The URL can be used to link to this page

Home My WebLink About196-077CAUTION: 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: KRU 2M-31 (PTD 196-077) Under Evaluation for Fluctuating IA Pressure Date:Monday, December 2, 2024 10:23:49 AM Attachments:AnnComm Surveillance TIO for 2M-31.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Monday, November 25, 2024 5:33 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: KRU 2M-31 (PTD 196-077) Under Evaluation for Fluctuating IA Pressure Chris, KRU 2M-31 (PTD 196-077) failed an SCLD on 11/23/2024 while on water injection. A Surface Casing Leak Detect was performed and confirmed a surface casing leak depth of 516’. A passing MITIA (3,300 psi) and passing pack off tests were achieved. The well has been shut in and freeze protected. We will prepare a water only injection and surface casing waiver for the AOGCC. A wellbore schematic and 90 day TIO trend are attached. Please let us know if you disagree or have any questions with this plan. Regards, Mark Shulman Well Integrity Engineer From: Well Integrity Specialist CPF2 Sent: Friday, October 18, 2024 3:18 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: KRU 2M-31 (PTD 196-077) Under Evaluation for Fluctuating IA Pressure Hi Chris, CPAI has concluded our diagnostics and confirmed that 2M-31 exhibits TxIA on gas injection. We will now WAG the well to water injection and prepare a water only injection waiver for the AOGCC. Thank you, Jaime From: Well Integrity Specialist CPF2 Sent: Monday, September 16, 2024 2:12 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2M-31 (PTD 196-077) Under Evaluation for Fluctuating IA Pressure Hi Chris, KRU 2M-31 (PTD 196-077) is a WAG injector currently on MI injection. The inner annulus was bled twice in the last month to maintain the IA pressure below DNE. The IA pressure trend shows fluctuation in pressure. CPAI intends to conduct an initial set of diagnostics and depending on the results, continue to monitor for 30 days for IA fluctuations. At the end of the 30 day monitor period the proper notifications for continued injection or repair of the well will be submitted as required. Attached is the current 90 day TIO plot and wellbore schematic. Please let me know if you have any questions or disagree with the plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2M-31 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2M-31 2024-09-04 2000.0 1400 -600.0 IA 2M-31 2024-09-14 2400.0 1100 -1300.0 IA 2M-31 2024-09-17 2300.0 1200 -1100.0 IA 2M-31 2024-09-21 2300.0 1400 -900.0 IA 2M-31 2024-10-19 2350.0 1500 -850.0 IA 2M-31 2024-10-21 2000.0 1000 -1000.0 IA 2M-31 2024-11-23 260.0 60 -200.0 OA 2M-31 2024-11-24 1375.0 1275 -100.0 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 12,990.0 2M-31 4/10/2019 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled CA-2 plug & baited pulling tool 2M-31 10/11/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 4/25/2010 lmosbor NOTE: 13.44' DEPTH CORRECTION POST WORKOVER 5/18/2007 lmosbor Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 41.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.84 41.5 4,035.3 2,825.6 40.00 L-80 BTCM PRODUCTION 7 6.28 38.2 13,160.0 6,287.2 26.00 L-80 BTCMOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 36.7 Set Depth … 12,807.8 Set Depth … 6,048.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABM OD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.7 36.7 0.03 HANGER 8.000 FMC TUBING HANGER w/ 3.47' Pin x Pin Pup FMC Gen 5 2.992 496.8 496.8 0.47 NIPPLE 4.520 CAMCO DB NIPLLE 2.875" Packing Bore Camco DB 2.875" 2.875 2,502.2 2,256.9 55.79 GAS LIFT 5.390 Camco KBMG 2.920 12,736.0 6,003.2 51.91 SLEEVE-C 4.510 BAKER CMU SLIDING SLEEVE w/ 2.812" DS Profile Closed 10/06/2024 Baker CMU 2.812 12,781.4 6,031.6 50.62 SEAL ASSY 4.000 LOCATOR/SEAL ASSEMBLY Baker Size 80- 40 3.000 12,781.8 6,031.8 50.61 LOCATOR 4.000 SPACE OUT LOCATOR ABOVE NO GO Baker Size 80- 40 3.000 12,783.8 6,033.1 50.54 PBR 5.880 BAKER 80-40 PBR, 4" SEAL BORE Baker Size 80- 40 3.000 12,807.1 6,048.1 49.69 SEAL ASSY 5.850 BAKER K-ANCHOR SEAL ASSY W/BLADED GUIDE (2.00' Overall) - STABBED INTO SAB-3 PACKER Baker Size 80- 40 3.000 Top (ftKB) 12,807.9 Set Depth … 12,835.0 Set Depth … 6,066.3 String Max No… 3 1/2 Tubing Description TUBING Original Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdMOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 12,807.9 6,048.5 49.66 PACKER 6.275 BAKER SAB-3 PERMANENT PACKER w/NEW K- ANCHOR/SEAL) 2.992 12,824.9 6,059.7 49.04 NIPPLE 4.500 CAMCO 'D' NIPPLE w/2.75" PACKING BORE, NO GO 2.750 12,834.1 6,065.7 48.70 WLEG 4.500 BAKER SOS/WIRELINE ENTRY GUIDE - TTL ELMD @ 12822' PDS IPROF 3/13/1998 (PRE CUT TUBING & WORKOVER) 2.992 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,502.2 2,256.9 55.79 1 GAS LIFT DMY BK 1 0.0 6/14/2007 6:30 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 12,895.0 12,921.0 6,106.6 6,124.2 C-4, 2M-31 9/9/1996 2.0 IPERF 2.5" HC; 0 deg. ph; 0 deg. CW 12,921.0 12,947.0 6,124.2 6,141.9 C-4, A-3, 2M-31 9/9/1996 4.0 IPERF 2.5" HC;180 deg. ph; Oriented 90 deg. CW 2M-31, 10/12/2024 4:32:04 AM Vertical schematic (actual) PRODUCTION; 38.2-13,160.0 FLOAT SHOE; 13,158.5- 13,160.0 FLOAT COLLAR; 13,072.5- 13,073.8 IPERF; 12,921.0-12,947.0 IPERF; 12,895.0-12,921.0 WLEG; 12,834.1 NIPPLE; 12,824.9 PACKER; 12,807.9 SEAL ASSY; 12,807.1 PBR; 12,783.8 LOCATOR; 12,781.8 SEAL ASSY; 12,781.4 SLEEVE-C; 12,736.0 SURFACE; 41.5-4,035.3 FLOAT SHOE; 4,033.6-4,035.3 FLOAT COLLAR; 3,950.3- 3,951.7 GAS LIFT; 2,502.2 NIPPLE; 496.8 CONDUCTOR; 41.0-121.0 HANGER; 41.5-45.7 HANGER; 36.7 KUP INJ KB-Grd (ft) 46.80 RR Date 5/10/1996 Other Elev… 2M-31 ... TD Act Btm (ftKB) 13,161.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032024100 Wellbore Status INJ Max Angle & MD Incl (°) 70.95 MD (ftKB) 10,755.41 WELLNAME WELLBORE2M-31 Annotation Last WO: End Date 5/18/2007 H2S (ppm) DateComment SSSV: NIPPLE 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: KRU 2M-31 (PTD 196-077) Under Evaluation for Fluctuating IA Pressure Date:Monday, October 21, 2024 2:26:01 PM From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Friday, October 18, 2024 3:18 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: KRU 2M-31 (PTD 196-077) Under Evaluation for Fluctuating IA Pressure Hi Chris, CPAI has concluded our diagnostics and confirmed that 2M-31 exhibits TxIA on gas injection. We will now WAG the well to water injection and prepare a water only injection waiver for the AOGCC. Thank you, Jaime From: Well Integrity Specialist CPF2 Sent: Monday, September 16, 2024 2:12 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2M-31 (PTD 196-077) Under Evaluation for Fluctuating IA Pressure Hi Chris, KRU 2M-31 (PTD 196-077) is a WAG injector currently on MI injection. The inner annulus was bled twice in the last month to maintain the IA pressure below DNE. The IA pressure trend shows fluctuation in pressure. CPAI intends to conduct an initial set of diagnostics and depending on the results, continue to monitor for 30 days for IA fluctuations. At the end of the 30 day monitor period the proper notifications for continued injection or repair of the well will be submitted as required. Attached is the current 90 day TIO plot and wellbore schematic. Please let me know if you have any questions or disagree with the plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 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: KRU 2M-31 (PTD 196-077) Under Evaluation for Fluctuating IA Pressure Date:Monday, September 16, 2024 3:15:13 PM Attachments:AnnComm Surveillance TIO for 2M-31.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Monday, September 16, 2024 2:12 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2M-31 (PTD 196-077) Under Evaluation for Fluctuating IA Pressure Hi Chris, KRU 2M-31 (PTD 196-077) is a WAG injector currently on MI injection. The inner annulus was bled twice in the last month to maintain the IA pressure below DNE. The IA pressure trend shows fluctuation in pressure. CPAI intends to conduct an initial set of diagnostics and depending on the results, continue to monitor for 30 days for IA fluctuations. At the end of the 30 day monitor period the proper notifications for continued injection or repair of the well will be submitted as required. Attached is the current 90 day TIO plot and wellbore schematic. Please let me know if you have any questions or disagree with the plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2M-31 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2M-31 2024-07-16 2000 1100 -900 IA 2M-31 2024-09-04 2000 1400 -600 IA 2M-31 2024-09-14 2400 1100 -1300 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 12,990.0 4/10/2019 2M-31 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth 4/10/2019 2M-31 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 41.0 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.84 Top (ftKB) 41.5 Set Depth (ftKB) 4,035.3 Set Depth (TVD) … 2,825.6 Wt/Len (l… 40.00 Grade L-80 Top Thread BTCM Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 38.2 Set Depth (ftKB) 13,160.0 Set Depth (TVD) … 6,287.2 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCMOD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 36.7 Set Depth (ft… 12,807.8 Set Depth (TVD) (… 6,048.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 36.7 36.7 0.03 HANGER FMC TUBING HANGER w/ 3.47' Pin x Pin Pup 2.992 496.8 496.8 0.47 NIPPLE CAMCO DB NIPLLE 2.875" Packing Bore 2.875 12,736.0 6,003.2 51.91 SLEEVE-C BAKER CMU SLIDING SLEEVE w/ 2.812" DS Profile CLOSED 5/18/2007 2.812 12,781.4 6,031.6 50.62 SEAL ASSY LOCATOR/SEAL ASSEMBLY 3.000 12,781.8 6,031.8 50.61 LOCATOR SPACE OUT LOCATOR ABOVE NO GO 3.000 12,783.8 6,033.1 50.54 PBR BAKER 80-40 PBR, 4" SEAL BORE 3.000 12,807.1 6,048.1 49.69 SEAL ASSY BAKER K-ANCHOR SEAL ASSY W/BLADED GUIDE (2.00' Overall) - STABBED INTO SAB-3 PACKER 3.000 Tubing Description TUBING Original String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 12,807.9 Set Depth (ft… 12,835.0 Set Depth (TVD) (… 6,066.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 12,807.9 6,048.5 49.66 PACKER BAKER SAB-3 PERMANENT PACKER w/NEW K-ANCHOR/SEAL) 2.992 12,824.9 6,059.7 49.04 NIPPLE CAMCO 'D' NIPPLE w/2.75" PACKING BORE, NO GO 2.750 12,834.1 6,065.7 48.70 WLEG BAKER SOS/WIRELINE ENTRY GUIDE - TTL ELMD @ 12822' PDS IPROF 3/13/1998 (PRE CUT TUBING & WORKOVER) 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 12,895.0 12,921.0 6,106.6 6,124.2 C-4, 2M-31 9/9/1996 2.0 IPERF 2.5" HC; 0 deg. ph; 0 deg. CW 12,921.0 12,947.0 6,124.2 6,141.9 C-4, A-3, 2M-31 9/9/1996 4.0 IPERF 2.5" HC;180 deg. ph; Oriented 90 deg. CW 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 2,502.2 2,256.9 Camco KBMG 1 GAS LIFT DMY BK 0.000 0.0 6/14/2007 6:30 Notes: General & Safety End Date Annotation 5/18/2007 NOTE: 13.44' DEPTH CORRECTION POST WORKOVER 4/25/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Comment SSSV: NIPPLE 2M-31, 4/11/2019 7:14:31 PM Vertical schematic (actual) PRODUCTION; 38.2-13,160.0 IPERF; 12,921.0-12,947.0 IPERF; 12,895.0-12,921.0 WLEG; 12,834.1 NIPPLE; 12,824.9 PACKER; 12,807.9 SEAL ASSY; 12,807.1 PBR; 12,783.8 LOCATOR; 12,781.8 SEAL ASSY; 12,781.4 SLEEVE-C; 12,736.0 SURFACE; 41.5-4,035.3 GAS LIFT; 2,502.2 NIPPLE; 496.8 CONDUCTOR; 41.0-121.0 HANGER; 36.7 KUP INJ KB-Grd (ft) 46.80 Rig Release Date 5/10/1996 Annotation Last WO: End Date 5/18/2007 2M-31 H2S (ppm) Date... TD Act Btm (ftKB) 13,161.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032024100 Wellbore Status INJ Max Angle & MD Incl (°) 70.95 MD (ftKB) 10,755.41 WELLNAME WELLBORE2M-31 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 25, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2M-31 KUPARUK RIV UNIT 2M-31 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2024 2M-31 50-103-20241-00-00 196-077-0 W SPT 6040 1960770 1510 2650 2650 2625 2625 260 260 270 270 4YRTST P Sully Sullivan 6/22/2024 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 2M-31 Inspection Date: Tubing OA Packer Depth 1620 3310 3260 3260IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240624192336 BBL Pumped:1.8 BBL Returned:1.9 Thursday, July 25, 2024 Page 1 of 1             X0513 [U;7_A�7�luI TO: Jim Regg n P.I. Supervisor FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 17, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, [nc. 2M-31 KUPARUK RIV [IMT 2M-31 Ste: Inspector Reviewed By: P.I. Supry �l Comm Well Name KUPARUK RIV UNIT 2M-31 API Well Number 50-103-20241-00-00 Insp Num: mitAGE200617111942 Permit Number: 196-077-0 Rel Insp Num: Inspector Name: Adam Earl Inspection Date: 6/13/2020 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2Ma1 - Type Inj W' TVD 6040 - Tubing 2320 2320. 2320 - 2310 PTD 1960770 Type Test SPT ITest psi 1510 IA 630 1800 1750 - 1740 - BBL Pumped: 1 15 BBL Returned: L5 OA 2s0 250 250 250 ' Interval 4YRTST P/F P Notes: MIT [A >' Wednesday, June 17, 2020 Page I of 1 • • h\11/7• THE STATE Alaska Oil and Gas tiOfA cc TTKA Conservation Commission 333 West Seventh Avenue 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \" Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov August 15, 2017 Mr. Patrick Wolfe North Slope Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH-17-017 Defeated Safety Valve System SCANNED �� 017/ KRU 2M-31 (PTD 1960770) Dear Mr. Wolfe: The Alaska Oil and Gas Conservation Commission (AOGCC) has completed its review of ConocoPhillips Alaska Inc. (CPAI)'s July 24, 2017 letter summarizing an investigation and corrective actions in response to the defeated safety valve system on Kuparuk River Unit 2M-31. Consistent with CPAI's commitment, a field-wide bulletin was issued on July 26, 2017 alerting personnel to the error and reminding them of the expectations established in CPAI's Safety Valve System Operating Procedure. Implementation of other actions—including using supervisors and managers to periodically verify operable well safety valve systems—should help to protect against recurrence of this violation. The AOGCC does not intend to pursue any further enforcement action regarding the improperly defeated safety valve system at Kuparuk River Unit 2M-31. Sincerely, Hollis S. French Chair, Commissioner cc: AOGCC Inspectors (via email) • trick Wolfe RECEIVED Monhger \,/ L.fir/' North Slope Integrated Operations and Projects conocoPhiHipsED JUL 2 5 2017 Post Office Box 100360 Anchorage,Alaska 99510 Alaska Pt'.., VC ATO-1226 Phone 907.265.6202 Patrick.J.Wolfe@conocophillips.com July 24, 2017 Hollis S. French Chair, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501-3572 Dear Commissioner French: Re: Response regarding the KRU 2M-31 Defeated Safety Value System (SVS) On June 26, 2017, the wellhead safety valve system (SVS) was found to be defeated during a required performance test of the 2M-31 well in the Kuparuk River Unit (KRU). ConocoPhillips Alaska, Inc. (COPA) started an investigation of the matter on the same day. In a letter received July 12, 2017, the Alaska Oil and Gas Conservation Commission (AOGCC) asked COPA to provide the AOGCC with an explanation of how this event happened and what has been or will be done in the future to prevent recurrence. COPA provides the following description of events that led to the wellhead SVS being defeated, as revealed by the COPA incident investigation, and steps being taken to prevent recurrence. Description of Incident: During an AOGCC-witnessed SVS test on well 2M-31, the hydraulic panel for the well was found to be blocked, preventing discharge of the hydraulic pressure, thus holding the surface safety valve (SSV) open. The solenoid exhaust valve on the hydraulic panel was in the closed position, preventing the hydraulic actuator from discharging to the dump container. When the valve was opened, the pressured released and allowed the SSV to close. Contrary to COPA policy and Alaska Safety Handbook requirements,there was no flagging or tag present on the valve to indicate that it was in the closed position, and there was no entry to the Safety Defeat Log to record that the low-pressure pilot was in a defeated condition. The orange Operations custody seal was on the valve, indicating (incorrectly) that Operations personnel had confirmed it was in its normal position. Hollis S. French • • Chair, Commissioner, AOGCC July 24, 2017 Page 2 Findings: COPA completed an investigation into the defeated SVS on July 2, 2017. The investigators found that the solenoid exhaust valve was closed sometime between the 2M-31 "WAG" to gas injection procedure on June 22, 2017 and the SVS performance test on June 26, 2017; however,the investigators could not determine exactly when or why the valve was closed. The closed valve was not noticed during the daily operator wellhouse inspections that were completed each of the three days during that period prior to the AOGCC-witnessed test on the fourth day. Neither the maintenance crewmembers who conducted the WAG, nor the drill site operators responsible for the pad recall closing the valve. Operator logs do not indicate that any other work was done on the well during that time. The maintenance crew closed the SSV during the WAG for energy isolation purposes, so the valve was open immediately prior to that procedure. The crew also performed a function test of the SVS after completion of the WAG. The maintenance crew consisted of three drill site operator-qualified individuals, and they all understood the applicable procedures and requirements. The operator completed wellhouse inspections each day. While it is possible that the operator inadvertently closed the valve during his wellhouse inspections and verifications after the WAG, he does not recall touching it. The closed valve is partially obscured since it is behind the face of the hydraulic panel, but is not completely hidden. The operator recognized that the orange Operations custody seal was attached to the valve, but the incorrect position of the valve was not identified by the operator during well walks. In response to this discovery of a closed valve, we immediately inspected the wellhead SVS on each well in KRU for proper alignment and custody seals. All wells were found to be correctly aligned with the correct seals. Our investigation into this matter has revealed this was an isolated human error. In addition to inspecting all other KRU wellhead SVS system for proper valve alignment, which has been done, we are committed to completing the following work in response to this incident: • Prepare a field-wide bulletin, alerting personnel to this error and reminding them of the expectations in ensuring compliance with the Safety Valve System Operating Procedure. • Review and reinforce the Alaska Safety Handbook Tagging and Flagging Standard, daily well walk requirements, and SVS Operating Procedure requirements and expectations with drillsite managers and operators throughout the KRU. Hollis S. French • • • Chair, Commissioner, AOGCC July 24, 2017 Page 3 • Initiate periodic verification by supervisors and managers of wellhead safety valve systems. • Continue to implement improvements to the SVS Operating Procedure as improvements are identified. In addition to the action items listed above, we have commissioned a small learning team to take a fresh look at valve sealing and daily inspections to see if there are systematic adjustments we can make that would protect against recurrence of this error. Yours truly, cOrki\i‘ ,\N4Z— Patrick Wolfe • Kuk ZA -5 p-rb 19(O720 Regg, James B (DOA) A—%c bcC et- a m- 11-011 From: NSK HSE Admin Assist <n1154@conocophillips.com> Sent: Wednesday, July 26, 2017 9:28 AM Subject: Safety Bulletin-Wellhead Safety Valve System Hydraulic Panel Operation Attachments: 20170726 Wellhead Safety Valve System Hydraulic Panel Operation.pdf Safe Bulletin Wellhead Safety Valve System Hydraulic Panel Operation Please do not reply to this note Contact r Safety Dept withcomments r for further information. Safety Bulletins may also be viewed via the HSE Web Page CLICK HERE Please share with others and post appropriately. NSK HSE Administrative Assistant ConocoPhillips Alaska Work:(907)265-1369 Email: N1154@conocophillips.com 1 • • July 26,2017 ConocoPhiIIi s Alaska , SAFETY BULLETIN p Wellhead Safety Valve System Hydraulic Panel Operation A Wellhead Valve Safety System (SVS) hydraulic panel exhaust valve was recently discovered with a custody seal in the closed position. Normal operating position for this valve is open. Wellhead SVS Hydraulic Panel Valve in Normal Open Position with Custody Seal .