 3. This form supplements Form 2000 - 604 for Emission Unit (e.g. B001, P001, etc.) P025 Additional Information, Diagrams Item Number Compliance demonstration methods Requirement lOWE1659, Issuance 5, Condition 5: Emission limit 10WE1659, Issuance 5, Condition 4: Retain final authorization letter with most current construction permit 10WE1659, Issuance 5, Condition 5: Demonstrate compliance with annual VOC limits by calculating a new 12 month total by the end of each month lOWE1659, Issuance 5, Condition 6: Calculate actual emissions using representative actual component counts and most recent gas analysis lOWE1659, Issuance 5, Condition 19-20, 37: Comply with LDAR requirements of Regulation 6, Part A, Subpart KKK lOWE1659, Issuance 5, Condition 29: Follow recordkeeping format approved by APCD 10WE1659, Issuance 5, Condition 36: Complete an annual extended gas analysis and use in compliance demonstrations 10WE1659, Issuance 5, Condition 43: Submit revised APEN as needed lOWE1659, Issuance 5, Condition 47: Retain permit and attachments 10WE1659, Issuance 5, Condition 52: Pay annual fees as required Compliance Method Monthly records and calculations kept in DCP compliance database Recordkeeping/file system Records and calculations in DCP compliance database Records and calculations in DCP compliance database Semi-annual 40 CFR 60, Subpart KKK reports Recordkeeping/file system Recordkeeping/file system; Records and calculations in DCP compliance database Recordkeeping/file system Recordkeeping/file system Recordkeeping/file system 38 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant APPLICABLE REQUIREMENTS AND STATUS OF EMISSION UNIT 2. Facility identification code: CO1230049 3. Stack identification code: ECD-1, RTO-1 5. Pollutant VOC 6. Colorado Air Quality Regulations or Construction Permit Number 01WE0208, Issuance 1, Condition 6 4. Unit identification code: P033 7. State Only FORM 2000-604 Rev 06-95 8. Limitation Annual emissions shall not exceed 0.6 tpy 10. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, hours of operation, etc.) 01WE0208, Issuance 1, Condition 5: Retain final authorization letter with most current construction permit 01WE0208, Issuance 1, Condition 6: Demonstrate compliance with annual VOC limits by calculating a new 12 month total by the end of each month 01WE0208, Issuance 1, Condition 7: Compliance shall be demonstrated by running GLYCalc monthly using most recent plant inlet gas analysis and recorded operational values (including gas throughput, lean glycol recirculation rate, and other operational values specified in the O&M Plan). Recorded operational values, except gas throughput, shall be averaged on a monthly basis. 01WE0208, Issuance 1, Condition 8: Route still vent vapors to either the RTO or an enclosed combustor to reduce emissions to less than or equal to the limits in permit. 01WE0208, Issuance 1, Condition 8 & 9: 100% of flash tank emissions shall be recycled to the plant inlet and recompressed. 01WE0208, Issuance 1, Condition 10: Natural gas throughput shall not exceed 1,460 MMscf/yr 01WE0208, Issuance 1, Condition 10: Maintain monthly records of actual gas throughput 01WE0208, Issuance 1, Condition 10: By the end of each month, calculate a new 12 month total. 01WE0208, Issuance 1, Condition 11: Limit maximum lean glycol circulation rate to 3.5 gallons per minute. Record lean glycol circulation rate daily in a log and make available upon request. 01WE0208, Issuance 1, Condition 12: Mark subject equipment with permit number and AIRS ID. 01WE0208, Issuance 1, Condition 13. Visible emissions shall not exceed 20% opacity during normal operation. During startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% for more than 6 minutes in any 60 consecutive minutes. 01WE0208, Issuance 1, Condition 15: Beginning May 1, 2005, uncontrolled actual emissions of VOCs form the still vent and flash tank shall be reduced by at least 90% through the use of air pollution control equipment. Comply with the general provisions of Regulation 7, Section XII.H State Only 9. Compliance Status IN OUT x Compliance Status IN OUT X X X X X X X X X X X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** X 39 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant SUPPLEMENTAL INFORMATION FORM 2000-700 09-94 12 3. This form supplements Form 2000 - 604 for Emission Unit (e.g. B001, P001, etc.) P033 Facility identification code: CO1230049 Additional Information, Diagrams Item Number 10 10. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, hours of operation, etc.) 01WE0208, Issuance 1, Condition 16: The RTO/enclosed combustor is subject to Regulation No. 7, Sections XVII.B.1.a and XVII.B.1.c General Provisions. Combustion device used to control emissions of VOCs, shall be enclosed, have no visible emissions during normal operations, and be designed so that observer can, by means of visual observation from outside of the combustion device, or other convenient means approved by the Division, determine whether it is operating properly. Comply with all requirements of Sections XVII .B.1.a and XVII.B.l.c. 01WE0208, Issuance 1, Condition 16: All combustion devices used to control emissions of hydrocarbons must be equipped with and operate an auto -igniter. 01WE0208, Issuance 1, Condition 17: The equipment is subject to the control requirements under Regulation No. 7, Section XVII.D. Beginning May 1, 2008, uncontrolled actual emissions of VOCs from the still vent and flash tank shall be reduced by an average of at least 90% through the use of air pollution control equipment. 01WE0208, Issuance 1, Condition 17: The equipment is subject to the control requirements under Regulation No. 7, Section XVII.D. Beginning May 1, 2015, uncontrolled actual emissions of VOCs from the still vent and flash tank shall be reduced by an average of at least 95% on a 12 -month rolling basis through the use of air pollution control equipment. Comply with all applicable general provisions of Regulation No. 7, Section XVII 01WE0208, Issuance 1, Condition 18: Comply with all applicable provisions of 40 CFR 63, Subpart HH. Determine the actual average emissions of benzene using the methods listed in 63.772(b). 01WE0208, Issuance 1, Condition 18: Keep records of the actual average benzene emissions per year for at least 5 years 01WE0208, Issuance 1, Condition 19: Follow O&M Plan and recordkeeping format approved by the Division 01WE0208, Issuance 1, Condition 20: When RTO is used to control emissions, the combustion chamber temperature shall be recorded daily and information maintained in log on site 01WE0208, Issuance 1, Condition 21: When RTO is used to control emissions, the operating temperature shall be >1450 deg F at all times emissions are vented to the RTO 01WE0208, Issuance 1, Condition 22: Initial Testing: Demonstrate compliance with opacity standards for enclosed combustor using EPA Method 22 01WE0208, Issuance 1, Condition 23: Demonstrate compliance with opacity standards for enclosed combustor using EPA Method 22 daily. 01WE0208, Issuance 1, Condition 24: Complete annual extended wet gas analysis of plant inlet. Use results to calculate emissions of criteria pollutants and HAPs per Condition 6. 01WE0208, Issuance 1, Condition 26: Submit revised APEN annually if there is a significant increase in emissions, when there is an owner/operator change, whenever there is a control equipment change, whenever a permit limit must be modified, no later than 30 days before existing APEN expires State Only x X X X Compliance Status IN OUT x X X X X X X X X X X X X 40 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SUPPLEMENTAL INFORMATION FORM 2000-700 09-94 SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. This form supplements Form 2000 - 604 for Emission Unit (e.g. B001, P001, etc.) P033 Additional Information, Diagrams Item Number 10 10. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, hours of operation, etc.) State Only Compliance Status IN OUT 01WE0208, Issuance 5, Condition 29: Retain permit and attachments, make available upon request 01WE0208, Issuance 5, Condition 34: Pay annual fees as required X X 41 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SUPPLEMENTAL INFORMATION FORM 2000-7O0 O9-94 SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. This form supplements Form 2000 - 604 for Emission Unit (e.g. B001, P001, etc.) P033 Additional Information, Diagrams Item Number Compliance demonstration methods Requirement 10WE1659, Issuance 5, Conditions 5: Emission limits 01WE0208, Issuance 1, Condition 5: Retain final authorization letter/construction permit 01WE0208, Issuance 1, Condition 6: Calculate new 12 month total by the end of each month 01WE0208, Issuance 1, Condition 7: Demonstrate compliance by running GLYCalc monthly. 01WE0208, Issuance 1, Condition 8: Route still vent vapors to either the RTO or an enclosed combustor. 01WE0208, Issuance 1, Condition 8 & 9: Recycle flash tank emissions to the plant inlet. 01WE0208, Issuance 1, Condition 10: Natural gas throughput shall not exceed 1,460 MMscf/yr 01WE0208, Issuance 1, Condition 10: Maintain monthly records of actual gas throughput 01WE0208, Issuance 1, Condition calculate a new 12 month total. 01WE0208, Issuance 1, Condition circulation rate to 3.5 gallons 10: By the end of each month, 11: Limit maximum lean glycol per minute; record daily. 01WE0208, Issuance 1, Condition 12: Mark subject equipment with permit number and AIRS ID. 01WE0208, Issuance 1, Condition 13. Visible emissions shall not exceed 20% opacity during normal operation; 30% during startup, process modification, or adjustment of control equipment. 01WE0208, Issuance 1, Condition 15: Reduce VOC emissions from still vent & flash tank by at least 90% 01WE0208, Issuance 1, Condition 16: RTO/enclosed combustor shall be enclosed, no visible emissions during normal operations, and designed so that observer can determine whether it is operating properly. 01WE0208, Issuance 1, Condition 16: Enclosed combustor must be equipped/operate with an auto -igniter. 01WE0208, Issuance 1, Condition 17: VOCs from still vent and flash tank shall be reduced by at least 90% by May 1, 2005 and by 95% by May 1, 2015. 01WE0208, Issuance 1, Condition 18: Comply with all applicable provisions of 40 CFR 63, Subpart HE. Keep records of actual average benzene emissions on file. 01WE0208, Issuance 1, Condition 19: Follow O&M Plan and recordkeeping format approved by the Division 01WE0208, Issuance 1, Condition 20: RTO combustion chamber temperature shall be recorded daily 01WE0208, Issuance 1, Condition 21: RTO operating temperature shall be >1450 deg F 01WE0208, Issuance 1, Condition 22: Initial Testing: Demonstrate compliance with opacity standards for enclosed combustor using EPA Method 22 01WE0208, Issuance 1, Condition 23: Demonstrate compliance with opacity standards for enclosed combustor using EPA Method 22 daily. Compliance Method Monthly records and calculations kept in DCP compliance database Recordkeeping/file system Records and calculations in DCP compliance database Records and calculations in DCP compliance database Vendor specifications, plant/unit design specifications Plant/unit design specifications Records and calculations compliance database Records and calculations compliance database Records and calculations compliance database Records and calculations compliance database/log Visual inspection in DCP in DCP in DCP in DCP Initial Method 22 RTO & enclosed combustor; daily Method 22 enclosed combustor Vendor specifications/one-time stack test RTO RTO/enclosed combustor specifications Specifications Vendor specifications/one-time stack test RTO Benzene emissions on file Recordkeeping/file system Records kept in DCP compliance database, log Records kept in DCP compliance database, log Recordkeeping/file system Recordkeeping/file system 42 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant SUPPLEMENTAL INFORMATION FORM 2000-700 09-94 2. Facility identification code: CO1230049 3. This form supplements Form 2000 - 604 for Emission Unit (e.g. B001, P001, etc.) P033 Additional Information, Diagrams Requirement 01WE0208, Issuance 1, Condition 24: Complete annual extended wet gas analysis of plant inlet. 01WE0208, Issuance 1, Condition 26: Submit revised APENs as needed 01WE0208, Issuance 5, Condition 29: Retain permit and attachments 01WE0208, Issuance 5, Condition 34: Pay annual fees Item Number Compliance demonstration methods Compliance Method Recordkeeping/file system Recordkeeping/file system Recordkeeping/file system Recordkeeping/file system 43 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 COMMITMENTS AND SCHEDULE 09-94 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: S025 4. Unit identification code: P025 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. X We will continue to operate and maintain this Unit in compliance with all applicable requirements. ❑ Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. ❑ This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Progress reports will be submitted: Corrective Actions EMISSION UNIT COMPLIANCE PLAN COMMITMENTS AND SCHEDULE -- Form 2000-606 and every six (6) months thereafter Deadline 44 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Gas Plant 3. Stack identification code: ECD-1, RTO-1 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. X We will continue to operate and maintain this Unit in compliance with all applicable requirements. ❑ Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. ❑ This Unit is in compliance with all applicable pace requirements iss needed attachthose additiindicated opies of Form 2000-700): ow. We will achieve compliance according to the following schedule (If more EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 COMMITMENTS AND SCHEDULE 09-94 2. Facility identification code: CO1230049 Applicable Requirement 4. Unit identification code: P033 Corrective Actions Deadline 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter EMISSION UNIT COMPLIANCE PLAN COMMITMENTS AND SCHEDULE -- Form 2000-606 45 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 COMMITMENTS AND SCHEDULE 09-94 1. Facility name: Roggen Gas Plant 2. Facility identification code: CO1230049 3. Stack identification code: ECD-1, RTO-1 4. Unit identification code: P-136 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. X We will continue to operate and maintain this Unit in compliance with all applicable requirements. ❑ Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. ❑ This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. 2. 3. Progress reports will be Start date: and submitted: every six (6) months thereafter EMISSION UNIT COMPLIANCE PLAN COMMITMENTS AND SCHEDULE -- Form 2000-606 46 Operating Permit Application Colorado Department of Health Air Pollution Control Division Facility Name: Roggen Gas Plant I. ADMINISTRATION TABULATION OF PERMIT APPLICATION FORMS FORM 2000-800 09-94 Facility Identification Code: CO1230049 This application contains the following forms: X Form 2000-100, Facility Identification X Form 2000-101, Facility Plot Plan x Forris 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. printine X Form 2000-200, Stack Identification 3 ❑ Form 2000-300, Boiler or Furnace Operation 0 ❑ Form 2000-301, Storage Tanks 0 ❑ Form 2000-302, Internal Combustion Engine 0 ❑ Form 2000-303, Incineration 0 ❑ Form 2000-304, Printing Operations 0 ❑ Form 2000-305, Painting and Coating Operations 0 x Form 2000-306, Miscellaneous Processes 1 x Form 2000-307, Glycol Dehydration Unit III. AIR POLLUTION CONTROL SYSTEM 2 Total Number of This Form This application contains the following forms: x Form 2000-400, Miscellaneous 2 ❑ Form 2000-401, Condensers 0 O Form 2000-402, Adsorbers 0 x Form 2000-403, Catalytic or Thermal Oxidation 1 ❑ Form 2000-404, Cyclones/Settling Chambers 0 O Form 2000-405, Electrostatic Precipitators 0 O Form 2000-406, Wet Collection Systems 0 O Form 2000-407, Baghouses/Fabric Filters 0 IV. COMPLIANCE DEMONSTRATION Total Number of This Form This application contains the following forms (one for each facility boiler. orintine operation. x Form 2000-500, Compliance Certification - Monitoring and Reporting 3 O Form 2000-501, Continuous Emission Monitoring 0 ❑ Form 2000-502, Periodic Emission Monitoring Using Portable Monitors X Form 2000-503, Control System Parameters or Operation Parameters of a Process 0 2 ❑ Form 2000-504, Monitoring Maintenance Procedures X Form 2000-505, Stack Testing 0 2 ❑ Form 2000-506, Fuel Sampling and Analysis 0 X Form 2000-507, Recordkeeping 3 x Form 2000-508, Other Methods 3 47 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 0 X Form 2000-601, Emission Unit Criteria Air Pollutants 3 X Form 2000-602, Facility Hazardous Air Pollutants 1 ❑ Form 2000-603, Facility Criteria Air Pollutants 0 X Form 2000-604, Applicable Requirements and Status of Emission Unit 3 ❑ Form 2000-605, Permit Shield Protection Identification 0 x Form 2000-606, Emission Unit Compliance Plan - Commitments and Schedule 3 ❑ Form 2000-607, Plant -Wide Applicable Requirements 0 ❑ Form 2000-608, Plant -Wide Compliance Plan - Commitments and Schedule 0 VI. SIGNATURE OF RESPONSIBLE OFFICIAL - FEDERAL/STATE CONDITIONS A. STATEMENT I have reviewed the statements B. CERTIFICATION X ❑ WARNING: Any or certification in, with the provisions OF COMPLETENESS this application in its entirety and, based on information and and information contained in this application are true, accurate OF FACILITY COMPLIANCE STATUS - FEDERAL/STATE I certify that the facility described in this air pollution permit application requirements. I certify that the facility described in this air pollution permit application requirements, except for the following emissions unit(s): belief formed after reasonable inquiry, I certify that and complete. CONDITIONS (check one box only) is fully in compliance with all applicable is fully in compliance with all applicable (list all non -complying units) any false material statement, representation, misdemeanor and may be punished in accordance person who knowingly, as defined in § 18-1-501(6), C.R.S., makes or omits material information from this application is guilty of a of § 25-7122.1, C.R.S. Printed or Typed Name William L Johnson Title Vice President of Operations Signature 1 Date Signed 3%1)'Zacp 48 Operating Permit Application Colorado Department of Health 09-94 Air Pollution Control Division Facility Name: Roggen Gas Plant CERTIUCATION FOR STATE -ONLY CONDITIONS FORM 2000-800 Facility Identification Code: CO1230049 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 the statements and information contained in this application are true, accurate B. CERTIFICATION OF FACILITY COMPLIANCE STATUS FOR STATE -ONLY X I certify that the facility described in this air pollution permit application requirements. ❑ I certify that the facility described in this air pollution permit application requirements, except for the following emissions unit(s): belief formed after reasonable inquiry, I certify that and complete. CONDITIONS (check one box only) is fully in compliance with all applicable is fully in compliance with all applicable (list all non -complying units) any false material statement, representation, misdemeanor and may be punished in accordance 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 with the provisions of § 25-7122.1, C.R.S. Printed or Typed Name William L Johnson Title Vice President of Operations Signature Date Signed '5jI7f 2bILO SEND ALL MATERIALS TO: COLORADO DEPARTMENT OF HEALTH APCD-SS-B1 4300 CHERRY CREEK DRIVE SOUTH DENVER, CO 80246-1530 49 Attachment B Plot Plan Roggen Gas Plant 50 S uT MI" BF 59' IT 03 1,311. GIFT NOE GIMES OLIN FLARE 6 • s1W ml O 9MP1206 NR ® F]A6 {nf 0mc GP IS ALCMS ONM�IAI[gwf MOO R10:,:,1 vi�w O 'TX tempo -_ nAI r Ill ✓SD6 ;OS P -TAI I Y.. C-3 RSISIII.1 BBg ggT OXON SIC CATCHER 065 ACC OWISBRE6 _N PA. f1 l2 LO NAGAI BEEO TBUM , IE11.3 WON o -Ns m o I Ire I I \sago--Ti S V-00 W[MM EA Rat- V-ERi 00"1=,05 r Q 16,00_,, AE -2604A F&D B IS -605 VAG E-111 '��,��m=�Y �p 000 out II Am-a-�1 � 'CONDENSATE STPBIUZER —G SAPID � 9 - >m iueo a sm ,s 11` 7(1 sr - 1, - „� wRpvq. TAW 9Hr [-CM ~elm s ®Nl-1m�A{- LeJ - JEAIJ YdIN41ANl Z1§ }9m F -1St [f-fxl - 11 m eF-1P t Ali IC . � w pvl 71® ≥≥LLLIII --- By —'m6 (11,030 R6.P®MN:T . M 1 -Ft-mot 'RC. P_�lm nr� xg a s-MNJ° P w g °_ • NLFT SCRUBBER r �� ^-v &I�))NII� v-eMD im l' 1 �_�I. PILL - - - -, Il1 C -_L ii i, ,, fit F6S P-. m -- �M-IID vimpI e a �P Ga "'-^'"'-^''''''9l jl IF I II f 1�-�� 1TjgS I I I f I I I I l r-eml I I I I I I I fl I( .-Ica I le PC LAYING m1PF1� IUT_� EL n 3 DINE 166 OGG AFF1 tONA lu�� idua AST SS Bb�hmm pL RBOAT erlk AGO 610) F-1601 MISS ' SCOA PATOIS Pill f -11B L Q RNEOT. GllR HOT DL S▪ YSTEM IN PAT1NN N1 OA 911P-10_ IUYP; II 9YP-Y USD NN—ffi I>' Cecile 4a ° CRYOGENIC SYSTEM 70.-riK®. Q9 ffi e $ 5 ;NT COMPRESSOR INLET FUEL SCRUBBER I ,PIESSOg M' —am lox is Nem N R dT NNIR a IraNa 6 LIOUD TREATER OM RIG 1 I��a G.oacee me O a . I vY G oL i6 wu MOLECULAR SIEVE/GLYCOL 0EHTDAATOO I 01 N CLOT OE EMIG GA 100 M ' ws 26 OCT Bta C 0,111 HOS11 NOT FEAT. I - MP II MY M P --a vI m1Ersvc Lose moo No Lora rev 0, PARING Sri On o 01 PUG O31D ON GNAT O CAB X al, se u• E t31 • MN GTE SHOP In 9321 GRIN MUG GA I 11% .� 'oo\ T -1 0010' \ TO Aso A50 AST 1.e DIEM 612 GM FEIN FLARE RAI AST I-4 SIN., a0M GO cis YEBR - COUNTY RD 18 SEE THE FOLLOW NC DRAWINGS FOR THE LOCATIONS OF OIL CONTAINING PIRNO: RUSSELL & RAN OM I FS -001 II -DO -901 11 -00-002 11-00-0D3 11-00-004 II -00-005 22-00-001 22-00-002 22-00-003 22-00-004 22-00-005 22-00-008 23-00-001 23 -OD -002 23-00-003 21-00-904 23-00-005 23-00-O06 30-00-001 30-00-002 30-D0-0034 30-00-0038 30-00-004 61-00-001 61-00-9010 61-00-002 71-00-002 71-00-002 71-00-004 LEGEND INLET CAS SCREENING RJRASPEC INLET LI0210 SEPARATION 554800000 SYSTEM PRODUCT HANOUNG 5T51EM MOLE SIEVE OEHYORA000 SYSTEM (RUSSELL) MOLE SIEVE REGENERATION SYSTEM (RUSSEL) RUSSELL DEMETHANQER SYSTEM EXPANDER/COMPRESSOR (RUSSELL) RUSSEL PRODUCT HANDLING sacIeN RUSSELL/COMPRESSOR UTIUTIES MOLE SIEVE DEHYDRATION SYSTEM (RANDALL) MOLE SIEVE REGENERATION SYSTEM (RANDALL) RANDALL DEMERLW2ER SYSTEM EXPANDER/COMPRESSOR (RANDALL) DEMLTAAND:ER RANDALL UNIT RANDALL EXPANDER/COMPRESSOR URLRIES PRODUCT HANDLING SYSTEM PROPANE. BUTANE & Y -GRADE LINES Y-SRADE/PROPANE TANKS & TRANSFER PUMPS BUTANE TANKS & TRANSFER PUMPS C3/04 TRUCK LOADING RESIDUE GAS COMPRESSOR RESIDUE GAS COMPRESSOR COMPRESSOR UTILITIES 7407 OIL 555100 1407 OIL HEATER bloke, FLARE/INSTRUMENT NR PFTRDFA^ O -CD -Dal 0-00-002A 0-00-0026 D-00-0020 0-00-003 0-OO-003A 0-00-004 0-00-005A 0-00-005B O -00-006 0-00-101 0-00-301 0-00-501 0-00-701 20-00-001 20-00-002 20-00-003 20-00-004 20-00-D05 20-00-006 20-00-007 20-00-003 20-00-004 20-00-005 20-00-006 20-00-007 So -DO -101 50-00-530 53 -D -F -00I 60-00-091 60-00-002 LOW PRESSURE INLET GAS L.P. COMPRESSOR NO. 1 L.P. COMPRESSOR NO. 3 LP. COMPRESSOR NO. 5 LP. COMPRESSOR NO. 7 L.P. OAS COOUNG & SEPARATION ENTERPRISE INLET FACILITIES LIQUIDS TREATER & GRID INLET SEPARATION INLET SULFUR BOX ELDER COMPRESSOR L.P. COMPRESSOR C-1 UTILITES L.P. COMPRESSOR C-3 UTILITIES L.P. COMPRESSOR C-5 IJTILTDES L.P. COMPRESSOR C-7 UTILTOES PETROFAC CRYD INLET DEHYDRATION PETRCFAC CRYO COLD SEP Is EXPANDER PETROFAC CRY0 DEMETNNNIZER PRODUCT SURGE & FUEL GAS PETRCFAC CRY0 REGEN CA5, TED 00141. PETROFAC ORYC REGEN GAS HEATER LUKE OIL SYSTEM PETROFAC CRYO DEMETHANLMR PRODUCT SURGE & FUEL CAS PETRCFAC CRYD REGEN CAS. TEC DENY. PETRCFAC CRY0 ROGER CAS HEATER WEE OIL SYSTEM CRYD REFRIGERATION COMPRESSOR REPRO. COMPRESSOR C-530 UTIUTI6 VEHICLE PROPANE TANK RESIDUE COMPRESSION RESIDUE COMPRESSION — SOLES CAS METER 60-00-600 60-00-501 60-00-604 70-00-001 70-00-0010 70 -00 -DOD 70-00-003 70-00-004 50-00-001 R6. CAS COMPRESSOR C-600 UFUTIES RE -5. GAS COMPRESSOR C-601 UTUTIES RES. GAS COMPRESSOR C-602 UTILITIES INSTRUMENT/STARTING AIR SYSTEM INSTRUMENT/STARTING NR ASSISM PETROFAC EXPANDER LUKE OIL SYSTEM CONDENSATE AND PRODUCED WATER STORAGE L.D. & CHEMIOAL STORAGE & MAKE—UP FLARE SYSTEM Notec 1. Th16 drawing 's bailed o a DCP held sketch or baseman and depicts the locations al oil containing IPAer. p 00.00 vessels. equipment urpipnThl9 drawing Is not to scale ud should only biused for Spill PrevenSan Control 000 Countermeasure Ran (SPCC) purposes Sea the 100111tys Prceess and Instrumentation Diagram (POD), and Maximum Intended Inventory (MIT) II.I equivalent for exact locations and contents of oil containing containers. Process vessels. eAuipment and ORping 09 required by 40 CFR 112.7(3). 