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Home My WebLink AboutKRU CPF 2 / Conoco Phillips STATE OF ALASKA AOGCC GAS DISPOSITION FILES YEAR: 2004 FACILITY: KRU CPF 2 OPERATOR: CONOCOPHILLIPS ALASKA OIL AND GAS CONSERV A TION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Facility CENTRAL PROCESSING FACILITY #2 Operator CONOCOPHILLIPS ALASKA, INC. Disposition Volume MCF* 1. Sold 26.963 2. Reinjected 5,802,589 3. Flared or vented less than I hour 38,189 3,457 5. Pilot and Purge 25,986 6. Used forIease operations Fuel 756,293 7. Other TOTAL items I - 7 6.653.417 8. NGL gas equivalent produced 9. Purchased gas 10. Transferred from: PBU CGF (LSEOR NGLS) CPFI 908.952 1,126,102 II. Transferred to: Remarks: Reinjected vol does not include volumes of PBU NGLS aquired for LSEOR reflected on line 10 or Na tha used in SSEOR meter #20 I I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: 11tf.J,tJ..~ Title: Supervisor ó2/;Jo. '() FOnTI 10-422 (Revised 4/95) Field(s) KUPARUK RIVER UNIT MonthlY ear of Disposition *Indicate contribution of each pool to total. Pool Name KUPARUK RIVER UNIT KUPARUK RIVER UNIT MELTWATER /' KUPARUK RIVER UNITTABASCO KUPARUK RIVER UNIT TARN o Official Use Only--Flaring Authorization> I hr. 1. Safety o 2. Lease Use o o Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60 degrees F. Report due by the 20th ofthe month following the month of disposition. Authority 20 AAC 25.235. 1/04 Code Percent 490100 89.41% 490140 3.35% 490160 0.10% 490165 7.14% '3 467 MCF 3/t-- MCF MCF Date DATE TIME PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE CONOCOPHILLlPS ALASKA, INC. CONSERVATION ORDER NO. 219 GAS FLARING OR VENTING INCIDENTS CPF #2 JANUARY 2004 VOLUME MCF DESCRIPTION OF INCIDENTS & CAUSE FLARING OR VENTING EVENTS GREATER THAN 1 HOUR 1/15/2004 0324-0506 1/18/2004 1718-1821 1/23/2004 0855-1008 TOTAL OVER 1 HOUR 524 1,370 1,563 3,457 PLANNED EVENTS LESS THAN 1 HOUR Flare or Vent Volumes: Greater than 1 hour Less than 1 hour Continuous Assist Pilot and Purge TOTALFLAREDNENTED 3,457 38,189 o 25.986 67,632 Tie-line pressure high Excessive inlet gas rates into facility; process upset in gas section of facility Process upset in gas section of facility; A GLC trip on high 1st stage disc pressure; shut in 2X-13 and choked back 2V-16 and T-12 which reduced gas rate by - 5mmscf Unplanned Reduced inlet gas rates; lowered gas, lower temp. Unplanned Started/restarted T/C # C2 101A; reduced inlet gas rates; stabilized facility process and operation Unplanned Started/restarted T/C # C2-101A; reduced/increased inlet gas rates .. .r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 0290000022 2. Facility Name CENTRAL PROCESSING FACILITY #2 3. Field 4. Operator 5.Month/Year of Disposition KUP ARUK RIVER UNIT CONOCOPHILLIPS ALASKA, INC. 2/04 Disposition Volume MCF* 20. For production from multiple pools. list contribution of each /Jool as a /Jercent of Total Volume. 6. Sold 30.381 Pool Name Code Percent 7. Reinjected 5,851,660 KUPARUK RIVER UNIT 490100 89.41% 8. Flared or vented less than 1 hour 22,511 KUPARUK RIVER UNIT MELTWATER 490140 3.35% / 9. Flared or vented greater than 1 hour 4,593 '" KUPARUK RIVER UNIT TABASCO 490160 0.10% (SuDDlemental reoort reauired--See 20 AAC 25.235) 10. Pilot and Purge 21,872 KUPARUK RIVER UNIT TARN 490165 7.14% 11. Used for lease ooerations A~~el 764.00g ist 12. Other 0 Official Use Only AUt!10nzatlon > 1 nr: Safety 4¡5'CB MCF 13. TOTAL VOLUME (ITEMS 6-12) 6,695,026 Lease Use MCF 14. NGL I!as eauivalent nroduced 0 Conservation MCF 15. Purchased gas 0 Waste: .... ..... " MCF 16. Transferred from: PBU CGF (LSEOR NGLS) 876.917 I /) f--/~/? 41J7./ f- CPFl 678,164 C YI';IV / Commissioner Date 17. Transferred to: 0 Note: All volumes must be corrected to pressure of J 4. 65 psia 18. Remarks: Reinjected vol does not include volumes ofPBU NGLS aquired for LSEOR and to a temperature of 60 degrees F. Report due by the 20th reflected on line 10 or Naptha used in SSEORmeter #201 60 degrees F. Report due by the 20th of the month following I hereby certify that the foregoing is true and correct to the best of my knowledge. the month of disposition. ~~þh~ Authority 20 MC 25.235. Signature: Title: SUDervisor Printed Name: ~.e .(1Or,.J¡:tU S -/!.r IJ. /),U Phone: 263-4121 Date gill/of FOnTI 10-422 evised 1/2004 I Submit in Du licate 36'L (R p .. CONOCOPHILLlPS ALASKA, INC. CONSERVATION ORDER NO. 219 GAS FLARING OR VENTING INCIDENTS CPF #2 FEBRUARY 2004 DATE TIME VOLUME MCF DESCRIPTION OF INCIDENTS & CAUSE PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE FLARING OR VENTING EVENTS GREATER THAN 1 HOUR 2/2/2004 2057-2232 TOTAL OVER 1 HOUR PLANNED EVENTS LESS THAN 1 HOUR Flare or Vent Volumes: Greater than 1 hour Less than 1 hour Continuous Assist Pilot and Purge TOTALFLAREDfVENTED 4,593 4,593 4,593 22,511 o 21.872 48,976 Electrical/instrumentation malfunction at other facility (T&D); process upset in Gas section of facility; loadshed due to Frame 6 trip Unplanned Started/restarted T/C; Reduced/increased inlet gas rates; restart C2-104A,B,C; also restarted C2-1 01 B 1. Facility Number 0290000022 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 2. Facility Name CENTRAL PROCESSING FACILITY #2 3. Field 4. Operator 5.Month/Year of Disposition KUP ARUK RIVER UNIT CONOCOPHll..LIPS ALASKA, INC. 3/04 Disposition Volume MCF* 20. For production from multiple pools, list contribution of each /Jool as a percent of Total Volume. 6. Sold 33.210 Pool Name Code Percent 7. Reinjected 6,231,646 KUPARUK RIVER UNIT 490100 84.37% 8. Flared or vented less than 1 hour 37,792 KUPARUK RIVER UNIT MELTWATER 490140 5.86% ,.. / 9. Flared or vented greater than 1 hour 3,625 KUPARUK RIVER UNIT T ABASCO 490160 0.08% (SuDPlemental reDort reauired--See 20 AAC 25.235) 10. Pilot and Purge 25,153 KUPARUK RIVER UNIT TARN 490165 9.69% 11. Used for lease operations A~~;~ 776.27~ 12. Other 0 Official Use Only AUthOriZatIOn> 1 hr: Safety 3,þz,5' MCF 13. TOTAL VOLUME (ITEMS 6-12) 7,107,704 Lease Use MCF 14. NGL I!as eauivalent produced 0 - / \ Cof¡servation MCF 15. Purchased gas 0 Waste: ~ / MCF / I't , rlrlðt/ 16. Transferred from: PBU CGF (LSEOR NGLS) 908.323 . CPFl 733,027 1J¡ I \ ), ) Com issionJ r ...... ./ Date 17. Transferred to: 0 ---r / \ - f I Note: All vdiJg¡fes mu~orrected to pressure of 14. 