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188-118
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2K-05 KUPARUK RIV UNIT 2K-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 2K-05 50-103-20098-00-00 188-118-0 W SPT 5944 1881180 1800 2750 2750 2750 2750 1220 2010 1960 1950 REQVAR P Guy Cook 6/11/2025 MIT-OA to 1800 psi per AIO 2C.089. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2K-05 Inspection Date: Tubing OA Packer Depth 1310 1350 1350 1350IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250612073315 BBL Pumped:0.4 BBL Returned:0.4 Tuesday, July 22, 2025 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2K-05 KUPARUK RIV UNIT 2K-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 2K-05 50-103-20098-00-00 188-118-0 W SPT 5944 1881180 3000 2750 2750 2750 2750 1010 1270 1320 1355 REQVAR P Guy Cook 6/11/2025 MIT-IA to max anticipated injection pressure per AIO 2C.089. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2K-05 Inspection Date: Tubing OA Packer Depth 1280 3470 3400 3375IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250612073914 BBL Pumped:2.4 BBL Returned:2.4 Tuesday, July 22, 2025 Page 1 of 1 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger COPA Wireline Backlog – Batch 2 DATE: 03/01/2024 Transmitted: North Slope, KKuparukk Via SFTP drop - DEVELOPMENT - AOGCC – SCHLUMBERGER 2 of 2 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 192-103/ T38565 188-118/ T38564 192-050/ T38566 184-164/ T38567 185-284/ T38568 185-246/ T38569 203-091/ T38570 202-210/ T38571 202-206/ T38572 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.03.04 11:44:20 -09'00' 188-118/ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2K-05 KUPARUK RIV UNIT 2K-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 2K-05 50-103-20098-00-00 188-118-0 W SPT 5944 1881180 1800 2660 2660 2675 2675 300 2000 1920 1895 REQVAR P Kam StJohn 6/20/2023 MIT-OA to 1800 psi per AIO 2C.089 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2K-05 Inspection Date: Tubing OA Packer Depth 510 590 590 590IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230621140823 BBL Pumped:0.7 BBL Returned:0.6 Thursday, July 27, 2023 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2K-05 KUPARUK RIV UNIT 2K-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 2K-05 50-103-20098-00-00 188-118-0 W SPT 5944 1881180 3000 2675 2675 2675 2675 340 690 700 710 REQVAR P Kam StJohn 6/20/2023 MIT-IA to maximum anticipated injection pressure per AIO 2C.089 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2K-05 Inspection Date: Tubing OA Packer Depth 510 3500 3420 3400IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230621140152 BBL Pumped:2.6 BBL Returned:2.3 Thursday, July 27, 2023 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Kuparuk injector 2K-05 (PTD #188-118) Report of IAxOA convergence Date:Tuesday, April 25, 2023 1:54:00 PM Attachments:image001.png AnnComm Surveillance TIO for 2K-05.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Monday, April 24, 2023 2:36 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: Kuparuk injector 2K-05 (PTD #188-118) Report of IAxOA convergence Chris- Kuparuk injector 2K-05 (PTD #188-118) has completed the extended 60-day monitor period for suspect IAxOA convergence. During the additional 30-days, the IA & OA repeated the same convergence and appears the IAxOA communication active at elevated differential pressures and intermittently active at lower differential pressures. It is CPAI’s intention to apply for administrative approval to continue water injection only with known IAxOA communication. CAPI intends to leave the well on water injection while the AA is in process. Please let me know if you have any questions or disagree with the plan. Attached is the current 90 day TIO plot and wellbore schematic. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 Sent: Thursday, March 23, 2023 2:54 PM To: 'Wallace, Chris D (CED)' <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: Kuparuk injector 2K-05 (PTD #188-118) Report of IAxOA convergence Chris- Kuparuk injector 2K-05 (PTD #188-118) is nearing the end of the 30 day monitor period. DHD established ~700 psi differential pressure between the IA and OA at the beginning of the monitor period. Initially it appeared the IA and OA continued to converge, however, it appears that the convergence ceased and the IA and OA maintained a differential pressure of ~100 psi. Due to the initial pressure convergence during the monitor period, CPAI intends to extend the monitor period by 30 days to re-establish a greater pressure differential and evaluate IA and OA convergence under the conditions the leak is only active with an elevated differential pressure. Please let me know if you have any questions or disagree with the plan. Attached is a current 90 day TIO plot and well bore schematic. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 Sent: Monday, February 20, 2023 7:57 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: Kuparuk injector 2K-05 (PTD #188-118) Report of IAxOA convergence Chris- Kuparuk injector 2K-05 (PTD #188-118) has shown indications of IAxOA convergence. CPAI intends to conduct an initial set of diagnostics to investigate the possibility of IAxOA communication. Depending on the results of the diagnostics the well will be placed on a 30 day monitor period to verify long term integrity or the proper notification for administrative approval will be submitted for continued injection. Attached is a 90 day TIO plot and current well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est. 60' of Rathole) 7,658.0 9/26/2019 2K-05 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth & Locked Out TRSSSV 9/26/2019 2K-05 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 4,103.1 Set Depth (TVD) … 3,448.1 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 7,919.6 Set Depth (TVD) … 6,443.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.1 Set Depth (ft… 7,404.7 Set Depth (TVD) (… 6,005.6 Wt (lb/ft) 9.30 Grade J-55 Top Connection AB-MOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.1 31.1 0.14 HANGER FMC GEN IV TUBING HANGER 3.500 1,808.5 1,726.7 38.25 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE ((LOCKED OUT 9/26/2019)) 2.812 7,318.0 5,933.0 33.15 PBR BAKER PBR 3.000 7,331.7 5,944.4 33.14 PACKER BAKER HB RETRIEVABLE PACKER 2.892 7,370.3 5,976.8 33.11 NIPPLE OTIS XN NIPPLE NO GO 2.750 7,404.0 6,005.0 33.10 SOS BROWN SHEAR OUT SUB 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,484.0 7,490.0 6,071.9 6,076.9 C-4, 2K-05 4/17/2010 6.0 APERF 2.5" MILLENIUM HMX, 60 deg phase 7,537.0 7,545.0 6,116.2 6,122.9 A-5, 2K-05 4/17/2010 6.0 APERF 2.5" MILLENIUM HMX, 60 deg phase 7,562.0 7,598.0 6,137.2 6,167.5 A-4, 2K-05 10/29/1989 4.0 IPERF 90 deg. Phasing; 4.5" Ultra Pac Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,630.6 2,349.1 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/18/1991 2 4,955.9 4,088.1 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/18/1991 3 6,517.7 5,291.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/18/1991 4 7,275.2 5,897.1 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.0 9/20/2016 Notes: General & Safety End Date Annotation 11/1/2010 NOTE: View Schematic w/ Alaska Schematic9.0 2K-05, 9/28/2019 11:17:54 AM Vertical schematic (actual) PRODUCTION; 33.0-7,919.6 IPERF; 7,562.0-7,598.0 APERF; 7,537.0-7,545.0 APERF; 7,484.0-7,490.0 SOS; 7,404.0 NIPPLE; 7,370.3 PACKER; 7,331.7 PBR; 7,318.0 GAS LIFT; 7,275.2 GAS LIFT; 6,517.7 GAS LIFT; 4,955.8 SURFACE; 35.0-4,103.1 GAS LIFT; 2,630.6 SAFETY VLV; 1,808.5 CONDUCTOR; 36.0-115.0 HANGER; 31.1 KUP INJ KB-Grd (ft) 40.19 Rig Release Date 8/10/1989 2K-05 ... TD Act Btm (ftKB) 7,936.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009800 Wellbore Status INJ Max Angle & MD Incl (°) 44.28 MD (ftKB) 2,800.00 WELLNAME WELLBORE2K-05 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Kuparuk injector 2K-05 (PTD #188-118) Report of IAxOA convergence Date:Thursday, March 23, 2023 3:18:18 PM Attachments:image001.png TIO and Table.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, March 23, 2023 2:54 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: Kuparuk injector 2K-05 (PTD #188-118) Report of IAxOA convergence Chris- Kuparuk injector 2K-05 (PTD #188-118) is nearing the end of the 30 day monitor period. DHD established ~700 psi differential pressure between the IA and OA at the beginning of the monitor period. Initially it appeared the IA and OA continued to converge, however, it appears that the convergence ceased and the IA and OA maintained a differential pressure of ~100 psi. Due to the initial pressure convergence during the monitor period, CPAI intends to extend the monitor period by 30 days to re-establish a greater pressure differential and evaluate IA and OA convergence under the conditions the leak is only active with an elevated differential pressure. Please let me know if you have any questions or disagree with the plan. Attached is a current 90 day TIO plot and well bore schematic. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 Sent: Monday, February 20, 2023 7:57 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: Kuparuk injector 2K-05 (PTD #188-118) Report of IAxOA convergence Chris- Kuparuk injector 2K-05 (PTD #188-118) has shown indications of IAxOA convergence. CPAI intends to conduct an initial set of diagnostics to investigate the possibility of IAxOA communication. Depending on the results of the diagnostics the well will be placed on a 30 day monitor period to verify long term integrity or the proper notification for administrative approval will be submitted for continued injection. Attached is a 90 day TIO plot and current well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 2500 _ 2000 a ` 1500 N a 1000 ION 9 600 0 500 LL V m g 400 0 a 300 m a 200 m m 100 0 Pressure Summary for 2K-05 130 120 100 m 90 a E m 80 10 — IA PRESSURE — OA PRESSURE — TUBING PRESSURE (PSI) — TEMPERATURE(DEGF) — DRY GAS(MSCFD) — MI GAS (MSCFD) — PRODUCED WATER (BPD) — SEAWATER(BPD) HTt I" MI I I I N N N 0 0 0 N H N N N N N M O 0 O N N r� N N N O O O N H H N N N N N N N N N N N N N 0 .a .a .a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 00 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 00 0 0 0 0 0 0 0 0 0 N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N Date 100 m 90 a E m 80 10 — IA PRESSURE — OA PRESSURE — TUBING PRESSURE (PSI) — TEMPERATURE(DEGF) — DRY GAS(MSCFD) — MI GAS (MSCFD) — PRODUCED WATER (BPD) — SEAWATER(BPD) CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Kuparuk injector 2K-05 (PTD #188-118) Report of IAxOA convergence Date:Tuesday, February 21, 2023 8:31:21 AM Attachments:image001.png AnnComm Surveillance TIO for 2K-05.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Monday, February 20, 2023 7:57 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: Kuparuk injector 2K-05 (PTD #188-118) Report of IAxOA convergence Chris- Kuparuk injector 2K-05 (PTD #188-118) has shown indications of IAxOA convergence. CPAI intends to conduct an initial set of diagnostics to investigate the possibility of IAxOA communication. Depending on the results of the diagnostics the well will be placed on a 30 day monitor period to verify long term integrity or the proper notification for administrative approval will be submitted for continued injection. Attached is a 90 day TIO plot and current well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (Est. 60' of Rathole) 7,658.0 9/26/2019 2K-05 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth & Locked Out TRSSSV 9/26/2019 2K-05 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 4,103.1 Set Depth (TVD) … 3,448.1 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 7,919.6 Set Depth (TVD) … 6,443.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.1 Set Depth (ft… 7,404.7 Set Depth (TVD) (… 6,005.6 Wt (lb/ft) 9.30 Grade J-55 Top Connection AB-MOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.1 31.1 0.14 HANGER FMC GEN IV TUBING HANGER 3.500 1,808.5 1,726.7 38.25 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE ((LOCKED OUT 9/26/2019)) 2.812 7,318.0 5,933.0 33.15 PBR BAKER PBR 3.000 7,331.7 5,944.4 33.14 PACKER BAKER HB RETRIEVABLE PACKER 2.892 7,370.3 5,976.8 33.11 NIPPLE OTIS XN NIPPLE NO GO 2.750 7,404.0 6,005.0 33.10 SOS BROWN SHEAR OUT SUB 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,484.0 7,490.0 6,071.9 6,076.9 C-4, 2K-05 4/17/2010 6.0 APERF 2.5" MILLENIUM HMX, 60 deg phase 7,537.0 7,545.0 6,116.2 6,122.9 A-5, 2K-05 4/17/2010 6.0 APERF 2.5" MILLENIUM HMX, 60 deg phase 7,562.0 7,598.0 6,137.2 6,167.5 A-4, 2K-05 10/29/1989 4.0 IPERF 90 deg. Phasing; 4.5" Ultra Pac Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,630.6 2,349.1 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/18/1991 2 4,955.9 4,088.1 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/18/1991 3 6,517.7 5,291.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/18/1991 4 7,275.2 5,897.1 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.0 9/20/2016 Notes: General & Safety End Date Annotation 11/1/2010 NOTE: View Schematic w/ Alaska Schematic9.0 2K-05, 9/28/2019 11:17:54 AM Vertical schematic (actual) PRODUCTION; 33.0-7,919.6 IPERF; 7,562.0-7,598.0 APERF; 7,537.0-7,545.0 APERF; 7,484.0-7,490.0 SOS; 7,404.0 NIPPLE; 7,370.3 PACKER; 7,331.7 PBR; 7,318.0 GAS LIFT; 7,275.2 GAS LIFT; 6,517.7 GAS LIFT; 4,955.8 SURFACE; 35.0-4,103.1 GAS LIFT; 2,630.6 SAFETY VLV; 1,808.5 CONDUCTOR; 36.0-115.0 HANGER; 31.1 KUP INJ KB-Grd (ft) 40.19 Rig Release Date 8/10/1989 2K-05 ... TD Act Btm (ftKB) 7,936.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032009800 Wellbore Status INJ Max Angle & MD Incl (°) 44.28 MD (ftKB) 2,800.00 WELLNAME WELLBORE2K-05 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP MEMORANDUM State of Alaska Pretest Alaska Oil and Gas Conservation Commission TO: J Jim Regg 715I1. DATE: Thursday, June 27, 2019 SUBJECT: Mechanical Integrity Tests Pi Supervisor 1 r""/q'// t ' Type Inj I G - TVD ( ` ConocoPhillips Alaska, Inc. 3850 2K-05 FROM: Lou Laubenstein KUPARUK RIV UNIT 2K-05 Petroleum Inspector 1500 - IA 760 Sre: Inspector 2060 Reviewed By; BBL Pumped:1 P.I. Supry'� NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-05 API Well Number 50-103-20098-00-00 Inspector Name: Lou Laubenstein Permit Number: 188-118-0 Inspection Date: 6/8/2019 [nsp Num: mitLOu 9061 of 657a7 , Rel Insp Num: Notes: Thursday, June 27, 2019 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Wel 2K-05 ' Type Inj I G - TVD 5944 Tubing 3850 3850 3850 - 3850 - PTD1881180 ' Type TestI SPT 'Test psi 1500 - IA 760 2110 2060 2050 - BBL Pumped:1 - 3 ,BBL Returned: -- 13 OA 360 ". 460 460 - 460 Interval 4vRTST — P/F P Notes: Thursday, June 27, 2019 Page I of 1 • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, January 02, 2017 1:37 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: RE: Report of multiple IA bleeds KRU injector 2K-05 (PTD 188-118) 7-11-16 update 1-2-17 Attachments: 2K-05 90 day TIO 1-2-17.PNG Chris, The extended monitor period on 2K-05 is coming to an end today. The IA pressure appears to be responding to thermal inputs alone. Therefore we intend to return the well to normal injection status; and it will be governed under A10 2C. If the well begins to show signs of communication again in the future, it will be reported at that time. Please let me know if you disagree. Attached is an updated TIO plot. -Kelly From: NSK Problem Well Supv JAN 1 8 21117 Sent: Saturday, December 03, 2016 8:21 AM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Cc: Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: RE: Report of multiple IA bleeds KRU injector 2K-05 (PTD 188-118) 7-11-16 update 12-3-16 Chris, The 30 day monitor period while on gas injection is coming to an end. During most of the monitor, the well did not show signs of TxIA communication. There was a recent decline in injection temperature,which the IA responded to in kind. However, when the temperature increased (but not returned fully to where it had been before), the IA returned to the same pressure that it had been when the well was running hotter. This may be initial indications of slow communication resuming. But nothing is conclusive at this point. Therefore we plan to extend the monitor out an additional 30 days. A followup email will be provided at the conclusion of the monitor. If communication does resume, the well will be WAG'ed back to water injection and an AA application will be submitted for your consideration. Let me know if you disagree with the path forward. Attached is an updated TIO plot. Kelly Lyons/Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907)943-0170 From: NSK Problem Well Supv Sent:Sunday, October 30, 2016 8:54 AM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> 1 W .,:. Ia • W5 , • G.., = LL ofl_ U to w C <) a . I` 'o O VI N_ w cr = D, '2 6 •r 11 2 y W m v, W CI. C� 4.1 w I= .. O_ J I 9i Jy s r. l ABap ^I CI µJ 4.C J C J [J f.-. f 1 a I 1 I t 1 C M1 r" r C C .11111.1111111, r A d In ti u ."="."'""""... ."A"-C Q o 7 co a Ca p z z° a) Ca tel ._ SO CD E z U z N u7 Q 8 O <O (D to X Ur r O C O eQ, N I ' (C ! i d l i (n N C 1 a ` I I ( I I , -- co I I Cty� n d y n C--J a ra c H C3 a r_i N is n ^ ,2 2 a Fa ;5 C� CI C.I CI C.I CI O [7 a. (fl LJ nil C.1 I.1./ CJ Vi C7 Ye1 Z Q Q K CI-I Cl C 1 C I .- r :1118'QaCrA t N v e isd SCn0w • S Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday, December 03, 2016 8:21 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: RE: Report of multiple IA bleeds KRU injector 2K-05 (PTD 188-118) 7-11-16 update 12-3-16 Attachments: 2K-05 90 day TIO 12-3-16.PNG Chris, The 30 day monitor period while on gas injection is coming to an end. During most of the monitor, the well did not show signs of TxIA communication. There was a recent decline in injection temperature, which the IA responded to in kind. However, when the temperature increased (but not returned fully to where it had been before),the IA returned to the same pressure that it had been when the well was running hotter. This may be initial indications of slow communication resuming. But nothing is conclusive at this point. Therefore we plan to extend the monitor out an additional 30 days. A followup email will be provided at the conclusion of the monitor. If communication does resume, the well will be WAG'ed back to water injection and an AA application will be submitted for your consideration. Let me know if you disagree with the path forward. Attached is an updated TIO plot. Kelly Lyons/ Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 DEC ® 5 2016 Mobile Phone (907) 943-0170 WANE® From: NSK Problem Well Supv Sent:Sunday, October 30, 2016 8:54 AM To: Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tye Ier.Senden@conocophillips.com> Subject: RE: Report of multiple Beds KRU injector 2K-05 (PTD 188-118) 7-11-16 update 10-30-16 Chris, As per the note below,the well was WAG'ed to water jeon on August 13 and during the 30 day monitor did not exhibit any signs of TxIA communication. On August 17, an MIT1Ato 3100psi passed, as did the tubing packoff tests. The negative drawdown inner casing packoff test failed, while the positive pre sure test passed. While the well was secured for the circ out, we repaired a minor bradenhead external leak on October i7. The followup MITOA on October 19 passed, indicating a successful repair. The well has been unsecured and is getting ready to be returned to gas injection for the 30 day monitor as proposed below. Coincidentally, 2K pad was recently swapped-from produced to seawater injection and operations needs to pig the line. Having the extra hole at 2K-05 will give them a better sweep. Therefore 2K-05 will be returned to water injection very briefly(probably for a maximum of 12 hrs) during the pigging operations. It will then be WAG'ed togas Please let me know ifyou disagree with the plan forward. p injection. g Attached is the form for the diagnostic MITIA performed and an updated TIO plot. 1 • i • i CC Ce 6 c, o N , w a i4 tD u, O N er 0. U U u r, L r,� .f 0) Z 0) W m co W O. U, t, N `r) w C; 0 N2 0 JI c> J 1 y ... I I ABap c:. to O N to Co to a 6 I Ci > O Z o z 4530.5"."... ..."."".." 1 3 1 i } 1 z m 8 z 3 VJa 6 O R a V 8 Q C to ,_ U 6 8 I H to y m t0 0 C a v C to a I m d**rgi .; A a cc co C -L- C) C C N N Y o+ a c. m w IN 1 ! , f r' III ► 1 Il . 