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HomeMy WebLinkAbout185-248CAUTION: 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 2A-08 (PTD#185-248) Increasing IA Pressure Date:Tuesday, October 29, 2024 8:47:43 AM Attachments:AnnComm Surveillance TIO for 2A-08.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Tuesday, October 29, 2024 7:29 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: KRU 2A-08 (PTD#185-248) Increasing IA Pressure Hi Chris, CPAI has concluded our diagnostics and monitoring of KRU 2A-08 (PTD 185-248) is a WAG injector currently on Produced Water injection and confirmed no observations of annular communication. The TIO plot and well schematic are attached. Please let me know if you have any questions. Thanks, Jaime From: Well Integrity Specialist CPF2 Sent: Thursday, September 26, 2024 3:12 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2A-08 (PTD#185-248) Increasing IA Pressure Hi Chris, KRU 2A-08 (PTD 185-248) is a WAG injector currently on Produced Water injection. The IA pressure increased toward tubing pressure on 9/25/24 without an obvious cause. CPAI plans to conduct initial diagnostics and monitoring to confirm any annular communication. The IA pressure is currently 1450 psi and the well head injection pressure is 1591 psi. Please let me know if you have any questions or disagree with the plan. The TIO plot and well schematic are attached. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2A-08 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2A-08 2024-08-24 1800 850 -950 IA 2A-08 2024-09-01 1200 500 -700 IA 2A-08 2024-09-26 1550 700 -850 IA 2A-08 2024-09-27 620 320 -300 IA 2A-08 2024-10-01 360 175 -185 IA 2A-08 2024-10-02 200 45 -155 IA 2A-08 2024-10-03 1 500 499 IA Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: RKB 8,317.0 2/23/2019 2A-08 fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Tag, CV Swap 2/23/2019 2A-08 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 34.0 Set Depth (ftKB) 110.0 Set Depth (TVD)… 110.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 34.7 Set Depth (ftKB) 3,405.7 Set Depth (TVD)… 2,787.0 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION TIE- BACK OD (in) 7 ID (in) 6.28 Top (ftKB) 35.4 Set Depth (ftKB) 649.0 Set Depth (TVD)… 648.5 Wt/Len (l… 26.00 Grade L-80 Top Thread TC-II Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 649.0 Set Depth (ftKB) 8,459.4 Set Depth (TVD)… 6,151.5 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING WO Upper String Ma… 3 1/2 ID (in) 2.92 Top (ftKB) 24.4 Set Depth (ft… 8,165.7 Set Depth (TVD) (… 5,919.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 24.4 24.4 0.00 HANGER FMC GEN 3 TUBING HANGER 3.500 492.0 491.91.05 NIPPLE CAMCO DS NIPPLE 2.813 7,888.5 5,709.4 43.12 LOCATOR BAKER 4.5" LOCATOR SUB + 7' FOR SPACE OUT 3.000 7,895.7 5,714.7 42.61 PBR PBR 80-40 6 PINS SET @ 40K 3.000 7,918.8 5,731.7 42.74 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 8,082.4 5,855.0 39.89 BLAST JT BAKER BLAST JOINTS (2) 4.5" OD 3.000 8,148.6 5,905.938.83 SLEEVE BAKER SLIDING SLEEVE, "X "PROFILE 2.812 8,158.9 5,913.938.84LOCATOR BAKER 80-40 GBH-22 LOCATOR SUB 2.990 8,159.7 5,914.5 38.85 SEAL ASSY BAKER SEAL ASSEMBLY w/ 5.98' STROKE w/ MULE SHOE 2.970 8,165.2 5,918.8 38.89 SHOE MULE SHOE 2.990 Tubing Description TUBING WO Lower String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 8,158.7 Set Depth (ft… 8,177.5 Set Depth (TVD) (… 5,928.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 8,158.7 5,913.8 38.84 PACKER BAKER 85-40 FB-1 PACKER 4.000 8,162.1 5,916.4 38.87 SBE BAKER GBH-22 SEAL BORE EXTENSION 4.000 8,166.5 5,919.8 38.91 GUIDE BOTTOM B GUIDE 4.000 8,171.7 5,923.9 38.90 NIPPLE HES X PROFILE NIPPLE 2.813 8,176.9 5,928.038.90 WLEG BAKER WIRELINE GUIDE 3.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 8,076.08,139.0 5,850.1 5,898.4 C-4, 2A-08 11/7/1985 12.0 IPERF 120 deg. phasing; SOS Csg Gun 8,185.08,214.0 5,934.2 5,956.8 A-3, 2A-08 11/7/19854.0 IPERF 90 deg. phasing; SOS Csg Gun 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 7,832.6 5,669.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/30/2012 2 8,032.6 5,816.9 CAMCO MMG 1 1/2 GAS LIFT HFCV RK 0.500 0.0 2/23/2019 Notes: General & Safety End Date Annotation 9/8/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLE 2A-08, 2/24/2019 7:16:36 AM Vertical schematic (actual) PRODUCTION; 649.0-8,459.4 IPERF; 8,185.0-8,214.0 WLEG; 8,176.9 NIPPLE; 8,171.7 GUIDE; 8,166.5 SHOE; 8,165.2 SBE; 8,162.1 SEAL ASSY; 8,159.7 PACKER; 8,158.7 LOCATOR; 8,158.9 SLEEVE; 8,148.6 IPERF; 8,076.0-8,139.0 GAS LIFT; 8,032.6 PACKER; 7,918.8 PBR; 7,895.7 LOCATOR; 7,888.5 GAS LIFT; 7,832.6 SURFACE; 34.7-3,405.7 PRODUCTION TIE-BACK; 35.4- 649.0 NIPPLE; 492.0 CONDUCTOR; 34.0-110.0 HANGER; 24.4 KUP INJ KB-Grd (ft) 41.20 Rig Release Date 10/31/1985 Annotation Last WO: End Date 10/21/2012 2A-08 H2S (ppm)Date... TD Act Btm (ftKB) 8,500.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032004900 Wellbore Status INJ Max Angle & MD Incl (°) 53.68 MD (ftKB) 7,325.00 WELLNAME WELLBORE 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 2A-08 (PTD#185-248) Increasing IA Pressure Date:Monday, September 30, 2024 9:42:32 AM Attachments:AnnComm Surveillance TIO for 2A-08.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, September 26, 2024 3:12 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2A-08 (PTD#185-248) Increasing IA Pressure Hi Chris, KRU 2A-08 (PTD 185-248) is a WAG injector currently on Produced Water injection. The IA pressure increased toward tubing pressure on 9/25/24 without an obvious cause. CPAI plans to conduct initial diagnostics and monitoring to confirm any annular communication. The IA pressure is currently 1450 psi and the well head injection pressure is 1591 psi. Please let me know if you have any questions or disagree with the plan. The TIO plot and well schematic are attached. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2A-08 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2A-08 2024-06-28 2200 600 -1600 IA 2A-08 2024-08-24 1800 850 -950 IA 2A-08 2024-09-01 1200 500 -700 IA Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By Last Tag: RKB 8,317.0 2/23/2019 2A-08 fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Tag, CV Swap 2/23/2019 2A-08 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 34.0 Set Depth (ftKB) 110.0 Set Depth (TVD)… 110.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 34.7 Set Depth (ftKB) 3,405.7 Set Depth (TVD)… 2,787.0 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION TIE- BACK OD (in) 7 ID (in) 6.28 Top (ftKB) 35.4 Set Depth (ftKB) 649.0 Set Depth (TVD)… 648.5 Wt/Len (l… 26.00 Grade L-80 Top Thread TC-II Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 649.0 Set Depth (ftKB) 8,459.4 Set Depth (TVD)… 6,151.5 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING WO Upper String Ma… 3 1/2 ID (in) 2.92 Top (ftKB) 24.4 Set Depth (ft… 8,165.7 Set Depth (TVD) (… 5,919.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE-8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 24.4 24.4 0.00 HANGER FMC GEN 3 TUBING HANGER 3.500 492.0 491.91.05 NIPPLE CAMCO DS NIPPLE 2.813 7,888.5 5,709.4 43.12 LOCATOR BAKER 4.5" LOCATOR SUB + 7' FOR SPACE OUT 3.000 7,895.7 5,714.7 42.61 PBR PBR 80-40 6 PINS SET @ 40K 3.000 7,918.8 5,731.7 42.74 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 8,082.4 5,855.0 39.89 BLAST JT BAKER BLAST JOINTS (2) 4.5" OD 3.000 8,148.6 5,905.938.83 SLEEVE BAKER SLIDING SLEEVE, "X "PROFILE 2.812 8,158.9 5,913.938.84LOCATOR BAKER 80-40 GBH-22 LOCATOR SUB 2.990 8,159.7 5,914.5 38.85 SEAL ASSY BAKER SEAL ASSEMBLY w/ 5.98' STROKE w/ MULE SHOE 2.970 8,165.2 5,918.8 38.89 SHOE MULE SHOE 2.990 Tubing Description TUBING WO Lower String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 8,158.7 Set Depth (ft… 8,177.5 Set Depth (TVD) (… 5,928.4 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 8,158.7 5,913.8 38.84 PACKER BAKER 85-40 FB-1 PACKER 4.000 8,162.1 5,916.4 38.87 SBE BAKER GBH-22 SEAL BORE EXTENSION 4.000 8,166.5 5,919.8 38.91 GUIDE BOTTOM B GUIDE 4.000 8,171.7 5,923.9 38.90 NIPPLE HES X PROFILE NIPPLE 2.813 8,176.9 5,928.038.90 WLEG BAKER WIRELINE GUIDE 3.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft )Type Com 8,076.08,139.0 5,850.1 5,898.4 C-4, 2A-08 11/7/1985 12.0 IPERF 120 deg. phasing; SOS Csg Gun 8,185.08,214.0 5,934.2 5,956.8 A-3, 2A-08 11/7/19854.0 IPERF 90 deg. phasing; SOS Csg Gun 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 7,832.6 5,669.0 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/30/2012 2 8,032.6 5,816.9 CAMCO MMG 1 1/2 GAS LIFT HFCV RK 0.500 0.0 2/23/2019 Notes: General & Safety End Date Annotation 9/8/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLE 2A-08, 2/24/2019 7:16:36 AM Vertical schematic (actual) PRODUCTION; 649.0-8,459.4 IPERF; 8,185.0-8,214.0 WLEG; 8,176.9 NIPPLE; 8,171.7 GUIDE; 8,166.5 SHOE; 8,165.2 SBE; 8,162.1 SEAL ASSY; 8,159.7 PACKER; 8,158.7 LOCATOR; 8,158.9 SLEEVE; 8,148.6 IPERF; 8,076.0-8,139.0 GAS LIFT; 8,032.6 PACKER; 7,918.8 PBR; 7,895.7 LOCATOR; 7,888.5 GAS LIFT; 7,832.6 SURFACE; 34.7-3,405.7 PRODUCTION TIE-BACK; 35.4- 649.0 NIPPLE; 492.0 CONDUCTOR; 34.0-110.0 HANGER; 24.4 KUP INJ KB-Grd (ft) 41.20 Rig Release Date 10/31/1985 Annotation Last WO: End Date 10/21/2012 2A-08 H2S (ppm)Date... TD Act Btm (ftKB) 8,500.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032004900 Wellbore Status INJ Max Angle & MD Incl (°) 53.68 MD (ftKB) 7,325.00 WELLNAME WELLBORE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 1, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2A-08 KUPARUK RIV UNIT 2A-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/01/2024 2A-08 50-103-20049-00-00 185-248-0 W SPT 5732 1852480 1500 1775 1775 1775 1775 20 20 20 20 4YRTST P Adam Earl 5/19/2024 4-year MIT-IA 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 2A-08 Inspection Date: Tubing OA Packer Depth 900 2500 2450 2440IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240521072237 BBL Pumped:1.6 BBL Returned:1.4 Monday, July 1, 2024 Page 1 of 1               185-248 T38926 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.13 08:40:17 -08'00' MEMORANDUM State of Alaska Depth Pretest Alaska Oil and Gas Conservation Commission To: Jim Regg 161 r111 DATE: Monday, May 11, 2020 P.I. Supervisor \ i SUBJECT: Mechanical Integrity Tests 5732 '- ConocoPhillips Alaska, Inc. 2A-08 FROM: Guy Cook KUPARUK RIV UNIT 2A-08 Petroleum Inspector st .TVD SPT Test l Src: Inspector Reviewed By: 3010 - P.I. Suprvjto-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2A-08 API Well Number 50-103-20049-00-00 Inspector Name: Guy Cook Permit Number: 185-248-0 Inspection Date: 5/6/2020 Insp Num: mitGDC200507160113 Rel Insp Num: Monday, May 11, 2020 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min II Well zA-o8 a In� � bV YP J � 5732 '- TUbin Tubing 1852480 '!Type st .TVD SPT Test l 1200. i 6608 3010 - 29020 - I 29010 BBL Pumped: _ BBL Returned: 'i 0A 50 } So So � _ So -- Interval 4YRTST 1P�F P -- Notes: Testing was done with a Little Red Services pump truck and calibrated gauges. Monday, May 11, 2020 Page 1 of 1 Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: r 4i AOGCC +. ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 1852 8 30 71 7 TRANSMITTAL DATE �- I` TRANSMITTAL# i Please return via courier or sign/scan and email a copy Date Schlumberger and CPAI. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. SERVICE ORDER NAME 1A -04A 2A-09 1R-07 50.029.20621-01 50-103.20059.00 50-029-21332-00 EBNL-00001 EOSH-00041 EOSH-00042 FIELDWELL NAME KUPARUK RIVER I KUPARUK RIVER KUPARUK RIVER DESCRIPTION r WL WL WL r Caliper Rev1 Caliper Caliper P DATA TYPE FINAL FIELD FINAL FIELD FINAL FIELD Color DATELOGGED Prints 4 -Apr -19 17 -Apr -19 18 -Apr -19 CV5 1 1 1 2A-08 1y-11 50.103-20049-00 50-029.20926-00 DWUJ•00092 EBNL-00016 KUPARUK RIVER KUPARUK RIVER WL WL IPROF LDL FINAL FIELD FINAL FIELD 28 -Apr -19 28 -Apr -19 1 1 2B-07 1A-01 2X•10 50.029-21080-00 50.029-20590-00 50.029-21187-00 DWUJ-00093 EBNL-00018 DWUJ-00094 KUPARUK RIVER KUPARUK RIVER RIVER KUPARUKWL WL WL W ]PROF PPROF PPROF PPROF FINAL FIELD FINAL FIELD FINAL FIELD 29-AprA9 30 -Apr -19 30 -Apr -19 1 1 1 3H-21 2S-315 50-103.20094-00 50-103-20776.00 EBSI-00004 EBNL-00020 KUPARUK RIVER KUPARUK RIVER WL WL Caliper PPROF FINAL FIELD FINAL FIELD 3 -May -19 5 -May -19 1 1 10 Please return via courier or sign/scan and email a copy Date Schlumberger and CPAI. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,May 09,2016 TO: Jim Regg P.I.Supervisor c Z41I SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2A-08 FROM: Johnnie Hill KUPARUK RIV UNIT 2A-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2A-08 API Well Number 50-103-20049-00-00 Inspector Name: Johnnie Hill Permit Number: 185-248-0 Inspection Date: 5/7/2016 Insp Num: mitJWH160508214023 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2950- 2950 - 2950 W2A-08 ',Type Inj G TVD s7sz �Tubing� 2950 PTD 1852480 'Type Test;SPT Test psi Isoo . I IA 600 2000 - 1965 -r 1960 _ Interval14YRTST P/F P I OA - Notes: 1.3 bbls of diesel - SCANNED SEP 2 7 2016 Monday,May 09,2016 Page 1 of 1 STATE OF ALASKA 1 ALADA OIL AND GAS CONSERVATION CONOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Plug Plrrf orations r FFrf orate fl Other Subsidence Repair Alter Casing jW Pull Tubing 17 Stimulate-Frac r Waiver r Time Extension "' Change Approved Program r Operat.Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 185-248 3.Address: 6.API Number: Stratigraphic r Service 50-103-20049-00^ P. O. Box 100360,Anchorage,Alaska 99510 7.Property Designation(Lease Number): 8.Well Name and Number: ., ADL 25570 2A-08 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8500 feet Plugs(measured) None true vertical 6184 feet Junk(measured) None Effective Depth measured feet Packer(measured) 7919,8159 true vertical feet (true vertucal) 5732,5914 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 16 110 110 SURFACE 3371 9.625 3406 2787 PRODUCTION 8427 7 8459 6152 RECEIVED N� �y ZD NOV 152012 S' Perforation depth: Measured depth: 8076'-8139',8185'-8214' AOGC True Vertical Depth: 5850'-5899', 5934'-5956' Tubing(size,grade,MD,and ND) 3.5,J-55,8186 MD,5934 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL RETRIEVABLE PACKER @ 7919 MD and 5732 ND PACKER-BAKER FB-1 PACKER @ 8159 MD and 5914 TVD SSSV-CAMCO DS NIPPLE @ 492 MD and 492 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation 2600 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service j7 Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG 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 r/ 312-333 Contact Erik Nelson 263-4693 Email Erik.Nelsona,conocodhillips.com Printed Name Frik elson Title Wells Engineer Signature Phone:263-4693 Date Form 10-404 Revised 11/2011 RaDMS NOV 15 2012 fit► //27•a_Submit Original Only .401k/fle7, i KUP 2A-08 ConocoPhillips 011 Well Attributes Max Angle&MD TD Al.It k_ 1/I Wel!bore API/UWI Field Name Well Status Inc!p) MD(ftKB) Act Btm(ftKB) care ■PldNps 501032004900 KUPARUK RIVER UNIT INJ 5168 7,325.00 8,500.0 "° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' _SSSV:NIPPLE Last WO: 10/21/2012 41.20 10/31/1985 Well Comas -2A-08.11/11/20122'.32'.14 PM schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WORKOVER ninam 11/3/2012 Casing Strings HANGER.24 ".r ..." Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String.. String Top Thrd Illi CONDUCTOR 16 15.060 34.0 110.0 110.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(15(B) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 9 5/8 8.765 34.7 3,405.7 2,787.0 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 35.4 649.0 648.5 26.00 L-80 TC-II Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 1 PRODUCTION 7 6.276 649.0 8,459.4 6,151.5 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)... String Wt...String... String Top Thrd Upper Completion 31/2 2.922 24.4 8,165.7 5,919.2 9.30 L-80 EUE-8rd - Completion Details Top Depth CONDUCTOR, (TVD) Top Inc! Nomi... 39-110 Top(ftKB) (ftKB) Ii Item Description Comment ID(in) 11111 24.4 24.4 -1.77 HANGER FMC GEN 3 TUBING HANGER 3.500 NIPPLE.492 492.0 491.9 1.05 NIPPLE CAMCO DS NIPPLE 2.813.ailt 7,888.5 5,709.4 43.12 LOCATOR BAKER 4.5"LOCATOR SUB+7'FOR SPACE OUT 3.010 7,895.7 5,714.7 42.61 PBR PBR 80-40 6 PINS SET @ 40K 3.000 7,918.8 5,731.7 43.17 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 8,082.4 5,855.0 39.89 BLAST JT BAKER BLAST JOINTS,4.5"OD 3.000 • 8,148.6 5,905.9 38.83 SLEEVE BAKER SLIDING SLEEVE 2.812 PRODUCTION, 8,158.9 5,913.9 38.92 LOCATOR BAKER 80-40 GBH-22 LOCATOR SUB 2.990 35-849 8,159.7 5,914.5 38.92 SEAL ASSY BAKER SEAL ASSEMBLY w/5.98'STROKE w/MULE SHOE 2.970 8,165.2 5,918.8 38.91 MULE SHOE MULE SHOE 2.990 Tubing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(TVD)...String Wt...String...String Top Thrd Lower Completion 3.52 3.010 8,158.7 8,177.5 5,928.4 9.30 L-80 EUE Completion Details Top Depth I (TVD) Top Inc! Norni... • SURFACE, Top(ftKB) (ftKB) El Item Description Comment ID(in) 35-3,406 - 8,158.7 5,913.8 38.92 PACKER BAKER 85-40 FB-1 PACKER 4.000 Mk 8,162.1 5,916.4 38.92 SBE BAKER GBH-22 SEAL BORE EXTENSION 4.000 GAS 71833 8,166.5 5,919.8 38.91 GUIDE BOTTOM B GUIDE 4.000 p 8,171.7 5,924.0 39.32 NIPPLE HES X PROFILE NIPPLE 2.813 8,177.0 5,928.1 39.24 WLEG BAKER WIRELINE GUIDE 3.000 LOCATOR, 7,868 Perforations&Slots PBR,7,896 Shot PACKER,7,919 Top(TVD) Btm(TVD) Dens Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (ah..• Type Comment 8,076 8,139 5,850.1 5,898.5 C-4,2A-08 11/7/1985 12.0 IPERF 120 deg.phasing;SOS Csg Gun 8,185 8,214 5,934.3 5,956.2 A-3,2A-08 11/7/1985 4.0 IPERF 90 deg.phasing;SOS Csg Gun Notes:General&Safety End Date Annotation 9/8/2010 NOTE:View Schematic w/Alaska Schematic9.0 IIIII GAS LIFT, 8,033 IPERF, 8.078-8,139 SLEEVE.8.149 LOCATOR, 8.159 R. 1Wil PACKER,8,159 r SEAL A,100 8,180 SBE,8,182 MULE SHOE. 8.165 GUIDE.8.107 Mandrel Details IIIIII Top Depth Top Port NIPPLE,8,172 WIL (TVD) not OD Valve Latch Sine TRO Run Stn Top(ftKB) (ftKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Corn... 1 7,832.6 5,669.1 44.72 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/30/2012 WLEG,8,177 t 2 8,032.6 5,816.9 40.31 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/17/2012 IPERF, 8.1858,214 PRODUCTION. 649-8,459 TD.8.500 DATE SUMMARYOPS 2A-08 Pre and Post Rig Well Work 7/25/12 PRE-RIG T POT(PASSED)itPOT(FAILED) IC-POT(PASSED) IC-PNT(PASSED) FUNCTION ALL LDS ALL NO AL. 9/1/12 DRIFT TBG WITH 2.77" DUMMY WRP TO 7998' SLM. PULLED WRP @ 8032' RKB. DRIFT TBG W/2.25" DUMMY CA-2 PLUG TO 8138' SLM. MEASURED BHP(2649 psi) @ 8185' RKB. UNABLE TO SET CA-2 PLUG (APPEARS TO BE X-FLOW). DRIFTED TO TPI @ 8156' RKB W/BRUSH ASSEMBLY. IN PROGRESS. 9/2/12 SET 2.25" CA-2 PLUG @ 8179' RKB. CHASED 2.79"x 29"AVA CATCHER TO 8156' RKB TOP OF TPI ) . PULLED 1.5" DV @ 7943' RKB ( LEFT POCKET OPEN ) . READY FOR CIRC OUT. 9/10/12 ATTEMPT TO SET WRP WITH MID ELEMENT AT 8031'. INSPECT SETTING TOOL, FOUND THAT TOOL PARTED DOWN HOLE JUST BELOW FIRING HEAD AT THE THREADS OF THE POWER CHAMBER, LEAVING A PARTIAL SETTING TOOL AND WRP STILL IN HOLE. UNSURE IF PLUG IS FULLY SET OR IF SETTING TOOL IS SHEARED FREE OF WRP. LENGTH OF FISH LEFT IN THE HOLE IS 95". �Q 9/13/12 FISHED E-LINE SETTING TOOL&WRP. READY FOR E-LINE. \4 9/14/12 RUN#1: RAN WEATHERFORD 2.69"WRP, TOOLSTRING OAL 33.55'x 2.69". SET PLUG AT 8031'. LOG CORRELATED TO TUBING DETAIL RECORD DATED 08 NOV 1985. RUN#2: RAN RCT 2500-200, TOOLSTRING OAL 44.08'x 2.5". CUT TUBING AT 7966'. UNABLE TO MOVE AFTER CUTTING, ACTIVATED E-JARS AND PULLED TO 2500 LBS. PULLED OUT OF ROPE SOCKET LEAVING 1.375" FISHING NECK, SWIVEL, 7'WB, ROLLER, 7'WB, ROLLER, E-JAR, KNUCKLE, KNUCKLE, CENTRAILIZER, CCL, EMA, CENTRAILIZER, RCT, AND CENTRAILIZER IN THE HOLE. I°/)/ 9/15/12 FISHED E-LINE TOOLSTING FROM 7890' SLM. ALL COMPONENTS ACCOUNTED FOR. COMPLETE. 9/16/12 ATTEMPTED TO RECOVER 100 BBLS OF ISOTHERM FROM IA. SAMPLE SENT TO MI LAB FOR EVALUATION FOR REUSE. 10/30/12 SET CATCHER @-6-1-i0 SLM. PULLED SOV, REPLACED w/DV @ 7833' RKB. MIT TBG 2500 PSI, PASSED. MIT IA 3000 PSI, PASSED. PULLED CATCHER. IN PROGRESS. 10/31/12 MIT TBG 2500 PSI, PASSED. EQUALIZED& PULLED 2.81"XX PLUG @ 8172' RKB. n 7 MEASURED BHP @ 8185' RKB: 2730 PSI. COMPLETE. ijO • • Conoco Phillips lips Time Log & Summary WelAnew Web Reporting Report Well Name: 2A-08 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 10/1/2012 12:00:00 PM Rig Release: 10/21/2012 1:00:00 PM Time Logs Date From. To Dur S.Depth E.Depth Phase Code Subcode T Comment .. 09/30/2012 24 hr Summary Release rig move to 2A-08,split complexes,move pipe sheds,pits&motor complexes. Hold sub base at 2B pad and wait for drilling support to mat 2A access road.Move sub to 2A-08 and spot over well. Rig up. 00:00 12:00 12.00 MIRU MOVE MOB P Release rig move to 2A-08.Split complexes and move pipe sheds, pits&motor complexes to 2A pad. 12:00 00:00 12.00 MIRU MOVE MOB P Move sub base to 2B pad, hold sub base at 2B pad due to soft roads. Gather mats and mat the access road to 2A pad. 10/01/2012 Move sub in,spot over well,lay rig mats,spot complexes,rig accepted @ 1200 hrs,rig up tiger tank&hard lines, pull BPV,take on sea water to pits, Presure test lines t/2500psi,displace well to 8.5 ppg sea water, set BP V. N/D tree and N/U BOPE. 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Move Sub&pipe sheds f/2B pad t/ 2A pad,spot sub over well, lay mats spot complexes&rock washer,lay mats spot pipe sheds,work on rig acceptance. 12:00 13:45 1.75 0 0 MIRU MOVE OTHR P Rig accepted @ 1200 hrs,load pipe shed w/4"DP,take on sea water to pits,fill water tanks on rig, R/U lines in cellar. 