2 the number or drums may wry from month month. Drums or. ore maintained in secondary containment. Typical number of drum. A approximately 20. EGE= —C SURFACE WATER FLOW DIRECTION PCCINC EQUIPMENT SECONDARY CONTAINMENT BERM FACIUTY WIDE EARTHEN 0006 p9 L0400UT ROADS BUILDINGS F Y FENCE LINE — — — — PROPERTY UNE ABOVEGROUND STORAGE TANN (AST) OR DRUM (OWNED BY DOS MIDSTREAM) SPCC REGULATED AST OR DRUM (OWNED ED DCP MIDSTREAM) 1 "-1in ¢L M M1acea Equprvt catching Ols. Cm00 den Probable UnNus Dell Nome Uc eypb 50 Velum. CDOaen10 Systems NOL00 Condensate 00 of e No N.OW00Mgrolor 0 .manol 0 90 Not 01! SYslen ON 6 9d H-72!11 011 6 ad Uquld Treater NCI., Condensate, Water . 6 gtl lycol Oa InGolar NOL Canbensale 05 MI mmpreae net NM Sarubben NCL COndenede 6 gel MM Gae Snubber NCL Condensate 6 0d Cond SMbilar NOL Cond.neel. 6 gel Slue Catcher ROL Condone,. CO 9d V-0192 NOL Condensate O gtl OI fame On...5n UNeld Name Alsue 004`0, Drcdonan volere AST —I Canderaa. 300 bbl AST -2 Condensate 300 bbl AST -3 confe e:Re 300 sal AST -4 Condensate 300 hbl e51-5 Condone 300 bbl AST -6 Condensate 300 bbl AST -7 Condensate 300 bbl AST —I! Condensate 300 001 AST -12 Yereeene 500 psi AST_13 tube GI 210 bbl AST -14 Wad OII 4.512 gel ASr— Wae Oil 6,003 gal AST -24 Wbe Oil 500 pal AS1-26 Diml 500 gal 1ST -27 HSW7C0 Scours. 500 0 AST -29 Slep CM220 gal v-3003 N 4L® gat 0-3005 NM. ]4003 al V-3007 NO- 4;06 gal V-3006 Kt 34000 gal Sump -1 Prowled Water 60 bbl sump -2 Pmweed Omer 80 0121 Sump -4 Slop all 30 bbl sumo -5 Stormvater 80 bbl Sumo -6 Produced Wmer se sal Sumo -7 Slap Oil 10 bbl Sumo -B Slap 011 80 bbl Sump -9 Slap Oll B0 bbl sum OIlp-10 slop 011 10 sal Sump -11 Sian Oil B0 ea Sump -12 Slap ON 210 bbl Sump -13 Used 01 110 eel Sump -14 Produced Water 80 bbl Sumo -16 0900 Water 100 gal Sump -72119 Produced Water 210 bbl Deby4re0on Water Slurp -100 Produced Weer 10 bbl Sumo -7211 Mot ql 210 pal Sump -7214 Produced Nate 210 bbl Portable Tank Ueed Oil 66 gal Drum Storage Area 1 M0aellonew,s 000 55 g0eob Drum Swage Area 1 Mecellaneeue OM 55 pal! each Drum and 01000001 Storage Area 3 Ca d Chemicals 55 got (car) !Pun Storage Area A Mseelaneous Oils 55 gal (such) Dna. Serape Ano 5 Ifs delan.oue Ode 55 sal Roth) Lobe 011 Crum Wipe 01 SS Ad LPG EN HI (Sod OIl 225 gal Used Oil *2 Usd Oil 225 1 Used OH *3 U.. Oil 225 gal 90 1600 Day TONI LUNA 00 6e ga 16tH Day Tank Ube 01 66 gal 158 Day Tank Ube OT 60 gal Ca CGS, DayTank{12 0 11 • 67 gd semen pompoms - Building Dey Tank Ube m 300 pot 5-1080 PRODUCED WATER 70 gal Non -606 Re9UUd O rMa ners Unique FeM None Ocr,:edpllan n7j. Valsree AST -9 Widow 1,000 ON AST -10 Narked 1,000 sal ASI-11 Narked 1.000 001 AST -1g Narked 24 Vol AST -2C Norimd 24 bill AS -21 0.N,ee1 500 sal AST -22 Methanol 500 gal AST -27 Amine 500 ad 053006 TEC 470 sal 0-3000 Butane 00,030 gal v-463006 Butane 80,000 <I v—,0011 Stencrea Propane ]0,000 gm X011 M6genol 16,003 9a Compressor 011000 Day Tank Hl ,be Rl 50 sal 159 Lay Tank tube RI 45 gal 161 pay Tank Wae al 45 am Portable eUano! ants eeMeve! 55 0°I (.°.4) Used OH e Used Oil Fdtere Varae0 AS-1205 Ave El 411110 200 WI AST -7201 New Amin. 200 WI AST -7210 TEC 90 bbl Sump -7206 Arnim 210 lei Sumo -721S Glycol & Water EC bbl AST -7208 Treated Weiler BO WY TX -0001 Odorant 160 gal TX -0103 WATER & METHANOL 300 bbl CH CorGn110 EOU0nr400101,1.0 Mpa CO Moor Oat) contents Unique FIG Name Doodah. Volume Engine 154 Lees UT 150 gal Engine 155 Wbe OR 150 pal Engine 100 Loa 06 100 gal Engine 157 Luba 00 I50 pal Ermine 156 Lube Oil ISO gal Enyn 150 Lee. Oil 150 gal Engine 100 Lobs 011 160 sal ceryceser Is0 Lobe 00 50 gal Ennire 161 Labe Oil 150 001 Erpine 100 Luba all 165 gel DNIne 223 LUCA 011 100 sal Engine 225 LOde 011 100 ad Leine 227 Lobe 00 150 gal Engl. 102 Luba 011 ISO ad Tremram.r Transformer QI 150 am SPCC PLOT PLAN REV DATE REVISION BY CHK'D ENGR. LAOS. MGR. REV DATE REVISION BY CHK'D ENGR. 3 -10 —ON REVISIONS PER, R.P.M. FIELD SKETCH J.R.E. R.P.M. 12-6-11 UPDATE FROM M.C.F. MARK-UP J.R.E. M.C.F. MGR. MGR. 2 3-25-09 REVISIONS PER: R.P.M. FIELD SKETCH J.R.E. R.P.M. 3 10-5-09 REVISIONS PER: R.P.M. FIELD SKETCH J.R.E. R.P.M. 7 5-16-12 RELOCATED AND CHANCED CONTENTS OF AS7-27 J.R.E. M.C.F. 7-9-13 UPDATE PER: D.N.B. MARK-UP J.R.E. D.N.B. 7-1-10 ADDED SUMP 14 J.R.E. R.P.M. 1D-14-11 SITE UPDATED K.A.H. P.R.B. dip Midstream. ROGGEN GAS PLANT WELD COUNTY GATHERING SYSTEM Weld County COLORADO \data\EhsDrawin gs\Mapping\Colorado\Weld\RoggenSPCC Attachment C Copies of Most Recent APENs P025, P033, P-136 Roggen Gas Plant 51 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit— Fugitive Component Leak Emissions Permit Number: 10WE1659 Facility Equipment ID: P025 Section 01 — Administrative Information Company Name: DCP Midstream, LP [Leave blank unless APCD has already assigned a permit')/ & AIRS IDJ Emission Source AIRS ID: 123 / 0049 / 122 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization,] Section 02 —.Requested Action (Check applicable request boxes) ❑ Request for NEW permit or newly reported emission source Source Name: Roggen Natural Gas Processing Plant Source Location: Section 24, T2N, RG3W Mailing Address: 370 17th Street, Suite 2500 NAICS, or SIC Code: 1311 ® Request MODIFICATION to existing permit (check each box below that applies) County: Weld O Change process or equipment ❑ Change company name Elevation: 4,776 Feet ® Change permit limit ❑ Transfer of ownership ❑ Other ZIP Code: 80202 ❑ Request to limit HAPs with a Federally enforceable limit on PTE O Request APEN update only (check the box below that applies) ❑ Revision to actual calendar year emissions for emission inventory Update 5 -Year APEN term without change to permit limits or previously reported emissions Person To Contact: Roshini Shankaran Phone Number: 303-605-2039 E-mail Address: RShankaran@dcpmidstrearn.com Fax Number: 303-605-1957 Section 03 — General Information For existing sources, operation began on: Normal 1 -lours of Source Operation: 24 hours/day Brief description of equipment associated with these components: Will this equipment be operated in any NAAQS nonatainment area? (II up: ,v,ww.edphe.slate.cn.us'ap allainmainlain.hlnll) Section 04 — Regulatory Tnformation Is this equipment subject to NSPS 40 CFR Part 60, Subpart KKK? Is this equipment subject to NESHAP 40 CFR Part 63, Subpart HH? List any other NSPS or NESHAP Subpart that applies to this equipment: Section 05 — Stream Constituents identi1 the VOC & I-IA1 content of each applicable stream. Steam VOC (wt. %) Benzene (wt. a/) Toluene (wt. %) Ethylbenzene (wt. 0/0) Xylene (wt. %) n -Hexane (wt. %) Gas 29.85 0.21 0.05 0.02 0.04 0.42 Heavy Oil (or Heavy Liquid) -- — — -- — — Light Oil (or Light Liquid) 100 0.21 0.05 0.02 0.04 0.42 Water/Oil -- — — -- — — O Additional Info. & Notes: Update permit with new component count and gas analysis / 1981 For new or reconstructed sources, the projected startup date is: 7 days/week 52 weeks/year Natural Gas Processing Plant ® Yes O No ❑ Dott't know • Yes ❑ No ❑ Yes ® No ❑ Don't know ❑ Don't know ® Submit a representative gas and liquid extended analysis (including BTEX to support emission calculations FORM APCD-203 Page 1 (1)1.2 Colorado Department of Public Health and Environment Air Pollution Control. Division (APCI)) This notice is valid for five (5) years. Submit a revised ADEN prior to expiration of five-year term, or when a significant change is made (increase production, new equipment, change in fuel type, etc). Mail this form along with a check for $152.90 to: Colorado Department of Public Health & Enviroumerl,, yip APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For guidance on how to complete this APEN form: Air Pollution Control Division: (303) 692-3150 Small Business Assistance Program (SBAP): (303)692-3 148 or (303) 692-3175 APEN forms: Into://www.eclohe.state.co.us,apidowillonillornishinil Application status: hip:/'www.eduhc.state.cn.us'ap'ss'sspept.hlntl • Check box to request copy ol'draft permit prior to issuance. • Check box to request copy of draft permit prior to public notice, 030 FugitiveConlponentLeuks 2014-04-30,doc AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Fugitive Component Leak Emissions Permit Number: 10WE1659 Emission Source AIRS ID: 123 / 0049 / 122 Section 06 — Location Information (Provide Datum and either Lat/Long or UTM) Section 07 —Leak Detection & Repair (LDAR) & Control information Horizontal Datum (NAD27. NAD83, UTM Zone UTM Easting or Longitude UTM Northing or Latitude Method of Collection for Location Data (c.g. map, GPS, \VG584) (12 or 13) (meters or degrees) (meters or degrees) GooglcEartl ) WGS 84 13 -104.3883 40.1174 GPS Cheek appropriate boxes to identify LDAR program conducted at this site: LDAR per NSPS KKK ❑ No LDAR program ❑ Other: if LDAR per NSPS KKK with 10,000 ppmv leak definition: ® Monthly monitoring. Control: 88% gas valve, 76% lig. valve, 68% It, lig. pump ❑ Quarterly monitoring. Control: 70% gas valve, 61% It. lig. valve, 45% It. lig. pump Section 08 — Emission Factor Information Identify the emission factor used to estimate emissions under "EX.", along with the units relating to the emission factor (e.g. lblhr/component). ® Check this kitty if you used Table 2 of i s tYY3 Protocolor .q3 .c....,, .,,,..,... ... ..._.. ... --- -- ----- Equipment Type Service Gas Heavy Oil (or Heavy Liquid) Light Oil (or Light Liquid) Water/Oil Count' E.P. Units Count' E.F. Units Count' E.P. Units Counts E.P. Units Connectors 3610 2987 Flanges 1716 1044 Open -Ended Lines -- — Pump Seals — 31 Valves 2706 2383 Other 138 40 �_ .. _ -r a-. . m�.: t t , rl r..tio atnd count RI Actual Count conducted on the following date: _12/1/11 (+20"/ ) Low if checked. Count shall be the actual or estimated number of components m each type of Sc Section 09 — Emissions Inventors' Information & Emission Control Information hnin.a !n .. 7x1171. ❑ Emission Factor Documentation nttachetl uau, ..o..r ,o . ..................... ,,...........�.�..., .._..... ,--_- --_ .,- Pollutant Control Device Description Control Efficiency CA) Reduction) Emission Factor 2 Actual Calendar Year Emissions2 Requested Permitted Estimation Method or Emission Factor Source Uncontrolled Basis Units Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/Year) Primary Secondary VOC Identify in Section 07 Identify in Section 08 31.2 114.07 33.54 EPA 0.46 0.13 EPA Benzene EPA Toluene EPA Ethylbenzene EPA Xylenc 0.89 0.26 EPA u-I-Iexanc Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. ll b b d rc ueslcd emissions 'Annual emission lees will be based on actual emissions reported here. if IeSt blank, annual cttnssron tees wt c asc on q , 3 You may request permitted emissions in excess of actual emissions to account for component count and gas composition variability. If Requested Permitted Emissions is left blank, emissions will be based on info. in Sec. 03 -09. Section 10 —Applicant Certification - I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. (2- (Zcr(L Signattire ofPerson Legally Authorized to Supply Data Date Roshini Shankaran Name of Legally Authorized Person (Please print) Title Environmental Engineer Page 2 of 2 03e FugitivcCompoucntLcaks 2014-04-30.doc AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Glycol Dehydration Unit' Emission Source AIRS ID: 123/0049/130 Permit Number: 01 WE0208 Facility Equipment ID: P033 Section 01— Administrative Information Company Name: DCP Midstream, LP Source Name: Roggen Gas Plant Source Location: Section 24, R63W, T2N at 35409 County Road 18 [Leave blank unless APCD has already assigned a permit // & AIRS ID] [Provide Facility Equipment ID to identify how this equipment is refetcnced within your organization.] Section 02 — Requested Action (Check applicable request boxes) O Request for NEW permit or newly reported emission source ❑ Request MODIFICATION to existing permit (check each box below that applies) ❑ Change process or equipment ❑ Change company name ❑ Change permit limit O Transfer of ownership O Other ❑ Request to limit HAPs with a Federally enforceable limit on PTE ® Request APEN update only (check the box below that applies) ® Revision to actual calendar year emissions for emission inventory ❑ Update 5 -Year APEN term without change to permit limits or previously reported emissions Mailing Address: 370 17th Street, Suite 2500 Denver, CO 80202 NAICS, or SIC Code: County: Elevation: ZIP Code: 1311 Weld 4,776 Feet 80202 Person To Contact: Dana Stephens Phone Number: 303-605-1745 E-mail Address: dstephens@dcpmidstream.com Fax Number: 303-605-1957 Section 03 — General Information For existing sources, operation began on: Normal Hours of Source Operation: Addl. Info. & Notes: 1 / 1 / 1976 For new or reconstructed sources, the projected startup date is: 24 hours/day 7 days/week 52 weeks/year General description of equipment and purpose: Dehydration unit for water removal ► Is this unit subject to the 90% control requirement of Colorado Regulation No. 7, XVII.D (total uncontrolled actual VOC emissions from all dehydration units at this stationary source, including APEN Exempt units, ? 15 tons/yr)? ► Will this equipment be operated in any NAAQS nonattainmcnt area? (httn://www.colorado.gov/cdphc/attainment) ► Is this unit located at a stationary source that is considered a Major Source of Hazardous Air Pollutant (HAP) emissions? Section 04 — Dehydration Unit Equipment Information Custom Unit Manufacturer: Custom Unit Model: Custom Unit Serial No.: Reboiler Rating: n/a MMBtu/hr Glycol Used: [Z TriEthylene Glycol (TEG) Glycol Pump Drive: O Electric ® Gas Pump Make & Model: Custom _ Glycol recirculation rate (gal/min): Max: 3.5 Requested'-: 3.5 Lean glycol water content: Dehy. Gas Throughput: Design Capacity: 4.0 MMSCF/day Requested': 1,460 Calendar year actual: 958.0 Inlet Gas: Pressure: 850 psig Temperature: Water Content: Wet Gas: lb/MM scf ® Saturated Dry Gas: Flash Tank: Pressure: 125 psig Temperature: Cold Separator: Pressure: psig Temperature: StriGas: ® None ❑ Use flash gas ❑ Use dry gas: scfin ❑ Use N2: ❑ Ethylene Glycol (EG) ❑ DiEthylene Glycol (DEG) If gas, injection pump ratio: 0.08 acfm/gpm # of Pumps: 1 80 °F 1.5 wt. % MMSCF/yr. MMSCF/yr. 7.0 lb/MMscf 90 °F 0 None OF pptng 'You will be charged an additional APEN fee if APEN is filled out incorrectly or missing information and requires re -submittal. ZRequested values will become permit limitations. D Attach a process flow diagram ❑ Attach GRI-GLYCaIc 4.0 Input Report & Aggregate Report (or equivalent simulation report/test results) O Attach the extended gas analysis (including BTEX & n -Hexane, temperature & pressure) Additional Information Required: [Si None scfm rgi Yes Yes Yes ❑ No ❑ No ® No 1 I O Don't know ❑ Don't know ❑ Don't know Colorado Department of Public Health and Environment Air Pollution Control Division (APCD) This notice is valid for five (5) years. Submit a revised APEN prior to expiration of five-year term, or when a significant change is made (increase production, new equipment, change in fuel type, etc). Mail this form along with a check for $152.90 to: Colorado Department of Public Health & Environment >,.< APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For guidance on how to complete this APEN form: Air Pollution Control Division: (303) 692-3150 Small Business Assistance Program (SBAP): (303) 692-3148 or (303) 692-3175 APEN forms: littp://www.colorado.aov/cdohe/APENforms Application status: hup://www.colorado.gov/cdphe/pennitstatus ❑ Check box to request copy of draft permit prior to issuance. ❑ Check box to request copy of draft permit prior to public notice. Page 1 of4 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Glycol Dehydration Uniti Permit Number: 01WE020B Emission Source AIRS ID: 123/0049/130 Section 05— Stack information (Combustion stacks must be listed here) Operator Stack ID No. Stack Base Elevation (feet) Stack Discharge 1-ieight Above Ground Level (feel) Temp. (OF) Flow Rate (ACFM) Velocity (11./see) Moisture (%) S033 4,776 AMB Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) Horizontal Datum (NAD27, NAD83, WGS84) UM Zone (12 or 13) UTM Basting or Longitude (meters or degrees) UTM Northing or Latitude (meters or degrees) Method of Collection for Location Data (e.g. map, GI'S, Googlclarth) WGS84 13 -104.3383 40.1177 CPS Direction of stack outlet (check one): ® Vertical ❑ Vertical with obstructing rainca t Exhaust Opening Shape & Size (check one): ❑ Circular: Inner Diameter (inches) _ ❑ Horizontal ❑ Down ❑ Other: Length (inches) = Section 07 — Control Device Information (Indicate if a control device controls the flash tank and/or regenerator emissions) ❑ Other (Describe): Width (inches) _ ■ Condenser used for control of: a Combustion Device used for control of: Still Vent Stream Rating: MMBlu/hr Type: Make/Model: Type: RTO/enclosed comuustor Make/Model/Serial #: Anguil/John Zink Temperature (°P): Maximum: Average: VOC & HAP Control Efficiency: Requested: 97 % Manufacturer Guaranteed: 98 % Requested VOC & HAP Control Efficiency: % Minimum temp. to achieve requested control: 1,450 °F Waste gas heat content: 569 liui/scf ■ VRU used for control of: Constanuilot light'? ■ Yes • No Pilot burner rating: 0.05 MMlitu/hr Size: Make/Modcl: I Closed loop system used for control of: Flash tank vent stream Requested VOC & I-lAP Control Efficiency: % % Description: The flash tank emissions are piped directly to the low pressure inlet. Annual time that VRU is bypassed (emissions vented): O Describe Any Other: Enclosed combustor has constant pilot; RTO does not. Section 08 — Emissions Inventory Information & Emission Control Information Emission Factor Documentation attached Data year for actual calendar yr. emissions below & as throughput above (e.g. 2007): 2014 Pollutant Control Device Description Control Efficiency (% Reduction) Emission Factor Actual Calendar Year Emissions3 Requested Permitted Emissions Estimation Method or Emission Factor Source Primary Secondary Uncontrolled Basis Units Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/Year) NOx Identify in Section 07 VOC 41.75 lb/MMscf 20.0 2.31 15.2 0.55 GLYCaIc CO Benzene 4.53 lb/MMscf 2.17 0.80 1.7 0.06 GLYCaIc Toluene 5.08 lb/MMscf 2.43 0.94 1.9 0.07 GLYCaIc Ethylbenzenc 0.19 lb/MMscf O.09 0.04 0.07 0.003 GLYCaIc Xylcne 1.70 lb/MMscf 0.81 0.38 0.6 0.02 GLYCale n-l-lexane 0.37 lb/MMscf 0.42 0.07 0.3 0.01 GLYCale Please use the AI'CD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. ' You will be charged an additional Al'EN lee if APEN is filled out incorrectly or missing information and requires re -submittal. Annual emission fees will be based on actual emissions reported here. if left blank, annual emission fees will he based on requested emissions. Section 09 —Applicant Certification - I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. o J M S Dana Stephens Signature of Person Legally Au orized to Supply Data Date Name of Legally Authorized Person (Please print) Title Air Permitting Nlanager Page 2 of 4 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Glycol Dehydration Unitl Emission Source AIRS ID: 123/0049/136 Permit Number: Facility Equipment ID: P-136 Section 01— Administrative Information Company Name: DCP Midstream, LP Source Name: Roggen Gas Plant [Leave blank unless APCD has already assigned a permit # & AIRS ID] [Provide Facility Equipment ID to identify how this equipment Is referenced within your organization.] Section 02 — Requested Action (Check applicable request boxes) Source Location: Section 24, R63W, T2N at 35409 County Road 18 Mailing Address: 370 17th Street, Suite 2500 Denver, CO 80202 NAICS, or SIC Code: County: Elevation: ZIP Code: 1311 Weld 4,776 Feet 80202 Person To Contact: Dana Stephens Phone Number. 303-605-1745 E-mail Address: dstephens@dcpmicistream.com dcprrtidstream.com Fax Number: 303-605-1957 Section 03 — General Information For existing sources, operation began on: Normal Hours of Source Operation: General description of equipment and purpose: Dehydration unit for water removal 7/1/2011 _ 24 hours/day 7 days/week 52 weeks/year Is this unit subject to the 90% control requirement of Colorado Regulation No. 7, XV1I.D (total uncontrolled actual VOC emissions from all dehydration units at this stationary source, including APEN Exempt units, ? 15 tons/yr)? ® Will this equipment be operated in any NAAQS nonattainmentarea? (httn://www.colorado.s:ov/cdphe/attainment) It. Is this unit located at a stationary source that is considered a Major Source of Hazardous Air Pollutant (HAP) emissions? Section 04 -- Dehydration Unit Equipment Information Manufacturer: Eveo Fabrication Model: T-901 Serial No.: 2090 Reboiler Rating: n/a MMBtu/hr Glycol Used: ® TriEthylene Glycol (TEG) O Ethylene Glycol (EG) ❑ Di Ethylene Glycol (DEG) Glycol Pump Drive: ® Electric O Gas If gas, injection pump ratio: acfm/gpm Pump Make & Model: # of Pumps: 1 Glycol recirculation rate (gal/min): Max: Requested'-: 24 Lean glycol water content: 1 wt. % Dehy. Gas Throughput: Design Capacity: 85 MMSCF/day Requested': 31,025 MMSCF/yr. Calendar year actual: 0.00 MMSCF/yr. Inlet Gas: Pressure: 829.33 psig Temperature: 116 °F Water Content: Wet Gas: 97.96 lb/MMscf 0 Saturated Dry Gas: 4 lb/MMsef Flash Tank: Pressure: 72.33 psig Temperature: 128.5 °F O None Cold Separator: Pressure: psig Temperature: °F El None Stripping Gas: ® None D Use flash gas O Use dry gas: sefin 0 Use N2: scftn 'You will be charged an additional APEN tee if APEN is filled out incorrectly or missing information and requires re -submittal. 2Requested values will become permit limitations. Additional Information Required: ❑ Attach a process flow diagram ❑ Attach GRI-GINCale 4.0 Input Report & Aggregate Report (or equivalent simulation report/test results) ❑ Attach the extended gas analysis (including BTEX & n -Hexane, temperature & pressure) ❑ Request for NEW permit or newly reported emission source ❑ Request MODIFICATION to existing permit (check each box below that applies) ❑ Change process or equipment O Change company name ❑ Change permit limit O Transfer of ownership O Other O Request to limit 11APs with a Federally enforceable limit on PTE El Request APEN update only (check the box below that applies) ® Revision to actual calendar year emissions for emission inventory Update 5 -Year APEN term without change to permit limits or previously reported emissions O Addl. Info. & Notes: For new or reconstructed sources, the projected startup date is: Yes Yes Yes O No ❑ No El No / / ❑ Don't know ❑ Don't know ❑ Don't know Colorado Department of Public Health and Environment Air Pollution Control Division (APCDZ This notice is valid for five (5) years. Submit a revised APEN prior to expiration of five-year term, or when a significant change is made (increase production, new equipment, change in fuel type, etc). Mail this form along with a check for $152.90 to: Colorado Department of Public Health & Envlron. APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For guidance on how to complete this APEN form: Air Pollution Control Division: (303)-692-3150 Small Business Assistance Program (SBAP): (303) 692-3148 or (303) 692-3175 APEN forms: http://www.colorado.gov/cdphe/APENfonns Application status: htta://www.colorado.gov/cdphe/permitstatus O Check box to request copy of draft permit prior to issuance. O Check box to request copy of draft permit prior to public notice. I ,-,.•,.Y.. K . Ira !IT, Page 1 of 4 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Glycol Dehydration Unit' Permit Number: 95OPWE055 Emission Source AIRS ID: 123/0049/136 Section 05 — Stack Information (Combustion slacks must be listed here) Section 06 -Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) Operator Stack ID No. Stack Base Elevation (feet) Stack Discharge Height Above Ground Level ( feet) Temp. (°F) Flow Rate (ACFM) Velocity (11/sec) Moisture (%) I'136 4,776 AMB Horizontal Datum (NAD27, NAD83, UTM Zone UTM Eastingor Longitude UTM Northing or Latitude Method of Collection for Location Data (e.g. map, WGS84) (12 or 13) (meters or degrees) (meters or degrees) tIPS, GooglcCarlh) WGS34 13 -104.3883 40.1177 GPS Direction of stack outlet (cheek one): ® Vertical U Vertical with obstructing lanneap Exhaust Opening Shape & Size (check one): ❑ Circular: Inner Diameter (inches) = ❑ Other: Length (inches) = Section 07 — Control Device Information (Indicate if a control device controls the flash tank and/or regenerator emissions) Condenser used fbr control of: N Combustion. Device used for control of: Still Vent Stream Rating: MMBtu/hr lit Type: Make/Model: Type: RTO/enclosed comuustor Make/Model/Serial #: Anguil/John Zink 98 % Temperature (°F): Maximum: Average: VOC & HAP Control Efficiency: Requested: 97 % Manufacturer Guaranteed: Iltu/scf Requested VOC & HAP Control Efficiency: % Minimum temp. to achieve requested control: 1,550 °F Waste gas heat content: 697 Constant pilot light? [] Yes • No Pilot burner ratings: MMBtu/Itr_ • VRU used for control of: Closed loop system used for control of: Flash tank vent stream Size: Make/Model: O. Requested VOC & HAP Control Efficiency: Annual time that V RU is bypassed (emissions vented): % % Description: The flash tank emissions are piped directly to the low pressure inlet. Describe Any Other: Enclosed combustor has constant pilot; RTO does not. 0 ❑ Horizontal ❑ Down O Other (Describe): Width (inches) _ Section 08— Emissions Inventory information & Emission Control Information 1 I I d • 't•emis+icny below & t.