1 w Eo 0 0 U 0 0 0 CI rq a a a u o 0 0 d $ R $ " d3 i7 u, O u, ft - O ) Z ❑�..r Q o r, r, r rJ WS 11.330 y d t4 F6' i$d V1 ❑▪ W • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, October 30, 2016 8:54 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of multiple IA bleeds KRU injector 2K-05 (PTD 188-118) 7-11-16 update 10-30-16 Attachments: MIT KRU 2K-05 diagnostic non witnessed 08-17-16.xls; 2K-05 90 day TIO 10-30-16.PNG Chris, As per the note below,the well was WAG'ed to water injection on August 13 and during the 30 day monitor did not exhibit any signs of TxIA communication. On August 17,an MITIA to 3100psi passed, as did the tubing packoff tests. The negative drawdown inner casing packoff test failed,while the positive pressure test passed. While the well was secured for the circ out,we repaired a minor bradenhead external leak on October 17. The followup MITOA on October 19 passed, indicating a successful repair. The well has been unsecured and is getting ready to be returned to gas injection for the 30 day monitor as proposed below. Coincidentally, 2K pad was recently swapped from produced to seawater injection and operations needs to pig the line. Having the extra hole at 2K-05 will give them a better sweep. Therefore 2K-05 will be returned to water injection very briefly(probably for a maximum of 12 hrs) during thei in pgg g operations. It will then be WAG'ed to gas injection. Please let me know if you disagree with the plan forward. Attached is the form for the diagnostic MITIA performed and an updated TIO plot. Kelly Lyons/Brent RogersProblem Wells Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) 659-7224 Mobile Phone(907)943-0170 stow FEE 2 12017 From: NSK Problem Well Supv Sent:Wednesday,August 10, 2016 10:52 AM To:Wallace,Chris..(DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R. enden@conocophillips.com> Subject: RE: Report of multiple IA KRU injector 2K-05 (PTD 188-118) 7-11-16 update 8-10-16 Chris, The 30 day monitor while on gas injection is coming to an end. Ther . -ffects from the unavoidable summertime significant fluctuations in injection rate and temperature continue to play a ro '• the pressure fluctuations of the annuli. However there is still some uncertainty as to whether or not there is a very sloe g asked TxIA communication issue present. CPAI plans to WAG this well to water injection and monitor for 30 days, during -'ch time an MITIA and packoff testing will be performed. At the conclusion of the water injection period,the IA will be circ'e• •ut with clean inhibited fluid. The well will be returned to gas injection and monitored for an additional 30 days. By the tim-Ake, resume the gas injection test,the fluctuations in the gas injection should be lessened as the cooler months returnih will enable us to more definitively determine the integrity state of the wellbore. Please let me us know if you disagree with the plan forward. Attached is an updated TIO plot. 1 STATE OF ALASKA OCT 24- 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOCICC 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown E Performed: Suspend p r Perforate r Other Stimulate r Alter Casing r Change Af oowd Program r Plug for Redrill r Perforate New Pool E Repair Well r Re-enter Susp Well r p"gars/a✓-Cr 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number ConocoPhillips Alaska, Inc. Developmen r Exploratory E 188-118 3.Address: 6.API Number: Stratigraphi E Service F P.O. Box 100360,Anchorage,Alaska 99510 50-103-20098-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025588 KRU 2K-05 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7936 feet Plugs(measured) None true vertical 6458 feet Junk(measured) None Effective Depth measured 7677 feet Packer(measured) 7318,7332 true vertical 6234 feet (true vertical) 5933,5944 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115' SURFACE 4068 9 5/8 4103 3448' PRODUCTION 7887 7 7920 6444' scow ,.,\PF, 0 3 LUi! Perforation depth: Measured depth: 7484-7490,7537-7545,7552-7598 True Vertical Depth: 6072-6077,6116-6123,6137-6168 Tubing(size,grade,MD,and TVD) 3.5,J-55,7404 MD,6005 TVD Packers&SSSV(type,MD,and TVD) SAFETY VLV-CAMCO TRDP-1A-SSA SAFETY VALVE @ 1809 MD and 1727 TVD PBR-BAKER PBR @ 7318 MD and 5933 TVD PACKER-BAKER HB RETRIEVABLE PACKER @ 7332 MD and 5944 ND 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys r 16.Well Status after work: Oil r Gas r WDSPL E Printed and Electronic Fracture Stimulation E GSTOR r WINJ r WAG F GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: NA Contact Roger Winter Email: n1927(c�conocophillips.com Printed Name /��/d Roger Winte Title: WI Field Supervisor ����� Signature Phone:659-7506 Date ,/ Form 10-404 Revised 5/2015 VEL lG`Z/ / Submit Original Only /O/L- v/`6 RBDMS W OCT 2 4 2016 • • 111 ConocoPhillips RECEIVED Alaska 0(21 2 4 20Th P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC October 20, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 2K-05, PTD 188-118, for starter head repair. Please contact me at 659-7506 if you have any questions. Sinc rely, Roger Winter ConocoPhillips Well Integrity Field Supervisor / qct+ r a ;z Q O p vii +, v, c6 X c.) a - tip #C r -r:;; O L.. 3] N ` O a" CO! � i' t, O OC Q > >.. r 'i t r.. e. ts, �a ,# v, °Rs .n3�. r,�J r it1 ''': -','-' '.'",,'''''..::: :'''''s...-4,',!if,,,fi-::::',:r-4;-:t:,,i, ',-,-,,,..ti-444) * ' ' „',.' -j..i''.. ' ::4siiiiiut,'-''-'-..,,'z ', ill* 441it,, , .Sti lk, i 'I -w4 • • 2K-05 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/06/16 Prep starter head for repairs. 10/17/16 Repair starter head with 3 pass weld. 10/19/16 MITOA to 1800 psi for 1 hour with no external leaks on Starter head. • + , • Wallace. Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday,August 10, 2016 10:52 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of multiple IA bleeds KRU injector 2K-05 (PTD 188-118) 7-11-16 update 8-10-16 Attachments: 2K-05 90 day TIO 8-10-16.PNG Chris, The 30 day monitor while on gas injection is coming to an end. Thermal effects from the unavoidable summertime significant fluctuations in injection rate and temperature continue to play a role in the pressure fluctuations of the annuli. However there is still some uncertainty as to whether or not there is a very slow masked TxIA communication issue present. CPAI plans to WAG this well to water injection and monitor for 30 days, during which time an MITIA and packoff testing will be performed. At the conclusion of the water injection period,the IA will be circ'ed out with clean inhibited fluid. The well will be returned to gas injection and monitored for an additional 30 days. By the time we resume the gas injection test,the fluctuations in the gas injection should be lessened as the cooler months return,which will enable us to more definitively determine the integrity state of the wellbore. Please let me us know if you disagree with the plan forward. Attached is an updated TIO plot. Kelly Lyons/Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk (907) 659-7224 7, one Mobi ehPhone (907)943-0170 atiti6 JA ' F ; : NSK Problem Well Supv Sent: - day,July 11,2016 12:38 PM To:Wallace, s D (DOA)<chris.wallace(a@alaska.gov> Cc:Senden, R.Tyler ' T ler.Senden • conoco.hilli.s.com> Subject: Report of multiple •leeds KRU injector 2K-05 (PTD 188-118)7-11-16 Chris, KRU WAG injector 2K-05 (PTD 188-118) has ha• •- IA and OA bled several times over the past several months when reaching its DNE,with the latest IA bleed occurring yes - day. The well has been on gas injection since August 2015 and there have been erratic temperature and injection swings. - .ressure increases are currently believed to be thermally induced. However,the erratic nature of the response to the injectio • ay be masking potential TxIA communication. This report is to inform you that CPAI intends to monitor - well under heightened scrutiny for 30 days to confirm the theory that the increase in pressure is due to thermal effects. TxIA communication becomes suspected during the monitor,we will begin the initial round of DHD diagnostics to ine MITIA/packoff testing/IA drawdown with extended bleeding as needed. A follow-up email will be sent at the concliisiort,of the monitor period. Please let us know if you disagree or have any questions. 1 • W - " - g, g g g.- g ._„ r 00 . C? C7 0 O O O 0 0 0 z cc E Et ir re cc Et cc cc ce tY cr Cr W W W w r W w W F W W Q ✓ — O O — =- - 0 — — 00 — — cn w U ; • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, July 11, 2016 12:38 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report of multiple IA bleeds KRU injector 2K-05 (PTD 188-118) 7-11-16 Attachments: 2K-05 90 day TIO 7-11-16.PNG; 2K-05 schematic.pdf Chris, KRU WAG injector 2K-05 (PTD 188-118) has had the IA and OA bled several times over the past several months when reaching its DNE,with the latest IA bleed occurring yesterday. The well has been on gas injection since August 2015 and there have been erratic temperature and injection swings. The pressure increases are currently believed to be thermally induced. However, the erratic nature of the response to the injection may be masking potential TxIA communication. This report is to inform you that CPAI intends to monitor the well under heightened scrutiny for 30 days to confirm the theory that the increase in pressure is due to thermal effects. If TxIA communication becomes suspected during the monitor, we will begin the initial round of DHD diagnostics to include MITIA/packoff testing/IA drawdown with extended bleeding as needed. A follow-up email will be sent at the conclusion of the monitor period. Please let us know if you disagree or have any questions. Attached are the schematic and 90 day TIO plot. Kelly Lyons/ Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 SCANNED DEC 0 6 2016 W ' T z •fY a 0 U 0 0 0, c. 0 0 0 0 ILO 01 g cc re ¢' re re Q a LY cr cc r7 } W tV L'' ' W w 4J W W W N r, 1 0 0 ) 0 O O 0 0 u, 0 0 0 0 0 0 0 .) 4 yU,a. te �_ " h in a Q N) S o N ",,,7, 2 00 o 0000 Q 4iI h) 0 L 8 _ � __ d ,-J f V I ca -' Or a> a O W ID N St� C 0 0 0 0 0 0 0 0 0 4 ®O P7 M a f f 1" O^ 1,5 cin CC N N N IN N N N N fJ 4- tit N D 1D u3 ICJ w W 1.D tD u, W ID— I 2 Q 0 0 co ID C 0 0 0 N 0 pT "� aa as C � U, U) U, UU , > UU, U ) 0) 0) , J0 c. 0 0 0 0 0 0 0 0 0 J Y Y Y Y Y Y Y Y Y Y Y IN N N N N N N N N NJ CJ I. ABap v f4 Ca C> o e> o a aG o a ca c0 CO .— I I 1 I 4 f I to 'D 5'7 110* !LE' 1P c j 3 u l C as 4.0n 47. ns 74. v c Cde. ID U., CO .) V d co = 2 z C ro m a. 1 .3 co 00 C- c N.I Co IN II 4 ILII I 4.C4a Z c 0 a c> �i CJ N 01118'ai3w ap to TTi � � ow Isd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,July 14,2015 TO: Jim Regg P.I.Supervisor (9 �'���� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-05 FROM: Chuck Scheve KUPARUK RIV UNIT 2K-05 Petroleum Inspector SCANSrc: Inspector NED f w� _ h Reviewed By: P.I.Supry r1( - NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-05API Well Number 50-103-20098-00-00 Inspector Name: Chuck Scheve Permit Number: 188-118-0 Inspection Date: 7/10/2015 Insp Num: mitCS150713093919 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Type ---j 5944 Tubing 2550 2550 - 2550 ./ , — 18811080 ,Type SPT psi1500 1050 2000 - 1920 2550 �� Well T e In' TVD Tubin i PTD Test Test IA I920 - Interval 4YRTST P/F P OA 700 740 - 740 740 Notes: Tuesday,July 14,2015 Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ,/(~<~" - )_ J_ ~ Well History File Identifier Organization (done) ~Two-Sided RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES: NOTES' ORGANIZED BY: BEVERL.Y BREN VINCENT SHERYL MARIA LOWELL OATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Is/ Project Proofing PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE. [] Staff Proof By: Da~e: /s/ PAGES: 7,._~ (at the time of scanning) SCANNED BYi BEVERLY BREN VINCEN~MARtA LOWELt ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL M,~RIA LOWELL DAfF /S/ General Notes or Comments about this file: Quality Checked (clone) RevlNOTScanned,wpd 04,,P',\\ 11/7,',v v THE STATE Al'aeltrA Ott a rc. Gas f _ 333 West Seventh Avenue "11 -17- :- '/ G0vLRNOR SEAN PARNGLL Anchorage, Alaska 99501-3572 0 :-. � Nain: 907 )79 1433 S '/.2/6.7542 gH g� Darrell Humphrey UZ#NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 SCANNED A U G Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-05 Sundry Number: 314-250 Dear Mr. Humphrey: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, i°,44..4, Cathy P oerster Chair DATED this Z...41.day of April, 2014. Encl. Rv ix,. . • STATE OF ALASKA II • ALAS,-,OIL AND GAS CONSERVATION COMMISS._,J PR '1 6 014 APPLICATION FOR SUNDRY APPROVALS 412` / 20 MC 25.280 A 1.Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend F. - Rug•Porforations r,- Perforate r PUltTubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: Prod to WAG F 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Fe7 Exploratory r 188-118 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20098-00 ' 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? ?th Will planned perforations require spacing exception? Yes r No t+.• • Kkk 2K-05 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 025588 • Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7936 • 6458 .. 7824' - 6314' None None Casing Length Size MD TVD Burst Collapse . CONDUCTOR 7916 cE.. 115' 115' SURFACE 4068 12 4103' 3488' PRODUCTION 7887 7 7920' 6444' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7484'-7490';7537-7545';7562'-7598'- 6072'-6077';6116-6123';6137'-6168' 3.5 J-55 7405 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-BAKER HB RETRIEVABLE PACKER ' MD=7332 TVD=5944 SSSV-CAMCO TRDP-IA-SSA • MD=1809 TVD=1726 12.Attachments: Description Summary of Proposal • r 13. Well Class after proposed work: Detailed Operations Program T BOP Sketch r Exploratory r Stratigraphic r Development r Service 'err 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/1/2014 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: VVINJ r GINJ r WAG p, . Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen/Darrell Humphrey Email: N1139 cni.conocophillips.com Printed Name Darrell Humphre Title: NSK Production Engineering Specialist Signature ...a.-1,1 Phone:659-7535 Date y 16/. '? Comm'lssion Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ‘.1-L-2S 0 Plug Integrity r BOP Test r Mechanical Integrity TestLocation Clearance r RBDM MAY U 8 2014 Other:MLT /A rt-41,t,l',,- d ( 7Gt h- L✓# trC.SSd) Cc ft v / GL b/7/ z- i ✓1/ fC f"'I-t • Spacing Exception Required? Yes 0 No ii Subsequent Form Required: /d—4 D 4- APPROVED BY Approved by: (2147 , ' COMMISSIONER THE COMMISSION Date: 4 `2.- ---/1 � pproved a •= 4 �I r 2 nths from th date of approval. Form 10-403(Revised 10/2012) 04,3yI L lY pp Subs• Form and Attachments in Duplicate 4/Z2/1 3 VL1�' P-`.4/.3 2K-05 • DESCRIPTION SUMMARY OF PROPOSAL -etilIMPhillirtsAlaska Inc.Wishes°to resubmit its request for approval to-return/convert Kuparuk Well 2K-05 to WAG Injection service. The previously approved sundry 313-146 signed 4/9/13 has expired. Well 2K-05 was converted from injection to production on March 9, 2013 for reservoir pressure reduction in support of well 2K-02 RWO operations. Flowback operations on well 2K-05 have been discontinued as the 2K-02 RWO has been suspended. A wittnessed MIT-IA was last performed on 06/24/11; MITIA 2700 psi, 30 minutes, Passed iz E 1' } { ¢' !.` ' Robert Christensen/Darrell Humphrey Production Engineering Specialists. NPV ()G L Greater Kuparuk Unit,NSK-69 PO ConocoPlhhiilli s An Box 196105 Anchorage,AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 April 14, 2014 Dan Seamount AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage, AK 995013 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. is resubmitting its request approval to convert/return Kuparuk River Unit well 2K-05 from Oil production to WAG injection service. The originally approved 10-403 Sundry 313-146 signed 4/9/13 has since expired. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 2K-05 (PTD 188-118). If you have any questions regarding this matter, please contact myself or Bob Christensen at 659-7535. Sincerely, Darrell Humphrey Attachments Sundry application Well schematic • 1 KUP INJ 2K-05 ConocoPhillips aua.s Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) r,..,.,at„fol„ 501032009800 KUPARUK RIVER UNIT INJ 44.28 2,800.00 7,936.0 -.- Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) -Rig Release Date 2K-05,10/21/2013 9;4947 AM SSSV:TRDP Last WO: 40.19 8/10/1989 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,689.0 10/18/2013 Rev Reason:TAG hipshkf 10/21/2013 1I 4` Casing Strings . Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread HANGER;37 1 � CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H 40 WELDED g .lis. SURFDes ippon OD(in) ID(in) Top(ftKB) Set Depth 4,103.10) Set Depth 3,448.1 36.00 55e Top 11. SURFACE 9 5/8 8.921 35 0 3 448 1 36 00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread' ' ii PRODUCTION 7 6276 330 7,919.6 64437 26.00 J-55 BTC i Tubing Strings ; Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 3 1/2 2.992 31.1 7,404.7 6,005.6 9.30 J-55 AB-MOD >olit.■u.Completion Details Nominal ID Top(ftKB) Top(TVD)(MB) Top not(°) Item Des Com (in) .nn.,CONDUCTOR,36 0-115 :,/v�..V, 31.1 31.1 0.14 HANGER FMC GEN IV TUBING HANGER 3.500 LI 1,808.5 1,726.7 38.25 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.812 7,318.0 5,933.0' 33.15 PBR BAKER PBR 3.000 01 7,331.7 5,944.4 33.14 PACKER BAKER HB RETRIEVABLE PACKER 2.892 SAFETY VLV,1,808.5 7,370.3 5,976.8 33.11 NIPPLE OTIS XN NIPPLE NO GO 2.750 7,404.0 6,005.0 33.10 SOS BROWN SHEAR OUT SUB 2.992 i--1 Perforations&Slots Shot Dens 0 Top(TVD) Btm(TVD) (shotsk -,.--GAS LIFT,2.630.6 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone.,- Date t) Type Com 2484.0 7,490.0 6,071.9 6,076.9 C-4,2K-05, 4/17/2010 6.0 APERF 2.5'MILLENIUM HMX, 60 deg phase 7,537.0 7,545.0' 6,116.2 6,122.9 A-5,2K-05 4/17/2010 6.0 APERF 2.5"MILLENIUM HMX, 60 deg phase 7,562.0 7,598.0 6,137.2 6,167.5 A-4,2K-05 10/29/1989 4.0 (PERF 90 deg.Phasing;4.5" Ultra Pac Mandrel Inserts St SURFACE,35.0-4.103.1-• • ati C Nn Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sent Type Type (in) (psi) Run Date m ft 1 2,630.6 2,349.1 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/18/1991 -.GAS LIFT; 2 4,955.9 4,088.1 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3118/1991 3 6,517.7 5,291.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/18/1991 4' 7,275.2 5,897.1 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/18/1991 11 Notes:General&Safety GAS LIFT.6,517 7 End Date Annotation 11/1/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;7,275.2 PBR;7.318.0 PACKER,7,331 7 NIPPLE,7.3703 I SOS.7,404.0 APERF;7,484.0-7,490.0-= APERF;7,537 0.7,545.0- I PERF;7,562 0-7,598.0- C. PRODUCTION,33.0-7.919 6 Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent: Tuesday,April 22, 2014 4:12 PM To: Ferguson,Victoria L(DOA) Subject: RE: KRU 2K-05 (PTD 188-118, Sundry 314-250) Note to file Note to file: Mike D. from CPAI informed me that 2K-05 was converted to a producer for reservoir pressure relief on 3/9/13 and then was shut in on 3/26/13 and has been shut in since due to a ruptured header. Likely will be a couple of months before header is repaired and 2K-05 is returned to injection service. I am going to approve Sundry 314-250 to convert from SI producer to SI injector with the requirement of a state witnessed MIT-IA after stabilized injection. Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W. 7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferquson(@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at (907)793-1247 or Victoria.Ferguson@alaska.gov From: Ferguson, Victoria L(DOA) Sent: Tuesday, April 22, 2014 2:42 PM To: CPF2 Prod Engrs(n1135@conocophillips.com) Subject: FW: KRU 2K-05 (PTD 188-118, Sundry 314-250) This well was in producer status for longer than 30 days; was a 10-403 submitted since backflow was greater than 30 days?What has been the status of this well since March, 2013? Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferquson alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov 1 From: Wallace, Chris D (DOA) Sent:Tuesday, March 05, 2013 7:48 AM To: 'NSK Well Integrity Proj' Cc: NSK Problem Well Supv; Dethlefs,Jerry C; McMains, Stephen E (DOA); Schwartz, Guy L(DOA); Regg, James B(DOA) Subject: RE: KRU 2K-05 (PTD 188-118) Back flow to reduce reservoir pressure MJ, You are approved and can begin. A 10-403 is not required as indicated in the Sundry Waiver rules (if less than 30 days backflow). A 10-403 would be required to be submitted and approved if you wish to keep this well as a producer for greater than the 30 days. Please submit a 10-404 to indicate change of status from injector to producer. Please submit the monthly production data on the 10-405 forms. Please submit the monthly injection data on the 10-406 forms. Please submit at end of backflow a 10-404 to indicate return from producer to injector. Please ensure you tag/highlight the injection and production data correctly as this reporting has caused problems in the past. Possibly a note in the comments indicating this month has both production and injection can help our data tracking and entry. Also please review Safety valve and the low pressure pilot (s)for the interim production requirements. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542 (fax) chris.wallace@alaska.gov From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Monday, March 04, 2013 8:48 AM To: Regg, James B (DOA); Wallace, Chris D (DOA); Schwartz, Guy L(DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; Dethlefs,Jerry C Subject: KRU 2K-05 (PTD 188-118) Back flow to reduce reservoir pressure Jim, Chris, Guy ConocoPhillips would like to back flow injection well KRU 2K-05(PTD 188-118)for less than 28 days for immediate reservoir pressure reduction to aid 2K-02 (188-121) rig workover. Injector 2K-05 will be hard line jumpered over to SI producer 2K-04's flow line for the back flow operation. We would like to start the backflow as soon as possible. Please advise any 10-403 approval, 10-404 Sundry, or any other AOGCC approval requirements. Regards MJ Loveland/Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907)659-7043 MJ's Cell (907) 943-1687 2 � OF 77.4. • • '/77 THE STATE Alaska gl and Gas of 1 1 L SK 1 Conservation C011ifiYSSi Yl GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Q. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1 433 Fax: 907.276.7542 Robert D. Christensen NSK Production Engineering Specialist 8q t ConocoPhillips Alaska, Inc. 1 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K -05 $CANNE® APR Sundry Number: 313 -146 1 0 2 013 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, • Cathy P.. oerster Chair DATED this Tt of April, 2013. Encl. 9#4,._ 3 : ,.,„„_. ----- s STATE OF ALASKA ,�r'S 4.h113 ALA OIL AND GAS CONSERVATION COMMON �� APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 A . C? C 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other: Prod to WAG r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r;• Exploratory r 188 -118 3. Address: Service r 6. API Number: Stratigraphic r P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20098 -00 • 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F 2K - - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 025588' Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7936 ' 6458 • • 7824' 6314' None - None Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 4068 12 4103' 3488' PRODUCTION 7887 7 7920' 6444' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): ' 7484'- 7490'; 7537'- 7545'; 7562' -7598' 607Z-6077'; 6116-6123'; 6137' -6168' 3.5 J - 7405 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER HB RETRIEVABLE PACKER MD= 7332 TVD= 5944 • SSSV - CAMCO TRDP -1A -SSA MD= 1809 TVD= 1726 12. Attachments: Description Summary of Proposal Ei . 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r°' 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/2/2013 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r`• Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Darrell Humphrey Email: N1139aconocophillips.com Printed Name) R. ... .i =•• D� ,listens - Title: NSK Production Engineering Specialist Signature / r ► � " , f Phone: 659 -7535 Date 3/a / 3 Commission Use Only Sundry Number:3 j 3 -/ ci 0 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r R APR 1020 Other: Spacing Exception Required? Yes ❑ No E7 Subsequent Form Required: J U r .4 C L---/ /* APPROVED BY / Approved by: COMMISSIONER THE COMMISSION Date: 4" - - — 3 Approved application is valid for 12 months from the date of approval. /D Q rRo f 8 j vN 1 0 2) 9/57/3 i/� / Submit Form and Attachm sin Dupli to ��� \`v • 2K -05 • n. . DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to return /convert Kuparuk Well 2K -05 to WAG Injection service. Well 2K -05 was converted from injection to production on March 9, 2013 for reservoir pressure reduction in support of well 2K -02 RWO operations. Flowback operations on well 2K -05 have been discontinued as the 2K -02 RWO has been suspended. A wittnessed MIT -IA was last performed on 06/24/11; MITIA 2700 psi, 30 minutes, Passed R R Robert Christensen/Darrell Humphrey A0 (;00 Production Engineering Specialists. Greater Kuparuk Unit , NSK -69 PO Box 196105 ConocoPhi 11 i ps Anchorage, AK 99519 -6105 Phone: (907) 659 -7535 Fax: 659 -7314 March 24, 2013 Dan Seamount AOGCC Commissioner State of Alaska Oil & Gas Conservation Commission 33 W. 7 Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert/return Kuparuk River Unit well 2K -05 from Oil production to WAG injection service. Enclosed you will find 10 -403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 2K -05 (PTD 188 -118). If you have any questions regarding this matter, please contact myself or Darrell Humphrey at 659 -7535. Sincerely, / , / ` Robert D. Christensen Attachments Sundry application Well schematic KUP 2K -05 ConocoPhillips i Well Attributes Max Angle& MD T D Inc . Wel!bore API/UWI Field Name Well Status Intl( °) MD (ftKB) Act Btm (ftKB) , Alaska, 501032009800 KUPAR UK RIVER UNIT INJ 44.28 2,800.00 7,936.0 . "v§x I Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date ' -- SSSV: TRDP Last WO: 40.19 8/10/1989 Well Confi - 2K-051/11/20139'47'52 AM Schematic .•Actual Annotation Depth (ftKB) End Date (Annotation Last Mod ... End Date Last Tag: SLM 7,564.0 12/25/2012 , Rev Reason: TAG haggea 1/10/2013 11 Casing Strings ` Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H - 40 WELDED HANGER, 31 - i Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 35.0 4,103.1 3,448.1 36.00 J - 55 BTC Casing Description String 0 ... String ID ... Top ftKB Set Depth f... Set Depth De ND String Wt... String String Top Thrd •�- 9 P 9 9 P( ) th P( P( )��� 9 9��� 9 P q r PRODUCTION ` 7 6.276 33,0 7,919.6 6,443.7 26,00 J 55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 j 31.1 7,404.7 6,006.7 9.30 J -55 AB -MOD Comr letion Details .. :: Top Depth (TVD) Top Ind Nomi... Top (ftKB) (ftKB) 1 ° ) Rem Description Comment ID (In) CONDUCTOR, 36115 31.1 31.1 0.33 HANGER FMC GEN IV TUBING HANGER 3.500 1,808.5 1,725.7 37.46 SAFETY VLV ' CAMCO TRDP -IA -SSA SAFETY VALVE 2.812 7,318.0 5,932.7 32.77 PBR BAKER PBR 3.000 �_ 7,331.7 5,944.2 32.82 PACKER BAKER HB RETRIEVABLE PACKER 2.892 SAFETY VLV, 1 7,370.3 5,976.7 32.97 NIPPLE OTIS XN NIPPLE NO GO 2.750 1,808 E 7,404.0 6,006.1 34.46 SOS BROWN SHEAR OUT SUB 2.992 Perforations & Slots Shot Top (ND) Btm (TVD) Dens GAS LIFT, i Top (ftKB) Min (ftKB) (MB) (ftKB) Zone Date (sh.- Type Comment 2,631 7,484.0 7,490.0 6,071.9 6,076.9 C-4, 2K -05 4/17/2010 6.0 APERF 2.5" MILLENIUM HMX, 60 deg phase • .�:r 7,537.0 7,545.0 6,116.3 6,123.0 A -5, 2K -05 4/17/2010 6.0 APERF 2.5" MILLENIUM HMX, 60 deg phase 7,562.0 7,598.0 6,137.2 6,167.5 A -4, 2K -05 10/29/1989 4.0 IPERF 90 deg. Phasing; 4.5" Ultra Pac Notes: General & Safety End Date Annotation 11/1/2010 NOTE: View Schematic w/ Alaska Schematic9.0 SURFACE. °■ l 354,103 GAS LIFT,_ 4,956 -.._.. •. GAS LIFT , 6,51 GAS LIFT, 7,275 k PBR. 7,318 PACKER, 7,332 a z NIPPLE, 7,370 l t.`. i SOS, 7,404 APERF, - 7.484 -7,490 Mandrel Details APERF, - - = - ;>s -- Top Depth Top Port 7,537 -7,545 (ND) I Ind OD Valve Latch Size TRO Run Stn Top (ftKB) ( ftKB) (o) Make Model (in) Sere Type Type (in) (psi) Run Date Com... 1 2,630.6 2,349.3 43.59 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/18/1991 IPERF, 2 4,955.9 4,088.0 40.15 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/18/1991 7.562 3 6,517.7 5,291.9 39.84 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/18/1991 4 7,275.2 5,897.1 33.19 CAMCO MMG -2 1 12 GAS LIFT DMY RK 0.000 0.0 3/18/1991 PRODUCTION, ,90 ' TD, 3&7 7,9326 STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Pe=rforate r Other F7 WAG to PROD Conversion Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 188 -11.8 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service f ' ' 50- 103- 20098 -00 " W 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 025588. 2K -05 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7936 feet Plugs (measured) None true vertical 6458 feet Junk (measured) None Effective Depth measured 7824 feet Packer (measured) 7332 true vertical 6314 feet (true vertical) 5944 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115 115 0 0 SURFACE 4068 12 4103 3488 0 0 PRODUCTION 7887 7 7920 6444 0 0 SCANNED APR 2 2 2013 0 P I 40 � � D 3, . Perforation depth: Measured depth: 7484'- 7490'; 7537'- 7545'; 7562' -7598' ` 4 s,, i;"; ,, 3 True Vertical Depth: 6072'- 6077'; 6116- 6123'; 6137' -6168' AOGCC Tubing (size, grade, MD, and TVD) 3.5, J - 55, 7405 MD, 6005 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER HB RETRIEVABLE PACKER @ 7332 MD and 5944 TVD SSSV - CAMCO TRDP -1A -SSA @ 1809 MD and 1726 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 950 900 Subsequent to operation 49 30 1782 1150 225 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development p Service r Stratigraphic r 16. Well Status after work: .. Oil F Gas r VVDSPL r Daily Report of Well Operations X GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Bob Christensen /Darrell Humphrey Email N1139ra a..,,d) Printed Name Robert D. Christensen Title NSK Production Engineering Specialist Signature Phone: 659 -7535 Date `1.6 ` RQDMS MAR 19 2013 401 wr- / / Form 10 -404 Revised 12/2012 4//I r f 3 Submit Original Only • • 2K -05 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03 /09 /13ICommenced Flowback ( <30 days) KUP 2K -05 ConocoP1illip5 w k Well Attributes Max Angle & M D TD Inc Wellbore AP WWI Field Name Well Status Inc, F MD (ftKB) Act Btm (ftKB) Alaska, conIlips _ 501032009800 KUPARUK RIVER UNIT INJ 44.28 2,800.00 7,936.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date .. Well Conker -2K- 05,1/11/20139: 47 52A SSSV TRDP Last WO: __ 40.19 8/10/1989 Schematic :• Actual : Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,564.0 1225/2012 Rev Reason: TAG haggea 1/10/2013 Casing Strings , I Casing Description String 0 String ID .. Top (ftKB) Set Depth (f... Set Depth (TVD) . String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H - 40 WELDED HANGER, 31 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 35.0 4,103.1 3,448.1 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd • IL PRODUCTION 7 6.276 33.0 7,919.6 6,443.7 26.00 J -55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (5103) Set Depth (1... Set Depth (TVD) ... String Wt... String . String Top Thrd • TUBING 31/2 2.992 31.1 7,404.7 6,006.7 9.30 J -55 AB -MOD Completion Details Top Depth (TVD) Top Intl Nomi... CONDUCTOR, Top (ftKB) (ftKB) (°) (tern Description Comment ID (in) 36-115 31.1 31.1 0.33 HANGER FMC GEN IV TUBING HANGER 3.500 1,808.5 1,725.7 37.46 SAFETY VLV CAMCO TRDP -1A -SSA SAFETY VALVE 2.812 7,318.0 5,932.7 32.77 PBR BAKER PBR 3.000 7,331.7 5,944.2 32.82 PACKER BAKER HB RETRIEVABLE PACKER 2.892 SAFETY vLV, 1 17' _ 7,370.3 5,976.7 32.97 NIPPLE OTIS XN NIPPLE NO GO 2.750 ■ 1,808 7,404.0 6,006.1 34.46 SOS BROWN SHEAR OUT SUB 2.992 Perforations & Slots Shot T op (TVD) Btm (TVD) Dens Top (ftKB) inn (RKB) (ftKB) (ftKB) Zone Date (sh.. Type Comment GAS LIFT 7,484.0 7,490.0 6,071.9 6,076.9 C 2K - 05 4/17/2010 6.0 APERF 2.5" MILLENIUM HMX, 60 deg phase 2,631 1 7,537.0 7,545.0 6,116.3 6,123.0 A -5, 2K -05 4/17/2010 6.0 APERF 2.5" MILLENIUM HMX, 60 deg phase 7,562.0 7,598.0 6,137.2 6,167.5 A -4, 2K -05 10/29/1989 4.0 IPERF 90 deg. Phasing; 4.5" Ultra Pac 1 : General & Safet l ' ': End Date Annotation 11/1/2010 NOTE: View Schematic w/ Alaska Schematic9.0 SURFACE, l 354,703 GAS LIFT, 4,956 IOW GAS LIFT, 6,518 GAS LIFT, 5 27 PBR, 7,318 i imago i PACKER, 7,332 NIPPLE, 7,370 -- (__ SOS, 7,404 - S APERF _ 7 484 -7,490 _ Mandrel Details APERF. _ _ Top Depth Top __ - - -- Port 7,537 -7,545 (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (MB) (ftKB) ( °) Make Model (in) Sery Type Typo (in) (psi) Run Date Com... 1 2,630.6 2,349.3 43.59 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/18/1991 IPERF, . 2 4,955.9 4,088.0 40.15 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/18/1991 7.562 - 7,598 (-- 3 6,517.7 5,291.9 39.84 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/18/1991 4 7,275.2 5,897.1 33.19 CAMCO MMG -2 1 12 GAS LIFT DMY RK 0.000 0.0 3/18/1991 PRODUCTION, 33- 7,920 TD, 7,936 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday, June 28, 2011 P.I. Supervisor ( �,fq Z 11(( SUBJECT: Mechanical Integrity Tests ( l CONOCOPI ALASKA INC 2K -05 FROM: John Crisp KUPARUK RIV UNIT 2K -05 Petroleum Inspector Src: Inspector Reviewed By: rr, P.I. Supry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2K - 05 API Well Number: 50 103 - 20098 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr110628105504 Permit Number: 188 - 118 - Inspection Date: 6/24/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 2K -05 Type Inj. G TVD 5944 IA 1830 2700 " 2624 2612 - — P.T.D1 18811x0 TypeTest SPT Test psi 1500 OA 640 _ 720 720 720 Interval 4YRTST P/F P Tubing 3650 3650 3650 3650 Notes: 1.5 bbls pumped for test. No problems witnessed. • 4 r 2 201 l .: a • Tuesday, June 28, 2011 Page 1 of 1 -~1V~~ STATE OF ALASKA ALAS AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS MAY1~2010 ~~m„~ 1. Operations Performed: Abandon "~ Repair w ell ~ Plug Perforations ~ Stimulate ~` ~~ Alter Casing ~'°" Pull Tubing ~"` Pfrrforate New Pbol Waiver ~ Time 6ctension Change Approved Program ~"" Operat. Shutdow n Perforate Re-enter Suspended Well '" 2. Operator Name: 4. Current Well Status: ~. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development '"' Exploratory "" 188-118 3. Address: ° `~ API Number: P. O. Box 100360, Anchorage, Alaska 99510 ` Service Stratigraphic 50-103-20098-00 7. Property Designation 8. Well Name and Number: ADL 25588 ~ 2K-05 9. Field/Pool(s): ~ Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7936 feet Plugs (measured) None true vertical 6458 feet Junk (measured) None Effective Depth measured 7824 feet Packer (measured) 7332 true vertical 6314 feet (true vertucal) 5945 Casing Length Size MD TVD Burst Collapse CONDUCTOR 115 16 115 115 SURFACE 4103 9.625 4103 3448 PRODUCTION 7906 7 7906 6432 Perforation depth: Measured depth: 7484'-7490', 753T_7545', 7562'-7598' r # ~~~ ~'~ ~ True Vertical Depth: 6072'-6077, 6116'-6123', 6137-6168' ~ ~f: c~~~~% `- ''} 1~ Tubing (size, grade, MD, and TVD) 3.5, J-55, 7405 MD, 6006 TVD 'f~ P Packers & SSSV (type, MD, and TVD) PACKER -BAKER'HB' PACKER 7332 M and 5945 TVD TRDP - CAMCO TRDP-1A-SSA @ 1808 MD and 1726 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1380 Subsequent to operation 3029 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory ~"° Development Service 1~. Well Status after w Oil Gas WDSPL '~` Daily Report of Well Operations XXX GSTOR .~ . GASINJ "" WINJ __ SPLUG "" 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact John Peirce (a) 265-6471 Printed Name John Peirce Title Wells Engineer Signature ~ W Phone: 265-6471 Date 5~.~2 ~~~ • ~ ` RBDMS MAY 14 Form 10-404 Revised 7/2009 f' ~:l ~.Cv ~r / Submit Original Only 2K-05 Perf Work Summary DATE SUMMARY 4/17/10 PERFORMED PERFORATIONS O 5 SANDS AND C4 SANDS. PERFORAT~C4 SAND FROM 7484' - 7490' AND PERFORATED A5 SAND FROM 7537' - 7545'. CORRELATED TO HES CBL DATED 26 SEP 1989 AND SWS PERF LOG DATED 19 OCT 1989. GUNS WERE 2.5" 6SPF 60 DEG PHASING MILLENNIUM HMX. NEEDED 5000 PSI ON SSSV TO PASS THROUGH. KUP ..,. _ _. ~t)t'°lt7CC?~11~~1~l5 ~~ Well Attributes ` Wellbore APVU WI Fieltl Name Well Status '"~`I ~I" _ .~ 501032009800 KUPARUK RIVER UNIT INJ C ment ~,R25 (ppm) (Date (Annotation /End Date ,- wen comg. zK-o¢,an 6rlo o ".:a.;~~~ _~~ - SSSV: TRDP Last WO: -_ _ Srl~emaT A t nl '~A otation (Depth (ftKB) End Date Annotation Last TaD~ SLM 7.570.0 2!1312010 (Rev Reason: ADD PERFS w1~lslrx99au~lnu• CONDUCTOR, 11s sAFETV vLV, __ 1,608 GAS LIFT. 2,83'1 SURFACE, a.1o3 GAS LIFT. 4.956 GAS LIFT, 6,518 GAS LIFT, ].2]5 PBR, 7.318 ~'ACKFR, 7,332- NIPPLE, ] 3]0 SOS, ],404 TTL. ],405 APERF. 7.464-7.496 APERF. 7.537-7,545 IPERF. _ -~-y ],562-].598 PRODUCTION, 7.906 TD, 7.536 2K-05 D t Btrn (HKB) 7,936.0 d Release Dat 8/10/1989 d Data 16 15.062 0.0 115.0 115.0 62.50 H~0 9 S/S 8.765 0 0 4,103.0 3,448.0 36.00 J-55 7 6.151 0.0 7,906.0 6,431.9 26.OOIJ-56 g ~ Stang ID OD Set Depth Set Depth (ND) String Wt SUmg (n) '~~ (~n) To p (HKB) (ftKB) (ftKB) (Ibs/ft) Grade ',. String Top Thrd 3 1/2~ - I. 2 992111 T R Jewel bin 0.0 8 R 7,405.0 trievable 6,006.91 Fish etc ) 9.30 J SS AB-MOD ry; u g Inc! un e , . ,_ ') Description Comment Run Date (ID (ir 7.46 SAFETY VLV Camco TRDP-tA-SSA 10/30/1989 i 2.81 4,088.1' 40.15 GAS LIFT MERLA/TMPD/1lDMY/BK/U Comment: STA2 3/18!1991 5,2921 i 39 84 GAS LIFT __- MERLA/TMPDl1/DMY/BK/U Comment: STA 3 3/18/1991 5,8970' 33.19 GAS LIFT CAMCO/MMG-2/1.5/DMY/RK///Comment: STA4 3/18!1991 5,932.7 32.77 PBR Baker PBR 10/30!1989 5,944.5 32.82 PACKER Baker'HB' PACKER 10/30/1989 5,976.5 32.97 NIPPLE Otis'XN' Nipple NO GO 10/30/1989 Btm (TVD) Vens (HKB) Zone Date (sh... Type Comment 6,076.9 C-4, 2K-OS 4/1712010 6 0 APERF 2.5" MILLENIUM HMX, 60 deg phase 6,123.0 A-5, 2K-05 4/1712010 6.0 APERF 2.5" MILLENIUM HMX, 60 deg phase 6,167.5 A!, 2K-OS 10/29/1989 4.0 IPERF 90 deg. Phasing; 4.5" Ultra Pac • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2K-OS Run Date: 4/17/2010 Apri129, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K-OS Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20098-00 f i ~~ rl (~ h f'' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto v'Z c~ J ~ ~ "' ~ ~ ~ 6900 Arctic Blvd. l ~ G ~~ Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barretonhiburt~:cor~-=~ ; = ~~ a _ , , __ Date: ~ ~~ Signed: ~,. _ , - - . .. ~ S • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 29, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~f~ AUK ~ 2008 ~~''= Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped June 30, July 4 and July 20, 2008. The corrosion inhibitor/sealant was pumped June 29, June 30, JulylO,and July 24, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, M.J. Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 7/29/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2K-01 188-122 SF NA 10" 6/30/2008 2 6/29/2008 2K-02 188-121 SF NA 10" 6/30/2008 2 6/29/2008 2K-03 188-120 24" NA 24" 6/30/2008 8.5 6/29/2008 2K-05 188-118 SF NA 10" NA 2.55 7/10/2008 2K-06 189-082 SF NA 15" NA 1.27 7/10/2008 3K-13 189-095 8'1" 1.00 25" 7/4/2008 6.38 7/10/2008 2K-15 189-089 SF NA 6" 6/30/2008 1 6/30/2008 2K-17 189-119 10" NA 10" 6/30/2008 23.8 6/30/2008 2K-18 189-108 SF NA 11" NA 2.12 .7/10/2008 2K-24A 198-158 20' 2.70 14" 7/4/2008 4.68 7/10/2008 2K-22 189-115 6" NA 6" 6/30/2008 5.1 6/30/2008 2K-25 190-012 SF NA 12" NA 2.55 7/10/2008 2K-26 190-015 SF NA 10" 6/30/2008 2 6/29/2008 2K-28 201-154 3'10" NA 3"10" 6/30/2008 23.8 6/30/2008 2M-04 192-093 SF NA 20" NA 3.4 7/10/2008 2M-27 192-071 9'9" 1.2 18" 7/4/2008 2.55 7/10/2008 26-07 184-024 20' 2.7 34" 7/4/2008 5.95 7/10/2008 2V-01 183-158 24" NA 24" NA 20.4 7/24/2008 2V-02 183-161 11" NA 11" NA 1.3 7/24/2008 2V-03 183-164 24' 6" 3.40 8" 7/20/2008 5.5 7/24/2008 2V-04 183-165 20' 4" 2.80 8" 7/20/2008 5.1 7/24/2008 2V-05 183-176 SF NA 4" NA 2.1 7/24/2008 2V-09 185-037 SF NA 4" NA 1.7 7/24/2008 2V-11 185-049 SF NA 4" NA 1.7 7/24/2008 2V-12 185-050 40' 5.4 8" 7/20/2008 8.5 7/24/2008 2V-13 185-030 18" NA 18" NA 3.8 7/24/2008 2V-14 185-031 SF NA 4" NA 1.7 7/24/2008 2V-15 185-032 SF NA 4" NA 1.7 7/24/2008 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor '~erl (I h( i/7 DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-05 KUPARUK RIV UNIT 2K-05 Src: Inspector \~~\\~ FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~ Comm Well Name: KUPARUK RIV UNIT 2K-05 API Well Number: 50-103-20098-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS07060 1180617 Permit Number: 188-118-0 Inspection Date: 6/1/2007 ./ Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K-05 Type Inj. G TVD 5945 IA , 900 2380 2310 2310 P.T.D 1881180 TypeTest SPT Test psi 1500 OA I 440 460 460 460 Interval 4YRTST P/F P /' Tubing I 3750 3750 3750 3750 Notes: Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. ¡/' sCANNED JUN 2 0 2007 Wednesday, June 06, 2007 Page 1 of 1 MEMORANDUM TO: THRU: Randy Rued rich Commissioner Jim Regg ,,'~,, P.I. Supervisor FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 14, 2003 SUBJECT: Mechanical Integrity Tests Conoco/Phillips Kuparuk River Field 2K Pad Kuparuk River Unit NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. We,I 2K-0S IType,nj.I S I T.V.D. I ~ I Tubingl 2200 122oo I 2200 122oo I,nterva, I 4 I P.T.D.I 1881180 ITypetestl P ITestpsil 3000 I Casingl 1380 I 2980 I 294O I 2930 I P/F I P Notes: OA 600 psi. pretest 680 psi. during test. 4.5 BBL. Pumped. I Well] 2K-06 ITypelnj.I s I T.V.D. l e0o6I Tubi.gI23~0 I~0 I 2310 I 2310 IlntervalJ 4 P.T.D.I 1890820]Typetest] P ITestpsil 3000 I Casingl 1320I 3010 I 2980 I 2975 I P/F I Notes: OA 9§0 psi. during test. 2.6 BBL. Pumped. VVe,,I =~.,o [~,,e,.j.I ~ I T.V.D. I ~ ITMI ~o I ~o I ~o I ~o I,.,e~a,I 4' P.T.D.] 1890590,TypetestI P ITestpsil 3000.l CasingI 410 I 2960 I 2910 I 2900I P/F Notes: OA 200 psi. during test. 5.4 BBL. Pumped We,,I2K-~3 I Type,nj.I SI T.V.~. I ~ ITMI ~01~4~0 I =4~0 I ~4~0 I,nte~va, I 4 P.T.D.I 1890950ITypetestl P I Testpsil 3000 I Casingl 1220 I 2940 I 2875 I 2860 I P/F I -P-P Notes: OA 850 psi, pretest 1020 during test, 4.5 BBL. Pumped. We,I ~-~ I T~pe,.J.I S I T.V.D. I~00 I Tub,~a125~0 125~0 12~0 12~0 I,~terv~,l 4 P.T.O.I 1891080 ITypetestl P ITestpsil 300O I Casingl 1320 I 2980 I 2925 I 2900 I P/F Notes: OA 300 psi. during test, 5 BBL. Pumped. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) 4 year MIT's witnessed. No failures. Test's Details M.I.T.'s performed: 4 Attachments: Number of Failures: 0 Total Time during tests: 4 hrs, CC: MIT report form 5/12/00 L.G. 2003-0614_MIT_KRU_2K-18_jc.xls 6/24/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD / UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuld KRU/2K 06/14/03 Sauvageau/Brake - APC John Cdsp Well 12K-05 P.T.D.It88tt80 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. [ I I I Ty. peTest Test psiI 1500 I Casing I 138°1 29801 29401 29301 P/F Well 12K-06 P.T.D. IIS90820 Notes: Type Test TestpsiI 1502 I Casing I 13201 30101 29801 29751 P/F , We"12K-lO P,TiD.I ~ 890590 Notes: Type Test Test psiI 1500 I Casingl 4101 29601 29101 29751 P/F P.T.D;I~890950 TypeTest Test psiI 1535 I Casing I 12201 29401 28751 28601 P/F Notes: .. P.,T.D.I~89~080 TypeTest Test ps.!I 1500 I Casing I 13201 29801 29201 29001 P/F Notes: ' We, 12K-20 I Typelnj [ Sp I T.V.D. 16143 I Tubing I 20401 '20401 20401 20401'nterva'l ; .... P.T.D:I~891~80 TypeTest Test psiI 1536 I Casing I 4001 29001 28751 28501 P/F Notes: P.T;D,I1891300 Type Test Test psil 1551 I Casing I 13001 28801 28201 28001 P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 2003-0614_MIT_KRU_2K-05 06 10 13 18 20 24.xls 612512003 ~(.RU 4 yr MIT's 2K & 2T Subject: KRU 4 yr MIT's 2K & 2T Date: Sun, 15 Jun 2003 16:23:23 -0800 From: "NSK Problem Well Supv" <nl 617@conocophillips.com> To: bob_fleckenstein~admin.state.ak.us, jim_regg@admin.state.ak.us, tom_maunder~admin.state.ak.us CC: "nl 617" <nl 617@conocophillips.com> Tom, Bob, Jim, Attached are the 4 yr MIT's for injection wells on 2K and 2T. Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224 (See attached file: MIT KRU 2T 06-14-03.xls) (See attached file: MIT KRU 2K 06-14-03.xls) [~MIT KRU 2T 06-14-03.xlsI Type: EXCEL File (application/msexcel)l .i~lEncoding: base64 l ............................................................................................ ] Name: MIT KRU 2K 06-14-03.xls ~[~MIT KRU 2K 06-14-03.xls. I Type: EXCEL File (application/msexcel) ]Encoding: base64 1 of 1 6/25/2003 1:45 P~ ARCO Alaska, Inc. Post Office Bo× 100360 AnchoraGe, Alaska 99510~0360 Telephone ~07 276 !2~5 June 12, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Report of Sundry Well Operations notices in the Kuparuk field. The wells are listed below. WELL ACTION 2 K - 0 5 Other 2 K - 0 6 Other 2 K- 1 0 Other 2 K- 1 2 Other 2 K- 1 8 Other 2 K - 2 0 Other If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer CC: J. R. Brandstetter ATe 1120 S. M. Renke ATe 1126 KeEl .4-9 w/o attachments RECEIVED Alaska 0il & 6as Cons, 6ommission /tnchorage ARCO Alaska, h'~c. is a Subsidiary 1. Operations Performed: 2. Name of Operator STATE OF ALASKA ALASKA OIL AND GAS ~SERVATION COMMIS~- ,,.)N REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown .. Stimulate __ Plugging Pull tubing Alter casing Repair well ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 196' FNL, 94' FEL, Sec. 2, T10N, RSE, UM At top of productive interval 1393' FNL, 1407' FWL, Sec. 1, T10N, At effective depth 1267' FNL, 1534' FWL, Sec. 1, T10N, At total depth 1229' FNL, 1575' FWL, Sec. 1, T10N~ 12. Present well condition summary Total Depth: measured 7 93 6' true vertical 6401 ' Effective depth: measured 7824' true vertical 6314' Length Size 115' 16" 41 O3' 9 5/8" 7906' 7" Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 7562'-7598' true vertical 6137'-6167' 5. Type of Well: Development Exploratory Stratigraphic Service R8E, UM RSE, UM RSE, UM ORIGINA[ Perforate Other 6. Datum elevation (DF or KB) 154' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-05 feet Plugs (measured) feet None feet Junk (measured) feet None 9. Permit number/approval number 88-118 10. APl number 50-1 03-20098 11. Field/Pool Kuparuk River Oil Pool Cemented Measured depth True vertical depth 115' 115' 997 Sx AS III & 41 03' 3448' 650 Sx Class G 310 Sx Class G 7906' 6431' 4.5" Ultrapal @ 4 SPF Tubing (size, grade, and measured depth) 3.5" J-55 set at 7404' Packers and SSSV (type and measured depth) Brown HB @ 7331', Camco TRDP-1A-SSA @ 1808' 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) feet RECEIVED Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation JUN 1 4 1991 Alaska 0il & Gas Cons. Commission Anchnmaa Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 570 1910 40 750 - 0 - 0 - 2000 1200 Status of well classification as: Water Injector ~ Oil m Gas Suspended 16. 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Tubing Pressure 295 2100 Service Date &-//2. ~ SUBMIT IN DUPLICATE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 ARCO Alaska, Inc~ Subsidiary of Atlantic Richfield Company WELL IPBDT '~NTRACTOR REMARKS FIELD- DISTRICT- STATE OPERA/~IONAT R~PORT TIME C.C.,' WELL SERVICE REPORT I ?;oo - EO:oo - Ro;~5 - .RZ' 3o - fvlI_ T- Co w4.o, I'"1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION ~MIb,~JON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 196' FNL, 94' FEL, SEC 2, T10N, R8E, UM At top of productive interval 1393' FNL, 1407' FWL, SEC 1, T10N, R8E, UM At effective depth 1267' FNL, 1534' FWL, Sec.1, T10N, R8E, UM At total depth 1229' FNL, 1575' FWL~ Sec. 1, T10N, R8E, UM 12. Present well condition summary Total Depth: measured 7 9 3 6 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service feet Plugs (measured) Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical 64 01 measured 7 8 2 4 true vertical 63 1 4 Length Size 115' 16" 4103' 9 5/8" 7906' 7" feet feet feet Junk (measured) Cemented 997 Sx AS III & 650 Sx Class G 310 Sx Class G measured 7,562'-4,598' 4.5" Ultrapal @ 4 SPF true vertical 6,137'-6,167' Tubing (size, grade, and measured depth) 3.5" J-55 set at 7,404' Packers and SSSV (type and measured depth) Brown HB @, 7~331'~ Camco TRDP-1A-SSA ~ 1808' 13. Attachments Description summary of proposal _ 6. Datum elevation (DF or KB) FIKB 154 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-05 feet 9. Permit number 88-118 10. APl number SOd 03-20098 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured de~h Trueve~icalde~h 115' 115' 4103' 3448' 7906' 6431' RECEIVED Detailed operation program X BOP sketch Gas Cons. Commissl0~ -- Convert well from oil producer to water injector. (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: March 1991 Oil __ Gas __ Suspended 6. If^proposal ~s verbally, approved 3 "Z ~Z-"~ I I~f4e~Of~a P ~~.~e "~..j~/~ '~eg~~ln Date approved Service Water Inie c~t~o r 17. I herff~ ce~if~ t for g is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY . Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test~ Subsequent form require IIAppr°'val~/N_.o./ Approved by order of the Commission Form 10-403 Rev 09/12/90 ORIGINAL SIGNED BY LONNtE C. SMITH Commissioner ,;,~pproved ~opY Returned - ' SUBMIT IN TRIPLICATE °' '~ '"-'" STATE OF ALASKA ~ ~-~ , ALASKA vlL AND GAS CONSERVATION COMMISSION ~-;~ WELL COMPLETION OR RECOMPLETION REPORT AND LOCI 1. Status of Well Classification of Service Well OIL ~ GAS [~] SUSPENDED ~ ABANDONED ~ SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 88-118 ,. 3. Address 8. APl Number P.0. Box 100360, Anchorage, AK 99510-0360 50- 103-20098 ,,. 4. Location of well at surface 9. Unit or Lease Name 196' FSL, 94' FEL, Sec. 2, T10N, R8E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1393' FNL, 1407' FWL, Sec. 1, T10N, R8E, UM 2K-5 At Total Depth 11. Field and Pool 1229' FNL, 1575' FWL, Sec. 1, T10N, R8E, UN Kuparuk River/ 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 154' RKBI ADL:25588 Kuparuk 0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ! 15. Water Depth, if offshore 16. No. of Completions 08/01/89 8/09/89 /~//~;~ ~J -_. feet MSL 1 I Survey ! I 21 Thickness of Permafrost 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Dire/etiona 20. Depth where SSSV set 7,936'MD&6401 'TVD 7824'MD&6314'TVD YES Ud NO []I 1808~ feet MDI --- 22. Type Electric or Other Logs Run DIL/CR/SP/SFL. FD£/£NI/CAL; £ET. Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSIZE!WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED ! 6" S'_' ."f 115 ' - - 9-5/8" 36# ~-~ Surf a.!03' !2-!/a.'' 997 sx AS !!! & 6508x 2!ass G 7" 26# J-55 Surf 7906' 8-~" 310sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 2§. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD} PACKER SET (MD} 7,562'-7,598' MD 3½",9.3#,J-$5 7,404' 7,331 4½" Ultrapal ~ 4 spf 6,137 ' -6,167 ' TVD 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) i Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL cHoKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED=l~ OIL-BBL GAS-MCF WATER-BBL :OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA ,, Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 Submit in duplicate / Rev. 7-1-80 WC1/29 CONTINUED ON REVERSE SIDE 'Z ' NAME Kuparuk C Kuparuk A GEOLOGIC MARKER~5 TOPS 31. LIST OF ATTACHMENTS Gyro MEAS. DEPTH TRUE VERT. DEPTH 6,072' 6,105' 5,918' 5,951 ' 30. FORMATION TESTS InclUde interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item I: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Alaska, Inc Date: Subject: From/Location: Telephone: To/Location: Internal Corresp Xnce March 11, 1991 File Code: Well File: Kuparuk Drill Site 2K Waterflood Com/esions Wells 2K-05 and 2K-12 Eric Paerels ATO-1178 263-433.9 R. Smith / J. Kralick NSK D. Miller/ J. Blackwelder NSK 2K-05 2K-12 As we discussed, this writing includes a brief procedure outlining the well work for waterflood conversions of Wells 2K-05 and 2K-12. These two wells have been recommended for conversion by G. Targac and K. Copeland in a memo dated 2-6-91 to J.Kralick and R. Sloan. These two conversions are in addition to the four wells that are presently being converted. Pressure Build-up (PBU) tests indicate that reservoir pressures in several areas of the drill site may have fallen below the bubble point. This pressure depletion can have a negative effect on the recoverable reserves of this drill site. The conversion of these two wells is of prime importance to maintaining the drill site reservoir pressure above the bubble point. Waterflood at Drill Site 2K should' recover an incremental 20% of OOIP, or 24 MMBBL of oil. The estimated initial water injection rate is 3500 BWPD per injection well. This rate should fall off after several weeks of injection as the reservoir pressure increases and a water bank is established. Ail wireline and diesel costs should be charged to the old 1990 Downhole Work Waterflood AFE number 899381. All Manifold building work should be charged to the old 1990 Facility Waterflood AFE number 899399. New 1991 Waterflood AFE charge codes will be available in the near future. If you have any questions comments, please contact me at the above number or call Letha Chapman at 265-1355. Operations Engineer Attachments cc: J.R. Brandstetter M. E. Eck G. K. Phillips S. M. Renke C. Victors / B. Fontenot / J. Kralick B. Sossamon / W. Carter C. House / A. Ealum CPF-2 Engineers ATO-1120 ATO-117~ ATO-117 ATO-11~ N~ (~~~il'd to NSK w/o attachments A~aska Oil & Gas Co~s. 6ommisslo~ ~ch0ra~a Wells 2K-05 and 2K-12 Water Injection Conversions CC: Downhole 899381 Surface 899399 3/1 1/9 1 The following is intended only as an outline, existing well conditions will dictate the exact procedure. 1 ) Obtain final 12 hour welltest. 2 ) SI well and MIRU Siickline and diesel pump truck. 3 ) RIH and set SV in "XN" nipple. Wells 2K-05 and 2K-12 are currently on gas lift. 4 ) Pump diesel down casing while taking returns from tubing. Fill annulus with diesel. Casing displacement to bottom mandrel and mandrel depth are listed below: 2 K- 0 5 192 bbls 7275' MD-RKB 2 K- 1 2 172 bbls 6488' MD-RKB 5 ) RIH to replace all GLV's with DV's, Ensure annulus is filled with diesel. 6 ) Pressure test tubing to 2500 psi to ensure DV's are set, 7) RIH and pulISV. 8 ) RDMO Slickline. Notify the State of the upcoming Mechanical Integrity Tests(MIT's) 9 ) Conduct MIT tests. Packer depths and 7" annular pressures necessary are shown below. Bleed the annulus to 500 psi after completing.the test. TVD Depth Required Casing Well .~ Pressure for MIT 2K-05 5945' 2170 PSI 2K-12 6013' 2195 PSI I 0 ) Prior to initiating water injection, a diesel/xylene spear should be injected to clean up the perforations. Pump 50 bbls of diesel with 10% xylene at 2 BPM. Initiate water injection at approximately 500 BWPD and gradually increase the injection rate until the maximum injection pressure is reached. WELL 2K-05 PRODUCER APl # 501032009800 SURFACE LOCATION: 196' FSL, 94' FEL, SEC 2, T10N, R8E, UM TOP KUPARUK: 1467" FNL, 1432' FWL, SEC 1, T10N, R8E, UM DEPTHS: REFERENCED TO (7 RKB TUBING SPOOL ELEV: 31' RKB ALL DEPTHS MD-RKB 16": 62.5# H-40 @ 115, 9 5/8": 36# J-55 @ 4103' TREE: FMC GEN IV 5000 PSI BAKER PBR: 3.000" ID @ 7318' BROWN HB PKR: 2.892" ID @ 7332' OTIS 'XN' NIPPLE: 2.75' X 2.813" ID @ 7370' SHEAR OUT: 3.000" ID @ 7404' SPUD' 8/1/89 COMPLETION: 10/30/89 SSSV · CAMCO TRDP-1A-SSA ID 2.812" @ 1808' GLM1: GLM2: GLM3: GLM4: 2631' / 1.0" TMPD/GLV 4956' / 1.0" TMPD/GLV 6518' / 1.0" TMPD/GLV 7275' / 1.5" MMG-2 /GLV 3.5" 9.3# J-55 EUE ABMOD IPC TUBING TAIL @ 7405' 7": B A5 A4 :~6# J-55 7906' PBTD: 7824' HOLE ANC_~.E ACROSS KUPARUK = 32 DEGREES MAX HOLE ANGLE = 44 DEGREES @ 2800' VOLUME TO TOP PERF = 70 BBLS RECEIVED 4!,~k~ Oil ~ l~s Cons. CmmJsslo~ "~:~' ~iichorag~ 7562' 4 SPF ~ 90° PHASING ORIENTED 35° CCW 7598' FILL TAGGED AT ????' REVISION: 3/12/91 WELL 2K-12 PRODUCER APl # 501032010900 SURFACE LOCATION' 21' FSL, 94' FEL, SEC 2, T10N, R8E, UM TOP KUPARUK: 1251' FNL, 1680' FWL, SEC 12, T10N, R8E, UM DEPTHS: REFERENCED TO 0' RKB TUBING SPOOL ELEV: 31' RKB ALL DEPTHS MD-RKB 16": 62.5# H-40 @ 115' 9 5/8": 36# J-55 @ 3021' · BAKER PBR: 3.000" ID @ 6531' BROWN HB PKR: 2.892' ID @ 6545' OTIS 'XN' NIPPLE: 2.75" X 2.813" ID @ 6582' SHEAR OUT: 3.000" ID @ 6615' C B A5 A4 A3 7": 26# J-55 @ 7050' TREE: FMC GEN IV 5000 PSI PBTD: 6967' SPUD: 9/2/89 COMPLETION: 10/24/89 SSSV · CAMCO TRDP-1A-SSA ID 2.812" @ 1815' GLM1: GLM2: GLM3: GLM4: 2350' / 1.0"TMPD /GLV 4333' / 1.0"TMPD /GLV 5764' / 1.0"TMPD /GLV 6488' / 1.5' MMG-2 /GLV 3.5" 9.3# J-55 EUE ABMOD IPC TUBING TAIL @ 6616' HOLE ANGLE ACROSS KUPARUK = 27 DEGREES MAX HOLE ANGLE = 31 DEGREES @ 3900' VOLUME TO TOP PERF = 63 BBLS 6764' 2 SPF~180° PHASING ORIENTED 128°CCW 6796' FILL TAGGED AT ????' REVISION' 3/1 2/91 ARCO Oil and Gas Company Well History- Initial Report- Daily: Instructions: P,epare and submit the "initial Rel:)orl" on the first Wednesday after a weir ts spudded or workover oaeralions are started. Dairy wbrk prior to ';pudding s,~ould be summarized on the form giving inclusive dates on v. District County. parish or borough ARCO ALASKA INC. I NORTH SLOPE Field ILease or Unit KUPARUK RIVER UNIT I ADL: 25588 Auth. or W.O. no. ITitle AK3609 I COMPLETIONS State 2K-5 IWeil no. Operator ARCO Spudded or W.O. begun Date Hour SPUD 08/01/89 04:30 Date and depth as of 8:00 a,m. Complete record for each day reported NORDIC ~1 10/30/89 (12) TD: 7936 PB: 7824 SUPV:GB IARCO W.L 55.8533 Prior status if a W.O, TIH W/COMPLETION ASSB. 7"@ 7905' MW: 0.0 NaC1 MOVE RIG FROM 2K-6, ACCEPT RIG AT 1030 10/29/89, ND DRYHOLE TREE, NU BOPE, TEST BOPE TO 3000 PSI, RU SOS, PERF 7578-7598 AND 7562-7578, RD SOS, TIH W/ 3-1/2" COMPLETION ASSEMBLY, 154 JTS IN SLIGHT FLOW OVER TBG, CIRC., PUMP HEAVY PILL, CONT. TIH W/ ASSEMBLY DAILY:S165,581 CUM:$1,023,711 ETD:S1,023,711 EFC:$1,294 The above ts~ee~ect Signatur~ ~ Drilling, Pages 86 a~/~r87. Tit[e, AR3B-459-1-D Number all dally well history forme consecutively Page no. es they are prepared for each well. ARCO'~,,I and Gas Company Daily Well History-Final Report. Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or wo!l is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of tirne. On workovers when an official test is not required upon completion, report completion and representative teat data in blocks provided. The "Final Raporl" Iorm may be used for reporting the entire operation if space is available. District County or Parish ARCO ALASKA INC. NORTH SLOPE Field ILease or Unit KUPARUK RIVER UNIT I ADL: 25588 Auth. or W.O. no. ITitle AK3609 I COMPLETIONS IAccountin9 cost center code State AK 2K-5 I Well no, Operator ,~ A.R.Co. W.I. " ARCO I 55. 8533 Spudded or W.O. begun I Date SPUD I 08/01/89 Complete record for each day reported NORDIC #1 Iotal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well I our I Prlor status if a W.O. 04:30 Date and depth as of 8:00 a.m. 10/31/89 (13) ~_TD:~ 7936 PB: 78'24 suPV:GB RIG RELEASED 7"@ 7905' MW: 0.0 NaC1 CONT. TIH W/3-1/2" COMPLETION, TEST CONTROL LINE, LAND TBG, DROP BALL, PRESS. UP TBG TO 2500 PSI, SET PKR, PU AND SHEAR ?BR, LAND TBG, RILDS, PRESS ANNULUS TO 2500 PSI OK, CLOSE SSSV, BLED TBG PRESSURE, SSSV OK, PRESSURE TBG TO 3800 AND SHEAR BALL, BLED TBG PRESS., CLOSE SSSV, SET BPV, ND BOPE, NU TREE, TEST TREE AND PACKOFF TO 5000 PSI, PULL BPV, OPEN SSSV, DISPLACE ANNULUS W/ 5 BBLS DIESEL, BULLHEAD 2 BBLS DIESEL DOWN TBG, RELEASE RIG AT 1530 10-30-89 DAILY:S19,441 CUM:$1,043,152 ETD:S1,043,152 EFC:$1,294 Old TD I New TD PB Depth Released rig I Date K nd of r g Classifications (oil, gas, etc.} Type completion (single, dual, etc,) Producing method Official reserve r name(s). Potential test data Well no. Date Reservoir Producing interval Oil or gasTest time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above i~,q~rect Sig nat u re,~ ~ ~ Date-- Drilling, Pages 86 and 87. AR3B-459-3-C INumber all dally well history forms consecutively I Page no. as they are prepared for each well. I Dlvl'don of AtlantlcRIchfleldCompany October 9, 1989 Mr. Brit Brown Drilling Manager ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Boss Gyroscopic Survey Job No. AK-BO-90096 Well: 2K-5 Field: Kuparuk Survey Date: 9/16/89 Operator: T. McGuire Mr. Brown: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Also enclosed is one diskette. As per A. Thompson, copies have been sent to UNOCAL and BP EXPL. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard District Manager Directional Services Enclosures MED 8537 Corbin Drive (99507) · RO. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522-3432 A Baroid Company ARCO ALASKA, INC. 2K-5 KUPARUK ALASKA COMPUTATION DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA 9/22/89 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 0 .00 100 100.00 200 199.99 300 299.99 400 399.99 500 499.98 600 599.97 700 699.97 800 799.94 850. 