13:45 14:45 1.00 0 0 MIRU WELCTL RURD P R/U scaffolding in cellar 14:45 15:30 0.75 0 0 MIRU WHDBO RURD P Continue R/U hard lines in cellar, P/U lubricator,strap DP. 15:30 17:00 1.50 0 0 MIRU WELCTL OTHR P R/U lubricator&test t/1500 psi,pull BPV 17:00 19:00 2.00 0 0 MIRU WELCTL RURD P Spot tiger tank R/U lines to dsiplace well 19:00 19:15 0.25 0 0 MIRU WELCTL SFTY P Pre job safety meeting on displacing well 19:15 21:30 2.25 0 0 MIRU WELCTL CIRC P Pressure test lines t/2500 psi, displace the well t/8.5 ppg sea water. Pumped 300 bbls of 8.5 ppg seawater @ 3 BPM-540 PSI ICP, 330 PSI FCP. 21:30 22:00 0.50 0 0 MIRU WELCTL OWFF P Monitor well f/30 minutes,static. 22:00 22:30 0.50 0 0 MIRU WHDBO OTHR P Set BPV w/dry rod. Blow down and rig down hard lines in cellar. 22:30 23:00 0.50 0 0 MIRU WHDBO RURD P Rig down scaffolding in cellar. 23:00 00:00 1.00 0 MIRU WHDBO NUND P PJSM, nipple down tree and nipple up BOP. 10/02/2012 Rig up and test bop's U 250 low 3500 high, Pull hanger and 3.5"completion string,strap&number all components to 4722'MD. Page 1 of 20 • • Time Logs Date -> From To Our S.Depth-E Depth Phase Code Subcode T ",Comment 00:00 01:30 1.50 0 0 MIRU WHDBO NUND P Continue Nipple Down tree&adaptor flange 01:30 02:15 0.75 0 0 MIRU WHDBO OTHR P Dress threads on hanger,install blanking plug. 02:15 06:15 4.00 0 0 MIRU WHDBO NUND P Nipple up adaptor flange&stack, hook up choke line. 06:15 07:45 1.50 0 0 MIRU WHDBO RURD P R/U t/test BOP fill satck&choke with water,pump air out of system. 07:45 14:00 6.25 0 0 MIRU WHDBO BOPE P Test choke valves 1-14,auto&man. !BOP, Upper Ann.&Blind Rams,4" demco, Man.&HCR choke&kill, 3.5&4"test jts.t/250 low 3500 high, acc.test.(Witness waived by state inspector Jeff Jones) 14:00 14:45 0.75 0 0 MIRU WHDBO RURD P R/D test equip.blow down lines,pull blanking plug. 14:45 15:15 0.50 0 0 MIRU WHDBOOTHR P Pull BPV 15:15 16:45 1.50 0 0 COMPZ RPCOM RURD P Rig up casing equip.&M/U landing jt.3-10'pups. 16:45 17:15 0.50 0 0 COMPZ RPCOM OTHR P Back out lock downs,pull tubing hanger to floor,P/U weight 88K w/ block wt. 35K,monitor well static. 17:15 18:30 1.25 0 7,966 COMPZ RPCOM CIRC P Circ 1.5 x hole volume down tbg @ 6 bpm=650 psi.Monitor well.Static. 18:30 00:00 5.50 7,966 4,720 COMPZ RPCOM PULL P UD tbg hanger,measurement top of hanger to rig floor=23.52',continue POOH with 3.5"9.3#J-55 EUE-Mod.completion string& jewlery, numbering and strapping all components to 4720'MD.(Got back all 25 stainless bands) 10/03/2012 Finish LID 3.5 tubing, R/U&test lower rams, P/U&Run scraper BHA tight spots observed f/300't/520' POOH stand back collars P/U HWDP RIH work through tight spots f/416't/660',continue RIH,tagged up at 7951'MD, Reverse circ 1.5 times volume, POOH to 3413'MD. 00:00 03:45 3.75 4,720 0 COMPZ RPCOM PULL P Continue t/L/D 3.5 tbg,250 jts, sssv, 1 glm,cut jt @ 14.30'25 ssb. 03:45 04:45 1.00 0 0 COMPZ RPCOM RURD P R/D tubing equipment 04:45 05:45 1.00 0 0 COMPZ WELLPF BOPE P R/U&test lower pipe rams T/250 low 3500 high, R/D test equip. 05:45 06:00 0.25 0 0 COMPZ WELLPF OTHR P Set wear ring 06:00 07:30 1.50 0 0 COMPZ WELLPF SLPC P Slip&cut drill line,service rig&top drive. 07:30 10:00 2.50 0 307 COMPZ WELLPF PULD P P/U BHA casing scraper T/307'tight spot tagged @ 300'work through 10:00 12:00 2.00 307 462 COMPZ WELLPF TRIP P Work pipe down to 462'w/2-7 down weight applied with top drive. 12:00 12:30 0.50 462 520 COMPZ WELLPF TRIP P Continue working pipe down T/520' MD taking more weight,20k down weight with top drive. 12:30 13:00 0.50 520 0 COMPZ WELLPF TRIP P POOH,stand back 3 drill collars 13:00 13:30 0.50 0 0 COMPZ WELLPF OTHR P Load shed w/9 jts of 4"hwdp strap and tally 13:30 13:45 0.25 0 416 COMPZ WELLPF TRIP P RIH w/4"HWDP&DP T/416' Page 2 of 20 • S Time Logs Date From To Dur S.Depth E.Depth Phase ,!Code Subcode T -Comment 13:45 14:30 0.75 416 660 COMPZ WELLPF TRIP P Work string F/416'T/660'taking 1-3K down weight 14:30 19:30 5.00 660 7,951 COMPZ WELLPF TRIP P Continue single in the hole F/660'T/ 7951'MD, Displacement calc=48.45 bbls,Act=47.25 bbls. 19:30 20:00 0.50 7,943 7,943 COMPZ WELLPF CIRC P Rig up to reverse circ. 20:00 21:15 1.25 7,943 7,943 COMPZ WELLPF CIRC P Reverse circ 1.5 times hole volume @ 6 bpm with 800 psi. 21:15 22:00 0.75 7,943 7,943 COMPZ WELLPF OWFF P Monitor well while R/D lines and bled OA off from 450 psi to 0 psi,blow down lines. 22:00 00:00 2.00 7,943 3,413 COMPZ WELLPF TRIP P PJSM, POOH F/7943'T/3413'MD. Displacement calc=24.3 bbls,Act= 25.67 bbls. 10/04/2012 Continue POOH t/surface, 10 K over pull @ 650', Nipple up shooting flange, R/U E-line test lubricator, E-line pack off failed retest failed, R/D E-line,rebuild pack off, make up new head test pack off head failed. Fix leaking seal on grease head,test,good, Log with RCBL,TOC @ 750'MD,Make up string shot and RIH to 662'and fire. 00:00 01:00 1.00 3,413 0 COMPZ WELLPF TRIP P PJSM,Continue POOH to surface, pulled 10K over at 650'MD. 01:00 01:45 0.75 0 0 COMPZ WELLPF PULD P UD BHA#2,clear rig floor. 01:45 04:00 2.25 0 0 COMPZ WELLPF OTHR P PJSM, HRW, N/D riser&flange, N/U shooting flange. 04:00 05:45 1.75 0 0 COMPZ WELLPF ELOG P PJSM, Rig up HES E-line. 05:45 08:00 2.25 0 0 COMPZ WELLPF ELOG T Test lubricator to 1000 psi,Failed, Pack-off head leaking, R/D lubricator inspect and reassemble, R/U and test again failed both times, R/D lubricator and disconnect pack-off head. 08:00 09:30 1.50 0 0 COMPZ WELLPF ELOG T Clean and dress Pack-off head, R/U and test to 1000 psi,failed. 09:30 12:00 2.50 0 0 COMPZ WELLPF ELOG T R/D lubricator and tools, Hot shot Pack-off head to 2A-pad 12:00 13:45 1.75 0 0 COMPZ WELLPF ELOG T PJSM,Wait on Halliburton grease head,work on MP2s and clean rig. 13:45 14:30 0.75 0 0 COMPZ WELLPF ELOG T R/U wire line, pressure test grease head found leak, R/D. 14:30 16:30 2.00 0 0 COMPZ WELLPF ELOG T Fix leak,weep hole on grease head leaking. 16:30 16:45 0.25 0 0 COMPZ WELLPF ELOG P R/U wire line and pressure tested to 1000 psi and chart same. (Good) 16:45 21:30 4.75 0 0 COMPZ WELLPF ELOG P RIH with HES E-line RCBL log to determine top of cement. / 21:30 00:00 2.50 0 0 COMPZ WELLPF ELOG P PJSM, R/D RCBL log tool,TOC__@_ 750'MD, M/U 240 grain string shot V / and RIH to 662'MD and fire shot. 10/05/2012 First string shot run failed, Ran second string shot successful, N/D shooting flange,M/U RBP and set @ 1215'MD,test same,dump sand, LID running tool,C/O rams and test, N/D BOP stack and tubing spool. 00:00 00:30 0.50 0 0 COMPZ WELLPF ELOG P POOH with 240 grain string shot, (Failed to fire) 00:30 01:30 1.00 0 0 COMPZ WELLPF ELOG T M/U second string shot&locate second collar above TOC and successful shot at 662'MD Page 3of20 • Time Logs Date :' From To Dur S:Depth E.Death Phase Code Subcode T Comment 01:30 02:30 1.00 0 0 COMPZ WELLPF ELOG P POOH and rig down E-line. 02:30 04:00 1.50 0 0 COMPZ WELLPF OTHR P PJSM, N/D shooting flange,N/U riser flange and bell nipple. 04:00 05:00 1.00 0 290 COMPZ WELLPF PULD P PJSM, P/U Baker RBP&M/U BHA to 290'MD. 05:00 08:00 3.00 290 1,215 COMPZ WELLPF MPSP P RIH to 458'started taking wt,screw into Top Drive taking 5-8K Top Drive wt.down to 900'RIH to 1230'MD and set RBP @ 1215'MD per Baker Rep. P/U=65K,S/0=45K. 08:00 08:30 0.50 1,215 1,215 COMPZ WELLPFMPSP P R/U and test RBP T/3000 psi for 5 mins.recorcLon chart, R/D test equipment. 08:30 12:00 3.50 1,215 1,140 COMPZ WELLPFOTHR P Rack back one stand T/1140'MD, R/U and dump 12 sx sand on top of RBP 720 lbs.Calc=7.8 bbls, Act= 8.4 bbls. 12:00 13:45 1.75 1,140 1,140 COMPZ WELLPFOTHR P Continue dumping sand sand on top of RBP. 13:45 14:45 1.00 1,140 1,155 COMPZ WELLPF OTHR P Let sand settle for 1 hr,Tag sand @ 1155'MD 14:45 15:30 0.75 1,155 0 COMPZ WELLPFMPSP P Monitor well, POOH,UD RBP running tool. 15:30 16:15 0.75 0 0 COMPZ WELLPF OTHR P Drain stack, Pull wear ring,set test plug. 16:15 17:30 1.25 0 0 COMPZ WELLPF OTHR P PJSM,C/O lower rams to 7" 17:30 19:30 2.00 0 0 COMPZ WELLPF OTHR P PJSM,Observed 7"test joint to high for test, PJSM,C/O Lower 7"to 2-7/8"x 5"VBR and upper 3.5"x 6" VBR to 7" 19:30 19:45 0.25 0 0 COMPZ WELLPF BOPE P Pull 7"test joint Torque X/O,Obtain RKBs and re-install test joint. 19:45 20:00 0.25 0 0 COMPZ WELLPF BOPE P R/U test equipment. 20:00 21:45 1.75 0 0 COMPZ WELLPF BOPE P PJSM,Test upper rams&Annular with 7"test jt.Test lower 2-7/8"x 5" VBRs with 4"test joint to 250 low/3500 high and record on chart. 21:45 22:00 0.25 0 0 COMPZ WELLPF BOPE P R/D test equipment and drain stack. 22:00 23:30 1.50 0 0 COMPZ WELLPF NUND P PJSM, N/D BOP stack and adapter spool. 23:30 00:00 0.50 0 0 COMPZ WELLPF NUND P Verified 0 psi on OA, Remove annulus valve, LDS and Blank flange from tubing head. 10/06/2012 Grow casing using hydratight to 18"growth, remove tbg head and pack-off,spear casing and set slip with 35K, N/U BOPs,Test brk,M/U multi string cutter and cut casing @ 639'MD,displace well w/sea water, POOH,M/U spear and pick casing free,Circ 188 bbls 90°diesel through 7"x 9-5/8"OA to tiger tank. 00:00 01:15 1.25 0 0 COMPZ WELLPF NUND P Break all bolts on tbg head&R/U hydratight,simops stage drilling spool in cellar. 01:15 06:30 5.25 0 0 COMPZ WELLPF OTHR P Grow casing w/hydratight system, casing grew 18"total. 06:30 07:00 0.50 0 0 COMPZ WELLPF OTHR P Remove tubing head&pack off 07:00 09:00 2.00 0 0 COMPZ WELLPF PULD P M/U spear,spear casing pull 35 K over,set slips UD spear. Page 4 of 20 I Time Logs I Date From. To Dur S.Depth.E.Depth Phase Code Subcode T Comment' 09:00 12:00 3.00 0 0 COMPZ WELLPF NUND P Nipple up drilling spool&stack, simops add 4"T/bell nipple. 12:00 13:00 1.00 0 0 COMPZ WELLPF NUND P PJSM,Continue N/U BOP Stack. 13:00 13:45 0.75 0 0 COMPZ WELLPF BOPE P Flood lines&choke lines,Close blinds ram and test break to 250/1700 psi for 5 min,record on chart, had leak on HCR kill,service and retest,Good. 13:45 14:15 0.50 0 0 COMPZ WELLPF BOPE P Blow down all lines. 14:15 15:45 1.50 0 456 COMPZ WELLPF OTHR P PJSM,M/U multi cutter&RIH to 329',work through tight spot, RIH to 456'tight spot, try several attempt with no success, P/U wt=47K. 15:45 16:15 0.50 456 0 COMPZ WELLPF TRIP P PJSM,POOH and laid down stabilizer,Calc=4.21,Act=4.9. 16:15 17:15 1.00 0 654 COMPZ WELLPF TRIP P RIH T/579',work through tight spot, cont RIH to 654'MD 17:15 17:45 0.50 692 649 COMPZ WELLPF CIRC P Establish parameters, P/U=47, S/0=43, Brk circ @ 2.5 bpm&150 psi,locate lower collar @ 692'and locate upper collar @ 649' 17:45 18:15 0.50 639 639 COMPZ WELLPF OTHR P Rack back stand, P/U to 639', establish parameters,rot wt=45, 1800 tq with 70 RPM,start cut with 4 bpm&500 psi,observe pressure bleed down,step rate up to 5 bpm 450 psi,Gas migrating from well and slowly S/O with 2K on cutters,shut down rotary. 