®► ..-__,J, r ,c,,,,,)/ Mips Alaska,Inc. r.,Alaska,Inc. 0 ." w: This photo I opyright oil ConocoPhillips Mask- _ : ^*�.a 4`Io s copyright of ConocoPhillips Alaska.inc and cann released or i-. ,s. wriiten consent 01 ""' or published without the express written consent of ConocoPhilli Al --,,, Authorized personnel must: - Follow the Ash Tagging and Flagging Standard when defeating a wellhead SVS, and - Apply a green custody seal to the valve after returning it to its normal position, and - Notify the operator The Drill Site Operator must: - Verify that valves are in the normal operating position, and - Replace green custody seals with orange custody seals within 12 hours following well work. Refer to the Safety Valve System Operating Procedure for more information about steps to ensure the correct valve alignment is verified prior to applying custody seals. Contact your Safety Department if further information is needed. Post on Bulletin Boards and Review in Safety Meetings y • 0 July 26,20" ConocoPh i l l i s p Alaska [ SAFETY BULLETIN 11 If this bulletin applies to your work group, please review the Safety Valve System Operating Procedure in tailgates or training sessions. Contact your Safety Department if further information is needed. Post on Bulletin Boards and Review in Safety Meetings • S Regg, James B (DOA) From: Regg,James B (DOA) Sent: Thursday, July 13, 2017 4:09 PM 71i 5 I' To: Foerster, Catherine P (DOA); French, Hollis (DOA); Seamount, Dan T (DOA); Ballantine, Tab A (LAW) Subject: RE: Inquiry from CPAI re Docket OTH 17-017 Summary is sufficient as long as it describes the root cause(s) identified in their investigation and corrective actions to be implemented. Because of past NOVs for defeated SVS,there has been an iteration of corrective actions put in place by CPAI as subsequent defeated valves have been found. We don't need a boiler plate reiteration of the same old information as a summary.That's why I asked for the investigation report. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 orjim.regg@alaska.gov. From: Foerster, Catherine P (DOA) Sent:Thursday,July 13, 2017 3:47 PM To: Regg,James B (DOA)<jim.regg@alaska.gov> Subject: FW: Inquiry from CPAI re Docket OTH 17-017 Sounds reasonable to me. Your thoughts? From: Ballantine,Tab A(LAW) Sent:Thursday,July 13, 2017 3:44 PM To: French, Hollis(DOA)<hollis.french@alaska.gov>; Foerster, Catherine P(DOA) <cathy.foerster@alaska.gov>; Seamount, Dan T(DOA)<dan.seamount@alaska.gov> Subject: Inquiry from CPAI re Docket OTH 17-017 Hollis, Cathy and Dan, Took a call this afternoon from Jon Goltz, CPAI's lawyer, about the July 10, 2017 letter to CPAI requesting CPAI's internal investigation into the defeated SVS at KRU 2M-31. Jon asked that I inquire as to AOGCC's willingness to accept a summary and the results of CPAI's internal investigation rather than the entire internal investigation. CPAI feels it is currently able to achieve frank and candid input during internal investigations what would be chilled or diminished if those involved in the investigation thought their comments might be made public at a later time. Essentially CPAI feels its ability to effectuate change is hampered once those involved in an investigation start filtering what they say or how they say it. I told him I would make the inquiry. Let me know what you think or if you want to meet on this. 1 • • • �w\�O �/7, THE STATE Alaska Oil and Gas � d�� 9� 0 f A T aS]�`�T Conservation Commission 1 1Ll 11 1 333 West Seventh Avenue 1. 41111..1- 111wGOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ��'ALAS�P Fax: 907.276.7542 www.aogcc.alaska.gov July 10, 2017 CERTIFIED MAIL— RETURN RECEIPT REQUESTED 7015 1660 0000 1487 7296 Mr. Patrick Wolfe North Slope Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH-17-017 Defeated Safety Valve System KRU 2M-31 (PTD 1960770) Dear Mr. Wolfe: On June 26, 2017, an Alaska Oil and Gas Conservation Commission (AOGCC) Inspector witnessed miscellaneous well safety valve system tests on Kuparuk River Unit(KRU)2M pad that were performed by a ConocoPhillips Alaska Inc (CPAI) representative. The safety valve system on KRU 2M-31 was found defeated. Investigation revealed that the safety valve system was defeated at the panel. The well safety valve system did pass the required performance test once the valve was normalized. A copy of the Inspector's report is attached. The facts reported by the AOGCC Inspector indicate a failure to maintain an operable safety valve system which is a violation of State regulations. CPAI's NSK Fieldwide Operations Superintendent contacted AOGCC's Inspection Supervisor on June 28, 2017 about the defeated safety valve system, noting that an internal investigation was underway. CPAI is reminded that a completed well must be equipped with a functional safety valve system as described in 20 AAC 25.265. Paragraph(m)of 20 AAC 25.265 establishes tagging procedures for a well safety valve system component that is inoperable, removed, or blocked. There was neither a tag observed on KRU 2M-31 that would indicate an inoperable safety system nor was there any reason for the valve to be defeated. Defeating any component of the critical well safety valve system—except as provided in 20 AAC 25.265 —will not be tolerated. Within 14 days of receipt of this letter, CPAI is requested to provide the AOGCC with a copy of its internal investigation report, and describe what has or will be done in the future to prevent its • • Docket Number: OTH-17-017 Notice of Violation—KRU 2M-31 July 10,2017 Page 2 of 2 recurrence at CPAI-operated fields in Alaska. Failure to comply with this request will be an additional violation. The AOGCC reserves the right to pursue enforcement action in connection with the defeated safety valve system on KRU 2M-31. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, Hollis S. French Chair, Commissioner Attachment cc: P. Brooks AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • • • ill crl 0 T.) 47›.1 t 4 o.•a E _� ° R� €n. a a: U v) O "o .s a. y 00 C c y ti „ o d▪ a (4 w a E p N CI Ol f:4 iso ? GE z z colC SCC 6.4o o N r� v z z o > Mto o 0 /J VD st, M Hr�u1 O a ,'OI F a M M oU FV e w h 0 C -5a M o0 03 cn o 3 N w PC o ar V1 4 a o C 74 4Li o, tit flt!IH en 4J � `¢ o� yV — A x a R12 U g 4v w u ZO Fv ct a, Uy p� m., E, U a. a, - .r C O . W o W L ar Or w) 0 en c'l �. o. E O a N v .3 F. o o I.! CA FSI a C) 0, _ d N N o vi y N rq a 11 A~ ati > E o h `' y O E• .0h W N M o N waz• � � y , �^ N a o v tO,....4)Ny ;It 6 j O. O.....I £ M U T CQ — d ,to O M A o 3 a E °- , ^y Z N N E N G -o a W., 3 0 U.S. Postal Service"' • CERTIFIED MAIL° RECEIPT -0 Domestic Mail Only a- ru For delivery information,visit our website at www.usps.com". r- ro Certified Mail Fee ? $ I-1 Extra Services&Fees(check box,add fee as appropriate) ❑Return Receipt(Hardcopy) $ C ❑Return Receipt(electronic) $ Postmark ❑Certified Mail Restricted Delivery $ Here ❑Adult Signature Required $ ❑Adult Signature Restricted Delivery$ p Postage .-0 $ Total Postage and Fees Patrtick Wolfe $ Ln Sent To North Slope Operations Manager _ ConocoPhillips Alaska, Inc. p Street and Apt.No.,or PO Box A r- P.O. Box 100360 City,State,ziP+44 Anchorage,AK 99510-0360 11130 ralF*jIIe1_TMIIP2t1FT1cLre.nt.u.ra in.aa.cs� ht.,11.,`i4e-7 4t.irrrwhunyftnr1 • SENDER: COMPLETE THIS SECTION COMPLETE i"hIS SECTION OP'DELIVERY • Complete items 1,2,and 3. A. Sig `, ifr � , ▪ Print your name and address on the reverse X ` I0 Agent so that we can return the card to you. Addressee ■ Attach this card to the back of the mailpiece, B. eceived by 7i•. d -me) C. Date of Delivery or on the front if space permits. - 4//ll -- —r D. Is delivery address different rom item 1? • Yes Patrtick Wolfe AltitVelbLery address below: 0 No North Slope operations Manager ConocoPhillips Alaska, Inc. JUL 1 2 2011 P.O. Box 100360 Anchorage,AK 99510-0360 `' OG I III II I'I 'IIIII I1I1I 11111 III 111 3. Service TypeE❑Priority ss® ❑Adult Signature 0 Registered Mail aiiprlm° ❑Adult Signature Restricted Delivery 0 Registered Mail Restricted ®Certified Mail® Delivery 9590 9402 1823 6104 6488 56 0 Certified Mail Restricted Delivery Return Receipt for ❑Collect on Delivery Merchandise 2. Article Number(Transfer from service label) 0 Collect on Delivery Restricted Delivery 0 Signature Confirmationro _.pail 0 Signature Confirmation 7015 1660 0000 1487 7296 Mail Restricted Delivery of Restricted Delivery PS Form 3811,July 2015 PSN 7530-02-000-9053 Domestic Return Receipt • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,March 07,2017 Jim Regg P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-31 FROM: Brian Bixby KUPARUK RIV UNIT 2M-31 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2M-31API Well Number 50-103-20241-00-00 Inspector Name: Brian Bixby Permit Number: 196-077-0 Inspection Date: 2/27/2017 Insp Num: mitBDB170228055644 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2M-31 - Type Inj W TVD 6040 Tubing 2575 2575 - 2575 • 2575 - PTD 1960770 Type Test SPT Test psi 1510 - IA 1550 3200 - 3180 - 3175 BBL Pumped: 2.1 - BBL Returned: 2.1 OA 410 430 - 430 - 430- - Interval 4YRTST P/F P Notes: Injection pressure was 2575 psi so we tested to 3200 psi. SCOW APR 2 8 20117, Tuesday,March 07,2017 Page 1 of 1 • ! MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 09,2016 TO: Jim Regg . 1 P.I.Supervisor , � ' "(l• SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-31 FROM: Jeff Jones KUPARUK RIV UNIT 2M-31 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 3j12— NON-CONFIDENTIAL 1Z- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2M-31 API Well Number 50-103-20241-00-00 Inspector Name: Jeff Jones Permit Number: 196-077-0 Inspection Date: 6/5/2016 Insp Num: mitJJ160608092433 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2M-31 Type Inj W'TVD 6040 - Tubing 1440 1440 1440 ' 1440 • PTDI 1960770 Type Test SPT Test psi 1510 - IA 400 2210 - 2160 - 2150 - Interval 4TST P/F P OA 360 • 420 • 380 - 380 Notes: 1 well inspected,no exceptions noted. SCAMSDEC 292016 Thursday,June 09,2016 Page 1 of 1 • • Vq(c, , 0-11 25'°1 WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. December 17, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 /2,A/2016, .vi.K.BENDER RE: Multi Finger Caliper (MFC): 2M-31 Run Date: 11/15/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2M-31 Digital Data(LAS), Digital Log file, Casing Inspection Report,3D Viewer 1 CD Rom 50-103-20241-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: � �., _ /4. ,/, XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Complete [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS' Scanned by: Bevedy ~incent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ MEMO1~Alli11DUM State of Alaska Alaska Oil and Gas Conservation Commission ,~ DATE: Wednesday, June 11, 2008 To: Jim Regg '~~~;~~ (~ IZI P.I. Supervisor `/ `~ SUBJECT: Mechanical Integrity Tests L CONOCOPHILLIPS ALASKA INC 2M-31 FROM: Jeff Tones KUPARU'K RIV UNIT 2M31 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv,~~ Comm Well Name: KUPARUK RN UNIT 2M-31 API Well Number 50-103-20241-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ080610130559 Permit Number: .196-07~-o Inspection Date: 6/2/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I 2M-31 W Well ;Type Inj' I ' TVD ~ 6040 ~ ~ IA I loo Soso ~ I i ITT--- Soso Soso ~ i 1960770 YP -_ --- P.T. _ ~T eTest Test psi ! lsto ~ OA sso aoo aoo j aoo ~ ~ Interval 4YRTST per, ___ __ P ~ _ _ _ Tubing i 2400 ', 2375 I ___ _ _ 2450 T 2450 -_ - _ - r- NOteS' 2.6 BBLS diesel pumped; no exceptions noted. ~~~~' JUL ~. ~r 2008 Wednesday, June 1 1, 2008 Page 1 of t • ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 6, 2008 • RECEIVED JAN U 8 200 Alaska Oil & Gea Conan, Ga~uion Anchorage Mr. Tom Maunder Alaska Oil & Gas Commission ~~ 333 West 7~' Avenue, Suite 100 r,~~ Anchorage, AK 99501 c~~~~'~~,~ ,SAN ~. ~. ~~D~ w"`` Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of 12". The remaining volume of annular void respectively was filled with a corrosion inhibiter, RG2401, 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 top-fill operation was completed on Dec 25, 2007. We mixed 15.7 ppg Class G cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor/sealant was pumped in a similar manner Jan 6, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Sincerely, r' Perry ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404j Kuparuk Field n~+e MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor r cft;;;' (0 7 DATE: Thursday, August 09, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-31 KUPARUK RIV UNIT 2M-31 FROM: Bob Noble Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .:JBr2- Comm NON-CONFIDENTIAL Well Name: KUPARUKRIVUNIT2M-31 API Well Number: 50-103-20241-00-00 Inspector Name: Bob Noble Insp Num: mitRCN070806132042 Permit Number: 196-077-0 Inspection Date: 8/5/2007 Rei Insp N urn: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 2M-31 IType Inj. I w I TVD 6040 '/(IA 1000 i 2130 I 2130 r 2130 I , i ! I ! I 1960770 I ! I /1 OA I ¡ I ! P.T. ¡TypeTest i SPT ¡ Test psi 1510 380 ! 390 390 390 ! I I I , I / -..-/ Tubing 2600 i 2600 2600 ! 2600 ! Interval INlTAL P/F P ! ¡ I -- Notes: ~~ (..JcJr-LLCv"er JvU>TJA SCANNED AUG 23 Z007 Thursday, August 09, 2007 Page 1 of 1 STATE OF ALASKA ~ . ?,,?.p~ . RECEIVED c~~ JUN 2 ~ 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION ' REPORT OF SUNDRY WELL OPERA TIONSlaska Oil & Gas Cons. CiJmmission . 1. Operations Performed: Abandon D Repair Well 0 Plug Perforations D Stimulate D Other An~rage Alter Casing D Pull Tubing 0 Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 196-077 1 -- 3. Address: Stratigraphic D Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20241-00 ? 7. KB Elevation (ft): 9. Well Name and Number: Nordic 3 Rig RKB 46.8', GL 100.2' 2M-31 < 8. Property Designation: 10. Field/Pool(s): ADL 25585,/ ALK 2671 Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 13161' / feet true vertical 6288' , feet Plugs (measured) Effective Depth measured 13040' feet Junk (measured) true vertical 6205' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SUR. CASING 3994' 9-5/8" 4035' 2826' PROD. CASING 13110' 7" 13151' 6281' Perforation depth: Measured depth: 12895'-12947' SCANNED JUl o 5 2007 true vertical depth: 6107'-6142' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 12822' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'SAB-3' pkr= 12794' Cameo 'OS' nipple @ 496' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none RBDMS 8Ft JUL 0 ::I 2007 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met I Water-Bbl Casino Pressure Tubina Pressure Prior to well operation I SI -- Subsequent to operation waiting on facility maintenance -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory D Development D Service 0 Daily Report of Well Operations _X 16. Well Status after work: oilD GasD WAG 0 GINJD WINJD WDSPL D 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: 307-080 Contact Jill Long @ 265-1102 Printed Name Jill Long ~õYW Title Wells Group Engineer D0/27J07 Signature Q "0 0 Phone 1to 5 -I (0 2- Date PreMred bv Sharon AI/sun-Drake 263-4612 U ORIGINAL þ., l~ ~ " ·/.$-(;17 Form 10-404 Revised 04/2006 Submit Or' . al Onl :;!f7;!Þ7 . . Conoc~hillips Time Log Summary We/Mew Web Reporting Well Name: 2M-31 Job Type: RECOMPLETION 05/12/2007 12:00 00:00 12.00 MIRU MOVE MOB P Moving rig from 3M Pad to 2M pad. Estimate 23 miles. Wait on crew change @ CPF #3. 05/13/2007 00:00 04:00 4.00 MIRU MOVE MOB P Moving Nordic 3 from 3M Pad to 2M Pad 04:00 06:30 2.50 MIRU MOVE RURD P Rig arrive 2M-31. Hang tree in sub, locate rig over well, center I level rig. I (accept rig @ 0630 5-13-07) 06:30 10:30 4.00 MIRU MOVE RURD P Spot tanks, lay lines, test same 3000 I psi. 10:30 12:00 1.50 COMPZr WELCT COND P Take on kill fluids, condition same. 12:00 13:00 1.00 COMPZr WELCT OTHR P PJSM, pull BPV, monitor well. Well static. 13:00 16:00 3.00 COMPZr RPCOII. CIRC P Circ I displace freeze protect diesel from well. Cont circ well free from diesel. Monitor well, set BPV. 16:00 17:30 1.50 COMPZr RPCOII. NUND P PJSM, Mark I photograpth flanges, ND I prod tree. 17:30 21:30 4.00 COMPZI RPCOII. NUND P PJSM, NU BOPE 21:30 00:00 2.50 COMPZI RPCm OTHR P Test BOPE 250-3500. 05/14/2007 00:00 02:00 2.00 COMPZI RPCOII. OTHR P Finish testing BOPE 250-3500. 02:00 03:00 1.00 COMPZI RPCOII. OTHR P Rig down test lines-pull Blanking plug & BPV. 03:00 04:00 1.00 COMPZI RPCOII. OTHR P Rig up landing jt.-PJSM-pull hanger to rig floor. Picked up to 115k-leveled out @ 11 Ok. 04:00 05:00 1.00 COMPZr RPCOII. CIRC P Reverse circ. annulus volume 335 bbls. @ 6 bpm 1260 psi. 05:00 06:00 1.00 COMPZr RPCOII. OTHR P Monitor well-fill trip tank-lay down landing jt. & hanger. 