•rs ihrouorhltut above (C.rr ❑ Emission Pollutant Factor Docuntentalron attached Control Device Description Data Vicar tit atria Control Efficiency (% Reduction) ca en m y . Emission Factor �- x Actual Calendar Year Emissions y Requested Emissions Permitted Estimation Method or Emission Factor Source Primary Secondary Uncontrolled Basis Units Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/year) Identify in Section 07 0.068 lb/mmbtu 0.00 0.00 2.6 2.6 AP -42 NO 64.17 Ib/MNlscf 0.00 0.00 995. 21.6 GLYCalc VOC 0.37 Ib/mmbtu 0.00 0.00 14.3 14.3 AP -42 CO 2.52 Ib/MNlscf 0.00 0.00 39.0 1.2 GLYCalc_ Benzene 2.43 Ib/MNlscf 0.00 0.00 37.7 1.1 GLYCalc Toluene 0.12 lb/MMscf 0.00 0.00 1.9 0.1 GLYCalc Ethylbcnzenc 0.5 lb/MNlscf 0.00 0.00 7.8 0.2 GLYCaIc Xylene 3.42 lb/MMscf 0.00 0.00 53.1 1.3 GLYCalc n_Hexane Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. You will be charged an additional APEN fee if APEN is tilled out incomuly or missing information and requu•es r - submutal . • ' Annual emission fees will be based on actual emissions reported here. If tell blank, annual emission fees will be -based on requested emissions. , Section 09 —Applicant Certification - I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. ( CA—„,,, �lhitLzy/ 3�r4is Signature of Person Legally horized to Supply Data Date Name of Legally Authorized Person (Please print) Title Dana Stephens Air Permitting Manager Page 2 of 4 Attachment D Enclosed Combustor Documentation Roggen Gas Plant 52 JOHN ZINK. .JOHN ZINK COMPANY LLC u.:;1: T•eR: 03 G'tit.•.j. !LC � �•n.a,t February 17, 2014 Via Email: CTWolohon@dcpmidstreatn.com DCP Midstream Attention: Mr. Tommy Wolohon Subject: Firm Proposal for Enclosed Flare Roggen TEG - DCP Midstream John Zink Proposal BF -201401-41767 Revision 1 Dear Tommy, Thank you for your interest in JOHN ZINK® brand products and services. John Zink is the proven leader in Flare system, pilot and ignition technology. While our ideas have been copied, our design success has never been duplicated. Due to the nature of this product we have standardized our design in order to minimize our costs. The unit(s) offered in this proposal is/are a standard pre-engineered. package. John Zink has reviewed your inquiry and can meet the required destruction efficiency with 100% smokeless flaring per the design cases reference in this proposal. Please be advised, unless specifically referenced in this proposal. John Zink has not reviewed or prepared this bid to your specific project specifications. John Zink offers a range of features and options as listed in the "Recommended Optional Equipment" section. Our intent is to supply the safest, most reliable and economical system available that will also allow you to customize your system to meet your specific needs. After reviewing the proposal, please let us know if there are any additional options you would like to include. We look forward to working with you on this project, and if you require any additional information please do not hesitate to contact me at 918.234.2791 or our local sales representative, Wade Sears with Douglas Scientific at 303.380.2662. Sincerely, JOHN ZINK COMPANY, LLC Aron J. Katz, P.E. Applications Engineer Vapor Control Group 918.234.1800 Tel 1918.234.2700 Fax 111920 East Apache 'Tulsa, OK 74116 'P.O. Box 21220 1 Tulsa, OK 74121-1220 I www.johnzink.com DCP Midstream - Roggen TEG John Zink Reference BF -201401-41767 Rev 1 P. DISCOVER THE JOHN Z1NK DIFFERENCE C r, 7i t J K. I S THE (AU -3A L F ADE R in developing next -generation products, technolo- gies and solutions to enhance air and water quality through the clean, efficient combustion of fossil fuels. Every day, John Zink's technologies are put to work by industry giants worldwide that refine oil, produce plastics, distribute fuels, generate power, transport energy and manage waste. The company's portfolio of brands includes JZ' flares, process burners, duct burners, thermal oxidizers and vapor control systems: KALDAIR'-�� flares: GORDON-PIATF" boiler burners; and KEU"h'thermal oxidizers and heat recovery systems. John Zink's Research, Development and Test Center, located in Tulsa, is the largest, most comprehensive of its kind. Here, the next generation of ultra -low emission combustion and environmental systems is engineered and tested at industrial scale to measure performance under a wide range of operating conditions. An affiliate of the company also operates a similar facility in Luxembourg. John Zink's world -class management systems are recognized for meeting or exceeding industry standards in quality, safety and health, and the environment, and for setting new standards in knowledge -sharing through accredited education. The world-renowned John Zink Institute`` -r°' offers practical, accredited courses on the latest advancements in process and boiler burner, process and biogas flare and vapor control technologies. John Zink Company is a Koch Chemical Technology Group, LLC company. To learn more about John Zink, visit Www.lohnzink.com. 02/17/14 PROPRIETARY AND CONFIDENTIAL Page 2 of DCP Midstream - Roggen TEG John Zink Reference BF -201401-41767 Rev I n John Zink's Tulsa and Luxembourg operations meet the requirements of the internationally recognized ISO 90gt2000 Quality Management System. _ fE r e€ OHSAS 18001 certification of John Zink's Tulsa and Luxembourg facilities underscores our commitment to providing a culture of safety that focuses on identifying and eliminating workplace hazards while maintaining health and safety compliance. u John Zink's Tulsa facility is a recipient of the Voluntary Protection Program (VPP) Star Certification, which recognizes selective companies that show a commitment to improved safety and health performance beyond the requirements of the OSHA standards, and who have demonstrated safety performance considered best in class. i",1if fl' i iE Fir'll- C -,`At F iE;tb s John Zink's Tulsa and Luxembourg operations meet the requirements of the internationally recognized ISO 14001 Environmental Management System. UAPr The U.S. Environmental Protection Agency has selected John Zink's Tulsa facility as a member of the agency's National Environmental Performance Track program, which recognizes top environmental performers that voluntarily go beyond compliance. John Zink preserves its legacy expertise and experience through knowledge -sharing practices. The IACET-accredited John Zink Institutesm at John Zink Company, LLC offers year-round courses in combustion education to enhance operations knowledge. The John Zink Institutesrr has earned certification of its Process Burner Fundamentals and Process Burner Operations courses from the American Petroleum Institute. John Zink is the first company to have a burner course certified under API's training provider certification program. 02/17/14 PROPRIETARY AND CONFIDENTIAL Page 3 of 8 DCP Midstream - Roggen TEG 02/17/14 John Zink Reference BF -201401-41767 Rev 1 DESIGN CRITERIA Flare Gas Stream Type: Composition: Lower Heating Value: Temperature: Flow Rate: Waste Heat Release: Production - Waste Gas Worse Case without Amine 951 BTU/SCE (maximum) 1.51 °F 226,133 SCFD (Continuous) 8.96 MM BTU/hr (maximum) NOTE: Hydrogen Sulfide concentrations greater than 1,000 ppm will require special materials and will increase costs. Jvlechanical Design Wind Speed: Ambient Temperature: Electrical Area Classification: Elevation: Process Smokeless Capacity: Required Inlet Pressure: Ambient Pressure: Utilities Pilot Gas (continuous): Compressed Air: Electricity: Auxiliary Fuel: 110 mph 0°F to 120 °F Unclassified 4,862 100% 1.33 psig 12.4 psia 22 SCFH of propane at 7-10 psig (or) 50 SCFH of natural gas at 10-15 psig 100 PSIG (regulated) 120V none (pilot only) Expected Emission Range (Design Flow)ill Overall Destruction Efficiency 98% NOTE: Destruction efficiency shown is valid for combustion ofspecified gas only. PROPRIETARY AND CONFIDENTIAL Page 4 of 8 DCP Midstream — Roggen TEG 02/17/14 John Zink Reference BF -201401-41767 Rev 1 SCOPE OF SUPPLY Item 1, Enclosed Flare (ZTOF) • One (1) John Zink Burner assembly with 2" diameter flanged inlet connection. Individually flanged burner connections allow easy servicing. • One (1) 2" Stainless Steel Cup Burner flare tip • One (1) 4' x 30' (34' OAH) Carbon Steel Construction Stack with three (3) support legs. • Exterior protection (carbon steel) using SSPC-SP-6 surface preparation and a single coat of inorganic zinc primer, 4 mils DFT. • One (1) lot, Design and Engineering (including anchor bolt pattern for stack base.) •- One (1) RE -1D Electronic Ignition Flare Pilot Assembly • One (1) pilot flame monitoring thermocouple with extension thermocouple wire. • Two (2) lifting lugs to assist in erection. • One (1) sight port for ease of viewing the pilot and main flame. • Two (2) 4" diameter COPT couplings with plug provided as sample ports at 90° apart located one stack diameter from the flare top for accurate emission testing. Item 2, Refractory • One (1) 1"' layer of ceramic fiber refractory providing temperature protection and protection for the carbon steel stack. • One (1) stainless steel rain cap consisting of overlapping tabs to provide weather protection at the refractory and flare shell interface. Item 3, Automatic Ignition and Control Station and Pine Rack • One (I) self-supporting steel rack with electrical panels; pilot gas piping and instrumentation; and waste gas piping and instrumentation attached. • One (1) Pilot Gas Control System including a pressure regulator, double block and bleed fail -closed shutdown valve, manual block valve, and pressure indicator. • One (1) NEMA 4 relay based control panel assembly to monitor (through a thermocouple) and control the pilot. Prior to shipping, the enclosure is rack mounted for easy access and no field wiring to the pilot assembly. The control station assembly is completely piped and wired in a UL approved shop and functionally tested simulating actual operations. • One (1) NEIMIA 4 ignition panel assembly including a transformer, pilot spark electrode, and ignition wire. The enclosure is stack mounted for easy access to the pilot assembly. • One (1) Waste Gas Pipe spool for factory mounting of instrumentation as described below. • One (I) lot of coiled wire and flexible conduit for connection to KE-1D Pilot Item 4, SAFETY ITEM - Inlet Flame Arrester (Rack Mounted) • One (1) 2" diameter, eccentric Enardo Flame Arrester with aluminum housing, housing drain, and removable aluminum internals mounted at the flare inlet. Internal elements can be cleaned without removing the flame arrester body from the pipe. • Flame Arrester mounted to waste gas piping on pipe rack. PROPRIETARY AND CONFIDENTIAL Page 5of8 DCP Midstream - Roggen TEG 02/17/14 John Zink Reference BF -201401-41767 Rev 1 Item 5, SAFETY ITEM - Automatic Block Valve fRack Mounted • One (1) automatic block valve assembly consisting of a 2" diameter, high performance butterfly or ball valve and fail -closed pneumatic actuator. The valve has a carbon steel wafer body, 316 stainless steel disk and shaft, and PTFE seal. The pneumatic actuator includes a three-way solenoid valve, speed control valve, position indicator, and auxiliary switches. Pneumatic actuation is achieved using 100 psig of compressed air. • Automatic Block Valve to be prewired and mounted to waste gas piping on pipe rack. Item 6, SAFETY ITEM - Flashback Temperature Shutdown Thermocouple (Rack Mounted) • One (1) additional temperature monitoring thermocouple. • One (1) temperature switch for high temperature shutdown. • This switch will be prewired and incorporated in pipe rack. Item 7, SAFETY ITEM - Stack High Temperature Shutdown Thermocouple • One (1) additional temperature monitoring thermocouple. • One (1) temperature switch for high temperature shutdown. • Additional 20 feet of thermocouple extension wire supplied. Installed by others. • Conduit supplied and installed by others. Jf requested. fohn Zink can also supple flew meter with flow recording capabilities. PROPRIETARY AND CONFIDENTIAL Page 6 of 8 Attachment E Compliance Assurance Monitoring Roggen Gas Plant 53 Operating Permit 95OPWE055 contains an existing Compliance Assurance Monitoring (CAM) Plan for P-136 (November 2012) and no changes are proposed. P033 does not require a CAM plan because uncontrolled emissions are below major source thresholds. P025 does not require a CAM plan because it does not use a control device. 54 dcp Midstream July 7, 2017 DCP Midstream 370 17th St., Suite 2500 Denver, CO 80202 (303) 605-2039 www.dcpmidstream.com UPS Tracking No. 1Z F46 915 02 9595 7252 Colorado Department of Public Health and Environment Air Pollution Control Division ATTN: Elie Schuchardt 4300 Cherry Creek Drive South Denver, CO 80246-1530 Re: Roggen Natural Gas Processing Plant Title V Minor Modification: 95OPWE055 AIRS ID 123/0049 Dear Ms. Schuchardt: DCP Operating Company, LP ("DCP") is submitting the attached operating permit minor modification application for the Roggen Natural Gas Processing Plant ("Facility"), located at Section 24, Range 63W, Township 2N in Weld County, Colorado. This facility currently operates under Title V permit 95OPWE055 originally issued on May 1, 2001 and last revised on August 29, 2005, with an expiration date of May 1, 2006. A timely Title V permit renewal application was submitted in April 2005; however, a revised Title V permit has not yet been issued. Several construction permits have been issued since this date, and have all been subsequently requested to be rolled into the Title V permit for the facility. DCP received a draft Title V permit in May 2013 that incorporated all of the changes that were requested prior to 2013. The requested language changes within this minor modification are based on the conditions in the 2013 draft Title V permit. The facility includes the following equipment and authorizations in addition to others that are not modified as part of this application. Only changes specifically requested in this minor modification are listed below. Minor Modification for Engine Limitation and Emission Updates per Reg. 7 DCP is requesting lower emission limitations and corresponding compliance emission factors for the following engines located at the Roggen Natural Gas Processing Plant in order to match the Colorado Air Quality Control Commission's Regulation Number 7 limits that were submitted on previous AOS APENs': • P001/C154, AIRS ID: 101, Waukesha L7042GSI, 1100 hp • P003/C159, AIRS ID: 103, Waukesha L7042GSI, 1350 hp2 • P008/C161, AIRS ID: 108, Waukesha L7042GSI, 1350 hp • P014/C156, AIRS ID: 114, Waukesha L7042G, 806 hp2 These engines were swung in accordance with AOS provisions in the Title V permit, Section I.2. Any engine that was relocated from outside Colorado is subject to Reg 7 Section XVII.E limits. 2 DCP is including these formally in this minor modification application even though these engines are properly reflected on the 2013 draft Title V permit. Page 2 of 5 Roggen Title V Minor Modification 95OPWE055 • P017/C225, AIRS ID: 117, Superior 8G825, 800 hp • P019/C227, AIRS ID: 119, Superior 8G825, 720 hp • C181, AIRS ID: 134, Waukesha L7042GSI, 1478 hp Please see Appendix F for the affected permit conditions as well as the updated emission limitations and compliance emission factors. Additionally, DCP is seeking to modify the control device downtime for the following sources: • P033 — AIRS Point 130 — Permit 2% enclosed combustor downtime, decrease enclosed combustor control efficiency from 97% to 95% • P136 — AIRS Point 136 — Permit 2% enclosed combustor downtime and decrease enclosed combustor control efficiency from 97% to 95%, or 4% RTO downtime • P137 — AIRS Point 137 — Permit 4% RTO downtime Minor Modification for Control Device Downtime The following is the regulatory history of the sources covered in this minor modification: • P033 — AIRS Point 130 — One (1) triethylene glycol (TEG) dehydrator unit with a processing capacity of 4.0 MMscfd and glycol pump rate of 3.5 gallons per minute (gpm). Still vent emissions routed to a RTO or an enclosed combustor (ECD) at 97% control efficiency. o Title V Permit 95OPWE055 (August 29, 2005)/Draft permit (May 15, 2013) — Gas processing limit of 912.5 MMscf/yr, glycol circulation rate of 2.0 gpm, no still vent controls. o Construction Permit 01WE0208 Issuance 1 (March 18, 2015) — Gas processing limit of 1,460 MMscf/yr, glycol circulation rate of 3.5 gpm, still vent control authorized to RTO or ECD with 97% DRE. o Title V modification application to roll in CP 01WE0208 was submitted on March 17, 2016. o This modification requests: • Removal of RTO as a control option for P033; • Decreasing control efficiency of ECD to 95% to be consistent with other permits, and meet Reg. 7 Section XVII. D requirements; and • Permit 2% annual downtime for ECD maintenance and malfunctions. • Permit limits and proposed language are included in Appendix E. • P136 — AIRS Point 136 - One (1) TEG dehydration unit with a processing capacity of 85 MMscfd and glycol pump circulation rate of 24 gpm. Still vent emissions routed to an ECD or the RTO with 97% control efficiency. o Title V draft permit (May 15, 2013) — Gas processing limit of 31,025 MMscf/yr, glycol pump circulation rate of 24 gpm, still vent control authorized to RTO with 97% DRE. o Construction Permit 10WE1659 Issuance 5 (March 18, 2015) — Gas processing limit of 31,025 MMscf/yr, glycol pump circulation rate of 24 gpm, still vent control authorized to RTO or ECD with 97% DRE. Page 3 of 5 Roggen Title V Minor Modification 95OPWE055 o Title V modification application to roll in CP 01WE0208 was submitted on March 17, 2016. o This modification requests: ■ Decreasing control efficiency of ECD to 95%, while retaining control efficiency of RTO at 97%; • Permit 2% annual downtime for ECD maintenance and malfunctions if ECD is used as the control device; • Permit 4% annual downtime for RTO maintenance and malfunctions if RTO is used as the control device; and • Ensuring that the P136 will achieve a minimum of 95% overall system control to meet Reg 7 Section XVILD requirements. • Permit limits and proposed language are included in Appendix E. • P137 — AIRS Point 137 — One (1) DEA and MDEA natural gas sweetening system for acid gas removal with a design capacity of 85 MMscfd and amine pump rate of 376 gpm. Still vent emissions routed to a RTO with 97% control efficiency o Title V draft permit (May 15, 2013) — Gas processing limit of 31,025 MMscf/yr, still vent control authorized to RTO with 97% DRE. o Construction Permit I 0WE1659 Issuance 5 (March 18, 2015) — Gas processing limit of 31,025 MMscf/yr, still vent control authorized to RTO with 97% DRE. o Title V modification application to roll in CP 01 WE0208 was submitted on March 17, 2016. o This modification requests: ■ Permit 4% annual downtime for RTO maintenance and malfunctions ■ Permit limits and proposed language are included in Appendix E. Project Emission Increases Table 1 Existing Permit Limits Emission Increases AIRS ID Equipment Description NOx (tpy) VOC (tpy) CO (tpy) PM (tpy) NOx (tpy) VOC (tpy) CO (tpy) PM (tpy) 123/0049/130 P-033, Regen Dehya - 0.60 - - - 0.45 - - 123/0049/136 P-136, Inlet TEG Dehyb 2.60 21.60 14.30 - 0.00 28.19 0.00 - 123/0049/137 P-137, Amine Unitb 0.85 2.30 4.60 - 0.00 3.03 0.00 - Total Roggen Net Project Increases New Source Review Thresholds Trigger New Source Review? 0.00 31.67 0.00 0.00 40 40 100 10 5.02 ' - tpy tpy ., sx Highest Individual HAP Total HAP 18.71 a VOC limit is from construction permit 01WE0208 Issued March 18, 2015. b Existing limits are from construction permit 10WE1659 Issuance 5 Issued March 18, 2015. Page 4 of 5 Roggen Title V Minor Modification 95OPWE055 Regulatory Analysis Nonattainment New Source Review & Prevention of Significant Deterioration The federal New Source Review program applies to new or modified sources in both attainment and nonattainment areas that result in emission increases in this are potentially subject cess of pecified thresholds. to nonattainment Weld County is designated as nonattainment for ozone, so sources in or volatile organic compounds (VOC) are in New Source Review if emissions of nitrogen oxides (NOx ) excess of 100 tons per year (tpy). The Roggen Natural Gas Processing Plant is a major. source (potential ired if a emissions > 100 tpy) of both NOx and VOC and nonattaintof 40 tpy or more of eithr pollbe cant. The proposed modification would result in a net emissions increase0 tpy or more current proposed permitting action does not increase existing major emissions sour e for Prevention y 4of Significant as indicated in Table 1. Additionally, Roggen is an 250 tpy. The Deterioration (PSD) purposes due to emissions of NOtrigger x dPOD review. The proposed act on is ssion increases in Table 1 indicate that the project does therefore a minor modification. New Source Performance Standards, 40 Code of Federal Regulations (CFR) Part 60 & National Emission Standards for Hazardous Air Pollutant (40 CFR Part 63) As a general matter, the facility' s NSPS and NESHAP applicability does not change with this minor modification: • The amine unit, P137 will continue to be subject to NSPS Subpart LLL; • The glycol dehydrators, P136 and P033 will continue to be subject to NESHAP Subpart HH. Note that the facility will continue to remain an area source of HAPs after this minor modification; and • All units subject to an NSPS and NESHAP are subject to NSPS and NESHAP Subpart A, General Provisions. State Regulations Regulation 3, Part A, Section II must be Regulation 3, Part A, Section II describes when an Air Pollutant Emission Notice (APEN) submitted for new, modified, and existing sources. Updated he aAPENs mine unit are included in this application for the two TEG dehydration units (P033 and P136) an (P137). Regulation 3, Part C maRegulation 3, Part C describes the requirements for Operating n rolled its.into This Operating Permit is a 95OPWBOS and m the changes described this application are requested Regulation 3, Part D Regulation 3, Part D describes the requirementsfor major modification and s therefore neither subject to review and PSD review. The proposed actson is aminor NSR nor PSD reviews. Page 5 of 5 Roggen Title V Minor Modification 95OPWE055 Regulation 6, Part A Regulation 6 incorporates by reference the EPA's New Source Performance Standards (NSPS). NSPS applicability is discussed above. Regulation 7 The requirements of Reg 7, Section XII and XVII apply to oil and gas operations located in the 8 -hour Ozone Control Area. With this minor modification request, DCP will continue to demonstrate compliance with Section XII. H. and Section XVII.D.3 by achieving at least 95 percent control of the glycol dehydrator still vent and flash tank system emissions for P033 and P136. Regulation 8 Regulation 8 incorporates by reference the EPA's NESHAPs in 40 CFR 61 and 40 CFR 63. The dehydrators at this facility, P033 and P136, are subject to 40 CFR 63 Subpart HH. They will continue to comply with the applicable requirements under this subpart. Attachments Attached please find forms and attachments needed to make the requested changes to operating permit 95OPWE055, as well as the required certification signed by the Responsible Official, David M. Jost, Vice President of Northern Operations (formerly titled General Manager of Area Operations). Also included are: • Appendix A: RO Signature Page • Appendix B: APEN Fee Payment • Appendix C: Updated APENs for regen TEG dehy (P033), inlet TEG dehy (P136), and amine unit (P137) • Appendix D: Emission Calculations for regen TEG dehy (P033), inlet'1'.G dehy (P136), and amine unit (P137), as well as an updated list of insignificant activities • Appendix E: Title V Red -Line for regen '1EG dehy (P033), inlet TEG dehy (P136), and amine unit (P137) • Appendix F: Title V Red -Line for Requested Engine Emission Limitation Updates • Appendix G: Updated Facility Wide Emissions Inventory Form 102 If you have any questions or require any additional information about this submittal, please contact me at (303) 605-2039 or RShankaran@dcpmidstream.com. Sincerely, DCP Operating Company, LP Roshini Shankaran Environmental Engineer /rmm /bco APPENDIX A: RO SIGNATURE PAGE er authority of I have reviewed this Minor Modification tspent retiosupplied based oninformation and bdelief formed ulation No. 3, Part C, Section X (5 CCR 1001-5) mentirety and after reasonable inquiry, I certify that the proposed modification meets the criteria for use of minor permit modification procedures and request that such ulation No. 3, Partres by used to process this C, Section X.D.3 (5 CCR application. This certification conforms with Re g 1001-5). David M. Jost Printed or Typed Name Signature of R ponsible Official Vice President of Northern Operations Title 11 Date APPENDIX C: UPDATED APENS P033 Regen TEG Dehy, AIRS ID: 123/0049/130 P136 Inlet TEG Dehy, AIRS ID: 123/0049/136 P137 Amine Unit, AIRS ID: 123/0049/137 Glycol Dehydration Unit APEN - Form APCD-202 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Glycol Dehydration (Dehy) Units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options wilt not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Rov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 01 WE0208 q5 6 PNr6 055 AIRS ID Number: 123 / 0049 / 130 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Site Name: Site Location: DCP Operating Company, LP Roggen Natural Gas Processing Plant Site Location Section 24, R63W, T2N County: Weld Mailing (Include Address: p Code370 17th Street, Suite 2500 (Include Zip Code) Denver, CO 80202 E -Mail Address2: rshankaran@dcpmidstream.com NAICS or SIC Code: 1311 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 1Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-202 - Glycol Dehydration Unit APEN - Revision 9/2016 365751 /y�/y��, COLORADO 1 w+annsswv1,n.nrm I!"P@ dl Permit Number: 01WE0208 AIRS ID Number: 123 / 0049 e 130 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source -OR - ✓❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit O Change permit limit ❑ Transfer of ownership3 0 Other (describe below) - OR • APEN submittal for update only (Please note blank APENs will not be accepted) ADDITIONAL PERMIT ACTIONS ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: incorporate 2% enclosed combustor downtime 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: dehydration unit to regenerate the moleseive beds Facility equipment Identification: P-033 For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 1 /1 / 1976 / / 0 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area Is this unit located at a stationary source that is considered a Major Source of (HAP) Emissions Form APCD-202 -Glycol Dehydration Unit APEN - Revision 9/2016 days/week Yes Yes El weeks/year No No CO I. OR ADO 2 I IrS:A� o�pme�wed� HFII�T 6Envinrv„ant 0 O1 ir+ air Permit Number: 01W0208 AIRS ID Number: 123 /0049/130 NI or [Leave blank unless APCD has already assigned a permit # and AIRS ID] IS-pHQ p.,4 by ND Manufacturer: Custom Model Number: Custom -N„ Ikh Dehydrator Serial Custom Reboiler Rating: n/a MMBTU/hr Number: NIt ., Ethylene Glycol DiEthylene Glycol TriEthylene Glycol Fill Glycol Used: ❑ (EG) ❑ (DEG) ❑✓ (TEG) Section 4 - Dehydration Unit Equipment Information Glycol Pump Drive: ❑ Electric ❑✓ Gas If Gas, injection pump ratio: Pump Make and Model: Custom Glycol Recirculation rate (gal/min): Max: 3.5 Lean Glycol Water Content: 1.5 Wt.