18:15 18:30 0.25 639 639 COMPZ WELLPF CIRC P Displace well with 40 bbls sea water @ 3bpm 70 psi. 18:30 18:45 0.25 639 639 COMPZ WELLPF OWFF P Monitor well(static with arctic pack swapping out) 18:45 20:00 1.25 639 0 COMPZ WELLPF TRIP P PJSM, POOH w/MSC BHA,and LID same. Did not fill hole to midigate arctic pack back to pits. 20:00 20:15 0.25 0 0 COMPZ WELLPF PULD P Clear and clean rig floor. 20:15 21:30 1.25 0 24 COMPZ WELLPF PULD P PJSM,M/U spear and space out across annular, P/U single and engage spear, Kelly up, Pull casing free with 55K, P/U to 4:and set slips &LID single. 21:30 22:00 0.50 24 24 COMPZ WELLPF CIRC P M/U head pin&cement line,pull slips and close annulur 22:00 00:00 2.00 24 24 COMPZ WELLPF CIRC P PJSM, R/U little Red and PT lines 500/1500 psi,Good,displace arctic pack F/7"x 9-5/8"through cut out to OA to tiger tank with 188 bbls 90° diesel @ 2 bpm. 10/07/2012 Finish pumping diesel and sea water down 7"x 9-5/8",spear 7", N/D BOP, remove slips, N/U BOP, UD 7" casing,C/O rams and test VBRs,Make 9-5/8"scraper run, R/U SLB e-line and Gyro data survey,40-arm caliper and log, R/D SLB e-line. Page 5 of 20 • Time Logs Date` From. To Dur S.Death E.Depth Phase Code Subcode T Comment 00:00 01:30 1.50 24 24 COMPZ WELLPFCIRC P PJSM,Continue pumping heated diesel @ 2 bpm 450 psi,Pumped total of 188 bbls followed with 150 heated sea water @ 3 bpm 250 psi. 01:30 02:00 0.50 24 24 COMPZ WELLPF OWFF P Monitor well,blow down lines. 02:00 02:45 0.75 24 24 COMPZ WELLPF NUND P PJSM, Nipple down BOPE and remove slips. 02:45 04:00 1.25 24 24 COMPZ WELLPF NUND P Nipple up BOPE. 04:00 04:30 0.50 24 24 COMPZ WELLPF PULD P R/U casing equipment. 04:30 05:30 1.00 24 0 COMPZ WELLPF PULD P PJSM, Raise spear to rig floor and lay down spear and cut off joint. 05:30 08:00 2.50 0 0 COMPZ WELLPF PULD P L/D 7"casing. P/U=65K, 1 well head joint=6.67', 14 full joints and 1 cut joint=27.38'Length of Fish= 614.99'Calc=6.0 bbls,Act=6.4 bbls. 08:00 08:45 0.75 0 0 COMPZ WELLPF PULD P R/D casing equipment. 08:45 09:30 0.75 0 0 COMPZ WELLPF PULD P P/U spear and redress as per-Baker Rep. 09:30 10:45 1.25 0 0 COMPZ WELLPF OTHR P PJSM,Set test plug,change rams to 3.5"x 6"VBRs 10:45 12:00 1.25 0 0 COMPZ WELLPF BOPE P R/U test equipment and test top rams T/250/3000 psi and chart same. R/D test equipment. 12:00 12:30 0.50 0 0 COMPZ WELLPF BOPE P R/D test equipment and pull test plug and set wear ring. 12:30 12:45 0.25 0 0 COMPZ WELLPF PULD P P/U baker tools to rig floor. 12:45 16:00 3.25 0 639 COMPZ WELLPF TRIP P M/U casing scraper assembly,&RIH to 268'MD work through tight spot to 5 272'with 10K drag&overpull,cont. i , RIH and tag casing stump@ 639' MD.Calc=9.45 bbls,Act=10.03 Ck bbls. 16:00 16:30 0.50 639 639 COMPZ WELLPF CIRC P Break circ at 5 bpm 250 psi,clean well with 40 bbls of heated sea water. 16:30 16:45 0.25 639 639 COMPZ WELLPF OWFF P Monitor well static. 16:45 18:00 1.25 639 0 COMPZ WELLPF TRIP P PJSM, POOH rack back DCs and L/D scraper.Calc=10.30 bbls,Act= 9.8 bbls. 18:00 18:30 0.50 0 0 COMPZ WELLPF OTHR P Clear and clean rig floor. 18:30 20:45 2.25 0 0 COMPZ WELLPF ELOG P PJSM,R/U SLB E-line equipment, _.--&tIVIOPS work on MP2s. 20:45 21:15 0.50 0 0 COMPZ WELLPF ELOG P RIH with Gyro-data survey and 40 arm caliper to 639' ■• 21:15 21:30 0.25 0 0 COMPZ WELLPF ELOG - e e ••ging at 50 FPM. 21:30 22:30 1.00 0 0 COMPZ WELLPF ELOG P R/D E-lione tools and equipment. 22:30 22:45 0.25 0 0 COMPZ WELLPF OTHR P Shuffle stands in derrick for next run. 22:45 00:00 1.25 0 0 COMPZ WELLPF PULD P PJSM, Bring up BOT subs and tools via beaver slide for next BHA. Page 6 of 20 • • Time Logs Date From To > Dur S.Depth E Deoth Phase Code Subcode • T Comment 10/08/2012 24 hr Summary RIH w/BOT Backoff tool back off 7"dutchman 5 complete turns,POOH, P/U Tandem string Mill RIH mill bad spot in casing from 225',230',255',288', RIH to 632'MD,Circ 100 bbls sea water, POOH,M/U triple connect drift BHA&RIH took 4-5K drag,cont RIH with 1-2K drag to 610'MD,CBU, Blow down top drive. 00:00 02:30 2.50 0 320 COMPZ WELLPF PULD P PJSM,M/U BHA#8, Back off assembly to 320'MD 02:30 03:00 0.50 320 884 COMPZ WELLPF TRIP P RIH F/320'T/884'MD,S/O=50K, P/U= 03:00 03:45 0.75 884 884 COMPZ WELLPF OTHR P Fill dp with fresh water, R/U pump in sub and lines to set anchors on back off tool. P turn with back 03:45 05:00 1.25 884 884 COMPZ WELLPF OTHR Back out 5 complete to t bac off tool. 05:00 05:30 0.50 884 884 COMPZ WELLPF CIRC P Drop shear out rod,shear out pump out sub break circ, R/D circ. lines 05:30 06:15 0.75 884 320 COMPZ WELLPF TRIP P Pooh t/320' 06:15 07:45 1.50 320 0 COMPZ WELLPF PULD P Stand back&L/D BHA 07:45 08:30 0.75 0 0 COMPZ WELLPF OTHR P Clean&Clear rig floor P/U tools for next run 08:30 10:15 1.75 0 197 COMPZ WELLPF PULD P M/U BHA Tandem string mill assembly 10:15 15:15 5.00 197 288 COMPZ WELLPF MILL P Work mill through tight spot in casing @ 229',60 rpm 3-5k tq.294 gpm 100 psi,continue to work string through until 5-7K drag observed. 15:15 15:45 0.50 288 629 COMPZ WELLPF TRIP P Continue RIH w/Tandem scraper t/ 629' 15:45 16:15 0.50 629 629 COMPZ WELLPF CIRC P Circ.bottoms up 294 gpm 280 psi 16:15 16:45 0.50 629 183 COMPZ WELLPF TRIP P Pooh stand back drill collars. Observe 7-10 K over pull through tight spot 16:45 17:30 0.75 183 229 COMPZ WELLPF REAM P RIH w/Tandem string mill without drill collars t/229'work through tight spot w/80 rpm,294 gpm 150 psi, no drag in rotary slight tq,when sick off and pick up,attepmt to work through without pumps or rotary take 10K weight to get through. 17:30 19:15 1.75 229. 0 COMPZ WELLPF PULD P Pooh w/tandem mills stand back& L/D BHA,inspect mill no damage slight wear on leading edge and gauge. 19:15 20:00 0.75 0 0 COMPZ WELLPF OTHR P Clear and clean rig floor. 20:00 20:30 0.50 0 0 COMPZ WELLPF PULD P Stage Baker tools for next run on rig floor,SIMOPS service tools and equipment. 20:30 22:45 2.25 0 610 COMPZ WELLPF TRIP P PJSM,M/U triple connect dummy drift assembly and RIH to 275'(P/U= 38K,S/0=40K)took 7K drag, P/U 10'rot 1/2 turn&RIH,took 4-5K drag through tight spot F/275'T/280', Cont. RIH w/1-2K drag to 610'MD, Kelly up, P/U=45K,S/O=45K. Calc=3.5 bbls,Act=4.5 bbls. Page 7 of 20 • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T," Comment. 22:45 23:00 0.25 610 637 COMPZ WELLPF CIRC P Establish circ @ 6 bpm 50 psi and wash down to 637'MD, Increase rate to 16 bpm 225 psi and circ hole clean. 23:00 00:00 1.00 637 637 COMPZ WELLPF OTHR P PJSM, Blow down Top Drive. 10/09/2012 POOH with drift BHA, P/U spear&RIH to 619'CBU,engage fish, POOH and UD fish,C/O lower rams to 7" found 10#s of metal in cavity,open blind ram clean out 2#s of metal,sucure well and shut down rig for drop object meeting with both crews,Test rams,service rig,found cementer had wrong threads,W/O X/O,M/U cementer and X/Os and run casing and engaged 7"w/triple connect, Brk out Top Drive connects and clear floor. 00:00 00:30 0.50 637 74 COMPZ WELLPF TRIP P PJSM, POOH to 74'MD, Pulled 5K over at 280'and 275'MD. 00:30 01:45 1.25 74 0 COMPZ WELLPF PULD P UD BHA,Clean Magnet had very fine metal on it. 01:45 03:15 1.50 0 0 COMPZ WELLPF OTHR P C/O elevators, P/U X-O and redress spear. 03:15 04:15 1.00 0 619 COMPZ WELLPF TRIP P RIH T/619'MD Obtain parameters, P/U=41K,S/0=43K,backed out Dutchman 5 turns to the left. 04:15 04:45 0.50 619 619 COMPZ WELLPFCIRC P CBU @ 10bpm 100 psi,Observed Arctic pack and sand on bottoms up, contiue circ till shakers clean. 04:45 05:45 1.00 619 0 COMPZ WELLPF TRIP P POOH to surface with Fish on. 05:45 06:15 0.50 0 0 COMPZ WELLPF PULD P UD Fish and spear assembly, Leng. of Fish=9.14' 06:15 07:30 1.25 0 0 COMPZ WELLPF OTHR P Clear rig floor,drain stck,pull wear ring and set test plug. 07:30 09:30 2.00 0 0 COMPZ WELLPF OTHR P PJSM,C/O lower pipe rams to 7", found and cleaned out 10 lbs of metal cuttings out of cavity. 09:30 11:00 1.50 0 0 COMPZ WELLPF OTHR P Open Blind ram doors and clean out 2 lbs of metal. 11:00 12:00 1.00 0 0 COMPZ WELLPF SFTY P Shut down rig operations to attend ./ dropped ojbects meeting at camp. 12:00 13:15 1.25 0 0 COMPZ WELLPF BOPE P PJSM,Set test plug and R/U and test equipment. 13:15 14:30 1.25 0 0 COMPZ WELLPF BOPE P Test lower rams and blind rams to 250/3000 psi and record same on chart. 14:30 14:45 0.25 0 0 COMPZ WELLPF BOPE P Rig down test equipment and pull test plug. 14:45 15:45 1.00 0 0 COMPZ WELLPF RNCS P PJSM, R/U casing equipment. 15:45 17:15 1.50 0 0 COMPZ WELLPFSVRG P Service rig and PJSM on running casing. 17:15 18:00 0.75 0 0 COMPZ WELLPF OTHR T Wrong thread on HES cementer, W/O cross over. 18:00 19:00 1.00 0 0 COMPZ WELLPF OTHR P Drift X/O pup with 6.151"drift and clean threads, rearrange running order. 19:00 22:00 3.00 0 614 COMPZ WELLPF RNCS P M/U Cementer,5'7"casing X/O and triple connect and baker lock joints, RIH as per casing detail. Page 8of20 •.. al Time Logs Date From To Dur S.Depth"E.Depth Phase Code Subcode T Comment 22:00 22:30 0.50 614 614 COMPZ WELLPF RNCS P Change elevators,M/U X/Os and 10' pup to landing joint on skate,P/U and make up to string and Top Drive. P/U=50K,S/O=46K,Rot wt=50K, 1k tq. 22:30 22:45 0.25 614 649 COMPZ WELLPF OTHR P S/O and engage stub with rotary @ 1Q112 n.saw orque up @ 649'MD. , maintain 2K on stub,M/U to 10K, work torque out of casing string with 20K over pull and set down 5K work up to 50K, let torque out slowly. 22:45 23:30 0.75 649 649 COMPZ WELLPF PULD P Break out X/Os and dp pup from Top Drive and UD same. 23:30 00:00 0.50 649 649 COMPZ WELLPF OTHR P Clear and clean rig floor. 10/10/2012 C/O bails,M/U cement head,Test casing and open cementer and circ 100 bbls heated sea water,Cement as per-program.got back 16.5 bbls cement to surface, Flow check(Good)WOC 4 hrs, N/D BOP,set slips,cut casing,set pack-off N/U tbg spool and test pack-off to 3000 psi, N/U BOP and C/O lower ram to VBR,R/U and test BOPE. 00:00 01:30 1.50 649 649 COMPZ WELLPF CMNT P PJSM,CIO bails and M/U cement head and circ lines. 01:30 03:30 2.00 649 649 COMPZ WELLPF OTHR P R/U and test 7"casing tieback to 3000 psi for 30 min and chart same, Cement X/O leaked made repairs. (twice) 03:30 04:00 0.50 649 649 COMPZ WELLPF OTHR P Close Rams and open HES cementer w/3300 psi. 04:00 04:45 0.75 649 649 COMPZ WELLPF CIRC P Pump 100 bbls heated sea water taking returns out the OA.5 bpm 300 psi. 04:45 06:30 1.75 649 649 COMPZ WELLPF CMNT P PJSM, Pump cement per-plan, .( pumped 5 bbl water,test lines to (% 4500 psi,pumped 36 bbls 15.7 ppg 1 ASI,drop plug with 3 bbls cement, followed with 5 bbls water,turn over GS� to rig and displaced and bumped plug with 177 stks pressured up to 1800 psi and closed HES cementer, check for flow Good CIP @ 06:15 hrs,got back 16.5 bbls cement to surface. 06:30 07:00 0.50 649 0 COMPZ WELLPF WOC P Monitor well, Flush stack and 2"hard line to pits with black water, (WOC) 07:00 10:00 3.00 0 0 COMPZ WELLPF WOC P PJSM,CIO bails and elevators,R/D circ lines in cellar. 10:00 11:00 1.00 0 0 COMPZ WELLPFWOC P PJSM, N/D BOP and bell nipple, suck fluid out of landing joint. 