65 psia 18. Remarks: Reinjected vol does not include volumes ofPBU NGLS aquired for LSEOR and to a temperature of 60 degreesF. Report due by the 20th reflected on line 16 or Naptha used in SSEOR meter #20 I of the month following the month of disposition. I hereby certifY that the foregoing is true and correct to the best of my knowledge. Signature:~ ~ r /L~ Authority 20 AAC 25.235. Title: Supervisor Printed Name: $ .¡2. E'bl.A! I'hZM .w Ai.)) ¡/~ Phone: 263-4121 Date ~Í-ð/O <l- . . Form 10-422 (RevIsed 1/2004) 3ße- Submit m Duphcate DATE TIME PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE CONOCOPHILLlPS ALASKA, INC. CONSERVATION ORDER NO. 219 GAS FLARING OR VENTING INCIDENTS CPF #2 MARCH 2004 VOLUME MCF DESCRIPTION OF INCIDENTS & CAUSE FLARING OR VENTING EVENTS GREATER THAN 1 HOUR 3/8/2004 12:34-13:35 3/14/2004 01 :33-02:42 TOTAL OVER 1 HOUR 672 2,953 3,625 PLANNED EVENTS LESS THAN 1 HOUR Flare or Vent Volumes: Greater than 1 hour Less than 1 hour Continuous Assist Pilot and Purge TOTALFLAREDNENTED 3,625 37,792 o 25.153 66,570 Facility maintenance D GLC restart of fuel gas stripping unit after frame 6 repaired Excessive/lnsufficient inlet gas rates into facility Process upset in GAS section of facility unplanned Reduced/increaded inlet gas rate; stabilized facility process and operation unplanned Reduced/increased inlet gas rate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 0290000022 2. Facility Name CENTRAL PROCESSING FACILITY #2 3. Field 4. Operator 5.MonthNear of Disposition KUP ARUK RIVER UNIT CONOCOPHILLIPS ALASKA, INC. 4/04 Volume MCF* Disposition 6. Sold 31.123 5,673,888 9,931 14,757 21.710 Fuel 716.061 A' 0 6,467,470 0 0 793.712 567,502 0 7. Reinjected 8. Flared or vented less than 1 hour 10. Pilot and Purge 11. Used for lease oDerations 12. Other 13. TOTAL VOLUME (ITEMS 6-12) 14. NGL!!as eauivalent Droduced 15. Purchased gas 16. Transferred from: PBU CGF (LSEOR NGLS) CPFl 17. Transferred to: 18. Remarks: Reinjected vol does not include volumes ofPBU NGLS aquired for LSEOR reflected on line 16 or Na tha used in SSEOR meter #201 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: 11¡J.1/ Å. riP- Printed Name: Af()(,1 J:5 tJ(~ Form 10-422 (Revised 1/2004) Phone: 263-4121 Date Pool Name Code Percent KUP ARUK RIVER UNIT 490100 82.13% KUPARUK RIVER UNIT MEL TW A TER 490140 6.04% KUPARUK RIVER UNIT TABASCO 490160 0.09% KUPARUK RIVER UNIT TARN 490165 11.74% Official Use Only Authorization> I hr: \4/761 MCF SBr'- Safety Lease Use MCF MCF Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60 degrees F. Report due by the 20th of the month following the month of disposition. Authority 20 MC 25.235. Submit in Duplicate DATE TIME CONOCOPHILLIPS ALASKA, INC. CONSERVATION ORDER NO. 219 GAS FLARING OR VENTING INCIDENTS CPF #2 MARCH 2004 VOLUME MCF DESCRIPTION OF INCIDENTS & CAUSE PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE FLARING OR VENTING EVENTS GREATER THAN 1 HOUR 4/3/2004 4/3/2004 4/4/2004 4/4/2004 0834-1025 1916-2305 0130-0300 0937-1316 TOTAL OVER 1 HOUR 3,133 7,705 602 3317 14,757 PLANNED EVENTS LESS THAN 1 HOUR Flare or Vent Volumes: Greater than 1 hour Less than 1 hour 14,757 9,931 Excessive/insufficient inlet gas rates into facility; Faulty shutdown on Hi Pressure; Mechanical difficulty/ Crude surge drum level control bridle Excessive/insufficient inlet gas rates into facility; Facility maintenance; Gas processing equipment failed to start during Facility re-start due to mechanical difficulties Electrical/instrumentation malfunction; excessive/ insufficient inlet gas rates into facility; liquid condensate purged from the gas train; difficulty with backflow switch causing a gas train to depressure T/C SD due to high exhaust temperature; electrical! instrumentation malfunction; excessive/insufficient inlet gas rates into facility; process upset; facility maintenance; facility upset due to process flow restrictions and facility gas processing equipment instrument problems Unplanned Compressor/train depressured; reduced/increased inlet gas rates; repaired equipment difficulties-- bridle repaired Unplanned Compressor/train depressured; reduced/increased inlet gas rates; repaired equipment difficulties with turbine hydraulics; depressured gas train/reduced inlet gas rates; repaired broken hydraulic system Unplanned Compressor/train depressured; corrected E&I fluctua- tion/failure; stabilized facility process and operation; began reducing gas inlet rates/repaired faulty switch and restarted machine Unplanned Started/restarted TIC # NGL Pump; Compressor/train depressured; reduced/increased inlet gas rates; corrected E&I fluctuation/failure; repaired equipment difficulties with ROV; depressured gas train/reduced inlet gas rates/ repaired instrumentation system, started Facility Equipment CPF-2 Shutdown and Associated Flaring Jim, We experienced four flaring events over the weekend at Kuparuk's CPF-2 Plant. Flaring reports were submitted, but I wanted to supply you with some additional information on the cause of each event and the steps we took to mitigate flaring. A summary is provided below. Please feel free to contact me if you have any questions or need additional information concerning these events. Leigh On Saturday, April 3rd, CPF2 experienced a plant shutdown at 9:05AM. This shutdown along with the subsequent restart of the plant the next day caused 4 separate flaring events to occur. These events are reviewed in chronological order below. The initial plant shutdown and flaring event occurred at 08:34AM and was the result of the following events: * Gas and liquid slugs from the wells/gathering lines were causing pressure swings in the Primary Separator. These pressure swings eventually caused first one Gas Lift Compressor, and then the other three Gas Lift Compressors to trip off line. * While attempting to restart the plant, a mechanical malfunction was found in the Crude Surge Drum level control system, which necessitated a full plant shutdown to isolate and fix the problem. At this point all wells were shut-in, and the plant was shutdown. Because all pumps, and compressors, including the vapor recovery unit on the Divert Tanks were shutdown, the flare remained high for safety reasons. Gas evolving from the crude trapped in the inlet header had to be vented to prevent over pressuring of plant piping. This flaring event lasted 1:51 hours with a volume of 3,133 MSCF of gas burned. The second flaring event occurred because of the CPF2 Facility restart, which began at