06:00 23:30 17.50 COMPZr RPCOII. PULD P POH laying down 401 jts. & cut off jt. inspecting pipe while laying down strapping & unloading pipe shed. (Cut off Piece is 12.56') 23:30 00:00 0.50 COMPZr RPCOII. PULD P Unloading pipe shed & loading floor wI milling tools. 05/15/2007 00:00 01:00 1.00 COMPZr RPCOII. RURD P Rig down tbg. equipment. & rig up for I picking up 3.5" DP. 01:00 11 :00 10.00 COMPZr RPCOII. OTHR P Rack & Tally 3.5" DP in pipe shed.(Set wear ring & make up BHA while racking & tallying DP.) 11:00 21:30 10.50 COMPZr RPCOII. PULD P Picking up 3.5" DP to 12744'. 05/15/200721:30 00:00 2.50 COMPZr RPCOII. OTHR P Working over top of 3.5" stub @ 12768 Drill pipe measurements. COMPZr RPCOII. 05/16/2007 00:00 02:00 2.00 COM pzr RPCOII. OTHR P Continue wash down to 12768'-mill on stump. PP-1550 psi-100 spm-155k up 80k down Rot-118k RPM 100 Tq 87-92k 02:00 03:00 1.00 COMPZr RPCm CIRC P Pump hi-vis sweep. 03:00 08:30 5.50 COMPZr RPCOII. TRIP P Monitor well-blow down top drive & POH. 08:30 10:00 1.50 COMPZr RPCOII. PULD P Lay down BHA-Retrieved "K" Anchor-pup & 18.85 cut off jt. Clean boot baskets. Small amount of trash. 10:00 12:00 2.00 COMPZr RPCOII. OTHR P Continue loading pipe shed wI 3.5" Tbg. & finish breaking down BHA while waiting on "K" anchor. 12:00 14:30 2.50 COMPZr RPCOII. PULD P Pick up PBR-assemble PBR & "K" Anchor. Finish loadin9pipe shed. 14:30 16:30 2.00 COMPZr RPCOII. OTHR P Testing csg. to 2000# in 500# increments. 16:30 00:00 7.50 COMPZr RPCOII. TRIP P Make up "K" Anchor & PBR & RIH to 12627' . 05/17/2007 00:00 01:00 1.00 COMPZr RPCOII. OTHR P Test Csg. to 2500 OK. RIH locate & latch in "K" Anchor @ 12794' DP measurements. Presure DP to 2000# Shear PBR wI 165k up. Top of PBR @ 12771 DP measurements. 01:00 02:00 1.00 COMPZr RPCOII. CIRC P Circ. Capacity of DP & pump slug. 02:00 11 :00 9.00 COMPZr RPCm PULD P Lay down 3.5" DP. 11:00 12:00 1.00 COMPZr RPCm OTHR P Lay down 3.5" Seal Assembly-clean floor & pull wear rinQ. 12:00 13:30 1.50 COMPZr RPCm RURD P Rig up floor to run 3.5" Tbg. 13:30 00:00 10.50 COMPZr RPCOII. RCST P Make up seal assembly & sliding sleeve & RIH picking up 3.5" 9.3# L-80 EUE 8rd MOD tbg. 05/18/2007 00:00 01:00 1.00 COMPZr RPCOII. RCST P Continue RIH PU 3-1/2", 9.3#, L-80, EUE 8rd MOD Tubing and jewelry. 01:00 02:00 1.00 COMPZr RPCOII. RCST P Sting seals into PBR, locate out on no go, mark pipe for space-out 2' up from no go. Test seals with 500 psi, 5 minutes, OK. Unsting, install space out pups (9.97' + 9.95') a full joint below hanger. MU FMC Tubing Hanger & landing joint with circulating line. 02:00 04:00 2.00 COMPZr RPCOII. CIRC P Circulate 9.6 ppg brine with 1 % CRW-132 corrosion inhibitor down tubing and chase with tubing volume of brine to spot inhibited brine in annulus from seals up to GLM at 2502' MD, 5 BPM, 820 psi. 06:30 08:30 2.00 COMPZ 08:30 10:30 2.00 COMPZ 10:30 11:30 1.00 11:30 13:30 2.00 COMPZ RPCOII. FRZP 13:30 14:00 0.50 14:00 15:00 1.00 Drain stack. Land tubing hanger. RILDS. Test tubing to 2500 psi, 15 minutes, OK. Bleed tubing down to 1750 psi, test IA to 2500 psi, 30 minutes, OK. Bleed off tubing and sheared open the SOV in GLM, OK. RD lines. Set BPV. P PJSM. ND BOPE. P NU new 3-1/8", 5 Ksi, WKM tree. Pull BPV. Set TP. Test tree 250 psi & 5000 si, OK. P Pull TP. Change out wing valve on tree - new valve had damaged retainer for chain operator. Install new valve and test to 250 psi & 5000 psi, OK. Chain operator missing some parts for proper installation - valve shop will be alerted to line up and install missing arts. P RU circulating lines and Little Red Hot Oil Unit. PJSM. Test lines to 2500 psi. LRS reverse circulate 88 Bbls of diesel into IA and up tubing for freeze protection, 2 BPM, 1100 psi. Initial shut down ressure 50 si. RD LRS. P Set BPV. P RD lines. Secure well. Tubing = IA = o psi. OA = 340 psi. Finish cleaning out pits. Release Rig at 1500 hrs, 5/18/07. . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTI) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8952 1 Report / EDE 2M - 31 Caliper Report 29-Apr-07 1) 2) 3) 4) 5) 6) 7) i,~MA,{ 0''1 Z007 U ..L- c.. 1£1(0 -O-1-~ ~:!l I 'S 07-<1 RECEIVED Print Name: ¡j (] ) ''\--- - (~tlrì6tl'¡A e .lilÎ.dkLl~'~ MAY 0 3 Z007 Signed: Date ÀIeska Oil & Gas CeRs. Com",i~iOl1 Anchorage PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.GOM WEBSITE : WWW.MEMORYLOG.COM D:lMasIBr _copy _ 00 ]DSANC-2OxxIZ _ WordlDistribution\TnmsmittaC Sheets\TrnnsmiU>riginal·doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Well: Field: State: API No.: Top Log IntvI1.: Bot. Log I ntvl1.: ConocoPhillips Alaska, Inc. April 29, 2007 8591 2 3.5" 9.3 lb. L-80 EUE Tubing Inspection Type: COMMENTS: Co«osive & Mechanical Damage Inspection 2M-31 Kuparuk Alaska 50-103-20241-00 Surface 12,532 Ft. (MD) This caliper data is tied into the top of GLM 1 @ 2,104' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to internal corrosive and mechanical damages. The recordings indicate the 3.5" tubing is in good to poor condition with respect to corrosive damage, with a recorded hole in joint 60 at 1,938'. Penetrations in excess of 20% are recorded in 353 of the 399 joints logged. The damage appears in the forms of general corrosion, isolated pitting, and lines of corrosion below 1,160', No significant areas of cross-sectional wall Joss or 10 restrictions are recorded. This is the second time a PDS caliper has been run in this well. A comparison between the current and previous log (October 9,2005) for the interval between 786' - 3,025' indicates a slight increase in corrosive damage. A comparison plot illustrating the difference in maximum - recorded penetrations betwe~n logs on a joint by joint basis is included in this report. Indications of damage are also recorded in the upset areas of a number of joints throughout the tubing interval logged. The distribution of maximum - recorded upset penetrations is illustrated in the Coupling Region Analysis Page of this report. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report, A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Hole Isolated Pitting Corrosion Corrosion Isolated Pitting ( 100%) ( 83%) ( 83%) ( 81%) ( 80%) Jt. Jt. Jt. Jt. Jt 60 52 64 54 40 @ @ @ @ @ MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional wall loss (> 9%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded. Field Engineer: K. Miller Analyst: M. Tahtouh 1,938 Ft. (MD) 1,671 Ft. (MD) 2,041 Ft. (MD) 1,724 Ft. (MD) 1,298 Ft. (MD) D P¡'oActive Diagnostic Services. lnc. / P,O. Box 1369, Stafford, TX 7í497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ú~~Q, /C,(o-O--::¡r:4P ISOl-L-\ MAY l) ~ 7007 AlæÞ.i\ .".",~ I I I Well: Field: 2M-31 I ConocoPhillips Alaska, Ine USA Tubing: Nom.OD 3.5 ins Weight 9.3 f Grade & Thread L-80 WE I I Penetration ami Metal Loss (% wall) penetration metal loss body I 400 300 200 100 0 o to 1% 10 to 20 to 40 to over 20% 40% 85% 85% I 1 to 10% I 1 o I pene. loss I Damage Configuration ( 300 250 200 150 100 50 o ísolated píttíng I I general line ring hole! poss corrosion corrosion corrosion ible hole I I I I ew Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: 29,2007 MFC 24 No. 40665 1.69 24 M. Tahtouh Nom.ID 2.992 ins Nom. Upset 3.5 ins Upper len. 6.0 ins Lower len. 6.0 ins Damage Profile (% penetration metal loss 50 100 96 196 296 Bottom of Survey = 394 Analysis Overview page 2 I I I Correlation to Borehole Profile I Pipe 1 3.5 in (29.7' - 12506.4') Well: Field: Company: Country: Survey Date: 2M-31 Kuparuk ConocoPhillips Alaska, Inc. USA April 29, 2007 I I I Approx. Tool Deviation Approx. Borehole Profile 50 33 I I 1592 GlM1 I 100 3186 I 150 4770 I I ... Q) 200 6355 .,.; J::¡ E u.. ::;j .S: z E 'õ 7943 250 I 300 9530 I 350 11114 I I 394 o 50 12506 100 Damage Profi!e (% wall) / Tool Deviation (degrees) I I BaHam of Survey = 394 I I -------------------- I I I urn Penetration To Previous Well: 2M-31 SUrYe Date: April 29, 2007 I Field: K uparuk Prey. Date: October 9, 2005 Compan : ConocoPhillips Alaska, Inc. rool: MFC 24 No. 40665 Countr : USA Tubing: 35' 9.3 Ib L-30 EUE I Ov ria rence Max. !tee. Pen. (mils) Difl'. in Max. Pen. (mils) I 0 100 200 300 -200 -100 0 100 200 24 I 34 I 44 I I 54 .. .. w li .1:1 ë ë ::I ::I Z Z ... ... I " " ]. 64 ]. I 71 I 81 I 91 I -64 ·32 0 32 64 Approx. Corrosion Rate (mpy) I I I I I REPORT JOI TABULATION SH I I Pipe: BodyWal!: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf L-80 EUE 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2M-31 Kuparuk ConocoPhillips Alaska, Ine. USA April 29, 2007 I I Joint Jt. Depth Perl. Pen. PerL Metal Min. Damage Profile No. (Ft.) \~:~:I;t Body !.D. Comments (%wall) (Ins.) (Ins.) 0 50 100 .1 30 0.02 7 2.94 PUP 1 33 0.03 10 2.92 2 66 0.02 6 2.92 3 98 gID=3±±i 2.91 Shallow corrosion. 4 131 2.92 Shallow oittirìºr. Lt. Denosits. 5 162 0.0313 2.92 Shallow oittimz. 6 194 C 0.03 ¡'J 2.91 Shallow nittin\!. Lt. Denosits. 7 226 0 0.02 q 2.92 8 257 0 0.02 9 2.91 9 289 0 0.02 2.92 10 320 0 0.03 2 2.92 11 352 C 0.02 1 2.91 12 384 0 0.03 r2 2 2.93 13 416 0 0.02 2.92 14 448 0.01 2.91 14.1 480 0.02 2.95 PUP 14.2 485 ( 0 ( N/A DS NIPPLE 14.3 487 0.00 ( 2.95 PUP 15 492 0 0.02 B 2.92 16 524 0 0.03 1 2 2.93 17 556 0 0.01 6 2 2.92 18 588 ( 0.02 6 2.92 19 620 ( 0.0311i 2.91 20 651 0.03 2.93 21 683 ( 0.03 10 2.93 22 715 0.02 9 2.92 23 tio 0.02 7 2 2.92 24 0.03 12 2.93 25 810 ( 0.03 10 2.93 * ( 0.0 2.94 27 873 0.03 10 2.92 Lt Denosits. 28 905 ( 0.03 I ¡ 2.94 U. Deoosi ts. 29 937 0.04 6 2.92 Shallow corrosion. ¡ 30 969 0 0.03 12 2 2.92 31 1001 0 0.03 13 2.90 Shallow oittim~. 32 1032 0 0.03 2 2.93 33 1064 0.03 2.93 34 1096 0.03 2.92 35 1128 0.02 2.92 III 36 1160 ( 0.ü7 2.89 Isolated oittimI. 37 1190 ( 0.03 2.91 Shallow oittímI. 38 1219 0 0.17 67 IJ 2.92 Isolated oíttírm. 39 1251 0 0.19 ( 2.91 Isolated níttín\!. 40 1282 0 0.20 ) 2.91 Isolated níttín\!. 41 1314 0 0.17 2.93 Corrosion. 42 1346 0.12 0.17 2.92 Isolated oittin\!. 43 1377 0 0.15 ( 2.90 Corrosion. U. Deoosits. 1409 0 0.16 63 5 2.92 Corrosion. I 45 I 1439 0 0.15 57 6 2.91 Isolated Dittim~. 46 I 1468 0.11) 0.16 63 4 2.91 Isolated oíttirw. I I I I I I I I I I I I Body Metal Loss Body Page 1 I I I I INT LATION SH I Pipe: BodyWaH: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf L-80 EUE 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2M-31 Kuparuk Co no co Phillips Alaska, Ine. USA April 29, 2007 I I Joint Jt Depth Pel Pen. ¡¡en. Melal Min. Damage Profile No. 1(;:::';1 Body I.D. Comments (%wall) (Ins.) (Ins.) 0 50 100 47 1500 I) 0.15 5 2.92 Corrosion. 48 1531 I) 0.19 7 2.91 Isolated nittinQ. 49 1561 0 0.17 I 6 2.91 Corrosion. 50 1592 ° 0.18 I 6 2.91 Corrosion. U. Deoosíts. 51 1624 0 0.16 6 2.91 Corrosion. 52 165f. ° 0.21 2.92 Isolated oittínQ. 53 1688 [) 0.17 2.92 Corrosion. 54 1719. 2.92 Corrosion. 55 1751 4 2.93 Corrosion. 56 1783 2.93 Corrosion. 57 1814 6 2.92 Corrosíon. 58 1846 ° 5 2.93 Corrosion. 59 1878 0 or, 0.16 6 6 2.93 Corrosion. II 60 ti°.oa 0.26 1 0 2.94 HOLE! 61 0 0.19 2.91 Corrosion. Lt DenosÎts. 62 1973 0 W 0.16 2.91 Corrosion. L t. DenosÎ ts. 63 2005 Iì 1 " 2.94 Corrosion. 64 2036 0.09 0.21 2.91 Corrosion. U. Deoosi ts. 65 2067 o.oa 0.17 613 ¡ 6 2.94 Corrosion. 65.1 2098 0 0.05 3 2.91 PUP Corrosion. 65.2 2104 0 0 0 N/A GLM 1 (Latch @ 9:00\ 65.3 2112 0 0.06 2.85 PUP Corrosion. Lt. Deposits. 66 2118 01 5 0.20 2.93 Isolated niUÎnQ. 67 2150 010 0.18 2.91 Corrosion. 68 2182 0 tffD 2.93 Corrosion. 69 2214 0 2.91 Corrosion. Lt Deoosits. 70 2246 ° 0.18 ,t 2.92 Corrosion. 71 2277 ° 0.14 4 2.91 Corrosion. 72 2309 o c±ft15 6 2.90 Corrosion. 73 2338 : .18 6 2.92 Corrosion. 74 2368 0.17 6 2.90 Corrosion. 75 2400 ( 0.15 / 2.90 Corrosíon. Lt. Denosi ts. 76 2430 0.06 0.16 : 6 2.91 Corrosion. 77 2462 0.07 0.19 73 6 2. 78 2493 0.07 0.16 I 13 2.91 Corrosion. Lt. DeDosits. 79 2523 0013 0.17 I ) 2.91 Corrosion. ! 80 2555 om 2.91 Corrosion. 81 2587 0.17 I 2.89 Corrosion. 82 2619 ()17 2.87 Corrosion. Lt. Denosi ts. 83 2650 o 0.17 I 2.89 Corrosion. It. Denosits. 84 2682 O.OB 0.17 I 2.91 Corrosion. 85 2713 1).07 0.11 2.90 Corrosion. 86 2745 [) 0.11 2.91 Corrosion. 87 2777 0 0.13 5 6 2.89 Corrosion. 88 2809 n nr, 0.12 2.87 Corrosion. 89 2838 n 0.12 2.89 Corrosion. Lt. Denosits. 90 2870 () 0.12 2.90 Corrosion. 91 2902 [) 0.12 2.88 Corrosion. Lt. Deoosi ts. q) ±:f34 0 0.09 36 ß 2.84 Corrosion. Lt. Deoosíts. 93 964 012 0.10 38 7 2.84 Corrosion. Lt. Deoosíts. I I I I I I I I I I I I Body Metal Loss Body Page 2 I I I PDS REPORT INT ON SHEET I Pipe: 3.5 in 9.3 ppf L-80 EUE Well: 2M-31 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhmips Alaska, Ine. Nominal LD.: 2.992 in Country: USA Survey Date: April 29, 2007 I Joint Jt. Depth Pen Pen. Pen i\.leîal Min. Damage Profile No. I.D. Comments (O!· .~II\ \ /0 IVd"! (Ins) (Ins.) (Ins.) 0 50 100 I 94 2996 0 0.12 46 îCl 2.84 Corrosion. It Denosits. 95 3027 o()() 0.11 4S 2.84 Corrosion. It Deoosits. 96 3059 0.10 ¡in Corrosion. 97 3091 OOß 0.10 =1=ft ( 2.81 Corrosion. It Deoosits. I 98 3123 0 0.08 to 2.84 Corrosion. U. Deoosi ts. 99 3154 005 0.08 5 2.85 Corrosion. l t Deoosi ts. 100 3186 o )(¡ 0.14 7 2.87 Corrosion. U. Denosits. 101 3216 í 0.10 {¡ 2.84 Corrosion. U. Denosi ts. 102 3248 OJ 0.09 (¡ ~ CoITŒ;OO U. Deoosits. I 103 3280 o H) 0.10 5 2 Corrosion. Lt. Denosits. 104 3311 0.06 0.14 56 ß Corrosion. 105 3343 0.06 0.18 69 6 Corrosion. U. Deoosi ts. 106 3375 0 0.09 ]. ') 2.85 Corrosion. Lt. Deoosits. I 107 3406 0 0.10 , 2.83 Corrosion. Lt. Deoosits. 108 3437 0 0.10 2.84 Corrosion. Lt Denosits. 109 3469 0 0.15 2.86 Corrosion. 110 3501 01 S 0.09 2.85 Corrosion. Lt. Denosits. I 111 3531 0 0.11 ( 2.86 Corrosion. It. Deoosi ts. 112 3563 0 0.12 fj ( 2.85 Corrosion. Lt. Deoosits. 113 3595 0.09 0.11 4 ¡ 2.87 Corrosion. 114 3627 o O!, 0.12 2.84 Corrosion. U. Deoosi ts. I 115 3658 o )7 0.17 í 2.85 Corrosion. 116 3690 í 0.13 2.85 Corrosion. 117 3722 í 0.11 2.85 Corrosion. U. Deoosi ts. 118 3754 o )') 0.14 *~ 2.88 Corrosion. 119 3786 0 0.11 2.81 Corrosion. It Deoosits. I 120 3818 0 0.12 2.86 Corrosion. 121 3847 0 0.09 ], 5 2.86 Corrosion. It. Deoosits. 122 3878 i 0.11 ~t: 7 2.85 Corrosion. 123 3910 i 0.11 (, 2.87 Corrosion. I 124 3942 0.12 ¿ 6 2.86 Corrosion. 125 3974 i 0.12 ¿ a 2.83 Corrosion. It. Deoosits. 126 4005 o )ß 0.12 ¡ 7 2.83 Corrosion. U. Denosi ts. 127 4037 0.07 0.09 b B 2.86 Corrosion. I 128 4069 0 0.12 ( 2.86 Corrosion. 129 4101 0.05 0.09 ( 2.86 Isolated oittim~. 130 4133 0 0.10 2.85 Corrosion. I.t Denosits. 131 4165 007 0.11 ( 2.83 Corrosion. Lt. Deposits. 132 4196 0 0.11 ( 2.86 Corrosion. I 133 4228 =æj 0.08 2.86 Corrosion. Lt. Deoosits. 134 4260 0.10 ( 2.86 Corrosion. 135 4292 o 0.10 41 6 2.85 Corrosion. It. Deoosits. 136 4324 0 0.08 5 2.83 Corrosion. It. Deoosits. I 137 4356 0 0.09 (, 2.85 Corrosion. U. Deoosi ts. 138 4388 0 0.07 2.84 Corrosion. U. Deoosi ts. 139 4420 () 07 0.08 2.83 Corrosion. Lt. Denosits. 140 4452 0 0.07 2.86 Corrosion. I 141 4483 0 0.07 H) 2.84 Corrosion. 142 4515 0 0.12 47 ( 2.84 Corrosion. It Deoosits. 143 4547 0 0.09 \7 4 2.87 Corrosion. I Body Metal Loss Body Page 3 I I I I I I I I I I I I I I I I I I I I I PDS REPORT NT TABULATION SH Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 WE 0.254 in 0.254 in 2.992 in Well: Eield: Company: Country: Survey Date: 2M-31 Kuparuk ConocoPhillips Alaska, Inc. USA April 29, 2007 Joint Jt. Depth Pen. Pen. PerL ;\¡Ielal Min. -0 Profile No. 'I i W. Comments ('% wail) (Ins) (Ins.) 0 50 100 144 4579 ( 4 2.84 Corrosion. Lt. Deoosits. 145 4611 () F; 0.07 fJ , 2.83 Corrosion. Lt. Deoosits. 146 4643 ( 0.07 7 2.82 Corrosion. U. Deoosi ts. '147 4675 ( 0.10 39 2.82 Corrosion. Lt. Deoosits. 148 4707 01 )() 0.09 33 4 2.84 Corrosion. 149 4739 ( 0.09 5 2.83 Corrosion. U. Deoosi ts. 150 4770 t 0.11 6 2.84 Corrosion. L1. Deposits. 151 4802 0.06 0.06 4 2.84 Corrosion. U. Deposi ts. 152 4834 0 0.08 ') 2.85 Corrosion. It. Deposits. 153 4866 0 010 I 2.84 Corrosion. Lt. Deposits. 154 4898 () ()6 0.10 ( 2.83 Corrosion. L1. Deoosits. 155 4930 () 0.09 , 2.83 Corrosion. Lt Deoosits. m 4962 ( 0.11 43 6 2.79 Corrosion. U. Deposi ts. 157 4993 ( 0.08 ,1 '> 2.83 Corrosion. U. Deoosits. 1 5025 0.06 0.09 \'1 5 2.86 Corrosion. Lt. Deposi ts. 159 5057 ( ~ ( 2.84 Corrosion. L1. DeDosits. 160 5089 () 2.85 Corrosion. L1. DeDosits. 161 5118 ( 2.86 Corrosion. Lt. Deoosits. 162 5150 1 0.09 ( 2.86 Isolated oitting. Lt. Deoosit. 163 5181 o. 1'1 0.08 11 2.83 Corrosion. U. Deoosits. 164 5213 0.08 32 2.86 Isolated oittim!. U. Deoosit 165 5245 0 0.09 6 2.85 Corrosion. 166 5277 0.06 0.10 t 2.81 Corrosion. I.t. Deposits. 167 5308 (L06 0.08 , 2.84 Isolated nitting. Lt. Deoosit. 168 5340 0 0.06 2.85 Corrosion. U. Denosits. 169 5372 I 0.06 2' ( 2.84 Corrosion. L1. Deposits. 170 5404 i 0.09 H 2.85 Corrosion. 171 5436 0 16 0.09 6 2.87 Corrosion. 172 5467 ( 0.07 5 2.86 Corrosion. 173 5499 0 0.08 ( 2.84 Corrosion. U. Deposits. 174 5531 0 0.08 , 2.87 Isolated nittina. It Deoosit 175 5563 0 0.12 2.87 Corrosion. 176 5594 i 0.09 , 2.84 Corrosion. It. Deoosits. 177 5626 0 ·)h 0.07 2.85 Isolated oiWmL U. Deoosit 178 5658 ( 0.09 I 2.83 Corrosion. I.t Deoosits. 179 5690 (). J9 0.10 6 2.86 Corrosion. Lt Deoosits. 180 5722 l 0.07 6 2.85 Corrosion. Lt. DeDosits. 181 5753 0.07 0.14 6 2.83 Corrosion. I.t Deposits. 182 5785 0.0.5 0.07 4 2.84 Corrosion. 183 5817 OOB 0.09 ( 2.83 Corrosion. 184 5849 0.06 2.82 Corrosion. 185 5881 ( 0.07 2 I 2.84 Corrosion. Lt Deoosits. 186 5909 ( onq 2.87 Corrosion. U. Deoosi ts. 187 5941 0.1 Jb 0.09 'j 2.86 Corrosion. 188 5973 ( 0.08 'j 6 2.83 Corrosion. Lt. Deoosits. 189 6004 0 0.11 6 ±i Corrosion. 190 6036 i 0.07 '1 Corrosion. Lt Deoosits. 191 6068 ( 0.09 33 2.86 Corrosion. Lt. Deoosits. 192 6100 ( 0.06 24 b 2.86 - n. I.t. Deoosits. 193 6131 0 )6 0.07 Jí1 .5 2.87 Corrosion. U. Deoosits. Body Metal Loss Body Page 4 I INT TABULATION SHEET I Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 WE 0.254 in 0.254 in 2.992 in Well: Fieid: Company: Country: Survey Date: 2M-31 Kuparuk ConocoPhillips Alaska, Ine. USA April 29, 2007 I I I Joint Jt Depth Pen Pen. Pen ¡vletal Min. Damage Pr ofile No. (Fl.) Body !.D. Comments (%wall) (liì (Ins.) (Ins.) 0 50 100 194 6163 0 0.07 2.85 Corrosion. It. Deoosits. 195 6195 0 0.07 ') nt:; Corrosion. It. Deoosits. ~7 OJ ;; 0.08 2.83 Corrosion. 59 o (Hi 0.07 2.85 Corrosion. Lt. Deoosits. 6291 0 0.07 2.83 Corrosion. Lt. Deoosits. 199 6323 0 0.08 2.87 Corrosion. 200 6355 0 0.07 2 2.88 Corrosion. 201 6386 0 0.09 2.82 Corrosion. Lt. Deoosi ts. 202 6418 o or, 0.07 '; 2.86 Isolated Dining. 203 6450 0.08 6 2.85 Corrosion. 204 6482 0.07 {, 2.87 Corrosion. Lt Deoosits. 205 6514 o Hi 0.09 £1 2.86 Corrosion. 6546 0.08 Corrosion. Lt. Deoosits. ~ 6577 0.07 tl±11t Corrosion. 208 6609 0 0.06 2, .85 Corrosion. Lt. DeDosits. 209 6641 005 0.07 5 2.83 Corrosion. U. DeDosi ts. 210 6673 0 0.07 2.84 Corrosion. 211 6705 ow; 0.09 2.88 Isolated nittin<>. 212 6737 0 0.09 2.87 Corrosion. U. Denosits. 213 6768 0 0.10 iI 2.86 Corrosion. Lt. Denosíts. 214 6800 0 0.13 2.83 Corrosion. U. Denosits. 