11:00 12:00 1.00 0 0 COMPZ WELLPF NUND P Lift BOP stack,P/U with 50K in tension and set slips,found firm cement down @ 14'. 12:00 13:00 1.00 0 0 COMPZ WELLPFCPBO P PJSM,S/O and land casing on slips with 50K tension, P/U 1K and rig up WACHS cutter and cut landing joint. 13:00 14:30 1.50 0 0 COMPZ WELLPF NUND P Lay down landing joint, N/D drilling spool and dress TBG spool. Page9of20 • Time Logs Date From To Dur S.Depth E.Depth Phase Code =Subcode_ T Comment 14:30 16:15 1.75 0 0 COMPZ WELLPF OTHR P Remove VR plug and attempt to run .5"hose into annulus No success, attempt same with.25"SS line, No success,SIMOPS P/U sppear and remove fish and redress,Measure TOC again 7'down and fill with diiesel 3 gal. 16:15 16:45 0.50 0 0 COMPZ WELLPF NUND P Install FMC 7"pack-off. 16:45 19:00 2.25 0 0 COMPZ WELLPF NUND P PJSM, N/U new 7-1/16"5M x 11"3M Tbg spool and PT pack-off to 3000 psi(Good) 19:00 20:00 1.00 0 0 COMPZ WELLPF NUND P Nipple up adapter spool and BOP stack 20:00 21:30 1.50 0 0 COMPZ WELLPF OTHR P PJSM,C/O lower ram to 2-7/8"X 5" VBR,SIMOPS set test plug with 4" test joint and R/U test equipment. 21:30 21:45 0.25 0 0 COMPZ WELLPF BOPE P PJSM for BOPE test. 8oe 21:45 00:00 2.25 0 0 COMPZ WELLPF BOPE P Test BOPE:250/3500 psi for 5 min /5� each&record on chart.Test#1 /i Upper 3.5"X 6"VBR,Choke valves 1, 12, 13, 14 and manual Kill valve. Test#2 Upper IBOP,HCR Kill, Choke valves 5&11.Choke valve#9 failed.(Witness of test waived by State Inspector Chuck Scheve) 10/11/2012 Test BOP,test waived by Chuck Scheve, RIH with plug milling BHA&drill cement and cementer, POOH, Wash out stack,M/U cocave mill&RIH,Mill junk, POOH,M/U Reverse Circ Junk Basket BHA&RIH, POOH clean junk basket up and rerun into hole again. 00:00 04:00 4.00 0 0 COMPZ WELLPF BOPE P PJSM,Continue testing BOP, Tested all rams&choke valves, Accumulator test system pressure =3000 psi,psi after closing=1800 psi,200 psi attained in 38 sec,full psi attained in 184 sec,Avg. nitrogen=2050 psi. 04:00 05:00 1.00 0 0 COMPZ WELLPF BOPE P R/D all test equipment and blow down all lines,set wear ring.(ID= 6-5/16") 05:00 07:00 2.00 0 324 COMPZ WELLPF PULD P PJSM,M/U BHA, Plug milling assembly to 324'MD. 07:00 07:15 0.25 324 534 COMPZ WELLPF TRIP P RIH Tag cment @ 534'MD, P/U= 48K,S/0=48K,Act=8.9 bbls, Calc=8.54 bbls. 07:15 10:15 3.00 534 700 COMPZ WELLPF COCF P Drill out cement stringers F/534'T/ 639'Drill out cmt plugs and cementer F/639'T/641'wash and ream to 700' MD. ream through cementer twice no problems. 10:15 10:45 0.50 700 1,075 COMPZ WELLPFTRIP P RIH on elevators T/1148'MD and tag TOS with 5K, Rack back stand to 1075'MD, P/U=55K,S/O=55K, '1 Act=2.2,Calc=1.95. - C 5 10:45 12:00 1.25 1,075 1,075 COMPZ WELLPF OTHR P R/U and test casing t 2500 psi f 30 min and chart same. 12:00 12:15 0.25 1,075 1,075 COMPZ WELLPF OTHR P Bleed off casing,open rams, R/D 'f and blow down. Page 10 of 20 Time Logs. Date From To ' Dur S.Depth, E.Depth Phase Code Subcode T Comment; 12:15 13:15 1.00 1,075 0 COMPZ WELLPFTRIP P PJSM, POOH with plug milling BHA 13:15 13:30 0.25 0 0 COMPZ WELLPF PULD P Clean Junk Baskets 13:30 14:45 1.25 0 0 COMPZ WELLPF PULD P PJSM,C/O handling equipment and UD 6-3/4"DCs via mouse hole. 14:45 15:00 0.25 0 0 COMPZ WELLPF PULD P Clear and clean rig floor.C/O handling equipment. 15:00 16:30 1.50 0 1,084 COMPZ WELLPFTRIP P PJSM,M/U concave milling BHA and RIH to 1084'MD, P/U=56K,S/O= 56K, Rot=57K,off Tq=1K,Act= 9.85,Calc= 10.77. 16:30 17:15 0.75 1,084 1,150 COMPZ WELLPF MILL P Brk Ciro @ 4 bpm 150 psi,circ string volume shut down pump&RIH w/40 RPM took wt.@ 1110'MD,shut down rotation&set dn 10K, P/U and work through tight spot w/3/5K, drag. RIH&tag TOS @ 1148'MD set down w/5K,with rotary 50 RPM &S/O and mill debris on TOS w/ 1-2K, P/U 5'shut dn rotary,S/O& tag TOS w/8K, P/U 5'rotate 75 RPM S/O and mill TOS w/1K on mill for 15 min, P/U 10'&brk circ.@ 4 bpm 150 psi,S/O and tag TOS 3 ,69Q times with 8K @ 1150'MD, P/U 80' and CBU 8 bpm 500 psi. W �z4 17:15 17:45 0.50 1,150 1,089 COMPZ WELLPF CIRC P CBU @ 4 bpm 150 psi, increase rate to 8 bpm 500 psi&CBU x 3, Blow down TD. 17:45 19:00 1.25 1,089 0 COMPZ WELLPFTRIP P PJSM, POOH w/concave mill BHA, F/1089'to surface.Act=10.09, Calc=9.39 bbls. 19:00 19:45 0.75 0 0 COMPZ WELLPF OTHR P M/U stack washer w/magnet and flush stack x 2,got back 8 lbs of metal on magnet. 19:45 20:30 0.75 0 0 COMPZ WELLPF OTHR P UD stack washer and clean junk baskets. 20:30 22:00 1.50 0 1,089 COMPZ WELLPF PULD P PJSM,M/U Reverse Circ Basket assembly&RIH to 1089'MD, P/U= 56K,S/0=56K, Rot wt=57K,Act= 7 bbls,Calc=8.73 bbls. 22:00 22:45 0.75 1,089 1,153 COMPZ WELLPF MILL P Establish Rates&pressure,break std and drop ball,ball on seat bring rate up to 5bpm 450 psi,shut down pump,S/O and tag TOS @ 1152', P/U 5'increase rate to 9.5 bpm 1400 ✓ psi and wash down to sand with 35 RPM,attempt to wash through with 5-12K wt.on RJB,made 1 footin 30 min. 22:45 23:00 0.25 1,153 1,089 COMPZ WELLPFOTHR P Rack back one stand and blow down TD. 23:00 00:00 1.00 1,089 146 COMPZ WELLPF TRIP P PJSM, POOH F/1089'T/146'MD, P/U=38K,S/O=38K,Act=7.99 bbls,Calc=7.7 bbls. 10/12/2012 Made three more RCJB runs,(Recovered about 14 lbs of metal,2 Brass shear bolts and rubber), POOH and M/U RBP retrieving tool and retrieve RBP and UD same.M/U Overshot BHA and RIH to 6924 MD. Page 11 of 20 • • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 00:00 00:30 0.50 146 0 COMPZ WELLPFTRIP P PJSM,cont. POOH to suface,Clean out junk basket recovered 3 lbs of metal cuttings. 00:30 01:30 1.00 0 1,153 COMPZ WELLPFTRIP P RIH with RJB run#2 to 1189'MD, brk circ,shut down and RIH to 1153" MD,tag btm, P/U=56K,S/O=56K, 01:30 02:30 1.00 1,153 1,154 COMPZ WELLPFMILL P Mill F/1153 T/1154'MD,95 spm 1400 psi, Rot 40 RPM,TQ=1-2K S/O=56K 02:30 03:30 1.00 1,154 0 COMPZ WELLPFTRIP P POOH,Clean off magnet and Brk RJB. 03:30 04:00 0.50 0 0 COMPZ WELLPFOTHR P Clean out RJB recovered 8 lbs metal and 10 pieces of rubber from cement plug. 04:00 05:30 1.50 0 1,154 COMPZ WELLPF TRIP P M/U RJB run#3 BHA and RIH T/ 1089'MD&brk circ, 395 gpm 1400 psi,Wash down to 1154'tag btm, Act=9.25,Calc=9.59. 05:30 06:00 0.50 1,154 1,154 COMPZ WELLPF CIRC P CBU x 3, 105 spm,425 gpm, 1500 psi. 06:00 07:00 1.00 1,154 0 COMPZ WELLPFTRIP P POOH to surface,Act=9.4,Calc= 9.32. 07:00 07:45 0.75 0 0 COMPZ WELLPF PULD P Brk RJB and clean out 3 lbs of metal rubber,M/U same. 07:45 09:15 1.50 0 1,170 COMPZ WELLPFTRIP P RIH with RJB run#4 to 1089'MD, Brk circ 100 spm 1550 psi,wash T/ 1158'Tag btm,wash&ream F/1158' T/1164'20 rpm,Tq=2K,WOB= 4-6K,Wash F/1164'T/1170'No Ro2-6K WOB. 09:15 09:30 0.25 1,170 1,170 COMPZ WELLPFCIRC P CBU x 3, 100 spm 1450 psi. 09:30 12:00 2.50 1,170 0 COMPZ WELLPFTRIP P POOH to surface,clean out RJB and found 2-1"x 1.25"brass shear bolts and 7 lbs of metal debris on magnet. 12:00 12:15 0.25 0 1,089 COMPZ WELLPFTRIP P PJSM, M/U RJB and RIH to 1089' MD,Act=9.18,Calc=10.89. 12:15 13:00 0.75 1,089 1,207 COMPZ WELLPF CIRC P Tag TOS @1170'MD wash F/1170' T/1207'MD 13 bpm 2400 psi. P/U=56K,S/O=55K, Rot wt=57K, 13:00 13:15 0.25 1,207 1,207 COMPZ WELLPFCIRC P Increase rate to 14 bpm 2750 psi and circ till clean. 13:15 13:30 0.25 1,207 1,181 COMPZ WELLPF TRIP P Rack back std and blow down TD. Monitor well. 13:30 14:45 1.25 1,181 0 COMPZ WELLPFTRIP P POOH F/1181'to surface,clean and lay down RCJB and magnets. 14:45 15:45 1.00 0 1,184 COMPZ WELLPF PULD P PJSM,M/U RBP retrieval tool and RIH to 1144'.Act= 11.42,Calc= 10.17. 15:45 16:15 0.50 1,184 1,215 COMPZ WELLPF PULL P Wash down and en age RBP @ S/0=56K, Rot wt=57K, 10 bpm 350 psi.CBU x 2. 16:15 16:30 0.25 1,215 1,215 COMPZ WELLPF PULL P Wait for element to relax and monitor well. 16:30 16:45 0.25 1,215 1,140 COMPZ WELLPFOWFF P Rack back stand and observe fluid drop in stack. Page 12 of 20 Time Logs Date From To Dur S.Depth.E.Depth Phase Code Subcode; T Comment 16:45 18:15 1.50 1,140 0 COMPZ WELLPF TRIP P PJSM, POOH F/1140'to surface with RBP and LID same.Act=10.2, Calc=10.17. 18:15 19:30 1.25 0 0 COMPZ WELLPF PULD P Clear and clean rig floor,off load 5"& BOT subs, P/U subs for next run. 19:30 23:45 4.25 0 6,924 COMPZ WELLPF TRIP P PJSM,M/U over shot BHA and RIH to 6924'MD,Act=44.54,Calc= 43.58. 10/13/2012 Cont. RIH to 7930'MD Displace well to 9.3 ppg Brine, Engage Fish @ 7954'(3.5 tbg stub seal assembly leng=31.97')Pick up and CBU, POOH and LID fish,M/U fishing spear BHA and RIH to 7970'MDengage fish with 75 overpull,pick up and open pump out sub and CBU, attempt to pull but swabbing,pump out to 6995' Pi( ,� MD,monitor well and POOH, Lay down Fish, Leng-184.79'.clear and clean floor. K 00:00 00:30 0.50 6,924 7,930 COMPZ WELLPF TRIP P PJSM,RIH F/6924'T/7930'MD, � P/U=135K,S/O=105K,Act=5.95, ), Clac=5.95. 00:30 00:45 0.25 7,930 7,930 COMPZ WELLPF SFTY P PJSM on displacement. 00:45 01:15 0.50 7,930 7,930 COMPZ WELLPF CIRC P Displace well,from 8.6 ppg sea water to 9.3 Brine @ 7 bpm 700 psi FCP=800 psi. Pumped 311 bbls. 01:15 01:45 0.50 7,930 7,951 COMPZ WELLPF FISH P Establish parameters, Rot wt=120K, Tq=3.5K, P/U=135K,5/0=105K, Rotate w/10 rpm F/7951'T/7954' MD,Shut down Rotary and slack off 5'and set down 5K,Total sallow 8' and No Go @ 7959'MD, Pulled up with 15K over pull. 01:45 02:15 0.50 7,951 7,951 COMPZ WELLPF CIRC P CBU @ 6 bpm 650 psi. 02:15 02:30 0.25 7,951 7,951 COMPZ WELLPF OWFF P Monitor well(Static) 02:30 02:45 0.25 7,951 6,864 COMPZ WELLPF TRIP P Rack back one stand and blow down. 02:45 06:00 3.25 6,864 323 COMPZ WELLPF TRIP P POOH F/6864'T/323'MD,Act= 52.19,Calc=48.98 06:00 07:45 1.75 323 0 COMPZ WELLPF PULD P PJSM, UD BHA as per Baker. 07:45 08:00 0.25 0 0 COMPZ WELLPF SFTY P PJSM on P/U and M/U spear BHA 08:00 08:45 0.75 0 321 COMPZ WELLPF PULD P M/U BHA as per-Baker rep.to 321' MD 08:45 10:30 1.75 321 7,936 COMPZ WELLPF TRIP P RIH F/321'T/7936'MD,Act=51.34, Calc=49.52. 10:30 11:00 0.50 7,936 7,967 COMPZ WELLPF CIRC P P/U single and brk circ @ 4 bpm 600 psi, Blow down. 11:00 11:15 0.25 7,967 7,952 COMPZ WELLPF FISH P Establish parameters, P/U=135K, S/O=107K, Engage fish Ca)7970' MD Pull 75K over to bleed oil jars, Pull 75K over string wt.observe wt drop off,P/U 10'with 15K drag. 11:15 12:00 0.75 7,952 7,952 COMPZ WELLPF OWFF P Monitor well, had slight flow,then became static. 12:00 12:15 0.25 7,952 7,930 COMPZ WELLPF OTHR P PJSM, LID single Drop ball&rod, Kelly up, P/U=165K,S/O=115K, Brk circ @ 4 bpm 750 psi,saw 50 psi increase with ball on seat,psi stailized @ 200 psi. 12:15 13:00 0.75 7,930 7,930 COMPZ WELLPF CIRC P Increase pump rate to 8 bpm 1000 psi,CBU x 2. Page 13 of 20 • Time Logs Date From To Dur S.Depth E.Death Phase Code Subcode T ;Comment. 13:00 13:45 0.75 7,930 7,930 COMPZ WELLPF TRIP P Attempt to rack back stand, P/U 15' and hole swabbing Slack off 10'and observe the fluid drop, P/U 15' swabbing,S/O 10'and pump 16 bbls,Monitor well for 30 min fluid dropped 10'in stack. 