% 0.08 # of pumps: Requested: 3.5 Acfm/gpm 1 Dehydrator Gas Throughput: Design Capacity: 4.0 MMSCF/day Requested: 1,460 MMSCF/year Actual: 0 MMSCF/year Inlet Gas: Pressure: 850 Water Content: Wet Gas: Flash Tank: Pressure: 125 Cold Separator: Pressure: psig Temperature: 80 lb/MMSCF ❑✓ Saturated Dry gas: 7,0 lb/MMSCF psig Temperature: 90 °F O NA psig Temperature: °F ❑✓ NA Stripping Gas: (check one) p None ❑ Flash Gas O Dry Gas ❑ Nitrogen Flow Rate: scfm °F Additional Required Information: ❑ Attach a Process Flow Diagram O Attach GRI-GLYCalc 4.0 Input Report Et Aggregate Report (or equivalent simulation report/test results) O Attach the extended gas analysis (including BTEX Et n -Hexane, temperature, and pressure) Form APCD-202 -Glycol Dehydration Unit APEN - Revision 9/2016 COLORADO 3 I JAW f,= sewn sav+roomvn+ Permit Number: 01WE0208 AIRS ID Number: 123 /0049/ 130 ❑✓ Upward ❑ Horizontal [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.1177 / -104.3883 Operator Stac ID No Dischar H ght Above Ground Level (Feet) Temp ( F) Flow Rate ACF/N Velocity c) (ft/sec) P-033 Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): COLORADO Form APCD-202 -Glycol Dehydration Unit APEN - Revision 9/2016 Permit Number: 01WE0208 AIRS ID Number: 123 /0049/130 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information O Condenser: Used for control of: Type: Make/Model: Maximum Temp Average Temp Requested Control Efficiency O VRU: Used for control of: Size: Make/Model: Requested Control Efficiency VRU Downtime or Bypassed % ❑ Combustion Device: Used for control of: Rating: Type: still vent stream* enclosed combustor Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: MMBtu/hr Make/Model: 95 98 % John Zink Waste Gas Heat Content 569 Btu/scf Constant Pilot Light: ❑✓ Yes 0 No Pilot burner Rating 0.05 MMBtu/hr Closed p Loop System: Used for control of: flash tank vent stream Description: stream routed to low pressure inlet System Downtime 0 0/0 ❑ Other: Used for control of: Description: Control Efficiency Requested *ECD used for still vent control has 2% (175.2 hours) of annual downtime for maintenance and repairs. Still vent emissions will be vented to atmosphere during ECD downtime. Form APCD-202 -Glycol Dehydration Unit APEN - Revision 9/2016 coLORADO 5 I A� 1=` ro= Permit Number: 01WE0208 AIRS ID Number: 123 /0049/130 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach alt emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ✓❑ Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Overall Requested Control Efficiency (% reduction in emissions) PM SOX NOx CO voe Enclosed Combustor 95% HAPs Other: Enclosed Combustor 95% l e..cltireO Pkc Loom- usimbecod rrnsAess lilctlR 171-11 t' ESS PM From what year is the following reported actual annual emissions data? 2016 Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Uncontrolled Emission Factor Emission Factor Units Emission Factor Source Mfg. etc) Uncontrolled (Tons%year) Controlled5 (Tons/year). Ann l Pere mit missionhmit(s) Uncontrolled (Tons/year) Controlled (Tons/year) SOX NOx CO VOC &3.2[n61 04/00 lb/M Mscf GlyCalc 0 0 WI Het MR mei Wrkub t 1.05 Benzene 2.3i%e Nitat Toluene 2.5-4,5c6 401144 lb/MMscf GlyCalc 0 0 0.11 lb/MMscf GlyCalc 0 0 0.13 Ethylbenzene o.cci4b ,gp lb/MMscf GlyCalc 0 0 0.00 Xylenes o46 lb/MMscf GlyCalc 0 0 o.1o2 0.04 n -Hexane p l ,gl lb/MMscf GlyCalc 0 0 O.l 0.02 2,2,4- Trimethylpentane Other: a Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual wntrolled emissions reported. If source has not yet started operating, leave blank. Form APCD-202 -Glycol Dehydration Unit APEN - Revision 9/2016 COLORADO gi 6 i ', n, Permit Number: 01WE0208 AIRS ID Number: 123 /0049/130 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. liVori Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: ❑r Engineer's Preliminary Analysis conducted ✓0 Draft permit prior to issuance ✓❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/aped Form APCD-202 -Glycol Dehydration Unit APEN - Revision 9/2016 7 I COLORADO '.. o aleh Ea emwmm semen rfnv�ronmvm �I( 1T JUL 10201 Glycol Dehydration Unit APEN - Form APCD-202 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Glycol Dehydration (Dehy) Units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: J.G.WE1659 049N O AIRS ID Number: 123 / 0049 / 136 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Site Name: Site Location: DCP Operating Company, LP Roggen Natural Gas Processing Plant Site Location Section 24, R63W, T2N County: Weld Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 E -Mail Address2: rshankaran@dcpmidstream.com NAICS or SIC Code: 1311 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-202 - Glycol Dehydration Unit APEN - Revision 9/2016 365752 © COLORADO 1 I A- 5, «mot. Na,�4k6 U1tlIroIF11NM II hIi l`�II Permit Number: 10WE1659 AIRS ID Number: 123 / 0049 / 136 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source - OR- ✓❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership3 ✓❑ Other (describe below) - OR APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ▪ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info & Notes: incorporate 2% enclosed combustor downtime and 46/o RTO downtime Per einclAGone ,a ug_ Reel 8I (ll 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: dehydration unit for water removal at the plant inlet Facility equipment Identification: P-1 36 For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 7 /1 /2011 / / ✓❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Will this equipment be operated in any NAAQS nonattainment Yes ❑ No area Is this unit located at a stationary source that is considered a ❑ Yes 0 No Major Source of (HAP) Emissions Form APCD-202 -Glycol Dehydration Unit APEN - Revision 9/2016 2 COLORADO 'HWICABFmironmart Permit Number: 10WE1659 AIRS ID Number: 123 / 0049 / 136 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: Dehydrator Serial Number: Glycol Used: Evco Fabracation 2090 Ethylene Glycol (EG) Model Number: T-901. Reboiler Rating: n/a ❑ (DEG) DiEthylene Glycol Glycol Pump Drive: p Electric ❑ Gas If Gas, injection pump ratio: Pump Make and Model: Glycol Recirculation rate (gal/min): Max: Lean Glycol Water Content: 1.5 Wt.% ▪ (TEG) # of pumps: Requested: 24 MMBTU/hr hr TriEthylene Glycol Acfm/gpm 1 Dehydrator Gas Throughput: Design Capacity: 85 MMSCF/day Requested: 31,025 MMSCF/year Actual: 7,727.78 MMSCF/year Inlet Gas: Water Content: Flash Tank: Cold Separator: Pressure: 829.33 psig Wet Gas: 97.96 lb/MMSCF Pressure: 72.33 psig Pressure: psig Stripping Gas: (check one) ✓❑ None ❑ Flash Gas Flow Rate: ❑ Dry Gas ❑ Nitrogen scfm Temperature: ❑ Saturated Dry gas: 4 116 °F Temperature: Temperature: 128.5 °F °F lb/MMSCF ❑ NA ❑✓ NA Additional Required Information: ❑ Attach a Process Flow Diagram ❑ Attach GRI-GLYCalc 4.0 Input Report Et Aggregate Report (or equivalent simulation report/test results) ❑ Attach the extended gas analysis (including BTEX i3 n -Hexane, temperature, and pressure) Form APCD-202 -Glycol Dehydration Unit APEN - Revision 9/2016 3 I COLORADO 24141 bm VIK*D, .8 HaIIN bEn.�rcnmMt Permit Number: 10WE1659 1;11 �n AIRS ID Number: 123 /0049/ 136 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.1177 / -104.3883 Operator , StacklD IVo�� Dischar-e Heights Above Ground Level�� (Feet Temp I F)�(ACFM,(ft } arty FfowRate �. Yeloctt sect ��; P-136 Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-202 -Glycol Dehydration Unit APEN - Revision 9/2016 COLORADO p� ' Haa1N 6EnvlraNnert pill Omit, Permit Number: 10WE1659 AIRS ID Number: 123 /0049/136 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information ❑ Condenser: Used for control of: Type: Maximum Temp Requested Control Efficiency Make/Model: Average Temp VRU: Used for control of: Size: Make/Model: ■ Requested Control Efficiency % . VRU Downtime or Bypassed Combustion Device: Used for control of: Still vent stream* Rating: MMBtu/hr Type: RTO/enclosed combustor Make/Model: Anguil / John Zink Requested Control Efficiency: 97/95 Btu/scf MMBtu/hr 0 Manufacturer Guaranteed Control Efficiency 98 Minimum Temperature: 1,450 Waste Gas Heat Content 697 Constant Pilot Light: • Yes • No Pilot burner Rating 0.05 Closed Loop System: Used for control of: flash tank vent stream Description: stream routed to low pressure inlet p System Downtime 0 Other: Used for control of: still vent stream Description: RTO no constant pilot; ECD has constant pilot p Control Efficiency Requested ° *ECD used for still vent control has 2% (175.2 hours) of annual downtime for maintenance and repairs. RTO used for still vent control has 4% (350.4 hours) of annual downtime for maintenance and repairs. Still vent emissions will be vented to atmosphere during ECD/RTO downtime. Form APCD-202 -Glycol Dehydration Unit APEN - Revision 9/2016 tz COLORADO 5 I AWv o. PM PM Permit Number: 10 WE 1659 AIRS ID Number: 123 /0049/136 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ✓❑ Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Overall Requested Control Efficiency (% reduction in emissions) Control Equipment Description'. SOX NOX CO VOC RTO / Enclosed Combustor 97/95 HAPs RTO / Enclosed Combustor 97/95 Other: From what year is the following reported actual annual emissions data? 2016 Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) • Uncontrolled Emission . Factor:;, Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Controlleds (Tons%year) Uncontrolled (Tons/year) Controlled (Ton's/year) Uncontrolled (Tons/year). SOX NOx 0.068 lb/MMBtu AP -42 0.14 0.14 2.6 2.6 CO 0.37 lb/MMBtu AP -42 0.75 0.75 14.3 14.3 VOC 64.18 Ib/MMscf ProMax 40.90 0.59 995.54 49.79 Benzene 2.52 Ib/MMscf ProMax 1.56 0.05 39.02 2.65 Toluene 2.43 lb/MMscf ProMax 0.56 0.02 37.69 2.58 Ethylbenzene 0.12 lb/MMscf ProMax 0.00 0.00 1.85 0.13 Xylenes 0.50 lb/MMscf ProMax 0.00 0.00 7.77 0.53 n -Hexane 3.42 lb/MMscf ProMax 1.47 0.04 53.10 3.00 2,2,4- Trimethylpentane Other: Methanol 0.01 lb/MMscf ProMax 16.40 0.49 0.22 0.02 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-202 -Glycol Dehydration Unit APEN - Revision 9/2016 6 I COLORADO Cepart.u.awmm l"P h per t-411 Permit Number: 10WE1659 AIRS ID Number: 123 /0049/136 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. 1/-71zO7- Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: E✓ Engineer's Preliminary Analysis conducted 0 Draft permit prior to issuance rj Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-202 -Glycol Dehydration Unit APEN - Revision 9/2016 7 COLORADO oeparteieneN Public 711 l r Amine Sweetening Unit - Form APCD-206 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Amine Sweetening Units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 65,9--. io5 opW O'55 AIRS ID Number: 123 / 0049 / 137 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: P-137 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Site Name: Site Location: DCP Operating Company, LP Roggen Natural Gas Processing Plant Site Location Section 24, R63W, T2N County: Weld Mailing Address: (Include Zip Code) 370 17th Street Suite 2500 Denver, CO 80202 E -Mail Address2: rshankaran@dcpmidstream.com NAICS or SIC Code: 1311 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 365753 COLORADO 1 I aePr.i Permit Number: 10WE1659 AIRS ID Number: 123 /0049/ 137 [Leave blank unless APCD has already assigned a permit #, and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source -OR - ✓❑ MODIFICATION to existing permit (check each box below that applies) 0 Change fuel or equipment El Change company name ❑ Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership3 p Other (describe below) - OR • APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ID Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: incorporate 4% RTO downtime 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Amine unit for acid gas removal Facility equipment Identification: For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: P-137 7 /1 /2011 / / ❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week Will this equipment be operated in any NAAQS nonattainment Yes area Does this facility have a design capacity less than 2 long Yes tons/day of H2S in the acid gas? 0 0 weeks/year No No Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 COLORADO 2IAI �� N C�bFnwewue1LL Permit Number: 10WE 1659 AIRS ID Number: 123 /0049/ 137 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer:. Evco Fabrication Model : T-9002 Serial Number: 2082 Reboiler Rating: n/a Amine Type: Pump Make and Model: ❑ MEA MMBtu/hr Absorber Column Stages: 7 ❑ DEA ❑ TEA stages ❑✓ MDEA ❑ DGA # of pumps: 1 Sweet Gas Throughput's: Design Capacity: 85 MMSCF/day Requested: 31,025 MMSCF/year Actual: 0.0 MMSCF/year 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Inlet Gas: Pressure: 847.33 psig Temperature: 86 °F Rich Amine Feed: Pressure: 839.33 psia Flowrate: 376 Gal/min Temperature: 131 °F Lean Amine Stream: Pressure: 266 psia Temperature: 252 Flowrate: 3.550 Gal/min Wt. % amine: 50 Mole loading ll S 1.23E-6 Mole Loading 0.0099 CO2. °F Sour Gas Input: Pressure: Flowrate: psia MMSCF/Day Temperature: °F NGL Input: Pressure: Flowrate: psia Gal/min Temperature: °F Flash Tank: El No Flash Tank Pressure: 60 psia Temperature: 133 °F Additional Required Information: El Attach a Process Flow Diagram ❑ Attach the simulation model inputs Et emission report El Attach composition reports for the rich amine feed, sour gas feed, NGL feed, Et outlet stream (emissions) El Attach the extended gas analysis (including BTEX ft n -Hexane, H25, COZ, temperature, and pressure) Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 3,A COLORADO Department b Permit Number: 1 0WE1659 IlM°'II pp4 Pi .II r�n INlI AIRS ID Number: 123 /0049/ 137 III [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.1174 / -104.3883 Operator Stack ID NO Discharge Height Above Ground Level (Feet) Temp ( F) Flow Rate (ACFM) Velocity (ft/sec) P-137 Indicate the direction of the stack outlet: (check one). ❑✓ Upward 0 Horizontal ❑ Downward ❑ Other (describe): 0 Upward with obstructing raincap Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inches): 0 Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 4, AV COLORADO DeD.resneseo Patic !With b FnweuneN Ili "off MII NI! q.su Permit Number: 10WE1659 AIRS ID Number: 123 /0049/ 137 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information ❑ VRU: Used for control of: Size: Make/Model: Requested Control Efficiency VRU Downtime or Bypassed 0 Combustion Device: Used for control of: still vent stream* Rating: MMBtu/hr Type: RTO Make/Model: Anguil / Model 150 Requested Control Efficiency: 97 % SN: AE 597225 Manufacturer Guaranteed Control Efficiency 99 Minimum Temperature: 1,450 Waste Gas Heat Content 29 Btu/scf Constant Pilot Light: ❑ Yes ✓❑ No Pilot burner Rating MMBtu/hr 0 Other: Used for control of: flash tank stream Description: closed loop system Control Efficiency 1 % Requested * RTO used for still vent control has 4% (350.4 hours) of annual downtime for maintenance and repairs. Still vent emissions will be vented to atmosphere during RTO downtime. Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 ASSSTTTTTTICOLORADO 5 friZIT V= KeLLA.6 EnvuexeaN PM PM Permit Number: 10WE1659 AIRS ID Number: 123 /0049/ 137 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 -Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ® Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) SOX H 2 NOx VOC RTO 97% CO HAPs RTO 97% Other: From what year is the following reported actual annual emissions data? 2016 Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Criteria Pollutant Emissions Inventory Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)4, Uncontrolled (Tons/year) Controlled5 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) !" SOX 1.88 ton SO2/ton H2s ProMax 0 0 30.0 30.0 H2S 0.09 Ib/MMscf ProMax 0 0 1.39 0.10 NO. 0.068 lb/MMbtu AP -42 0 0 0.8 0.8 VOC 18.24 lb/MMscf ProMax 0 0 282.96 5.33 CO 0.37 lb/MMbtu AP -42 0 0 4.6 4.6 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 6 I A COLORADO Department of Pu6ne xeollnxFnnmenwm Permit Number: 10WE1659 P, .I AIRS ID Number: 123 /0049/ 137 Tj [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 (continued) 5 Non -Criteria Reportable Pollutant Emissions Inventory Pollutant Chemical Abstract Service (CAS) Number Uncontrolled Emission Factor " Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions* Uncontrolled (lbs/year) Controlleds (lbs/year) Benzene 71432 1.64 lb/MMscf AP -42 50,789.27 3,292.34 Toluene 408883 1.07 lb/MMscf AP -42 33,225.36 2,178.14 Ethylbenzene 100414 0.03 lb/MMscf AP -42 1,074.43 70.38 Xylenes 1330207 0.19 lb/MMscf AP -42 6,018.75 400.11 n -Hexane 110543 0.21 lb/MMscf AP -42 6,508.94 47.24 2,2,4- Trimethylpentane 540841 Other: * NOT Actual emissions. Instead providing potential -to -emit (PTE) for the purposes of this minor mod app Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. - 1(11/20' Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: �✓ Draft permit prior to issuance i Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 COLORADO 7 I AV [COLORADO HUNIb EnvUanmaN APPENDIX D: EMISSION CALCULATIONS Appendix D-1: P033 Regen TEG Dehy with RTO downtime Appendix D-2: P136 Inlet TEG Dehy with RTO downtime Appendix D-3: P136 Inlet TEG Dehy with ECD downtime Appendix D-4: P137 Amine Unit with RTO downtime Appendix D-5: Insignificant Activities List Appendix D-1, 1 of 3 APPENDIX D-1: 2% ECD Downtime, P033 Regen TEG Dehydration Unit Emissions DCP Operating Company, LP Roggen Natural Gas Processing Plant Source ID Description Manufacturer Model Serial # Operation Date Operation Wet Gas Temperature Wet Gas Pressure Wet Gas Water Content Dry Gas Flow Rate Dry Gas Water Content Lean Glycol Water Content Lean Glycol Flow Rate Cold Separator? Cold Separator Temperature Cold Separator Pressure Glycol Pump Make & Model Glycol Pump Type Glycol Gas Injection Pump Ratio Flash Tank? Flash Tank Temperature Flash Tank Pressure Flash Tank Control VRU Downtime Cooling Cycle: P033 Dehydration Unit Custom Custom Custom 1/1/1976 8760 hr/yr 80 deg F 850 psig Saturated IbH2O/MMscf 4.0 MMscfd 7.0 IbH2O/MMscf 1.0 wt% H2O 3.5 gpm N Y/N N/A deg F N/A psig Kimray 9015PV Gas driven Elec. or Gas 0.08 acfm/gpm Y Y/N 125 deg F 90 psig 100.00% Recycled to Inlet N/A Stripping Gas? N Y/N What is Stripping Gas? Stripping Gas Flow Rate N/A scfm Condenser? N Y/N Condenser Temperature deg F Condenser Pressure psia Combustor? Y Y/N Combustor Type Enclosed Combustor Combustor Ambient Air Temp 60 deg F Combustor Excess Oxygen 0 Combustor Destruction Efficiency 95% Combustor Downtime 2% Uncontrolled Hours of ECD Downtime - Cooling Cycle 87.6 hr/yr Hours of ECD Uptime - Cooling Cycle 4292.4 hr/yr Hours of ECD Downtime - Heating Cycle 87.6 hr/yr Hours of ECD Uptime - Heating Cycle 4292.4 hr/yr Component Cooling Cycle Still Vent Uncontrolled Emissions' (lb/hr) (tpy) Cooling Cycle Still Vent ECD Control Emissions' (lb/hr) (tpy) Cooling Cycle Still Vent 2% Downtime Emissions' (lb/hr) (tpy) Cooling Cycle Flash Gas Uncontrolled Emissions' (lb/hr) (tpy) Cooling Cycle Flash Tank Controlled Emissions4 (lb/hr) (tpy) Methane 0.80 1.75 0.04 0.09 0.80 0.04 42.25 92.52 0.00 0.00 Ethane 1.03 2.26 0.05 0.11 1.03 0.05 13.25 29.02 0.00 0.00 Propane 0.78 1.71 0.04 0.08 0.78 0.03 4.58 10.04 0.00 0.00 Isobutane 0.14 0.31 0.01 0.01 0.14 0.01 0.49 1.07 0.00 0.00 n -Butane 0.43 0.94 0.02 0.05 0.43 0.02 1.11 2.43 0.00 0.00 Isopentane 0.10 0.23 0.01 0.01 0.10 0.00 0.22 0.48 0.00 0.00 n -Pentane 0.15 0.32 0.01 0.02 0.15 0.01 0.24 0.52 0.00 0.00 Cyclopentane 0.03 0.08 0.00 0.00 0.03 0.00 0.01 0.03 0.00 0.00 n -Hexane 0.04 0.09 0.00 0.00 0.04 0.00 0.03 0.07 0.00 0.00 Cyclohexane 0.05 0.11 0.00 0.01 0.05 0.00 0.01 0.02 0.00 0.00 Other Hexanes 0.05 0.12 0.00 0.01 0.05 0.00 0.06 0.13 0.00 0.00 Heptanes 0.04 0.09 0.00 0.00 0.04 0.00 0.01 0.03 0.00 0.00 Methylcyclohexane 0.03 0.06 0.00 0.00 0.03 0.00 0.00 0.01 0.00 0.00 Benzene 0.20 0.44 0.01 0.02 0.20 0.01 0.00 0.01 0.00 0.00 Toluene 0.10 0.21 0.00 0.01 0.10 0.00 0.00 0.00 - 0.00 0.00 Total VOC 2.15 4.71 0.11 0.23 2.15 0.09 6.78 14.85 0.00 0.00 Total HAP 0.34 0.75 0.02 0.04 0.34 0.01 0.04 0.08 0.00 0.00 1. Uncontrolled Still Vent and Flash Tank cooling cycle emissions obtained from GlyCalc Aggregate Report dated April 8, 2014 2. ECD Control Emissions apply a 95% DRE to Still Vent Uncontrolled emissions and are annualized based on annual hours of cooling cycle ECD uptime. 3. 2% ECD Downtime Emissions are based on Still Vent Uncontrolled Emissions and are annualized based on annual hours of cooling cycle ECD downtime. 4. There is no flash tank downtime because emissions are piped to low-pressure inlet. Appendix D-1, 2 of 3 Heating Cycle: Heating Cycle Still Vent Uncontrolled Emissions' (tpy) Heating Cycle Still Vent ECD Control Emissions' (lb/hr) (tpy) Heating Cycle Still Vent 2% Downtime Emissions' (lb/hr) (tpy) Heating Cycle Flash Gas Uncontrolled Emissions' (lb/hr) (tpy) Heating Cycle Flash Tank Controlled Emissions' (lb/hr) (tpy) 0.00 Component Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane Benzene Toluene Ethylbenzene Xylenes (lb/hr) 0.79 1.05 0.91 0.18 0.59 0.16 0.25 0.06 0.11 0.14 0.13 0.21 0.17 0.55 0.75 0.03 0.28 0.30 1.74 2.31 1.99 0.39 1.29 0.34 0.54 0.14 0.23 0.31 0.28 0.45 0.37 1.21 1.64 0.07 0.62 0.65 0.04 0.05 0.05 0.01 0.03 0.01 0.01 0.00 0.01 0.01 0.01 0.01 0.01 0.03 0.04 0.00 0.01 0.01 0.09 0.11 0.10 0.02 0.06 0.02 0.03 0.01 0.01 0.02 0.01 0.02 0.02 0.06 0.08 0.00 0.03 0.03 0.79 0.03 1.05 0.05 0.91 0.04 0.18 0.01 0.59 . 0.03 0.16 0.01 0.25 0.01 0.06 0.00 0.11 0.00 0.14 0.01 0.13 0.01 0.21 0.01 0.17 0.01 0.55 0.02 0.75 0.03 0.03 0.00 0.28 0.01 0.30 0.01 42.11 13.63 5.37 0.63 1.53 0.33 0.40 0.02 0.09 0.03 0.14 0.07 0.02 0.01 0.01 0.00 0.00 0.01 92.23 29.84 11.76 1.37 3.36 0.73 0.88 0.05 0.19 0.06 0.32 0.16 0.05 0.03 0.02 0.00 0.00 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 C8+ Heavies Total VOC 4.81 1.72 10.52 3.77 0.24 0.09 0.52 0.18 4.81 0.21 1.72 0.08 8.68 0.11 19.01 0.24 0.00 0.00 0.00 Total HAP A to Re on dated Apol 8 2014 1. Uncontrolled Still Vent and Flash Tank heating cycle emissions obtained from GlyCalc ggrega p 2. ECD Control Emissions apply a 95% DRE to Still Vent Uncontrolled emissions and are annualized based on annual hours of heating cycle ECD uptime. 