215 6832 00'; 0.10 m 5 2.85 Corrosion. It. Deoosits. 216 6864 I 0.09 I 2.83 Corrosion. U. DeDosits. 217 6896 I 0.07 I 2.87 Corrosion. U. Deoosits. 218 6928 I 0.ü7 2.85 I Corrosion. 219 6960 I 0.08 I 2.85 Corrosion. Lt. Deposit.<;. 220 6992 I 0.06 2.86 Corrosion. Ll. Denosits. 221 7022 I 0.08 2.85 Corrosion. 222 7054 I 0.07 I 2.87 Corrosion. 223 7086 0 0.07 27 " 2.85 Corrosion. 224 7118 0 i 0.08 32 6 2.87 Isolated oittimL 225 7150 0 i 0.08 7 2.86 Corrosion. U. Deoosits. 226 7182 I 0.09 I 2.86 Corrosion. U. DeDosits. 227 7214 n I)(ì 0.09 2.85 Corrosion. U. Deposits. 228 7246 I 0.07 2.84 Corrosion. It. Denosits. 229 7278 Ii 0.ü7 2.84 Corrosion. U. Deoosits. 230 7310 0 D.07 2.86 Corrosion. 231 7341 ().05 0.09 34 Î3 2.87 Corrosion. 232 7373 0.06 0.08 ( 2.86 Corrosion. U. Deoosi ts. 233 7405 n 0.06 ( 2.87 Corrosion. It. Deposits. 234 7437 0 0.07 2.88 Isolated niUinQ. 235 7469 () 0 i, 0.08 2.81 Corrosion. Lt. Deoosits. 236 7501 0 0.11 2.83 Corrosion. Lt Denosits. 237 7533 () 0.08 :n 2.84 Corrosion. U. Deoosits. 238 7565 n 0.08 :n 2.85 Corrosion. )1C) 7597 n 0.06 :5 ( 2.86 Corrosion. It. Deoosits. 240 7629 0 0.06 2.86 Isolated pittim¡;. 241 7660 () 0.06 2.85 tti nQ. 242 7692 () 0.06 2.85 Corrosion. 243 7724 ( 0.08 3.. 4 2.86 Corrosion. I I I I I I I I I I I I Body Metal loss Body Page 5 I I I PDS INTTABU ON SHEET I Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 9.3 ppf L-80 FUE 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2M-31 Kuparuk ConocoPhìilips Alaska, Inc. USA April 29, 2007 I I I Joìnt Jt. Depth PelL Pen. F'eno Ivletal Min. Damage Profile No. (Ft.) (~:::(;t Body ID. Comments (%wall) (Ins.) (Ins.) 0 50 100 244 7756 0 0.06 ''; :) 2.85 Corrosion. U. Deoosits. ~87 0 0.08 ì 2.86 Corrosion. 819 0 0.07 2.87 Corrosion. Lt. Denosits. 851 0 0.06 2.87 Isolated nittin1::L 248 7880 0 0.07 2.87 Isolated oittìml. Lt. Deoosit. 249 7912 0.07 0.07 2.86 Corrosion. 250 7943 0 0.05 2.87 Isolated oittin2. 251 7975 0 0.09 2.89 Isolated oittin2. 252 8007 0 0.06 6 2.83 Corrosion. U. Deoosits. 253 8038 0 0.07 4 2.82 Corrosion. 254 8070 OY! 0.07 S 2.85 Isolated oìttìnQ. Lt. Deoosit. 255 8102 O. 0 0.05 4 2.84 Shallow corrosion. Lt. Deoosi =ili= I I 0.07 II Corrosion. Lt. Deoosìts. Hffi I I 0.06 2.85 Corrosion. Lt. Deoosits. 258 8197 0 0.07 2; , t. Deoosi ts. 259 8229 0 0.07 10 Corrosion. Lt. Deoosits. 260 8261 0 0.09 I 2.83 Corrosion. U. DeDosits. 261 8293 0 0.06 2.87 Isolated oittinQ. iii 262 8324 0 0.11 I 2.85 Corrosion. 263 8356 0 0.07 2.87 Isolated oittin2. 264 8387 0 0.05 2.83 Isolated oìttin2. 265 8419 0 0.06 23 4 2.85 Isolated oìttim;!. 266 8451 0 Ii ~~ 4 2.87 Isolated Dittínl!. 267 8482 Do09 2.87 Isolated Dittim~. 268 8514 I I 269 8546 I 0.07 I 2H ! 2.86 Corrosion. 270 8578 D 16 0.07 I 26 2.86 Corrosion. 271 8610 I 0.08 32 I 2.87 Isolated nittim2. 272 8641 I 0.06e± 2.87 Isolated nittín2. 273 8673 0 0.06 4 2.84 Isolated oittimr. Lt. DeDosit 274 8705 0 0.07 4 2.86 Corrosion. Lt. DeDosits. 275 8737 D 0.08 2.86 Corrosion. 276 8769 I)D S 0.08 , 2.86 n. 277 8801 () 0.05 2.85 Shallow oittin2. Lt. Deoosits 278 8833 0 0.07 2.87 Corrosion. Lt. Deoosits. 279 8864 0 0.05 2.85 Shallow nittin2. Lt Deoosíts 280 8896 ( 0.09 4 2.85 Corrosion. Lt. Deoosits. 281 8928 0 0.06 5 2.85 Corrosion. Lt. Deoosits. 282 8960 0 0.07 , 2.84 Corrosion. Lt. Denosìts. 283 8992 0 0.07 2.84 Corrosion. Lt. Deposits. 284 9024 0 0.10 2.87 une corrosion. 285 9055 0 0.07 2.86 Corrosion. Lt. Denosits. 286 9086 0 0.07 2.87 Corrosion. U. Deoosits. 287 9118 0 0.06 24 S 2.85 Iso!ated oittin!2. 288 9150 0 0.06 4 5 2.83 Corrosion. Lt Deoosits. 289 9182 0 0.08 ( 2.83 Corrosion. Lt. Deoosits. 290 9213 00'; 0.07 2.86 Corrosion. 291 9245 O.IH) 0.07 2.87 Corrosion. 292 9277 0 0.07 2.84 Corrosion. U. Deoosits. 293 9308 0 0.11 14 ( 2.84 Isolated oìttin2. I I I I I I I I I I I I Body Metal Loss Body Page 6 I I I PDS REPORT INTTABU ON SHEET I Pipe: Body Wall: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf L-80 WE 0.254 in 0.254 in 2.992 in Well: field: Company: Country: Survey Date: 2M-31 Kuparuk ConocoPhiilips Alaska, Inc. USA April 29, 2007 I I Joint Jt. Depth Pel Pen. Pen> ! Melal Min. Profile No. Body I.D. Comments (% (Ins) (Ins.) (Ins.) 0 50 100 294 9340 0 0.07 ( 2.88 Corrosion. 295 9372 o~ 2.87 Isolated nittina. 296 9404 0 2.85 . tin<>. ~9436 0>06 0.09 i 2.86 Corrosion. 9467 0 0.06 Isolated nit!in<>. Lt. Denosit. 299 9498 0 0.07 28 f, 2.86 Isolated nittin<>. U. Deoosit. 300 ~ 0.07 27 2.86 Isolated oiHinQ. U. Denosi t 301 9 i) 11') 0.06 =fH 2.86 Corrosion. 302 9625 ; 0.07 2.84 Corrosion. Lt. Deoosits. 303 0.05 2.87 Shallow oittimæ. 304 9656 I) 0.05 20 I 2 Isolated n¡ttina. 305 9688 0 0.07 Ll Corrosion. U. Denosits. 306 9720 0.07 0.08 32 II . n. U. Denosits. 307 9752 I 0.07 I, 2.85 Isolated niHinQ. iii 308 9783 I 0.15 {, 2.88 Corrosion. 309 9815 ;±!= { 2.86 Corrosion. Lt. Deoosits. 310 qM7 J 2.84 Corrosion. U. Denosits. 311 9879 2.87 Isolated niHina. 312 9911 o 0.06 5 2.87 Isolated nittina. Lt. Denosit 313 9942 0 0.06 24 I) 2.85 Line corrosion. Lt. Denosits. 314 9974 OW) 0.06 13 c; 2.86 Isolated nittin<>. 315 10005 I 0.05 II 2.88 Shallow nittin<>. 316 10037 I 0.10 6 2.Ii6 Corrosion. Lt. Deoosits. 317 10068 I 0.06 2.87 Isolated oittinu. 318 10 100 I 0.06 2.91 Corrosinn. 319 10131 0 0.07 2.86 Line corrosion. LL Deoosils. 320 10163 0 0.08 ( 2.85 Corrosion. Lt. Denosits. 321 10194 0 0.06 24 4 2.86 Isolated niHinQ. U. Deoosit 322 10226 0 0.06 S- 2.87 Isolated n¡ttin<>. 323 10258 0 0.07 m Isolated oitûnu. 324 10290 0 0.06 Line corrosion. 325 10322 0 0.06 I 2. Isolated oittiml. 326 10354 0 0.10 í 2.86 Line corrosion. 327 10385 0 0.06 25 4 2.89 Line corrosion. Lt. Denosits. 328 1041 7 o +%09 35 ') 2.87 Corrosion. Lt. Denosìts. 329 10449 o .05 20 ') 2.91 Isolated oitûnQ. 330 10481 o .05 ì 2.89 isolated nittinQ. 331 10513 0 0.06 4 2.88 Isolated oitûnQ. LL Deoosit. 332 10545 0 0.06 4 2.89 Isolated oittinu. 333 10577 0 0.07 5 2.89 ' Isolated oitûmz. 334 10609 0 0.06 4 2.88 nittif1l2. 335 10641 006 0.10 7 2.88 Line corrosion. 336 10672 0 0.09 (, 2.90 Corrosion. 337 10704 0.06 I 0.10 38 ".... . 12.90 Isolated oittinQ. 338 10736 0 0.07 + 4 2.88 Corrosion. 339 10767 0 0.07 2.88 Corrosion. U. Deoosìts. 340 10799 OW 0.13 2.87 Corrosion. 341 10831 I) 0.07 !B 2.87 Isolated nìttin<>. 342 10862 0 0.06 24 2.90 Corrosion. 343 10894 0 0.07 )8 ;¡ 2.87 Corrosion. I I I I I I I I I I I I I Body Meta! Loss Body Page 7 I I I PDS JOINT TABU ON SHEET I Pipe: BodyWal!: Upset Wall: Nomina! I.D.: 3.5 in 9.3 ppf L·80 WE 0.254 in 0.254 in 2. 992 in Well: Field: Company: Country: Survey Date: 2M-31 Kuparuk ConocoPhillips Alaska, Inc. USA April 29,2007 I I I Joint Jt Depth Pel Pen. Pen, I Metal Min. Damage Profile No. (Ft) I.D. Comments (%wall) (Ins) (Ins.) (Ins.) 0 50 100 344 10926 { 0.17 65 q 2.85 Corrosion. Lt. Denosits. 345 10957 0 ~ffit 'j 2,88 Isolated nittina. ~ 10988 II 0.06 'j 2.88 Isolated níttina. 11020 0,09 h 2.86 Corrosion. 348 11 052 0.07 4 2.88 ~ 349 11083 I 0.07 / 2.89· Isolated oittinº. 350 11114 0.08 2.87 Corrosion. 351 11146 0.ü7 ¡ 2.89 Isolated nittina. 352 111 77 0.09 0.10 2.88 Corrosion. 353 11210 0 0.10 m I ( 2.87 Line corrosion. 3'14 11241 0 0.08 32 {¡.. mcorrosion. U. Denosits. 355 11272 I 0.07 2( ¿f Isolated nittinº. 356 lnm I 0.08 ¡ {, 2.88 Line corrosion. 357 11336 I 0.11 2.88 line corrosion. Lt Deoosits. 358 11367 0 t6 0.12 2.86 Corrosion. 359 11399 t 0.10 2,88 Isolated nittinq. 360 11431 0.06 2.90 Isolated nittina. 361 11462 ( 0.13 2.88 Corrosion, 362 11494 0 0.06 23 4 2.90 Isolated nittin<>. Lt. Denosit 363 11526 0.07 ,1 ) 86 Corrosion. 364 11557 0.07 =t=± 2.87 Corrosion. 365 11589 o H:" 0.07 2.87 Corrosion. 366 11621 0 i9 0.12 2.86 line corrosion. Lt. Deoosits, .. 367 11652 o t') 018¢" 2.87 Line corrosion. Lt Deoosits. 368 11684 0 0.07 7 2,90 lin" corrosion. 369 11716 006 0.06 4 2.90 Corrosion. Lt. Denosits. 370 11747 0 0.05 S 2.88 Line corrosion. 371 11 779 0.10 q 2.89 Line corrosion. Lt. Denosits. 372 11811 0 )e; 0.07 2.89 Line corrosion, It Denosits. 373 11841 0.14 2.85 Corrosion. U. Denosits. 374 11875 I 0.15 2.87 Corrosion. 375 11907 0 ) qi 0.13 2.89 Corrosion. 376 11938 0 0.06 2.91 Line corrosion. 377 11970 0.06 0.09 37 7 2.91 Line corrosion. Lt Denosits. 378 12002 n Ii) gJij f4 2.87 Line corrosion. U. Denosits. 379 12034 n in II 2.88 Line corrosion. Lt. Deoosits. 380 12064 1 0.08 2.86 Line corrosion. Lt. Deoosits. 381 12096 0.08 2.87 Line corrosion. Lt Deoosits. 382 12127 OW 0.07 2.91 Line corrosion. . 383 12159 oon 0.16 ¡ 2'illine corrosion. Lt. Deoosits. 384 12191 0.07 0.10 2.86 Line corrosion. Lt. Dennsits. 385 12223 0.09 0.09 2.92 Line corrosion. U. Deoosits. 386 12255 on 0.12 47 2.89 Corrosion. 387 12287 o. 0.12 '16 4 2.87 Line corrosion. Lt Denosits. 388 12318 it 0.09 Hi 2.88 Corrosion. Lt. Denosits. 389 12349 IU 0.11 '12 2.89 Line corrosion. 390 12380 O. 0.10 '10 2.89 Line corrosion. Lt Deoosits. 391 12412 0 0.12 45 2.90 Line corrosion. 392 12444 n nil 0.14 54 'i 2.86 Inrrosion. Lt Denosits. 393 12476 niJ7 0.18 70 4 2.82 Corrosion. Lt. Denosits. I I I I I I I I I I I I Body Metal Loss Body 8 I I I I Pipe: Body Wall: Upset Wall: NominaII.D.: I I I I I I I I I I I I I I I I I Joint jt. No. 394 REPORT JOINT 3.5 in 9.3 ppf L-80 WE 0.254 in 0.254 in 2.992 in Well: Field: Company: Coun try: Survey Date: 2M-31 Kuparuk ConocoPhì!1íps Alaska, Inc. USA April 29, 2007 Line corrosion. Lt. De osits. Comments Page 9 o Profile wall) 50 100 Penetration Body Metal Loss Body .. .. .. .. .. .. .. .. .. .. .. .. .. .. S rt S ns Well: 2M-31 Survey Date: Aprit 29, 2007 Field: Kuparuk Tool Type: MFC 24 No. 40665 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin : 3..5 ins 9.3 f L-80 EUE Anal st: M. Tahtouh Cross Tool speed 51 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 93 % Tool deviation 470 for 8.4 ft depth 1 Finger 3 Penetration = 0.262 ins HOLE 0.26 ins 100% Wall Penetration HIGH SIDE = UP Cross Sections page 1 .. .. .. -l .. .. .. .. .. Well: Field: Company: Country: Tubin : .. .. .. .. .. .. .. .. .. .. s s 2M-31 KuparuK ConocoPhillips AlasKa, Inc. USA 3.5 ins 9.3 f l-80 EUE Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st April 29, 2007 MFC 24 No. 40665 1.69 24 M. Tahtouh Tool = 52 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 93 % Tool deviation = 33 0 Joint 52 depth 1 6 ft Finger 3 Penetration = 0.21 ins Isolated Pitting 0.21 ins 83% Wall Penetration HIGH SIDE = UP Cross Sections page 3 .. s .. .. .. .. .. .. .. .. .. Well: Field: Company: Country: Tubin : .. .. .. .. .. .. .. .. .. s rt C 55 2M-31 Kuparuk ConocoPhiliips Alaska, Ine. USA 3.5 ins 9.3 f l-80 WE April 29, 2007 MFC 24 No, 40665 1.69 24 M, Tahtouh for Joint Tool speed = 50 Nominal 10 = 2.992 Nominal 00 3.500 Remaining wall area = 94 % Tool deviation = 48 0 SUlvey Date: Tool Type: Tool Size: No, of Fingers: Anal st: ft Finger 3 Penetration = 0.21 ins Corrosion 0,21 ins = 83% Wall Penetration HIGH SIDE = UP Cross Sections page 2 .. n5 .. .. I I I NIP (490-491, 00:3.500) TUBING (0-12822, OD:3.500, ID:2.992) I I GasUft , n<:IreIlDummy Valve 1 (2104-2105, OD:5.968) I I I SLEEVE 1274&12747, 00:3.500) PROD. CASING (0-13151. OD:7.000, wt:26.00) I I PKR 12794-12795, 00:6.151) I I NIP 12811-12812, 00:3.500) I I I TTL 12822-12823, 00:3.500) I Perf 12895-12921) I Perf 12921-12947) I I KRU 2M-31 Rev Reason: Pull !NJ VALVE Last U ate: 8/29/2005 10 2.812 2.812 3.000 2.750 2.992 2.992 . . SARAH PALIN, GOVERNOR AI,ASKA. OIL AND GAS CONSERVATION COMMISSION 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jill Long Wells Group Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2M-31 Sundry Number: 307-080 $~E.D MAR 0 {1 2007 ~; 01 ~ \C\ Dear Ms. Long: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ~ day of March, 2007 Encl. . Conoc~hillips Alaska . RECEIVED MAR 0 2 Z007 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 :Alaska Oil & Gas Cons. Commission Anchorage March 1, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk We1l2M-31 (PTD# 196-077). Injecting well 2M-31 was drilled in May 1996 and completed in August 1996. The well operated on injection until March 2005 when it failed an MITIA.' In April 2005 the well passed a Combo MIT and subsequently the well was shut-in due to apparent tubing leaks. Further tubing diagnostics identified tubing leaks between 1,845' and 1,897' MD, below the mandrel at 2,104' MD, and around 2,301' MD. A caliper log survey run from 3,000' to surface on October 9,2005, confirmed the poor condition of the tubing throughout. The well was then put on the rig workover list for replacement of the 3-1/2" injection tubing. The purpose of the proposed workover will be to pull the existing tubing string and replace it with . a new one. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 265-1102. Sincerely, ~ fðY: èf)~ Jill W. Long Wells Engineer CPAI Drilling and Wells (t>1 ~ 3/517. RECEIVED .- 3/)' VV..} STATE OF ALASKA fr-oa,¡ MAR 0 2 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION 5" . APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas Cons. Commission 20 MC 25.280 Anchorage 1. Type of Request: Abandon 0 Alter casing 0 Change approved program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: o D· 0' Operational Shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic 0 Suspend Repair well Pull Tubing CONDUCTOR SUR. CASING PROD. CASING 80' 3994' 13110' 16" 121' 4035' 13151' 9-518" 7" Perforation Depth MD (ft): 12895'-12947' Packers and SSSV Type: pkr= BAKER 'SAB-3' Cameo 'DS' nipple @ 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 15. Estimated Date for Commencing Operat 17. Verbal Approval: Commission Representative: Perforation Depth TVD (ft): 6107'-6142' Perforate 0 Waiver 0 Other 0 Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 Exploratory 0 Service 0 5. Permit to Drill Number: 196-077 6. API Number: 50-103-20241-00 . 8. Well Name and Number: TVD 121' 2826' 6281' Tubing Size: 3-1/2" . Burst Collapse P. O. Box 100360, Anchorage, Alaska 99510 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Requires? Yes 0 No 0 2M-31 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25585: ALK 2671 Rig RKB 41', Pad 106' Kuparuk River Field 1 Kuparuk Oil Pool .. 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13161' 6288' I 12946' 6141' Casing Length Size MD Tubing Grade: L-80 Tubing MD (ft): 12822' Packers and SSSV MD (ft) pkr= 12794' 490' 14. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0" GINJ 0 April 1 , 2007 Date: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Jill Lonq Signature au ~lc:íi_ U 0 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test ~ Mechanical Integrity Test ~ Contact: Title: Phone 265-1102 Location Clearance 0 Service 0 . Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Jill Long @ 265-1102 Wells Group Engineer Date 03/01107 sundry2õ~:.. rfP{) Other: ,)$00 ~c;l ""\"\~-.),, ~~ ~'")~. \)\.\'u""c~t: o\>e.¿\C","';.,\", CJ,~LC\~ ~I A \'0 ð-- ~ \ . ~ RBDMS BFl MAR (; ., 2007 ::~=:~FO~ Re,"'md ~~(j;lfJíICOMMISSIONER Form 10-403 Revised 06/2006 0 R 6t'~ J ~ APPROVED BY THE COMMISSION Date:~-5~:¡ ? Submit in Duplicate þ4tP ~~ -S.Z' Ó? . Kuparuk 2M-31 General Workover Procedure . Pre-Ria Work 1. Test packoffs and LOS 2. Drift tubing as far as possible 3. Obtain an updated SBHP reading as deep as possible 4. Set blanking plug in nipple at 12,811' MO 5. Open the sliding sleeve at 12,746' MO 6. Perform positive and negative pressure test on the plug 7. Perform a string shot and chemical cut the tubing at 12,770' MO 8. Load the well with 9.6 ppg brine thru the sliding sleeve 9. Freeze protect if necessary 10. Set 3" FMC ISA BPV 11. Prepare location for arrival of W orkover Rig General Workover Procedure 1. Verify Sundry approval acquired 2. MIRU Nordic 3 3. NO tree. MU blanking plug 4. NU and pressure test BOPE. 5. The last SBHP measurement was 4,009 psi on January 28,2002, at 12,921' MO (6,124' TVO) which is mid-perf depth. Prior to rig arrival, a plug will be set in the liner below the seal assembly and the well loaded with 9.6 ppg brine. Because of this, kill weight fluid should not be needed; however, in the event that the plug fails, the estimated brine weight needed at mid-perf would be 12.6 ppg. Assuming a 125 psi overbalance, the brine weight would need to be 13.0 ppg. The calculated maximum possible surface pressure assuming a gradient of 0.1 psi/ft is 3,397 psi. The current SIWHP is 1,700 psi. ) 6. Pull tubing and run new tubing/new completion 7. Prior to setting new completion, load IA with corrosion inhibited seawater 8. Set BPV and NO BOPE 9. NU tree, pull BPV, set tree test plug, and test tree 10. Remove tree test plug and freeze protect well 11. Set BPV and ROMO workover rig Post-Ria Work 1. Pull BPV 2. Pull ball and rod 3. Pull SOV and run OV 4. Pull RHC plug body 5. Pull CA-2 blanking plug from nipple 6. Return to injection . Conoc<>Phillips Well: 2M-31 Field: Kuparuk . API: 50-103-20241 PTD: 96-077 2007 RWO PROPOSED COMPLETION WELLHEAD Lift threads: 3%" 8rd EUE BPV: 3" FMC ISA Model: FMC Gen 4A CONDUCTOR 16",62.58 ppf, H-40, welded SURFACE CASING 9%", 40 ppf, L-80, BTC-MOO PRODUCTION CASING 7", 26 ppf, L-80, BTC-MOO TUBING 3%", 9.3 ppf, L-80, 8rd-MOO PERFS C-4, C-3 12,895'-12,947' MO 6,107'-6,142' TVO 09/09/1996 A B c E F G NEW COMPLETION A: Nipple: 2.875" OS Nipple @ 490' TVD= 490' MD B: Gas Lift Mandrels No. MO TVO TYPE 1 2,500 3,078 1" KBMG- SOV c: Sliding Sleeve: 3%" with 2.813" OS profile- at least 1 full joint above seal assembly D: PBR Seal Assembly E: Baker FHL Packer- at least 1 full joint above the nipple F: Nipple: 2.813" X Nipple- at least 1 full joint above the overshot G: Overshot: will swallow chemical cut @ - 12,770' MO Last Tag: 04/16/05 Tag Depth: 12,946' RKB Fill: l' fill above btm perf TD: 13,161' RKB Last Updated: 15-Feb-07 Updated by: JWL ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reggy-) P.I. supervisorl,ê(7 c¡1'1°'5' DATE: Wednesday, August 17,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-31 KUPARUK RIV UNIT 2M-31 ./ \ ~.. ./0\ ,Ø\.VJ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.l. Suprv ,~r:£- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2M-31 Insp Num: mitCS050812203813 Rellnsp Num: API Well Number: 50~103-20241-00-00 Permit Number: 196-077-0 Inspector Name: Chuck Scheve Inspection Date: 8112/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. _~{~II:~~7~~::Jf~T i ; :!I-~;> r~;i~::- T~2::; -rl:::---fl:5~-l-~-i _ __ -- -~ _= -.!!tt~rYªL~~TS!_.__.~~..~n___. .__ :rUbl"-_~.L~~~_o_---L_.q_1800 ___ _L2.~~0_L_._~_ __...L.__-.L______ Notes: Well was not on injection at this time. Pretest and test pressures indicate possible Tubing x IA communication .\1Jtc..( -PWV'¡ e-1e.cJ ~ CPA-I- -êt.tJu:L-h"1 h,~' re p Cll j- S 0( \ 3/0') ~ Vv~¡{ S-L '5,1\((:. /\-{{.\¡--cA le.1tY5· I J !(e'fl 1(1"310s ,; ,->-/ h 1t'..