849.79 900 899.48 950 948.99 1000 998.29 1050 1047.34 1100 1096.02 1150 1144.23 1200 1191.99 1250 1239.21 1300 1285.90 1350 1332.19 1400 1378.00 1450 1423.19 1500 1467.72 1550 1511.64 1600 1555.00 1650 1597.71 1700 1639.48 1750 1680.22 1800 1720.00 1900 1798.32 PAGE 1 2000 1875.65 2100 1951.79 2200 2027.66 2300 2103.26 2400 2178.06 DATE OF SURVEY: 9-16-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90096 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. -154.00 -54.00 45.99 145.99 245.99 0 0 0 26 0 36 0 10 0 36 N .00 E .00 .00 .00 S 14.10 E .44 .37S .09E S 10.30 E .16 1.26S .28E S 44.00 E .47 1.88S .48E S 15.70 W .53 2.49S .44E .00 -.30 -1.04 -1.54 -2.11 345.98 445.97 545.97 645.94 695.79 0 44 0 40 0 32 2 43 5 41 S 34.40 W .26 3.53S .07W S 43.10 W .12 4.50S .84W S 31.10 W .19 5.33S 1.49W N 22.50 E 3.26 3.54S .82W N 22.80 E 5.94 .15S .60E -3.27 -4.46 -5.48 -3.57 .10 745.48 7 5 794.99 8 54 844.29 10 14 893.34 11 58 942.02 14 19 N 24.60 E 2.81 4.95N 2.85E N 25.40 E 3.65 11.25N 5.79E N 24.70 E 2.67 18.79N 9.31E N 26.50 E 3.55 27.47N 13.48E N 27.80 E 4.74 37.59N 18.68E 5.67 12.63 20.94 30.57 41.92 990.23 1037.99 1085.21 1131.90 1178.19 16 23 17 57 2O 2O 21 36 22 49 N 26.20 E 4.23 49.39N 24.69E N 27.10 E 3.16 62.59N 31.31E N 28.00 E 4.80 77.13N 38.90E N 28.30 E 2.53 92.90N 47.35E N 28.80 E 2.49 109.50N 56.38E 55.14 69.88 86.23 104.07 122.89 1224.00 1269.19 1313.72 1357.64 1401.00 24 22 26 17 27 47 29 15 30 30 N 27.90 E 3.16 127.12N 65.88E N 26.50 E 4.02 146.15N 75.65E N 27.00 E 3.03 166.44N 85.88E N 27.00 E 2.94 187.71N 96.72E N 25.50 E 2.90 210.05N 107.73E 142.83 164.17 186.86 210.69 235.57 1443.71 32 7 1485.48 34 30 1526.22 36 20 1566.00 38 12 1644.32 38 40 N 23.80 E 3.71 233.67N 118.56E N 23.60 E 4.75 258.81N 129.60E N 23.80 E 3.71 285.35N 141.24E N 23.10 E 3.82 313.13N 153.29E N 22.60 E .56 370.43N 177.43E 261.54 289.00 317.98 348.26 410.43 1721.65 40 0 1797.79 40 48 1873.66 40 29 1949.26 41 16 2024.06 41 53 N 23.00 E 1.35 428.87N 202.00E N 23.10 E .80 488.51N 227.38E N 23.90 E .61 548.25N 253.36E N 23.90 E .79 608.09N 279.88E N 23.50 E .67 668.87N 306.55E 473.82 538.64 603.79 669.24 735.61 ARCO ALASKA, INC. 2K-5 KUPARUK ALASKA COMPUTATION DATE: SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA 9/22/89 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 2500 2252.54 2098.54 2600 2326.60 2172.60 2700 2399.43 2245.43 2800 2471.28 2317.28 2900 2542.88 2388.88 3000 2615.67 2461.67 3100 2690.32 2536.32 3200 2765.35 2611.35 3300 2839.57 2685.57 3400 2914.10 2760.10 3500 2990.07 2836.07 3600 3066.17 2912.17 3700 3141.09 2987.09 3800 3216.02 3062.02 3900 3292.55 3138.55 4000 3369.60 3215.60 4100 3445.63 3291.63 4200 3521.06 3367.06 4300 3596.27 3442.27 4400 3670.93 3516.93 4500 3745.12 3591.12 4600 3819.83 3665.83 4700 3895.26 3741.26 4800 3970.59 3816.59 4900 4045.80 3891.80 41 48 42 37 43 52 44 16 44 15 PAGE 2 42 18 41 5 41 40 42 29 41 7 39 59 40 53 42 4 40 51 39 15 DATE OF SURVEY: 9-16-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90096 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. N 23.10 E .28 730.14N 332.94E N 23.10 E .82 791.95N 359.31E N 23.40 E 1.26 854.90N 386.35E N 23.20 E .43 918.79N 413.87E N 23.00 E .14 983.00N 441.25E 802.32 869.52 938.03 1007.59 1077.40 39 55 41 5 40 58 41 28 41 56 N 22.60 E 1.97 1046.19N 467.82E N 22.90 E 1.23 1107.54N 493.55E N 23.10 E .59 1168.40N 519.38E N 23.70 E .91 1229.90N 546.00E N 23.40 E 1.37 1291.01N 572.63E 1145.94 1212.47 1278.57 1345.59 1412.25 42 16 41 2 41 1 41 13 41 13 N 23.50 E 1.14 1350.66N 598.51E N 23.60 E .90 1410.12N 624.42E N 24.00 E 1.21 1470.72N 651.15E N 23.80 E 1.22 1531.25N 677.98E N 22.90 E 1.70 1590.33N 703.49E 1477.27 1542.13 1608.36 1674.57 1738.92 5000 4121.57 3967.57 40 14 5100 4197.79 4043.79 40 27 5200 4273.90 4119.90 40 25 5300 4349.79 4195.79 40 50 5400 4426.63 4272.63 38 43 N 22.70 E .68 1649.08N 728.19E N 22.60 E 1.16 1709.03N 753.20E N 21.80 E .54 1769.81N 778.01E N 21.90 E .49 1830.98N 802.54E N 21.80 E .47 1892.73N 827.30E 1802.66 1867.60 1933.24 1999.12 2065.62 5500 4504.59 4350.59 5600 4582.44 4428.44 5700 4660.26 4506.26 5800 4738.22 4584.22 5900 4815.94 4661.94 N 21.50 E .39 1955.05N 852.03E N 20.10 E 1.53 2017.17N 875.64E N 20.20 E .07 2078.81N 898.26E N 20.20 E .20 2140.53N 920.97E N 20.20 E .02 2202.37N 943.72E 2132.64 2199.03 2264.58 2330.24 2396.03 N 19.50 E 1.09 2263.75N 965.88E N 19.50 E .21 2324.77N 987.49E N 19.40 E .07 2385.94N 1009.09E N 19.30 E .42 2447.38N 1030.67E N 16.70 E 2.69 2508.22N 1050.47E 2461.16 2525.75 2590.46 2655.42 2719.11 38 49 38 55 38 53 38 39 39 20 N 16.50 E .15 2568.23N 1068.36E N 16.60 E .13 2628.39N 1086.24E N 17.00 E .25 2688.52N 1104.39E N 17.20 E .27 2748.37N 1122.81E N 17.40 E .70 2808.45N 1141.52E 2781.29 2843.61 2906.00 2968.24 3030.80 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC. 2K-5 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 DATE OF SURVEY: 9-16-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90096 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6000 4893.28 4739.28 39 20 N 16.80 E .38 6100 4970.82 4816.82 38 58 N 15.60 E .84 6200 5048.28 4894.28 39 29 N 14.70 E .76 6300 5125.32 4971.32 39 43 N 14.50 E .26 6400 5201.85 5047.85 40 25 N 14.90 E .75 2869.04N 1160.16E 3093.81 2929.68N 1177.78E 3156.46 2990.73N 1194.30E 3219.05 3052.42N 1210.37E 3282.04 3114.68N 1226.71E 3345.67 6500 5278.15 5124.15 40 6 N 15.60 E .55 6600 5355.46 5201.46 38 36 N 17.50 E 1.92 6700 5433.96 5279.96 37 57 N 19.40 E 1.34 6800 5512.70 5358.70 38 9 N 20.70 E .82 6900 5591.55 5437.55 37 45 N 23.30 E 1.65 3177.04N 1243.71E 3409.65 3237.82N 1261.75E 3472.59 3296.59N 1281.35E 3534.31 3354.49N 1302.48E 3595.84 3411.49N 1325.51E 3657.30 7000 5671.31 5517.31 36 26 N 25.30 E 1.78 7100 5752.27 5598.27 35 26 N 28.20 E 1.97 7200 5834.44 5680.44 34 4 N 33.20 E 3.16 7300 5917.70 5763.70 33 10 N 36.30 E 1.94 7400 6001.45 5847.45 33 4 N 39.80 E 1.91 3466.46N 1350.31E 3717.60 3518.86N 1376.70E 3776.17 3567.87N 1405.75E 3832.69 3613.36N 1437.29E 3886.96 3656.37N 1470.95E 3939.81 7500 6085.06 5931.06 33 27 N 43.60 E 2.12 7600 6168.98 6014.98 32 25 N 44.30 E 1.11 7700 6254.08 6100.08 30 55 N 45.00 E 1.53 7800 6340.15 6186.15 30 16 N 47.60 E 1.48 7900 6426.52 6272.52 30 16 N 47.60 E .00 3697.30N 1507.43E 3991.87 3736.45N 1545.17E 4042.79 3773.81N 1582.06E 4091.73 3808.98N 1618.84E 4138.62 3842.97N 1656.07E 4184.60 7936 6457.61 6303.61 30 16 N 47.60 E .00 3855.20N 1669.47E 4201.16 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4201.16 FEET AT NORTH 23 DEG. 24 MIN. EAST AT MD = 7936 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 23.41 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA, INC. 2K-5 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 DATE OF SURVEY: 9-16-89 JOB NUMBER: AK-BO-90096 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL'VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 .00 -154.00 1000 998.29 844.29 2000 1875.65 1721.65 3000 2615.67 2461.67 4000 3369.60 3215.60 .00 .00 .00 18.79 N 9.31 E 1.71 1.71 428.87 N 202.00 E 124.35 122.64 1046.19 N 467.82 E 384.33 259.98 1649.08 N 728.19 E 630.40 246.06 5000 4121.57 3967.57 6000 4893.28 4739.28 7000 5671.31 5517.31 7936 6457.61 6303.61 2263.75 N 965.88 E 878.43 248.03 2869.04 N 1160.16 E 1106.72 228.29 3466.46 N 1350.31 E 1328.69 221.97 3855.20 N 1669.47 E 1478.39 149.70 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. 2K-5 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 DATE OF SURVEY: 9-16-89 JOB NUMBER: AK-BO-90096 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 .00 -154.00 .00 .00 .00 54 54.00 -100.00 .05 S .01 E .00 154 154.00 .00 .79 S .19 E .00 254 254.00 100.00 1.76 S .38 E .01 354 354.00 200.00 2.05 S .55 E .01 .00 .00 .00 .00 454 454.00 300.00 3.04 S .25 E .01 554 554.00 400.00 4.09 S .47 W .02 654 654.00 500.00 4.96 S 1.25 W .03 754 754.00 600.00 4.99 S 1.40 W .04 854 854.00 700.00 .26 N .77 E .23 .01 .01 .01 .01 .19 955 954.00 800.00 11.96 N 6.13 E 1.07 1056 1054.00 900.00 28.73 N 14.11 E 2.80 1160 1154.00 1000.00 51.98 N 25.96 E 6.19 1265 1254.00 1100.00 81.99 N 41.50 E 11.78 1373 1354.00 1200.00 117.65 N 60.84 E 19.71 .85 1.73 3.38 5.59 7.93 1484 1454.00 1300.00 160.00 N 82.60 E 30.49 1598 1554.00 1400.00 209.53 N 107.48 E 44.85 1717 1654.00 1500.00 267.96 N 133.59 E 63.62 1843 1754.00 1600.00 337.77 N 163.79 E 89.28 1971 1854.00 1700.00 412.14 N 194.90 E 117.74 10.79 14.35 18.77 25.67 28.45 2102 1954.00 1800.00 490.27 N 228.13 E 148.92 2234 2054.00 1900.00 568.81 N 262.47 E 180.64 2367 2154.00 2000.00 649.08 N 297.95 E 213.69 2501 2254.00 2100.00 731.34 N 333.45 E 247.95 2637 2354.00 2200.00 815.15 N 369.20 E 283.24 31.18 31.72 33.05 34.27 35.29 2775 2454.00 2300.00 903.30 N 407.23 E 321.87 2915 2554.00 2400.00 992.97 N 445.49 E 361.52 3051 2654.00 2500.00 1078.24 N 481.19 E 397.73 3184 2754.00 2600.00 1159.11 N 515.42 E 430.81 3319 2854.00 2700.00 1242.00 N 551.31 E 465.57 38.63 39.66 36.20 33.08 34.76 3452 2954.00 2800.00 1322.83 N 586.41 E 498.87 3583 3054.00 2900.00 1400.46 N 620.20 E 529.90 3717 3154.00 3000.00 1481.36 N 655.89 E 563.40 3850 3254.00 3100.00 1561.16 N 691.12 E 596.10 3979 3354.00 3200.00 1637.03 N 723.15 E 625.65 33.29 31.03 33.50 32.70 29.55 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. 2K-5 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 DATE OF SURVEY: 9-16-89 JOB NUMBER: AK-BO-90096 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4111 3454.00 3300.00 1715.77 N 756.01 E 657.11 31.45 4243 3554.00 3400.00 1796.40 N 788.65 E 689.65 32.54 4377 3654.00 3500.00 1878.60 N 821.65 E 723.24 33.59 4511 3754.00 3600.00 1962.56 N 854.99 E 758.00 34.76 4645 3854.00 3700.00 2045.12 N 885.87 E 791.31 33.31 4777 3954.00 3800.00 2126.89 N 915.95 E 823.94 32.63 4910 4054.00 3900.00 2209.12 N 946.20 E 856.90 32.96 5042 4154.00 4000.00 2289.62 N 975.05 E 888.48 31.58 5173 4254.00 4100.00 2369.95 N 1003.46 E 919.86 31.38 5305 4354.00 4200.00 2450.80 N 1031.85 E 951.55 31.69 5435 4454.00 4300.00 2529.24 N 1056.78 E 981.08 29.53 5563 4554.00 4400.00 2606.38 N 1079.68 E 1009.44 28.35 5691 4654.00 4500.00 2683.70 N 1102.92 E 1037.96 28.53 5820 4754.00 4600.00 2760.43 N 1126.54 E 1066.20 28.24 5949 4854.00 4700.00 2838.23 N 1150.82 E 1095.21 29.01 6078 4954.00 4800.00 2916.57 N 1174.12 E 1124.36 29.15 6207 5054.00 4900.00 2995.29 N 1195.50 E 1153.42 29.06 6337 5154.00 5000.00 3075.49 N 1216.34 E 1183.29 29.87 6468 5254.00 5100.00 3157.44 N 1238.24 E 1214.42 31.14 6598 5354.00 5200.00 3236.71 N 1261.40 E 1244.13 29.71 6725 5454.00 5300.00 3311.34 N 1286.55 E 1271.42 27.29 6852 5554.00 5400.00 3384.72 N 1314.09 E 1298.49 27.06 6978 5654.00 5500.00 3454.90 N 1344.85 E 1324.48 26.00 7102 5754.00 5600.00 3519.94 N 1377.29 E 1348.12 23.64 7223 5854.00 5700.00 3578.94 N 1413.00 E 1369.62 21.50 7343 5954.00 5800.00 3632.44 N 1451.38 E 1389.36 19.74 7462 6054.00 5900.00 3682.44 N 1493.28 E 1408.77 19.41 7582 6154.00 6000.00 3729.64 N 1538.52 E 1428.25 19.48 7699 6254.00 6100.00 3773.78 N 1582.03 E 1445.91 17.66 7816 6354.00 6200.00 3814.43 N 1624.81 E 1462.04 16.13 7936 6457.61 6303.61 3855.20 N 1669.47 E 1478.39 16.36 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 7 ARCO ALASKA, INC. 2K-5 KUPARUK ALASKA COMPUTATION DATE: 9/22/89 DATE OF SURVEY: 9-16-89 JOB NUMBER: AK-BO-90096 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MARKER 4103 3447.89 3293.89 1710.85 N 7484 6071.71 5917.71 3690.92 N 7490 6076.72 5922.72 3693.31 N 7524 6105.08 5951.08 3706.89 N 7668 6226.63 6072.63 3762.18 N 753.96 E 9 5/8" CSG 1501.35 E TOP KUPARUK C 1503.63 E BASE KUPARUK C 1516.56 E TOP KUPARUK A 1570.43 E BASE KUPARUK A 7800 6340.15 6186.15 3808.98 N 7824 6360.88 6206.88 3817.14 N 7905 6430.84 6276.84 3844.67 N 7936 6457.61 6303.61 3855.20 N 1618.84 E SURVEY DEPTH 1627.78 E PBTD 1657.93 E 7" CSG 1669.47 E TD mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm ARCO ~I~SI~ INC. 2K-5 STRATIGRAPHIC SUMMARY ....... MARKER ....... DEPTH ........ TVD ........ BKB BKB SUB-SEA COORDINATES WITH RE?. TO WELLHEAD ORIGIN: 196FSL 94FEL SEC 02 T10N R08E 9 5/8" CSG TOP KUPARUK C BASE KUPARUK C' TOP KUPARUK A BASE KUPARUK A 4103 3447.89 3293.89 1710.85N 753.96E 7484 6071.71 5917.71 3690.92N 1501.35E 7490 6076.72 5922.72 3693.31N 1503.63E 7524 6105.08 5951.08 3706.89N 1516.56E 7668 6226.63 6072.63 3762.18N 1570.43E PBTD 7824 6360.88 6206.88 3817.14N 1627.78E 7" CSG 7905 6430.84 6276.84 3844.67N 1657.93E TD 7936 6457.61 6303.61 3855.20N 1669.47E mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm COMPUTER PROGRAM - SPERRY-SUN THREE DIMENSION RADIUS OF CURVATURE ____________________________________________________m________________mm____m------e----m--~m--------m--e--mmm~--~--~--~-------- DATE OF SURVEY: 9-16-89 COMPUTATION DATE: 9/22/89 JOB NUMBER: AK-BO-90096 KELLY BUSHING ELEV. = 154.00 FT. 2K-5 KUPARUK ALASKA 9-16-89 SPERF, (-SUN HORTZONTAL DRLG. SVCS. PROJECTION START TVD = 0 FINISH TVD = 6457.61 SCALE IS 1000 FEET/IN it 6000 5000 4000 8000 2000 1000 7936 (~ soho :oho oobo ~obo soho eobo DEPARTURE 2K-5 KUPARUK ALASKA 9-16-89 SPERE~"-SUN VERTTCAL DRLG. ~SVCS. PROJECTTON START TVD = 0 FINISH TVD - 6457.61 SCALE IS 1000 FEET/IN 1000 2000 0000 4000 SO00 8000 7000 7~ 4,201.16 1oho 2oho oobo ~obo VERTICAL SECTION D]:RECT~ON - O. O0 soho 8000 ARCO Alaska, Inc. Date: December 6, 1989 Transmittal #: 7620 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 1 2 Acoustic Cement Bond Log 9 - 2 4; 8 9 4 5 8 8 - 6 9 0 6 2 K - 1 I Acoustic Cement Bond Log 9 - 2 3- 8 9 4 9 9 8 - 6 7 7 0 2 K - 0 6 Acoustic Cement Bond Log 9 - 2 2 - 8 9 5 5 0 2 - 7 9 2 0 2 K - 0 5 Acoustic Cement Bond Log 9 - 2 6 - 8 9 5 3 5 6 - 7 8 0 3 2 K - 01 Acoustic Cement Bond Log 9 - 2 3 - 8 9 5 8 3 8 - 8 4 4 0 Receipt Acknowledged: RECEIVED ............ Anchorage DISTRIBUTION' NSK Drilling State ~"~KA OIL ANDGASCONSERVATIONCOk ~-"~SION r~ R I G IN A AppL,GATION FOR SUNDRY APPROVALS" 1. Type of Request: Abandon _ Suspend _ Operation Shutdown ~ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Exploratory Stratigraphic Service 4. Location of well at surface 196' FNL, 94' FWL, Sec. 2, T10N, R8E, UM At top of productive interval 1328' FSL, 1259 FWL, Sec. 1, T10N, R8E, UM At effective depth 1094' FSL, 1328' FWL, Sec.1 T10N, R8E, UM At total depth 1026' FSL, 1347' FWL, Sec. 1, T10N, R8E, UM (approx) (approx) (approx) 12. Present well condition summary Total Depth: Effective depth: measured 7 9 3 6' (approx) true vertical 6401' measured 7 8 2 4' (approx) true vertical 6 31 4 feet feet feet feet Plugs (measured) None Junk (measured) None RKB 154 7. Unit or Property name Kuparuk River Unit feet 8. Well Number 2k-5 9. Permit number 88-118 10. APl number 50-1 03-20098 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 4070' 9 5/8" 7872' 7" measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) Cemented Measured depth True vertical depth (approx) 179 Sx AS I 115' 115' 997 Sx AS III & 4103' 3208' 650 Sx Class G 310 Sx Class G 7905' 6377' RECEIVED AUG 2.5 Alaska Oil & Gas Cons. C0mmJsd0rt Anchorage 13. Attachments Description summary of proposal Detailed operation program X BOP sketch 14. Estimated date for commencing operation O~tob~r, 1989 16. If proposal was ~verbally approved 15. Status of well classification as:, Oil X Gas _ Suspended Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~.~T--~.~L ~ (~~,~ Title Area Drilling Engineer Signed FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10-~ IIAppr°val No.~,, ?~2~"-_ Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY ! nt~kllF R. SMITH Commissioner Approved Copy Returned - Date (~' ~ J~)f SUBMIT IN TRIPLICATE ARCO Oil and Gas Company Well History Initial Report - Dailyi! In~tmctlone: Prepare and submit the '*Initial R~it" on the first Wednesday after a well Is spudded or workover operetlone are started. Daily work prior to S~udding should be summarized on the form giving inclusive dates only, District ARCO ALASKA INC. KUPARUK RIVER County. parish or borough NORTH SLOPE Lease or Unit ADL: 25588 AKL: 2674 Title ' DRILLING Field Auth. or W.O. no. AK3609 [Sta~ Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 08/01/89 ( TD: 200'( SUPV:CD Ioete 08/01/89 iHOur Complete record for each day reported DOYON 14 08/02/89 ( TD: 2446'( 2: SUPV:CD 08/03/89 ( TD: 4121' ( 1 SUPV:JR/JG 08/04/89 ( TD: 4121'( SUPV:JR/JG 08/05/89 ( TD: 6090' ( I .) :00) ) 46) ) 75) 04:30 DRLG F/200' MW: 8.SVIS: 81 ACCEPT RIG 2400 7/31/89, NU DIVERTER SYSTEM, CHANGE OUT. KELLY TO 5-1/4", PU BHA, FUNCTION TEST DIVERTER, DRLG F/115-200 DAILY:S42,614 CUM:$42,614 ETD:S42,614 EFC:$1,294 DRLG F/2446 MW: 9.0 VIS;108 DRLG F/200-747, KICKOFF W/MOTOR & BENT SUB, DRLG F/747-1839 (COAL STRINGERS AT 1200, 1400-1600), CBU, DROP SINGLE SHOT, TOH, PU BIT 92 & BHA ~2, TIH, DRLG F/1839-2446 DAILY:S64,323 CUM:$106,937 ETD:S106,937 EFC:$1,294 TIH W/HOLE OPENER MW: 9.4 VISt 85 DRLG F/2446-4121, CIRC & COND HOLE, SHORT TRIP TO 1780' (TIGHT SPOT), TIH, CIRC & COND, DROP SURVEY, TOH (TIGHT AT 1783' PIPE STACKS OUT), LD BHA, PU 12-1/4" HOLE OPENER DAILY:S49,818 CUM:$156,755 ETD:S156,755 EFC:$1,294 ) TESTING BOPE 9-5/8"6 4103' MW: 9.5 VIS: 45 0) CONT. LD BHA, PU 12-1/4" HOLE OPENER, TIH, REAM F/1685-1790, CONT. TIH, CIRC & COND MUD, TOH, LD BHA, RO & TIH W/9-5/8" CSG, LAND CSG, RU DOWELL, CIRC & COND MUD, PUMP 80 BBL WATE~;:!i TEST LINES TO 4000 PSI, PUMP 345 BBL AS III.CEMENT : .,~!~iiii(lZ~i[~, DROP BTM PLUG, PUMP 143 BBL CL G W/ADDITIVES, ,!i~:~:,~i~:i~[si~'e~P:e), DROP TOP PLUG, DISPm, CE W/310 SaLE WATER, SOm~ ~!=:~ilPLU~TQ~!2000 PSI, LD LANDING JT FLUSH STACK, ND DIVERTER, NU i~!~i'BOPE,~'TEST BOPE DAILY:S181,522 CUM:$338,277 ETD:S338,277 EFC:$1,294 ) 69) CIRC & COND MUD 9-5/8"@ 4103' MW: 9.1 VIS: 40 INSTALL W/B, PU BHA, TIH, DRLG FC & CMT, TEST CSG TO 2000 PSI, DRGL FS & 10' NEW HOLE, CIRC HOLE TO MUD, PERFORM LOT TO 13 PPG, DRLG F/4131-5298, CIRC., PERFORM OPENHOLE LOT (BROKE DOWN AT 10.4 PPG), DRLG F/5298-5806, CIRC & COND MUD, PERFORM OPENHOLE LOT (HELD AT 10.4 PPG EMW), DRLG F/5806-6090 DAILY:S47,894 CUM:$386,171 ETD:$386,171 EFC:$1,294 DRLG F/6830. 9-5/8"@ 4103' MW: 9.3 VIS: 42 CIRC & COND,. SHORT TRIP TO CSG ( TIGHT F/5318-5477), CIRC, TOH, LD TURBINE, PU ROT BHA, TIH, REAM F/6030-6090, DRLG F/6090-6607, CIRC, PERFORM OPENHOLE LOT TO 11.7 EMW (HELD), DROP SURV, DRLG F/6607-6830 DAILY:S59,127 CUM:$445,298 ETD:S445,298 EFC:$1,294 ) ~0) ARCO W.I. 55.8533 Prior status if a W.O. The above ~.~rrect For form preparation an~y'~stribution, /"~, see Procedures Manual, (Sdction ~0. Drilling. Pages 86 and 87%.) IDate / / I Iitle AR3B-459-1-D Number all daily well history forms consecutively .as they are prepared for each well. Page no. ARCO ,..,, and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lnlerlm" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion, District ICounty or Parish I State Field ILease or Unit IWell no. KUPARUK RIVER ~ ADL: 25588 AKL:2674 2~-5 Complete record for each day while drilling or workover in progress DOYON 14 Date and deptl~ as of 8:00 a.m. 08/07/89 ( TD: 7303'( SUPV:JR/JG 08/08/89 ( TD: 7884'( SUPV:JR/JG 08/09/89 ( TD: 7936'( SUPV:JR/JG O8/lO/89 ( TD: 7936 ?B: SUPV:CD 7) 473) 8) 581) 9) 52) CIRC & COND MUD 9-5/8"@ 4103' MW: 0.0 VIS: DRLG F/6830-7303, CIRC, PERFORM OH LOT TO 11.7 EMW, SHORT TRIP TO CSG, PERFORM OH LOT TO 11.7 EMW, DROP SURV, CIRC & RAISE MW TO 11.2 PPG, CIRC & COND MUD (FLOWLINE VIS INCR, DILUTED W/ H20 & DESCO) DAILY:SO CUM:$445,298 ETD:SO EFC:$1,294 9-5/8"@ 4103' MW:ll.2 VIS: 44 TOH, PU BIT ~5, TIH, DRLG F/7303-7884 DAILY:S86,732 CUM:$532,030 ETD:S532,030 EFC:$1,294 TIH F/ WIPER RUN 9-5/8"@ 4103' MW:ll.2 VIS: 42 DRLG F/7884-7936, CIRC, SHORT TRIP 15 STDS, CIRC., DROP SS SURV, SPOT DISEL PILL ON BTM, TOH, RU & LOG W/ SOS (CNL, DIL,FDC,GR),RD SOS, PU BIT & TIH DAILY:S61,636 CUM:$593,666 ETD:S593,666 EFC:$1,294 CIRC W/ 7" CSG 9-5/8"@ 4103' MW:ll.2 WBM TIH TO 4908, CBU, TIH TO 5955, CBU, TIH TO 6902, CBU, TIH TO 7936, CBU, SHORT TRIP 10 STDS, CBU, TOH LDDP, PULL W/B, RU & RUN 201 JTS 7" CSG TO 7905, RU CMT HEAD, CIRC, LOST CIRC AT 1000 STROKES, (4.7 BPM & 450 PSI), SLOWED PUMP RATE TO 2.5 BPM, RETURNS IMPROVING DAILY:S219,799 CUM:$813,465 ETD:S813,465 EFC:$1,294 RECEIVED AUG 2.5 ]989 AJaska 0ii & Gas Cons. C0mmJssi0n Anchorage Tho ab.~s correct For form preparatio~f"a~d distribution see Procedures M%fnualJSection 10' , Drilling, Pages · ~ AR38-459-2-B lNumber all daily well history forms consecutively as they are prepared for each well. JPage no. ARC~. ,.)il and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well ia Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations ere suspended for an indefinite or appreciable length of time. On workovers when an official lest Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District ARCO ALASKA INC. Field ICounty or Parish NORTH SLOPE Lease or Unit ADL: 25588 Title DRILLING State IWell no, KUPARUK RIVER Auth. or W.O. no. AK3609 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. ALK: 2674 A.R.Co. W.i. 55.8533 IDate 08/10/89 Complete record for each day reposed DOYON 14 08/11/89 (1.) TD: 7936 PB: 7824 SUPV:CD Iotalnumber of wells (active or inactive) on this cst center prior to plugging and I bandonment of this well I our ~ Prior status if a W.O. I 04:30 RIG RELEASED 7"@ 7905' MW:ll.2 BRINE CMT W/10BBL CHEMICAL WASH, 20 BBL SPACER 3000 @12.2 PPG, 65 BBL CMT SLURRY (310 SX CL G, 3% KCL,.9%D127, .3% Dl13, .2% D46 @ 15.8 PPG), DISPLACED W/ 11.2 BRINE, BUMPED PLUG, FLOATS HELD, ND BOPE, SET 7" SLIPS, INSTALL PACKOFF, NU TUBING SPOOL, ADAPTER, & MASTER VALVE, TEST PACKOFF TO 3000 PSI, RIG RELEASED 1200 HRS 8/10/89 DAILY:S44,665 CUM:$858,130 ETD:S858,130 EFC:$1,294 Old TD New TD Released rig Classifications (oil. gas, etc.) Producing method Potential test data Date IPB Depth Kind of rig IType completion (single, dual, etc.) Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above i/~rect sFD~ri, ?nrr~ ~Pdar~rP~~t, r~ nb%* ~n' AR3B-459-3-C Number all daily well history forms consecutively I Page no. as they are prepared for each well. I I Division of AllsntlcRIchfleldCompany ARCO Alaska, Inc. Date: August 25, 1989 Transmittal #: 7544 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 0 6 LWD EDIT Tape and Listing 8 - 2 0 - 8 9 # 7 3 4 3 4 2 K - 0 6' OH EDIT Tape and Listing 8 - 2 0 - 8 9 # 7 3 4 3 5 2 K - 0 5 OH EDIT Tape and Listing 8 - 2 0 - 8 9 # 7 3 4 2 8 Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: Craig Suchland State of Alaska ARCO Alaska, Inc. Date: August 18, 1989 Transmittal #: 7540 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2K-05 2" & 5" Raw FDC 8-08-89 7290-7896 2K-05 2"& 5" Porostiy FDC 8-08-90 7290-7896 2K-05 2" Dual Induction - SFL 8-08-89 1000-7922 2 K - 05 5" Dual Induction - SFL 8 - 08 - 89 1 000 - 7922 2K-05 Cyberlook 8-09-89 7390-7850 Receipt Acknowledged: DISTRIBUTION: NSK Franzen State of Alaska(+sepia) Drilling D&M L. Johnston(vendor package) AL '~-".A OIL AND GAS CONSERVATION COMM' "-" ~N 0 g 1 G IN A APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _X__ Repair well Change approved program ~X Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance .~ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P, O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 196' FSL, 94' FEL, Sec. 2, T10N, R8E, UM At top of productive interval 1320' FNL, 1320' FWL, Sec. 1, T10N, R8E, UM At effective depth At total depth 1128' FNL~ 1392' FWL~ Sec. 1~ T10N~ R8E~ UM 12. Present well condition summary Total Depth: measured feet true vertical feet Effective depth: measured feet true vertical feet Casing Length Size Structural Conductor Surface 3 92 5' 9 5/8" Intermediate Production 7 8 0 9' 7" Liner Perforation depth: measured Plugs (measured) Junk (measured) Cemented 6. Datum elevation (DF or KB) RKB 154' 7. Unit or Property name Kuparuk River Unit true vertical Tubing (size, grade, and measured depth Packers and SSSV (type and measured depth) 8. Well number 2K-5 feet 9. Permit number 88-118 10. APl number 5o-1 03-20098 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth To Surface 3 9 6 0' 3 4 5 2' 500' above the 7 8 4 4' 6 3 41 ' Kuparuk 13. Attachments Description summary of proposal X Revised casing program. 