3. 2% ECD Downtime Emissions are based on Still Vent Uncontrolled Emissions and are annualized based on annual hours of heating cycle ECD downtime. 4. There is no flash tank downtime because emissions are piped to low-pressure inlet. Total PO33 Emissions Overall Total Uncontrolled Emissions' (tpy) Total ECD Uptime Controlled Emissions' (lb/hr) (tpy) Total ECD Downtime Emissions' (lb/hr) (tpy) Total Flash Tank Emissions' (lb/hr) (tpy) System Wide Total Emissions' (lb/hr) (tpy) S stem Sy Control' Component Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane (lb/hr) 85.96 28.96 11.65 1.43 3.67 0.81 1.03 0.14 0.26 376.49 126.86 51.02 6.27 16.06 3.56 4.52 0.60 1.15 0.08 0.10 0.08 0.02 0.05 0.01 0.02 0.00 0.01 0.17 0.22 0.18 0.03 0.11 0.03 0.04 0.01 0.02 1.59 0.07 2.09 0.09 1.69 0.07 0.32 0.01 1.02 0.04 0.26 0.01 0.39 0.02 0.10 0.00 0.14 0.01 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.67 2.19 1.78 0.33 1.07 0.27 0.41 0.10 0.15 0.20 0.24 0.32 0.26 0.05 0.15 0.04 0.06 0.01 0.02 0.03 98.93 Cyclohexane Other Hexanes Heptanes Methylcyclohexane Benzene Toluene Ethylbenzene Xylenes 0.22 0.39 0.34 0.23 0.77 0.86 0.03 0.28 0.31 0.98 1.70 1.47 0.99 3.38 3.76 0.14 1.25 1.36 0.01 0.01 0.01 0.01 0.04 0.04 0.00 0.01 0.01 0.02 0.02 0.03 0.02 0.08 0.09 0.00 0.03 0.03 0.19 0.18 0.01 0.25 0.01 0.20 0.01 0.75 0.03 0.85 0.04 0.03 0.00 0.28 0.01 0.30 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.19 0.26 0.21 0.79 0.89 0.03 0.30 0.31 0.03 0.04 0.03 0.11 0.13 0.00 0.04 0.0 4 1.05 CB+Heavies O8 Total VOC 22.42 98.21 0.35 0.75 6.96 0.30 0.09 0.00 0.00 0.00 0.00 7.31 2.16 031 2.21 9.67 0.10 0.22 2.06 Total HAP ' s from the cooling cycle and heating cycle. 1. Total P033 uncontrolled emissions are represented as the sum of still vent and Appendix D-1, 3 of 3 Description Vent Flow Rate Vent Flow Rate Hours of operation Annual Flow Rate Reqen Dehy Still Vent Stream - Heating Cycle 0.0049 203.0 4380 0.889 MMSCFD scf/hr hr/yr MMscf/yr Component % Mol Fraction Pure Component Mol Weight (]b/Ib-mol) Component Fraction Mol Weight (Ib/Ib-mol) Component Mass Fraction Pure Component Heat Value (Btu/scf) Component Fraction Heat Value (Btu/scf) 93.3 9.24 0.0924 16.04 1.48 0.1113 1010.0 Methane 6.56 0.0656 30.07 1.97 0.1481 1769.6 116.1 Ethane 3.86 0.0386 44.10 1.70 0.1278 2516.1 97.1 Propane 0.57 0.0057 58.12 0.33 0.0246 3251.9 1 . 5 i•Butane 1.90 0.0190 58.12 1.10 0.0829 3262.3 62.0 n -Butane 0.41 0.0041 72.15 0.29 0.0220 4000.9 16.2 i-Pentane 0.64 0.0064 72.15 0.46 0.0345 4008.9 25.5 n -Pentane 0.17 0.0017 70.10 0.12 0.0089 3763.7 6.4 Cyclopentane 0.23 0.0023 86.18 0.20 0.0148 4755.9 10.8 n -Hexane 0.31 0.0031 84.16 0.26 0.0197 4481.5 14.0 Oyclohexane 0 28 0.0028 86.18 0.24 0.0181 4755.9 13.3 Other Hexanes 0.39 0.0039 100.20 0.39 0.0290 5502.5 212 Heptanes 0.32 0.0032 98.19 0.32 0.0238 5215.7 16.8 Methylcyclohexane 0.0000 114.23 0.00 0.0000 6231.7 0.0 2,2,4-Trimethylpentane 1.32 0.0132 78.11 1.03 0.0774 3741.8 49.4 Benzene 1.52 0.0152 92.14 1.40 0.1051 4475.0 68.0 Toluene 0.06 0.0006 106.17 0.06 0.0044 5222.2 2.9 Ethylbenzene 0.50 0.0050 318.50 1.59 0.1193 5208.8 26.0 Xylenes 033 0.0033 114.23 0.37 0.0280 6248.9 20.4 Octanes + 0.0000 32.04 0.00 0.0000 866.7 0.0 Methanol 28.59 - 0.2859 13.32 1.00 678 Description Vent Flow Rate Vent Flow Rate Hours of operation Annual Flow Rate Component % Mol Fraction Pure Component Mol Weight ((lb/lb-mop(Ib/Ib-mol) Component Fraction Mol Weight Component Mass Fraction Pure Component Heat (Btu/scf) Vlla Component Fraction Hat Valle ( f ) 10.00 0.1000 16.04 1.60 0.2006 1010.0 101.0 Methane 6.89 0.0689 30.07 2.07 0.2591 1769.6 121.9 Ethane 3.56 0.0356 44.10 1.57 0.1963 2516.1 89.6 Propane 0.48 0.0048 58.12 0.28 0.0350 3251.9 15.6 i-Butane 1.49 0.0149 58.12 0.87 0.1083 3262.3 48.6 n -Butane 0.29 0.0029 72.15 0.21 0.0259 4000.9 11.5 i-Pentane 0.41 0.0041 72.15 0.29 0.0368 4008.9 16.4 n -Pentane 0.10 0.0010 70.10 0.07 0.0087 3763.7 3.7 Cyclopentane 0.09 0.0009 86.18 0.08 0.0099 4755.9 4.4 n -Hexane 0.12 0.0012 84.16 0.10 0.0122 4481.5 5.2 Cyclohexane 0.13 0.0013 86.18 0.11 0.0137 4755.9 6.0 4.7 Othher Hexanes 0.09 0.0009 100.20 0.09 0.0107 5502.5 3.0 Heptanes 0.06 0.0006 98.19 0.06 0.0071 5215.7 0.0 Methylcyclohexane 0.00 0.0000 114.23 0.00 0.0000 6231.7 19.5 2,2,4-Trimethylpentane Benzene 0.52 0.0052 78.11 0.41 0.0510 3741.8 4475.0 9.5 Toluene 0.21 0.0021 92.14 0.20 0.0245 0.0000 5222.2 0.0 0.0000 106.17 0.00 0.0 XylenEthylbenzene s 0.0000 318.50 0.00 0.0000 0.0000 5208.8 6248.9 0.0 Octan es + 0.0000 114.23 0.00 0.0000 866.7 0.0 Meeanthanol 0.0000 32.04 0.00 461 24.43 0.2443 8 00 1.00 Reqen Dehy Still Vent Stream - Cooling Cycle 0.0045 189.0 4380 0.828 MMSCFD scf/hr hr/yr MMscf/yr APPENDIX D-2: 2% ECD Downtime, P136 TEG Dehydration Unit Emissions DCP Operating Company, LP - Roggen Natural Gas Processing Plant Source ID P136 Description Dehydration Unit Manufacturer Evco Fabrication Model T-901 Serial 6 2090 Operation Date 7/1/2011 Operation Wet Gas Temperature Wet Gas Pressure Wet Gas Water Content Dry Gas Flow Rate Dry Gas Water Content Lean Glycol Water Content Lean Glycol Flow Rate Cold Separator? Cold Separator Temperature Cold Separator Pressure Glycol Pump Make & Modal Glycol Pump Type Glycol Gas Injection Pump Ratio Flash Tank?' Flash Tank Temperature Rash Tank Pressure Flash Tank Control VRU Downtime 8760 hr/r 116 degF 82933 psig 97.96 EH2O/MMscf 85.0 l9Mscfd 4.0 IbH2O/MMscf 1.5 wt% H2O 24 gpm N Y/N N/A deg F N/A psig Electric Elec. or Gas n/a acfm/gpm Y Y/N 128.5 deg F 72.33 psig 100.00% Recycled to Inlet N/A Stripping Gas? _ What is Stripping Gas? _ Stripping Gas Row Rate _ Condenser? _ Condenser Temperature _ Condenser Pressure Combustor?° N YM N/A scam N Y/N deg F psis. Y Y/N Combustor Type Enclosed Combustor Combustor Ambient Air Temp Combustor Excess Oxygen Combustor Destruction Efficiency Combustor Downtime Hours of ECD Downtime Hours of ECD Uptime Pollutant NOx' CO' SO," Uncontrolled Emission Factor 0,068 Ib/MMBTU Controlled Emissions 0.37 Ib/MMBTU 1.88 ten SOr /ton His Combusted 2.6 ton/yr 14.3 ton/yr 0.0 ton/yr 60 deg F 0 % 95 % 2% Uncontrolled 175.2 hr/r 8584,8 hr/yr Emission Factors from AP -42, Chapter 135 Assume 100% of hl n converted m 20s VOC and HAP emissions from the flash vent stream controlled with the VRU end still vent stream controlled with the ECD. ° P-136 can either be controlled by the EC0, as seen here, or the RTC. DCP requests the EGO emission votumes (illustrated here) be considered for dila minor modification application. TEG Dehydration Unit Dehy Rash Gas Emissions Dehy Still Vent Emissions with 2% ECD Downtime Total Emissions Overall System Control' Dehy Rash Uncontrolled Emissions' Controlled Errisslons° Dehy Still Uncontrolled Emissions' ECD Uptime Emissions' ECD Downtime Emissions' Controlled Emissions' Uncontrolled Emissions' lb/hr ton/yr fron/yr lb/hr torVyr ton/yr ton/yr " ton/yr `=. ton/yr Hydrogen Sulfide 0.000 0000 0.000 0.000 0.000 0.000 0.000 0.00 : 0.00 95% N2 0.084 0368 0,000 1.411 6.180 0.303 0.124 0.43 6.55 CO2 0.051 0.225 0.000 0.074 0.324 0:016 0006 0.02 : : 0.55 Water 0.321 1.406 0000 326.741 1431.124 70.125 28.622 ---.98.75-' 1432,53 Methane 32.916 144.173 0.000 162.040 709.735 34.777 14.195 ':: 48.97 853.91 Ethane 30.260 132.538 0,001 67.083 293.824 14.397 5.876 Propane 29.105 127,482 . 0.000 - -55,006 240.927 11.805 4.819 I -Butane 5.026 22.013 0.000 10332 - 45.256 '- 2218 0.905' : ' 3.12 --':., 6727 • n -Butane - - 14.902 65.270 - . 0.000 - 30.702 - 134.473 - 6.586 . - 2689- ,.- 9.28 - 199.74 I -Pentane - 4.921 21.555 - . 0,000 - 13.138 -. 57.543 '- '2.820 -.1.151 n-Pentane 5.016 21.968 0.000 14.673 64.268 -. 3.149 1:285.: 'x'4.43 5624 Cyclopentane 0.281 ` - 1.231 0.000 -:-2.548 -922 11.159 -.--'77: . 0.547: 0.223 :-0.77 --7--T-73:007 12.39 rt Hex6n ,^t " Cyclohexane S -n'- "` 00 - 0.208 _ _;=9238:020O 0.912 - W 0.000 - 2.342 3459&FP 10.259 .. 0,503 0205' 0.71 ---'-11.17 -'3:1 D m; Heptane 0.545 2.389: 0.000 5.247 22.983 1.126 0.450 1-59:.'=, -25.37: Octane - - 0.088 0.387 ', 0,000 - - -1.150 5.038 0.247 0.101 Methanol 0.000 0.001' 0.000 : 0.050 0220 - 0.011'.• - 0.004 Benzene .. s. . .? =ONO= - '.637 Y. " 400 _ &':5.765 V x':38390, 1?881 't'�-`'"'07680A Waraerfati. - T32. , Ethyl - ,-'-'--u,u03 u0T2 -n .rut20 ia»'3,83a s?s 0'090L .-0,037, _AVW Toluen . = ,, - IVIV.701 '$8:526 73412+11t0 -1.^..1330.44M AM.71144147r«st a? 'e52fig mOCyJe`p-`„ -' - n;010' ;0488 'mso ttSO4M t 0.'37n,' t SMI.1.- ginatslffak tef3.0i000R0V , d040.d 2-s 012.110 0T1721a 0.1.759x, s. ""/0:035,1 "s VS,A111Z524Ft ° ?OQVg* OfiraMilli§e DEA 0000 0.000 2,000 0,000 0.000 :0.000 ` 0.000 . , , o,o0 0.00 DGA -0.000 • 0.000 0.000 0.000 0,000 0.000 0.000'. ''-000 0.00. TEG - 0.002 -- 0.010 -0-000 ' -0.001 - 0.006 0.000 -0.000 0.00 _.. 0,02 VOC 62.53 273,89 0,00 164.76 721.65 35.36 14.43 49.79 995.54 Total HAP 2.44 10.67 0.00 29,45 128,98 6.32 2.58 8.90 139.65 1. Uncontrolled SUIT Vent end Flash Tank emissions obtained ton ProMax report dated March 7,2012 2. ECD Control Emissions apply a 95% ORE molt Vent Uncontrolled emissions and are annualised based on annual hours of ECU uptime. 3.2% ECD Downtime Emissions are based on Still Vent Uncontrolled Emissions and are annualised based on annual hours of ECD downtime, 4. There is no flash tank downtime because emissions are piped to low-pressure Inlet 5. Total Controlled Emissions ere represented as the sum of ECD Uptime, ECD Downtime, and Flash Tank emissions. 6, Total uncontrolled emissions are represented as the sum of still vent and flash tank emissions. 7. Demonstrating an overall system control of 95%, calculated as 1100% Total Controlled Dehy VOC Emissions/Total Uncontrolled Dehy Emissions] APPENDIX D-3: 4% RTO Downtime, P136 TEG Dehydration Unit Emissions DCP Operating Company, LP Roggen Natural Gas Processing Plant Source ID P136 Description Dehydration Unit Manufacturer Even Fabrication Model T-901 Serial # 2090 Operation Date 7/1/2011 Operation 6760 hr/yr Wet Gas Temperature 116 degF Wet Gas Pressure 829.33 psig Wet Gas Water Content Dry Gas Row Rate _ Dry Gas Water Content Lean Glycol Water Content Lean Glycol Row Rate Cold Separator? _ Cold Separator Temperature Cold Separator Pressure Glycol Pump Make & Model _ Glycol Pump Type Glycol Gas Injection. Pump Ratio • Rash Tank?' Flash Tank Temperature Flash Tank Pressure RashTank Control VRU Downtime Pollutant NOxe co S02° 97.96 IbH2O/MMscf 85.0 MMscfd 4,0 IbH2O/MMsct 1.5 wt% H2O 24 gpm N YIN N/A deg F N/A psig Electric Elec. or Gas i/a acfm/gpm Y Y/N 128.5 deg F 72.33 nag 100% Recycled to Inlet N/A Uncontrolled Emission Factor 0.068 IbIMMBTU 0.37 IbIMMBTU 1.88 ton 802 /ton HaS Combtated Stripping Gas? _ What is Stripping Gas? Stripping Gas Flow Rate Condenser? Condenser Temperature Condenser Pressure Still Vent Control' RTO RTO Make Anguil RTO Model Model 150 RTO Minimum Temperature _ RTO Waste Gas Heat Content RTO Destruction Efficiency RTO Constant Pilot Light RTO Downtime N Y/N N/A sof m N Y/N Hours of RIO Downtime Hours of RTO Dpflme Controlled Emissions I 2.6 ton/yr 14.3 ton/yr 0.0 ton/yr deg F psia 1450 deg F 29 btu/scf 97 % N Y/N ' Emission Factors from AP -42, Chapter 13.5 e Assume 100% of HS converted to SO, e VOC and HAP emissions from the (lash vent stream controlled with the VRU end still vent stream controlled with the RTO. application. d P-136 can either be controled by the RIO. as seen here, or the ECD. DCP requests the ECD omission wlumes trot Ihrse) to be considered far this minor modification a tion. TOG Dehydration Unit Deily Flash Dehy Flash Uncontrolled Emissions' Gas tmisslons Controlled Emissions° lb/hr ton/yr tonlyr 0.000 0.368 0.000 D 050 Hydrogen Sulfide 0.000 N2 0.084 0.051 0.321 0.225 1.406 0003 0.000 0.000 CO2 Water Methane 32.916 144.173 0.000 Ethane 30.260 132.538 127.482 ' ' - 0.000 .- . 0.000 Propane - 29.105 I -Butane . 5.026 22.013 _ 0.000 " n -Butane - 14.902 4.921 -"65.270 ' 21.555 0.000 - nPentane n -Pentane 5.016 - � 21.968 0.000 0.281 1231 x'0.%63 T _0:000 0.000 Cyclopentane , i 20 -0.208 Cyclohexa e 0.912 " 2.389 0.000 0.000 Heptane Hoptane 0.545 Octane 0.088 0.387. '0.000 0.000 0.001 -' Methanol Bdr¢ '02244 1 :080 Eth/11b0n2en/ MillatIsiM*OI[ . °;e4. Melt=0014tOR Totue:. " - :; t'[iO7 I34.6 `. 90airia _..+ -.-._ - Oh5S 0.000_ :➢4.,:,a - 0000 ..',�+0,00A4",l 0,000 - • MDEA DEA .. - 0.000 0.000DGA - 0.000 0,000 :0.000 TEG - 0.002 0.010 010 VOG 6253 273.89 Total HAP 2.44 10.67 0.00 Dehy Still lb/hr 0.000 1.411 0.074 4% Uncontrolled 350.4 hr/yr 8409.6 hdyr Dehy Still Vent Emissions with 4% RTO Downtime RTO Downtime Emissions' Uncontrolled Emissions' ton/yr 0.000 6.180 0.324 326.741 162.040 67.083 55.006 10:332 30.702 13.138 14.673 2.548 6922:. 2.342 5.247 <1.150 0.050 1431.124 709.735 293.824 240.927 45.256 134.473 57.543 64.268 - 11.159 43:459 10.259 22.983 5.038 0.173 0.000 0.000 0.001 164.76 29.45 WittirtetOS IRIBADAM 38M4 ar40ro53 #0#47A4Mt. Z28 0.759 0,000 • ' 0.006 721:65 128.98 1. Uncontrolled Still Vent and Flash Tank emissions obtained from PmMex report dated Mach 7, 2012 2. RTO Control Emissions apply a 97% ORE to Still Vent Uncontrolled emissions end are annualized based on annual hours of RTO optima. 3, 4% RTO Downtime Emissions are based on Still Vent Uncontrolled Emissions and are annualized based an annual hours of RTO downtime. 4. There is no flash tank downtime because emissions are piped to low-pressure Inlet. 5. Total Controlled Emissions are represented as the sum of RTO Uptime, RTO Downtime, and Flash Tank emissions. 0. Total uncontrolled emissions are represented as the sum of still vent end flash tank emissions. • 7. Demonstrating an overall system control of 95%, calculated as [100% -Total Controlled Dehy VOC Emissions /Total Uncontrolled Dehy Emissions] RTO Uptime Emissions' ton/yr 0.000 0.178 0.009 41.216 20.440 8.462 6.939 .1.303 1.657 1.851 0.321 1`.252 0.662 0.145. 0.006 ,.7070. 0.022 0.000 0.000. . 20.78 3.71 ton/yr 0.000 0.247 0.013 57.245 28.389 11.753 • 9.637 ' 1.810 5.379 2.302 2.571 0.446 0.410 0.919 0.202 '- .`0 074 0.000 Mt6ffilft9inkSt x,0,309';. 0,030 0.000 0.000 - 0.000 28.87 5.16 Total Emissions Controlled Emissions ton/yr 0.00 Uncontrolled Emissions' ton/yr 0.00 6.55 0.55 Overall System Control' 48.83 20.22 16.58 1432.53 853.91 426.36 368.41 67.27 - 3.11 4.42 sr 199.74 79.10 86.24 12.39 33.107 11.17 25.37 5.43 0.22 2.99':: 0.71 0.35 0.02 264::`- WB 0.00 0.00 49.65 8.87 Cdr.-69� r77i ddigil 0.76 0.00 0.00 - 995.54 139.65 95% APPENDIX D-4: 4% RTO Downtime, P-137 Amine Unit Emissions DCP Operating Company, LP Roggen Natural Gas Processing Plant Source ID P137 Description Amine Treater Manufacturer Evco Fabrication Model T-9002 Serial dl 2082 Operation Date 7/1/2011 Operation 8760 hr/yr Reboiler Rating Absorber Column Stages: n/a mmbtu/hr 7 stages Amine Type: MDEA Sweet Gas Throughput 85 MMscf/day Requested Sweet Gas Throughput 31025 MMscf/yr Inlet Gas Pressure 847.33 psig Inlet Gas Temperature 86 deg F Rich Amine Feed Pressure 839.33 psis Rich Amine Feed Temperature 131 deg F Rich Amine Feed Flowrate 376 gal/min Lean Amine Stream Pressure 266 psis Lean Amine Stream Temperature 252 deg F Lean Amine Stream Flowrate .350 gal/min Lean Amine Stream Wt. % Amine 50 Lean Amine Stream Mole Loading H2S 1.23E-6 Lean Amine Stream Mole Loading CO2 0.0099 Flash Tank Control VRU Downtime 1 Recycled to Inlet N/A Sour Gas Input NGL Input Flash Tank Pressure Flash Tank Temperature Still Vent Control N Y/N N YIN 60 psia 133 deg F RTO RTO Make . Angull RTO Model Model 150 RTO Minimum Temperature RTO Waste Gas Heat Content RTO Destruction Efficiency RTO Constant Pilot Light RTO Downtime Hours of RTO Downtime Hours of RTO Uptime Pollutant Emission Factor Controlled Emissions NOxa 0.068 Ib/MMBTU 0.8 ton/yr CO' 0.37 lb/MMBTU 4.6 ton/yr SO,' 1.88 ton S%/ ton H0S Combusted 30.0 ton/yr 1450 deg F 29 btu/scf 97 % N Y/N 4% Uncontrolled 350.4 hr/yr 8409.6 hr/yr ° Emission Factors from AP -42, Chapter 13.5 for the RT0 for combustion of the amine still vent stream. Assume 100% of HA converted to 0O,_ Hz5 values from the 3/25/13 PR0MAX run. Includes both flash and stillvent streams. Controlled V0C and HAP emissions from bath the flash and still vent streams assuming 100% control of flash gas e4h you and still vent stream routed to the RT0 assuming 57% ORE, Amine Unit Amine Rash Gas Emissions Amine Still Vent Emissions 4% Downtime Total' '., -. -;:Controlled. -Emisstoris6.;'- 'ton/yr:',3','',i Total Uncontrolled Emissions' ton/yr Overall System Control7 Amine Flash Uncontrolled Emissions' Controlled Emissions° Amine Still Uncontrolled Emissions' RTO Uptime Emissions' RTO Downtime Emissions' lb/hr ton/yr ton/yr lb/hr ' ton/yr ton/yr ton/yr — __ Hydrogen Sulfide 0.001 0.004 0.000 0.317 1.368 0.040 0.056''. 0.10',., g 1.39 98% N2 0.287 1.256 0.000 0.006 0.025 0.001 0.001 ':rz x:0.00` .;§_.' 1.28 CO2 18.181 79.635 0.000 10263.308 44953290 1294.655 1798.132 :s' 3092.79- ,. 45032.92 Water 6.516 28.540 0.000 374.919 1642.145 47.294 65.686 ''-i:112.98 F'-:'- 1670.69 Methane 106.457 466.280 0.000 8.548 37.441 1.078 1.498 -=,:2.58' =.: 503.72 Ethane 55.944 245.034 0.000 1 8.899 38.977 1.123 1.559 - ' 2.68'x' .. 284.01 Propane 26.917 117.896 0.000 3.696 16.187 . 0.466 0.647 °'--1.11 ,'c'. 134.08 i-Butane 3.322 14.550 0.000 0.377 1.650 0.048 • 0.066 --- 0.11. 1620 n -Butane 11.159 48.877 0.000 : 1.890 8280 0.238 0.331 . 0.57 _, : 57.16 I -Pentane 1.728 7.570 0.000 ='0.173 0.757 0.022 0.030 n -Pentane 1.991 8.719 0.000 0.250 1.097 0.032 0.044 0.08- " 9.82 Cyclopentane - ` 0224 0.981 0.000 •0.098 `9 0.431 'r-P-0:crto'M 0.012 ' 0.017 ? 0.03 `;.f ` 1.41 n Hepane' a..._ Cyclohexane 0.66G 0.205 .-_.,.= .9J_._1 0.896 'oU3500 _.. 0.000 I 9 - 0.133 7M.L.I1031 0.585 0017 0144 0.023 ' 0-OL ': 0.04 1 sc "1.48 Heptane .. 0.143 - 0.628 0.000 0.031 0.136 0.004 0.005 Octane 0.014 - - 0.063 0.000 0.001 0.005 0.000 0.000 Methanol -' 0.002 0.007 - - 0.000 : - 1.098 4.809 .-0.138 -. 0.192 Benz r'a. __ _ . _.. _ . .S3.. . - ., r._. 5466 _,. -�- .-.:,0 0.2).04,-,#,, 5'483, ; "2Si92J' 5 :C. 1..0 S89 _-,- ffi..._-.: 7 55z' 539;x: . eigen , -: isrie2Wf , 0< "lY.?;:~'t5 eee ..,._.7,. -:° :;` IY. lLuit,u• w tuttI2t. SI.S 4 litildesa '1i,g' Onte 11SiD' � 'r �55829t a o45C .1,.. -i, - 309 ?' fir-'. t yro... '~w� .: 0',0.. .... 0l0 tt. 444AMORXICROM aniKMx:'80-IE IMMICSIM .. _ :_ :2ftstaian `.t1 •. MDEA 0.006 0.025 0.000 0.000 - 0.000 - 0.000 0.000 ^". �b =0 00 .:�' •-0.02: ` DEA - - 0.000 0.000 0.000 • 0.000 0.000 0.000 0.000 " -0.00• •' 0.00 DGA - 0.000 0.000 0.000 - . 0.000 0.000 0.000 0.000 -a 0.00 �: _.. 0.00 TEG 0.000 0.000 0.000 0.000 0.000 0.000. 0.000 VOC 46.92 205.50 0.00 17.68 77.46 2.23 3.10 ':'- -5.33 ..!, 282.96 Total HAP 1.21 5.30 0.00 11.03 48.33 1.39 1.93 ---3.32 , 53.62 1. Uncontrolled Still Vent and Rash Tank emissions obtained from ProMax report dated March 26, 20 -3 2.. RTO Control Emissions apply a 97% DRE to Still Vent Uncontrolled emissions and are annualized based on annual hours of RTO uptime. 3.4 % RTO Downtime Emissions are based on Still Vent Uncontrolled Emissions and are annualized based on annual hours of RTO downtime. 4. There is no flash tank downtine because emissions are piped to low-pressure inlet. 5. Total Controlled Emissions era represented as the sum of RTO Uptime, RTO Downtime, and Flash Tank emissions, 6. Total uncontrolled emissions are represented as the sum of still vent and flash tank emissions. 7. Demonstrating an overall system control of 98%, calculated as 1100% -Total Controlled Amine VOC Emissions /Total Uncontrolled Amine Emissions] APPENDIX D-5: Insignificant Activities List DCP Operating Company, LP Roggen Natural Gas Processing Plant Description 2.5 MMBtu/hr, Broach Regen Heater 0.115 MMBtu/hr, Office Heater 1 0.115 MMBtu/hr, Office Heater 1 0.038 MMBtu/hr, Hot Water Heater 0.02 MMBtu/hr, Shop Heater Tank Combustor Dehy Combustor C-154 Maintenance Blowdown Vent C-155 Maintenance Blowdown Vent C-156 Maintenance Blowdown Vent C-157 Maintenance Blowdown Vent C-158 Maintenance Blowdown Vent C-159 Maintenance Blowdown Vent C-160 Maintenance Blowdown Vent C-161 Maintenance Blowdown Vent C-180 Maintenance Blowdown Vent C-223 Maintenance Blowdown Vent C-225 Maintenance Blowdown Vent C-227 Maintenance Blowdown Vent 500 gal, Kerosene tank 500 gal, Scavenger tank, AST- 27 500 gal, Diesel tank 500 gal, Dyed Diesel tank 300 gal, Unleaded Gasoline Tank 30,000 gal Pressurized NGL Storage Tank 30,000 gal Pressurized NGL Storage Tank 30,000 gal Pressurized NGL Storage Tank 30,000 gal Pressurized NGL Storage Tank 80 bbl, Produced Water Tank, Sump 1 80 bbl, Produced Water Tank, Sump 2 80 bbl, Produced Water Tank, Sump 14 80 bbl, Produced Water Tank, Sump 6 200 bbl, Produced Water Tank, Tank 7209 80 bbl, Produced Water Tank, Tank 7213 200 bbl, Produced Water Tank, Tank 7214 80 bbl, Wastewater Tank, Sump 8 80 bbl, Stormwater Tank, Sump 5 240 bbl, Lube Oil tank, 805 Central 6,000 gal, Lube Oil tank, 805 West 500 gal, Lube Oil tank, AST -24 500 gal, portable Used Oil Tank 225 gal, Used Oil Tank, #1 225 gal, Used Oil Tank, #2 225 gal, Used Oil Tank, #3 110 bbl, Used Oil tank, AST -13 80 bbl, Slop Oil Tank, Sump 5 10 bbl, Slop Oil Tank, Sump 7 80 bbl, Slop Oil Tank, Sump 9 210 bbl, Slop Oil Tank, Sump 12 10 bbl, Slop Oil Tank, Sump 10 30 bbl, Slop Oil Tank Sump 4 220 gal, Slop Oil tank, Air Compressor Sump 1,000 gal, Norkool tank, AST 7 1000 gal, Norkool tank, AST 8 1000 gal, Norkool tank, AST 19 100 gal, Portable Methanol Tank 500 gal, Methanol tank, Randel Insignificant Per Regulation No. 3, Part C, Section II.E.3.k Regulation No. 3, Part C, Section II.E.3.ggg Regulation No. 3, Part C, Section II.E.3.ggg Regulation No. 3, Part C, Section II.E.3.k Regulation No. 3, Part C, Section II.E.3.ggg Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.aaa Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.aaa Regulation No. 3, Part C, Section II.E.3.zz Regulation No. 3, Part C, Section II.E.3.zz Regulation No. 3, Part C, Section II.E.3.zz Regulation No. 3, Part C, Section II.E.3.zz Regulation No. 3, Part C, Section II.E.3.uu Regulation No. 3, Part C, Section II.E.3.uu Regulation No. 3, Part C, Section II.E.3.uu Regulation No. 3, Part C, Section II.E.3.uu Regulation No. 3, Part C, Section II.E.3.uu Regulation No. 3, Part C, Section II.E.3.uu Regulation No. 3, Part C, Section II.E.3.uu Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.aaa Regulation No. 3, Part C, Section II.E.3.aaa Regulation No. 3, Part C, Section II.E.3.aaa Regulation No. 3, Part C, Section II.E.3.aaa Regulation No. 3, Part C, Section II.E.3.aaa Regulation No. 3, Part C, Section II.E.3.aaa Regulation No. 3, Part C, Section II.E.3.aaa Regulation No. 3, Part C, Section II.E.3.aaa Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a NOz (tpy) 1.07 0.05 0.05 0.02 0.01 0.05 0.05 CO (tpy) 0.90 0.04 0.04 0.01 0.01 0.05 0.05 VOC (tpyl 0.06 0.00 0.00 0.00 0.00 0.05 0.05 0.07 0.06 0.06 0.09 0.18 0.11 0.01 0.11 0.26 0.01 0.01 0.01 0.00 neg. 0.00 0.00 neg. neg. neg. neg. neg. 0.37 0.37 0.37 0.37 0.37 0.37 0.37 neg. neg. neg. neg. neg. neg. neg. neg. neg. neg. neg. neg. neg. neg. neg. neg. neg. neg. neg. neg. 0.00 0.01 500 gal, Methanol tank, Petro Frac 500 gal, Methanol tank, 212 500 gal, Methanol tank, CIG 1,000 gal, Methanol tank, AST 20 1,000 gal, Methanol tank, AST 9 4,000 gal, TEG Tank, Tank 7210 500 gal, TEG tank, Ast 28 80,000 gal Pressurized Butane Storage Tank 80,000 gal Pressurized Butane Storage Tank 30,000 gal Pressurized Propane Storage Tank 18,000 gal Pressurized Methanol Storage Tank Kohlar Commercial Pro 15 Methonal Trailer Pump Briggs & Stratton Vangaurde 16HP Hotsy Pump Hotsy Heater, 385,800 BTU/hr. Catco 12,000 BTU/Hr CIG Meter Shed Heater Catco 12,000 BTU/Hr Excel Meter Shed Heater CataDyne 12,000 BTU/Hr Box Elder Meter Shed Heater CataDyne 6,000 BTU/Hr Bypass Gas Meter Shed Heater CataDyne 6,000 BTU/Hr North Inlet Meter Shed Heater CataDyne 6,000 BTU/Hr South Inlet Meter Shed Heater CataDyne 6,000 BTU/Hr Low Pressure Inlet Meter Shed Heater Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.zz Regulation No. 3, Part C, Section II.E.3.zz Regulation No. 3, Part C, Section II.E.3.zz Regulation No. 3, Part C, Section II.E.3.a Regulation No. 3, Part C, Section II.E.3.nnn(iii) Regulation No. 3, Part C, Section II.E.3.nnn(iii) Regulation No. 3, Part C, Section II.E.3.ggg Regulation No. 3, Part C, Section II.E.3.ggg Regulation No. 3, Part C, Section II.E.3.ggg Regulation No. 3, Part C, Section II.E.3.ggg Regulation No. 3, Part C, Section II.E.3.ggg Regulation No. 3, Part C, Section II.E.3.ggg Regulation No. 3, Part C, Section II.E.3.ggg Regulation No. 3, Part C, Section II.E.3.ggg Totals 0.01 0.01 0.01 0.02 - 0.02 neg. - neg. neg. - neg. neg. - neg. - neg. -- - neg. 0.17 0.14 0.01 0.01 0.00 0.00 0.01 0.00 0.00 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.49 1.28 3.84 APPENDIX E: TITLE V RED -LINE P033 Regen TEG Dehy, AIRS ID: 123/0049/130 P136 Inlet TEG Dehy, AIRS ID: 123/0049/136 P137 Amine Unit, AIRS ID: 123/0049/137 VOC VOC P033 - Triethylene Glycol Dehydration Unit Permit Condition Number 1.05 11.0 tons per year Emission Factor Monitoring Method Interval 4.1 ProMax or GLYCaIc 4.0 or higher Parametric 12 month rolling Monthly Gas Processed 4.3 1,460 912.5 MMscf per year Gas Processed During ECD Downtime 4.3 29.2 MMscf per year P136 - Triethylene Glycol Dehydration Unit Permit Condition Number ProMax or GLYCaic 4.0 or higher Limitations Emission Factor Monitoring Method Interval 4.1 49.79 24,6 tons per year Parametric 12 month rolling Monthly Gas Processed 4.3 31,025 MMscf per year Gas Processed During ECD Downtime 4.3 620.5 MMscf per year Gas Processed During RTO Downtime 4.3 1,241 MMscf per year 4.6 Days and hours of operation shall be monitored and recorded monthly in a log that is to be made available to the Division upon request. Hours of ECD or RTO downtime shall be monitored and recorded monthly in a log. Days of operation shall be used to calculate an average daily gas throughput as specified in Condition 4.3. Hours of operation for the month shall be used in the GLYCalc runs required by Condition 4.1. Control efficiency shall only be claimed for the hours of operation with ECD or RTO. 4.11 ECD (State Only) The enclosed combustor shall be operated at all times when emissions are routed to it, except for a maximum annual downtime period of 175.2 hours (2% annual downtime) for malfunctions and maintenance. The enclosed combustor shall be operated with a pilot flame present at all times, except for these periods of downtime. The presence of an enclosed combustor pilot flame shall be monitored using a thermocouple or any other equivalent device to detect the presence of a flame. Records of the times and duration of all periods of pilot flame outages and estimated emissions shall be maintained and made available to the Division upon request. P137 - Amine Unit Parameter Permit Condition Number Limitations Emission Factors Monitoring Method Interval VOC 5.1 5.4223 tons per year ProMax Recordkeeping & Calculation 12 month rolling total Monthly Gas Processed 5.3 31,025 MMscf per year Gas Processed During RTO Downtime 5.3 1,241 MMscf per year 5.4.5 Records of the time and duration of all RTO downtime experienced shall be kept and available for Division review upon request. Control efficiency shall only be claimed for the hours when RTO is operating. 