approximately 18:30 hours on 4/3/04. Because of the subsequent hard shutdown of the plant, numerous minor mechanical difficulties were encountered as the operators brought the plant back on line. Because of the winter temperatures, lines had cooled and liquids were dropping out in the vessels in larger volumes than could be handled without multiple equipment shutdowns, and the subsequent venting and purging of gas to the flare. Reduced compression capacity due to the damaged STV Compressor caused high flaring rates to continue. Wells were once again shut-in to minimize and stop the flaring. Warm gas from the other CPFs (Production Facilities) was brought into the plant via a connecting pipeline as we attempted to get gas moving through the plant to warm up the cooled process lines, and purge the condensate from the gas plant piping .This initial start-up flaring event lasted 03:49 hrs and resulted in flaring 7,705 MSCF of gas. The 3rd flaring incident occurred at 01:30 on 4/4, and was shortly after the incident described above. This flaring incident was a result of additional mechanical difficulties, which caused the compressor trains to depressure and flare. Additionally, problems continued as the cold crude moved from the gathering lines into the plant causing liquids/condensate to drop out in the gas process piping. various process changes were made during the Facility re-start in order to minimize flaring without compromising the integrity of the Facility and/or gas handling equipment. Enough produced crude flow had to be brought on to stabilize the plant and get the shipping pumps up and running or the crude lines would have frozen. This event lasted 01:30 hrs and had a volume of 602.5 MSCF of gas flared. The final flare event reported on 4/4/04 at 09:37 was a result of bringing on the NGL blending and injection process, and the continued instability of the plant due to gas/liquid slugging from the wells. NGLs were brought into the plant, but had to be diverted to the Oil Separators due to mechanical and instrument problems with the injection pump. Inlet gas rates were reduced and multiple wells were shut-in, but flashing NGLs caused high gas off the Oil Separators. Because of the erratic gas rates into the plant we had difficulties with gas condensates and hydrates freezing piping in the coolers, backing up the gas flow and knocking compressors off line. Incoming oil and gas fluid streams were lof2 4/7/2004 11 :55 AM CPF-2 Shutdown and Associated Flaring reduced to slow flaring. Severe Plant swings occurred and had to be addressed during this time period to prevent larger flaring events and complete facility shutdown. As the wells stabilized and inlet gas/fluid swings from Drill-Sites were reduced, the equipment was able to stay on line and the flaring stopped. This flaring event lasted 03:39 hrs. and resulted in 21,773 MSCF of gas being flared. The severity of the flaring events was due to the unplanned shutdown and the delayed restart of the facility during winter ambient conditions. Leigh McDaniel and Jeff Smith Senior Field Environmental Coordinator - Kuparuk (907) 659-7242 Phone (907) 659-7712 Fax 20f2 4/7/2004 11 :55 AM RE: CPF-2 Shutdown and Associated Flaring Jim, Over the weekend, ConocoPhillips Alaska, Inc. conducted an incident investigation of the CPF-2 plant shutdown and further clarified the sequence of events surrounding the associated flaring. The revised summary expands on the information originally submitted to you on April 7th and provides additional detail on the causes and corrective actions taken to minimize flaring. Please call if you have any questions or require additional information. Leigh On Saturday, April 3rd, CPF2 experienced a plant shutdown at 9:05AM. This shutdown along with the subsequent restart of the plant the next day caused 4 separate flaring events to occur. These events are reviewed in chronological order below. The initial plant shutdown and flaring event occurred at 08:34AM and was the result of the following events: * Gas and liquid slugs from the wells/gathering lines were causing pressure swings in the Primary Separator. These pressure swings eventually caused first one Gas Lift Compressor, and then the other three Gas Lift Compressors to trip off line. * While attempting to restart the plant, a mechanical malfunction was found in the Crude Surge Drum level control system, which necessitated a full plant shutdown to isolate and fix the problem. At this point all wells were shut-in, and the plant was shutdown. Because all pumps, and compressors, including the vapor recovery unit on the Divert Tanks were shutdown, the flare remained high for safety reasons. Gas evolving from the crude trapped in the inlet header had to be vented to prevent over pressuring of plant piping. This flaring event lasted 1:51 hours with a volume of 3,133 MSCF of gas burned. The second flaring event occurred because of the CPF2 Facility restart, which began at approximately 18:30 hours on 4/3/04. Because of the subsequent hard shutdown of the plant, numerous minor mechanical difficulties were encountered as the operators brought the plant back on line. Wells were not brought back on immediately. The trapped, pressure in the inlet gathering lines was initially used to bring crude and gas into the plant. Because of the winter temperatures, lines had cooled and liquids were dropping out in the vessels in larger volumes than could be handled without multiple equipment shutdowns, and the subsequent venting and purging of gas to the flare. Reduced compression capacity due to the damaged STV Compressor caused high flaring rates to continue. The A STV compressor motor was damaged due to high amps from overloading the motor. An investigation is ongoing into the failure, but the preliminary finding is that the protective relay failed to trip and protect the motor from overloading during the plant upset. Warm gas from the other CPFs (Production Facilities) was brought into the plant via a connecting pipeline as we attempted to get gas moving through the plant to warm up the cooled process lines, and purge the condensate from the gas plant piping. Production wells which were needed to provide enough feed to the plant to stabilize operations and keep the plant pumps and compressors fed, were slowly brought back on line, one well at a time, starting around 9:30PM. Only 8 wells were brought