9-5/8" casing setting depth 14. Estimated date for commencing operation Spudded well 8/1/89 16. If proposal was verbally approved Name of approver Date approved Detailed operation program w BOP sketch changed from 3365' MD to 3960' MD 15. Status of well classification as: Oil m Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned ~)~ ~ ~.c~.a.,,~ Title Area Drilling Engineer " FOR COMMISSION USE ONLY Date ~'///~ ? Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test w Mechanical Integrity Test m Approved by the order of the Commission Form 10-403 Rev 06/15/88 Location clearance Subsequent form require ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner IApproval No_. ... Returned SUBMIT IN TRIPLICATE Kuparuk River Unit Well 2K-5 Change in Casing Program 9-5/8" Casing Moderate to severe lost circulation problems have been encountered while drilling the production section of hole of several of the Drill Site 2K development wells. Intermediate casing was to run to cover the LC zone in wells 2K-2 & 2K-9 to protect from expected higher Kuparuk reservoir pressures. Openhole logging on well 2K-7 has indicated several possible sands that could be the LC zone. The likeliest sand is located at 3380- 3390' TVD. As a diagnostic step for future 2K wells, the surface casing would be set past this zone (3960' MD 3452'. TVD). This would be 452' TVD deeper than the exception depth of 3000' TVD. No hydrocarbon or abnormal pressured zones are expected above this point based on previous 2K wells. The only sand between 3000' TVD and this LC zone is the K-10 Sand which has little porosity and is wet. '~'~' STATE OF ALASKA '~-~' ~ 0 ~1~~~' ~ ALASKA OIL AND GAS CONSERVATION COMMISS,ON 6 / ~ ,,~-~, APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program ~ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 196' FSL, 94'FEL, Sec. At top of productive interval 1320'FNL, 1320'FWL, Sec. At effective depth 2, TION, R8E, UM 1, TION, R8E, UM At total depth 1128'FNL, 1392'FWL, Sec. 1, T10N, R8E, UM 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) RKB 154 ' 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-5 9. Permitnumber 88-118 10. APInumber 50-- 103-20098 11. Field/Pool Kuparuk River Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Structural Conductor Surface 3330 ' 9-5/8" Intermediate Production 7809 ' 7" Liner Perforation depth: measured true vertical Tubing (size. grade, and measured depth) Packers and SSSV (type and measured depth) feet Plugs (measured) feet feet Junk (measured) feet RECEIVE,D Cemented To surface LIUL 2 419, 9 Alaska 0il & Gas Cons. Commission Measured ~rchorage True vertical depth 3365'MD 2939'TVD 500' above 7844'MD 6341'TVD Kuparuk This sundry request revises the target for subject well resulting in revised casing setting depths and directional plan. 13. Attachments Description summary of proposal __ Revised Directional Plan Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation August 15, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 9 ~'~~ Title Area Drilling Engineer Date FOR COMMISSION LJSEONLY (TWM) SA1/12 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location olearance __ Mechanical Integrity Test __ Subsequent form required lO- Approved C.opY ORIGINAL SIGNED BY Returned Approved by order of the Commission LONNIE C. SMITH __~,~ Commissioner Form 10-403 Rev 06/15/88 feet I Approval No. ~__~,.~ Z~ Date SUBMIT IN TRIPLICATE ARCO ALASKA. !nc=, Ped 2K. 14e liNG= 5 Propoeed Kuparuk Field, North Slope. Aleeka 0 . RI(B ELEVAT%0#, 1 1000_ 2000 _ ~000_ 4000_ 5000 _ 6000 _ 7000 KOP TVD=700 TMD=700 DEP=O 3 BUILD 3 DE~ 9 PER lOO FT 15 21 B/ PERMAFROST TVD=1424 THD=1443 DEP-143 T/ UGNU SNDS TVD=1544 TMD=1574 DEP=197 39 EOC TVD=1942 TMD=2053 DEP=45g T/ W SAK SNDS TVD=2166 TMD=234Z DEP=651 B/ W SAK SNDS TVD=2739 TMD=3102 DEP=1142 9 5/8' CSO PT TVD=2939 TMD=3365 DEP=1313 K-lO TVD=3181 TMD=3683 DEP=1520 AVERAGE ANGLE 40 DEO 35 HI N K-5 TVD=4552 THD=5489 DEP-2694 T/ ZONE C TVD=6014 TMD=7413 DEP=3946 T~ ZONE A TVD=6066 TMD=7482 DEP=3991 TARGET CNTR TVD=6101 TMD--7528 DEP=402 B/ KUP SNDS TVD=6189 TMD=7644 DEP=4096 TD (LOG PT) TVD=6341 TMD=7844 DEP=4226 I I I 0 ! 000 2000 3000 VERTIOAL SEOTION Alaska Oil & Gas Cons. Commission'* Anchorage I I 40O0 5OOO HOR;"~'ONTAL PROJECT ION -~- ~¢ALE 1 IN, = lO00 FEET ARO0 ALASKA, !hQ. Pad 2K. ~/ell Not $ Pr'opoeed Kuper. uk Field. Nor'th Slope. Alaeka 4000 3000 z 2000 I (:3 '-r 1 000 ! 000 SURFACE LOCAT! ON 196' FSL. 94' FEL SEC. 1 000 ,, SUREAI~ WEST-EAST 0 1 000 2000 I I 3000 I TO LOCATION ~ 1128' FNL, 1392' Fk'L. SEC. I, TI ON, R8E TARGET CENTER TVD-6101 THD-?$28 OEP- 4.0,?. I NORTH ;~T64 EAST 1414. TARGET LOCAT [ ON ~ 1320' FNL, 1320' FVL SEC. 1. TI ON. RSE &laska Oil & Gas Cons, Anchorage N 20 DEO 4021 ' (TO 55 MI N E TARGET) 250 I 2OO ! 5O 1 O0 5O 0 50 I i I 400 ~s~,~~ - I! %~oo ..... \~ ' ~o_ I .......~oo oo,, ~o.J ~', ~o ~oo ,, . x X · ~o9- ~ I ',, ~ ~,oo 'x ~oo_~o / / / d 900 400 350 3OO 250 I - I ",~roo . / ~oo 200_ I " /29 200 x 500 150 [ x - .~ ~ 150 x 5OO ~ 2700 I '-~=oo , /~soo I _ ~oo I ~' ~oo, ~ I ~ / 2~oo ' 500 ~ 50 · 500 ~ ' / I ~ ~S~o I I ~ , , .. ~ ~=no p 0 t I [ [ ~w [ 100 _ 50 _ ~ 250 200 ! 50 ! O0 50 0 50 ARCO Alaska, Inc. Post Office BOx '100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 12, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Conductor As-Built Location Plat - 2K Pad (Wells I - 24) Dear Mr. Chatteron' Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4618. Sincerely, .'.';':'." 'i" 1'!::: ,r',"'ll...,., ,, r::' '4r '1'.':-!c;! II -,! If you have D. Martin Engineering Aide DM' hf Enclosure RECEIVED DEC 1 3 1988 Alaska 0il & Gas Cons. C0mmlssim] Anchorage GRU13/010 ARCO Al~t,c.k,3, Inc. is a $1Jbsidi~ry of AtlanticflichfietdCompal]y ~--J WELLS 1-12 ARE LOCATED IN _~ SECTION 2, T. I0 N., R. 8 E., o. UMIAT MERIDIAN. ~1~ ~!l[~L WELLS 13-24 ARE ~CATED IN ~ J TION X SECTION II,lION., R. 8 E., ~ ~THIS ~ UMIAT MERIDIAN. ~URV~ S~Cr~ON a e=~ S~C~O. ~ ~~ ~ D.S. 2K ~RACTED ~tes~ _ VICINITY MAP I"= Imi. ~ 14~s~5 .[ SECTION CORNER ~6~1 ~ I. CO0~INATES ARE ~SR ZONE 4. SECTION II ~O=19 SECTION ~ ~. ALL DISTANC~ SHOWN ARE TRUE. ' , ~[t 3. ELEVATIONS ARE B.P.M.S.L. 5. HORIZONTAL POSITION BASED ON 2-K CONTROL MONUMENTS PER ~NSBURY S A~OCIATES. Well ASP's ~las[:a Uti & ~ ~u,,::~. C~-~*~"" ; .......... , Dist. Dist. O.G. ~d ~ 'Y' 'X' ~M~ ~ ~NGITUDE ' F.S.L. EE.L. Elev. Elev. " I~ ~ ' ~ .... I 5,9~8,600.18 498,510.17 70° 14'56.519 150° 00'49.~35 296' i 94 114.0 118.5 2 5,958,575.14 498,510.28 70° 14' 56.27~" 150°00'49.150'' 271' ~ 11~.9 5 5,9~8,550.50 498,510.55 70° 14' 56.029" 150 ° 00' 49.128'' 246' 115.8 . 56" ' 4 5,958,525.46 498~510.06 70014' 55 784" 150°00'49.1 2~ I I 1~.8 5 5,958,500.19 498,~10.12 70014. 55.556" 150°00'49.154'' 196' ~ 115.8 6 5,958,475.14 498,510.55 70 °14' 55.289'' 150°00'49.128'' 171' ~ I : 115.8 ' 4' I 115.8 ~ 7 5~9~8,450.56 498~10.56 70°14,~5.046",, 150°00'49.127'' 146', I 8 5,958,425.50 ~ 498~510.18 70°1 54. 799 150°00' 49.1~2'' 121 11~.8 I 9 ~ 5,958,400.50 ~ 498,509.98 70014'~4.555'' 150°00'49.1~7'' 96' ~ 115.8 ilO 5,958,575.19 498~ 510.14 70° 14' ~4.506'' 150°00'49.1~5" 71' I 11~.9 ! I 5~938,550.22 498~510.14 70014' ~4.061" 150 ° 00' 49.1~3'' 46' 115.9 12 5,958 ,525.20 ~ 498,510.17 70°14' ~.815" 150°00'49.1~1" 21' 94' 115.9 ~ 118.5 F.N.L. ~ 15 5,958,2~5.51 498~10.57 70°!4'~2.950'' 150 ° 0 0' 49.125'' [ 69' 94' 113.7 118.5 14 5,9~8, 210.14 498,510.16 ~ 70°14'~2.685'' 150°00'49.1~1'' 94' ~ 115.7 il5 5~958,185.12 498,510.16 ' 70°14'~2.457'' 150°00'49.151'' ' 119' ~ !15.8 16 ~ 5,9~8, 160.11 498, ~ 10.20 70°14' 32. 191'' 150° 00' 49. 130'' 144' ' 115.8 ' I 17 5~938, 135.21 ~ 498~10.18 70°14' ~1.946" 150°00'49.130" i 169' I 1~.9 18 ] 5,938,110.19 j 498,310.29 70°14'31.700" 150°00'49.127'' 194' 114.0 i 19 5~938,085.20 ~ 498~10.27 70°14'31.454'' 150°00'49.127'' 219' 114.0. , ~21 5 938,035.16 498 310 16 70°14'30.962'' 150°0 49.130" 269' ' 114.0 [22 5,938,010.40 , 498,~10.19 70°14'30.718" ' 150°00'49.129'' 294~ 94' 114.0 23 5,937,985.32j 498,310.13 70°14'30.471'' 150°00'49.130" 319' 95' 114.0 5~937~960.29 498,310.08 70°14'30.225 150°00 49.132" . 344' 95' I 113.9 ~ 118.5 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED ,.~,. ~ .. T ,. m ~ m -- __ e ARCO STATE OF ALASKA AND THAT THIS ~.,,.,.. ................... ~ , PLAT REPRESENTS A SURVEY MADE~ .~ ~ , BY ME OR UNDER MY DIRECT SUPER d _.' DRILL SITE 2.K VISION AND THAT ALL DIMENSIONS ~* ~m ~ CONDUCTOR AS-BUILTS AND OTHER DETAILS ARE CORRECT '~'*** ~'~ ,,*"~ I I 1 ".'. ....... Well ASp's Alasl:a uti & ~;~ {;~',~:~=. u0;~ .m;;;:'::: Dist Dist. O.G. Pod Nc~ 'Y' 'X' L~]~,~II~I~ LONGITUDE F.S.L. EE.L. Elev. Elev. ,, ,,,, I 5,938,600.18 498,$10.17 70°!4'36.519" 150°00'49.133'' 296' 94' 114.0 118.5 2 5,938,575.14 498,310.28 70° 14' 36.273" 150°00'49.130'' 271' 113.9 $ 5,938,550.30 498,310.$5 70°14' 36.029" 150°00'49.128'' 246' 113.8 · 36" ' 4 5,938,5;:'5.46 498,310.06 70o14' 35 784" 150°00'49.1 222 113.8 5 5,938,500.19 498,310.12 70o14' 35.536" 150° 00'49.154'' 196' 113.8 6 5,938,475.14 498,310.33 70014'35.289'' 150°00'49.128" 171' I 113.8 7 5~938,450.36 498,310.36 70014' 35.046" 150°00'49.1:~7'' 146' 113.8 8 5,958,425.30 498~$10.18 70° 14' 34. 799'' 150°00' 49.132" 121' 113.8 9 5,938,400.30 498,309.98 70o14' 34.553" 150°00'49.137" 96' 115.8 I0 5,958~375.19 498,510.14 70° 14' 34.$06'' 150°00'49.155'' 71' 115.9 ! I 5,938,350.22 498,310.14 70o14' 34.061" 150o00'49.135'' 46' 113.9 12 5,958,325.20 498,310.17 70014' 33.815" 150°00'49.151" 21' 94' 113.9 118.5 EN.L. 13 5,938,235.$1 498,310.37 70°!4'32.930" 150 ° 0 0' 49.125'' 69' 94' 113.7 118.5 14 5,938,210.14 498,310.16 70014'32.683" 1500 00' 49. I$1'' 94' ~ 113.7 15 5,938,185.12 498,$10.16 70°14' 32.437'' 150°00' 49. 131'' 119' i !13.8 16 5,938, 160.11 . 498,$10.20 70°14' 32. 191" 150° 00' 49. 150'' 144' 113.8 17 5,938, 13,5.21 i 498,310.18 70014' 31.946" 150°00'49.130'' 169' 113.9 18 5,938, 110.19 i 498,310.29 70014' 31.700" 150°00'49.127'' 194' 114.0 19 5,938,085.20 ! 498,310.27 70014' 31.454" 150 °00' 49.127'' 219' 114.0 · 21 5,938,035.16 498,310.16 70Ol4'30.962'' 150o00'49.130" 269' 't 114.0 22 5,938,010.40 ~ 498,310.19 70°14'30,718'' 150°00'49.129" 294~ 94' 114.0 23 5,937,985.37I 498,310.13 70°14'30.471'' 150°00'49.130'' 319' 95' 114.0 24 5~957~960.29 498,310.08 70o14'30.225" 150°00'49.132'' . 344' 95' I 113.9 118.5 October 19, 1988 Telecopy No. (907) 276-7542 J B K ewin Regional Drilling Engineer ARCO Alaska, inc P 0 Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 2K-5 ARCO Alaska, Inc Permit # 88-118 Surf Loc 200'FSL, 90'FEL, Sec 2, T10N, RSE, UM Btmhoie Loc l127'FNL, 867'FWL, Sec 1, T10N, RSE, UM Dear Mr Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit-to drill does not indemnify you from the probable need to obtain additional permits required by law from other govern- mental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve.r~y"~truly yours, C V Chatterton Chairman Alaska Oil and Gas Conservation Commission BY ORDER OF THE COI~.~ISSION c: Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl la. Type of work Drill Re-Entry STATE OF ALASKA ALASKA OI- AND GAS CONSERVATION COk...,ISSION PERMIT TO DRILL 20 AAC 25.005 Redrill []1 lb. Type of well. Exploratory ~ Stratigraphic Test [] Development Oil Deepen[]1 Service [] Developement Gas [] Single Zone ~ Multiple Zone 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of wellatsurface 200'FSL, 90'FEL,$ec.2,T10N,R8E,UH Attop of productiveinterval(~ target) 1320'FNL,820'FWL,Sec.l,T10N,R8E,UH Attotaldepth 1127'FNL',867'FWL,Sec. feet ,TION,R8E,UM 13. Distance to nearest well 2K-4 25' ~ surface feet 12. Distance to nearest property line 1127' @ TD 16. To be completed for deviated wells Kickoff depth 700 feet 18. Casing program size Maximum hole angle 40~ Specifications _W_ei_gh.,tI Grad_e I CouplingI Length I 26.0# J -55 BTC I 7695 5. Datum Elevation (DF or KB) RKB 136',PAD 101'GLfeet 6. Property Designation ADL 25588 ALK 2674 7. Unit or property Name Kuparuk River Unit 8. Well nurpber 2K-5 10. Field and Pool Kuparuk River Field Kuparuk River' 0il Po 9. Approximate spud date 12/02/88 14. Number of acres in property 2560 11. Type Bond (see 20 AAC 25.025) Statewide Number #8088-26-27 Amount $500,000 Hole Casing :-' i 6 .': ,,-, 8-1/2 7" 15. Proposed depth (MD and TVD) 7729'MD 6324 ' TVD feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 1 729 psig At total depth (TVD) 2873 Quantity of cement TVD 115' psig Settin¢ Depth Top Bottom MD I TVD I MD I i , 35i 35 3320 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet (include stage data) ±200 # cf bUU sx Ab I I I & 4uO sx Class u 6324' 200 sx Class G tail Top of G 500' above Kuparuk Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ,~. Diverter Sketch,~L Drilling program ~ Drilling fluid program ~ Time vs depth plot [] Refraction analysis C Seabed report [] 20 AAC 25.050 requirements ~ 21.1herebyce/~,~atthefo~/~c~r~ ue an~d correct to the best of my knowledge . Signed / /~f'~f__~f,/////_~.~..~4./t.,'r.~,(~/ Title Regional Drilling Engineer Date/~).?-,-,-,~.~,~ ~/"' //" / / ' CommissionUseOnly~TEM) PD3/025~ ' Permit Number ' I APl number I Approval date I See ~'o(,e~ letter ~¢- //~ I 50--/o3-2_oo~' I 10/19/88 Iforotherrequirements Conditions of approval Samples required [] Yes J~ No Mud log required ~ Yes ~ No Hydrogen sulfide measures [] Yes ,~ No Directional survey required ,,,~'Yes [] No Required workin sure f~or ~ _[]2M; "~ 3M; [] 5M; [] 10M; [] 15M Other: ~~. ~.~./7. ~~~ --. by order of Approved by Commissioner the commission GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) Drill 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casing, Pressure test to 3500 psig. 11) Downsqueeze Arctic pack"and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. Circulate hole with '- OEGASSER MUD CLEANER SHALE SHAKERS STI STIR STIR TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface.Casin~ to Weight Up 9'.6-9.8 8.7-9.2 weight Up to TD 10.3 PV 15-30 5-15 9-13 Yp 20-40 8-12 8-12 Viscosity 50-100 35-40 35.45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 " 5-12 Filtrate AP1 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of .I1 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LNI~/ih RIVER UNIT 20' DIVERTER SCHEHATIC D£SCJ:IIDTIOM _ I. 16' CCNX~TCI. 2. Iq'lC SLIP-~ ~ S?ARTII~ HEN) 3. FI"lC DIVERTER .,tl,q~"iILY 'MTI4 'PdtO 2-I/16' 2OO0 m31 8,I,U. vALv~ S. 10' HCR 8ALL VALVEIV/IO' DiVIRTll LII4:I. A SINel, E VALVE ~ ~TICALL¥ I~ ~mOTiLY Cmlll~U~ TOACIIIVE KMIMiI 01VERSIO)L · 4 AK0 ALASKA, INC.. I~~ THIS DiVF. RTEA SY~T~ AS A FqC~ 20AAC2~.~) ~Ai NTENANCIE & OPERATION UPON INITI.kL INSTALLATIC~N. CLC]~, PREVEHI"F.R ~ YF. RIFY TH.k T VALVE 01~ PI~i~RLY. 2. CLOSE: ANNULAR ~ AN~ ~I, OtlM AIR Tl. lq(3~ OlVERTER LINES LrVE:RY 12 3. CLOSE ANNULAR PREVENTER IN THE EVENT ~4r iNFLUX OF WE:LL~:Xq~ FLUIDS (:IR ~AS IS DETECTED OPEN APPROPRIATE VALVE 1'0 ACHIEV~ DIVERSION. DO NOT SHUT IN WELL UNDER ANY ClRCUI'ISTANCES o, 6 D]:~ el I. 16' - 2000 I~Jl TAN(CO ~"rARTIM) 2. II * - 3000 I:~I CASIN~ lEAD 4. 1~/8' - ~ ~X PX~ ~ KI~ LI~ ACO.MA. ATCR CAPACITY TEST I. O-ECl( AI~ FILL N;O,M/.ATCR RE~INOIR TO LEVEL WITH ~IC FLUID. 2. ~ THAT ACO.M.LATCR ~ 15 ICl(X) I:~I NITH 1500 PSI ~I'REAM OF TIE REGLLATCR. 3. ~ TIIwF_, TI-EN ~ Aid. UN/'P3 SIMJLTAI~CUSLY A~ I~CI~ TI-[ TII~ AI~ PI~ ELrI~INII~ AIrTEE ALL tJNXTS N;~ ~ WITH O-IA~ING I~ arF. 4. RECa~ (:)N ~ RE)3~To TI-E ACC:E:PTABI. E L~ LIMIT IS 45 SE~ CL~ZNI$ TII~: ~ 1200 PS! 2 13-5/8" BOP STACK TI~$T i. FILL I~P STACI( AN3 O4:]<E lvlI~N/FCLD WI:TH AI:~lC DIESEl., 2. CI-E~ THAT ALL LOCI( ~ SO~11¥S IN ND_LFEAD AI~ FLLLY I;~TRACTED, SEAT TEST PLUG IN V~EZ.L~ W/TH RU~III~, JT ~ ~ IN L(XI(I:X:]V~ 3. O.OSE AI~MJLA~ ~NTER AI~D ~ KILL ~ 043<E L:ZI~E VALVES ADJACF. NT TO BCP STAO<, ALL VALVES A~) Q43KES ~43LI. D BE CPE~ 4. PI:~SSU~ UP TO 250 PSI ~ 143.D FO~ IO MIN, ~ PRE~ TO 34:X30 PST AI~ HOLD FC~ IO I~1~ ~_FED PRE~ TO 0 PSI. 5, CPEN ~ PRLr~NTER AhD ~ KILL AhD L]I~[ VALVES. CLOSE TOP PIPE ~ AI~ HCR VALVES ON KILL AI~ 04(:m~ 6, TES'T TO 250 PSI AliI3 34:130 PS/ AS ]N b-TLrp 4. 7. OCNTIN.E TESTING ALL VALVES, LZI~:...% AI~ o-a(E$ W/TH A ~50 PSI LOW AI~ 30(X) 1:~31 HIGH. TEST A,5 IN STEP 4. (3~3 N~IT PI~'.~u:u~ TF.grI' ANV CMOdE TI-~T lkOl* A FLLL CLOSIN3 POSITIVE SEAL O0<E. CN.Y 8. (:PEN TOP PII~ RAMS AJ~D CLOSE BOl'r(~ PIPE RAI~. TEST BOTTCM PIPE RAk6 TO 250 PSI AI~ 3000 PSI. OPEN BOTTOM PIPE RAk~ BACK OUT Rt,N~NG JT AI~ I0. CLOSE BLII~D ~ ~ TEST TO 250 PS! AI~ 3000 PSI. II, ~ BLII~ ~ AI~ I~TR~I;'VE TE~T ~ ~ MM~FI:LD AI~ LII~.S ~ FLLL CF ~EZZNG FLUID, SI~T ALL VALVI~ IN I~ZLLZNG I:N~ITZ~ 12. ll~ST 5'T~IPE VALVE~, ~'lmYo KELLY ~ DRILL PIPE SAFETY VALVE, AN3 Ik61DE BOP TO 250 PSI A~ 3000 PSI. I~, I~CCI~ TEST II~"CR~TICN CN BL~ PRLrvENTER 'rEST FORM, SIGN, AI~ SEI~D TO ERILLING ~:~c. RVISIIR. ~E:EKI.Y TI-EREAFTER F~ICNALLY OPERATE i)OPE I~ILY. ARCO ALASKA, Pad 2K, Nell Not 5 Propoaed Kuparuk Field, North Slope, Alaska 0 . RKB ELEVAT[ON~ 136' 1 000 _ 2000 _ 3000_ 4000_ 5000 _ 6000 _ ZOO0 ... KOP TVD=?O0 TMD=?O0 DEP=O 3 BUILD 3 DEO 9 PER 100 FT 15 21 B/ PERHAFROST TVD-1406 THD=1423; DEP-13;5 T/ UONU SNDS TVD=1526 THD-1554 DEP-188 ,39 EOC TVD-1914 THD-2016 DEP-436 T/ 14 SAK SNDS TVD-2148 THD-2319 DEP-628 K-12 TVD-2721 TMD-3;061 DEP-1100 9 5/8' CSG PT TVD-2921 THD=3320 DEP-1265 K-lO TVD-3163 THD=3634 DEP-1464 K-5 TVD-453;4 TMD-5410 DEP-2593 · · · AVERAGE ANGLE $9 DE( 28 T/ ZONE C TVD-5996 THD-7304 DEP-3;797 T/ ZONE A TVD-6048 THD-73;71 DEP-3;840 TARGET CNTR TVD-6083 THD-7416 DEP-3;869 B/ KUP SNDS TVD-6170 THD-7529 DEP-3940 ~D (LOG PT) TVD-63;24 THD-7729 DEP'406T k I I 0 1000 2000 3;000 I I 4000 5000 VERTICAL SECT[ON HORI~ .NTAL PROJECTION SCALE 1 IN. = I000 FEET ARCO ALASKA, !,o. Ped 2K. Well Not $ Propoeed Kuper'uk Field. Not'th Slope. Ala.ke 4000 WEST-EAST 1000 0 1 000 2000 TD LI:H~AT ! ON 1127' FNL. 867' SEC. 1. TI ON. RSE 3000 2000 _ 1000 . 1000 _ SURFACE TARGET CENTER TVD=60~ T~II)I?416 OE:P=~69 NORTH EAST 910 TARG~T LOCAT ! ON, 1320' FNL. 920' FWL SEC. I. TI ON. RBE SURIrACE LOOAT ! ON ' 21:)0' FSL. 90' FEL SEC. 2. TI ON. RBE N 13 DE(; 36 MI N E :3869' (TO TARGET) 550 _ 500 _ 450 _ 250 I 200 150 400 1 O0 50 I I 1 300 1 200 400. [ 1100 I ~ ~2 ~_ ~ ~oo t ~ ~oo ~o' 3od , ~ ~oo ~ ~oo 250 ~oo ~oo / - I ~ooo ~3~o [ - ~~~oo I ' ' 300 I I 1 50 0 f 1800 I I I I I I ~700 I I I 1 1600 I 900 1100 I 1 000 I I I I I I I I I I I 50 250 200 1 50 1 O0 50 5O 40( 35( 30( _ 25,' .20( .15( CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE 'DATE . Loc (3) Admin ~ (4) Casg Company ./~m~.o z~, ~-~'~....,' Lease & - YES Is the permit fee attached 2. Is well to be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. ~ 4. Is well located proper distance from other wells .................... , ~ .5. Is sufficient undedtcated acreage available in this pool ............ ~ 6. Is well to be deviated and is wellbore plat included ................ ~PC 7 Is operator the only affected party " ~:~ · .e®e..·~eeeee....... ...·..·....· , S. Can permit be approved before fif:een-day-wai= ...................... ~ ~ 9. (9 :hr: 13) i0. · ~ ,~ I~ ' ,, (i0 and 13) 12. 13. (14 thru 22) 14. 15. ,~'/~/~.~/ (5) BOPE ~.\,< .~. tm.~;L~ ('23 thru 28) (6) OTHER /£~ ~ (]29 thru 31) rev: 08/11/88 5.011 Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... __ ~?~. Is the lease number appropriate ..................................... ~Fc,_ Does the well have a unique name and number ........................ ~ ~ , 16. 17. 18. 19. 20. 21. · 22. Well No. NO ....... 23. 24. 2.5. 26. 27. 28. For 29. 30. 3i. 32. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment.procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diver:er system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diver:er and BOPE attached. Does BOPE have sufficient pressure rating - Test to 3000 psig .. Does the choke manifold comply w/API RP-53 (May 84) .... ~ ............. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabe~ conditions presented .,. Additional requirements ............................................. Additional R~rks: INITIAL GE0. UNIT CLASS STATUS AREA NO. ON/OFF'I SHO~ , POOL Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX.' .. No special'effort has been made to chronologically ~. ,. organize this category of information. ******************************* NLIROUG~,I : NORTH SLOPE API NL,iM~E~ ~ 50-103-200q8 REFERE;NC~ NO : 7342~ LIS Ta~e ve~'!f~c:at~on List:lng Schlumbe.r. qe~ AlaSKa Comput.i..no Cer~ter 20" AU.(.;- 198g 14:30 CONTINUAT1 0~,~ ~ : 1 pREvious t.~,.~,-~.,.t : ARCO, KUPAR'UK, 2K-5, APl ~50-103-20098 FIb~? NAi~'*;E : EDIT .001 SFRVICE : WI. ITC VERSION : 001A02 N~X REC S~Z,R : 1024 FTLF TYPt5 : I, AST FJLE : PAGEt COMP.Ar'!7 i',lAi,!E'-, ARCi.) AbASKA, INC, ~FLL: 2~ - 5 F 1~ F.I,D: K UP AR {J K J.