5.7.1 The thermal oxidizer shall be operated at all times when emissions are routed to it, except for a maximum annual downtime of 350.4 hours (4% annual downtime) for malfunctions and maintenance. APPENDIX F: TITLE V RED -LINE FOR REQUESTED ENGINE EMISSION LIMITATION UPDATES P001/C154 Waukesha L7042GSI, 1100 hp, AIRS ID: 123/0049/101 P003/C159 Waukesha L7042GSI, 1350 hp, AIRS ID: 123/0049/103 P008/C161 Waukesha L7042GSI, 1350 hp, AIRS ID: 123/0049/108 P014/C156 Waukesha L7042G, 806 hp, AIRS ID: 123/0049/114 P017/C225 Superior 8G825, 800 hp, AIRS ID: 123/0049/117 P019/C227 Superior 8G825, 720 hp, AIRS ID: 123/0049/119 C181 Waukesha L7042GSI, 1478 hp, AIRS ID: 123/0049/134 P001/C154 — Waukesha 1,100 HP Internal Combustion Engine Parameter Permit Condition Limitations Short Term Long Term Compliance Emission Factor Monitoring Method Interval NOx 1.1 N/A 21.2 22.3 TPY 0.573 0.601 lb/MMBtu Recordkeeping and Calculation Monthly CO N/A 21.2 223 TPY 0.573 0.601 lb/MMBtu VOC 1.2 N/A 10.6 TPY 0.285 lb/MMBtu Recordkeeping and Calculation Monthly P003/C159 — Waukesha 1,350 HP Internal Combustion Engine Parameter Permit Condition Limitations (per engine) Short Term Long Term Compliance Emission Factor Monitoring Method Interval NOx 1.1 N/A 26.1274 TPY 0.537 0.564 lb/MMBtu Recordkeeping and Calculation Monthly CO N/A 27.38 TPY 0.564 lb/MMBtu VOC 1.2 N/A 13.04 TPY 0.268 lb/MMBtu Recordkeeping and Calculation Monthly P008/C161 — Waukesha 1,350 HP Internal Combustion Engine Parameter Permit Condition Limitations (per engine) Short Term Long Term Compliance Emission Factor Monitoring Method Interval NOx 1.1 N/A 13.0 274 TPY 0.268 0.564 lb/MMBtu Recordkeeping and Calculation Monthly CO N/A 26.127:4 TPY 0.537 0.564 lb/MMBtu VOC 1.2 N/A 9.11 0 TPY 0.188 0.268 lb/MMBtu Recordkeeping and Calculation Monthly P014/C156 — Waukesha 806 HP Internal Combustion Engine Parameter Permit Condition Limitations (per engine) Short Term Long Term Compliance Emission Factor Monitoring Method Interval NOx 1.1 N/A 7.816.3 TPY 0.247 0.518 lb/MMBtu Recordkeeping and Calculation Monthly CO N/A 15.6 463 TPY 0.494 0.518 lb/MMBtu VOC 1.2 N/A 5.5 8 TPY 0.173 0.247 Recordkeeping and Calculation Monthly lb/MMBtu P017/C225 - Superior 800 HP Internal Combustion Engine Parameter Permit Condition Limitations (per engine) Short Term Long Term Compliance Emission Factor Monitoring Method Interval NOx 1.1 N/A 7.7 444 TPY 0.276 0.538 lb/MMBtu Recordkeeping and Calculation Monthly CO N/A 15.5 444 TPY 0.551 0.538 lb/MMBtu VOC 1.2 N/A 5.4 70 TPY 0.193 0.258 lb/MMBtu Recordkeeping and Calculation Monthly P019/C227 - Superior 720 HP Internal Combustion Engine Parameter Permit Condition Limitations (per engine) Short Term Long Term Compliance Emission Factor Monitoring Method Interval NOx 1.1 N/A 13.9 4.44 TPY 0.512 0.538 lb/MMBtu Recordkeeping and Calculation Monthly CO N/A 14.6 TPY 0.538 lb/MMBtu VOC 1.2 N/A 7.0 TPY 0.258 lb/MMBtu Recordkeeping and Calculation Monthly Note: C-181 is NOT yet incorporated into the OP, however, the construction permit 07WE0988, which governs this emission point, will be incorporated into the operating permit at the time of renewal. Changes to the permit limits and emission factors listed in 07WE0988 are requested to be reflected in the operating permit as follows: C-181 - Waukesha 1,478 HP Internal Combustion Engine Parameter Permit Condition Limitations Short Term Long Term Compliance Emission Factor Monitoring Method Interval NOx 2.1 N/A 14.3 28.5 TPY 0.283 0.565 lb/MMBtu Recordkeeping and Calculation Monthly CO N/A 28.54 TPY 0.565 lb/MMBtu VOC 2.2 N/A 10.0 #3 TPY 0.198 0.283 lb/MMBtu Recordkeeping and Calculation Monthly APPENDIX G: UPDATED FACILITY WIDE EMISSIONS INVENTORY FORM 102 Form APCD-102 ICi fit ; _ i zs : - : a ..coxigan7 Name: DCP Operating Company. LP —Sourc'e Name: Roggen Gas Plant Source AIRS ID: 123/0049 Colorado Department of Public Health and Environment Air Pollution Control Division Facility Wide Emissions Inventory Form Ver. April, 2015 Uncontrolled Potential to Emit (PTE) • Controlled Potential to Emit (PTE) Criteria (TPY) I HAPs (lbs/yr) Criteria (TPY) I HAPs (Ibs/yr) AIRS ID Equipment Description TSP PM10 PM2.5 SO2 NOx VOC CO I HCHO Acetal Acro BZ Tol EB Xyl n -Hex Meth 224-TMP TSP PN110 PNI2.5 SO2 NOx VOC CO I HCHO Acetal Acro BZ Tol EB _ Xyl n -Hex Meth 224-TMP 123/0049/101 Engine C-154/P001/S001 0.72 0.72 0.72 0.02 116.84 15.93 84.98 I 1,521 207 195 117 41 2 14 0 227 0 0.72 0.72 0.72 0.02 21.24 10.62 21.24 I 365 104 98 59 21 1 7 0 114 0 123/0049/102 Engine C -155/9002/S002 0.61 0.61 0.61 0.02 85.61 11.67 62.26 I 1,293 176 166 100 35 2 12 0 193 0 0.61 0.61 0.61 0.02 16.34 7.78 16.34 I 310 88 83 50 18 1 6 0 97 0 123/0049/103 Engine C -159/9003/S003 0.94 0.94 0.94 0.03 169.47 26.07 117.32 I 1.992 271 256 153 54 2 19 0 297 0 0.94 0.94 0.94 0.03 26.07 13.04 27.38 I 478 136 128 77 27 1 9 0 149 0 123/0049/107 Engine C-157/P007/S007 0.61 0.61 0.61 0.02 85.61 11.67 62.26 1 1.293 176 166 100 35 2 12 0 193 0 0.61 0.61 0.61 0.02 16.34 7.78 16.34 I 310 88 83 50 18 1 6 0 97 0 123/0049/108 Engine C-161/P008/S008 0.94 0.94 0.94 0.03 143.40 19.55 104.29 I 1,992 271 256 153 54 2 19 0 • 297 0 0.94 0.94 0.94 0.03 13.04 9.13 26.07 I 478 136 128 77 27 1 9 0 149 0 123/0049/110 Engine C158/P010/S010 0.66 0.66 0.66 0.02 97.30 13.27 70.76 I 1.401 191 180 108 38 2 13 0 209 0 0.66 0.66 0.66 0.02 18.57 8.85 18.57 I 336 95 90 54 19 1 7 - 0 105 0 123/0049/113 - Engine C-160/P013/S013 0.61 0.61 0.61 0.02 85.61 11.67 62.26 I 1.293 176 166 100 35 2 12 0 193 0 0.61 0.61 0.61 0.02 16.34 7.78 16.34 I 310 88 83 50 18 1 6 0 97 0 123/0049/114 Engine C-156/P014/S014 0.61 0.61 0.61 0.02 85.61 11.67 62.26 I 1.293 176 166 100 35 2 12 0 193 0 0.61 0.61 0.61 0.02 7.78 5.45 15.57 I 310 88 83 50 18 1 6 0 - 97 0 123/0049/115 Engine C-223/P055/S015 0.53 0.53 0.53 0.02 61.64 9.72 101.02 1,113 152 143 86 30 1 14 0 227 0 0,53 0.53 0.72 0.02 14.60 6.95 14.60 267 76 98 59 15 1 5 0 83 0 123/0049/117 Engine C-225/P017/S017 0.54 0.54 0.54 0.02 63.63 10.04 I 104.28 1,149 156 147 89 31 1 11 0 172 0 0.54 0.54 0.54 0.02 7.73 5.41 I 15.45 276 78 74 44 16 1 5 0 86 0 123/0049/119 Engine C-227/P019/S019 0.53 0.53 0.53 0.02 104.29 9.73 100.81 I 1,113 152 143 86 30 1 11 0 166 0 0.53 0.53 0.53 0.02 13.91 6.95 14.60 I 267 76 71 43 15 1 5 0 83 0 123/0049/122 P025/FUGITIVES 0.00 0.00 0.00 0.00 0.00 114.07 0.00 I 0 0 0 913 215 82 154 1,788 0 0 0.00 0.00 0.00 0.00 0.00 33.54 0.00 I 0 0 0 268 63 24 45 524 0 0 123/0049/125 P039, Stablized Condensate Tanks 0.00 0.00 0.00 0.00 0.00 28.84 0.00 I 0 0 0 771 2,571 200 1,857 5.600 0 0 0.00 0.00 0.00 0.00 0.00 1.44 0.00 I 0 0 0 39 129 10 93 280 0 0 123/0049/126 F029, Condensate Truck Loadout 0.00 0.00 0.00 0.00 0.00 30.84 0.00 I 0 - 0 0 0 0 0 0 0 0 0 0.00 0.00 0.00 0.00 0.00 30.84 0.00 I 0 0 0 0 0 0 0 0 0 0 123/0049/129 H037, Hot Oil Heater 0.26 0.26 0.26 0.02 3.45 0.19 2.90 I 5 0 0 0 0 0 0 124 0 0 0.26 0.26 0.26 0.02 3.45 0.19 2.90 I 5 0 0 0 0 0 0 124 0 0 123/0049/130 P-033, Regen Dehy 0.00 0.00 0.00 0.00 0.00 98.21 0.00 I 0 0 0 6,757 7,521 277 2,493 2.301 0 0 0.00 0.00 0.00 0.00 0.00 1.05 0.00 I 0 0 0 228 256 9 86 44 0 0 123/0049/133 F031, Pressurized Liquids Loadout 0.00 0.00 0.00 0.00 0.00 5.00 0.00 I 0 0 0 0 0 0 0 0 0 0 0.00 0.00 0.00 0.00 0.00 5.00 0.00 I 0 0 0 0 0 0 0 0 0 0 123/0049/134 Engine C-181 0.98 0.98 0.98 0.03 156.99 21.41 114.18 I 2,070 282 266 160 56 3 20 0 309 0 0.98 0.98 0.98 0.03 14.27 9.99 28.54 I 497 141 133 80 28 1 10 0 155 0 123/0049/136 P-136, Inlet TEG Dehy 0.00 0.00 0.00 0.00 0.00 995.54 0.00 I 0 0 0 78,042 75,377 3,699 15,547 106.192 0 0 0.00 0.00 0.00 0.00 2.60 49.79 14.30 I 0 0 0 5,298 5,153 254 1,066 5,997 0 0 123/0049/137 P-137, Amine Unit 0.00 0.00 0.00 0.00 0.00 282.96 0.00 I 0 0 0 50,789 33,225 1,074 400 6,509 0 0 0.00 0.00 0.00 30.04 0.85 5.33 4.60 i 0 0 0 3,292 2,178 70 400 47 0 0 123/0049/138 Hot Oil Heater 1.07 1.07 1.07 0.08 7.02 0.65 11.79 I 0 0 0 0 0 0 0 505 0 0 1.07 1.07 1.07 0.08 7.02 0.65 11.79 1 0 0 0 0 0 0 0 505 0 0 123/0049/140 Engine C-192 0.98 0.98 0.98 0.03 156.99 21.41 114.18 I 2.076 282 266 160 56 3 20 0 310 0 0.98 0.98 0.98 0.03 14.27 9.99 28.54 I 1.038 141 133 80 28 1 10 0 155 0 APEN Only - Permit Permitted Sources Subtotal = Exempt Sources 10.60 10.60 10.60 039 1423.47 I750.12 1175.56 I 19,604 2,667 2,514 138,783 119,444 5,356 20,641 123,020 2,986 0 10.60 10.60 10.80 30.43 214.43 237.56 293.20 I 5,249 ' 1,334 1,283 9,896 8,046 379 1,783 7,522 1,463 0 I I I I I I I I I I I I APEN Exempt / Insignificant APEN Only Subtotal = sources 0.0 0.0 . 0.0 0.0 0.0 0.0 0.0 I 0 0 0 0 0 0 0 0 0 0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 I 0 0 0 0 0 0 0 0 0 0 APEN Exempt / Insignificant sources 1.5 1.3 3.8 I 139 157 176 1.5 1.3 3.8 i 139 157 176 I I I I I I I I I I Insignificant Subtotal = Total, All Sources = 0.0 0.0 0.0 0.0 1.5 1.3 3.8 I 0 0 0 139 0 0 0 157 176 0 0.0 0.0 0.0 0.0 1.5 1.3 3.8 I 0 0 0 139 0 0 0 157 176 0 I 10.6 10.6 10.6 0.4 1425.0 1751.4 1179.4 I 19,604 2,667 2,514 138,921 119,444 5,356 20,641 123,177 3,162 0 I 10.6 10.6 10.8 30.4 215.9 238.8 297.0 I 5,249 1,334 1,283 10,034 8,046 379 1,783 7,679 1,638 0 Uncontrolled Uncontrolled HAPs Total, Summary All HAPs Controlled Controlled HAPs Total, Summary All HAPs (TPY) = 9.8 13 13 695 59.7 2.7 103 61.6 1.6 0.0 (TPY) =I 2.6 I 0.7 I 0.6 I 5.0 I 4.0 I 0.2 I 0.9 I 3.8 I 0.8 I - 0.0 I I (TPY) =I 217.7 (TPY) =I 18.7 Footnotes: 1. This form should be completed to include both existing sources and all proposed new or modifications to existing emissions sources 2. If the emissions source is new then enter "proposed" under the Permit No. and AIRS ID data columns 3. HAP abbreviations include: BZ = Benzene 224-TMP = 2,2,4-Trimethylpentane Tol = Toluene Acetal = Acetaldehyde EB = Ethylbenzene Acro = Acrolein Xyl = Xylene n -Hex = n -Hexane HCHO = Formaldehyde Meth = Methanol 4. APEN Exempt/Insignificant Sources should be included when warranted. Company Name 7/7/2017 Page 1 of 1 d p Midstream. July 28, 2017 Attn: Elie Schuchardt Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South APCD-SS-B 1 Denver, CO 80246-1530 RE: Roggen Natural Gas Processing Plant Title V Modification Application: 95OPWE055 Amine Unit (P-137) AIRS ID: 123/0049/137 Dear Ms. Schuchardt: DCP Operating Company, LP 370 17th Street, Suite 2500 Denver, CO 80202 (303) 605-2039 UPS: 1Z F46 915 02 9855 8437 On July 7, 2017 DCP Operating Company, LP ("DCP") submitted an operating permit modification application for the Roggen Natural Gas Processing Plant ("Facility"), located at Section 24, Range 63W, Township 2N in Weld County, Colorado. DCP is requesting to amend its request for the following source: • P137 — AIRS Point 137 — Permit 2% RTO downtime instead of 4% o Permit 2% annual downtime for RTO maintenance and malfunctions o Permit limits and proposed language are included in Appendix B. • Please reflect total HAPS in this application on the Title V Permit Project Emission Increases Existing Permit Limits Emission Increases AIRS ID Equipment Description NOx (tpy) VOC (tpy) CO (tpy) PM (tpy) NOx (tpy) VOC (tpy) CO (tpy) PM (tpy) 123/0049/130 P-033, Regen Dehya - 0.60 - - - 0.45 - - 123/0049/136 P-136, Inlet TEG Dehyb 2.60 21.60 14.30 - -0.03 28.19 -0.29 - 123/0049/137 P-137, Amine Unitb 0.85 2.30 4.60 - 0.00 1.52 0.00 - Total Roggen Net Project Increases New Source Review Thresholds Trigger New Source Review? -0.03 30.17 -0.29 0.00 40 40 100 10 NO NQ a nNO NO Highest Individual HAP Total HAP 6.89 tpy tpy 23.98 a VOC limit is from construction permit 01WE0208 Issued March 18, 2015. b Existing limits are from construction permit 10W E1659 Issuance 5 Issued March 18, 2015. Attachments Attached please find forms and documents needed to make the requested changes to the Title V modification application for operating permit 95OPWE055. • Appendix A: Updated APEN for amine unit (P137) • Appendix B: Emission Calculations for amine unit (P137) • Appendix C: Title V Red -Line for amine unit (P137) • Appendix D: Updated Facility Wide Emissions Inventory Form 102 If you have any questions or comments, please contact me at (303) 605-2039, or by email at rshankaran@dcpmidstream.com. Sincerely, DCP Operating Company, LP Roshini Shankaran Environmental Engineer Enclosure /rmm Amine Sweetening Unit - Form APCD-206 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result n — longer application processing times. You my be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Amine Sweetening Units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Rov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. 312 ot600vu 055 Permit Number: 10WE1659 AIRS ID Number: 123 / 0049 / 137 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: P-137 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Roggen Natural Gas Processing Plant Site Location: Section 24, R63W, T2N Mailing Address: (Include Zip Code) 370 17th Street Suite 2500 Denver, CO 80202 E -Mail Address2: rshankaran@dcpmidstream.com Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Roshini Shankaran Phone'Number: 303-605-2039 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 386853 1 I ieCOLORADO r!=b Env4oNnem Permit Number: 10WE1659 AIRS ID Number: 123 /0049/ 137 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action El NEW permit OR newly -reported emission source -OR - ✓❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership3 ✓❑ Other (describe below) -OR - ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - O Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) 2 5 pet' saxt¢, coazbpO thw te, ire t d 01011 Additional Info Et Notes: incorporate°/o RTO downtime 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Amine unit for acid gas removal Facility equipment Identification: For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: P-137 7 /1 /2011 / / ✓❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area Does this facility have a design capacity less than 2 long tons/day of H2S in the acid gas? Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 days/week Yes Yes weeks/year No No COLORADO 2 i Oep,� m.neotvutue �' NUNItb FavNnnment Permit Number: 10WE1659 AIRS ID Number: 123 /0049/ 137 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: Evco Fabrication Model : T-9002 Serial Number: 2082 Reboiler Rating: n/a Amine Type: Pump Make and Model: 0 MEA MMBtu/hr Absorber Column Stages: 7 ❑ DEA 0 TEA stages ❑� MDEA ❑ DGA # of pumps: 1 Sweet Gas Throughput4: Design Capacity: 85 MMSCF/day Requested: 31,025 MMSCF/year Actual: 0.0 MMSCF/year 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Inlet Gas: Pressure: 847.33 psig Temperature: 86 °F Rich Amine Feed: Pressure: 839.33 psia Flowrate: 376 • Gal/min Temperature: 131 °F Lean Amine Stream: Pressure: 266 psia Temperature: Flowrate: 350 Gal/min Wt. % amine: Mole Loading CO2 Mole loading H2S 1.23E-6 252 50 0.0099 °F Sour Gas Input: Pressure: Flowrate: psia MMSCF/Day Temperature: °F NGL Input: Pressure: Flowrate: psia Gal/min Temperature: °F Flash Tank: 0 No Flash Tank Pressure: 60 psia Temperature: 133 ,°F Additional Required Information: ❑ Attach a Process Flow Diagram ❑ Attach the simulation model inputs Et emission report ❑ Attach composition reports for the rich amine feed, sour gas feed, NGL feed, Et outlet stream (emissions) ❑ Attach the extended gas analysis (including BTEX Et n -Hexane, H2S, CO2, temperature, and pressure) Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 COLORADO R°aBl.bFnNr°nm? Permit Number: 10WE1659 AIRS ID Number: 123 /0049/ 137 [Leave blank unless APCD has already assigned a permit # and AIRS ID) Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.1174 / -104.3883 Operator Stack ID No. Discharge Height • Above Ground Level (Feet) Temp r F) flow Rate (ACFM) Veloaty (ft/sec) P-137 Indicate the direction of the stack outlet: (check one) 0 Upward O Horizontal ❑ Downward O Other (describe): O Upward with obstructing raincap Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 //Jy,�� COLORADO 4 I "t•VIiiye;,nronwm Permit Number: 10WE1659 AIRS ID Number: 123 /0049/ 137 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information O VRU: Used for control of: Size: Make/Model: Requested Control Efficiency % VRU Downtime or Bypassed O Combustion Device: Used for control of: still vent stream* Rating: MMBtu/hr Type: RTO Make/Model: Anguil / Model 150 Requested Control Efficiency: 97 % SN: AE 597225 Manufacturer Guaranteed Control Efficiency 99 % Minimum Temperature: 1,450 Waste Gas Heat Content 29 Btu/scf Constant Pilot Light: O Yes 0 No Pilot burner Rating MMBtu/hr O Other: Used for control of: flash tank stream closed loop system Description: Control Efficiency 100 Requested ° * RTO used for still vent control has 2% (175.2 hours) of annual downtime for maintenance and repairs. Still vent emissions will be vented to atmosphere during RTO downtime. Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 5 'COLORADO tiwHA6E VIMMIml Permit Number: 10WE1659 AIRS ID Number: 123 /0049/ 137 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 -Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ® Yes ❑ No ribe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM SO, H2S NO, VOC RTO 97% Co HAPs RTO 97% Other: From what year is the following reported actual annual emissions data? 2016 Use the following table to report the criteria pollutant emissions from source: Criteria Pollutant Emissions Inventory Pollutant Uncontrolled . Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled ` (Tons/year) Controlled5 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM SO, 1.88 ton SO2/ton H2s ProMax 0 0 30.0 30.0 H2S 0.09 lb/MMscf ProMax 0 0 1.39 0.07 NO, 0.068 lb/MMbtu AP -42 0 0 0.8 0.8 VOC 18.24 lb/MMscf ProMax 0 0 282.96 3.83 CO 0.37 Ib/MMbtu AP -42 0 0 4.6 4.6 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. AAnnual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 AVCOLORADO Ku[NbEavtronmt, APPENDIX D-4: 2% RTO Downtime, P-137 Amine Unit Emissions DCP Operating Company, LP Roggen Natural Gas Processing Plant Source ID P137 Description Manufacturer Amine Treater Evco Fabrication Model T-9002 Serial# 2082 Operation Date 7/1/2011 Operation Reboiler Rating Absorber Column Stages: 8760 hr/yr n/a mmbtu/hr 7 stages Amine Type: MDEA Sweet Gas Throughput Requested Sweet Gas Throughput Inlet Gas Pressure Inlet Gas Temperature Rich Amine Feed Pressure Rich Amine Feed Temperature Rich Amine Feed Flowrate Lean Amine Stream Pressure Lean Amine Stream Temperature Lean Amine Stream Flowrate Lean Amine Stream Wt. % Amine 85 MMscf/day 31025 MMscf/yr 847.33 psig 86 deg F 839.33 psia 131 deg F 376 gal/min 266 psia 252 deg F 350 gal/min 50 Lean Amine Stream Mole Loading H2S 1.23E-6 Lean Amine Stream Mole Loading CO2 0.0099 Flash Tank Control VRU Downtime 1 Recycled io Inlet N/A Sour Gas Input NGL Input Flash Tank Pressure Flash Tank Temperature Still Vent Control N YIN N YIN 60 psis 133 deg F RTO RTO Make Anguil RTO Model Model 150 RTO Minimum Temperature RTO Waste Gas Heat Content _ RTO Destruction Efficiency _ RTO Constant Pilot Light _ RTO Downtime Hours of RTO Downtime Hours of RTO Uptime Pollutant Emission Factor Controlled Emissions NOx ° 0.068 Ib/MMBTU 0.8 ton/yr CO ° 0.37 Ib/MMBTU I 4.6 ton/yr SOP` 1.88 ton SOP / ton HPS Combusted 30.0 ton/yr 1450 deg F. 29 btu/scf 97 % N Y/N 2% Uncontrolled 175.2 hr/yr 8584.8 hr/yr ° Emission Factors from AP -42, Chapter 13.5 far the RTO for combustion ofthe amine still vent stream. Assume 100% of H55 converted to 50c His values from the 3/2e/13 PROMAX run. Includes hoth flash andstill vent streams. ° Controlled VOC and HAP emissions from both the flash and still vent streams assuming 100% control of flash gm with VRU and still vent stream routed to the RTO assuming 97% ORE Amine Unit Amine Flash Gas Emissions - Amine Still Vent Emissions 2% Downtime Total Controlled Emissions' Total Uncontrolled Emissions' Overall System Cordial' Amine Flash Uncontrolled Emissions' Controlled Emission" Amine Still Uncontrolled Emissions' RTO Uptime Emissions' RTO Downtime Emissions' lb/hr ton/yr ton/yr lb/hr ton/yr ton/yr ton/yr ton/yr ton/yr Hydrogen Sulfide 0:001 0.004 0.000 0.317 1.388 0.041 0.028 0.07 1.39 99% N2 0.287 1256 0.000 0.006 0.025 0.024 0.000 0.02 1.28 CO2 18.181 79.635 0.000 10263.308 44953.290 44054.224 899.066 44953.29 45032.92 Water 6.516 28.540 0.000 374.919 1642.145 1609.302 32.843 1642.15 1670.69 Methane 106.457 466.280 0.000 8.548 ' 37.441 1.101 0.749 1.85 503.72 Ethane 55.944 245.034 0.000 8.899 38.977 1.146 0.780 1.93 284.01 Propane 26.917 117.896 0,000 3.696 16.187 0.476 0.324 0.80 134.08 i-Butane 3.322 14.550 0.000 0.377 1.650 0.049 0.033 0.08 16.20 n -Butane 11.159 48.877 0.000 - 1.890 8280 0.243 0.166 0.41 57.16 i-Pentane 1.728 7.570 0.000 0.173 0.757 0.022 0.015 0.04 8.33 n -Pentane 1.991 8.719 0.000 0.250 1.097 0.032 0.022 0.05 9.82 Cyclopentane 0.224 0.981 0.000 0.098 0.431 0.013 0.009 0.02 1.41 a-'Hezan '66F ids ft,,ii.V.VOOMM 607.8 aO343 .0010 Ok/;OO7 k."'',rsflio2 22. c Cyclohexane _ 0.205 0.896 0.000 0.133 0.585 0017 0.012 0.03 1.48 Heptane 0.143 0.628 0.000 0.031 0.136 0.004 0.003 0.01 0.76 Octane 0.014 0.063 0.000 0.001 0.005 0.000 0.000 0.00 0.07 Methanol 0.002 0.007 0.000 1.098 4.809 0.141 0.096 0.24 4.82 Berrie -6C- " 's O:335 Mia468J4WMiRDIOPOTOOTA M546302.oNzalsnom f. /703 W4 4001370.61W l64 X25.` r , - Toluene /6,1176/ G;7.83 WW0M..000 %61.4 I8 29-.°x+ W0.485�., W*2-.1.(E-31745a VattilaMale��1§i_8:1 .- m-Xylen4W,? tea - .40 .6,023M'• g2 47 0600: "= 's 6:664 r '2.908 , t .M40:085;47 "o 0158 4401},65i80469// MDEA .. 0.006 0.025 0.000 0.000 0.000 0.000 0.000 0.00 0.02 DEA 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.00 0.00 DGA 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.00 0.00 TEG 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.00 0,00 VOC 46.92 205.50 0.00 17.68 77.46 2.28 1.55 3.83 282.96 Total HAP 1.21 5.30 0.00 11.03 48.33 1.42 0.97 2.39 53.62 1. Uncontrolled Still Vent and Flash Tank emissions obtained Fern ProMax report dated March 26, 2013 2. RTO Control Emissions apply a 97% DRE to Still Vent Uncontrolled emissions and are annualized^based-on annual hours of RTO uptime. 3.2% RTO Downtime Emissions are based on Sell Vent Uncontrolled Emissions and are annualizedtased on annual hours of RTO downtime. 4. There is no flash tank downtime because emissions are piped to low-pressure inlet. 