into the plant prior to stabilizing operations and ending the flaring event. This initial start-up flaring event lasted 03:49 hrs and resulted in flaring 7,709 MSCF of gas. The 3rd flaring incident occurred at 01:30 on 4/4, and was shortly after the incident described above. This flaring incident was a result of additional mechanical difficulties, which caused the compressor trains to depressure and flare. Additionally, problems continued as the cold crude moved from the gathering lines into the plant causing liquids/condensate to drop out in the gas process piping. Various process changes were made during the Facility re-start in order to minimize flaring without compromising the integrity of the Facility and/or gas handling equipment. Enough produced crude flow had to be brought on to stabilize the plant and get the shipping pumps up and running or the crude lof3 4/12/20042:34 PM RE: CPF-2 Shutdown and Associated Flaring lines would have frozen. This event lasted 01:30 hrs and had a volume of 602.5 MSCF of gas flared. The final flare event reported on 4/4/04 at 09:37 was a result of bringing on the NGL blending and injection process, in an attempt to remove the indigenous NGLs from the plant streams, and reduce load on the remaining STV compressor. It was felt that this would provide more room to react as instability continued in the plant processes due to gas/liquid slugging from the wells. The indigenous NGLs knocked out in the plant need to have supplemental NGLs added in order to provide enough volume to run the MI injection pumps. The Prudhoe NGL line was pressured up in preparation for blending NGLs. There were difficulties preventing the startup of the skid, so the NGLs were blocked in. Although the NGLs were blocked in and not fed to the plant, flaring started to occur, due to the thermal relief on the inlet NGL line lifting and venting to flare. NGLs have a very high thermal expansion coefficient and when the cold pipeline NGLs warmed, as they sat trapped in the part of the pipeline that was in the plant module, they began to gas off and the thermal relief had to lift and relief pressure to prevent an overpressure of the pipeline. As this continued, inlet gas rates were reduced and multiple wells were shut-in in an attempt to prevent and minimize flaring. Additional difficulties with getting the main NGL pump up, prevented us from lowering the NGL pipeline pressure quickly, and reducing the flare. Because of the erratic gas rates into the plant we continued to have difficulties with gas condensates and hydrates freezing piping in the coolers, backing up the gas flow and knocking compressors off line. Incoming oil and gas fluid streams were reduced to slow flaring. Severe Plant swings occurred and had to be addressed during this time period to prevent larger flaring events and complete facility shutdown. As the wells stabilized and inlet gas/fluid swings from Drill-Sites were reduced, the equipment was able to stay on line and the flaring stopped. This flaring event lasted 03:39 hrs. and resulted in 21,773 MSCF of gas being flared. The severity of the flaring events was due to the unplanned shutdown and the delayed restart of the facility during winter ambient conditions. Leigh Leigh McDaniel and Jeff Smith Senior Field Environmental Coordinator - Kuparuk (907) 659-7242 Phone (907) 659-7712 Fax -----Original Message----- From: NSK Env proj Sent: Wednesday, April 07, 2004 10:11 AM To: Jim Regg (E-mail) Cc: Steve McMains (E-mail); CPF2 Prod Supv; Wheatall, Michael; Freswick, June; NS HSE Supv; CPF2 Fac Engr Subject: CPF-2 Shutdown and Associated Flaring Jim, We experienced four flaring events over the weekend at Kuparuk's CPF-2 Plant. Flaring reports were submitted, but I wanted to supply you with some additional information on the cause of each event and the steps we took to mitigate flaring. A summary is provided below. Please feel free to contact me if you have any questions or need additional information concerning these events. Leigh On Saturday, April 3rd, CPF2 experienced a plant shutdown at 9:05AM. This shutdown along with the subsequent restart of the plant the next day caused 4 separate flaring events to occur. These events are reviewed in chronological order below. The initial plant shutdown and flaring event occurred at 08:34AM and was the result of the following events: * Gas and liquid slugs from the wells/gathering lines were causing pressure swings in the Primary Separator. These pressure swings eventually caused first one Gas Lift Compressor, and then the other three Gas Lift Compressors to trip off line. * While attempting to restart the plant, a mechanical malfunction was found in the Crude Surge 2,of3 4/12/20042:34 PM RE: CPF-2 Shutdown and Associated Flaring Drum level control system, which necessitated a full plant shutdown to isolate and fix the problem.> At this point all wells were shut-in, and the plant was shutdown. Because all pumps, and compressors, including the vapor recovery unit on the Divert Tanks were shutdown, the flare remained high for safety reasons. Gas evolving from the crude trapped in the inlet header had to be vented to prevent over pressuring of plant piping. This flaring event lasted 1:51 hours with a volume of 3,133 MSCF of gas burned. The second flaring event occurred because of the CPF2 Facility restart, which began at approximately 18:30 hours on 4/3/04. Because of the subsequent hard shutdown of the plant, numerous minor mechanical difficulties were encountered as the operators brought the plant back on line. Because of the winter temperatures, lines had cooled and liquids were dropping out in the vessels in larger volumes than could be handled without multiple equipment shutdowns, and the subsequent venting and purging of gas to the flare. Reduced compression capacity due to the damaged STV Compressor caused high flaring rates to continue. Wells were once again shut-in to minimize and stop the flaring. Warm gas from the other CPFs (Production Facilities) was brought into the plant via a connecting pipeline as we attempted to get gas moving through the plant to warm up the cooled process lines, and purge the condensate from the gas plant piping .This initial start-up flaring event lasted 03:49 hrs and resulted in flaring 7,705 MSCF of gas. The 3rd flaring incident occurred at 01:30 on 4/4, and was shortly after the incident described above. This