~G~·' . \'V-F' (.1 -t < [ìO' ~;'~l.\~I;~iJ ~!t:J.. ~) t ¡J ¡.;: J 2. -5 Wednesday, August 17,2005 Page 1 of 1 MIT KRU 2M-31 03-27-05.xls ) Subject: MIT KRU 2M-31 03-27-05.xls From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Tue, 29 Mar 2005 20:22:42 -0900 To;::' Thomas Maunder <toID_maunder@admin.state.ak.us> CC: jim_regg@adinin.state.ak.us ) q,~, -f)",;·,.fiJ;,:,·lt7' ': i, '/,,' ",:.~! '. ...' ri,. - ....'" Tom, Attached is a failed MIT test form for well 2M-31 (PTD 1960770). The test was conducted on 03-27-05. We were unable to reach a stabilized pressure on the IA using a triplex pump, indicating a failure. The well will remain shut-in until we can do further diagnostics. Please call with any questions. «MIT KRU 2M-31 03-27-05.xls» Content-Description: MIT KRU 2M-31 03-27-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 s«·...å~\.¡k\.ijE~""; ð DR- ¡; " ?on'i'" " "",Ir-t,1' 1 ,¡ '\1 ~,) ,-¡. ¡ ..:.. ";,~ L :J:J 1 of 1 3/30/2005 11:01 AM ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/2M 03/27/05 'I,"", c011 '~VJ Packer Depth Pretest Initial 15 Min. 30 Min. Well 2M-31 Type Inj. S TVD 6,040' Tubing 1,700 1,700 Interval P.T.D. 1960770 Type test P Test psi 2500 Casing 1,600 1,850 P/F F Notes: We were unable to reach a stabilized pressure on the IA using a triplex pump, indicating a failure. The well will remain shut-in until we can do further diagnostics. Well Type Inj. P.T.D. Type test Notes: TVD Test psi Tubing Casing Interval P/F Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing 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 T = Test during Workover 0= Other (describe in notes) SCi·%~~~~El' !-\ ,+ ~ ~ ' , MIT Report Form Revised: 06/19/02 2005-0327 _MIT _KRU_2M-31.xls ON OR BEFORE PERMIT DATA 96-077 CDN 96-077 CDR 96-077 7357 96-077 CBT AOGCC Individual Well Geological Materials Inventory T DATA PLUS '~9400-13100 ~'4000-3100 ~'~CDR/CDN - MWD ~11241-13018 Page: 1 Date: 08/12/98 RUN RECVD FINAL 08/02/96 FINAL 08/02/96 1,2 08/02/96 1 09/26/96 T 10-407 LR~COMPLETION DATE ~// DAILY WELL OPS R ~//30/c~/ TO q~/q /g0/ Are dry ditch samples re~ifed? ~es - ~ ~ ~d received? Was the well cored? yes ~.Analysis & description received? yes-~ Are well tests required? yes ~Received? Well is in compliance ~ Initial COMMENTS ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 25, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2M-31 (Permit No. 96-077) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2M-31. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development ~.la.ok3 i_: :. WSI/skad STATE OF ALASKA ALASrkA OIL AND GAS CONSERVATION U,..;MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. ~tat~ of ~ell ....... Classification oi Service Well '" [] Oil [] Gas [] Suspended [] Abandoned [] Service Water & Gas Injector '2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-077 3. Address 8. APl Number P.O. Box 100360, Anchorage, AK 99510-0360 ..... , 50-103-20241 4. Locatid~ ofwell at'~urfac'e " ~ !~!?¢,!,.';i i-'?'i.-:,-~~ -; I~,,l~~__.__ ! ~~.~, 9. Unit or Lease Name 114' FSL, 316' FWL, Sec. 27, T11 N, R8E, UM ~ ..... ; - Kuparuk River Unit At top of productive interval ¢/¢2~.. . ~ 10. Well Number 1791'FSL, 1138'FWL, Soc. S2, TllN, R8E, UM i ~;___~ri.,.I 2M-31 At total depth ._ .~,7~-'%~-~'.-~;.,¢, ~11. Field and Pool 1724' FSL, 955' FWL, Sec. 32, T11 N, R8E, UM ........ Kuparuk River 'iL. El'evation in'¥eet (i~dic'ate K'I~i D'~", etc.) 16. L~aSe DeSign-etlon- anci-se~i~l N0: Rig RKB 41', Pad 106' I ADL 25585 ALK 2671 12. Date Spudded i13. Date T.D.' Reached 114. Date Comp., Susp., or Aband.115. W&ter depth, if offshore 116. No. of Completions 4/30/96 i 5/8/96 I 9/9/96 I N/A MSLI One 17. Total Depth (MD+T~/~)I1'~. Plug Back Depth (MD+TVD)I19. Directional SUrveyi20.' Del~h where SSSV Set~21. Thickness o~ Permaf'i~sl 13161 6288 FT~ 13063 6221 FT~ I~Yes [ZINc N/A MDl 1380' (Approx) 22. Type Electric or Other Logs Run GR/CDR/CDN-RT, GR/CCL/CBT 23. CASING, LINER AND CEMENTING RECORD ..... CASING SETTING DEPTH i HoEE SIZE _V~__. PER_FT. , GRADE TOP BO-FrOM I SIZE CEMENTING RECORD AMOUNT PULLED 16" 151.5# X-65 SURF. 121' I 24" 380sx AS I 9.~25" 40# L-80 SURF. 40-35' 12.25" 730 sx AS 111, 740 sx Class G 7" -26# ........ l-:-80 ........ ~URF~- --i-3-i ~i-' ...... ~:-5~' .... 2~0-sx-i21as-S--G _. . L__ 24. Perforations open to ProdUcti'~n (M'D+'I-VD of Top'~and Bottom 125. ' ..... TUBING RECO~D and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4 spf 2 spf .................. -3.~~' ......................... -i-28-22' - MD TVD MD TVD ......................................................................................................... 12921 '-12947' 6124'-6142' 12895'-12921' 6107'-6124' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF: MATERIAL USE[:) 27. PRODUCTION TEST Date First ProdUctiOn iMeth0cl of Operation (Fl~'~ving, gas lift, etc.) ...... ~ WAG I Date of Test iHours Tested I PRODUCtiON FOR OIL-BEE I GAs-MCF 'W'A-:r-~-R---I~'~-~ ......... i--~;-~-~)~--~iZ-E- ...... j-~-~:-Oi[ -R-~,~i~)- ..................... i TEST PERIOD' ROW-TubingiOa~ing--F'~b~-U~-A-LCD-~,-¢~---; ..... -OE:-B-i~t~ ................ G-~,~:-M-~i~ ........... W-~;~:E~---BBL ....... OiL ~Av~-~Y-AIF1 (CORR) Press. i 24-Hour RATE 28. CoRE DA:fA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL £- i Form 10-407 Rev. 07-01-80 '"'.:h:::!::':!::Submit In Duplicate 29. Geologic Mar 30. Formation Tests Measure~J' True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. -['~) K~'l~ar~j~ C .... 12895' ' 6 i 07' ' ............ Bottom Kuparuk C 12922' 6125' Top Kuparuk A 12922' 6125' Bottom Kuparuk A 13078' 6231' Annular pump volumes categories: 1 ) 24988 2) 100 3) 0 Total this period: 25088 Total to Date: 25088 Freeze protected annulus with diesel 31. List of Attachments Directional Survey, Daily Drilling History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 'b~ J~-_ ~ ,,,,,,,,_,...___ .__ .......... '__,~,,~ .-.-. ~ Title ORf. I.~.~..~G. ~.NC,,,,I:N~...~, Date ~O ~ 7. ~' Prepared By Name/Number: 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 1: 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, (;as Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 9/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:2M-31 RIG:PARKER 245 WELL ID: AK8533 AFC: AK8533 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:04/30/96 START COMP- BLOCK: FINAL: WI: 0% SECURITY:0 AFC EST/UL-$ 1420M/ 1860M API NUMBER: 50-103-20241-00 04/30/96 ( 1) TD: 904' (904) SUPV:GWR DAILY: 05/01/96 ( 2) TD: 4045' (3141) SUPV:GWR DAILY: 05/02/96 (3) TD. 4045' ( 0) SUPV' GWR DAILY' 05/03/96 ( 4) TD: 5929' (1884) S UP V: GWR DAILY: 05/04/96 (5) TD: 9694' (3765) SUPV:GWR DAILY: 05/05/96 ( 6) TD:11686' (1992) SUPV:GWR DAILY: 05/06/96 (7) TD:12236' (550) SUPV:GWR DAILY: 05/07/96 ( 8} TD:13125' (889) SUPV:RLM DAILY: MW: 10.0 PV/YP: 21/24 APIWL: 8.2 DRILLING AT 1650' Move rig to 2M-31. Accept rig @ 1400 hrs. 4/30/96. Function test diverter. Drill from 121' to 904' $56,111 CUM' $56,111 ETD' ~0 EFC: $1,476,111 MW' 10.0 RUNNING SURFACE CASING Drill from 904' to 4045' $83,539 CUM' $139,650 ETD' PV/YP: 17/19 APIWL: 7.6 $0 EFC: $1,559, 650 MW: 8.4 PV/YP: 7/13 APIWL: 20.0 P/U D.?. Held safety meeting. Run 9-5/8" casing to 4035' Cemented. Test BOPE. Ail components to 300/3000 psi. $242,526 CUM: $382,176 ETD: $0 EFC: $1,802,176 MW: 8.8 PV/YP: 11/16 APIWL: 10.5 DRILLING @ 7300' Test casing to 2000 psi. for 30 minutes. Drill cement, float collar, shoe jts., float shoe and 10' of new hole to 4055'. Perform FIT to 12.8 ppg EMW. Drill 4055' to 5929' $74,105 CUM: $456,281 ETD: $0 EFC: $1,876,281 MW' 9.3 RIH AFTER SHORT TRIP Drill from 5929' to 9500' $79, 648 CUM: $535,929 ETD' PV/YP' 14/19 AP IWL' 6.8 $0 EFC: $1,955,929 MW: 9.3 PV/YP' 14/22 APIWL: 6.4 DRILLING Drill from 9694' D.P. stuck @ 9690' while picking up after turbine stall. Jarred free. Drill from 9694' to 11686' $84,993 CUM' $620,922 ETD' $0 EFC' $2,040,622 MW: 9.3 PV/YP: 14/22 APIWL' 5.2 DRILLING Drill from 11686' to 12236'. Pump hi-vis pill. POOH to 11771' Pump dry job. TIH w/MWD/LWD. $92,244 CUM: $713,166 ETD: $0 EFC' $2,133,166 MW' 10.4 PV/YP: 15/20 APIWL' 4.8 WASHING TO BOTTOM Drill from 12236' to 13125'. Wipe hole to 8000' Work and wash tight hole at 11958', 11800', 9700' RIH wash and ream through intermittent tight spots. $97,985 CUM: $811,151 ETD: $0 EFC: $2,231,151 Date: 9/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 05/08/96 ( 9) TD:13161' ( 36) SUPV: RLM DAILY: 05/09/96 (10) TD:13161' ( 0} SUPV:RLM DAILY: 05/10/96 (11) TD:13161' ( 0) SUPV:RLM DAILY: MW: 10.5 PV/YP: 18/22 APIWL: 4.4 RUNNING 7" CASING Wash and ream intermittent tight hole to 9700' RIH to 11000' Wash and ream tight hole to bottom. Had 31' fill on bottom. Cleaned out. Drill from 13125' to 13144. Work through tight hole from 13144' to 13100' Ream tight hole. drill from 13144 to 13161' Circulate clean and condition for 7" casing. $77,300 CUM: $888,451 ETD: $0 EFC: $2,308,451 MW: 10.5 PV/¥P: 16/20 APIWL: 4.8 FREEZE PROTECT ANNULUS Run 7" casing to 4923', hit bridge. Worked pipe to regain returns, unsuccessful. Run casing to 7630' Hit bridge. Hole packed off. Work pipe and regain circulation. Pump through bridge. Run casing to 13151' Cement casing. CIP at 2300 hrs. 5/9/96. While pumping spacer full returns were achieved and the well started giving back mud that was pumped away. Well giving back mud. Observe well and wait for flow to subside. $167,499 CUM: $1,055,950 ETD: $0 EFC: $2,475,950 MW: 10.5 PV/YP: 16/20 APIWL: 4.8 RIG RELEASED Set 7" casing. Freeze protect annulus. Release rig @ 1200 hrs. 5/10/96. $35,136 CUM: $1,091,086 ETD: $0 EFC: $2,511,086 Date' 9/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 3 REMEDIAL AND COMPLETION OPERATIONS WELL'2M-31 RIG:PARKER 245 WELL ID: AK8533 AFC: AK8533 TYPE: -- STATE:ALASKA AREA/CNTY' NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:04/30/96 START COMP: BLOCK: FINAL: WI: 0% SECURITY:0 AFC EST/UL:$ 1420M/ 1860M API NUMBER: 50-103-20241-00 08/02/96 (12) TD:13161' PB:13063' SUPV:MEE DAILY: RIH W/COMP. ASSY MW: 8.5 SW NU BOPE. Pressure test casing to 3500 psi f/30 minutes. RIH w/3.5" completion assy. $45, 532 CUM' $1,182,150 ETD' $0 EFC' $2,602,150 08/03/96 (13) TD:13161' PB:16231' SUPV:JT DAILY: RIG RELEASED MW: 0.0 Continue to RIH with 3.5" tubing and completion assembly to 12821' Drop ball, set packer, test tubing for 30 minutes with 2500 psi. Pressure test casing for 15 minutes w/2500 psi. Freeze protect annulus with diesel. ND BOPE. NU tree and test to 500/5000 psi. Rig released @ 2100 hats. 8/3/96. $159,190 CUM: $1,500,530 ETD: $0 EFC: $2,920,530 End of WellSummary for Well:AK8533 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT A K1(2M-31(W4-6)) Wl:J I. JOB SCOPE JOB NUMBER 2M-31 PERFORATE, PERF SUPPORT 0905962300.7 UNfI' NUMBER DATE 09/09/96 DAY 2 DAILY DAILYWORK PERFORATE, PERF SUPPORT OPERATION COMPLETE [ SUCCESSFUL YES I YES Initial Tbg Press ] Final Tbg Press ] Initial Inner Ann 600 PSI 1500 PSI 600 PSI SUMMARY KEY PERSON SWS-JOHNSON SUPERVISOR GOLDEN Final Inner Ann I I 1500 PSI Initial Outer Ann [ I 0 PSI Final Outer Ann 0 PSI PERFORATED A SAND F/12921'- 12947' (4 SPF, 180 DEG PHASING, 90 DEG CW, DP). PERFORATED C SAND F! 12895'-12921' (2 SPF, O I DEG PHASING, 0 DEG CW, DP). I TIME LOG ENTRY 20:00 MIRU SWS E-LINE & HOT OIL DHP. TGSM-PERFORATING.HAD DIFFICULTY W/GUN CONNECIIONS 00:30 PT LUBRICATOR 3500 PSI.RIH W/HEAD/CCL/MPD/26' 2-1/2" HOLLOW CARRIER (4 SPF, 180 DEG PHASING, 90 DEG CW F/LOW SIDE, DEEP PENETRATING CHARGES)SAT DOWN @ 3000'. BEGAN PUMPING GUNS DOV(NHOLE @ 1.0 BPM.TIED INTO CBL DATED 7/17/96.PERFORATED 12921'-12947'WHP (BEFORE) = 530 PSI, WHP (AFTER) = 500 PSI. POOH. ASF.. 04:00 RIH W/HEAD/CCL/MPD/26' 2-1/2" HOLLOW CARRIER (2 SPF, 0 DEG PHASING, 0 DEG CW F/LOW SIDE, DEEP PENErI'RATING CHARGES)BEGAN PUMPING GUN DOWNHOLE AT 1.0 BPM - SHUT DOWN FOR MECHANICAL FAILURE OF DHP.WAITING ON DHP. 06:00 NEW PUMP ON SITE. CONTINUE RIH W/PUMPING AT 1.0 BPM.SAT DOWN AT 3400'. INCREASED PUMP RATE TO 1.5 BPM.SAT DOWN AT 6000'. HAD TO INCREASE PUMP RATE TO 2.5 BPM TO GET MOVING DOWNHOLE.SAT DOWN AT 10400'. OUT OF FLUIDS WA1TING ON ADDITIONAL DIESEL TRANSPORT. 10:10 NEW DIESEL TRANSPORT ARRIVED, START PUMPING @ 3.0 BPM AND CONTINUE RIH. 10:50 LOG TEG JEWELRY, ADJUST DEPTH. RIH TO 12,960' 10:55 TIE IN AND PERFORATE INTERVAL 12,895' TO 12,921'. POH. 11:45 OOH, ALL SHOTS FIRED. RDMO SWS AND LRS. 12: 3 0 WELL SECURE AND EVERYBODY OFF IdDCATION. O, 0::; O: C:O 0:25 .3051~ O0 i~ :6. 2,0(:: 245 <. O0 3:00 .- . '? 11 ? '( ':! ::~':-'. ::_: ". :14 i O, ,{,5 ~ A. - 3~ 37: :3: 5: 5: :.:':5::1:, ,':, i rT C? · '._Il!f{. !,," I F:.F': :: · :,"j :, '),.- t2 :',:;, 7 '/.: .. t ? 105:.4 9':, ! 94, 9,'::: ~ >% :,,vv :?.45.:33 -4 :'""' I(:,, ,':,7 :07 ": = 7ff - '. , ~,. ~ ,_.~ ..... ".,_ ~: T.~j- s !' i :::A:..,::v: i0©:77 17~57 252:16 1449,74 .'-:: 80, :i:i: !90.45 25:3,2:! ~'<':-::s'., 18!83:8! <,o ..-,':' 252:,.:¥0 ~ -:' £ ,:- C. ,D i62,! .-.65 20:,i ~42 25.~ :. 1. o-:.:o..,:>r, -64 ...... :706,32 :.?44,97 28,? 251,89 ,-,,'.. s,::'::. ~0:.7 ~.7.::,5:91 2?2'.-77 ..... '" '.:.'::;, A ': :.~4~$4 345,45 ?2:0 i737-..4'9 401<.5Z .3':T,' .. '20 29:3,.. O;? -'t27,ii ,--:,,4 207,5,2-7 52:?,'.:':'-.5 ?-:L',/: ~ £1:3"7' ,,-"_ s 2',: i -%- z r: .--: p.: ?~ ':/4,2 2i3'?:-22 ='-'"' 74 -'-"'' ...... :': -:92:27 .'7-' ."-~ .' .... 0 :o.,:- ::::'27.:50 "37-",, 2:." ~ 5','-'3-'5, ?i -.>,:c..:03 - !01:? ~":/:>, <373,53 -: i02,1'2 - ~44'¢: '" '< :.3? ,5,:. 'i, -""~ .' ::j '::.:: 0 .: S 4 ,~_-'*.> ,:- / :' ...... ' £,300 * C.,:' ~ .L::'~ ,T: 7 * C, _',' ,;': ,:.:, ,3:., ,5'R () .", ' .. .-' L%./ .'; ..::i 0,.'.'-.:[ 27':~: 7:72,,-'.:, 3::'2+6 373+ 37t:~ ...',,-.: ....... .... ~., $? :,.:,:: 2:';i ,. !. 2 -.,. c,.,..:'.., ~,53 <?&-:'"!3,(:'3 ~/O'q~ ¢~'4,~,~25 ,:,,:, ~ : ,:: :" '"'-' ,_: .:. :. ~ .-' o":' : ' ..... ~43:?:-0:~ --4,':'10:0::', 3)'4/, 23 4446,Y,5 q/?5.,-,'m,, 5-' i;~ 7? 13 [- ¢,. Q'v ,~/. ..;'r-,d/ , l 'L' ,5 !.83,, ~2 '.-"'.-qt' ."-(::(X '? O. :5'-._., ~ ..).7 0,.7? $700,27 373..-4 47:'.';5+75 ,.v c~ t 48"'.'..'.(~ 375,..15 5037~,% ....... ,_. ........ ., -.co..-- o.,,:, -',f, a27~ !. 7571 :. ,:-"~b ,- ....................... ¢, ,~: ,-,,-, ,3/~. E.L Z-:!,b.:,b3- ".~3f. Jd-'.'/;3 -: :_-5_.- .-- .','o 7??,30 68:67 248+40 - ?,-_,.3&, 42 --74,57,7,1 7227~?S , )1'...r, £_ ..'-2 :- P _;' ,-:, ~o; ~.,; 70:?2 247:.S2 8445, ;.2 ,' u; y::. 2'7--' t, :4C, ,.,: ;,; ~_.,~.~?0:? 9.,-r..'. a:; -- 2'.'.-.'34.,.. 48 ....... 2/" 8?75..40 ""' "-"' " ....... '" '' ., '..: .-. .:, ,~ ?';-227 ~. 5,:', 69+63 2&5~28 -3137~?'L -8,5,,?9:77 344,!,, i.'7 ¢./1 "...' ~ ?i.'}-'5 ~ 4 ?27-:?: 57 ?50: 2f;(':'~ 'Z:}O ,. ;i 2!!:.{:-, 2? 250:~.2 '7i .:. 03 O, 5j.: i1854,20 1.2320~78 27?+0 5578~0,3 5702,36 5740~35 748~,64 ,57+,., ~':' 245,22 9,659~53 ..... " o.,~:. 244.,8? ,.~78 7874~!2 84 13 24.4,74 O~rz; Z -':.: 9','"": %"/,. ?743, :'_:% 70,;4 ~ "'"'"~' ~ 5:1 7 '/[.;. 5'.. :[2592,35 t2777,4[ 5824,54 5~70,75 5?2,3? ~0214~27 ~r:...? 24?..,4:[ -':~:453-:~,5-'73;:'©~t2 ,-,,-,, ................ -, .-,-, · ...., ~ ...; 7 Y~:C~ ~ ~%; l'izi'.,' ~/'/' :,:,~.~ 248,09 .-:<4x:q~/a -'}'4.:i:~'.~ ~8 :t(:0,5'.':~27 ~_.~':':.,, 7'.5 55,86 243~27 .-3511.~.i. 3 ,",¢~ ....... ",.-,~ .',, .:u~o 7~ '-Y >t : : ;.=;, :.::...i.{,,~;.'t~ ,~q. '::h ?4A~.4P --3537 ,,.:,"":' '":*'~ '"'" :[02~. 4, ,52 '2.'?~'~ 73 ~?'~77 249.-,'i'! '~='= '"'" -'7647-52 , ngs7 ~o -'- -.: ........ ',, 249,/'X i!, 72 '2, 13078 :-7(;' 27,6 _::2,': $ i ~00 ....,,°':'..., ,:,.__.. 249,57 -3587.-. 8S ~ r,4~.,~ .';:c, 4;: ~ 0'.'_.17149; ",.' O-L, 7 ~./O ~ {':,5'..09. :~' i 4,5.~80 250 ~ 2'.:,' -3..-5,43.03 - 7858-:.7 :... t0470,14 .t'._.'..:.iU~.~i O .!';; (:,,',2:-5 ARCO Alaska, Inc. Date' September 12, 1996 Transmittal #: 9741 RETURN TO: ARCO Alaska, Inc. Attn.: Bethany Lilly Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. 2M-31 Cement Bond Log Receipt ~~~_~ Acknowledge DISTRIBUTION: 07-17-96 Date' Sharon AIIsup-Drake DS Development ATOo1205 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Please acknowledge 1 1241-13018 Chapman/Zuspan NSK Wells Group NSK69 RECEIVED SEP 2 6 ~996 ~ Oil & 6as Orms. O~mission GeoQuest 500 YV. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10313 Company: 7/31/96 Alaska Oil & Gas Cons Comm Attn: Howard Okland 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape .2M-31 "7% ~"7 96171 CDR/CDN 960508 1 ~2M-31 CDR 960508 1 1 · , 2M-31 CDN 960508 1 1 .... ,,, , -,. ~-o~7 SIGNED. Please sign and return one copy of this transmittal to Sherrie 'at the above address. Thank you. RECEIVED DA~-~jc ~, 2:1996 Alaska Oil& Gas Cons. ~ Anchorage May. !4. 1996 9'llAM No. 9668 ?. ]fi AP, CO' '~St[A iNC .~, CASIN(~ AND LEAK-OFF FRACTURE_TE$_T__S Well Name: KRU 2M-31 Date: S/3/t996 Supervisor: G.R, Whltlock Casing Size and Description: g 5/8, 40~, L-80, BTC Casing Setting Dspth: 4035' TMD 2825' TVD Mud Weight: 8.4 ppg EMW = Leak-off Pressure (PLO) 0,052 X TVD EMW = 650 psi I (0.052 x 2,825 ft) + 8.4 ppg EMW= 12,8 ppg + MW RECEIVED MAY 1 4 1996 1900 1800 1700 1800 1500 1400 1300 1200 1100 100o 900 8O0 7O0 600 4o0 3~o lOO 0 - - # ~ -~ AlaSI<~,0Ji & 6as Cons Post-it' F~ Note 7671 oa,e; ~'/j~ i~?' I - ' ~ Anch0rag Commission STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION 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 X 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 114' FSL, 317' FWL, Sec. 27, T11N, R8E, UM At top of productive interval 1854' FSL, 1049' FWL, Sec. 32, T11N, R8E, UM At effective depth At total depth 1756' FSL, 779' FWL, Sec. 32, T11N, R8E, UM 6. Datum elevation (DF or KB) Rig RKB 41' Pad level 106 feet 7. Unit or Properly name Kuparuk River Unit 8. Well number 2M-31 9. Permit number 96-077 10. APl number 5o-1 03-20241 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 1 31 61 ' feet 6288' feet 1 31 61 ' feet 6 2 8 8' feet Plugs None Junk None ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 3914' measured None true vertical Size 16" 9-5/8" Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Cemented Measured depth True vertical depth 250 Sx AS I 121 ' 121 ' 730 sxAS III & 4035' 2825' 740 sx Class G RECEIVED M~,¥ ~ ~ 199G 0il & Gas Cons. Commission A.chorage 13. Attachments Description summary of proposal ~ Detailed operation program _ BOP sketch _ 14. Estimated date for commencing operation 5/20/96 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas _ Suspended Service 17. 4~hereby certify that the foregoing is true and correct to the best of my knowledge. Signed..~~ ~.