13:45 15:30 1.75 7,930 6,995 COMPZ WELLPF TRIP P Pump out of hole F/7930'MD T/ 6995'MD. 15:30 15:45 0.25 6,995 6,905 COMPZ WELLPF TRIP P P/U and observe fluid drop in well, work string 60'packer took wt in casing collar work several times(Not swabbing)Rack back stand and blow down. 15:45 19:00 3.25 6,905 320 COMPZ WELLPF TRIP P POOH F/6905'MD T/320'MD. 19:00 19:30 0.50 320 320 COMPZ WELLPFOWFF P Monitor well, hole taking fluid, R/U 3.5"handling equipment. 19:30 22:30 3.00 320 0 COMPZ WELLPF PULD P POOH with BHA and Fish, UD same. Lenght of Fish=184.79'Act= 82.23,Calc=44.37. 22:30 22:45 0.25 0 0 COMPZ WELLPF PULD P Clean and clean floor. 22:45 00:00 1.25 0 0 COMPZ WELLPF PULD P PJSM, Pick up 9 jts of 4"dp and stand back for next run. (Total tour losses=56.64 bbls.) 10/14/2012 M/U spear BHA, RIH to 7415',Cut drilling line, RIH to 8103'had gas to surface,CBU,Monitor well,fluid dropping,RIH to 8149'MD,attempt to enter packer bore, No Go,discuss seal sizes,decision C/O/BHA, CBU, Monitor well, POOH,M/U packer milling BHA, RIH tagged up high @ 8041'wash&ream through tight spot down to 8147'MD,Started milling,milled 24"to 8149'MD 00:00 01:00 1.00 0 339 COMPZ WELLPF PULD P PJSM,M/U Packer Spear as per-Baker Rep.to 339'MD. 01:00 03:15 2.25 339 7,415 COMPZ WELLPF TRIP P RIH F/339'T/7415'MD.Act=27.88, Calc=48.9 03:15 04:45 1.50 7,415 7,415 COMPZ WELLPF SLPC P PJSM,Slip and cut 65'of drilling line. 04:45 07:00 2.25 7,415 8,103 COMPZ WELLPF TRIP P RIH F/7415'T/8103'MD, P/U= 135K,S/O=106K,3 bpm 390 psi,50 RPM,rot wt=123K,Observed gas to surface,circ gas out. 07:00 07:30 0.50 8,103 8,103 COMPZ WELLPFOWFF P Monitor well,fluid dropping. 07:30 08:30 1.00 8,103 8,151 COMPZ WELLPF TRIP P RIH F/8103'T/8137'MD,(Tagged up)Observed 16K overpull to get free, Pump 5 bpm 850 psi,44%flow out,tagged 12'high,Rotate through and went down to top of packer @ 8151'MD,Attempt to enter could not wash or drill through. 08:30 09:30 1.00 8,151 8,151 COMPZ WELLPF OTHR P Shut down and discuss seal sizes with Co. Rep.and Baker hand, Monitor well on Trip tank. 09:30 10:15 0.75 8,151 8,133 COMPZ WELLPFCIRC P CBU @ 8133'MD,5 bpm 900 psi, Observed gas to surface @ BU, cont circ gas out. 10:15 10:30 0.25 8,133 8,133 COMPZ WELLPFOWFF P Monitor well,fluid dropping. (PJSM on POOH) 10:30 10:45 0.25 8,133 8,075 COMPZ WELLPF TRIP P Rack on stand back and blow down. Page 14 of 20 • Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment" 10:45 12:00 1.25 8,075 6,229 COMPZ WELLPF TRIP P POOH F/8075 T/6229'MD,Act= 12.75,Calc=8.1.(Total losses=64 bbls for tour) 12:00 15:15 3.25 6,229 0 COMPZ WELLPF TRIP P PJSM,Continue POOH F/6229'T/ surface, UD packer mill BHA.Act= 62.22,Calc=42.09. 15:15 15:45 0.50 0 0 COMPZ WELLPF PULD P Clean Junk baskets,inspect Top Drive. 15:45 16:00 0.25 0 0 COMPZ WELLPF PULD P P/U BOT subs for next run. 16:00 16:45 0.75 0 0 COMPZ WELLPF SVRG P Service Drawworks and Iron Roughneck. 16:45 21:00 4.25 0 8,041 COMPZ WELLPF TRIP P PJSM,M/U Packer Milling shoe& RIH to 8041'MD,Tagged high and took 30 overpull to get free.Act= 29.92,Calc=50.42. 21:00 22:45 1.75 8,041 8,147 COMPZ WELLPF WASH P Tagged tight spot @ 8041'MDPulled out of it and establish parameters, P/U=135K,S/O=105K, Rot wt= 118K. Brk circ 4.5 bpm 450 psi, wash dn to 8035'MD took wt, P/U 10'rotate with 60 rpm&ream down to 8035'stalled out, P/U 5'took 30K O/P,Wash dn to 8035'maintain 5-8K WOM to 8037'work tight spot no O/P, P/U 5'and rotate with 60 rpm&ream out tight spot,Made connection and wash down to 8132' MD,tagged tight spot ream through with same parameters, Increase pump rate to 5 bpm 550 psi and ream dn to 8146',tagged some fill and hard tag @ 8147'MD. 22:45 00:00 1.25 8,147 8,149 COMPZ WELLPF MILL P Start Milling FB-1 packer @ 8147' MD T/8149'MD w/70 rpm,3-5K WOM,5 bpm 550 psi.Total losses for tour=73.42 bbls. 10/15/2012 Finish milling packer,chase dn T/8167'MD,CBU,gas to surface,Observe well, POOH and UD milling BHA, M/U Overshot BHA. RIH to 8177'MD set 20K on fish,verify fish on,open circ sub,CBU x 2, POOH and lay down fish and BHA,M/U clean out BHA with 6.125"OD Mill&RIH made it dn to 8171'MD with mill but no success getting any further.Call town,will make another run with 5.750"OD Mill to get to 8376'MD. 00:00 00:30 0.50 8,149 8,150 COMPZ WELLPF MILL P PJSM,Mill Packer as per-Baker, Observed wt drop off @ 8150'MD started to chase down and tag, Observe gas to surface,decision made to CBU. 00:30 01:15 0.75 8,150 8,150 COMPZ WELLPFCIRC P CBU @ 4bpm 350 psi,41%flow. 01:15 01:30 0.25 8,150 8,155 COMPZ WELLPF TRIP P TIH to locate top of packer,Tagged at 8167'P/U to 8155'MD. 01:30 02:15 0.75 8,155 8,155 COMPZ WELLPFCIRC P CBU @ 8.5 1450 psi,reduce pump rate to 6 bpm 800 psi,dur to loss. 02:15 02:45 0.50 8,155 8,078 COMPZ WELLPF OWFF P Monitor well,observed fluid dropping, rack back one stand and blow down. 02:45 05:30 2.75 8,078 342 COMPZ WELLPF TRIP P POOH F/8078'T/342',Act=78.37, Calc=50.42. 05:30 06:30 1.00 342 0 COMPZ WELLPF PULD P UD BHA as per Baker. Page 15'of 20 • • Time Logs Date From To - Dur S.Depth E.Depth Phase Code Subcode T 'Comment 06:30 06:45 0.25 0 0 COMPZ WELLPF PULD P Clear&clean rig floor. 06:45 07:00 0.25 0 0 COMPZ WELLPF SFTY P PJSM, HRW,and HRC on M/U _ overshot BHA 07:00 08:00 1.00 0 317 COMPZ WELLPF PULD P M/U Overshot BHA as per-Baker to 317'MD. 08:00 10:45 2.75 317 8,042 COMPZ WELLPF TRIP P RIH F/317'T/8042'MD, Breaking circ every 25 stands to ensure pipe is clear.Act=29.24,Calc=50.72. 10:45 11:00 0.25 8,042 8,176 COMPZ WELLPF CIRC P Brk circ 2 bpm 100 psi, P/U= 136K, S/O=106K,TIH tag up 8177'chase to 8187'set 20K down,pulled 150K broke over, P/U to 8176"with 10K drag,turned pumps on to verify we were latched on packer,pressured up indicating we had packer. 11:00 11:15 0.25 8,176 8,176 COMPZ WELLPF OTHR P Drop ball rod and let fall free for 15 min. 11:15 11:30 0.25 8,176 8,176 COMPZ WELLPFCIRC P Pressure up to 2200 psi to open circ sub. 11:30 12:00 0.50 8,176 8,176 COMPZ WELLPF CIRC P CBU x 2,5 bpm 900 psi. 12:00 12:45 0.75 8,176 8,176 COMPZ WELLPF CIRC P Continue CBU x 2 w/5 bpm 1000 psi. 12:45 13:00 0.25 8,176 8,145 COMPZ WELLPFOTHR P Rack back stand and blow down, observed well fluid dropping while monitor well. 13:00 17:30 4.50 8,145 0 COMPZ WELLPF TRIP P PJSM, POOH F/8145'to surface, UD BHA&Fish, lenght of fish= 20.14.Act=81.6,Calc=50.74. 17:30 18:45 1.25 0 0 COMPZ WELLPF PULD P Clear and clean rig floor, P/U BOT subs for next run. 18:45 22:45 4.00 0 8,155 COMPZ WELLPF PULD P PJSM,M/U clean out BHA and RIH to 8155'MD,Act=30.26,Calc= 50.85. 22:45 00:00 1.25 8,155 8,166 COMPZ WELLPF MILL P Brk circ 5 bpm 625 psi,60 rpm, P/U=137K,S/O= 106K, Rot wt= 122K,wash and ream down to 8166' MD took 3K WOM&stalled out 28K O/P,tried diff.parameters at reaming no success. 10/16/2012 CBU, POOH UD BHA,service rig,M/U clean out BHA RIH U 8154'Ream t/8359',CBU, POOH, LID BHA,35 lbs metal debris in boot baskets, N/D riser Bell nipple, N/U shooting flange, R/U ELine RIH w/5.9"Gauge ring 00:00 00:30 0.50 8,166 8,166 COMPZ WELLPF CIRC P CBU @ 294 gpm 1000 psi 00:30 00:45 0.25 8,166 8,166 COMPZ WELLPF OWFF P Observe well for flow,static loss 00:45 03:15 2.50 8,166 513 COMPZ WELLPF TRIP P Pooh f/8166't/513' 03:15 04:00 0.75 513 0 COMPZ WELLPF PULD P Stand back and UD BHA 04:00 04:45 0.75 0 0 COMPZ WELLPF SVRG P Service rig. 04:45 05:00 0.25 0 0 COMPZ WELLPF SFTY P PJSM on P/U BHA 05:00 05:30 0.50 0 512 COMPZ WELLPF PULD P M/U clean out BHA 05:30 07:30 2.00 512 8,154 COMPZ WELLPF TRIP P TIH f/512'U 8154' Page l6of20 • •. Time Logs Date From To ' Dur . S.Depth E.Depth Phase Code Subcode T : Comment 07:30 09:00 1.50 8,154 8,359 COMPZ WELLPF REAM P break circ @ 210 gpm 600 psi,ream U 8359'take weight 10k,pressure increase, P/U,CBU 09:00 10:00 1.00 8,359 8,359 COMPZ WELLPF CIRC P Pump 30 bbl hi-vis sweep 315 gpm 1175 psi. 10:00 10:15 0.25 8,359 8,359 COMPZ WELLPF OWFF P Observe well for flow,well static, blow down top drive. 10:15 14:30 4.25 8,359 512 COMPZ WELLPF TRIP P Pooh f/8359't/512' 14:30 15:30 1.00 512 0 COMPZ WELLPF PULD P Stand back LID BHA 15:30 16:30 1.00 0 0 COMPZ WELLPF OTHR P M/U stack washer w/magnet&flush stack,simops clean junk baskets 35 lb debris L/D stack washer blow down top drive. 16:30 17:15 0.75 0 0 COMPZ WELLPF OTHR P Clean&clear rig floor, L/D Subs prep floor for eline. 17:15 19:45 2.50 0 0 COMPZ WELLPF NUND P Nipple down riser&bell nipple, Nipple up shooting flange. 19:45 22:00 2.25 0 0 COMPZ WELLPF ELOG P R/U E-Line Equip.&M/U tools. 22:00 23:00 1.00 0 8,368 COMPZ WELLPF ELOG P RIH w/5.9 gauge rind on E-Line U 8368' 23:00 00:00 1.00 8,368 0 COMPZ WELLPF ELOG P POOH w gauge ring f/8368' 10/17/2012 RID Gauge ring,Change out tools U isolation packer, RIH set Isolation Packer @ 8167'top of packer, POOH, R/D ELine, RIH w/test packer U 8161',set packer attempt U test unable to hold pressure, retest multiple times,no ball on seat,drop ball and rod,unable U pressure up, R/U slickline U push ball&rod on seat. 00:00 01:45 1.75 0 0 COMPZ WELLPF ELOG P Rig down guage ring run w/eline, change out tool string U packer run and isolation packer. 01:45 04:30 2.75 0 0 COMPZ WELLPF ELOG P RIH w/isolation packer U 8159'set packer as per coralation w/orignal gamma ray survey, POOH 04:30 05:15 0.75 0 0 COMPZ WELLPF ELOG P R/D running tools and ELine equipment. 05:15 05:30 0.25 0 0 COMPZ WELLPF SFTY P Pre job safety meeting on nippling down shooting flange. 05:30 07:00 1.50 0 0 COMPZ WELLPF NUND P Nipple down shooting flange nipple up riser&bell nipple. 07:00 07:15 0.25 0 0 COMPZ WELLPF SFTY P Pre job safety meeting on picking up BHA. 07:15 07:45 0.50 0 17 COMPZ WELLPF PULD P P/U test packer BHA 07:45 10:45 3.00 17 8,161 COMPZ WELLPF TRIP P RIH f/17'U 8161'setting test packer. 10:45 11:00 0.25 8,161 8,161 COMPZ WELLPF RURD P R/U U test packer. 11:00 12:00 1.00 8,161 8,170 COMPZ WELLPF PRTS T Attempt to pressure up U 1000 psi didn't hold pressure, retest numerous times unable to test. 12:00 12:30 0.50 8,170 8,032 COMPZ WELLPF TRIP T POOH f/8170't/8032' 12:30 13:00 0.50 8,032 8,032 COMPZ WELLPF OTHR T Set test packer,close rams test ann.U 2500 f/10 min. bleed off and open well. Page 17 of 20 ! • Time Logs Date From To Dur S.Depth E.Death Phase Code Subcode T • Comment 13:00 15:00 2.00 8,032 8,170 COMPZ WELLPF OTHR T RIH t/8170'set packer,drop ball& rod,wait 10 min,attempt pressure test, unable to test, unseat packer work string est circ.210 gpm reset packer attemopt to test no good, R/D test equip. 15:00 16:00 1.00 8,170 8,170 COMPZ WELLPF OTHR T Wailt on Halliburton slick line, simops rig service 16:00 17:30 1.50 8,170 8,170 COMPZ WELLPF RURD T P/U tools&equipment f/wire line, spot unit. 17:30 20:45 3.25 8,170 8,170 COMPZ WELLPF SLKL T R/U slick line unit and equip.test lubricator t/500 psi. 20:45 21:30 0.75 8,170 8,170 COMPZ WELLPF SLKL T RIH w/LIB on slick line t./8368' WLM tag up 5 times. 