flaring incident was a result of additional mechanical difficulties, which caused the compressor trains to depressure and flare. Additionally, problems continued as the cold crude moved from the gathering lines into the plant causing liquids/condensate to drop out in the gas process piping. various process changes were made during the Facility re-start in order to minimize flaring without compromising the integrity of the Facility and/or gas handling equipment. Enough produced crude flow had to be brought on to stabilize the plant and get the shipping pumps up and running or the crude lines would have frozen. This event lasted 01:30 hrs and had a volume of 602.5 MSCF of gas flared. The final flare event reported on 4/4/04 at 09:37 was a result of bringing on the NGL blending and injection process, and the continued instability of the plant due to gas/liquid slugging from the wells. NGLs were brought into the plant, but had to be diverted to the Oil Separators due to mechanical and instrument problems with the injection pump. Inlet gas rates were reduced and multiple wells were shut-in, but flashing NGLs caused high gas off the oil Separators. Because of the erratic gas rates into the plant we had difficulties with gas condensates and hydrates freezing piping in the coolers, backing up the gas flow and knocking compressors off line. Incoming oil and gas fluid streams were reduced to slow flaring. Severe Plant swings occurred and had to be addressed during this time period to prevent larger flaring events and complete facility shutdown. As the wells stabilized and inlet gas/fluid swings from Drill-Sites were reduced, the equipment was able to stay on line and the flaring stopped. This flaring event lasted 03:39 hrs. and resulted in 21,773 MSCF of gas being flared. The severity of the flaring events was due to the unplanned shutdown and the delayed restart of the facility during winter ambient conditions. Leigh McDaniel and Jeff Smith Senior Field Environmental Coordinator - Kuparuk (907) 659-7242 Phone (907) 659-7712 Fax 3.of3 4/12/20042:34 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 0290000022 12. Facility Name 1 CENTRAL PROCESSING FACILITY #2 13. Field 14. Operator J5.Month/Year of Disposition IKUPARUK RIVER UNIT ICONOCOPHILLIPS ALASKA, INC. 5/04 Disposition Volume MCF* 6. Sold 35.425 7. Reinjected 5,386,495 8. Flared or vented less than 1 hour 2,209 9. Flared or vented greater than 1 hour 0 (Sunnlemental reDort reQuired--See 20 AAC 25.235) 10. Pilot and Purge 22,838 11. Used for lease operations Fuel 730.379 A~~i~t 0 12. Other 0 13. TOTAL VOLUME (ITEMS 6-12) 6,177,346 14. NGL gas eauivalent produced 0 15. Purchased gas 0 16. Transferred from: PBU CGF (LSEOR NGLS) 832.887 CPFl 812,005 17. Transferred to: 0 18. Remarks: Reinjected vol does not include volumes ofPBU NGLS aquired for LSEOR reflected on line 16 or Naptha used in SSEOR meter #201 I hereby certify that the foregoing is t@e and correct to the best of my knowledge. Signature: V7æU~ Title: Supervisor Printed Name: Noel Dike Phone: 263-4121 Date ~/t5Io¥ Form 10-422 (RevIsed 1/2004) 20. For production from multiple pools, list contribution of each /Jool as a ]I. rcent of Total Volume. Pool Name Code Percent KUPARUK RIVER UNIT 490100 79.29% KUPARUK RIVER UNIT MELTWATER 490140 5.88% KUPARUK RIVER UNIT TABASCO 490160 0.10% KUPARUK RIVER UNIT TARN 490165 14.73% OffieiaI Use Only Aumonzatton > 1 nr: Safety MCF Lease Use MCF Conservation MCF Waste: MCF Commissioner Date Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60 degrees F. Report due by the 20th of the month following the month of disposition. Authority 20 AAC 25.235. Submit in Duplicate CONOCOPHILLlPS ALASKA, INC. CONSERVATION ORDER NO. 219 GAS FLARING OR VENTING INCIDENTS CPF #2 MAY 2004 DATE TIME VOLUME MCF DESCRIPTION OF INCIDENTS & CAUSE PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE FLARING OR VENTING EVENTS GREATER THAN 1 HOUR TOTAL OVER 1 HOUR o PLANNED EVENTS LESS THAN 1 HOUR Flare or Vent Volumes: Greater than 1 hour Less than 1 hour Continuous Assist Pilot and Purge o 2,209 o 22,838 TOTALFLARED/VENTED 25,047 1. Facility Number 0290??oo22 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 2. Facility Name CENTRAL PROCESSING FACILITY #2 3. Field 4. Operator 5.MonthlYear of Disposition KUPARUK RIVER UNIT CONOCOPHILLIPS ALASKA, INC. 6/04 Disposition Volume MCF* 6. Sold 35.062 7. Reinjected 4,769,528 8. Flared or vented less than 1 hour 2,559 9. Flared or vented greater than 1 hour 0 (see inSb11ctions) 10. Pilot and Purge 20,066 11. Used for lease operations Fuel 659.564 (snecifv in Remarks) Assi~t 0 12. Other 0 (see insb11ctions) 13. TOTAL VOLUME (ITEMS 6-12) 5,486,779 14. NGL eas eauivalent 0 15. Purchased gas 0 16. Transferred from: PBU CGF lLSEOR NGLS) 817.346 CPFl 1,065,678 17. Transferred to (express as a negative #): 0 18. Remarks: Reinjected vol does not include volumes of PBU NGLS aquired for LSEOR reflected on line 16 or Naptha used in SSEOR meter #201 I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ,M_~~ ~6 Title: Supervisor Printed Name: Noel Dike Phone: 263-4121 Date 1//Q/o,/ Fonn 10-422 (RevIsed 4/2004) 20. For production from multiple pools, list contribution of each pool as a percent of Total Volume. Pool Pool Name Code Percent KUPARUK RIVER UNIT 490100 80.40% KUPARUK RIVER UNIT MELTWATER 490140 6.41% KUPARUK RIVER UNIT TABASCO 490160 0.16% KUPARUK RIVER UNIT TARN 490165 13.03% Official Use Only Authonzatlon > 1 hr: Safety MCF Lease Use MCF Conservation MCF Waste: MCF Commissioner Date Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60 degrees F. Authority 20 MC 25.235. Submit in Duplicate CONOCOPHILLlPS ALASKA, INC. CONSERVATION ORDER NO. 219 GAS FLARING OR VENTING INCIDENTS CPF #2 JUNE 2004 DATE TIME VOLUME MCF DESCRIPTION OF INCIDENTS & CAUSE PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE FLARING OR VENTING EVENTS GREATER THAN 1 HOUR TOTAL OVER 1 HOUR o PLANNED EVENTS LESS THAN 1 HOUR Flare or Vent Volumes: Greater than 1 hour Less than 1 hour Continuous Assist Pilot and Purge o 2,559 o 20.066 TOTALFLAREDNENTED 22,625 CPF-2 Flare - Flow Element Damaged Jack, This e-mail is intended to provide supplemental information to the Permit Deviation Report I faxed today for ConocoPhillips Alaska, Inc. (CPAI) CPF-2 Permit No. 273TVP01. Yesterday, the flow element on the low flow Kaldair flare at CPF-2 (Source No. 31, Tag