~~'~ ~~~' Title Drill Site Dev. Supv. t l .OR COMMISSION USE ONLY Conditions of approval: Notlfy Commission so representative may witness IApproval Plug integrity_ Mechanical Integrity Test BOP Test -- Approved by the order of the Commission Location clearance Subsequent form require Original Signed By 0avid W. Johnston ':~//7 Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 8, 1996 Dave Johnston Commission Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Annular Pumping Approval for KRU Well 2M-31 Dear Mr. Johnston: Kuparuk River Unit Well 2M-31 was permitted to drill on April 17, 1996. The permit application included a request to approve this well for annular pumping operations for the period of one year. The application included information specified in the proposed regulations 20 AAC 25.080, but approval was contingent on the subsequent submittal of a Form 10-403 describing the well's surface casing cement job. Information included in the permit to drill application is not repeated here since it has already been submitted to the AOGCC. We believe that the 2M-31 surface cement job will provide an adequate seal for annular pumping operations and that the well has been cased and cemented according to regulation. ARCO Alaska, Inc., requests approval to commence annular pumping operations on this well as needed for waste disposal as described in the Permit to Drill application. Please note that this is the first attempt at obtaining annular pumping approval in this fashion, and the Commission's assistance is requested in structuring the application process to meet the needs of both the AOGCC and the operating companies. If you have any questions or input on the request for approval, please contact the Drilling Engineer, Denise Petrash at 263-4183, or myself at 265-6206. Sincerely, Mike Zanghi ~i Drill Site Development Supervisor RECEIVED MAY 1 3 1991; Alagk~ 0tl & Saf~ Cons, Commission Anchorage AR3B-6003-93 242-2603 KRU 2M-31 Annular Pumping Permit Application Additional Information Please see the attached "Cementing Details" form for Well 2M-31 for basic details on the cementing operation. Additional information is offered below in support of ARCO Alaska Inc.'s opinion that the surface casing cement job will provide adequate sealing capability for annular pumping operations, and that the well has been cased and cemented according to regulation (AAC 25.030). Surface Hole TD: 4,045' MD / 2828' TVD Surface Hole Conditions: No problems were seen while drilling or tripping in the surface hole. Casing was run to bottom without problems, with precautionary circulation occurring at 1533' and 3100' MD. No fill was seen on bottom. All circulation while drilling and running casing saw full returns. Casing Placement: The fluted hanger was landed as planned. The surface casing shoe was placed at 4,035' MD, 10' off bottom. 10-20' off bottom is the planned standard with fluted casing hanger assemblies. Cementing Details: Full returns were seen while circulating on bottom prior to cementing and during the cementing operation itself until partway through the displacement. Returns were suddenly lost when 187 bbls out of 302 bbls of displacement fluids had been pumped. Pump pressures continued to steadily increase at the same rate indicating that the cement column in the annulus was continuing to rise. No signs of the water spacer which preceded the cement job were seen at surface. Excess on the lead cement was 150% (2.5 times the calculated gauge hole volume) and 15% on the tail cement. These excess factors are based on historical data and are calculated with the intent of bringing cement to surface during the primary job. Because cement was not seen at the surface, a top job was performed. A 1" line was run to 120' MD, the annulus was flushed with water, and cement was circulated to surface. At this point the likely cause of lost circulation was found: it appeared that the well packed off just below surface. The annulus below the fluted hanger was full of gravel. The 1" pipe had to be forced down and the gravel circulated out before starting the top job. Data from the cement job indicates that cement entered the annulus and continued to rise in the annulus even after losing circulation. The well appeared to pack off at the surface rather than downhole, based on how much gravel was seen. Previous 2M wells with lost circulation during the cement job have not shown any indications of problems during annular pumping operations (i.e., 2M-33). Based on the data, there should be an adequate seal for safe annular pumping operations. R E C ~lV ~ D Diagnostic Logs: None. MAY 1 x 1996 Almmkm Oil & O~s Con~. Commission Anchorage ARCO Alaska, Inc. Cementing Details Well#: 2M-31 Field: KUPARUK Date: 5/2/96 Casing Size Hole Diameter Hole Angle J Shoe Depth Float Depth % washout 9 5/8" 12 1/4" 69° I 4,035' 3,950' Centralizers State tFpe used, intervals covered and spacin~l Mud Spacer Lead Cement Tail Cement Displacement Ran 47 GEMECO bowspring centralizers. Run in center of first 2 its. and on next 45 collars. The float equip, was Weatherford. Weight 1 0.4/1 0.2 Gels before 10/16 Type Water YP(prior cond) 20 lbs/100 ft2 Gels after 5/8 Type I Mix wtr temp AS 3 I 65 iAdditives .23 #/sk D29 YP(after cond) IPV(prior cond) 16 lbs/100 ft21 22 cP Total Volume Circulated 630 bbls Volume 25 No. of sacks 73O Weight 12.1 PV(after cond) 19 cP Weight 8.3 PPG Yield 1.94 Type IMix water tempi No. of sacks Weight Yield G I 65 I 740 15.8 1.19 Additives G , 0.266 #/sk D29, 0.2% D46. 0.3% D65, 1% S1 Rate(before tail at shoe) 8 Reciprocation length 15' Theoretical Displacement 299.3 Calculated top of cement Surface top job. QP 1341 5/2/96 Rate(tail around shoe) 6 BPM Reciprocation speed 10 fpm Actual Displacement 302.6 Bumped plug I FIoats held NoI Yes Str. Wt. Up 170 Str. Wt. Dn 130 Str. Wt. Mud 130 Remarks: Include whether full returns were obtained, reciprocation throughout operation and any other pertinent information. Reciprocated pipe while circulating and until Lead slurry out of shoe. Had full returns while circulating and cementing. Lost all returns after pumping 187 bbls of displacement. Displaced with 5 bbls. cement followed by 25 bbls. cement rinsate followed by 272.6 bbls.mud. Did not bump plug, floats held. Performed top job on annulus with 78 sx. (16.5 bbls.) AS3. Had 11.9 ppg returns to surface. Cement Company Dowell IRig Contractor Parker ISignature G.R. Whi ~tkf- C ! \1 I;: I't MEMORANDU , State of Alaska Alaska Oil and Gas Conservation Commission TO' n~,,i~. Ohairman THRU: BlaJr Won~zeil~ P. !. Supemisor FROf~: Bobby Petroleum Inspector DATE: May 2, 1996 FILE NO: ABXIEBDD.doc SUBJECT: BOPE Test - Parker 245 ARCO - KRU - 2M- 31 PTD # 96-0077 Kuparuk River Field Thursday, May 2, 1.996: ! traveled this date to ARCO's KRU well 2M-31 being drilled by Parker rig 245 and witnessed the BOPE test. As the attached AOGCC BOPE Test Report shows there were no failures of the equipment that was witnessed. The choke manifold had been tested before I ardved on location and there was 1 valve that leaked. The valve had been cycled and retested OK. The results of the test of the choke manifold had been recorded on a chart recorder and I reviewed the chart. Before the test I reviewed the daily drilling report and i noticed that while cementing the surface pipe circulation was lost - approximately 160 barrels - but some of the space water did reach the surface indicating that the cement was close. The crew rigged up and did a 48 sack (16.5 bbis.) top job and good cement was circulated to surface after 11.9 bbls. had been pumped. The rig was clean and all equipment seemed to be in good working order. The location was lean and there was good access to the rig. Summary: ! witnessed the BOPE test on Parker rig 245 drilling ARCO's KRU well 2M-31. Attachment: ABXIEBDD.XLS X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9.625" Test: Initial X Workover: PARKER Rig No. 245 PTD # ARCO Rep.: 2M-31 Rig Rep.: Set @ 4,094' Location: Sec. Weekly Other 96-0077 DATE: 5/2/96 Rig Ph.# 659-7670 GUY WHITLOCK FRED HEBERT 27 T. 11N R. 8E Meridian U , ,,, , , MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Post~:! YES BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Pipe Rams 1 Blind Rams 1 Choke Ln. Valves 1 HCR Valves Kill Line Valves Check Valve Well Sign OK Drl. Rig OK Hazard Sec. YES ,. Test Pressure P/F 300/3,000 P P 300t3,000 300/3,000 300/3,000 300/3,000 1 300/3,000 2 300/3,000 N/A P P P 'p P MUD SYSTEM: V'suat Alarm Trip Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector YES YES H2S Gas Detector ~ES' ~YES FLOOR SAFETY VALVES: Quan. Upper Kelly / IBOP . 1. ~ Lower Kelly / IBOP 1 Ball Type 1 Inside BOP 1 Test Pressure 300/3,000 300/3,000 300/3,000 300/3,000 P/F ,P CHOKE MANIFOLD: No. Valves N~T1 No. Flanges Manual Chokes . Hydraulic Chokes Test Pressure 300/3,000 P/F 300/3,000 Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: . 6 (~ 2200 3,000 I P 1,700 P minutes 27 sec. minutes 19 sec. YES Remote: YES Psig. Number of Failures: I ,Test Hrs.: 2.0 Hours. Number of valves tested 8 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at: I 279-1433 .1 I I I I I I I I II I REMARKS: The choke manifold had been tested while cementing the casing and the results recorded on a chart which I reviewed. Distribution: orig-Well File c - Oper. ARig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES × NO Waived By: Witnessed By: BOBBY D. FOSTER F1-021L (Rev. 12/94) ABXIEBDD.XLS April l7, 1996 ALAS~ 0IL AND GAS CONSERVATION CO~VH$SION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Michael Zanghi> Dr/Il Site Develop Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 2M-31 ARCO Alaska, Inc. -. Permit No 96-77 Sm-fLoc. ll4'FSL, 317'FWL, Sec. 27, TllN, R8E, LrM Btmhole Loc. 1756'FSL, 779'FWL, Sec. 32, TllN, R8E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. Annular disposal approval w/il be contingent on submission of a form 10-403 (,Application for Sundry approval) with surface casing cement job details. The permit to drill does not exempt you from obtaining add/tional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance w/th 20 AAC 25.035. Su~cient notice (approx/mately 24 hours) ofthe BOPE test performed before dr/lling below the surface casing shoe must be given so that a representative of the Commission may w/mess the test. Notice may be given by contacting the Commission petroleum field inspector 659- 3607. SO BY ORDER OF TI:I~_ ~ CO1Vi_MISSION /encl c: Dept offish & Came, Habitat Section- w/o enct Dept of Envkonmental Conservation- w/o encl STATE OF ~ AL,-,,SKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry O Deepen D service E] Development Gas D Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 106' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 '~ADL 25585, ALK 2671 4. Location of well at surlace 7. Unit or property Name 1 1. Type Bond (see 2o AAC 25.025) 114' FSL, 317' FWL, Sec. 27, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1854' FSL, 1049' FWL, Sec. 32, T11N, RSE, UM 2M-31 #U-630610 At total depth 9. Approximale spud date Amount 1756' FSL, 779' FWL, Sec. 32, T11N, RSE, UM 4/26/96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2M-15 13323' MD 1756 @ TD feet 12.0' @ surface feet 2491 6412' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035(e)(2)) Kickoff depth 700' feet Maximum hole angle 69.17° Ma)drnurnsurface 1806 pslg At total depth (TVD) 3300 pslg 18. Casing program Settir~l Depth size Specifications Top Bottom Quantity/of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' :1:200 CF 12.25" 9.625" 40.0# L-80 BTC 4557' 41' 41' 4598' 3051' 590 Sx Arcticset III & · .~ HF-ERW 960 Sx Class G . 8.5" 7" 26.0# L-80 BTCMOE 13282 41' 41' 13323' 6412' 220SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet '" -' :~ '; - Effective depth: measured feet -Junk (measured) true vertical feet ' ~.: ..:? ./ Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor , ~ Intermediate g Production Liner Perforation depth: measured true vertical r-,it ~,2,~t.. -... 20. Attachments Filing fee X Property plat E] BOPSketch X Diverter Sketch X .~&~?3i~O?~JHIling program X Drilling fluid program X Time vs depth plot [] Refraction analysis E] Seabed report [~ 20 AAC 25.050 requirements X 21. I hereby certihj that ~,oregoingAPin~b ii' true and c°rrect t° the best of my knowledge Signed Title Drill Site Develop. Supv. Date ' Commission Use On~ Permit Number [ e-r I Approval date . I See cover letter for ~'; -077 I 5o-J03- 2 o~.,4~- ~o I ? '~/ '/ .~:/-'~ other requirements Cond.ions of approv Samp,e.r uired El Ye, No Uu k, g required D Yes 13: .o Hydrogen sulfide measures ~, Yes D No Directional survey required [~ Yes r~ No Required working pressure forBOPE [~ 2M ~. 3M E] 5M E] 1OM [~ 15M Other: Original Signed By David W. Johnston by order of ....... Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate , , , 10. 11. 12. 13. 14. 15. 16. 17. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 2M-31 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,598')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (13,323') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing string. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & either full opening valve (if logging planned) or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Run completion assembly. Set packer and pressure test tubing and annulus. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well KRU 2M-31 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-25 15-35 50-80' 5-15 15-4O 10-12 9.5-10 +_10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% ing Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General Notes: Weight up to TD 10.8 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1,806 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 2M-31 is 2M-15. As designed, the minimum distance between the two wells would be 12.0' @ surface. Drillin~l Area Risks- Risks in the 2M-31 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 7" casing will be topset above the Kuparuk and Nordic Rig #1 will drill out a 6-1/8" hole, and run a 5" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.8 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. .~.NNULAR PUMPING OPERA'I,ONS WELL KRU 2M-31 Incidental fluids developed from drilling operations will be pumped down the surface/production casing annulus of an existing well or the nearest dedicated disposal well (2M-23). (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2M-31 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 2M-31 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoes will be set +_200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure -- 3405 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 9.625 40 L-80 3 BTC 3090 2627 5750 4888 7.000 26 L-80 3 BTC-M 5410 4599 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 (g) (1). ARCO ALASKA, ]nc. Pad 2M 31 slot ~r51 Kuparuk River Unit North Slope, Alaska CLEARANCE REPORT by Baker Hughes !NTEQ Your ref : 31 Version Our ref : prop1477 License : Date printed : 1-Apr-96 Date created : 8-Dec-95 Last revised : 1-Apr-96 Field is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on n70 16 17.458,w150 5 54.03 Slot location is nFO 16 18.579,w150 5 44.801 Slot Grid coordinates are N 5948985.493, E 488157.659 ~'~ Slot local coordinates are 114.00 N 317.00 E Reference North is True North "~" Main calculation performed with 3-D Minimtill Distance Itlethod object wet[path 9B Version #6,,9B,Pad 2M PMSS <3542-4022'>,,9,Pad 2M PGMS <0-12177'>,,gA,Pad 2M PMSS <O-3464'>,,23,Pad 2M PGMS <O-?119'>,,12,Pad 2M PMSS <0-10399'>,,6,Pad 2M PGMS <0-9810'>,,14,Pad 2M P~MS <0-7947'>,,1~,Pad 2M PMSS <1579-3318'>,,1,Pad 2M PGM$ <0-9800'>,,IA,Pad 2M PGMS <O-7855'>,,27, Pad 2M PGMS <0-9835'>,,28,Pad 2M PGMS <0-6765'>,,26,Pad 2M PGMS <0-7445'>,,25,Pad 2M PGMS <0 - 9130'>,,19,Pad 2M PGMS <0-7510'>,,3,Pad 2M PGMS <0 - 10598'>,,21,Pad 2M PGMS <0 - 7926'>,,18,Pad 2M PGMS <0 - 12125'>,,13,Pad 2M PGMS <0-7020'>,,15,Pad 2M PGMS <0-8931'>,,5,Pad 2M PGMS <0-9070'>,,20,Pad 2M PGMS <0-7800'>,,10,Pad 2M PGM$ <0-7450'>,,24,Pad 2M PGMS <0 - 9515'>,,11,Pad 2M PGMS <0-6848'>,,16,Pad 2M PGMS <0-10340'>,,7,Pad 2M PGMS <0-8598'>,,22,Pad 2M PGMS <0-13385'>,,32,Pad 2M Closest approach with 3-D minim~ distance method Last revised Distance M.D. Diverging from M.D. 13-Mar-96 3358.3 2900.0 2925.0 11-Nov-92 193.0 20.0 20.0 9-Feb-96 193.0 20.0 20.0 27-Apr-92 212.0 360.0 13323.4 11-Nov-92 44.4 1400.0 4640.0 11-Nov-92 238.0 0.0 4280.0 22-0ct-92 13.0 0.0 0.0 22-0ct-92 62.0 0.0 0.0 5-Jan-93 264.9 1675.0 1675.0 5-Jan-93 264.9 1675.0 1675.0 11-Nov-92 82.7 2825.0 2825.0 22-0ct-92 282.5 3180.0 3180.0 22-0ct-92 276.9 120.0 120.0 1-Ju[-91 262.0 0.0 13123.4 3-Apr-92 112.0 0.0 13123.4 9-Apr-92 350.2 600.0 1417.5 3-Apr-92 162.0 100.0 13323.4 3-Apr-92 87.0 120.0 120.0 3-Apr-92 35.1 460.0 13123.4 9-Apr-92 12.0 0.0 0.0 30-Jul-92 134.5 1600.0 1600.0 30-Ju[-92 137.0 0.0 13323.4 3-Apr-92 89.9 1350.0 1350.0 30-Ju[-92 236.1 300.0 13000.0 3-Apr-92 152.0 540.0 2425.2 1-Ju[-91 37.0 0.0 0.0 22-Feb-93 223.0 20.0 10520.0 3-Aug-94 187.0 20.0 320.0 18-Feb-93 413.0 0.0 0.0 PGMS <O-9350'>,,30,Pad 2M PGMS <O-11003'>,,2,Pad 2M PMSS <10783-13015'>,,29,Pad 2M PMSS <0-11241>,,29,Pad 2M PGMS <0-12151,,8,Pad 2M PGMS <0-12370'>,,4,Pad 2M 2M-A Version #7,,35,Pad 2M 2M-G Version #6,,2M-G,Pad 2M 2M-F/M Version ~Z~,,2M-F/M,Pad 2M 2M-C Version ~5,,2M-C,Pad 2M 33 Version #11,,33,Pad 2M 11-Nov-92 382.9 200.0 3020.0 11-Nov-92 225.0 2178.7 2178.7 8-Dec-95 265.3 3460.0 3460.0 1-Feb-93 265.3 3460.0 3460.0 6-Jan-93 207.1 220.0 220.0 11-Nov-92 268.0 20.0 20.0 13-Mar-96 100.0 700.0 700.0 13-Mar-96 25.5 600.0 600.0 13-Mar-96 24.5 700.0 700.0 13-Mar-96 75.0 700.0 700.0 29-Mar-96 32.0 680.0 680.0 IA]RCO ALASKA, Inc. i Structure : Pod 2M Well : 31 jDot~ plott~d: 2-Apr-g6 J Field : Kuparuk River Unit Location : North Slope, Alaska jPIot Reference is 31 Version ~16. j J Coordinates ,J ore in feet reference slot ~31. True VerUcal Depths ore reterence RKB (Porker ~245).J , i < West ESTIMATED SURFACE LOCATION: 114' FSL, 317' FWL SEC. 27, Tl lN, RSE Scale 1 : .350.00 10500 9800 91 O0 8400 7700 7000 6300 5600 4900 4200 3500 2800 21 O0 1400 700 0 700 I I I I I I I I I I I I I I I I I I I I I ~ ~ ~ I f I ~ I ~o_ ~ ~ ~ ~ 700 TARG E-r LOCATION: 1854' FSL, 104g' FWL TVD=6171 TMD=12949 DEP=10446 SOUTH 3540 S 70.19 DEG W _,soo ..~..~ o,~ ~ 10446 (TO TARGET) %~. ~. TD LOCATION: 4200 0 _ RKB E~A~ON'. 147' 700_ I KOP WD=700 TMD=700 DEP=O ~s.~ 1400_ ~4n~ B/ PERMAFROST ~D=1417 TMD=1435 DEP=140 .... T- 2~00_ ~51.00 ~ 60.00 ~69.00 EOC ~D=2485 TMD=5006 DEP=1251 ~ B/ W ~K SNDS WD=2851 ~D=4035 DEP=2193 :'~ ......... ~, ~ _ 2800__ CompComp ~Bsst ~ TABASCO9 5/8"SNDScsG WD=2883pT WD=3051TMD=4125~D=4598DEP=2277DEP=2719 ~ ~ ~AXIMU~ ANGLR 3500 _ ~ 69.17 DgG 4200 _ 5600. BEGIN ANGLE DROP ~D=5669 T~D=ll9 5 B~E HRZ WD=5987 TMD=12647 DEP=10207 68~oo DROP 2 DEG / 100' K-1 MARKER W0=6074 TMD=12795 DEP=10327 ~0~ ' T~ T/ UNIT C - EOD. WD=6152 TMD=12920 DEP=10424 ""~oo CRT ANGLE ~3oo_ ~0 DEG TARGET - T/ Aa SNDS ~=0171 TMD=12~40 DEP=1044~ B/ KUP SNDS WD=6283 T~D=13123 DER=lO580 7000 7~ 0 700 ~400 ~00 2~00 3~00 4200 4900 5600 6~0 7O0O 7700 S400 ~00 9800 ~0500 ~200 Scale 1 : 350.00 Vedicol Section on 250.19 azimuth with reference 0.00 N, 0.00 W from slot ~31 700 0 -- _1400 _ _2100 I - I _2800 V _ Created by : jones For: D PETRASH Dote plotted : 2-Apr-9& Plot Reference is .