5. Total Controlled Emissions are represented as the sum of RTO Uptime, RTO Downtime, and Flash Tank emissions. 6.Total uncontrolled emissions are represented as the sum of still vent and flash tank emissions. 7. Demonstrating an overall system control of 99%, calculated as [Total Uncontrolled VOC Amine Ennsslons - Total Controlled Amine VOC Emissions / Total Uncontrolled VOC Amine Emissions] Permit Number: 10WE1659 AIRS ID Number: 123 /0049/ 137 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 (continued) 5 Non -Criteria Reportable Pollutant Emissions Inventory Pollutant Chemical Abstract Service (CAS) Number Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42; Mfg. etc) Actual Annual Emissions* Uncontrolled (lbs/year) Controlled5 (lbs/year) Benzene 71432 1.64 lb/MMscf 9""" 50,789.27 2,363.98 Toluene 108883 1.07 lb/MMscf 33,225.36 1,563.95 Ethylbenzene 100414 0.03 lb/MMscf Isa,z2Nrot, 1,074.43 50.54 Xylenes 1330207 0.19 lb/MMscf'"u"� 6,018.75 287.29 n -Hexane 110543 0.21 lb/MMscf 6,508.94 33.92 2,2,4- Trimethylpentane 540841 park\“ LA. crtkypanctirce, 0ther: cerid 43181i3 * NOT Actual emissions. Instead providing potential -to -emit (PTE) for the purposes of this minor mod app Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Legally Authorized Person (not a vendor or consultant) Roshini Shankaran 3128/20o - Date Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: E✓ Draft permit prior to issuance ® Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 AV iCOLORADO 7 m Ifvgutm�n[d Pobge f KnnrroiPMm P137 - Amine Unit Parameter Permit Condition Number Limitations Emission Factors Monitoring Method Interval VOC 5.1 3.82 2.3 tons per year ProMax Recordkeeping & Calculation 12 month rolling total Monthly Gas Processed 5.3 31,025 MMscf per year Gas Processed During RTO Downtime 5.3 620.5 MMscf per year 5.4.5 Records of the time and duration of all RTO downtime experienced shall be kept and available for Division review upon request. Control efficiency shallonly be claimed for the hours when RTO is operating. 5.7.1 The thermal oxidizer shall be operated at all times when emissions are routed to it, except for a maximum annual downtime of 175.2 hours (2% annual downtime) for malfunctions and maintenance. Appendix D Updated Facility Wide Emissions Inventory Form 102 Form APCD-102 Company Name: DCP Operating Company, LP Source Name: Roggen Gas Plant Source AIRS ID: 123/0049 Colorado Department of Public Health and Environment Air Pollution Control Division Facility Wide Emissions Inventory Form Ver. April, 2015 Uncontrolled Potential to Emit (PTE) • Controlled Potential to Emit (91E) Criteria (TPY) I HAPS (Ibs/yr) Criteria (TPY) HAPs (Ibs/yr) AIRS ID Equipment Description TSP PM10 PM2.5 SO2 NOx VOC CO I HCHO Acetal Acro BZ Tol EB Xyl n -Hex Meth 224-TMP TSP PM10 PM2.5 S02 NOx VOC CO I HCHO Acetal Acro BZ Tol IEB Xyl n -Hex Meth 224-TMP 123/0049/101 Engine C-154/P001/S001 0.72 0.72 0.72 0.02 116.84 15.93 84.98 I 1,521 207 195 117 41 2 14 0 227 0 0.72 0.72 0.72 0.02 21.24 10.62 21.24 I 365 104 98 59 21 1 7 0 -114 0 123/0049/102 Engine C-155/P002/S002 0.61 0.61 0.61 0.02 85.61 11.67 62.26 1 1,293 176 166 100 35 2 12 0 193 0 0.61 0.61 0.61 0.02 16.34 7.78 16.34 I 310 88 83 50 18 1 6 0 97 0 123/0049/103 Engine C-159/P003/S003 0.94 0.94 0.94 0.03 169.47 26.07 117.32 I 1,992 271 256 153 54 2 19 0 297 0 0.94 0.94 0.94 003 26.07 13.04 27.38 I 478 136 128 77 27 _ 1 9 0 149 0 123/0049/107 Engine C-157/P007/S007 0.61 0.61 0.61 0.02 85.61 11.67 62.26 I 1,293 176 166 100 35 2 12 0 193 0 0.61 0.61 0.61 0.02 16.34 7.78 16.34 I 310 88 83 50 18 1 6 0 97 0 123/0049/108 Engine C -161/9008/S008 0.94 0.94 0.94 0.03 143.40 19.55 104.29 1 992 271 256 153 54 2 19 0 297 0 0.94 0.94 0.94 0.03 13.04 9.13 26.07 I 478 136 128 77 27 1 9 0 _ 149 0 123/0049/110 Engine C-158/P010/S010 0.66 0.66 0.66 0.02 97.30 13.27 I 70.76 1,401 191 180 • � 108 38 2 13 0 '209 0 0.66 0.66 0.66 0.02 18.57 8.85 18.57 336 95 90 54 19 1 7 0 105 0 123/0049/113 Engine C-160/P013/S013 0.61 0.61 0.61 0.02 85.61 11.67 62.26 I 1,293 176 166 100 35 2 12 0 193 0 0.61 0.61 0.61 0.02 16.34 7.78 16.34 I 310 88 83 50 18 1 6 0 97 0 123/0049/114 Engine C-156/P014/S014 0.61 0.61 0.61 0.02 85.61 11.67 62.26 I 1,293 176 166 100 35 2 12 0 193 0 0.61 0.61 0.61 0.02 7.78 5.45 15.57 I 310 88 83 50 18 1 6 0 97 0 123/0049/115 Engine C-223/P015/S015 0.43 0.53 0.53 0.02 61.64 9.72 101.02 I 1,113 152 143 86 30 1 14 0 227 0 0.53 0.53 0.72 0.02 14.64 6.95 14.60 I 267 76 98 59 15 1 5 0 83 0 123/0049/117 Engine C-225/P017/S017 0.54 0.54 0.54 0.02 63.63 10.04 104.28 I 1,149 156 147 89 31 1 11 0 172 0 0.54 0.54 0.54 0.02 7.73 5.41 15.45 I 276 78 74 44 16 1 5 0 86 0 123/0049/119 Engine C-227/P019/S019 0.53 0.53 0.53 0.02 104.29 9.73 100.81 I 1,113 152 143 86 30 1 11 0 166 0 0.53 0.53 0.53 0.02 13.91 6.95 14.60 I 267 76 71 43 15 1 5 0 83 0 123/0049/122 P025/FUGITIVES 0.00 0.00 0.00 0.00 0.00 114.07 0.00 I 0 0 0 913 215 82 154 1,788 0 0 0.00 000 0.00 0.00 0.00 33.54 0.00 I 0 0 0 268 63 24 45 524 0 0 123/0049/125 P039, Stablized Condensate Tanks 0.00 000 0.00 0.00 0.00 28.84 0.00 I 0 0 0 771 2,571 200 1,857 5,600 0 0 0.00 0.00 0.00 0.00 0.00 1.44 0.00 I 0 0 0 39 129 10 93 280 0 0 123/0049/126 F029, Condensate Truck Loadout 0.00 0.00 0.00 0.00 0.00 30.84 0.00 I 0 0 0 916 2,749 305 2,138 6,110 0 0 0.00 0.00 0.00 0.00 0.00 30.84 0.00 I 0 0 0 916 2,749 305 2,138 6,110 0 0 123/0049/129 10037, Hot Oil Heater 0.26 0.26 0.26 0.02 3.45 0.19 2.90 I 5 0 0 0 0 0 0 124 0 0 0.26 0.26 0.26 0.02 3.45 - 0.19 2.90 I 5 0 0 0 0 0 0 124 0 0 123/0049/130 P-033, Regen Dehy 0.00 0.00 • 0.00 0.00 0.00 49.10 0.00 I 0- 0 0 3,378 3,761 138 1,247 1,151 0 0 0.00 0.00 0.00 0.00 0.00 1.05 0.00 I 0 0 0 228 256 9 86 44 0 0 123/0049/133 F031, Pressurized Liquids Loadout 0.00 0.00 0.00 0.00 0.00 5.00 0.00 I 0 0 0 0 0 0 0 0 0 0 0.00 0.00 0.00 0.00 0.00 5.00 0.00 I 0 0 0 0 0 0 0 0 0 0 123/0049/134 Engine C-181 0.98 0.98 0.98 0.03 156.99 21.41 114.18 I 2,070 282 266 160 56 3 20 0 309 0 0.98 0.98 0.98 0.03 14.27 9.99 28.54 I 497 141 133 80 28 1 10 0 155 0 123/0049/136 P-136, Inlet TEG Dehy 0.00 0.00 0.00 0.00 0.00 995.54 0.00 0 0 0 78,042 75,377 3,699 15,547 106,192 0 0 0.00 0.00 0.00 0.00 2.57 49.79 14.01 I 0 0 0 5,298 5,153 254 1,066 5,997 0 0 123/0049/137 P-137, Amine Unit 0.00 0.00 0.00 0.00 0.00 282.96 I 0.00 0 0 0 50,789 33,225 1,074 6,019 6,509 0 0 0.00 0.00 0.00 30.00 0.85 3.83 460 0 I. I 0 0 2,364 1,564 51 287 34 0 0 123/0049/138 Hot Oil Heater 1.07 1.07 1.07 0.08 7.02 0.65 11.79 I 0 0 0 0 0 0 0 505 0 0 1.07 1.07 1.07 0.08 7.02 0.65 11.79 0 0 0 0 0 0 0 505 0 0 123/0049/140 Engine C-192 0.98 0.98 0.98 0.03 156.99 21.41 114.18 I 2,076 282 266 160 56 3 20 0 310 0 0.98 0.98 0.98 0.03 14.27 9.99 28.54 1,038- 141 133 80 28 1 10 0 155 0 APEN Only - Permit Permitted Sources Subtotal= Exempt Sources 10.60 10.60 10.60 0.39 1423.47 '1701.02 1175.56 119,604 2,667 2,514 136,321 118,433 5,523 27,152 127,979 2,986 0 10.60 10.60 10.80 30.39 214.41 236.06 292.91 I 5,249 1,334 1,283 9,884 10,181 665 3,809 13,619 1,463 0 I I I I I I I I I I I I APEN Exempt / Insignificant APEN Only Subtotal = sources 0.0 0.0 0.0 0.0 0.0 0.0 0.0 I 0 0 0 0 0 0 0 0 0 0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 I 0 0 0 0 0 0 0 0 0 0 APEN Exempt / Insignificant sources 1.5 1.3 3.8 I 139 157 176 1.5 1.3 3.8 I 139 157 176 I I I I I I I I I I I Insignificant Subtotal = Total, All Sources = 0.0 0.0 0.0 0.0 1.5 1.3 3.8 I 0 0 0 139 0 0 0 157 176 0 0.0 0.0 0.0 0.0 1.5 1.3 3.8 I 0 0 0 139 0 0 0 157 176 0 ( 10.6 10.6 10.6 0.4 1425.0 1702.3 1179.4 I 19,604 2,667 2,514 136,460 118,433 5,523 27,152 128,136 3,162 0 10.6 10.6 10.8 30.4 215.9 237.3 I 296.7 I 5,249 1,334 1,283 10,022 10,181 665 3,809 13,776 1,638 0 Uncontrolled Uncontrolled HAPs Total, Summary All HAPS Controlled Controlled HAPs Total, Summary All HAPs (TPY) = 9.8 1.3 1.3 68.2 59.2 2.8 13.6 64.1 1.6 0.0 (TPY) =I 2.6 I 0.7 I 0.6 I 5.0 I 5.1 I ' 0.3 I 1.9 I 6.9 I 0.8 I 0.0 I I (TPY) =I 221.8 (TPY) =I 24.0 Footnotes: 1. This form should be completed to include both existing sources and all proposed new or modifications to existing emissions sources 2. If the emissions source is new then enter "proposed" under the Permit No. and AIRS ID data columns 3. HAP abbreviations include: BZ = Benzene 224-TIVIP = 2,2,4-Trimethylpentane Tot = Toluene Acetal = Acetaldehyde EB = Ethylbenzene Acro = Acrolein Xyl = Xylene n -Hex = n -Hexane HCHO = Formaldehyde Meth = Methanol 4. APEN Exempt/Insignificant Sources should be included when warranted. Company Name 7/28/2017 Page 1 of 1 &C V, Midstream July 28, 2017 Attn: Elie Schuchardt Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South APCD-SS-B 1 Denver, CO 80246-1530 RE: Roggen Natural Gas Processing Plant Title V Permit 95OPWE055 Condensate Liquid Loading (F029) AIRS ID: 123/0049/126 DCP Operating Company, LP 370 17th Street, Suite 2500 Denver, CO 80202 (303) 605-2039 UPS: 1Z F46 915 02.9855 8437 Dear Ms. Schuchardt: DCP Operating Company, LP (`DCP") is submitting the enclosed APEN for the condensate liquid loading (F029, AIRS ID: 123/0049/126) source for the Roggen Natural Gas Processing Plant ("Facility"), located at Section 24, Range 63W, Township 2N in Weld County, Colorado. The condensate liquid loading currently operates under Title V permit 95OPWE055 issued on May 1, 2001 and last revised on August 29, 2005, with an expiration date of May 1, 2006. A timely Title V permit renewal application was submitted in April 2006. On March 30, 2007, DCP submitted a minor modification application for the condensate liquid loading and requested to increase the VOC limit and the annual condensate volume limit, as well as update the VOC emission factor. A revised Title V permit has not yet been issued. DCP discovered the HAPs for F029 condensate liquid loading are reportable per Regulation 3 based on condensate speciation reported for condensate tanks (P039, AIRS ID: 123/0049/125). The enclosed APEN is submitted to comply with this regulation. DCP is not requesting any increases or adjustments to VOC. If you have any questions or comments, please contact me at (303) 605-2039, or by email at rshankaran@dcpmidstream.com. Sincerely, DCP Operating Company, LP Roshini Shankaran Environmental Engineer Enclosure /rmm a t 7'st1 Hydrocarbon Liquid Loading APEN - Form APCD-2k§ Air Pollutant Emission Notice (APEN) and Application for Construction Permit Alt sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Hydrocarbon Liquid Loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE055 AIRS ID Number: 123 /0049 / 126 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: F029 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Site Name: Site Location: DCP Operating Company, LP Roggen Natural Gas Processing Plant Site Location Section 24, R63W, T2N County: Weld 35409 Weld County Road 18 Mailing Address: e 370 17th Street, Suite 2500 (Include Zip Code) Denver, CO 80202 E -Mail Address2: rshankaran@dcpnnidstream.com NAICS or SIC Code: 1311 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 'Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Rev 02/2017 366850 pp COLORADO 1 I L3117 -'::4I$ & o�H� Hq1 av1�OOttront Permit Number: 95OPWE055 AIRS ID Number: 123 /0049 / 126 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source ❑ Request coverage under construction permit O Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN Filing fee. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment ❑ Change company name O Change permit limit ❑ Transfer of ownership3 O Other (describe below) -OR - ✓❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - O Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: stabilized condensate loadout For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: / /2002 Will this equipment be operated in any NAAQS nonattainment area? Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Does this source load gasoline into transport vehicles? Is this source located at an oil and gas exploration and production site? If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Does this source splash fill less than 6750 BBL of condensate per year? Does this source submerge fill less than 16308 BBL of condensate per year? O Yes ❑ No ❑ Yes 0 No ❑ Yes 0 No ❑ Yes 0 No ❑ Yes O No ❑ Yes ❑ No ❑ Yes O No Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 ACOLORADO 2 I Ansfif E1t=,dww� XWIhbEavk*M ltti Permit Number: 95OPWE055 AIRS ID Number: 123/0049/126 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information Product Loaded: ❑✓ Condensate 0 Crude Oil 0 Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded4: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth 285,714 Bbl/yr Actual Volume Loaded: 100,312 Bbl/yr This product is loaded from tanks at this facility into: (eg, "rail tank cars" or "tank trucks") tank trucks If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: 0.6 Average temperature of bulk liquid loading: 5 Q . 2 C7 ° F True Vapor Pressure 5.11 Psia ® 60 °F Molecular weight of displaced vapors V . 71 Lb/lb mol If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: Bbl/yr Actual Volume Loaded: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Bbl/yr Product Density: Lb/ft3 Load Line Volume: ft3/truckload Vapor Recovery Line Volume ft3/truckload Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 • 7 COLORADO1 Eavi HMIHI B ETVIN°mem Permit Number: 95OPWE055 AIRS ID Number: 123/0049/126 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Geographical Information Geographical Coordinates (Latitude/Longitude or UTM) 40.1174 / -104.3883 Operator _ Stack ID No Discharge Height Above Ground Level (Feet) Temp F ( ) = Flow_Rate ,__..- ACFM l ) 74ci (ftect F029 Indicate the direction of the stack outlet: (check one) ❑ Upward 0 Downward O Horizontal 0 Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Other (describe): 0 Upward with obstructing raincap Section 6 - Control Device Information ❑ Loading occurs using a vapor balance system: Requested Control Efficiency ❑ Combustion Device: Pollutants Controlled: Rating: MMBtu/hr Type: Make/Model: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency % Minimum Temperature: Waste Gas Heat Content Constant Pilot Light: 0 Yes ❑ No Pilot burner Rating Btu/scf MMBtu/hr O Other: Pollutants Controlled: Description: Control Efficiency Requested Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 }ny�COLORADO HWtRB Entommt U Permit Number: 95OPWE055 AIRS ID Number: 123/0049/126 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? D Yes ❑✓ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): PM Overall Requested Control. Efficiency (% reduction in emissions) SO, NO„ CO VOC HAPs Other: ❑ Using State Emission Factors (Required for GP07) VOC 0 Condensate 0.236 Lbs/BBL 0 Crude 0.104 Lbs/BBL Benzene n -Hexane 0.00041 Lbs/BBL 0.0036 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? 2016 Use the following table to report the criteria pollutant emissions from source: Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual ,� .: _,. _ = Emissions _�,... F.�. Re nested Annual 4 Emission Limits) . . Permit s Uncontrolled (Tons/year) Controlleds (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM SO, NO, VOC 5.14 lb/1000 gal Eng. Est 10.83 10.83 30.84 30.84 CO Benzene 0.08 lb/1000 gal Eng. Est. 0.16 0.16 0.46 0.46 Toluene 0.23 lb/1000 gal Eng. Est. 0.48 0.48 1.37 1.37 Ethylbenzene 0.03 lb/1000 gal Eng. Est. 0.05 0.05 0.15 0.15 Xylenes 0.18 lb/1000 gal Eng. Est. 0.38 0.38 1.07 1.07 n -Hexane 0.51 lb/1000 gal Eng. Est. 1.07 1.07 3.05 3.05 2,2,4- Trimethylpentane Other: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. AAnnual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 A V COLORADO 5 I xwm a Enr�ronm�a Permit Number: 95OPWE055 AIRS ID Number: 123 /0049 / 126 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. 1-(2 f'2oi 1 -- Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $250 as applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO 6I Alr ° L : Roggen Natural Gas Processing Plant Truck Loadouts Source ID F029 AIRS ID 123/0049/126 Stabilized Condensate Description Loadout Loaded from Tanks to: Tank Trucks ial Emissio Potential Operation 285,714 bbl/yr Reid Vapor Pressure 8.1 psia Average Temperature of Bulk Liquid Loaded: Control: 58.2 °F None Pollutant EPA S Factor2 True VP of Liquid3 (psia) Mol. Wt. of Vapors' (lb/lb-mol) T of Liquid (R) Sales Volume (bbl/yr) Estimated Emissions Source of Emission Factor (lb/1000 gal) (tpy) VOC 0.6 5.11 69.71 518.16 285714.3 5.14 30.84 Eng Est' ' Engineering Estimate 2 EPA AP -42, Volume I, Fifth Edition - June 2008, Table 5.2-1, Saturation (S) Factors for Calculating Petroleum Liquid Loading Losse; 3 Tanks 4.0.9d run 03/30/2007 F029 Loadout Potential HAP Emissions Pollutant Emission Factor of VOC' Estimated Emissions lb/1000 gal tpy n -hexane 10% 0.51 3.05 Benzene 1% 0.08 0.46 Toluene 4.5% 0.23 1.37 Ethylbenzene 0% 0.03 0.15 Xylene 3% 0.18 1.07 Emission factors from HAP emission factors table below. F029 Loadout HAP Emission Factors' Pollutant Condensate Tank (P039) Uncontrolled Emission Factor lb/1000 gal2 BTEX as % of VOC3 VOC 0.202 n/a n -hexane 0.020 10% Benzene 0.003 1% Toluene 0.009 4% Ethylbenzene 0.001 0% Xylene 0.007 3% HAP emission factors equal Condensate Tanks ratio of BTEX to VOC 2 Condensate Tank (P039) emission factors are from permit 12WE1242 3 HAP percent calculated as uncontrolled EF for n-hexane/uncontrolled EF for VOC Loadout Emissions Summary Roggen Gas Plant DCP Operating Company, LP Loadout: F-029 Stabilized Condensate Load -out AIRS ID: 123/0049/126 Conrol Equipment: Percent Controlled: Potential Loading Rate: Actual Loading Rate: None 0 % 285,714 barrels per year 100,312 barrels per year Uncontrolled Emission Factor, (Ib11000 gal) Controlled Emissions:' VOC 5.14 Potential tpy 30.84 2016 Actual tpy 10.83 Emission. Factor (lb/1000-gal) 5.14 Potential tpy 30.84 2016 Actual tpy. '` 10.83 HAP Emissions Total HAPs Ib11000gal Potential tpy 2016: Actual tpy lbli000`gal Potential tpy 2016 Actual tpy n -hexane Benzene Toluene Ethylbenzene Xylene *VOC emissions are based on emission factors in Permit 95OPWE055. HAP emission factors equal Condensate Tanks ratio of BTEX to VOC 0.51 0.08 0.23 0.03 0.18 3.05 0.46 1.37 0.15 1.07 1.07 0.16 0.48 0.05 0.38 0.51 0.08 0.23 0.03 0.18 3.05 0.46 1.37 0.15 1.07 1.07 0.16 0.48 0.05 0.38 dcp Midstream. September 8, 2017 Colorado Department of Public Health and Environment Air Pollution Control Division ATTN: Elie Shuchardt 4300 Cherry Creek Drive South Denver, CO 80246-1530 Re: Roggen Natural Gas Processing Plant Operating Permit 95OPWE055 Title V Modification Application AIRS ID 123/0049 DCP Midstream 370 17th St., Suite 2500 Denver, CO 80202 (303) 605-2039 www.dcpmidstream. com UPS Tracking No. 1Z F46 915 02 9828 9460 IZEtErviz SEP 1 11017 S otiA o E Z Dear Ms. Schuchardt: DCP Operating Company, LP (DCP) operates the Roggen Natural Gas Processing Plant (Roggen) located at Section 24, Township 2N, Range 63W in Weld County, Colorado. This facility currently operates under Title V permit 95OPWE055 originally issued on May 1, 2001 and last revised on August 29, 2005, with an expiration date of May 1, 2006. A timely Title V permit renewal application was submitted in April 2005; however, a revised Title V permit has not yet been issued. Several construction permits have been issued since this date, and have all been subsequently requested to be rolled into the Title V permit for the facility. This application serves as an addendum to the TV modification application submitted 7/07/2017. DCP is requesting the following changes to Permit 95OPWE055, which is currently under review for renewal by the Colorado Air Pollution Control Division (APCD): Modification of Operating Permit 95OPWE055 — Fugitive Emissions (P025) DCP recently discovered that process units RC, RP, and RTF at this facility triggered the NSPS OOOO definition of "modification," and are therefore subject to NSPS OOOO LDAR requirements, rather than the same NSPS KKK LDAR requirements as the rest of the process units at this facility. This evaluation determined that process unit RC triggered NSPS OOOO starting in Q2 of 2013, and process units RP and RTF triggered NSPS OOOO in Q1 of 2015. DCP has implemented the required LDAR program under NSPS OOOO immediately following this discovery, as of 8/18/2017. This portion of this Title V modification application is being submitted to reflect these updated Federal requirements for these three process units. There will be no changes to overall potential emissions for P025 based upon this update. Modification of Operating Permit 95OPWE055 — Emergency Flare DCP has determined that the emergency flare located at this facility, used for periods of maintenance or malfunctions, can no longer be considered an insignificant source based upon the potential waste gas throughput to the flare and resulting emissions. DCP wishes to file this Major Modification to add this flare to Permit 95OPWE055. ;fi Regulatory Analysis Nonattainment New Source Review & Prevention of Significant Deterioration The federal New Source Review program applies to new or modified sources in both attainment and nonattainment areas that result in emission increases in excess of specified thresholds. Weld County is designated as nonattainment for ozone, so sources in this area are potentially subject to nonattainment New Source Review if emissions of nitrogen oxides (NOx) or volatile organic compounds (VOC) are in excess of 100 tons per year (tpy). The Roggen Natural Gas Processing Plant is a major source (potential emissions > 100 tpy) of both NOx and VOC and nonattainment new source review would be required if a proposed modification would result in a net emissions increase of 40 tpy or more of either pollutant. The current proposed permitting action does not increase emissions of either pollutant by 40 tpy based upon revised emission calculations. Additionally, Roggen is an existing major source for Prevention of Significant Deterioration (PSD) purposes due to emissions of NOx and CO exceeding 250 tpy. The emission increases from this proposed permitting action indicate that the project does not trigger PSD review. The proposed action is therefore a minor modification for the purposes of NA-NSR and PSD. New Source Performance Standards, 40 Code of Federal Regulations (CFR) Part 60 & National Emission Standards for Hazardous Air Pollutant (40 CFR Part 63) Fugitives components associated with process units RC, RP, and RTF are subject to the LDAR provisions NSPS OOOO. All other existing fugitive components will remain subject to NSPS KKK. The emergency flare is subject to NSPS Subpart A, General Provisions. Specifically, the General control device and work practice requirements under 60.18. State Regulations There will be no change in state regulatory applicability for the fugitive emissions at this facility based on this modification application. There is no current underlying permit for the emergency flare at this facility. DCP has attached a list of suggested requirements, based on conditions in Construction Permit Construction Permit 15WE0939.CP1, issued 5/16/2016 for DCP's Greeley Gas Plant facility. Please refer to Attachment E for this table, as well as proposed compliance methods for these expected conditions. The following attachments are included in this application: • Attachment A: New APEN (Flare) • Attachment B: Revised APEN (P025 — Fugitives) • Attachment C: Colorado Title V Operating Permit Forms • Attachment D: Emission Calculations and Supporting Documentation • Attachment E: Suggested Permit Requirements for Flare, including proposed compliance methods • Attachment F: Flare O&M Plan • Attachment G: Updated Facility Wide Emissions Inventory Form 102 If you have any questions or require any additional information about this submittal, please contact me at (303) 605-2039 or RShankaran@dcpmidstream.com. Sincerely, DCP Operating Company, LP Roshini Shankaran Environmental Engineer Attachments Attachment A New APEN (Flare) Roggen Gas Plant General APEN - Form APCD-200 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. There may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, etc.). A list of specialty APENs is available on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/aped. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE055 [Leave blank unless APCD has already assigned a permit # and AIRS ID] REcErtli SEp 1 1 10/ q y .flo8 p s4fPcDtatso 413, AIRS ID Number: 123 /0049 / ' Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Roggen Gas Plant Site Location: Section 24, T2N, R63W Mailing (Include Address: p Code) 370 17th Street, Suite 2500 Zip Code) Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1321 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 E -Mail Address2: RShankaran@DCPMidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-200 - General. APEN - Revision 10/2016 368851 COLORADO iiQ1�'� d HwIM.k FatvROAi+oM Permit Number: 95OPWE055 AIRS ID Number: 123 / 0049 / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action O NEW permit OR newly -reported emission source (check one below) O STATIONARY source ❑ PORTABLE source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) - OR APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info ft Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Emergency Flare for Maintenance and Malfunctions Manufacturer: John Zink Model No.: Kaldair P-684 Serial No.: Company equipment Identification No. (optional): Flare For existing sources, operation began on: 2010 For new or reconstructed sources, the projected start-up date is: El Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Seasonal use percentage: Dec -Feb: Mar -May: Form APCD-200 - General APEN - Revision 10/2016 days/week weeks/year June -Aug: Sept -Nov: Taa COLORADO 21 liaath 6 FJIVYIB[IIX9H1 Permit Number: 95OPWE055 AIRS ID Number: 123 /0049 / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information Et Material Use 0 Check box if this information is not applicable to source or process From what year is the actual annual amount? Material Consumption' Design Process Rate (Spec►fy,Units) Actual Annual Amount, (Specify Units equested Annual Permit Ltmit4. Specify Units) 4 Requested values wil become permit limitations. Requested limit(s) should consider future process growth. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.1174 / -104.3883 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a If this is the case, the rest of this section may remain blank. era orsrat , O : p � Discharg Heigh A `ove round Level, =..`3��.-...>. y � m �i � gr( �) w_ elocb /sew Flo `Rates ACFM Flare 60.0 Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): ✓❑ Upward ❑ Horizontal Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): ❑ Other (describe): O Upward with obstructing raincap Interior stack depth (inches): �//Ar��yy COLORADO Form APCD-200 - General APEN - Revision 10/2016 Permit Number: 95OPWE055 AIRS ID Number: 123 / 0049 / [Leave blank unless APCD has already assigned a permit if and AIRS ID] iw Section 6 - Combustion Equipment Et Fuel Consumption Information ❑ Check box if this information is not applicable to the source (e.g. there is no fuel -burning equipment associated with this emission source) Design Input Rate - (MMBTU/hr) Actual Annual Fuel Use ' (Specify Units) Requested Annual Permit Limit4 (Specify Units) Fuel: 0.17, Purge: 0.27, Waste Gas: 4.73 Fuel: 1.31, Purge: 2.10, Waste Gas: 33.68 (MMscf/yr) From what year is the actual annual fuel use data? Indicate the type of fuel used5: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash Content: Sulfur Content: ✓❑ Other (describe): Fuel/Residue/Purge, Waste Gas Heating value (give units): 1141 Btu/scf, 1318 Btu/scf 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? 0 Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Overall Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.5 SOX NOx CO VOC Open Flare 95% Other: HAPs - Open Flare 95% Form APCD-200 - General APEN - Revision 10/2016 ©© COLORADO 4 m d men Permit Number: 95O PWE055 AIRS ID Number: 123 /0049 / [Leave blank unless APCD has already assigned a permit # and AIRS ID) 3 Section 7 (continued) From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) TSP (PM) PM10 Uncontrolled Emission Factor (Specify Units), Emission Factor Source (AP -42, Mfg. etc) Controlled6 (Tonslyear) ueste rmssionr Controlled (Tons/year) Uncontrolled (Tons/year) Uncontrolled (Tons/year) PM2.5 SOx 0.6 Lb/MMscf AP -42 0.01 0.01 NO„ CO 0.068 Ib/MMBtu AP -42 1.55 1.55 0.31 lb/MMBtu AP -42 6.84 6.84 VOC 11, 370.07 Ib/MMscf Engineering Calc. 190.00 9.50 Other: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) emissions equal to or greater than 250 ✓� Yes ❑ No lbs/year? If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: CAS umber 110-54-3 71-43-2 Chemical Name n -Hexane Benzene Overall Control Efficiency 95% 95% Uncontrolled Emission Factor. (specify units) 56.62 Ib/MMscf 11.30 Ib/MMscf Emission Factor Source - (AP -42, Mfg. etc) Engineering Calc. Engineering Calc. Uncontrolled Actual Emissions (lbs/year) 2,033.73 405.96 Controlled Actual Emissions6 (lbs/year) 101.38 20.30 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-2OO - General APEN - Revision 10/2016 5 I COLORADO 4 tabs and tvua.n Hun�6Faw�ronmaM Permit Number: 95OPWE055 AIRS ID Number: 123 /0049 / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Legally Authorized Person (not a vendor or consultant) Roshini Shankaran 9ikcii Date Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance �✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90, to: For more information or assistance call: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 43O0 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-200 - General APEN - Revision 10/2016 AWN COLORADO 6 ' o�,avmmed P Ik Hs4ltlB E. Wmmam4 t ti Attachment B Revised APEN (P025 — Fugitives) Roggen Gas Plant . v b '• SEp 11017 Fugitive Component Leak Apee- .ourerirs. Emissions APEN - Form APCD-203 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for fugitive component leak emissions. If your emission source does not fall into this category, there may be a different specialty APEN available for your operation (e.g. natural gas venting, condensate tanks, paint booths, etc.). In addition, the General APEN (Form APCD- 200) is available if the specialty APEN options do not meet your reporting needs. A list of specialty APENs is available on the Air Pollution Control Division (APCD) website at www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE055 AIRS ID Number: 123 / 0049/122 [Leave blank unless APCD has already assigned a permit ft and AIRS ID) Section 1 - Administrative Information Company Name: Site Name: Site Location: Mailing Address: DCP Operating Company, LP Roggen Gas Plant Section 24, T2N, R63W (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Permit Contact: Roshini Shankaran E -Mail Address2: RShankaran@DCPMidstream.com Site Location Weld County: NAICS or SIC Code: 1321 Phone Number: 303-605-2039 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 $68858 COLORADO 1 I u.nmbm=uN Permit Number: 95OPWE055 AIRS ID Number: 123 [Leave blank unless APCD has already assigned a permit # and AIRS ID] / 0049 / 122 Section 2- Requested Action ❑ NEW permit OR newly -reported emission source (check one below) -OR - ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change process or equipment 0 Change company name 0 Add point to existing permit ❑ Change permit limit 0 Transfer of ownership3 ❑✓ Other (describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: Add NSPS 0000 LDAR Applicability for select process units / fugitive components. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information For existing sources, operation began on: 1981 For new or reconstructed sources, the projected start-up date is: ✓❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: Facility Type: ❑ Well Production Facility4 ❑ Natural Gas Compressor Station4 (] Natural Gas Processing Plant4 ❑ Other (describe): hours/day days/week weeks/year 4 When selecting the facility type, refer to definitions in Colorado Regulation No. 7, Section XVII. Form APCD-203 Fugitive Component Leak Emissions APEN - Revision 7/2017 ICQLORADC 2 AV �V b£n atwbtr_ KULLNwoameef Permit Number: 95OPWE055 AIRS ID Number: 123 / 0049! 122 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Regulatory Information What is the date that the equipment commenced construction? 1981 Will this equipment be operated in any NAAQS nonattainment area?5 0 Yes 0 No Will this equipment be located at a stationary source that is considered a ❑ Yes ❑✓ No Major Source of Hazardous Air Pollutant (HAP) emissions? Are there wet seal centrifugal compressors or reciprocating compressors ❑✓ Yes ❑ No located at this facility? Is this equipment subject to 40 CFR Part 60, Subpart KKK? 0 Yes 0 No Is this equipment subject to 40 CFR Part 60, Subpart OOOO? 0 Yes 0 No Is this equipment subject to 40 CFR Part 60, Subpart OOOOa? ❑ Yes ❑✓ No Is this equipment subject to 40 CFR Part 63, Subpart HH? ❑ Yes ❑✓ No Is this equipment subject to Colorado Regulation No. 7, Section XII.G? 0 Yes 0 No Is this equipment subject to Colorado Regulation No. 7, Section XVII.F? 0 Yes ❑✓ No Is this equipment subject to Colorado Regulation No. 7, Section XVII.B.3? 0 Yes ❑✓ No 5 See http://www.colorado.Qov/cdphe/state-implementation-plans-sibs for which areas are designated as attainment/non- attainment. Section 5 - Stream Constituents The required representative gas and liquid extended analysis (including BTEX) to support the data below has been attached to this APEN form. e the following table to report the VOC and HAP weight % content of each applicable stream. Stream VOC (wt %) Benzene (wt %) Toluene (wt %) Ethylbenzene (wt %) Xylene (wt %) n -Hexane (wt %) 2,2,4 Trimethylpentane (wt %) Gas 25.54 0.043 0.028 0.000 0.004 0.247 -- Heavy Oil (or Heavy Liquid) 100 0.043 0.028 0.000 0.004 0.247 _— Light Oil (or Light Liquid) 100 0.043 0.028 0.000 0.004 0.24 -- Water/Oil -- - -- -- -- Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 3I VCOLORADO I== N.II1Eb Enwanm.N Permit Number: 95OPWE055 AIRS ID Number: 123 / 0049 / 122 [Leave blank unless APCD has already assigned a permit k and AIRS ID] Section 6 - Geographical Information Geographical Coordinates (Latitude/Longitude or UTM) 40.1174 / -104.3883 Attach a topographic site map showing location Section 7 - Leak Detection and Repair (LDAR) and Control Information Check the appropriate boxes to identify the LDAR program conducted at this site: [J✓ LDAR per 40 CFR Part 60, Subpart KKK ❑✓ Monthly Monitoring - Control: 88% gas valve, 76% light liquid valve, 68% light liquid pump O Quarterly Monitoring - Control: 70% gas valve, 61% light liquid valve, 45% light liquid pump LDAR per 40 CFR Part 60, Subpart 0000/0000a 0✓ Monthly Monitoring - Control: 96% gas valve, 95% lightliquid valve, 86% light liquid pump, 81% connectors ❑ LDAR per Colorado Regulation No. 7, Section XVII.F Other6: O No LDAR Program 6 Attach other supplemental plan to APEN form if needed. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 4 I AV COLORADO ,e,niaPublic NmIN bEnvvenmenl Permit Number: 95OPWE055 AIRS ID Number: 123 / 0049 / 122 [Leave blank unless APCD has already assigned a permit # and MRS ID] Section 8 - Emission Factor Information Select which emission factors were used to estimate emissions below. If none apply, use the table below to identify the emission factors used to estimate emissions. Include the units related to the emission factor. 0✓ Table 2-4 was used to estimate emissions'. D Table 2-8 (< 10,000ppmv) was used to estimate emissions'. Use the following table to report the component count used to calculate emissions. The component counts listed in the following table are representative of: ❑ Estimated Component Count �✓ Actual Component Count conducted on the following date: 12/1/2011 115 Count8 Equipment Type Connectors 2,398 Flanges, 2,137 Open -Ended Lines Pump Seals Valves 2,239 0ther9 Emission Factor 4.40E-04 8.6E-04 9.92E-03 1.94E-02 Units lb/hr/source Ib/hr/source lb/hr/source lb/hr/source Heavy Oil (or Heavy Liquid) Count8 57 1 Emission Factor 1.90E-05 7.0E-05 Units lb/hr/source lb/hr/source Light Oil (or Light Liquid) Count8 2,937 1,082 27 2,164 44 Emission Factor 4.63E-04 2.43E-04 2.87E-02 5.51 E-03 1.65E-02 Units Ib/hr/source lb/hr/source lb/hr/source Ib/hr/source lb/hr/source Water/Oil Count8 Emission Factor Units ' Table 2-4 and Table 2-8 are found in U.S. EPA's 1995 Protocol for Equipment Leak Emission Estimates (Document EPA -453/R- 95-017). 8 The count shall be the actual or estimated number of components in each type of service that is used to calculate the "Actual Calendar Year Emissions" below. 9 The Other equipment type should be applied for any equipment other than connectors, flanges, open-ended lines, pump seals, or valves. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 5'AV DepwwwwaPalk COLORADO Permit Number: 95OPWE055 AIRS ID Number: 123 / 0049 / 122 [Leave blank unless APCD has already assigned a permit ft and AIRS ID] Section 9 - Criteria and Non -Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. From what year is the following reported actual annual emissions data? 2016 Use the following table to report the criteria pollutant emissions and non -criteria pollutant (HAP) emissions from source: s. Chemical Name CAS Number Actual Annual Emissions Requested Annual Permit Emission Limit(s) Uncontrolled (tonstyear) _ 1 Controlled0 (tons/year) Uncontrolled (tons/year) Controlled1i (tons/year) vOC 98.37 29.34 114.07 33.54 Does the emissions source have any actual emissions of individual non -criteria pollutants (e.g. HAP- hazardous air pollutant) emissions equal to or greater than 250 ® Yes ❑ No lbs/year? If yes, use the following tame to report the non -criteria pouuLanL krikkr, elmb]iuui iiuiii ]VUI LC. Chemical Name CAS Number Actual Annual Emissions Requested Annual Permit Emission Limit(s) Uncontrolled (lbs/year) Controlled e (lbs/year) Uncontrolled (lbs/year) Controlledt0 (lbs/year) Benzene 71432 320 100 920 260 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 2,240 660 1,780 520 2,2,4 Trimethylpentane 540841 Other: 10 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. 11 Requested values will become permit limitations. Requested limit(s) should consider future process growth, component count variability, and gas composition variability. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision ��yy/�,� 7/2017 6 I -'--V W401 VANOMM.110 COLORADO Permit Number: 95OPWE055 AIRS ID Number: 123 [Leave blank unless APCD has already assigned a permit # and AIRS ID] / 0049 / 122 Section 10 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Si Roshini Shankaran Name (print) �l�'fwr- ature Date of Legally Authorized Person (not a vendor or consultant) Environmental Engineer Title Check the appropriate box to request a copy of the: 0 Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 to: For more information or assistance call: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/aped Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 7 AVICOLORADO o1 .n, Attachment C Colorado Title V Operating Permit Forms Roggen Gas Plant Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name and mailing address Street or Route City, State, Zip Code Name Roggen Gas Plant Rev 06-95 r 5 JI 370 17th Street, Suite 2500 Denver, Colorado 80202 2. Facility location (No P.O. Box) Street Address City, County, Zip Code 35409 Weld County Road 18 Roggen, Colorado 80652 3. Parent corporation Name Street or Route City, State, Zip Code Country (if not U.S.) DCP Operating Company, LP 370 17th Street, Suite 2500 Denver, Colorado 80202 4. Responsible official Name Title Telephone David M. Jost Vice President of Northern Operations 970-378-6345 5. Permit contact person (If Different than 4) Name Title Telephone Roshini Shankaran Environmental Engineer 303-605-2039 6. Facility SIC code: 1321 7. Facility identification code: CO 123-0049 8. Federal Tax I. D. Number: 841041166 9. Primary activity of the operating establishment: Natural Gas Liquids Processing and Compression 10. Type of operating permit ❑ New X Modified ❑ Renewal 11. Is the facility located in a "nonattainment" area: If "Yes", check the designated "non -attainment" pollutant(s): ❑ Carbon Monoxide X Yes ❑ No X Ozone ❑ PM10 ❑ Other (specify) 12. List all (Federal and State) air pollution permits (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. 1 Operating Permit Appncanon Colorado Department of Public Health and Environment Air Pollution Control Division Facility Identification Code: CO 123-0049 Facility Name: Roggen Gas Plant The operating permit must be prepared and submitted on forms supplied by the Division. Use of this form is required for all operating permit applications. The Division will not consider or act upon your application unless each form used has been entirely completed. Completion of the information in the shaded area of this form is optional. Use "NA" where necessary to identify an information request that does not apply and is not in the optional shaded area. 1.Briefly describe the existing Unit(s) to be permitted. Attach copies of Form 2000-700 as needed to provide the information. Process flowsheets or line diagrams showing major features and locations of air pollution control equipment can be most effective in showing the location and relationships of the units. Providing mass flowrates/balances at critical points on the diagrams is very helpful when developing an understanding of the processes involved. The Roggen Gas Plant uses cryogenic processes to separate liquid hydrocarbons from high nd low pressure op pressing natural gas streams. The operations at the facility include: inlet compression, gasdehydration, (cryogenic plant skids), product storage and transfer, and residue gas compression. This major modification makes the following changes: Addition of Emergency Flare to Permit. Addition of NSPS OOOO LDAR requirements for applicable fugitive components. 2.Site Location and Description (Include instructions needed to drive to remote sites not identified by street addresses) The facility is located at 35409 Weld County Road 18, Roggen, Colorado. It is located in Section 24, Township 2 North, Range 63 West, about 5 miles south of the town of Roggen in Weld County. 3. Safety Equipment Identify safety equipment required for performing an inspection of the facility: x Other, specify Fire retardant clothing Eye Protection Protection x Hard Hat x Safety shoes x Hearing Protection Gloves t �l c ill 2 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division Rev 06-95 Facility Name: Roggen Gas Plant Facility Identification Code: CO 123-0049 NOTE: Each new or updated Air Pollutant Emission Notice (APEN) submitted must be accompanied by payment of $152.90 per APEN. 1. For each emission unit enclose a copy of the most current complete Air Pollutant Emission Notice (APEN) on file with the Division. If the most current APEN was not completely and correctly filled out, a revised APEN is required. List an APEN number, date, and a brief description of the unit/process covered by the APEN. (No filing fees are needed for these copies) 2. No APEN exists for an emission unit. List the new APEN and the appropriate descriptive information here. Submit the APEN with a construction permit application. Attachment A contains copies of the following NEW APEN: Source I AIRS ID I Description ID Flare TBD Emergency Flare for Maintenance and Malfunctions APEN Date 9/8/2017 i 3.A revised APEN was prepared and enclosed for an emission unit. List the APEN and the appropriate descriptive information here. A revised APEN is needed where a significant increase in emissions has occurred, or is planned; or a major modification of the unit has occurred or is planned; or the existing information needs correction or completion. A construction permit application may need to be submitted. Attachment B contains copies of the following REVISED APEN: Source AIRS ID ID P025 122 Fugitive Emissions Description APEN Date 9/8/2017 Revised APEN submitted as part of this application: x Yes ❑ No ❑ Filing Fee Enclosed New permit application enclosed: ❑ Yes x No Permit modification application enclosed: x Yes ❑ No 3 iI Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division STACK IDENTIFICATION FORM 2000-200'4 Rev 06-95 SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Natural Gas Processing Plant 2. Facility identification code: CO 123-0049 3. Stack identification code: Flare 3a. Construction Permit Number: N/A 4. Exhausting Unit(s), use Unit identification code from appropriate Form(s) 2000-300, 301, 302, 303, 304, 305, 306, 307 2000-300 2000-301 2000-304 2000-302 2000-303 2000-305 2000-306 Flare 2000-307 5. Stack identified on the plot plan required on Form 2000-101 El 6. Indicate by checking: ® This stack has an actual exhaust point. The parameters are entered in Items 7-13. ❑ This stack serves to identify fugitive emissions. Skip items 7-13. Go to next form. ❑ When stack height Good Engineering Practice (GEP) exceeds 65 meters (Colorado Air Quality Reg 3.A.VIII.D) data entry is required for Item 7. 7. Discharge height above ground level: 60 (feet) 8. i'" Inside dimensions at outlet (check one and complete): ❑ Circular _(feet) 9. Velocity Exhaust flow rate: (FPS) ❑ Calculated ❑ Stack Test Rectangular length (feet) width (feet) 10.`"e Exhaust gas temperature (normal) Ambient ' (°F) 11. Does process modify ambient air moisture content?` ❑ Yes 0 If "Yes", exhaust gas moisture content: Normal percent Horizontal Maximum ?`-percent- - 12. Exhaust gas discharge direction: ® Up Down 13. " Is this stack equipped with a rainhat or any obstruction to the free flow of the exhaust gases from the stack? ❑ Yes ❑ No *****Complete the appropriate Air Permit Application Forms(s) 2000-300, 301, 302, 303, 304, ***** 305, 306, or 307 for each Unit exhausting through this stack. Jpc,a,,,,5 ,,,,. npp..,,u..u., Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Roggen Natural Gas Processing Plant 3. Stack identification code: Flare 2. Facility identification code: CO 123-0049 4. Process (Unit) code: Flare 5. Unit description: Plant Emergency Flare 6. Indicate the control technology status. ❑ Uncontrolled ® Controlled If the process is controlled, enter the control device code(s) from the appropriate form(s): 2000-400 Flare 2000-401 2000-402 2000-403 2000-404 2000-405 2000-406 2000-407 Actual annual process rates for 19 8. Date first placed in service: < 2010 Date of last modification: 2015 9. Normal operating schedule: 24 hrs./day 7 days/wk. 8760 hours/yr. 10. Describe this process (please attach a flow diagram of the process). Attached? ❑ Emergency flare with a DRE of 95% to handle maintenance and malfunction emissions. 11. List the types and amounts of raw materials used in this process: Material Storage/material handling process Actual usage Units Maximum usage Units Clean-up solvents Other (specify) 12. List the types and amounts of finished products: Material Storage/material handling process Actual _ Units : amount produced Maximum Units amount produced 13. Process fuel usage: Type of fuel Maximum heat input to process million BTU/hr. Actual usage Units ` Maximum usage Units Waste Gas 4.73 33.68 MMscf/yr Purge Gas 0.27 2.10 MMscf/yr Pilot 0.17 1.31 MMscf/yr 14. Describe any fugitive emissions associated with this process, such as outdoor storage piles, unpaved roads, open conveyors, etc.: ***** For this emissions unit, identify the method(s) of compliance demonstration by completing Form 2000-500, ***** DESCRIPTION OF METHODS USED FOR DETERMINING COMPLIANCE. Attach Form 2000-500 and its attachment(s) to this form. ***** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit. ***** Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE Rev 06-95 iI 1. Facility name: Roggen Natural Gas Processing Plant 2. Facility identification code: CO 123-0049 3. Stack identification code: Flare 4. Unit identification code: Flare 5. Control device code: 6. Manufacturer and model number: John Zink, Kaldair P-684 7. Date placed in service: < 2010 Date of last modification: 2015 8. Describe the device being used. Attach a diagram of the system. Emergency Flare with a DRE of 95% to handle maintenance and malfunction emissions. 9. List the pollutants to be controlled by this equipment and the expected control efficiency for each pollutant on the table below. ❑ Documentation attached EITHER the outlet pollutant concentration OR the control efficiency must be provided. Pollutant Inlet pollutant concentration gr/acf pprnv Emission capture efficiency (%) Outlet pollutant concentration gr/acf ppmv Control Efficiency (%) Volatile Organic Compounds HAPs 95% 95% 10. Discuss how the collected material will be handled for reuse or disposal. 11. Prepare a malfunction prevention and abatement plan for this pollution control system. The plan does not have to be submitted with the application. It is suggested the plan include, but not be limited to the following: a. Identification of the individual(s), by title, responsible for inspecting, maintaining and repairing this device. b. Operation variables such as temperature that will be monitored in order to detect a malfunction or breakthrough, the correct operating range of these variables, and a detailed description of monitoring or surveillance procedures that will be used to show compliance. c. What type of monitoring equipment will be provided (temperature sensors, pressure sensors, CEMs). d. An inspection schedule and items or conditions that will be inspected. f. Where is this plan available for review? Hello