21:30 22:00 0.50 8,170 8,170 COMPZ WELLPF SLKL T POH w/LIB 22:00 00:00 2.00 8,170 8,170 COMPZ WELLPF RURD T R/D lubricator,M/U head pin,set packer,M/U cmt line&attempt t/ test packer multiple times unable to pressure test leaking off, R/D test equipment, release test packer. 10/18/2012 R/D slickline,slip&cut drill line, POOH,UD BHA, R/U wireline, Pull Ball&Rod, Retrieve plug, install xx plug in profile R/D wireline,R/U&test BOP's 00:00 00:15 0.25 8,170 8,170 COMPZ WELLPF SFTY T PJSM R/D slickline 00:15 00:30 0.25 8,170 8,145 COMPZ WELLPF RURD T RID&clear wireline equip. UD pup 00:30 00:45 0.25 8,145 8,145 COMPZ WELLPFSFTY P PJSM SLip Cutting Drilling Line 00:45 01:45 1.00 8,145 8,145 COMPZ WELLPFSLPC P Slip&Cut Drill Line 01:45 04:45 3.00 8,145 16 COMPZ WELLPF TRIP T POOH f/8145't/16' 04:45 05:15 0.50 16 0 COMPZ WELLPF PULD T L/D BHA clear floor. 05:15 05:45 0.50 0 0 COMPZ WELLPF SFTY T PJSM on Rigging up t/wireline. 05:45 07:30 1.75 0 0 COMPZ WELLPF NUND T Nipple down bell nipple&riser, Nipple up shooting flange. 07:30 08:00 0.50 0 0 COMPZ WELLPFSVRG P Service Rig 08:00 08:15 0.25 0 0 COMPZ WELLPF SFTY P PJSM R/U Wire line 08:15 12:00 3.75 0 0 COMPZ WELLPF SLKL T R/U HES slickline equipment,crew change w/slickline. 12:00 13:00 1.00 0 0 COMPZ WELLPF SLKL T RIH t/8368'retrieve ball&rod, POOH 13:00 13:30 0.50 0 0 COMPZ WELLPF SLKL T C/O tools t/brush&plug retrieval tool. 13:30 14:45 1.25 0 0 COMPZ WELLPF SLKL T RIH t/8370',brush nipple @ 8170' POOH Retrieve plug 14:45 15:00 0.25 0 0 COMPZ WELLPF SLKL T C/O tools RIH W/XX plug 15:00 16:00 1.00 0 0 COMPZ WELLPF SLKL T RIH set XX plug @ 8172'WLM, POOH 16:00 17:00 1.00 0 0 COMPZ WELLPF RURD T R/D slickline equip. 17:00 19:15 2.25 0 0 COMPZ WELLPF NUND T N/D shooting flange,pull wear bushing, N/U bell nipple 7 riser. 19:15 20:00 0.75 0 0 COMPZ WELLPF BOPE P R/U t/test BOP Page 18 of 20 r • Time Logs Date From To . Dur S. Depth E.Depth Phase Code Subcode T Comment 20:00 00:00 4.00 0 0 COMPZ WELLPF BOPE P Test Bope choke valves 1-14, HCR& Man.Choke&Kill,Auto&Man IBOP,4"de m co,tiw&dart, u pp er lowe and blind rams,ann.prey.t/ 250 low 3500 high all w/4"test jt. Valve#9 failed) 10/19/2012 Continue testing BOP's, Rebuild/Replace Valve that failed in choke mannifold, P/U test packer BHA, RIH t/ 8147'set packer test t/1000 f/10 min good test, POOH w/BHA R/U t/run 3.5 completion. 00:00 05:00 5.00 0 0 COMPZ WELLPF BOPE P Continue testing Bop's w/3.5 test jt. Top Bottom&ann.t/250/3500, accumulator test. 05:00 15:15 10.25 0 0 COMPZ WELLPF BOPE P Rebuild&remove valve#9 that failed during BOPE test, install valve and retest 250/3500, R/D test equipment. 15:15 15:45 0.50 0 288 COMPZ WELLPF PULD T M/U test packer BHA 15:45 19:15 3.50 288 8,147 COMPZ WELLPF TRIP T RIH f/288'U 8147' 19:15 19:45 0.50 8,147 8,147 COMPZ WELLPF PRTS T Set packer @ 8147'R/U&test packer&XX plug t/1000 psi f/10 min.good test bleed off&unseat packer R/D test equip. 19:45 20:00 0.25 8,147 8,147 COMPZ WELLPF OWFF P Observe Well for flow static slight loss 20:00 22:45 2.75 8,147 288 COMPZ WELLPF TRIP P Pooh w/test packer f/8147't/288' 22:45 23:15 0.50 288 0 COMPZ WELLPF PULD P Stand Back&UD BHA 23:15 00:00 0.75 0 0 COMPZ RPCOM RURD P R/U t/run Upper 3.5 completion 10/20/2012 R/U and run 3.5 upper completion,displace well w/corrosion inhibited brine,shear out PBR, Land on hanger @ 8165', Nipple down stack nipple up adaptor&tree,test tree t/250/2500. 00:00 00:15 0.25 0 0 COMPZ RPCOM RURD P Continune rigging up to run 3.5 completion 00:15 01:00 0.75 0 0 COMPZ RPCOM OTHR P R/U&pull wear ring R/D 01:00 01:15 0.25 0 0 COMPZ RPCOM SFTY P Pre Job Safety Meeting on Running completion 01:15 10:30 9.25 0 8,137 COMPZ RPCOM RCST P Run 3.5 completion as per detail t/ no go @ 8168' UD 1 jt of tubing. 10:30 11:15 0.75 8,137 8,137 COMPZ RPCOM RURD P R/U t/displace corrosion Inhibited Brine 11:15 11:30 0.25 8,137 8,137 COMPZ RPCOM SFTY P Pre Job Safety Meeting on displacing fluid. 11:30 12:45 1.25 8,137 0 COMPZ RPCOM CIRC P Displace 9.3 ppg corrosion Inhibited brine @126 gpm 200 psi shut down pumping leaving 3 bbls in tubing. 12:45 13:30 0.75 8,137 8,137 COMPZ RPCOM OTHR P Slack off and locate FB-1 packer, P/U to neutral wt.and P/U 1 ft, pressure up tubing t/2500 psi to set packer,shear PBR. 13:30 15:15 1.75 8,137 8,165 COMPZ RPCOM OTHR P UD 3 jts.for space out,make up space out pups&jt.M/U hanger& landing jt. Land tubing on hanger @ 8165. RILDS 15:15 15:30 0.25 0 0 COMPZ RPCOM RURD P R/U t/test tubing&Ann. Page 19 of 20 • Time Logs Date From To Dur . S.Depth E.Depth Phase Code Subcode T Comment 15:30 17:15 1.75 0 0 COMPZ RPCOM PRTS P Pressure test tubing t/3500 for 30 min.bleed tubing V 300 test ann.t/ 3500 for 30 min. bleed Ann.and tubing V 0 psi 17:15 18:00 0.75 0 0 COMPZ RPCOM OWFF P Observe well for flow f/30 min.static 18:00 18:45 0.75 0 0 COMPZ RPCOM OTHR P Set BPV, Blow down lines,drain stack. 18:45 19:00 0.25 0 0 COMPZ RPCOM SFTY P Pre Job Safety Meeting on Nippling down stack. 19:00 20:15 1.25 0 0 COMPZ RPCOM NUND P Nipple down bell nipple, riser&BOP stack. 20:15 21:30 1.25 0 0 COMPZ RPCOM NUND P Nipple up tubing head adaptor,test t/ 250/5000 psi f/10 min. 21:30 00:00 2.50 0 0 COMPZ RPCOM NUND P Nipple up tree,set tree test plug, test tree t/250/5000 psi,flange leaked,tighten&retest. 10/21/2012 R/U Shear SOV freeze protect well w/85 bbls diesel allow t/u-tube put in communication,set BPV Secure well, UD4"dp, Rig realeased @1300 hrs. 00:00 00:45 0.75 0 0 COMPZ RPCOM RURD P R/D test equipment,pull tree test plug, R/U V freeze protect. 00:45 01:00 0.25 0 0 COMPZ RPCOM SFTY P Pre Job Safety Meeting on Freeze protecting well. 01:00 04:00 3.00 0 0 COMPZ RPCOM FRZP P Pressure test LRS V 2500 psi,shear out SOV w/1300 psi,pump 85 bbls of diesel @ 84gpm down IA,Put tubing and IA in communication, Let well U-Tube,check tubing pressure, 0 psi blow down lies R/U freeze protect equip.Simops clear floor R/U t/UD 4"DP f/Derrick. 04:00 04:30 0.50 0 0 COMPZ RPCOM RURD P Set BPV as per FMC, Install gauges secure well. 04:30 04:45 0.25 0 0 COMPZ RPCOM SFTY P Pre Job Safety Meeting on UD Drill pipe 04:45 13:00 8.25 0 0 COMPZ RPCOM PULD P UD dp via mouse hole. 13:00 13:00 0.00 0 0 COMPZ MOVE MOB P Rig Realeased @ 1300 hrs Page 20 of 20 • AITE ALAsia C; SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 N SE CORVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 CONSERVATION (907) 279 -1433 FAX (907) 276 -7542 Erik Nelson n � Wells Engineer ConocoPhillips Alaska, Inc.' P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2A -08 Sundry Number: 312 -333 Dear Mr. Nelson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, g( 9 Cathy i Foerster Chair DATED this W day of September, 2012. Encl. • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECEIVED 27 August 2012 AUG 2 7 2012 Commissioner Dan Seamount �OGVV r+V State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2A -08 (PTD 185 -248). Well 2A -08 was drilled and completed as a pre - produced injector in 1985 and converted to MWAG injection in 1988 into both the A and C sands. Well 2A -08 was shut -in May 2011 when it's well line was derated. In February 2012 it failed a mechanical integrity test for the inner annulus (MIT -IA) which, when compared with a passing combination mechanical integrity test of the tubing and inner annulus (CMIT- T +IA), indicates a tubing leak. The well cannot be returned to operation without tubing integrity. Well 2A -08 has been continuously monitored for subsidence damage; its nearest neighbors, injection wells 2A -06 and 2A -07 have been plugged and suspended because of severe damage. As with many wells on the 2A and 2T drillsites, subsidence is assumed to be the root cause of the casing and tubing issues in this well. The purpose of this workover is to restore the integrity of the tubing string and provide a stronger wellbore to combat the effects of future subsidence. This will be accomplished by replacing the 3 - %" tubing (including the selective) and also replacing the top —1,750 feet of 7" production casing. By cementing the replaced production casing to surface, this will effectively mitigate the surface casing leak and will provide a stronger wellbore. If you have any questions or require any further information, please contact me at 263 -4693. Regards, o / Erik Q. Nelson Wells Engineer CPAI Drilling and Wells S TATE OF ALASKA RECEIVE AL .A OIL AND GAS CONSERVATION COMMODN 2 t d APPLICATION FOR SUNDRY APPROVALS et 9 - 6 - 12,---`" 20 AAC 25.280 AOGCC 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well `i ° / Change Approved Program Suspend fl Rug Perforations r Perforate r Rill Tubing IF 1;:i_01. Time Extension j` Operational Shutdown Re-enter Susp. Well r Stimulate f Alter casing a' r R Wll g Other:Subsidence Repair rc. . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory [ 185 -248 • 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20049 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No p- 2A -08 . 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25570 J Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8690' �`>'e 7 6184 • Casing 5f. / L 7, ,, , Length Size MD TVD Burst Collapse CONDUCTOR 76 16 110' 110' SURFACE 3371 9.625 3406' 2787' PRODUCTION 8427 7 8459' 6152' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8076- 8139', 8185' -8214' 5850'- 5899', 5934' - 5956' 3.5 J - 8186 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - BAKER FHL PACKER MD= 7999 TVD= 5792 PACKER - BAKER FB -1 PACKER MD= 8165 TVD= 5919 SSSV - BAKER FVL SSSV MD =1785 TVD =1680 12. Attachments: Description Summary of Proposal 1' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/9/2012 Oil fl Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ f WAG P Abandoned r Commission Representative: GSTOR r SPLUG f 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Erik Nelson © 263 -4693 Printed Name rik Nelso Title: Wells Engineer 1/Z.-•- Phone: 2 63 4693 Date U✓ Signature ee , �j� Z( 7 Commission Use Only Sundry Number:31 2.3? Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test Mechanical Integrity Test 1 V , Location Clearance r l , _ . ,e1) ' iz 1 ,357'�'1 ; Ai' ar7 /}cZ,r< ;�1$)2 � �` it lf r ` Other: 6� . Subsequent Form Required: 0 -efP"), � ^-' APPROVED BY // Approved by: COMMISSIONER THE COMMISSION Date: C, r0 - / Z 0 s /2010 Vl rie S ubmit in Du licate .? ") 1 .t v q i 1 1- 1 1 7- ORIGINAL „..