~CATIOi':': 19G' F$!., & 94' t;'F!~ LiS ,~r,e Ver.l.f'lcati, or~ l,.,isti, t'~q SChlUmberger A,!as~ca Computin~ Center 20-AUG-t989 14130 P~CEI 2 DF: 15,3' GI,,, 1!.3 C~'l''''':c ' g " B 41 3 AND I.,,: ~GOER DEPTH (~}? .105 bTT SIZE ~; If !/P" (:~ 7936' '~ 05 a 84 ,,b6 m 78 ~6Q 0 78 q"'I~:iE CI~CtthAT(.ON E~,DLD: !8:00 AUGIIST 8 · I~4~,' ......... LO~(;EiR t.]~,,' BOTTON: 01.06' A~GUST 9 bP, G~glNG DTSTR!CT: LOG:"G I ~,~.~,G' E~',.IG I.'NEER: W I T~::ESS: BAY F~I~ZKE .R~BERTSON/BEAh IE~ 1347 ~L~ 13't8 GCC 2626 PCS 508 CNG 1238 b!S 1457 }~'TEI..~D REiq/~RES: 1 1/2" STA~.,~DuFF AND A tqOLE FiNUEI~" ..... wERE JibED UN TilE: DI,.,~ k;~.'rR[x DENSITY = 2,65 G/CC., FLIJID OENoT't'Y = ! 0 G/CC. ~'~EU*R(t:',~ ~;~T~IX = SAN[~ HULE COHRECTIO~.I =CAI. lPER. ';aXTi,l~l~ DEVIATION =~.~..4 DEGREES a 2658' ' 'lJHff; H[.!~ ~5YSTE~ CONTAINED 15 LBS, OF I,CM ~E.R oARRE[,, DgTE ,jEiji4 STAR'[ED: 20-AU(;-~9 LIS ~'ane verification l,i. st~.nq SChlUmber~er AlasKa Comp,ltino Center 20-AUG-19~i9 14:30 PAGE: 3 .... om~anv Name F ~ ~, U PA Rttt~ F~ e id Name W~ 2K - 5 Well Name STh.. A[.,~SKA or Province O U ~ ~ORTH ~SLOPE Cotlnty ~L 1~0~ FSL &'94' FEL Fleld'I~ocation SEC~ 02, Sect ion TO~' ' ION Township :~c 8,E Range ~[~(,~ ~~ F'RITZKE Enqineer's Name 54S365. Service Order Number APl~'' 5n-103, 200OR API Serial Number D~P~ DFPTw~, ,. C~NM~':I,. NA~E.. TENS ILD SFL!.I TE~S DPHI F~'DC C~LJT NP~4 T RCF~ RT~P CNTC CFTC TFi,~ GP Tension I t,-Deer~ Pesisttvit,v !b-.~eo i um Resistivi, tv SFT, ~naveraqpd S~.ontaneous Potential Tension DensiEv Porosity ~8 u 1 ~4: Density Delta F'~r FbC Count Pate ~ear FDC. Count ~ate Paw ~.~ear FDC Cou~t Rate [~aw war FI')C Cour~t ~ate Calioer Te~sioB ~ EI.J'I'P O 5'~ Pt)ROSITY THF~AL NE~ITR[JN P[~ROSITY C.AL Inl:~ ~TED :k'E~I'i'Rt.~,~ POROSITY t~UTPUT FR¢~ AN ~}~Pb!CATIO~ PHOG~AM ~C~.~T WCFT CrlTC CFTC Gamma Pay Tens~oD LIS ~ape Yeri t. i. cation ListJ~r! $chlumberoer AlasKa Computin~ Center 20-AUG-19@9 14130 ** SET '~ - Y. PE 64EB ** TYPF ~EPP CODE V ~I,UE; I 6 6 0 3 73 4 66 1 5 66 ~ ~8 0,5 II 66 8 12 68 i3 66 0 1.~ 65 ~T 15 66 68 16 66 1 (~ 66 O NAM~ SERV U~..*Iq' SERV! ID ORDER D~;PT FT 54836 TKNS DIL LB 54~36 ILt) D1L OMeN 54~36 I!~ DIL CH;MN 54R36 fiFLI! DIL (}!i~ 54~36 8P nil ~v ~a36 G~ DIL GAPI 5~836 DP}ti [;'DC pll 54836 R~OE ~'DC G/C3 54a3(, DPHO F'DC GtC3 5483~ FFi)C F'DC CPS 5~3{, NFDC FDC CPS 54~36 ~FP FDC CPS 5qg36 RFFD FDC CD3 54~36 C~I~I FDC 1N 54~36 GR FDC GAPI 54~36 TFNS C;'~ 1, L~ 54.~ 36 T~PP ("~uL P!j 56~36 ~NR~ CNL 5~836 RC~:~ CNL CPS 54A36 RCFT CN[: CPS 5q~36 E - C}.tAN ** ......... ......... ........ ..................... CE APl PI APl PI FII, E NUMB NUH}..' SIZE RF, PR PROCESS LOG TYPE CLASS MOD NUMB Sh.!qP EhEi~ CODE (HEX) m m m m m,m m m m ~,~mm mm m m m' m lmm mmm ,mm, ~ m Imm~ m~, m m m m mm m m m m qm mm mm m ~,~ m ~m~.lmm ~m m m mmm m ~mmm m m m 5 00 000 00 0 ~ I I 4 68 0O0O000000 5 oo 0()0 00 o i ! 1 4 68 0000000000 5 O0 000 O0 L, ], 1 I 4 b~ 0000000000 5 O0 000 O0 0 I 1 i 4 b8 0O00000000 5 00 000 () t) u 1 1 I 4 6 Fi 000 O 0 fl 0000 b O0 000 00 0 I I ! 4 68 0000000000 ~ O0 000 00 0 1 1 I 4 b~ 0000000000 5 00 n00 00 0 1 1 I 4 6~ 0000000000 b 00 000 O0 U 1 1 ! 4 68 0000000000 5 O0 000 00 0 1 1 t a 68 0000000000 5 UO 000 O0 0 1 I 1 4 08 0000000000 5 (~0 000 O0 o 1 1 I 4 6~t 0000000000 5 00 000 00 u i I 1 4 bP. o000000000 5 OO 000 On 0 1 ! 1 4 68 0000000000 5 00 0O0 00 u 1 i t 4 08 0000000000 5 0o 000 00 0 1 1 :! 4 b~ 0000000000 b 00 000 0o 0 1 1. I 4 6~ 0000000000 5 On 000 O0 0 1 1 l 4 68 0000000000 b ()0 000 uo t; I I 1 4 t~8 0000000000 5 00 000 0 t) 0 i ~ 1 4 h ~. 0 (.) 00000000 5 O0 000 00 0 ! 1 1 4~ 68 O0000OO000 5 0 t) O 00 00 0 I 1 1, 4 6 ~ 00. 00000000 5 0 (.) () 00 0 o 0 1 1 i 4 o ~ 00000 ¢.) 0000 5 () n o,, o 0 0 o L, i !. 1 4 6 fi 0 () 000 0 O () 00 LIS Tac-e Veri. fl cati. on I,~stinq ., ~ Sehlu~berqer AlasKa Computin~ CeD.,_er .ID ORPER ~ h3G YPE CLAS ~0D ~U~6 SA~P ELEa CODE (HEX) R~ C ....... ' '~'t ! I 4 6~ 0000000000 ,.: .,,,.~3.6D OO 0ct0 O0 4 68 O0000OO0~0 CFTC CNL CPS 54a365 OO aO0 oO 0 I ~ 1 4 68 0000000000 ~R , .4 ~e oooooooooo G, C,,~L GAP! 54~36D O0 000 00 ~ 1 I '~F"~ '' LR ~48365 00 I ~.-C. SG 000 oO !. ~i I 68 0000000000 ~AP, 54~365 O0 000 00 u i 1 t. 4 ~8 O00UO00000 DEpT 79421 500 '"F~'e,,,~o,DIL 2~0 . VI)C 7 F ..C 500 RdFD. FDC 14 GR,F~C 105 ~88 'I?EN8, CNb 20 TNRA .CN[, 3'522 NPOR, ~N[., ' r RTNR,C}~I~ ~ 7g~ CNTC.CN~ 2060 TFNS. CSG -999: 250 GR,CSG -999 DEPT. 790o.0a0 TENS,DIL 4!60,000 SFLU,DIL 3,077 SP,DIb 13,9i4 bPitl 'FDC ] 6.b32 RHOB. FDC 2,376 NFDC,:.: DC 754 000 RNFD,FDC 1475,000 GD, FDC,~, 105.688 TEHS,~NL 4160~000 TNRA, (,,~L 3,522 NPORiCNh 42,1$~ RTHP. C~I., 3,7B~ CN'TC, CN[, 2060.312 DEPT. 780u,O00 TENS DIb 3984,0U0 SVLU. F) ti: 2.172 SP: D!L -I 5.1 ~0 DPH!, Ft)C 8,947 RHOt~. FDC 2. 503 NFDC.VDC bi.>0. 000 R~-.~FD. FDC llbO.0O0 GR. F'0C !00.625 TENS.CNI4 3964.000 2'N~A. t'CNI, 3.301 NPOR. CNL 3a. 414 [{TN[,' C{'JL 3,51b CNTC. D' C,L 1966, , . 853 7'FNS. C5C -q99. 250 dR. CSG -99q. 250 DF'PT. 7700.000 TENS.D!L 3980.0U0 SF'L!', DIL 3.170 SP. D!L -16,953 DPHI,Vi,C ] 1,,859 RHOB.FDC 2.454 NFI.~C. F'DC 042.000 RNFIjJ. FDC 1217,000 GP.UPC It)b,93~ TENS.CNL 39H0.0i)0 '.i~'lR ~. C ~ L 3,39d HPCIR.CNL 39,719 RT,~P," ~" Clot, ..... 3.45~ Ci~TC.CNL 1966,~o3 'I'Ft.~S. CSG -909,250 OR, CSG -O99,250 bFPT. 7t~00.0()0 'PENS.L)Ih 37t~4.000 SwI,,~l, DI L 7,231 SP.DTt, -16. 922 DPI{T.Ft)C I 3.7R1 R~iOD,FDC 2,423 NF[)C. Vi)C 5Ra. fin~ R ~'~D F~C 1137.000 II,D, GR . OIL DRHtJ. FDC RFFD. FDC HPHi. CNL .~CMT,CNL CFTC ll,P. DI 1~ GR.i'}Ib ORHO.FDC RFFD.FOC N}'HI ,, CNG RCHT. Ct,~b CVTC. {'2 ~,, b gR.D!L DRHU.FDC RFFD.FDC 2 284 . ILM,DIL 105 688 rEI(IS,FDC 0 146 FFDC FDC i488 000 CAi, I~ . FDC 369 TNPH,CNL 31 ~ RCrTiCNL 594,806 GR,CNL 2.695 IbM.OIL . J.. 19 FFI)C FDC 1495.000 CAbI FDC 43.915 TNPH CNL 2016,318 R~T CNL 594.806 GR CNL 2 768 4160 000 737 5O0 4~ 289 524 105 688 1,907 ILM.D1L 100.625 TENS,FDC 0,047 FFDC,FDC 896.500 C~LI.FDC 38,064 TNPH.CNL 1965.514 RCFT.CNL 590.255 GR.CNL 2,008 3984,000 452.500 9,500 ~9,356 532.327 100,625 2.704 IL~,DIL 1(J6,938 TENS.FDC 40,I27 NPH.CNL ~20 862 .8~:666 GR.CNL 2.793 3980.000 529,500 9,313 39,630 503,873 !06.938 370~ '816 ,000 505.000 9,297 S '~a~ Verification l. isttnq a Co~putin,~ (?enter GP, wDC 86, (}63 TENS. CNL TNR~, CNL 2,748 NPOR, CNb TENS, Co , -999. 250 Ga, CSG DFPT 7500, TNR~ ' Ct~I~ 2 · 972 RTNR. CNL 3,461 TENS, CSC; -999, ~50 DF:pT. 74:00. 000 $1~'"Lt'.~, [)IL 5..404 DDNI . FI>C 3 ~ 081 NFDC.FDC 50i C:~L 3 16~ Tg~lS. CSg -999' 250 D~:PT '! 30o. 000 13 v L !]' I>., .[ L 3,579 DPH! FDC i7,183 GR.FDC 133,875 TNR~ .C~I_, 3.833 RTN~. C~L 4.073 TFNS,CSG -9°9.250 DFPT. 7200,000 SFLU. D l L 2.819 [)~H I, FPC -999,250 NFDC. FDC -999. 250 (~P. FDC -909. 250 T~R~ .C',~I,,., -o09,. . . 250 RT r.;P. C;~[, -999. 250 TFNS.CSG -999.250 DEPT. 71 O0. SFL, U, nl t, ~,662 DPHI ,FDC -999.250 NFDC. F/)C -999,259 G~, ~t)C -Q99,250 TNR~. C~,~L -~99. 250 TE~,~S. CSG -n99,250 TENS OIL SP RHOB FDC R NFO FDC TENS CNh MPOR CNL CNTC CNb GR CSG 20-AUG-~ 989 i4:30 PAGE: 3704. 000 NPH.I~ .....Nh 29. I 50 ,%'~IPH CNL 'i" ""' "k{ ' 3! 600 ~(:,NI.C, b : 24'12,536 RCFT, 258I'0 ..., '. C~L , 19 C~TC CNb 950,194 GR.CNL -999.250 29,839 ~29,859 86,063 9~.43.8 ILM,I)IL .813 TENS.[ 0,(23: ~'FD~,.DC 840,000 CALI.FDC 32,27~ INPH,CNL 2196.450 RCFTiCNL 822'39~ GR,CNL 4,375 3944;000 448:~:500 '492 ~ 6:82 96'813 3750 817 37~0 ~4 2146 -999 000 I L D . D I b 359 599 DRH~]. }"DC O0 R~ O,,FDC 000 N P ~',t i ' (] N h ~ r' N,'v, CNL 941 372 CFTC;C~L ~50 2 588 35 2321 641 972 I h ,~ , D I L 125 ~EN.=,FDC 004 FFDCiFDC 000 CALI,FDC 285 TNPHiCNL 583 RCFT,CNL 590 GR.CNt, 3,595 3780,000 320,750 39,420 5sl;6o~ 98,125 13~ 805 3~ 035 l~~'~ 000 47 682 1771 408 466.97.3 ILM,DiL TENS.FDC 'FDC,FDC .A t, :i, ~ p c TNPH,CNL RCFT,CNL GR,CNL 2 4080 46 401. 133 54 O0 5OO 586 59O 835 875 .51.4 000 i[.D.DTL 23::!72 CiR. I.)Ib 099.250 99,250 DFFi). FDC 90 2bO 999,250 RCNT.C~'~ 2q9o.250 CF .TC, C~,~L -999.~50 2.361 184.375 -999.25O -999 250 999:250 999,250 299q,250 ILM,DIL TENS,FDC FFDC,FDC CALl FDC TNPH~CNL RCFT.CNL GR.CNL 2 423 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 35q0, OOO II,D, -33,469 GR' OIL -999.250 DAHO,FDC -q9q,~50 R.FFI.). FDC -999.2b0 NPNI.C~L -999,250 -o99. ,250 C~"'~C~ .('i~L -q99,95() 3 158 !50:375 99,250 -999 250 -q99,250 ib~,DIL TE~S.FDC FFDC,FDC CAbI.FDC TNPH,CNL RCFT.CNL GR.CNL . 212 -99 .250 :999,250 999.250 -999,250 -999,250 -999,250 34, L:0.000 IL!).!3IL -30.710 G~,D!L -999,250 -999.25o RFF!),FDC -qgg,2bO ~PHI,C~L 3.229 101 !.8~ -999 25O -099:250 IL~,DIL TENS,FDC FVDC.FDC CAL!.FDC Tt~PH.CNL 3,303 '999,250 '999,250 '999,250 '999.250 LIS Tare Veritication Listin~ SChlU~beroer Alas~m Computim~ Center PAGE: -999 250 C~:~L,C~ h -999' 250 250 RCFT.CNL 2999,250 250 GR' CNL ' 999' 250 DFPT. 69 0,000 TENS ~FL~' [)!~ 6,040 SD DPHI' ' FI) -999,250 RHOB ~F~C, b~)~ -999. 250 RNF9 G~ ~ ~DC -999 ~ 250 TENS TNR~, (]~ I, ~999. 250 NPOR RTl, P.t.~.~L -909 ~250 CNTC · I'...~S.CSG -999,250 ~R 000 I L D. D I b 5.657 I t... ~4, D 1 L 9~9 GR,!~IL :85,313. ~E~S,FDC 250 D}~H(},~DC -999~250 ~FDC FDC 250 RP ~t),~[(~ -999,250 CADI F:DC 250 ~9 ~1 ).~ ~, ~ ~.I h -999~50 TNPH,CNL 250 c~:TCiCNL -q99~250 GR~CNL 25O 5,705 20 ~999,'5' :999,250 .999~50 :999,250 999,R50 -999~250 DEPT, 680~, SFI.,,I~ ~ l')In . · $49 DPHINFDC:FF{cFDC ~{~)9,250'999' 25~ RNFDRi'IOB G~, FDC -999,~50 TEN~ 'I'~RA. CN~ -909.250 NPO RTb~P CNL -999,250 CNTC TENS [ CSt -9o9' 250 GR ,FDC ,CNh ,CML ,CNL .CSG 250 ,~so r~,FFD'~OC -~9o:25o C~'FDC :999,250 DRHO, ~DC -999 ~50 FFDC,FDC 999,~50 51PMI CNb -999,~50 TN~M,CNL -99:9;250 -999;250 RCNT:C~L '999 250 RC~T~CML -999,250 -~ 99, ~ p9 CFTC. C,. h'a .99~. 25 O_ ' GR, CN 5 - 999; 250 -~99.z~0 DFpT. 9700.000 TE~ SFLU.DIL 2.92i S. DPHT.FDC -999.250 NFDC,VDC -999.250 RNFD GP.FI)C -9Qq.250 TE"NS TNR.~ c~''' · u~L '999,250 RT~P~CtqL. ...... -909 .250_ CN~ C t'..N$.CSG -999.250 GR ,DIL ,DIL .FDC , FDC , C~b ,C~b .C~tL .CSg 3~50,000 I.bD,DIL -999~250 -999,250 ~FF 250 -999, ':. -990 25u CFTCiC~fL -999,250 3 90 -999 -999 -999 006 ILM,DIL 688 TENS ~FDC ?~50 FFDC iFDC 25 CAbI .FDC ,250 ~iPH.CNL 250 RCFT,CNL 250 GR .CNL 3 089 -999 250 -999 250 -999 250 -9g9 250 -999 250 -999 250 DEPT. 6u()O,O00 TENS SFLU"n]'!, 3 377 SP DP{ii .WDC -9u9.250 RHOB NwI)C, t?DC -999,250 R{~FD GP,FDC -909.250 TENS 'I'~ R A. C ~',) I., -999~250 h~POR R~,CNL -999,250 C~,ITC TEt,~S. CSG -999. 250 GR ' D!L . , F[}C . FDC . C~L . C{',}L .CSG 3154 000 -47 750 -999 250 -999 250 -999 250 -999 250 '999,250 -999,250 ibD.DIL GR.DIL DRHO.FDC RFFD.FDC ~{PHI,CNL RCNT.CNL CFTC,CNb 3,224 124.563 '999 250 -999.250 -999,250 -999.~50 -999.250 ILg.DIL TENS.FDC FFDC,FDC CALI.FDC TNPH CNL RCFT:CNL GR.CNL 3,268 -999,250 -999.250 -999,250 -999,250 -999.250 '999,250 DFPT, 6500,000 TENS 8Vbl.!, DIL 2.839 SP DPET .{:DC -999,250 NFDC;FDC -999,250 RNFD GF,wDC -9a9,250 TENS T N l~ ~C... 1,:" I~.. - 9 g 9,25, 0 N P O R RTbP:C~g[.. -qq9.250 CNTC TENS.CSG -999. 250 GR . D I b ,DIb .FDC .FDC ,CML , C~L . C~b . CS(; 3144.000 -~9,9~9 -999.250 999,250 :999,256 :999,250 099,250 -999.~50 ILD.DIh G~.DIb DRMO.FDC RFFD.FOC ~JPHi.CNL ~CNT.CNb CFTC,C~L 2.994 115.063 -099,250 -099.250 -999.250 -999.250 '999,250 ILM,DIL TENS. FDC FFDC.FDC CAb! .FDC TMPH.CNL RC~T.CNL GR.CNL 2.992 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 DEPT, g400,O00 TENS, SF!.,,I'.DII, 3.36,4 SP. I)PM],F!)C -999.250 RHOB. NFDC'FDC -9°9.25C) RNFD. GP.FOC -q99.250 TENS, DIL OIL FDC FDC C ~i L C5~' L iO,OOO 3!67,~50 2999,250 999,750 -99q,250 -a99.250 ILO,bib GR.DIb D~{HO.FDC RFFD.FDC ~PHI.CML ~C~T,CNb 3 O95 89:875 99.~50 -999 -999~50 ILM.DIL TENS,FDC ~FDC.FDC CAL!.FDC TNPH,CNL kCFT.CNL 3,054 -999,250 999,250 2999.250 :999,250 999,250 LIS Tape ~ertf].cat!oD 1.,ist. ir~q 8ChlUmber.~er A!as~a ComDutin~ Center 20-AUG-J 989 M NP Cv,,L -qqq,250 TMNS, CSG -999,250 GR, C -999.250 CFTC,CNL -999'250 -999,~50 GR.CNL '999,250 6300. 000 TENS. 3. 222 SP -9~9,250 R~'iOB -~q 9.25(::) ~NFD .,999.25t) ENS -999,250 NP~R -999, ~50 CNTC -909.250 Ga D IL FDC .FDC CNL CN'L CN b CSG 3~94,000 ILD,DIb 5~;7$0 GR.DIL ~999~25() DRHU FDC -~99;250 PFFDiFDC , ~, -999 ~bO NPHI,CN~ ~g~O~ ~(.NT,CkL -999,~b0 -999~250 85,063 TENS.~DC 999,250 -999,250 : FFDC,FDC :999,2. 0'5 '999,2§0 ~ALI~FDC -999.250 -999.:~50 T~PH,C~L -999,~:50 -999,~50 RCFT,CNL -999,250 .999~50 GR,CNL . -999~250 DI.L 3000.000 ILD,DTL 2.795 I}M,DIL: 2 DIL -70,500 GR, t:'~II~ _[t5.000 TENS,FDC -999 99, FDC -999 FDC -999;250 DRHO; ~:[~ -q ~50 [~FI)C, ~'DC -999,250 RFFO,:~ D(~ .990.~50 CALI,FDC -999 CNb -999.2S0 NPMIi~NL -9~9'250 TNP}.'I. CML '999 CNb -999 250 RCNI"C~L : -999.25~ RC[~,CNL '999 CNL '999 250 CFTC~CND -q~O,~5 ' .CNL -999 ~.99 250 CSG -q ' 923 250 250 61 O0,000 1; '165 -999,250 -999 250 -~99' -999'250 .250 -999; 25o SP TENS NPOR CNTC, D I L, FDC PDC CML C.L CSG 2970 000 ILD,DIL -43' ~69 GR',DIb -999,250 '999.250 RF~D~FDC -999,250 NF -999 ~' . . .250 RCN~ CNb -999,250 -9991250 1 108 -999 , '999 '999 ~50 FFDC 250 Cll,,I 25~ I.'NPH 250 RCFT 250 GR D I L I FOC -999. 'DC '999 DC '999 CNL -999 C N L - 999 CNL -999 :~50 50 25O 250 25O D P H T NFDC TE NS . , DIb , FDC , FDC , (7 N L , Ci>l T, , CSC, 6000. 3, -9n9. 9o9~ -999. -909. 000 29S 250 25O 25 0 250 250 25 £) TENS SP Pi..tOB TENS N P 0 R CNTC .DIb ~DIL .FDC .FDC . CNL .CND ,CSG 3,3.43 122,938 -999.~50 -999.~50 -099,250 -999.250 -999.~50 !LM OIL TENS FDC FFDC FDC CAbI FDC TNPH CNL RCFT,CNL GR*CNL 3,2t5 '999,250 =999.250 '999,250 '999,250 '999,250 '999.250 DFPT SFLU DPHI i~ ? Lt C .DIL .FDC .FDC , C N L . C i'-:' L .CSG 5gO0, 2. -9q9 -gqg -999 -gO9 -999. 725 25O 250 250 250 250 25O TENS Si> ~HOB RNFD TENS NPOR CNTC ,DIb 29q0,O00 lb0.OIL 2,720 .DIL -57.000 GR,DIb ]33.500 ' FDC 999 25() ,FDC -999,250 DRHO, , C : ' " .FDC 999,250 RFFD,BD.. 999,250 .CNL -999.2b0 NPHi.CNL -999.250 .CNL -999,250 RCNT.CNL -999.250 .CNb -999.250 CFTC.CNb -999.250 .CSG -999,P50 !LM,DIL TENS.FDC FFOC,FD_ CAL1.PDC TNPH .CNL RCFT. CNL GR .CNL 2.680 -999,250 -999,250 -999.250 :999,250 999.250 -999,250 DKPT. DPHI,FDC NFDC.FDC TNRA.CN!~ R~NP,OF:!I, 5dO0, -999. -999. -999. -9g9, -999, 731 25O 25O 25O 25O 25O TENS. SP, RHOB. ~NFD. TENS, NPOR, CNTC, D I b DIL FDC C N h CN~ CNb 2q44.000 ib,),DIh ~'73,500 Ga i)Ih - 99.250 -999.250 ~I~'F'I), F OC -099'250 NPHI.CNb -999,250 -999.250 CFTC.CNL 121.188 -999,250 999 250 29991250 -099.250 !LM,DIL TENS,FOC FPDC.FDC CALI.FOC TNPH.CNL kCFT,CNL GP.CNL 3,786 -999.250 -999.250 :999,250 999,250 '999,250 '999,250 LIS Tape Verification Listinq Schlumberqer AlasKa Computino Centex' ...... ~t', -9q9,,. 250 GR. C, St,~ . 5700.000 TENS.DIL 4~'09 SP. Ol b ' Fi)El)it" -9991 ,' Pqo RHO[.½'FDC ,PDC ~9.), 250 RNFD,~LC . FDC -9~9. 250 TENS. CML ,CNb "999,250 NPOR,CNL -990 250 CNTC,CNh . S,.., -909.250 GR,CSG 5600.()00 TENS,DID 0i'[. 1. 867 SP, D!L [:, ~:C -999. ~50 RHOB FD~ FDC -999,250 RUFD, FDC PI ,~ -999,250 TEN~,CNL ~] ~'.U -999. 250 NPOR. CNL , .= .... ) 50 C N'B CMO: -999:250 GR.CSG ' fENS. L I')F'PT. 5500.000 ~ " D! ,SFL~. OiL ~, O! 0 SP,DI.L iJ)P~I' ,F'L)C -99.~,250 RHOBiFDC NFDC, F[)C -999,250 RNFD,FDC GR, FF~c -999,250 TENS,CNL RT:~PiC,':;[, -999,250 CNTC C. b TENS. cSG -9q9. 250 Ga,CSG 20-AUG-!gR9 I4:30 -999.250 2910.000 ILD.DI[, 52,938 :GK ~I:]~ -!1I -099,250 DRM(::][~DC ,999 -999~2b¢)REFO FDC ~999 -999.250 NPHi~CNb -999 -999 250 RCNT CNL: -999 '~99'250 , ,CNL -999 -999:.250 2~24 2920 -59 -999 -999 -999 -999 DFPT 5400,000 TENS,DIL 27b0, SFb11.' DTL 3. 004 SP. D!L -bl, DP~!! t~I..C -999 250 RHOB,FDC -999, bFf)C ' " .FDC -999.250 ~NFD,FDC 'ggg, GR.FDC '9g9,250 TEN6 CNL -999, TNR~, ,C~I., -999.2~(') NPOR:CNL -999, ~" . . C C N b - 999 R ..... '~P,C~[.~ '909 250 NTC~ . TFf¢S. CSG -909. 250 GR. CSG '999. PAGE: 5300.000 TENS.D!L 3.66U SP,DIL -999.250 RHOB.FDC '9Q9.250 RNFD.FDC -999.250 TENS.CNI~ -999.250 ~POR.CNL -909.25o CNTC.C~L -g99.25Q GR.CSG DKPT DPH T ~,FDC GR T N R A RTNR ,.r E i,~,'~ 55.] !L~{. DIL ! 0 0 .] 7: E NS, FDC 250 FFDC;FDC 25 CALI ;FDC PSO TNPH.CNL 250 .RCFT,CNL '999' 250 (;R,CNL '999', , , F [) ¢" , FL)C , _WDC ,CSG 000 ;lb?,DIb ~ 784 909 GR'Dib 102.750 1ENS,FDC 250 DRHO,FDC ~99.250 FFDC,FDC 250 ~FFD.FDC --99.250 CALI,FDC 250 NPH~, C,~L -999 250 TNPR,CNL 250 RCN~.CNL -g9g 25(3 RCFT.CNL 250 : C~TC.CNL - 99.250 GR.CNL 25O '9:99 ~50 '999 50 '999 250 [)KPT. 5200. 000 TENS, l)Ib SFbt!. D .'.I; I. 2. 862 DPhI.FD¢] -909.250 RdOB,FDC ~,~WDC. FDC -999.250 RNFD,FDC GR Of. -999 250 TENS,CNb Tt"R~.. C~;L -qq9: 250 NPOR.CML RTi~ C ~ f., -999.250 CNTC.CNb 'rF i'.~ ~: CSC -999,250 GR, CSG 366 IL~ 250 " I CAL. 2 5 0 T N P H G. DC CNL C N'L 2,369 "999 '999 '999 2.0 '999 250 '999 250 '999 250 000 ILD,DIL 3 438 GklOlb 78 250 DRHO.FDC -999 250 RFFD FDC -999 250 · ~ ' ' ~gPkI,CNU -999 250 .C~'T, .. D ' C~b -999 250 CFTC.CN~ -999 ~50 486 ~25 250 250 250 250 25O IE~,DiL , TENS.FDC FFDC,FDC CALI.FDC TNPH,CNL RCFT.CNL GR.CNL '999 -999 '9gg -999 -999 -999 593 .0 250 250 50 250 2980, -62. -999, -999 -999, -99q. -qgq, 000 ILD.DIL 219 GR,DIL 250 DRHU.FDC 2bO RFFD,FDC 250 NPHi,CNb 250 RCNT CNb 250 CFTC~C~L 250 3.808 90 5O0 -999:250 -999,2b0 -999,250 -999.250 -999.750 ILM.DIL TENS.FDC FFDC,FDC CALI.FDC TNPH.CNL ~CFT.CNL GR.CNL 3 770 -999~250 -999,250 -999,250 -999.250 -999.250 -999,250 2594. -~3. -999. -990. 'ggg, =999. :999 99q~ ooo ILL).D!L 3.048 188 GR.D!b 117.875 250 DRNO.FDC -999 250 250 ~FFD.FDC -999~50 250 NPHi.CNL 999 250 250 RCNT.C~)L :999:250 250 CFTC.CNb -999.750 ?bO ILM,DIL TENS,FDC fFDC.FDC CALI.FDC TNPH,CNL RCFT.CNL GR,CNL 2,946 '999.250 '999,250 "999,250 :999,250 999.250 '999,250 LIS TaP:e verification Listi. nq Schlumberger A! asKa Computing Center D~PT, 510 ,000 TEN~ S~ I,,U. DI!, ".953 DPt! FDC -999,25t) RHDB, FDC NFK:,.C'WD(~. , -999'250 RNFD. ~"D"C GR,~i..,(.: *999 250 TEN C,. L TNRA, C~L -9~9'250 NPO ~E}~$'CSC -909 SO . R I)F P"", ,, 5 O00.. 000 FLI, DIb 2 ~28 PMt.FDC -999~ 50 NFDC~]DC -999 250 RNFD GP. ~ DC -99f) ~ 250 TENS ~' " C~<~!, -999 250 NPOR iNRA 'CNI, -999~5(.') CNq'C ~ ,'~.. ,(.Stl -999,250 DF]PT, 4900,000 mENS SFLII, DI L 2' 265 SP DPH! F ' - < 9 250 Ri'lOB .. DC .~9 :.., . NwDC'Fhm -909 250 RNFD ~.' ~ gP F:OC -999.250 TENS TNR~'CNL, -999,250 NPOR ~L '999 250 C.~C .. F. aS -goc~ ~50 DEPT. 4itO(). 009 TENS SFGI.!. D~II, 2.313 SP DPHT. FDC -999. 250 RHOB NFDC, FDC -999. 250 RNFD GP. PDC -999. 250 TENS TNRA, CNI.: -999,25o .... NPOR RTNP. Ci<,b -999. 250 CNTC 'r~es. csa -999.250 GR DFPT, 4'700.000 TENS 8FL!~, OIL. 3.38 i SP DPHI, FDC -999. 250 RHOB NFDC. FL)C -999.250 PNFt) GR.F[)C -999.2~.0 TENS T~"RA, C~4I, -9~9.250 NPOR RTNR.CNL -999,250 CNTC TF~S. CSG -999.2~0 (;R DFPT. 4600.000 TENS SFLII.DIL 3. 162 SP D~.HI .Fi)C -999,250 RHOB Ni;'DC, V[:C -999.250 PNFD (;P FDC -999,250 T ~,~ R .~ ~ C i'~ I, - 9 ~ 9.25 0 N P 0 R RT~P.CNL -999.250 CNTC TFNS, CSG -9c~9,250 DIL , , C .:L CF! L CNL CS(; , D I L D I L ' FDC ~ ,. , F!,)C , C ~"! L ,CNL .CNL ,CSG .DIL .D!L .FDC ,FDC ~CNb CNb .CNb ,CSG .DIL . [) 1 b ,FDC ,FDC .CNL . CNL , CSG 1.).9 PAGE: 10 999,250 DRHO, FDC -~99 250 FFDC,FDC -999,250 RFFg;F!)C -.9~ 250 CALIiFDC -999 2~0 N:~:H!,(..,,~L 999 250 TNPH,C.NL -999'.230 RCN~i ;CN'b -999 250 RCFT;CNL -999 2bO C~'TC.CNL -999 250 GR;CNL '9991250 3,993 -999,250 "999,250 '999'250 '999,250 -999.250 -999,250 2604 -999 0o0 ILO,DIb 3 153 IL~.DIL , 2.99'5 9o9 G~,OIh 79 875 ~EN~,FDC ~:999,250 250 DRHO;FDC -999 ~50 ~FDC,FDC 999;~50 50 NPHI,CNL -990 250 TNPH;CNL ~999i2~0 ~bO RCNT.~[15 -999,2~0 ~CFT.CNL .999,250 50 CFTC,CNn -999.~50 GR,CNL -999,250 2520,000 -07,188 "999,~50 -999. 50 -999,250 -9991250 -999,250 -999,250 I. LD,D!h GR,DIL 9 DRHO,~DC -999 RFFO.PDC -999 NPH~)CNL -999 RENT.CMl, -999 371. ~LM,DIL 125 T NS,FDC 250 ~FDC.FDC 250 CALI'.FDC 250 TNPH,CNL 250 RCFTiCNL '~ ~ ' 250 G .CNL 299~'~09 999,250 "9992250 999.250 999,~B0 -9 9 9,250 24B4.000 '65,875 -99q,250 -999 250 -099,250 -999,250 -999,250 -999,2b0 ILD,D!!, G~,DIL DRMO.FDC RFFD.FDC NPHI.CNi, RENT.CML CFTC.CML 2.945 83 313 -999.250 -999,~50 -999.~50 99q 250 I[,~,DIL TENS,FDC FFDC.FDC C~LI.FDC TMPH.CNL RCFT,CNL GR.CNL 2,821 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 2400,000 -05.875 -~99.250 -999.250 -999,2b0 999.250 '999,250 '999,250 3 652 107:688 -999,250 -999.250 2999,250 999.250 -999.250 IL~.DIL TENS.FDC ffFDC,FDC CALI.FDC TNPH.CNL RCFT.CNL GR.CNL 3,431 -999.250 -999,250 -999.250 -999,250 -999.250 -999.250 2390,0o0 -~5,875 -990,250 -999'250 -999.250 -999,250 -q9~,250 -999.250 !LO. OIL GN.OIL DRHO. FDC FF!) F~C nCNf. Cab CFTC. Cf!l, 3 372 107!313 -999 250 -999,250 -999.~50 999.250 2999.~50 IL~.DIL TENS.FOE FFDC.FDC CALl FDC RCFT,CNL GP,CNL 3.219 '999,250 '999,250 '999,250 '999,250 -999,250 -999,250 IS rape Veri, f.i. cation l,ist, ino SChlumberger AlasK. a Comput.ina ...enter , 4500,000 TENS DIL ,Dl.b 2,722 SP.'D. iL ,FDC -999 2.:~U RH3B,FDC .,OC '999,250 TEN8,C L 'C{~t[., -999 25() NPOR CNL ,CNL -9q9 250 CNTC,CN~ CGG -gQ9' 250 .4400,000 TENS -999; 250 RHOB -999.250 TENS 99,250 NPOR ~'¢;250 CNTC -999,250 GR [.)IL D I L FDC FDC C N L CNn CSG EPT F DPHT T E N 5 4300.000 TENS,DIb DI[,, 2,979 SP. DTL FDC -999,259 PHOB.FDC ' ' ' - !) 2 5 .... V DC 99; 0 RNFD. FDC F{~C -999,259 TENS,CNG C~%~ I.'' -999,250 NPOR.CND CNL -999,250 CNTC,CNL CS(; -999' 25() GR. CSG DF. PT S F L U DPHI NFI)C TFNS , D~j l, ,FDC ,FDC .FDC , C .