No. H-KM01) shorted out during calibration. As a result, the facility cannot measure or report low flow lease use gas for this flare until the element is replaced. Flare events greater than 1,000 mscf are still being measured and reported via an alternate device ranged for higher flow rates. A replacement part has been ordered and is expected to arrive in about a week. A copy of the permit deviation notification will be included in the Third Quarter Facility Operating Report. If you have any questions or require additional information, please do not hesitate to contact me. Leigh Leigh McDaniel and Jeff Smith Senior Field Environmental Coordinator - Kuparuk (907) 659-7242 Phone (907) 659-7712 Fax t of 1 7/6/2004 9:24 AM Update: CPF-2 Flare - Flow Element Damaged Jack - we received an update from the flow element manufacturer and are looking at two weeks for a new part. The facility also tested the high flow meter and found it does not engage until 40 mscf. We are currently estimating our daily consumption of low flow lease use gas based on average historical use. Please call if you have any questions or require additional information. Leigh Leigh McDaniel and Jeff Smith Senior Field Environmental Coordinator - Kuparuk (907) 659-7242 Phone (907) 659-7712 Fax -----Original Message----- From: NSK Env proj Sent: Tuesday, July 06, 2004 9:09 AM To: Jack Coutts (E-mail) Cc: Steve McMains (E-mail) ¡ Freswick, June¡ Jim Regg (E-mail) ¡ CPF2 Prod SUPV¡ NS HSE SUPV¡ Poteet, Randy¡ Wheatall, Michael Subject: CPF-2 Flare - Flow Element Damaged Jack, This e-mail is intended to provide supplemental information to the Permit Deviation Report I faxed today for ConocoPhillips Alaska, Inc. (CPAI) CPF-2 Permit No. 273TVP01. Yesterday, the flow element on the low flow Kaldair flare at CPF-2 (Source No. 31, Tag No. H-KM01) shorted out during calibration. As a result, the facility cannot measure or report low flow lease use gas for this flare until the element is replaced. Flare events greater than 1,000 mscf are still being measured and reported via an alternate device ranged for higher flow rates. A replacement part has been ordered and is expected to arrive in about a week. A copy of the permit deviation notification will be included in the Third Quarter Facility Operating Report. If you have any questions or require additional information, please do not hesitate to contact me. Leigh Leigh McDaniel and Jeff Smith Senior Field Environmental Coordinator - Kuparuk (907) 659-7242 Phone (907) 659-7712 Fax 1 of I 7/7/2004 10:40 AM Rß: Update: CPF-2 Flare - Flow Element Damaged Jack - Correction, our high flow meter registers greater than 40,000 mscf. Leigh McDaniel and Jeff Smith Senior Field Environmental Coordinator - Kuparuk (907) 659-7242 Phone (907) 659-7712 Fax -----Original Message----- From: NSK Env proj Sent: Wednesday, July 07, 2004 10:18 AM To: 'Jack Coutts (E-mail)' Cc: 'Steve McMains (E-mail) '; Freswick, June; 'Jim Regg (E-mail) '; CPF2 Prod Supv; NS HSE Supv; Poteet, Randy; Wheatall, Michael Subject: Update: CPF-2 Flare - Flow Element Damaged Jack - we received an update from the flow element manufacturer and are looking at two weeks for a new part. The facility also tested the high flow meter and found it does not engage until 40 mscf. We are currently estimating our daily consumption of low flow lease use gas based on average historical use. Please call if you have any questions or require additional information. Leigh Leigh McDaniel and Jeff Smith Senior Field Environmental Coordinator - Kuparuk (907) 659-7242 Phone (907) 659-7712 Fax -----Original Message----- From: NSK Env proj Sent: Tuesday, July 06, 2004 9:09 AM To: Jack Coutts (E-mail) Cc: Steve McMains (E-mail); Freswick, June; Jim Regg (E-mail); CPF2 Prod Supv; NS HSE Supv; Poteet, Randy; Wheatall, Michael Subject: CPF-2 Flare - Flow Element Damaged Jack, This e-mail is intended to provide supplemental information to the Permit Deviation Report I faxed today for ConocoPhillips Alaska, Inc. (CPAI) CPF-2 Permit No. 273TVP01. Yesterday, the flow element on the low flow Kaldair flare at CPF-2 (Source No. 31, Tag No. H-KM01) shorted out during calibration. As a result, the facility cannot measure or report low flow lease use gas for this flare until the element is replaced. Flare events greater than 1,000 mscf are still being measured and reported via an alternate device ranged for higher flow rates. lof2 . 7/7/2004 10:40 AM RE: Update: CPF-2 Flare - Flow Element Damaged A replacement part has been ordered and is expected to arrive in about a week. A copy of the permit deviation notification will be included in the Third Quarter Facility Operating Report. If you have any questions or require additional information, please do not hesitate to contact me. Leigh Leigh McDaniel and Jeff Smith Senior Field Environmental Coordinator - Kuparuk (907) 659-7242 Phone (907) 659-7712 Fax 2 óf2 . 7/7/2004 10:40 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 0290000022 2. Facility Name CENTRAL PROCESSING FACILITY #2 3. Field 4. Operator 5.MonthlYear of Disposition KUP ARUK RIVER UNIT CONOCOPHILLIPS ALASKA, INC. 7/04 Disposition Volume MCF* 6. Sold 31.045 7. Reinjected 4,655,763 8. Flared or vented less than 1 hour 6,438 9. Flared or vented greater than 1 hour 1,362 ./ (see instructions) 10. Pilot and Purge 7,021 11. Used for lease operations A Fuel 681.61~ (soecifv in Remarks) ,odd 12. Other 0 (see instructions) 13. TOTAL VOLUME (ITEMS 6-12) 5,383,239 14. NGL !!as eouivalent 0 15. Purchased gas 0 16. Transferred from: PBU CGF (LSEOR NGLS) 674.526 CPFl 995,330 17. Transferred to (express as a negative #): 0 18. Remarks: Reinjected vol does not include volumes ofPBU NGLS aquired for LSEOR reflected on line 16 or Navtha used in SSEOR meter #201 I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: -I7ø£~ Title: Supervisor Printed Name: Noel Dike Phone: 263-4121 Date FOnTI 10-422 (Revised 412004) . . 20. For production from multiple pools, list contribution of each ool as a percent of Total Volume. Pool Pool Name Code Percent KUPARUK RIVER UNIT 490100 79.61% KUPARUK RIVER UNIT MELTWATER 490140 6.26% KUPARUK RIVER UNIT TABASCO 490160 0.20% KUPARUK RIVER UNIT TARN 490165 13.93% Official Use Only AuthonzatlOn > 1 hr: I( 3"Z-MCF 5B~ Safety Lease Use MCF ation MCF MCF Waste: Date Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60 degrees F. Authority 20 AAC 25.235. Submit in Duplicate . . -, DATE TIME PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE CONOCOPHILLlPS ALASKA, INC. CONSERVATION ORDER NO. 219 GAS FLARING OR VENTING INCIDENTS CPF #2 JUNE 2004 VOLUME MCF DESCRIPTION OF INCIDENTS & CAUSE FLARING OR VENTING EVENTS GREATER THAN 1 HOUR 7/2/2004 1210-1331 7/5/2004 0355-0459 TOTAL OVER 1 HOUR PLANNED EVENTS LESS THAN 1 HOUR Flare or Vent Volumes: Greater than 1 hour Less than 1 hour Continuous Assist Pilot and Purge TOTAL FLAREDNENTED . 