%1 Version I Coordinates are in feet referer~ce slot j~31. True Ver~col Depths ore reference RKB (Porker #245). 300 280 260 240 220 200 60 I 0 0 0 40 .. ._.. ~ 20 0 70O ARCO ALASKA, Inc. Structure : Pad 2M Field : Kuparuk River Unit Well : 31 Location : North Slope, Alaska 180 160 140 1900 West 120 1 O0 80 60 40 20 100 70o ,300 700 5500 Scale 1 · 10.00 0 2O 4O 6O o 4O ,, O I I V I100 1100 goo 1100 lOO goo 11oo _200 I I V 1300 1700 1300 300 280 260 240 220 200 180 160 140 120 1 O0 80 < West 60 40 20 0 20 40 Scole 1 · 10.00 I I V Created by : jones For: D PETRASH Dote plotted : 2-Apr-96 Plot Reference is 31 Version t~6. Doordinotes are tn feet reference slot ~51. True Vertical Depths ore reference RKB (Porker ~245). , I 960 920 160 120 8O ARC0 ALASKA, Inc. Structure : Pad 2M Well : 51 Field : Kuparuk River Unit Location : Norih Slope, Alaska ~ = = W e s f ~o,~ 1 ' 20.00 880 840 800 760 720 680 640 600 560 520 480 440 400 360 ,:320 280 I I I I I I I I I I I I I I I I I I I I I I I I [ I I i i ~-~L~, I I _ q~C)~ _ Proposed q,~® ~ _200 160 120 80 ~o 0 % 120 4O 11 O0 DO 1700 oo 120 160 160 200 240 11oo 2O0 240 280 320 360 40O 44O 480 52O 96O 920 1900 1900 50O 1500 3OO I I I I I I I I I I I I I I I I I I I I I I I I I I I I 880 840 800 760 720 680 640 600 560 520 480 440 400 ,360 520 < Wesf I 28O Scale 1 ' 20.00 280 520 360 400 _ _ 440 480 52O 0 I I V ~ ~UPARUK RIVER UN~, 20" DIVERTER SCHEMATIC 6 b4 I 5 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. 1. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16'- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16' OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16' DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 13 5/8" 5000 BOP STACK 7 , 6 5 ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. ~ CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3(X)O PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. & OPEN TOP PIPE RAMS AND CLOSE Bo,-rOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 1. 16"- 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 1;~5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5(:X:)O PSI PIPE RAMS 5. 13~o/8" - 5000 PSI DRLG SP(:X::)L W/ CHOKE AND KILL LINES 6 1:~5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 135/8" - 5000 PSI ANNULAR 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRIllING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE :~1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. l-, 1../ ,J ;,' WELL PERMIT CHECKLIST GEOL AREA PROGRAM: exp [] der !~ redrll [] serv [] ON/OFF SHORE wellbore seg [] ©U ADMINISTRATION 1. Permit fee attached ................... ~N 2. Lease number appropriate ................ ~N 3. Unique well name and number .............. ~ N 4. Well located in a defined pool ............. ~ N 5. Well located proper distance from drlg unit boundary.. ~ N 6. Well located proper distance from other wells ...... ~ N 7. Sufficient acreage available in drilling unit ...... ~ N 8. If deviated, is wellbore plat included ......... ~ N 9. Operator only affected party .............. ~ N 10. Operator has appropriate bond in force ......... ~ N 11. Permit can be issued without conservation order ..... ~O N 12. Permit can be issued without administrative approval...~ N 13. Can permit be approved before 15-day wait ........ G N REMARKS ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 27. 28. 2~. Conductor string provided ............... ~ N Surface casing protects all known USDWs ........ ~ N CMT vol adequate to circulate on conductor & surf csg..Y~ N CMT vol adequate to tie-in long string to surf csg . . . Y ~ CMT will cover all known productive horizons ...... ~ N Casing designs adequate for C, T, B & permafrost .... Y~ N Adequate tankage or reserve pit ............ ~ N If a re-drill, has a 10-403 for abndnmnt been approved. LY ~! Adequate wellbore separation proposed ......... ~ N If diverter required, is it adequate .......... .~ N Drilling fluid program schematic & equip list adequate .~ N BOPEs adequate ..................... ~ N BOPE press rating adequate; test to ~~-/ psig. Y~ N Choke manifold complies w/API RP-53 (May 84) ...... ~ Work will occur without operation shutdown ....... ~ N Is presence of H2S gas probable ............ ~ N GEOLOGY DATE 30. Permit can be issued w/o hydrogen sulk..Y 31. Data presented on potential ove~~re zones . .... Y 32. Seismic analysis of s~ gas zones. ......... Y 33. ~i~_off-shore) ~ .. ...... Y 34. ct name/phone for weekly progress reports ..... Y [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: BEW DWJ ~ HOW/ljb - A:\FORMS~cheklist rev 11/95 Comments/Instructions: Well HistorY 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. I I I I I I I I I I I I I I I I I I I e e Memory Multi..finger Caliper Log Results Summary ¡J(Jrv1 r q-i:- \'\( t t.,.-o.b Company: ConocoPhillips Alaska, Inc. Well: 21111'i31 Log Date: October 9, 2005 Field: Kuparuk \~<o- Log No. : 7535 State: Alaska Run No.: 1 API No.: 50-103-20241-00 Pipe1 Desc.: 3.5" 9.3 lb. L-80 EUE Top Log Intvl1.: 786 Ft. (MD) Pipe1 Use: Tubing Bot. Log IntvI1.: 3,025 Ft. (MD) a'ì'l Inspection Type : Co"osive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the IIGLM" @ 2,104' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing in the interval between 1,800' and 2,800' with respect to corrosive and mechanical damages. Tn.~tulDift.ilftervl!lt1'Oggéctappears' to be in good to poor condition with respect to corrosive'damage", with a probable hole recorded in joint 63 (2,041'). Possible holes are also recorded in joints 59 and 70 (1,938' and 2,288'). The damage recorded in the tubing appears in the forms of general corrosion and scattered pitting. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing interval logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. The numbering of the joints for this log is approximate based on an average joint length of 32'. MAXIMUM RECORDED WAll PENETRATIONS: Probable Hole Multiple Possible Holes Possible Hole Isolated Pitting Corrosion @ @ @ @ @ 2,041 Ft. (MD) 1,938 Ft. (MD) 2,288 Ft. (MD) 1 ,298 Ft. (MD) 2,191 Ft. (MD) ( 94%) ( 87%) ( 86%) ( 82%) ( 80%) Jt. Jt. Jt. Jt. Jt. 63 59 70 39 67 MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No significant areas of cross-sectional wall loss (> 7%) are recorded throughout the tubing interval logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing interval logged. SCN~ril~D G I Field Engineer: L. Mills-Dawson Analyst: M. Tahtouh Witness: T. Senden ProActive Diagnostic Services, Inc. / P.O. Box 1369, Staffol-dr TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 RECE\VED NO" 1 ß 1.005 Na'h gi\ & Gas Cons. Commission ~" MQ\nni!ge I I I Well: Field: Company: Country: 2M-31 Kuparuk ConocoPhillips Alaska, Inc. USA I [~~bing: Nom.OD 3.5 ins Weight 9.3 ppf Grade & Thread L-80 I and Metal loss ('Yo wall) I penetration body metal loss body I 80 60 40 20 0 o to 1% 10 to 20 to 40 to over 20% 40% 85% 85% I 1 to 10% I 3 o 13 o 2 o 55 o loss I I Damage Configuration ( body) 50 30 I 40 20 I 10 o I isolated general line ring hole I poss pittìng corrosion corrosion corrosion ¡ble hole I N"";~" of iO~: d'''''ž,'''' ÙQt" ~ 681 j- - J I I PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Nom.iD 2.992 ins October 9, 2005 MFC 24 No. 040665 1.69 24 Nom. Upset 3.5 ins Upper len. 1.2 ins Lower len. 1.2 ins Damage Profile ('Yo wall) penetration body o 23 metal loss body 50 GlM 1 Bottom of Survey = 93 Analysis Overview page 2 I I -~] 100 I I I I I I I I I I I I I I I I I I I Pipe: Body Wall: Upset Wail: NominaII.D.: 969 1001 1033 1065 1Q96 112JL 116~~ 11 9º_~ 1219 42~J1Zª-- 43 1409 44 1439 I 45 .J468 I 46 1500 ~.~~ L-.-... 48.... I 1 5 (Ü I . 49 1 $~93 ... 50 16~24 51.~ 52 1688 53 171~L 54 1751 55 1782 56 181A.._ 57 1846 1_ 58 T 1878 - I .. 59 I.. ·1909 1 ~11941 1 61 1·1973 I 62 )005 2036 2067 2098 04 64 64.1 64.2_.~ 64.3 l â~ r.~ ~~g 67 2182 68 2214 69 ...1246 PDS REPORT JOINT TABULATION SHEET ~2.94 2.93 2.92 2.,3l 2.94 2,22 2.9.1 2.94 2.92 2.94 2.94 Corrosion. 2.21... Corrosign. 2.93 2.95 Corrosion. 2.95 Corrosion. 2.94 Corr(jsion. 2.94 Corrosion. 0.22 87 1 6 1 2.92 1 Multiple Possible Holes! 0.16161T~îf.J 2.93 T Corrosion. 0.13 ~.;1 i294-L Corrosion. 0.14 2.95 Corrosion. 0.24 2.92 0.15 2.96 0.1£_ 2.92 o N 0.07 2. 0.15 2. 0.18 2.93 0.20 2.94 0.17 2.93 0.20~ 2.94 3.5 in 9.3 ppf L~80 0.254 in 0.254 in 2.992 in Min. 1.0. (Ins.) 2.95 2.95 2.94. 2.93 2.95 .2.94 2.95 2.93 2.95 2.94 o o -Q. o .. 0 o Well: Field: Company: Country: Survey Date: 2M-31 Kuparuk ConocoPhillips Alaska, Inc. USA October 9, 2005 Comments Damage Profile (%wall) o 50 100 .... ,Shallow co[IQsion. Shallow p.l!ting. .... Shallow pitting. I t. Deposits. .. Shallow pittinfL Sh.i1llow pitting. . Isolated pitting. Shallow corrosion. Isolated pitting._~.~ Isolated ilting. ittin . ISQlated pitting. __. I~olated pitting. ~.~ Isolated pitting. IsolatS'd pitting. Isolated pitting. Isolategj:Jittíng. Corro~on. Corr.Qsion. Lt.j)....ePosíts. Body Metal Loss Body Page 1 I I Pipe: Body Wall: Upset Wall: Nominal I.D.: I I I 70 ~ 72 2LZ7 2109 2338 2368 24Q0 . 2429 24.QL . 2493 2523 2554_ 2587 2618 2649 2682 2712 2743 I 74 75~ l6 ~.. 78 79. ---ªº--- 81 82 ~_ 83 I 84 185 I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in L s Min. I.D. (Ins.) 2.92 .2.91 2.94 _ 2.93 2.91 2·92 _2.92 2.92 2.93 2.93 2.93 2.92 .2.91 2.93 2.91 2.93 2.93 2.8.9 2.90 2.89 2.91 2.87 2.87 2.87 Well: Field: Company: Country: Survey Date: Jossible Hole! I C.orrosion. Corrosion. 2M-31 Kuparuk ConocoPhillips Alaska, Inc. USA October 9, 2005 Comments ----~ Page 2 Corrosion. Lt. Depos.its. Corrosion. Corrosion~ Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Lt. Deposits. Corrosion. I Corrosion. TCorrosiº!l. Lt. Dep..9sits. I Corrosion. Lt. Deposits. Cor~osion. Lt. D?'posits. Corrosion. Lt. Deposits. ..___ CoITQsion. Lt. De[2osits.___ Corrosion. Lt. Deposits. Corrgsion. End..9f Log . D';mage Profile I (%wall) o 50 100 I Body Metal Loss Body - - - - - Well: Field: Company: Country: Tubin : - - - - - - - - - - P S Repo Cross S 2M-31 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 f L-80 October 9, 2005 MFC 24 No. 040665 1.69 24 M Tahtouh Cross Section Tool speed = 51 NominallD = 2.992 Nominal OD = 3.500 Remaining wall area = 95 % Tool deviation = 57 0 Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: at depth 2040.783 Finger 1 Penetration = 0.24 ins Probable Hole 0.24 ins = 94% Wall Penetration HIGH SIDE UP Cross Sections page 1 - s - - - ------ ------- - ----- PDS Rep ross Sections Well: Field: Company: Country: 2M-31 Kuparuk ConocoPhillips Alaska, Inc. USA Survey Date: Tool Type: October 9, 2005 MFC 24 No. 040665 Cross Section for Joint 59 at depth 1938.453 ft Tool speed'" 51 NominallD '" 2.992 Nominal OD = 3.500 Remaining wall area 95 % Tool deviation'" 42 0 Finger 1 Penetration = 0.222 ins Possible Hole 0.22 ins'" 87% Wall Cross Sections page 2 I II I '" ¡:,~; ... TUBING (0-12822, 00:3.500, 10:2 .992) I I Gas Lift ~ndre!lDummy Valve 1 (2104-2105, I 00:5.968) I SLEEVE :12746-12747, I 00:3.500) PROO. _.~ CASING (0-13151, 00:7.000, Wt26.00) I I PKR~- I :12794-12795, 00:6.151) I I NIP-~ :12811-12812, 00:3.500) I I I SOS -~. :12821~12822, 00:3.500) TTL :12822-12823, 00:3.500) I I Perf :12895-12921) I Perf :12921-12947) I I KRU 2M-31 ND 121 2826 6281 Wt 62.58 40.00 26.00 Grade Thread !j-40~ L-80 L-80 ID 2.812 2.812 ..~ 2. 2. 2. 7 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 2M- 31 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE · ALASKA API NUMBER : 50-103-20241-00 REFERENCE NO : 96171 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:22 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/07/24 ORIGIN : FLIC REEL NAME : 96171 CONTINUATION # PREVIOUS REEL : CO~fEl~r : ARCO ALASKA, INC. ,KUPARUK 2M-31,API # 50-103-20241-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/07/24 ORIGIN : FLIC TAPE NAME : 96171 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA, INC. ,KUPARUK 2M-31,API # 50-103-20241-00 TAPE HEADER KUPARUK RIVER ~¢WD/~ LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION BIT RUN 1 96171 BOSSE WHITLOCK SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 2M-31 501032022410 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 24-JUL-96 BIT RUN 2 96171 BOSSE WHITLOCK BIT RUN 3 27 liN 8E 114 317 147. O0 147.00 106.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 4042.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14 3RD STRING PRODUCTION STRING Well drilled 03-MAY through 08-MAY-96 with CDR/CDN. Ail data was collected in two bit runs. MAD data was collected on bit run 2 in two washdownpasses. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE - 96/07/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED I4ERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUI~MARY LDWG TOOL CODE .............. $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 3968.0 13161.0 BASELINE DEPTH .............. 88888 0 12992 5 12988 5 12971 5 12942 0 12929 5 12925 0 12921.5 12899.5 12893.0 12886.5 12876.5 12832.0 12822.5 12819.5 12812.5 12783.5 12770.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... ....... 88889.0 12993.5 12989.5 12971.5 12942.0 12930.0 12924.5 12922.0 12900.5 12893.5 12885.0 12876.0 12829.5 12821.0 12817.5 12810.5 12781.5 12769.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12752.0 12736.0 12729.0 12720.0 12703.0 12692.5 12687.0 12677.5 12647.5 12641.0 12638.5 12627.5 12625.0 12620.5 12612.5 12607.0 12601.5 12598.0 12589.0 12570.5 12564.0 12562.0 12555.0 12549.0 12541.5 12537.5 12527.5 12526.0 12511.0 12501.0 12490.5 12481.5 12470.0 12458.5 12450.0 12445.5 12428.5 12411.0 12404.5 12390.5 12379.5 12349.0 12314.0 12302.0 12286.5 12277.5 12258.5 12243.5 12234.5 12194.5 12191.0 12179.0 12173.0 12161.5 12153.5 12750.5 12735 5 12729 0 12721 0 12704 5 12692 5 12688 0 12675.5 12646.0 12638.0 12636.5 12626.5 12624.5 12620.5 12612.0 12606.0 12599.5 12597.0 12587.0 12569.0 12563.5 12560.0 12554.0 12548.5 12541.0 12537.5 12526.5 12523.5 12509.0 12498.5 12487.5 12479.0 12468.5 12457.5 12449.5 12444.5 12427.5 12410.0 12402.5 12388.5 123 78.5 12348.0 12313.0 12300.0 12284.0 12275.0 12258.0 12243.0 12233.0 12197.5 12192.0 12180.0 12174.5 12161.0 12153.0 24-JUL-1996 14:22 PA GE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:22 PAGE: 12134.5 12126.0 12117.5 12109.5 12082.5 12066.5 12056.0 12040.5 12034.0 12029.5 11972.0 11948.0 11919.5 11889.5 11879.5 11856.5 11799.5 11673.5 11588.0 11552.0 11548.0 11509.5 11453.5 11438.0 11353.5 11324.0 11297.5 11284.0 11281.5 11247.5 4045.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ 12134 5 12124 0 12116 5 12110 0 12084 5 12067 5 12058 0 12042 0 12033 0 12029 0 11973 5 11948 0 11920 0 11889 5 11881 0 11858 0 11801 0 11675 0 11589 5 11554 5 11550 0 11510 0 11455 5 11438 5 11356.0 11327.5 11302.0 11288.0 11286.5 11251.5 4045.0 BIT RUN NO. MERGE TOP MERGE BASE 1 3968.0 12237.0 2 12237.0 13161.0 The depth adjustments shown above reflect the MWD GR to the CBT GR logged by SWS. Ail other MWD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:z2 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE- CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630168 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD 0H~4~630168 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD 0H~4~630168 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD 0H~630168 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OH~4 630168 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD 0P~4630168 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 630168 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 630168 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 630168 O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 630168 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 630168 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 630168 O0 000 O0 0 i 1 1 4 68 0000000000 CALNMWD IN 630168 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 630168 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CBT GAPI 630168 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13161.500 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 20.692 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN. MWD -999.250 NPHI.MWD -999.250 GRCH. CBT -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:22 PAGE: DEPT. 13000.000 RA.MWD VRP.MWD 4.561 DER.MWD GR.MWD 89.195 RHOB.MWD CALN. MWD 8.806 NPHI.MWD DEPT. 12000.000 RA.MWD VRP.MWD 8.537 DER.MWD GR.MWD 113.001 RHOB.MWD CALN. MWD -999.250 NPHI.MWD DEPT. 11000.000 RA.MWD VRP.MWD 5.435 DER.MWD GR.MWD 125.761 RHOB.MWD CALN. MWD 9.259 NPHI.MWD DEPT. 10000.000 RA.MWD VRP.MWD 2.953 DER.MWD GR.MWD 87.686 RHOB.MWD CALN.MWD 9.041 NPHI.MWD DEPT. 9000.000 RA.MWD VRP.MWD 5.236 DER.MWD GR.MWD 136.869 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 8000.000 RA.MWD VRP.MWD 5.023 DER.MWD GR.MWD 106.388 RHOB.MWD CALN. MWD -999.250 NPHI.MWD DEPT. 7000.000 RA.MWD VRP.MWD 3.641 DER.MWD GR.MWD 112.797 RHOB.MWD CALN. MWD -999.250 NPHI.MWD DEPT. 6000.000 RA.MWD VRP.MWD 3.920 DER.MWD GR.MWD 86.053 RHOB.MWD CALN. MWD -999.250 NPHI.MWD DEPT. 5000.000 RA.MWD VRP.MWD 3.642 DER.MWD GR.MWD 97.780 RHOB.MWD CALN. MWD -999.250 NPHI.MWD DEPT. 4000.000 RA.MWD VRP.MWD -999.250 DER.MWD GR.MWD 44.299 RHOB.MWD CALN. MWD -999.250 NPHI.MWD DEPT. 3968.000 RA.MWD VRP.MWD -999.250 DER.MWD GR.MWD 40.257 RHOB.MWD CALN. MWD -999.250 NPHI.MWD 5.193 RP.MWD 5.001 ROP.MWD 2.491 DRHO.MWD 27.700 GRCH. CBT 5.185 RP.MWD 7.271 ROP.MWD -999.250 DRHO.MWD -999.250 GRCH. CBT 4.412 RP.MWD 5.075 ROP.MWD 2.406 DRHO.MWD 39.000 GRCH. CBT 2. 947 RP.MWD 2. 947 ROP.MWD 2. 363 DRHO.MWD 34. 800 GRCH. CBT 4.306 RP.MWD 5.105 ROP.MWD -999.250 DRHO.MWD -999.250 GRCH. CBT 3. 778 RP.MWD 4. 041 ROP.MWD -999. 250 DRHO.MWD -999. 250 GRCH. CBT 3. 751 RP.MWD 3. 759 ROP.MWD - 999.250 DRHO. MWD -999. 250 GRCH. CBT 3.723 RP.MWD 3.773 ROP.MWD -999.250 DRHO.MWD -999.250 GRCH. CBT 3.505 RP.MWD 3.591 ROP.MWD -999.250 DRHO.MWD -999.250 GRCH. CBT -999.250 RP.MWD -999.250 ROP.MWD -999.250 DRHO.MWD -999.250 GRCH. CBT -999.250 RP.MWD -999.250 ROP.MWD -999.250 DRHO.MWD -999.250 GRCH. CBT 4.902 72.507 -0.007 55.375 8.316 129.323 -999.250 73.563 5.403 229.468 0.043 -999.250 2.947 43.794 0.089 -999.250 5.372 352.934 -999.250 -999.250 4.203 367.165 -999.250 -999.250 3.763 215.182 -999.250 -999.250 3.799 243.097 -999.250 -999.250 3.640 366.814 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 VRA.MWD FET. MWD PEF. MWD VRA.MWD FET. MWD PEF. MWD VRA.MWD FET.MWD PEF. MWD VRA.MWD FET.MWD PEF. MWD VRA.MWD FET. MWD PEF. MWD VRA.MWD FET.MWD PEF. MWD VRA . MWD FET.MWD PEF. MWD VRA . MWD FET.MWD PEF. MWD VRA.MWD FET. MWD PEF. MWD VRA.MWD FET.MWD PEF. MWD VRA.MWD FET. MWD PEF. MWD 4.542 0.856 3.208 5.338 1.360 -999.250 4.367 0.518 4.130 3. 