~, [.., .CSG a200.O00 TENS.DIL 2,725 SP. Df b -909 250 RHOB F .... C -999,250 RNFD,FDC -999,250 TENS. CI~L -999,250 NPOR.CNL -999.250 C~qTC.CML -9q9,250 GR,CSG DEPT GP TNR~ TF .DII, , FDC . FDC .F'DC , Ch!I, ,CSt 4100, OOO TENS, I) Ib 2000. 000 SP. D!'L -909,250 RNOB.FDC -999,250 RNFD,FDC -999.250 TENS.CNL -9q9.250 ?~PDR.CNL -999.250 Cf~TC,CNL 221 O. 000 GR, CSG D F [-' T . SFLI! ,DIL DPHT. t'~FDC. FDC GP, !.'DC TNRI~. CNI, R'rNP.C~L TF~S.CS~ 20-AU(;-1989 14:30 2 3 30, O0 0 i ~. 0, DI .b -67,625 ' R'Dii~~, 973 -999,2bO I)RHO. ~jDC -999 -999.2b0 ~FFD;FDC -999 -999,250 a P:H.,[ ,CNb -999 "999,2bO PC~, CNb -999 ~999~250 CFr(,,CNb -ggg -99g. 250 PAGE: 1I 22b0 .t ' 9 t59 It.,~,D1L 2,906 500 TENS, FDC -999,250 FDC '999,250 FDC '999.250 250 TNPH,CNL '999,25:0 250 RCFT.CNL -999,250 25{) G ,CNL ,.999,.250 000 ILD.DII~ 3 8't5 GR, OIL 105 250 DRHU,FDC -999 ' ( ' ~ DC 999 2b~ RFFO, 25 0 N P H 'i. C N h - 99 o ' ~"' CNb 999 250 t.:~ TC' CNt, -990 25 () 2254 000 · IIiD,OtL -72'003 GR '999 50 DRHO,P[.C .~.. 50 RFFD.FDC -999.250 ~CN'f,CNb -999 099 IL~.[IIL 2.883 9. 9,2~ 0 250 FFDC;FDC '999~250 '999 ;:250 '"0 ' ' [;'DC 25 C A b I 0 ~ 25 TNPH, CNI. '999'~50 250 RCFT CNL "999,250 250 GR C~L -999~250 2434.000 1LD,DIL -71,625 G.R.DIb FDC -99q,250 DRH{'I,F · -999.250 RFFD,.DC CNL 999,~50 [tPHI, .,~t :999,~50 RCNT.CFNb '999,250 CFTC.C, h -999,~50 DIL ~7'500 .999' .99~,250 FFDC FDC 2'50 CabI' · ..... FDC -999 250 TNPH,CNL -999.250 GR.CNL ~99~',250922 999,250 -999,250 -999,250 -999,250 '999,2 3237 102750 -999250 -999250 -999250 -999,250 -999.250 ~330.000 ILO,OIL 146,875 GR,DIL -999,250 DRHO,FI)C 9 9,250 RCNT,C~L '999,250 CFTC,CNb ILM.DIL TEN$,FDC FFDC,FDC CAbI.FOC TNPH.CNL RCFT,CNL GR.CNL 2964 -999250 -999250 '250 -999. 12 592 62' ,531 '999.250 '999.250 999250 :9991 so -999.250 4UO0.O00 TENS.DIL 22~4.000 II, D.DIL 14.259 2000.000 SP,DIb -15q. 125 GR. DIL 51,969 -999,250 RHOB.FDC -999,250 PRHO'FDC -999.~50 '909.250 R NFl). F[)C '999 ~50 RFFi). FDC -99q.2bO ' ' 990' .... - .250 '.? P H I. C q b -999.250 TENS. C~.]L -999 250 lqPOR. C~:b ~999 25n RCNT.C~b -999~50 -999,250 C';~ CNL 999~250 CFTC CNL -999 250 -999,250 2250.00 (.) IL~.DIL TENS,FOC FFDC FDC CAL~:FDC TNPH,CNL RCFT.CNL GR,CNL 2000,000 '999,250 '999,250 '999.250 '999,250 '999,250 '999,250 ILM,DIL 'IENS FDC FFDCiFDC CALl FDC TNPHCNL RCFT.CNL G~,CNL 2000,000 -999,250 -999,250 -999,250 -909,250 -999,250 -999,250 LIS Tape 'verification Listing SChlUmberger AlasKa Co~P]ting t.::er~ter 20-AUG-1989 4.30 DFPT, ~900 000 T~F. 8 ~ F L ! ~, Il) i L 99 i~. 250 S P DPNJ:. ~DC -999,250 ~HOB G ~,~DC ~999.250 tENS T ~ R ,a. C ~'~ h - 999.250 ~.t p 0 R ~TNR,CNL -999 250 C,~TC t Ki~:~S, CS(; 22! O' .000 8 F L D P H I U F D C TF~S 3800 O00 25O 25 o 250 250 sO .~ .. 0 .DIL ,FDC . FDC 'CSG 9<)9,250 -999,250 -999;25(.) -999,250 -999.250 -999 250 2154' .000 DEPT SVLU DPHI NFDC TNR.a RTNP TENS . DIL , F DC Ft)C . Ci'~ L ,, C i:.{ L ,CSG 2999,250 999.250 -999.250 -909,250 -999 250 9~9~50 216~,000 SP [-?,HOB RNFD TEN~ NPOR C~TC .DIb ,OIL .FDC , FDC ,CN'L CNL ", C b! , CSG DEPT I)PH I T.~R~ RTNR .DI[, , FDC ,F'DC ,FDC , C'~ L .CNL . CSG 3500. -999, -999. -999, -999. -999. -999, 20~4. 000 250 25O 25O 25O 25O 250 TENS $ P TENS CNTC GR ,Olb .DIb .FDC 'FDC .CNL ,CNb 'tNb ,C:G DFPT 5FLU DPHI NFDC GP RT!~F · , D.II, .F'DC . FDC .FDC , C h b , Ci'J'L .CSG 340(:), -909. -999. -999, -999, -999. -9q9. POOh, O0O 251) 250 25 o 250 250 250 00O '099;250 RFFD FDC ~99g re ...... ,2p,) NPH! CNL -~99,250 RCNT~ CNL ~ r~ ~ 55;969 -999 -99~ -999 250 TN~H.CNI, -99:9 250 RC~T,CNL -999 250 GR,CNL '99:9 -099 250 ILD, DID -999 250 GR, [Jib -999 250 DRHO ~ FDC -999 2~0 RFFD,FDC ~999 250 NP.H!~ CNL .999 250 RC9.[, CL!~ -999 25o C~'TC;C~L -~99 8~4 250 IbM DI, L '999,250 250 TEN$:FDC "999,250 250 FFDC,FDC '999,250 250CA.LI,FDC '"'9:99,25:0 250 TNPH,CNL '999;250 50 RCFT,CNL :'99~,250 50 GR.CNL '99 .250 -999 -990', -999, '999, '999, -999, -999, 61, 250 I!,~.D,Olh -999 ~50 CR.DIL -999 250 }]RHO,FDC "999 250 RFFD'FDC 'Ogg 'b ~50 250 C~'T.. C"'. CNL -999 344 250 ,IbM,DIL 250 IENS,FDC 25. fFDC,FDC 250 CALI'FDC 25. INPH CNL 250 RCFT,CNL 250 GR,CNL 999,250 999'250 '999,250 '999'250 '999'2 0 '999,250 "999,250 '999, -999. -999. -g99 'q99' -999, -999. 59, 250 II.D.DIL 2bO GR. [)IL, 250 DRNO. FDC 250 RFFD,FDC 250 NPNi.CNL 250 RCNT,CNh 250 CFTC.CNL -999,250 -999,250 -999.250 -999 250 -99~' _,250 -999,250 -999..250 IL~,DIL ~EN .FDC FFDC.FDC CAbI.FDC TNPH.CNL RCFT.CNL GR.CNL -999 -999 -999 -999 -999 -999 -999 25O 250 25O 250 250 250 250 999 29991 -999, -999, -999. 999, 299 , ~0, 250 iLO.DI!~ 250 GR.DIL 250 DRHU.FDC 250 PFFD.FDC 250 NPHI,CNL 250 ~C~]T,C~L 250 CFTC,CNb 094 :999,250 999.250 -999 250 -999 250 -999 250 -999 250 -999 250 Ib~ DIL TENS' .FDC FFDC FDC CALI:FDC TNPH,CNL RCFT.CN[ GR.CNL :999.250 999.250 ~999,250 999.250 :999,250 999,250 '999.250 'q99, '999 990: '999. 'gYg, '999, 250 ILD,DIh -999.250 2bO GR.i~IL -999,250 250 DRFIt], DC -999,~50 250 RFFD.FDC -999.250 250 ~PNi,C~!L -999.250 250 PCNT,CaL :29Q 250 250 CFTC.C~L -~_96125o 4()9 Ib~.DIL TENS.FDC FFDC.FDC CALI.FDC TNPH,CNL RCFT,CNL GR,CNL -999.250 -999,250 -999.250 -999,250 -999.250 -999,250 -999,250 LIS Tane v~ri.~!icatIon Listin<~ 8cblumberoer AlssKa ComputJncT Center 20-AUG-:1. 989 14:3f') 3300,000 TENS. -9o9 ~ 250 Sp, ~ 9.2 .>0 -999,250 ~99,250 -999 ' 250 NPOR. 20 0 O. 000 . .1[;I; N F R T N ~ TFN$ DIL Fi.)C CML CSG DIb ,:.'°99., ,250 : II~D D'i. !, -~99,250 GR.t)IU -999 ~DC -999,250 RFFD,FDC CML : ~999,~b0 .NPHI CkL 999 c~b -999,250 CFTC , C,,b -99:9; 42 .844 ' ' DFPT 8FLU DPH! NFDC G~ TNR~ TV NS , I) IL .WDC ,FDC ,FDC .CHI. . Cr.~L . C 8G DEPT DPHI l,l F D C RTNF TF l~ S , DIl., .FDC ,F~}_ ,CNL 3100,000 T~,.;B S DIb -999 i -999,250 ~HOB,FDC -999,250 TE~$ CNb -999.25u NPOR:CNL. 9.: 9 250 CNTC 1,930.00o ~;¢,CNb .CSG 3 0 0 o, 0 0 C) 'E N S. D .T ,.., -999,25{,) SP. D] b -999. 250 R }.,I[.10, FDC -999. 250 RNFD, FDC -999.250 TENS.CML -999.250 NPOR.CNL -999. 250 CHTC. CNb 1830. 000 GR. CSG 2900.000 TENS.DIb -909.250 SP.DIb -999.250 RHOB.FDC -999.250 RNFI).F[)C -999.250 TENS.CML -9q9.25u NPOR,CNL T~99 250 CNTC.CrJL so:oeo eR.esi; 250;!bM,DIL 250F~DC;FDC -999 50 RCFT'CNL '99 250 G:R,CN:L '999i 2:50 '999.250 TENS.CNL '909.250 NPOR.CNL -909.250 CNTC.CN[, 1765. OOO (;R, CSG -999 25,, IbM DIL -999,250 '999,25 ~EN~,.DC '999 -999~5. F~DC,FDC '999 '999'2 Q CAbI,FDC -999 -999~50 TNPH'CNL 2909 -999,250 RCFT'CNL ,999 -099;250 GR;CNL -999 - 9 ' '" ~ 250 ,ILM.DIL .9.9,250 ILD,DIL - 99, 99. -099.~50 ~,DI~ -. 250~ENS;FDC -999~250 I')~[~O,FD~ ~999 250 ~F[)C,FDC -990,~50 RFFi)~FDC qgq~250 C~ l, -Q99.2'50 RCFT~CNL -999,260 CFTC.CNb -999,250 G~.CNL 55;031 " '999,250 '999,250 '999,250 '999;250 "999~250 '999,250 "999~250 -999 250 -999 250 -099 250 -999 250 -99q 250 -999 250 -999 250 b2,531 ILD.DT!~ 999,250 Ib~.DIb GR.t)Ib 2999~250 TENS,FDC DRHO,FDC -999,250 FFDC,FDC RFF!),FDC -999,250 CAhI,FDC .MPHI,CNL -999,250 TDPH.CNL RCNT.CNb -999,~50 RCFT.CNL CFTC.CNh -999,250 GR,CNL -999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.25¢) -999o2b0 -999.250 -ggq 250 -999~250 -999,250 51..188 ILD.oIN -999,250 IL~,~IL G.R.r~TL -999.~50 TENS. DC DRHO.f'DC -999 250 FFDC,FDC ~FDD,FDC -999~250 CALI.FDC NPHI.CNL -999 250 TNPH.CNL R'~'C.,,T,CML -999~250 RCFT,CNL CFTC,CML -999i 25O GR.CNL =999,250 '999,250 '999,250 '999.250 '999 250 -999:250 '999.250 '999.250 IbD,DIb -999.250 ILM.DIL -999 ~50 GR,DIL -099.250 TENS FDC -990:250 DRH,).Fnc -990.250 FFDC~FDC -099,2b0 ~FFI),FDC -999.250 CALI.FDC -999,250 NDHI,CML -99g 250 TNPH.CN[, -999,250 RCN~CNb -999:250 RCFT.CNL -999.2b0 CFTC.CML -999.250 GR.CNI. 44.094 -999 -999 -999 -999 -999 -999 -999 250 25O 250 25O 250 25O 25O [.IS ~a~e Verif~.catioD Listinc~ Scblumberqer AlaSKa ComputiDq Center EPT, 2700,000 FLU, Di L -999,250 S~, DIL F [)C DPHI,FDC -999,2.50 NFDC ~ F[~C -999,250 ~NF!'J. ~ C G~ F.~C -999~250 TNRA ~C~L -999,250 NPOR .LNL R.. f~. (.. N [, -999,250 C..~TC. CNb TE~S.CoG 1745~000 GR.CoG 2600. 000 -999 250 -999 250 -999 250 -999 250 -999 2,50 -999 250 1690 000 2~00,00.0 '999,250 -999.2~0 '999,250 '999.250 -999,250 1635'000 2400,0o() -999.250 -999.250 -909.250 -999,250 -999,250 -999.250 158o,000 2300.000 -999.250 -909.250 -999.250 -999.250 -999'250 -909 250 i535~00() 2200.00u 999,290 2999.250 999,250 2999.250 -999.250 -999.250 1515.0oo T E N S, D I b tSP. RI..OB, FDC T ..... s. . ~ · NPOR, C. ~b C ~:~TC, CNL Gf{, CS(; 20-AUG-I989 I4:30 PA~E: 14 2uO ILD.DIh 999 -099~2~0 DRHO,FDL -999 -~99.250 RFFD,FDC -999 '9Q°'250 NPHt'.CNL-999 '~561~5o RC~'r.C~,U -99~ CFTC.:CNb -999 250 G R -999. "9'99 -990 ~ggg -999 -999 -999 49 " q,DIL -999 250 ~. !.~ ~, 2~0 G}~, D:Ib -999 250 DRHO, FDC -~99 250 RFFD, ~'I'_)C' -999 250 NPHi, CUB -999 2b) RLN !',CNL 999 250 CFTC, dN,la -999 656 250 IL~.DIL '999 250 FFDC~FDC '999 :250 ~A~I,F DC 999 (. N I., 9.9 .250 ~NPH,'~ - q 250 RCFT,CNL -999 250 GR~CNL -999 250 -999, -qgo, -999, -qq9, -099, -q9g. 45. -999.250 -999,250 IENS.FDC -99~,250 FFDC,FDC -99~.250 CALI~FDC .999 250 TNPH CNL 250 RCFT,CNL 2999: ' 999,250 GR,CNL -999 50 .9o9: so 2999,250 999,250 '999,250 -990. '999, '999, -ggg. -ggq, '999, 'qgq, ~Sn ILD,DIL 252) GR, DIL 250 DRHO,FDC 250 RFFi),FDC 250 NPH I. CNL 250 RCN_ CNL 250 CFTC. CNL O o 3 -999 250 ILM.~IL -999~250 TENS DC -999.250 FFDC:FDC -999,250 -990,250 TNPH,CNL -q99 250 RC~'T,CNL -990~250 -999.250 -999,250 -999.250 -999,2~0 -999.250 -999,250 -999.250 - 99. '~99, ggg, 2999. '999. '999' 250 !LD.DIL 2 50 G R, 01 L 250 DRHU, f'DC 250 RFFD, FDC 250 NPHi.CNL 250 RC~T'CNL 2bO CFTC,CNL 594 -999 250 I5~,DIL -999:250 TENS,F[)C 999.250 FFDC,FOC 2999.~50 C~LI.FDC 999 250 TNPH.CNL 2999:250 RCFT,CNL '999,~50 G~.CNL -999 -999 -999 -999 -999 -999 -999 250 25O 250 25O 25O 25O 250 -999. -999. -999' -999. -999. -999, -090. 37. 250 ILU.D!L 250 GR,DIb 250 DRHC). FDC 2bO RFFD.FDC 250 NPH I, Cf.;L 250 RCN r. CN.b 250 CFTC.Ck, L -999.250 IL~,DIL ~999 250 TENS.FDC 999.'9.50 FFDC.FDC ~999 250 Cgb! FDC ~99:~5o CR.CN[ i999,250 999,250 999.250 '999,250 '999,250 '999,250 '999,250 bis Tape verif!ication bistinc! SChlUmberger AlasKa Computinq (]enter " 'T 99 D i L DPBt, ~ D,~ -999,25p NFDC. FDc -999,250 G~ FDC -999,2~0 ,,,-,,R~, C~[., -909,250 RTNR, C~gL -999,25(t 'tFaS i CSt; 1475 ~ 00() . 2t.) .)0 000 -9~9' FDC '999,250 F[')C -999,250 C ;~ L - 9 ~ 9,2 ~ 0 1465,00() DEPT t900 00o sFL!I'. !.:)II, -9q9.256' LIP~:I',FDC -999 250 GR, FDC "999,250 TMR~, CNI., -999' 250 RT'NR, CNI., .-999,250 TK~K, CSG J 430,00 o DFPT. ~800.000 51;'IjU, l')II., -999,250 [)PHI. FDC -999.25o NFDC VDC -999.250 GP, F[)C -999,250 9'~i'R~, C~b -999. 250 ~NP. Ci~L -999. 250 'I.-~S CSG 1,~0 000 1700. -9n9,2~0 -999. 250 -999.25O -999.250 -_999.250 1345. 1600.000 -999,250 -909,250 -999.259 -999,250 -999.250 1305.u00 TENS,OIL oP. [')IL ~ H 0 !3, F :O C R NFD. FDC NPOR ~ CNb C ~'~ TC, C ~ 1.~ GR..C" ' 980 14: 30 -999.250 ihU.D.IL -999 2 5 0 ., R -999 .... C . . 250 2 b 0 a P ii:l, C N L 250 i)CNT' C~L 250 CFIC.C": b -999 -9az 031 -999,250 II, D DID '999 -qgg, .s,:50 :GR, DIb -999," ," :99~,250 :.FFD.~:DC : -999 99 . 250 t~'P'H"[, C'~,lb -999 -999,250 RCNT CNb -999 -~99,~50 CFTC'Ct,lb. -~99... 4: PAGE: 15 -q99 2b.O ILD,DIL -~9~:2so GR,D:b '999,250 DRHO,FDC -999,250 RFFD~FDC -999,250 BPH~,CNb -999.250 ~C~T,C~b 250 Ii~:~.DIL -999.~50 250TENS'FDC '999,.50 250 FFDC,FDC -999~ ~50 YNPH,CNL :999 ~50 RCFT~CNL 999 zSO GR.CNL '999,~50 250 ILm OIL 250 ~ FDC FDC 99,250 TENS FDC -999,250 FFD~ FDC -999,~50 CALI FDC -999,250 TNPH,CN~ '999.250 RCF'T,CNI. -999.250 GR,CNL 25O -999.250 ll,,D.DIh -q99. 250 GR, OIL -999 250 DR;{O ~..(. -999,250 RFFD,FOC cr! b -qgq.250 UP~i.t:WL -999.2b0 RC.NT. -99q,250 C" 25.859 -999.250 -999 250 -999 250 -999 250 -999 250 -99q 250 -999 250 -999 -999 -999 '999 -999 -999 -999 250 250 25O 25O ~250 TENS,D.Ih -999.250 IhO,OlU -999,250 SP.Olb -990.250 GR,DJL -999.250 RHOB.FL)C -999.250 DRHO.FDC -q90.250 RN~'D.FDC -999.~50 RFFiJ,FDC -999,~50 TENS,CNb -999.250 NPHI,CNb -999,250 NPIIR C~I, (~99 250 RCNT C~ b 999.250 CNTC.CNb -g99 260 CFTC.CRb -999.250 GR.CSG 42:969 TENS.OIL SP,DIb PHOB,FDC RNPD,FDC TENS.CNL NPOR,CNb CNTC,CNL GR.CSG IL~ OiL TENS F.DC ~FD... FDC CALl FDC TNPH CNL RCFT CNL GR C~L -999 250 -999 250 -999 250 -999 250 -999 250 -999,250 -999,250 IL~.DIL TENS,FDC FFDC.FDC CALI.FDC TNPH,CNL RCFT.CNL GR,CNL -999 50 -999.250 -999.250 2999 250 9991 5o -999,250 -q99,250 ILD.I)IL -999.250 GR.DIb -999,250 DRHO,FOC -999.250 ~FFO,FDC -ggg.~bO NP~I.CNL -999,250 ~CNI,CNb -99~,250 CFTC,C~L 15.445 -999.250 -999.250 -999.250 -999.250 -099'250 -999,250 -999.~50 IL~.OIL TEi~S,FDC FFDC,FDC CAbI,FDC TNPH,CNL RCFT.CNL GR,CNL '999.250 '999.250 '999.250 '999.250 '999.250 '999.250 '999.250 ,.~IS Ta!De ~derifica51on Listino ~Cbltlmberqe¥ ~%!a$<a Co~putinq Center DEPT I~00,000 TEN$,DIL SFL!.i ~ I)i [~ -9q~ ~ 25(') SP. DIL DPH1 ~'LC '9~ ~ 25O b LC -999. 250 RNFD FDC GR,VOC -999,250 TENS CNL TMR~ ,C~L -999,25o .... R ',' 250 C~.. TF),4$.Caf; i 230. 000 G:R. CSG DEP'I. 1400.000 TENS.DIh SFLU' DI[~ --qgq=. ,.,, 250 SP, DI~ DPH]'. Fi')C -999;250 PHOB, FDC NFDC,F DC ,.999 25() RNFv,FDC GR, FDC -999'. 250 T~'~]~'., ... ~. C.NL ' ' A {'"~ (9 250 NPOR,CNh C;4L -9q9 250 CNTC,CNL TENS, CSG 124,0. 000 GR, CSG I.)EP , 1300,U0o 8PI.~!.')-, DI !, -999,250 DPHI ~'l')C -999,Z NFDC' FDC -999 ;250 ,~ D,~ '9c)9 250 . C~ l.., -999 ' 250 RTNR "" - (. ~ 1,, 999.25U TKNS'CSF; 12o5 ooo DFPT. 1.. 200,000 TEN$,DIL SFLU, OIL '909,250 SP, HID DDHI.FDC 999 250 NFDC,FDC -999,250 R~F[),FEC GR,WDC -9o9.250 TENS.CNb TNR/,C?$L -999,250 NPOR,CNb ){~ND. C)"~L -909. 250 C~,gTC. C~L TF~S.CSC I 140,000 GR,CSG DEPT. 1100.000 TENS,DIb ,5F L,I). DI !, -999. 250 SP. D.IL ~C DPHI, FL. -999,250 RHOB. ~.~FDC. ~fDC -9q9.25U RNFO FDC TMR~. CN[. -999,250 5tPOR. CNb RTNP,Ca~L. -999.250 CNTC,CNb TFf<S. C5C 1090.00() GR. CSG -999 20-AUG- ' 4 * 1989 i .. 30 PAGE: 250 1La, L)IIU 5o RFgO; 250 NPHi -999 250 RCN'T* CNG -99g,250 CFTC :]0. 375 -999 -999 -999 -999 -999 -999 -999. 250 Ib~,DIL -999,250 250 ~ENS.FDC 250 (,ALI'~FDC -999~25 ~50 RCFT;~NL -999,25 250 G:R,CNL' : '999,250 -999.250 ILO.DIL -q99.250 IL~.DIL ,999~ 50 ~R.DIL -99.9 250 TE:NS,FDC -999, 50 DRH{'),FDC -999.250 FFDC.FDC -999,2b0 RFFD,fLC -999 250 CAb'!~FgC -99~250 NPHI'C ;L~ -999'250 TNP}-~,CNL '~999,'5 ' ', " 2 0 ~C~1:'.~Nb 999,250 RC~,CNL -99~50 CFTC',CNL~ -999.~50 28,922 " 250 '999,~5 '999,250 :999,250 ~999,250 999'250 '999.250 -999 '999 999 999 -q99 25O 'a ~F.,PH 250 RCFT 250 GR DIL '99:9,250 FDC '999'250 FDC .~999' ~50 FDC 999 * 250 .. -999,250 CNL '999,2.0 -999 250 -999 250 -999 25O -999 250 -999 250 -999 250 -999°250 IbM.DIL TENS.FDC FFDC,FDC CADI,FDC TNPH,CNL RCFT.CNL G~.CNI, -999.250 -999' 50 -999:~50 -999,250 -999,250 -999,250 -999.250 -999.250 lI, D.Olh -999.250 GR.DIL -999 250 DRHO,FDC -9901250 RFF' '"~t<. FgC_ -999,250 NPHI,CNI~ -999.750 RCNT.CNb -999,2b0 CFTC.C~OL -999 250 -99q~250 -999 250 -999 250 -999 2bO -999 250 -999 250 ILM,DIL TENS.FDC FFDC.FDC CALI.FDC TNPH.CNL RCF'T.CN[ GR.CNL -999.250 '999,250 '999.250 '999,250 '999,250 '999,250 '999.250 -q99,250 ILb. OI!, -999.2b0 Gk,Olb -99g,250 RFFO,FDC -999'250 NPHi,C~!L -999,250 RCNi'.CNb -qgq,~SO CFTC,CNS 37,53! -990,250 -999.250 -999,250 -999,250 -999.250 -g99,250 -q99.250 ILF.DIL TENS.FDC FFDC*FDC CALI,FDC TNPH.CNL RCFT.CNL GD.CNL -999.250 -999,250 -999.250 -999,250 -999.250 '999,250 '999,250 16 Verification LJ. stino AlasKa COmputing Center ~AGE: I7 l)'Ep'r : G ' D I L FDC WDC CiViL , C~L CSG 94?, 000 TENS -9q~-'250 SP f)IL ~ . .... , .... .rDC -999 250 TENS CNb -999'250 NPOR -999,250 Ch TC OiO~O00 GR CSG -999,250 IL~.2 OIL -999 -99q.250 ~' G~.,DIL '9:99 ~ : ~999 ~' "~ FbC 999 -99q 250 R~FD.F[L 999 -99 2bO : ~PHI,CNb -999 -99q 250~C~T.CN[, -999 - q 5 ...... 99:, 2 0 CPfC.C~IL -999 24 250 :IL~,DiL ,-999,~50 ~50 TENS;FDC ~50FFDC~FDC -999,:250 250 CALI.FDC -999'250 250TNP~'CN~ '-999,250 ~50 RCFT~CNL -999;250 ,250 GR.:CNL -999~25:0 DATA * * * * F I ,k, E' T N A t L E [~ * * * g ,', , .... E D I ,, ,0 VE~Si[')N I 00'lA02 DA'I ..... : 89108/20 H.~ :X '" ;'" R[:.,C S!ZE . i024 TYPE : C!)NS C~ ARCO AbASKA, INC. Company Name F~ KUPARUK ~Nield ame WN 2K - 5 Well ~ame ~"?1 USA Nation STAT ALASMA State or Province C0[]~3 SOt{TH SLOPE County FI~ 19b' FSL & 94' FEL Field Location SFC· 02 Section T~W~ 10N Township R~C 8E Range E~iG] h. FRITZK~: Engineer's Name SON 548365 Service Order Number ~PlM 50-103-20098 API Serial Number LIS Ta~e Verittcat,ion Listtnq ~hlumber~er ~.,tasKa Computing, .(.'?enter 989 i4: 30 ?~BL, E TYPE : CU~!~ [JPHI Densitv Porosity R~O~ Bul~ Density DPH~ Delta rr~o FF~C Far ~DC Count Rate NF[)C tleaF Ft)C Count Rate R~U Ra,.~ ~',,~ar FDC Count Rate RFFD Daw Far F!)C Count Rate C ~LI Caliper G~ Gamma TENS Tens:ton TB.~P:}.~ THER~AL NEUT~O~t PUROSIT'Y NPOR ME!JTROM POROSITY OUTPUT FR(3a AN .~PPLICATION PROGRAm4 C F T R C F T ~T:'~P RAW T~.IMRMAL NEUTR[)~ RATIO C FTC CFTC GR Camera RaV PAGE: ** DATA FORe, AT ~PECIFICATION RECORD ** I 66 0 2 66 0 3 73 4 66 5 6 7 } 7 6.5 8 68 0,099 9 65 F'I' i.~ 66 11 12 68 1~ 66 0 14 ~5 i5 66 68 !6 66 0 6~ ~IS WaDe Veriflcatic)n Listln(] ;chlumberqer $1a$~a £Om~,ut!n~ Center 14:30 ** 8ET TYPE - CHA~] '}"~ ' ;' ' 'S "D ID ORDER ~ b[,G T~PL CbA8~ MO. NUMB SA~P ELEct CODE (HEX} TENS FDH i.,E 54~65 OD DO0 O0 0 DPHI FDN PU 548365 O0 000 O0 FDC b'Dtq CPS 54~365 O0 RNFD Fi)H CPS 548365 ()0 000 O0 02 1 RFF'D FDF~ CPS 548365 O0 000 2 68 0000000000 6a OOC) O000000 I 4 68 0000000000 ~ 4 6n 0000000000 ¢., LI ~'DH 1/{':~ 548365 O0 000 O0 G~ F'DI4 G.~ P I' 548366 O0 000 O0 L~ v,1- 36~ O0 000 O0 NPHI. C,a~ P J 548365 O0 000 O0 TN'P~ C ,'.~ )4 PU ~48365 O0 00() O0 ~t" .... ,~ ..,, R ~ CN~i 548365 00 000 O0 NPOP CN~ Pll 54~365 00 000 00 RCNT CNH CPS 548365 O0 0(')0 OO R C F · C ~'~ ~.) C P $ 548365 o 0 o 00 00 R'I: N ~ CNH 548365 00 000 C~.~TC C.{'.~ [4 CPS 548365 O0 o00 CFTC CNH CPS 548365 oO 000 0 0 2 I ! 4 68 0000000000 0 2 ~ 1 ~ 6~ 0000000000 ~ .. } 4 68 0000000000 ~ } 4 68 0000000000 0 ~ I I 4 ~8 0000000000 o. oooooooooo i oooooooooo . oooooooooo o , 4 oooooooooo oo o oooooooooo oo o 2 ~ ~ ~.o~ooooooc)ooo co o ~ '! i 2 ~.oooooooooo PAGE, 1.9 ** i).hTh DFP'r . 7941.800 TENS. FDH 1775.000 DPN,I. FDH 25, 323 RHOB.FDH DPi,!O,FDi,.t 0,082.. F~ .C,FDH 9bg,ouo NFDC,FDH 78~ 500 RNFD,FDH RFFD. FDH 1930.000 C ~I., l. FI)}-t 7,590 (;~, Fnl. l 183, ~75 TENS. CNH NPi-II, Cr~ 38,738 TNPH.CN~ 36,887 TN~A.CNH 3,185 NPOR.CNH RC~%~. CN;I 2024,251 ~CFT.CNH 582.536 RTNR.CNN 3,427 CNTC.CNH CFT(',CNH 660.651 GR.CNH ! 83,875 DFPT, 7900,000 TEN,5. FDH 4104,000 DPHI.FDM 24.859 RHOB.FDI4 DPaO.F[3.~-~ () 074 FFDC FDd q2~.O00 t-iFUC,F[)H 766.500 RNF'D.FDH ...... ' ' TENS.CN~ RFFIJ,FDH 1909.000 C~Li,FDH 7,6~4 GR,FD~ 183,875 .. . , , .... . CN}! 36.887 TbIRA,CN~ 3,185 NPOP,CN~ NPiiI CN~ '~S 654 TNPH. - .. RCNT, Ci'c~ 2024.251 RCFT.CNH 5~2.536 ~TNR.CNH 3.427 C~)TC,C~H C~'TC,',~)-4 .... 660,551 dR CN}i 183.875 DFPT, 7dOO,0O0 TENS, [.,'DH 4112.000 DPHI.FDH 10.539 RH©R.FDH DPHC.FD~ 0, t)65 FF'DC. FDH,. 504.000 ~,~,t~'/)C, F DH 634.000 RNFD FDH RFFD. ~{')U 900,000 C~!. I.FDH 9,359 GR, F,.gH 102,750 TENS:CNH I..{PHI.CN~ 39.533 TitPH CtJH 3A,131 TN~A.C'~iH 3:170 NPOR.CNH F;C~'~T. CNi4 1959,802 RCFT: CN)) 60~ .7a5 {~TNR* C,~H 3:!21 CNTC, CN~ CFTC, CN},~ Ot 3,200 GR,CNH 102,750 2.232 1506~000 1775,000 36,887 2068,417 2 240 1460:000 4104,000 36.8~7 2068,q17 2,476 1219,000 4112.000 37,930 1992,258 ,!$ Tat~e Verification I, istl~a ;ch!umberqer AlasKa Computin{] Center D~PT. CtC F F DH ~.,h~4 CN~4 7700 0 039 1009 5.00 40 904 I 9gO O36 DEPT 7600,000 TENS,fEd [)DD]O '~FDH O, 000 FFDC FDH J~FFD, FDH I 1. t O. gO0 CALl, FDH NPH!, C?~H 31.516 TNP[1. CNH CFTC,cNH 951.~2 ~.3 GR.C.~H .000 008 000 702 990 .432 TENS. FDH AI,,I FPH ' r, iPH CNH ~C r CNH Ga CN.H D[;PT 7400.00o ~F'FD, FDH 851,500 ~,~PH l Ci~H 47.638 ~CNT' tC~H 1990,03o DFPT. 7300. FDH 0,031 DRHO, RFFP .FDH 1155.000 NPHI,CNH 43 188 RCNT.CNt} 1767~239 CFTC, CNH ~ 10,972 TENS FFDC CALl TNPH RCFT G~ , FDH FDH FDlt CNH CNH DEPT. 7278.899 D~'HP,FI)F 0.018 RFFD,FDH 1037,000 NDHI.CH~ 38.469 RCNToCNH 1931.38~ CFTC.CN~ 568,475 TENS FFDC'. CALl T .N P H RCFT, FDH FDH FDH C N H C ~)H END (iF DATA 20-~L)CI'19B9 i4;30 3960,000 O~.HI. FDH 507,5qo . ,j. '~'. ~ ~ , ~2,240 T~RA CNH 95,375 3720,0~0 DPHt, 541 ' ~' ' "· ,0(,0 NFPC ~ DH 826 3~14.000 DPHI,FDH 4.3B, 000 NF~. FDH q~4bq .FDH 33 70I T~A,CNh 739~928 RT~R,CNH 36b0 430 9 ~23 3~34.000 576,590 11..664 42,2~7 420'646 i24.313 PPHI. FDH NFDC, FDH (.:a , FDH t~ a C ~H RTNR. CNH 35~(), 524 ,, 10,3i3 38.~31 555.32.1. ! 90.000 NF'DC. R'I'Nx.CNH F DH V. FDN C~H tl,49q RUOB.FDH 533,500 RNFD,FDH 125 TENS CNH 2,999 3.34~ CNTC,CN" 62 ',122 ~HOB, F[)H ~ 000 RNFD FDH 12],250 TENS C~H ,835 NPO~'CNH. 3.765 CNTC.CN~ 15.926 6~9,500 124,313 3,704 4.~7 RHDB FDH RNFD FDH TENS CNN NPOR CNH CNTC CNH 14,325 600,000 190.000 3.390 3.508 RHOB,FDH RNFD.FDH TENS.CNM NPOP..CNH CNTC.CNH PAGE: 20 44'8 000 000 2764,406 2,460 997,.500 3864~000 34,244 2507,714 2,566 1205,000 3650,000 50,378 2248.719 2,387 1193; ooo 3534.000 41,943 I839,405 2 414 1203 000 3560 000 38 780 1895 479 LIS Tape Verificatlor~ I~istino SChlumberger AlasKa'ComPuti. n~. Center, 20-AUG-1989 14;30 PAGE: 21 **** FIL, E TRILLER FIL~ NA~E : -IT , V~TRSION : 001102 L~ST FIt E SERVICE ~AF~F; : EDIT ~PF ~3A~f'~ : 73428 PREV .If)liS ~aP~j : C[]M~E.NT : :ARCO, KUPARUK, 2K,,5, /APl. 50-103-2009~ SFRI~!CE ~ME : EDIT D~T'[ ' ' : 89/0gt20 ORIGIN ~ FLIC :,~]tlflUS RE'EL C 0 N ~' N 'l M ~E .... ' ARCO, KUPARUK , 2K-5, APl ~50~103-20098