657 705 1,362 14,821 Seal oil system difficulties, high ambient temperatures, older gas lift machines have difficulties at higher ambient temperatures Electrical/instrumentation malfunction at other facility (T&O), Frame 6 SO @ CPF-1 -load-shed @ CPF-2 1,362 6,438 o 7.021 . Unplanned Reduced/increased inlet gas rates, stabilized facility process and operation, reduced IGOR (lift gas) , shut in 12 wells (37 MMSCFO, 7842 BOPO, 35000 BWPO) Unplanned Reduced/increased inlet gas rates, stabilized facility process and operation, shut in 20 wells (71.4 MMSCFO, 24015 BOPO & 45385 BWOPO) . Update on CPF-2 Flare Flow Element Jack, Jim and Steve, Just wanted to update you on the repair status of our CPF-2 Kaldair flare (Source No. 31, Tag No. H-KM01) flow element. The new flow element has been installed and is now fully operational. Please give me a call if you have any questions. Leigh Leigh McDaniel and Jeff Smith Senior Field Environmental Coordinator - Kuparuk (907) 659-7242 Phone (907) 659-7712 Fax 1 @fl 7/28/20047:49 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 0290000022 3. Field KUP ARUKRlVER UNIT 2. Facility Name CENTRAL PROCESSING FACILITY #2 Disposition Volume MCF* 6. Sold 29,957 ' 7. Reinjected 4,240,302 . 8. Flared or vented less than 1 hour 10. Pilot and Purge 15,538 Fuel Ass't 681,673 o o 12. Other (see instructions) 13. TOTAL VOLUME (ITEMS 6-12) 4,987,033 ' 14. NGL gas equivalent 15. Purchased gas 16. Transferred from: PBU CGF (LSEOR NGLS) CPFl 223,203 1,566,544 17. Transferred to (express as a negative #): 18. Remarks: Reinjected vol does not include volumes ofPBUNGLS aquired for LSEOR reflected on line 16 or N a tha used in SSEOR meter #201 I hereby certifY th the foregoing is true and correct to the best of my knowledge. Signature: m. ~ Title: Supervisor Printed Name: Noel Dike Form 10-422 (Revised 4/2004) ~ /17 / () L./ Phone: 263-4121 Date 9,854· Pool Name Percent KUP ARUK RIVER UNIT 490100 76.73% KUP ARUK RIVER UNIT MELTWATER 490140 8.36% KUPARUKRlVER UNIT TABASCO 490160 0.21% KUP ARUK RIVER UNIT TARN 490165 14.70% 9,709 o Official Use On! Authorization> 1 hr: Safety q, tOC:¡ MCF ::f8Þ Lease Use MCF Conservation MCF Waste: MCF o o Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60 degrees F. Authority 20 MC 25.235. Submit in Duplicate DATE TIME CONOCOPHILLlPS ALASKA, INC. CONSERVATION ORDER NO. 219 GAS FLARING OR VENTING INCIDENTS CPF #2 August 2004 VOLUME MCF DESCRIPTION OF INCIDENTS & CAUSE FLARING OR VENTING EVENTS GREATER THAN 1 HOUR Process upset in gas section of facility, high ambient temperatures and wind direction swap causing the turbine to go into surge conditions. 8/7/2004 18:24-19:51 8/15/2004 16:34-18:36 8/21/2004 22:41-00:08 TOTAL OVER 1 HOUR PLANNED EVENTS LESS THAN 1 HOUR Flare or Vent Volumes: Greater than 1 hour Less than 1 hour Continuous Assist Pilot and Purge TOTALFLAREDIVENTED 1 ,493 4,743 3,473 9,709 9,709 9,854 o 15,538 35,101 Electrical/instrumentation malfunction, process upset in gas section of facility, D GLC 2nd stage discharge RTD malfunction causing trip, C GLC went down because of gas surge created by trip of D GLC. Process upset in gas section of facility, facility shutdown on C GLC, A GLC SID on high vibration, C GLC tripped on 1 st stage compressor high discharge temp. TT-1035C2 was found to have a bad element. Inst. Tech swapped to spare element. A GLC shutdown while C was down on pinion radial thrust end high vibration. PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE Reducedlincreased inlet gas rates, shut in 19 wells with Unplanned total daily gas volume of 74 mmscfd. Started/restarted T/C # C GLC then D GLC, reduced/increased inlet gas rates, corrected E & I fluctuation/failure, C GLC restarted. Shut 2U, 2T, and 2W pads and several other individual production wells. Unplanned Repaired and restarted D GLC. Ambient temperature Started/restarted T/C# A and C, Reduced/increased gas inlet rates, shut in 26 production wells, restarted A GLC Unplanned on second attempt. Repaired and restarted C GLC. .--- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 0290000022 2. Facility Name CENTRAL PROCESSING FACIIlTY #2 3. Field 4. Operator 5.Month/Year of Disposition KUPARUKRNER UNIT CONOCOPHII.LIPS ALASKA, INC. 9/04 Disposition Volume MCF* 6. Sold 34,619 7. Reinjected 5,005,287 8. Flared or vented less than 1 hour 11,478 9. Flared or vented greater than 1 hour 0 (see instructions) 10. Pilot and Purge 14,935 11. Used for lease operations Fuel 688,273 (soecifV in Remarks) A~si~t 0 12. Other 0 (see instructions) 13. TOTAL VOLUME (ITEMS 6-12) 5,754,592 14. NGL gas equivalent 0 15. Purchased gas 0 16. Transferred from: PBU CGF (LSEOR NGLS) 791,002 CPFl 1,092,273 17. Transferred to (express as a negative #): 0 18. Remarks: Reinjected vol does not include volumes ofPBU NGLS aquired for LSEOR reflected on line 16 or Naptha used in SSEOR meter #201 I hereby certifY that the foregoing is true and correct to the best of my knowledge. Signature: Y7~ f/Lrk-<- Title: Supervisor Printed Name: Noel Dike Phone: 263-4121 Date /01/9/04- FOnTI 10-422 Revised 4 2004 , 20. For production from multiple pools, list contribution of each pool as a percent of Total Volume. Pool Pool Name Code Percent KUPARUKRIVER UNIT 490100 78.75% KUPARUKRNER UNIT MELTWATER 490140 8.31% KUP ARUKRNER UNIT TABASCO 490160 0.14% KUP ARUK RNER UNIT TARN 490165 12.80% Official Use Only Authorization> 1 hr: Safety MCF Lease Use MCF Conservation MCF Waste: MCF Commissioner Date Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60 degrees F. Authority 20 MC 25.235. Submit in Duplicate ~-...... CONOCOPHILLlPS ALASKA, INC. CONSERVATION ORDER NO. 219 GAS FLARING OR VENTING INCIDENTS CPF #2 September 2004 DATE TIME VOLUME MCF DESCRIPTION OF INCIDENTS & CAUSE PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE FLARING OR VENTING EVENTS GREATER THAN 1 HOUR TOTAL OVER 1 HOUR PLANNED EVENTS LESS THAN 1 HOUR Flare or Vent Volumes: Greater than 1 hour Less than 1 hour Continuous Assist Pilot and Purge TOTAL FLAREDNENTED o o 11,478 G 14.935 26,413 l' .... ."" . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number I~' Facility Name 3. Field I¡. Operator J5.MonthlYear of Disposition 0290000022 CENJRAL PROCESSING FACIU1Y #2 KUP ARUK RIVER UNIT CONOCOPHILLIPS ALASKA, INC. 10/04 Disposition Volume MCF* 20. For production from rrmltiple pools, list contribution of each pool as a percent of Total Volume. Pool 6. Sold 36,039 Pool Name Code Percent 7. Reinjected 5,159,331 KUP ARUK RIVER UNIT 490100 79.67% 8. Flared or vented less than 1 hour 3,527 KUPARUKRIVER UNIT MELTWATER 490140 6.47% 9. Flared or vented greater than 1 hour 0 KUP ARUK RIVER UNIT TABASCO 490160 0.18% (see instructions) 10. Pilot and Purge 16,639 KUP ARUK RIVER UNIT TARN 490165 13.68% 11. U~:d £'i:. lease op~~ations Fu~! 727,943 snec' in Remarks Assis 0 12. Other 0 Official Use Only (see instructions) Authorization> 1 hr: Safety MCF 13. TOTAL VOLUME (ITEMS 6-12) 5,943,479 Lease Use MCF 14. NGL gas equivalent 0 Conservation MCF 15. Purchased gas 0 Waste: MCF 16. Transferred from: PBU CGF (LSEOR NGLS) 784,554 CPFl 1,178,989 Commissioner Date 17. Transferred to (express as a negative #): 0 Note: All volumes rrmst be corrected to pressure of 14.65 psia 18. Remarks: Reinjected vol does not include volumes ofPBUNGLS aquired for LSEOR and to a temperature of 60 degrees F. reflected on line 16 or Naptha used in SSEOR meter #201 I hereby certifY that the foregoing is true and correct to the best of my knowledge. ~ ~ Authority 20 MC 25.235. Signature: ~ Title: Supervisor Printed Name: Noel Dike Phone: 263-4121 Date 1/ / I b /0 'I , . . Form 10-422 (RevIsed 4/2004) SubmIt In DuplIcate ..~ ,.. - CONOCOPHILLlPS ALASKA, INC. CONSERVATION ORDER NO. 219 GAS FLARING OR VENTING INCIDENTS CPF #2 October 2004 DATE TIME VOLUME MCF DESCRIPTION OF INCIDENTS & CAUSE PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE FLARING OR VENTING EVENTS GREATER THAN 1 HOUR TOTAL OVER 1 HOUR PLANNED EVENTS LESS THAN 1 HOUR Flare or Vent Volumes: Greater than 1 hour Less than 1 hour Continuous Assist Pilot and Purge TOTALFLAREDNENTED o o 3,527 o 16,639 20,166 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 3. Field 4. Operator 5.Month/YearofDisposition KUPARUK RIVER UNIT CONOCOPHILLIPS ALASKA, INC. 11/04 20. For production from multiple pools, list contribution of each 001 as a ercent of Total Volume. Pool Pool Name Code Percent 1. Facility Number 0290000022 2. Facility Name CENTRAL PROCESSING FACILITY #2 Disposition Volume MCF* 6. Sold 35.104 7. Reinjected 5,419,823 8. Flared or vented less than 1 hour 679 V' 9. Flared or vented greater than 1 hour 1,309 ... (see instructions) 10. Pilot and Pur,ge 14,674 11. Used for lease operations Fuel 714.64Õ (snecifv in Remarks) A~.i.t 12. Other 0 (see instrUctions) 13. TOTAL VOLUME (ITEMS 6-12) 6,186,231 14. NGL I!:as eauivalent 0 15. Purchased gas 0 16. Transferred from: PBU CGF (LSEOR NGLS) 736,292 CPFl 642,268 17. Transferred to (express as a negative f): 0 18. Remarks: Reinjected vol does not include volumes of PBU NGLS aquired for LSEOR reflected on line 16 or Navtha used in SSEOR meter #201 I hereby certify that the foregoing is,. true and correct to the best of my knowledge. Signature: f7 fJ1J! .... OJ....iUl.- Title: Suoervisor Printed Name: Noel Dike Phone: 263-4121 Date P-!17/°f Form 10-422 (Revtsed 4/2004) KUPARUK RIVER UNIT 490100 81.11% KUPARUK RIVER UNIT MELTWATER 490140 5.77% KUPARUK RIVER UNIT TABASCO 490160 0.25% KUPARUK RIVER UNIT TARN 490165 12.87% Official Use Only Autl1onzatton > 1m: / I 3CP¡ MCF Ú.Æte- MCF MCF Safety Lease Use /-/1- , Date Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60 degrees F. Authority 20 AAC25.235. Submit in Duplicate .,' DATE TIME CONOCOPHILLlPS ALASKA, INC. CONSERVATION ORDER NO. 219 GAS FLARING OR VENTING INCIDENTS CPF #2 November 2004 VOLUME MCF DESCRIPTION OF INCIDENTS & CAUSE PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE FLARING OR VENTING EVENTS GREATER THAN 1 HOUR Electrical/instrumentation malfunction at other facility. Frame 6 SID caused fast load shed. Unplanned Reduced/Increased inlet gas rates 11/24/2004 11:21-13:22 TOTAL OVER 1 HOUR 1,309 1,309 PLANNED EVENTS LESS THAN 1 HOUR Flare or Vent Volumes: Greater than 1 hour Less than 1 hour Continuous Assist Pilot and Purge TOTAL FLAREDNENTED 1,309 679 o 14.674 16,662 r 1. Facility Number 0290000022 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 2. Facility Name CENTRAL PROCESSING FACILITY #2 3. Field 4. Operator 5.MonthNearofDisposition KUPARUK RIVER UNIT CONOCOPH1LLIPS ALASKA, INC. 12/04 Disposition Volume MCF* 6. Sold 36.158 7. Reinjected 5,573,868 8. Flared or vented less than 1 hour 622 9. Flared or vented greater than 1 hour 0 (see instructions) 10. Pilot and Purge 13,755 11. Used for lease operations A~~~~ 750.33Õ (snecifv in Remarks) 12. Other 0 (see instructions) 13. TOTAL VOLUME (ITEMS 6-12) 6,374,738 14. NGL !ras eouivalent 0 15. Purchased gas 0 16. Transferred from: PBU CGF (LSEOR NGLS) 528.030 CPFl 684,811 17. Transferred to (express as a negative f): 0 18. Remarks: Reinjected vol does not include volumes of PBU NGLS aquired for LSEOR reflected on line 16 or N aptha used in SSEOR meter #201 I hereby cert~: foregoing is ~e and correct to the best of my knowledge. Signature: I ~~ Title: Supervisor " ,I n /05 Printed Name: Noel Dike Phone: 263-4121 Date Form 10-422 (Revised 4/2004) 20. For productionfrom multiple pools, list contribution of each pool as a percent of Total Volume. Pool Pool Name Code Percent KUPARUK RIVER UNIT 490100 83.00% KUPARUK RIVER UNIT MELTWATER 490140 6.29% KUPARUK RIVER UNIT TABASCO 490160 0.24% KUPARUK RIVER UNIT TARN 490165 10.47% Official Use Only AuthonzatJon > I hr: Safety MCF Lease Use MCF Conservation MCF Waste: MCF Commissioner Date Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 60 degrees F. Authority 20 MC 25.235. Submit in Duplicate CONOCOPHILLlPS ALASKA, INC. CONSERVATION ORDER NO. 219 GAS FLARING OR VENTING INCIDENTS CPF #2 December 2004 DATE TIME VOLUME MCF DESCRIPTION OF INCIDENTS & CAUSE PLANNED UNPLANNED ACTION TAKEN TO ELIMINATE CAUSE FLARING OR VENTING EVENTS GREATER THAN 1 HOUR TOTAL OVER 1 HOUR o PLANNED EVENTS LESS THAN 1 HOUR Flare or Vent Volumes: Greater than 1 hour Less than 1 hour Continuous Assist Pilot and Purge o 622 o 13.755 TOTALFLAREDNENTED 14,377