035 O. 719 2. 564 4.176 0.201 -999. 250 5.531 5.981 -999.250 3.531 0.342 -999.250 3.795 0.367 -999.250 3.537 0.191 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:22 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE · 96/07/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE igIIFZBER: 2 EDITED f4~RGEDMAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: 0.5000 FILE SUMmArY LDWG TOOL CODE $ FZERGED DATA SOURCE LDWG TOOL CODE .............. $ THIS MAD DATA WAS COLLECTED AS WASHDOWN DATA COLLECTED DURING BIT RUN 2 IN TWO PASSES TO RE-LOG INTERVAL FROM BIT RUN 1 WHERE THE CDN FAILED. $ START DEPTH STOP DEPTH 9425.0 9890.0 10825.0 11584.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 1 1 9425.0 9890.0 1 2 10825.0 11584.0 LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:22 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630168 O0 000 O0 0 2 1 1 4 68 0000000000 RA MAD OH~ff~630168 O0 000 O0 0 2 1 1 4 68 0000000000 RP MAD 0t~4~630168 O0 000 O0 0 2 1 1 4 68 0000000000 DER MAD 0t~4~630168 O0 000 O0 0 2 1 1 4 68 0000000000 ROP MAD FPHR 630168 O0 000 O0 0 2 1 1 4 68 0000000000 GR MAD GAPI 630168 O0 000 O0 0 2 1 1 4 68 0000000000 RHOBMAD G/C3 630168 O0 000 O0 0 2 1 1 4 68 0000000000 DRHOMAD G/C3 630168 O0 000 O0 0 2 1 1 4 68 0000000000 PEF MAD BN/E 630168 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI MAD PU-S 630168 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11585.000 RA.MAD -999.250 RP.MAD -999.250 DER.MAD ROP.MAD 87.803 GR.MAD -999.250 RHOB.MAD -999.250 DRHO.MAD PEF.MAD -999.250 NPHI.MAD -999.250 DEPT. 11000.000 RA.MAD 4.412 RP.MAD 5.403 DER.MAD ROP.MAD 1772.079 GR.MAD 125.761 RHOB.MAD 2.406 DRHO.MAD PEF.MAD 4.130 NPHI.MAD 39.000 -999.250 -999.250 5.152 O. 043 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:22 PAGE: DEPT. 10000.000 RA.MAD ROP.MAD -999.250 GR.MAD PEF.MAD -999.250 NPHI.MAD DEPT. 9429.000 RA.MAD ROP.MAD -999.250 GR.MAD PEF.MAD -999.250 NPHI.MAD -999.250 RP.MAD -999.250 RHOB.MAD -999.250 -999.250 RP.MAD -999.250 RHOB.MAD 34.000 -999.250 DER.MAD -999.250 DRHO.MAD -999.250 DER.MAD -999.250 DRHO.MAD -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 3 EDITED MAD PASSES Depth shifted and clipped curves; for each pass of each run in separate files. MAD RUNNUM~ER: 1 MAD PASSNUFZBER: 1 DEPTH INCREMENT: 0.5000 FILE SO?4T4ARY LDWG TOOL CODE START DEPTH MAD 9425.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH STOP DEPTH 9890.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... MAD LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:ZZ PAGE: 10 88888.0 88889.0 11523.5 11524.5 11509.5 11510.0 11490.5 11491.5 11454.0 11456.0 11442.0 11443.0 11434.0 11434.5 11379.5 11381.5 11350.0 11352.5 11343.0 11346.0 11324.0 11327.5 11315.0 11319.0 11289.5 11293.5 11281.5 11286.5 11275.0 11280.0 11266.0 11270.5 11253.5 11257.5 11226.0 11230.0 11191.0 11195.0 9817.0 9820.0 9472.5 9475.5 100.0 103.0 $ REMARKS: THIS MAD DATA WAS COLLECTED AS WASHDOWN DATA DURING BIT RUN 2. THIS IS INTERVAL ONE OF TWO. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:zz PAGE: 11 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELECt CODE (HEX) DEPT FT 630168 O0 000 O0 0 3 1 1 4 68 0000000000 RA MAD OH~M630168 O0 000 O0 0 3 1 1 4 68 0000000000 RP MAD OFff4M630168 O0 000 O0 0 3 1 1 4 68 0000000000 DER MAD OP~4M 630168 O0 000 O0 0 3 1 1 4 68 0000000000 ROP MAD FPHR 630168 O0 000 O0 0 3 1 1 4 68 0000000000 GR MAD GAPI 630168 O0 000 O0 0 3 1 1 4 68 0000000000 RHOBMAD G/C3 630168 O0 000 O0 0 3 1 1 4 68 0000000000 DRHOMAD G/C3 630168 O0 000 O0 0 3 1 1 4 68 0000000000 PEF MAD BN/E 630168 O0 000 O0 0 3 1 1 4 68 0000000000 NPHIMAD PU-S 630168 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9883.000 RA.MAD -999.250 RP.MAD -999.250 DER.MAD ROP.MAD 151.862 GR.MAD -999.250 RHOB.MAD -999.250 DRHO.MAD PEF.MAD -999.250 NPHI.MAD -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .004 SERVICE · FLIC VERSION · O01CO1 DATE : 96/07/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~IBER: LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:z2 PAGE: 12 EDITED MAD PASSES Depth shifted and clipped curves; for each pass of each run in separate files. MAD RUN NUM~ER: 2 MAD PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUF~4ARY LDWG TOOL CODE START DEPTH MAD 10825.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 88888.0 11523.5 11509 5 11490 5 11454 0 11442 0 11434 0 11379 5 11350 0 11343 0 11324 0 11315.0 11289.5 11281.5 11275.0 11266.0 11253.5 11226.0 11191.0 9817.0 9472.5 100.0 $ REMARKS: STOP DEPTH .......... 11584.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... MAD 88889.0 11524.5 11510.0 11491.5 11456.0 11443.0 11434.5 11381.5 11352.5 11346.0 11327.5 11319.0 11293.5 11286.5 11280.0 11270.5 11257.5 11230.0 11195.0 9820,0 9475.5 103.0 THIS MAD DATA WAS COLLECTED AS WASHDOWN DATA DURING BIT RUN 2. THIS IS INTERVAL TWO OF TWO. LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:22 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630168 O0 000 O0 0 4 1 1 4 68 0000000000 RA MAD Otfl~M630168 O0 000 O0 0 4 1 1 4 68 0000000000 RP MAD OH~ 630168 O0 000 O0 0 4 1 1 4 68 0000000000 DER MAD OHMM 630168 O0 000 O0 0 4 1 1 4 68 0000000000 ROP MAD FPHR 630168 O0 000 O0 0 4 1 1 4 68 0000000000 GR MAD GAPI 630168 O0 000 O0 0 4 1 1 4 68 0000000000 RHOB MAD G/C3 630168 O0 000 O0 0 4 1 1 4 68 0000000000 DRHO MAD G/C3 630168 O0 000 O0 0 4 1 1 4 68 0000000000 PEF MAD BN/E 630168 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI MAD PU-S 630168 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11585.000 RA.MAD -999.250 RP.MAD -999.250 DER.MAD ROP.MAD 87.803 GR.MAD -999.250 RHOB.MAD -999.250 DRHO.MAD PEF.MAD -999.250 NPHI.MAD -999.250 DEPT. 11000.000 RA.MAD 4.412 RP.MAD 5.403 DER.MAD ROP.MAD -999.250 GR.MAD 125.761 RHOB.MAD 2.406 DRHO.MAD PEF.MAD 4.130 NPHI.MAD 39.000 -999.250 -999.250 5.152 0.043 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:z2 PAGE: 14 DEPT. 10894.000 RA.MAD ROP.MAD -999.250 GR.MAD PEF.MAD -999.250 NPHI.MAD -999.250 RP.MAD -999.250 RHOB.MAD 33.300 -999.250 DER.MAD -999.250 DRHO.MAD -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .004 SERVICE : FLIC VERSION . O01CO1 DATE : 96/07/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .005 SERVICE : FLIC VERSION ' O01CO1 DATE : 96/07/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~ER 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUAmL~RY VENDOR TOOL CODE START DEPTH MWD 3968.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (M~MORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) STOP DEPTH 12237.0 08-MAY-96 FAST2.5 4.0 MEMORY 13161.0 3968.0 13161.0 70 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:22 PAGE: 15 MINIMUM ANGLE MAXIMUM ANGLE TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR CDN NEUT./DENS. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~k~) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): 65.8 69.3 TOOL NUMBER RGS059 NDS057 8.500 4042.0 LSND 10.50 47.0 9.5 500 5.2 3. 690 74.0 2. 920 74.0 REMARKS: ** RUN 1 DRILLED INTERVAL 4045' ~ 12237'**** RES TO BIT: 64.52'; GR TO BIT: 74.94 ' NEUT TO BIT: 124.56'; DENS TO BIT: 117.58' ** RUN 1 DRILLED INTERVAL 12237' - 13161'**** RES TO BIT: 42.52'; GR TO BIT: 52.94 ' NEUT TO BIT: 102.44'; DENS TO BIT: 95.46' CDN RUN 1 DATA BAD DUE TO TOOL FAILURE RELOGGED 9433' TO 9893'; 11000' TO 11585' $ LIS FORMAT DATA TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:22 PAGE: 16 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) 630168 O0 000 O0 0 5 1 1 4 68 0000000000 DEPT FT RA LW1 OH~ 630168 O0 000 O0 0 5 1 1 4 68 0000000000 RP LW1 OH~I 630168 O0 000 O0 0 5 1 1 4 68 0000000000 DER LW1 OP~4~ 630168 O0 000 O0 0 5 1 1 4 68 0000000000 ROP LW1 FPHR 630168 O0 000 O0 0 5 1 1 4 68 0000000000 GR LW1 GAPI 630168 O0 000 O0 0 5 1 1 4 68 0000000000 RHOB LW1 G/C3 630168 O0 000 O0 0 5 1 1 4 68 0000000000 DRHO LW1 G/C3 630168 O0 000 O0 0 5 1 1 4 68 0000000000 PEF LW1 BN/E 630168 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI LW1 PU-S 630168 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 12236. 500 RA. LW1 -999. 250 RP. LW1 - 999. 250 DER. LW1 ROP.LW1 56. 605 GR.LW1 -999.250 RHOB.LW1 -999.250 DRHO.LW1 PEF. LW1 -999. 250 NPHI. LW1 -999. 250 DEPT. 12000. 000 RA. LW1 4. 999 RP. LW1 7. 682 DER. LW1 ROP.LW1 116.206 GR.LW1 109.116 RHOB.LW1 -999.250 DRHO.LW1 PEF. LW1 -999. 250 NPHI. LW1 -999. 250 -999.250 -999.250 6.830 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:22 PAGE: 17 DEPT. 11000 . 000 RA . LW1 ROP. LW1 184. 323 GR. LW1 PEF.LW1 3.187 NPHI.LW1 DEPT. 10000. 000 RA. LW1 ROP . LW1 34. 951 GR. LW1 PEF. LW1 2. 525 NPHI. LW1 DEPT. 9000. 000 RA. LW1 ROP . LW1 346. 369 GR. LW1 PEF.LW1 11. 791 NPHI.LW1 DEPT. 8000. 000 RA. LW1 ROP. LW1 373. 570 GR. LW1 PEF.LW1 9. 649 NPHI.LW1 DEPT. 7000. 000 RA. LW1 ROP. LW1 222. 875 GR. LW1 PEF. LW1 12.124 NPHI.LW1 DEPT. 6000. 000 RA. LW1 ROP. LW1 243. 097 GR. LW1 PEF. LW1 8. 991 NPHI. LW1 DEPT. 5000. 000 RA. LW1 ROP . LWI 368.544 GR. LW1 PEF.LW1 15.567 NPHI.LW1 DEPT. 4000. 000 RA. LW1 ROP . LW1 -999. 250 GR. LW1 PEF.LW1 12. 631 NPHI.LW1 DEPT. 3916. 500 RA . LWl ROP. LW1 -999. 250 GR. LW1 PEF. LW1 -999.250 NPHI.LW1 4. 289 RP. LW1 130. 340 RHOB. LW1 35.200 2.947 RP.LW1 80.381 RHOB.LW1 32,500 4.237 RP. LW1 140. 957 RHOB. LWl 37. 600 4.237 RP.LW1 106.636 RHOB.LW1 41.600 3. 751 RP. LW1 114. 231 RHOB . LW1 33. 400 3.751 RP.LW1 88.698 RHOB.LW1 39.600 3.445 RP. LW1 94. 505 RHOB. LW1 28. 800 0.124 RP.LW1 44.299 RHOB.LW1 35.000 -999. 250 RP. LW1 -999. 250 RHOB. LW1 33. 700 4.942 2.506 2.879 2.412 5.434 0.629 4.411 0.797 3.868 0.782 3. 793 O. 646 3.354 -0.360 8.932 0.456 -999.250 -999.250 DER.LW1 DRHO.LW1 DER. LW1 DRHO. LW1 DER. LW1 DRHO. LW1 DER. LW1 DRHO. LW1 DER. LW1 DRHO. LW1 DER. LW1 DRHO. LW1 DER. LW1 DRHO. LWl DER. LW1 DRHO. LW1 DER. LW1 DRHO. LW1 4. 692 O. 051 2. 902 0.115 5.135 -2. 660 4. 351 -2. 496 3. 827 -2. 642 3. 778 -2. 513 3. 384 -3. 601 O. 127 -3. 730 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:22 PAGE: 18 **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION : O01CO1 DATE : 96/07/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LOG HEADER DATA FILE HEADER FILE NUMBER 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SD?4~iARY VENDOR TOOL CODE START DEPTH STOP DEPTH 12049.0 13161.0 DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (M~MORY or REAL-TI~i~) : TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (?T) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR CDN NEUT./DENS. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: 08-MAY-96 FAST2.5 4.0 MEMORY 13161.0 3968.0 13161.0 65 47.0 65.8 TOOL NUMBER RGS059 NDS086 8.500 4042.0 LSND 10.50 47.0 9.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:22 PAGE: 19 MUD CHLORIDES (PPM) : 500 FLUID LOSS (C3): 5.2 RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 3. 690 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2. 920 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: ** RUN 1 DRILLED INTERVAL 4045' - 12237'**** RES TO BIT.. 64.52'; GR TO BIT: 74.94' NEUT TO BIT: 124.56'; DENS TO BIT: 117.58' ** RUN 1 DRILLED INTERVAL 12237' - 13161'**** RES TO BIT: 42.52'; GR TO BIT: 52.94' NEUT TO BIT: 102.44'; DENS TO BIT: 95.46' CDN RUN 1 DATA BAD DUE TO TOOL FAILURE RELOGGED 9433' TO 9893'; 11000' TO 11585' $ LIS FORMAT DATA 74.0 74.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:22 PAGE: 20 ** SET TYPE - CHAN ** NAi~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) 630168 O0 000 O0 0 6 1 1 4 68 0000000000 DEPT FT RA LW2 OH~ 630168 O0 000 O0 0 6 1 1 4 68 0000000000 RP LW2 OH~f 630168 O0 000 O0 0 6 1 1 4 68 0000000000 DER LW2 OH~ 630168 O0 000 O0 0 6 1 1 4 68 0000000000 ROP LW2 FPHR 630168 O0 000 O0 0 6 1 1 4 68 0000000000 GR LW2 GAPI 630168 O0 000 O0 0 6 1 1 4 68 0000000000 RHOB LW2 G/C3 630168 O0 000 O0 0 6 1 1 4 68 0000000000 DRHO LW2 G/C3 630168 O0 000 O0 0 6 1 1 4 68 0000000000 PEF LW2 BN/E 630168 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI LW2 PU-S 630168 O0 000 O0 0 6 1 1 4 68 0000000000 CALN LW2 IN 630168 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 13160.500 ROP.LW2 20.692 PEF.LW2 -999.250 DEPT. 13000. 000 ROP. LW2 68. 563 PEF. LW2 3 . 352 DEPT. 12049.000 ROP.LW2 -999.250 PEF. LW2 -999.250 RA. LW2 -999. 250 RP. LW2 - 999. 250 DER. LW2 GR.LW2 -999.250 RHOB.LW2 -999.250 DRHO.LW2 NPHI.LW2 -999.250 CALN. LW2 -999.250 RA. LW2 5. 091 RP. LW2 5. 047 DER. LW2 GR. LW2 85. 650 RHOB. LW2 2. 491 DRHO. LW2 NPHI.LW2 28. 900 CALN. LW2 8. 803 RA.LW2 -999.250 RP.LW2 -999.250 DER.LW2 GR.LW2 -999.250 RHOB.LW2 -999.250 DRHO.LW2 NPHI.LW2 30.800 CALN. LW2 -999.250 -999.250 -999.250 5. 062 -0. 003 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:22 PAGE: 21 **** FILE HEADER **** FILE NAI~E : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~ER 7 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN ~ER: 1 MAD PASS NUMBER: 1 DEPTH INCREfflENT: O. 5000 FILE SUI~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 9425.0 9890.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR CDN NEUT./DENS. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) MUD VISCOSITY (S) : 08-MAY-96 FAST2. 4.0 MEMORY 13161. 3968. 13161. 65 47.0 65.8 TOOL NUMBER ........... RGS059 NDS057 8.500 4042.0 LSND 10.50 47.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:zz PAGE: 22 MUD PH: 9.5 MUD CHLORIDES (PPM) : 500 FLUID LOSS (C3): 5.2 RESISTIVITY (OPff4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 3. 690 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2.920 MUD CAKE AT (MT): NEUTRON TOOL MA TRIX: SANDS TONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: ** RUN 1 DRILLED INTERVAL 4045' - 12237'**** RES TO BIT: 64.52'; GR TO BIT: 74.94 ' NEUT TO BIT: 124.56'; DENS TO BIT: 117.58' ** RUN 1 DRILLED INTERVAL 12237' - 13161'**** RES TO BIT: 42.52'; GR TO BIT: 52.94 ' NEUT TO BIT: 102.44'; DENS TO BIT: 95.46' CDN RUN 1 DATA BAD DUE TO TOOL FAILURE RELOGGED 9433' TO 9893'; 11000' TO 11585' $ LIS FORMAT DATA 74.0 74.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:~2 PAGE: 23 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630168 O0 000 O0 0 7 1 1 4 68 0000000000 ATR MAi OPiMM 630168 O0 000 O0 0 7 1 1 4 68 0000000000 PSR MAI OPiMM 630168 O0 000 O0 0 7 1 1 4 68 0000000000 ROPE MA1 F/HR 630168 O0 000 O0 0 7 1 1 4 68 0000000000 GR MAI GAPI 630168 O0 000 O0 0 7 1 1 4 68 0000000000 DER MAI OH~ 630168 O0 000 O0 0 7 1 1 4 68 0000000000 RHOBMA1 G/C3 630168 O0 000 O0 0 7 1 1 4 68 0000000000 DRHOMA1 G/C3 630168 O0 000 O0 0 7 1 1 4 68 0000000000 PEF MAi BN/E 630168 O0 000 O0 0 7 1 1 4 68 0000000000 NPHIMA1 PU-S 630168 O0 000 O0 0 7 1 1 4 68 0000000000 CALNMA1 IN 630168 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 9890.500 ATR.MA1 -999.250 PSR.MA1 -999.250 ROPE.MAI GR.MA1 -999.250 DER.MAi -999.250 RHOB.MA1 -999.250 DRHO.MA1 PEF.MA1 -999.250 NPHI.MA1 -999.250 CALN. MA1 -999.250 DEPT. 9425.000 ATR.MA1 -999.250 PSR.MA1 -999.250 ROPE.MAI GR.MA1 -999.250 DER.MAi -999.250 RHOB.MA1 -999.250 DRHO.MA1 PEF.MA1 -999.250 NPHI.MA1 34.700 CALN. MA1 -999.250 2577.741 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE · FLIC VERSION · O01CO1 DATE · 96/07/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION · O01CO1 DATE : 96/07/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:~2 PAGE: 24 FILE HEADER FILE NI]Ai~ER 8 RAW MAD Curves and log header data for each pass of each run in separate files. MAD RUN NUMBER: 1 MAD PASS NUPIBER: 2 DEPTH INCR124F2VT: 0.5000 FILE SUM~zARY VENDOR TOOL CODE START DEPTH MAD 10825.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11584.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR CDN NEUT./DENS. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OP2V~I) AT TEMPERATURE (DEGF) : MUD AT MEASURED TE~IPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: 08-MAY-96 FAST2.5 4.0 MEMORY 13161.0 3968.0 13161.0 65 47.0 65.8 TOOL NUMBER ........... RGS059 NDS086 8.500 4042.0 LSND 10.50 47.0 9.5 5OO 5.2 3.690 74.0 2. 920 74.0 SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14 PAGE: 25 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: ** RUN 1 DRILLED INTERVAL 4045' - 12237'**** RES TO BIT: 64.52'; GR TO BIT: 74.94 ' NEUT TO BIT: 124.56'; DENS TO BIT: 117.58' ** RUN 1 DRILLED INTERVAL 12237' ~ 13161'**** RES TO BIT: 42.52'; GR TO BIT: 52.94 ' NEUT TO BIT: 102.44'; DENS TO BIT: 95.46' CDN RUN 1 DATA BAD DUE TO TOOL FAILURE RELOGGED 9433' TO 9893'; 11000' TO 11585' $ LIS FOPdVlAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 66 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 44 1 0.5 FT 23 0 FT 68 1 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 630168 O0 000 O0 0 8 1 1 4 68 0000000000 ATR MA2 OIff4~630168 O0 000 O0 0 8 1 1 4 68 0000000000 PSR MA2 OH~4M 630168 O0 000 O0 0 8 1 1 4 68 0000000000 ROPE MA2 F/HR 630168 O0 000 O0 0 8 1 1 4 68 0000000000 GR MA2 GAPI 630168 O0 000 O0 0 8 1 1 4 68 0000000000 DER MA2 OP~4M 630168 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14 ~ ~z PAGE: 26 NAI~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RHOBMA2 G/C3 630168 O0 000 O0 0 8 1 1 4 68 0000000000 DRHOMA2 G/C3 630168 O0 000 O0 0 8 1 1 4 68 0000000000 PEF MA2 BN/E 630168 O0 000 O0 0 8 1 1 4 68 0000000000 NPHIMA2 PU-S 630168 O0 000 O0 0 8 1 1 4 68 0000000000 CALNMA2 IN 630168 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 11584.500 ATR.MA2 -999.250 PSR.MA2 -999.250 ROPE.MA2 93.742 GR.MA2 -999.250 DER.MA2 -999.250 RHOB.MA2 -999.250 DRHO.MA2 -999.250 PEF.MA2 -999.250 NPHI.MA2 -999.250 CALN.MA2 -999.250 DEPT. 11000.000 ATR.MA2 4.237 PSR.MA2 5.036 ROPE.MA2 542.994 GR.MA2 114.223 DER.MA2 4.837 RHOB.MA2 2.243 DRHO.MA2 0.043 PEF.MA2 4.985 NPHI.MA2 38.000 CALN.MA2 9.686 DEPT. 10825.500 ATR.MA2 -999.250 PSR.MA2 -999.250 ROPE.MA2 -999.250 GR.MA2 -999.250 DER.MA2 -999.250 RHOB.MA2 -999.250 DRHO.MA2 -999.250 PEF. MA2 -999.250 NPHI.MA2 34.700 CALN.MA2 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 96/07/24 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/07/24 ORIGIN : FLIC TAPE NA~E : 96171 CONTINUATION # : 1 PREVIOUS TAPE : COMF~f : ARCO ALASKA, INC.,KUPARUK 2M-31,API # 50-103-20241-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 24-JUL-1996 14:~2 PAGE: 27 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/07/24 ORIGIN .. FLIC REEL NAME : 96171 CONTINUATION # : PREVIOUS REEL : COf4FiFJ~T : ARCO ALASKA, INC. ,KUPARUK 2M-31,API # 50-103-20241-00