--,, MINIM • • 2A -08 Kupaurk Injector Expense Rig Workover PTD #: 185 -248 Current Status 2A -08 is currently SI w/ a WRP effectively isolating the A- & C -sands awaiting pre -RWO well work. Scope of Work ♦ Cut and pull 3 -W J -55 tbg above Baker FHL retrievable pkr (7999' MD) ♦ Run 7" csg scraper, run CBL, cut - pull - replace 7" csg above TOC • Pull remaining 3 -W selective completion to Baker FB -1 permanent pkr (8165' MD) ♦ Mill and retrieve Baker FB -1 pkr (8165' MD) and remaining tailpipe assembly • C /out run through C- and A -sand perfs ♦ MU and TIH to new Baker FB -1 permanent pkr and tailpipe ♦ MU and TIH w/ new 3 -' /2" L -80 selective completion to surface General Well info MASP: 2125 psi Reservoir pressure /TVD: 2710 psi / 5850' TVD (TOP in C -sand) Using SIWHP of 600 psi from numerous wellwork reports across the past 6 months and utilizing an 8.5 lb /gal seawater gradient in the tubing. We will grab an updated SBHP survey closer to the RWO start date. Wellhead type /pressure rating: FMC Gen III / 7- 1/16" 5M '` BOP configuration: Annular / Pipe / Blind / Flowcross / Pipe TIFL / MIT -IA / MIT -OA: CMIT -T + IA passed 07 March 2012 MIT -IA failed 12 February 2012 MIT -OA passed 12 February 2012 Well Type: Injector Estimated Start Date: 09 September 2012 Production Engineer: Lynn Aleshire RWO Engineer: Erik Q. Nelson Work: 263 — 4693 Cell: 903 — 7407 E -Mail: Erik.Nelson @conocophillips.com • Proposed RWO Procedure: Pre -Rig Well Work MIRU HES SL 1. Pull WRP 2. Obtain updated SBHP data w/ Panex gauges run to tbg tail (8185' MD) w/ gradient stop at 8055' MD 3. MU and RIH w/ plug for 2.250" ID (2.296" No -Go) nipple profile (8179' MD) ._._s pj 4. RIH w/ catcher sub and set on top of plug / f 5. Pull DV from GLM #1 (7943' MD) and leave open 6. Drift tbg to catcher sub w/ dummy RCT gun assembly as specified by HES E -Line supervisors and w/ dummy 3-%" WRP setting assembly MIRU HES E -Line 1. MU and RIH w/ WRP setting assembly to set WRP - 8032' MD. CMIT -T + IA to 1500 psi Bleed pressure to 0 psi and insure it stays. 2. MU and RIH w/ RCT assembly setup for 3 -W 9.3# tbg a. Cut tbg at -7966' MD (mid -jt in 1 full jt above PBR) 3. PT tbg and csg packoffs and FT LDSs 4. Set FMC Type 'ISA' BPV RU, Test, Pull Tbq, and Evaluate 7" Csq 1. MIRU Doyon 141. Accept Rig, take on fluids, pull FMC Type `ISA' BPV, circulate and bullhead KWF, and insure well is dead. 2. Install FMC Type 'ISA' BPV, ND tree, NU 13 -5/8" 5M BOPE, install blanking plug, function and PT BOPE to 250/3500 psi and annular to 250/3500 psi A ft fir fI c C 5/9 C tc'r 24-- -/ -7 e s 1 h 6r ( -I ""68.- 3. Pull blanking plug & FMC Type `ISA' BPV. Screw in landing jf, BOLDS's, and pull tbg hgr to the rig floor. 4. LD tbg hgr and TOOH sideways w/ 3 -W, J -55 EUE -Mod tbg 5. MU and TIH w/ 7" csg scraper assembly on 4" XT -39 DP 7" Csq Replacement 1. RU HES E -Line for CAST -M (or RCBL) and string shot runs. RDMO HES E -Line. 2. MU and TIH w/ RBP or IBP and set below TOC. PT to 3000 psi and drawdown test same. Dump sand on top of plug. 3. ND 13 -5/8" BOPE and tbg head. Spear and re -land 7" csg in tension. Cut off 7" csg growth ". NU 13 -5/8" 5M BOPE on 11" 3M csq head. 4. Test break to 250/1750 psi (1750 psi due to previous highest PT on OA csg is 1800 psi) 5. Cut 7" csg with multi- string cutter on drill pipe above TOC. Circ 9 -5/8" x 7" annulus clean. 6. Spear and TOOH laying down 7" csg. 7. Run 9 -5/8" csg scraper to top of 7" stub. Circ clean. 8. RU HES E -line and run gyro w/ GR and memory caliper log. RDMO E -line. 9. Run tandem string mill assembly to gauge csg for installation of new 7" csg string. Make dummy run for 7" csg and Halliburton ES cementer. 10. TIH w/ back off tool and back off csg stub. TOOH. 11. TIH w/ spear and recover csg stub. TOOH. 12. C /out lower BOP ram to 7" and test ram to 250/3500 psi. 13. TIH with new 7" csg and Halliburton ES cementer. / 14. Screw into top of 7" csg. Pressure test 7" csg to 3000 psi. ' • • • 15. Open ES cementer and pump cement (calculated plus — 25% excess) into 9 -5/8" x 7" annulus Cmt Req'd 15.7 ppg ArcticSet 1 0.93 ft /sk Estimated TOC = 2300 ft MD 84 bbl vol including excess 16. Cmt Pump Schedule (exact volumes will be adjusted according to actual TOC) a. 5 bbls freshwater b. 80 bbls neat 15.7 lb /gal ArcticSet 1 c. Launch closing plug d. Displace w/ 3 bbl neat 15.7 lb /gal ArcticSet 1 e. 5 bbls freshwater f. XX bbls heated seawater (— 90° F) to bump plug 17. WOC. ND BOPE and land 7" on slips. Cut 7" csg and install ackoff. NU tbg head. 18 N11 13 -5/8" 5M BOPE and test break to 250/3000 psi, ' = a.�;�4 7 19. Set plug in tbg head and test 13 -5/8" 5M BOPE to 250/3500 psi for 30 min and record"on chart. 20. Drill out cement and plug. Pressure test csg to 250/2500 psi for 30 min and record on chart. TOOH. 21. TIH w/ reverse circulating junk basket to clean out remaining debris. TOOH. 22. TIH with wash shoe and circulate out sand on top of RBP. TOOH. TIH w/ retrieving tool. Release RBP /IBP and TOOH. Pulling Selective Completion 23. MU and TIH w/ Fishing Assembly w/ Overshot for 3 -W tbg stub in Baker PBR. Locate and overshot tbg stub. TOOH w/ tbg stub. 24. MU and TIH w/ PBR Retrieving Assembly. TIH to retrieve selective completion above Baker FHL pkr. TOOH and lay down same. 25. MU and TIH w/ Baker FB -1 pkr Mill /Retrieve Assembly. Mill up and Retrieve Baker FB -1 pkr. TOOH and lay down same. 7" Csq Cleanout and run 3 -Y" Selective Completion 26. MU and TIH w/ 7" Csg Scraper w/ RCJB. Cleanout to PBTD and TOOH. 27. MU and TIH w/ Baker FB -1 pkr and tailpipe assembly on 4" XT -39 DP. Set pkr — 8160' MD. 28. MU and TIH w/ Selective and Baker FHL / PBR assembly on 4" XT -39 DP. Set pkr — 7980' MD. TOOH laying down 4" XT -39 DP. 29. MU and TIH w/ 3 -W L -80 completion 30. Load tbg and IA with diesel. Stab seal assembly into PBR and space out. PT tbg and IA to 2500 psi respectively for 30 min and record on chart. 31. Set 2 -way check. ND BOPE. NU tree and pressure test tree and packoffs to 250/5000 psi. 32. Pull 2 -way check. Freeze protect well. Set FMC Type 'ISA' BPV. 33. RDMO Doyon 141. Post -Rig Work: MIRU HES Slickline 1. Pull SOV from GLM and replace w/ DV 2. Handover to Ops to put back on injection µ (�_ IA t ` ', . � r�. KUP 2A -08 \ Conoco Ph fillips V ,' Well Attributes Max Angle & MD TD ' a:, Wellbore API /UWI Field Name Well Status Ind (°) MO (ftKB) Act Btm (ftKB) Alaska. (r1" IV d 501032004900 KUPARUK RIVER UNIT INJ 53.68 7,325.00 8,500.0 LOnocoPha9p5 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: LOCKED OPEN Last WO: 41.20 10/31/1985 Well Conag' - 2A-08, f2012 2:15:12 PM Schematic 315 -Aaual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 8,189.0 10/24/2010 Rev Reason: SET WRP ninam 3/5/2012 Casing Strings Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) .. String Wt.. String ... String Top Thrd CONDUCTOR 16 15.060 34.0 110.0 110.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd `' SURFACE 95/8 8.765 34.7 3,405.7 2,787.0 36.00 J - 55 BTC '. Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 32.5 8,459.4 6,151.5 26.00 J -55 BTC HANGER. 33 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 32.8 8,185.6 5,934. 9.30 J-55 8RD Completion Details ! Top Depth !I (TVD) Top Incl Nomi... I Top (ftKB) MB) ( °) Item Description Comment ID (in) 32.8 32.8 -0.41 HANGER FMC GEN III TUBING HANGER 3.500 1,784.5 1,680.4 35.07 SAFETY VLV BAKER FVL SAFETY VALVE, LOCKED OUT 9/1/98 2.813 CONDUCTOR, 7,9$5,4 5,781.3 41.81 PBR BAKER PBR 3.000 34 - 110 7,999.1 5,791.5 41.29 PACKER BAKER FHL PACKER 4.000 III 8,076.0 5,850.1 39.90 BLASTJT 2.992 8,156.6 5,912.1 38.92 NIPPLE PORTED NIPPLE with 2 7/8" CROSSOVER 2.750 SAFETY VLV, 1 o 8,164.2 5,918.1 38.91 LOCATOR BAKER 4.000 1,785 8,164.9 5,918.6 38.91 PACKER BAKER FB-1 PACKER 4.000 8,179.4 5,930.0 39.20 NIPPLE CAMCO D NIPPLE 2.250 8,184.9 5,934.2 39.11 SOS CAMCO SOS 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Intl Top (,KB) (,KB) (0 Description Comment Run Date ID (in) 8,032 5,816.4 40.31 WRP WEATHERFORD WRP (SPECIAL CLEARANCE 2.69"OD) 3/4/2012 0.000 SURFACE, 406 ' . ; 8,157 5,912.1 38.92 SLEEVE -C AVA. TPI with extended packing area. 10/7/1998 2.313 Perforations & Slots GAS LIFT, Shot ]•943 Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (s Type Comment (,. 8,076 8,139 5,850.1 5,898.5 C-4, 2A -08 11/7/1985 12.0 IPERF 120 deg. phasing; SOS Csg Gun 8,185 8,214 5,934.3 5,956.2 A -3, 2A -08 11/7/1985 4.0 IPERF 90 deg. phasing; SOS Csg Gun Li , (`"r I No tes: General & Safety End Date Annotation PBR. 7 985 9/8/2010 NOTE: View Schematic w/ Alaska Schematic9.0 PACKER, 7,999 V i WRP, 8,032 GAS LIFT, 8,038 IRF, 8.0] -8,139 _ SLEEVE-C, 8,157 NIPPLE, 8,157 LOCATOR, 8,164 PACKER, 8,165 ' NIPPLE, 8,179 it IF Mandrel Details Top Depth Top Port _ (TVD) Ind OD Valve Latch Size TRO Run SOS,8.185 = _ Stn Top(ftKB) (ftKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... = 1 7,943.4 5,749.9 42.07 CAMCO MMG-2 1 GAS LIFT DMY BK 1.500 0.0 11/28/2010 IPERF, _ 2 8,037.8 5,820.8 40.30 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 11/28/2010 8,185-8,214 I I PRODUCTION, 32 -8.459 TO, 8,500 z a-547 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 5, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 2A -08 SE P 2 4 ZU1Z Run Date: 3/4/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -08 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20049 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: *Y12. Signed: WIL /r G� • 2a- -o Prb 16524-too Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, February 14, 2012 4:51 PM l \�' 41,41( 7i To: Regg, James B (DOA) Subject: RE: 2A -08 (PTD 185 -248) Report of failed MITIA Attachments: MIT KRU 2A -08 02- 12- 12.xls Jim, Attached is a copy of the MITIA and the MITOA that were performed. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 From: Regg, James B (DOA) [mailto:jim.regg ©alaska.gov] Sent: Tuesday, February 14, 2012 10:45 AM To: NSK Problem Well Supv Subject: [EXTERNAL]RE: 2A -08 (PTD 185 -248) Report of failed MITIA Please send MIT results Jim Regg AOGCC � �� iL 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 7934236 From: NSK Problem Well Supv [ mailto :n1617C@conocophillips.com] Sent: Monday, February 13, 2012 11:10 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; Dethlefs, Jerry C; Glessner, Dana Subject: 2A -08 (PTD 185 -248) Report of failed MITIA Jim, Guy i Kuparuk injector 2A -08 (PTD 185 -248) failed a diagnostic MITIA on 02/12/12. Following the MITIA, a passina MITOA was performed. The well has been shut -in since May 2011 and will be added to the monthly injector report. Diagnostics will be done using Slickline and E -line if necessary. Pending the outcome of the diagnostics, the appropriate paperwork will be submitted for repair or continued injection. Attached are a schematic and a 90 day TIO plot. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 - 7224 Pager (907) 659 -7000 pgr. 909 1 KRU 2A-08 PTD 1852480 2/13/2012 TIO Pressures Plot TRN_ANNL ANNULUS PRESSURE TRENDS WLKRU2A -08 3000. 3000 200. 3000. 2700 3900. 3000. 2400 3000. 2100 1800 1500 1200 ---- ----- - 900 600 n. AA AAAA-A AA AA A A-A 1 AA-AA O. 0. 300 ArA 7 A AA AA AA- A* AA 11111111 0. 0, 0. PLOT START TIME MINOR TIME PLOT DURATION PLOT END TIME 15-NOV-11 11:11 MAJOR TIME WEEK +02160:00:00 ims13 -FEB -12 11:11 1111 rEFECTITIFEI!! 1111111111111 131 picx TIME 13-FEB-12 11:06:20 TAG NAME DESCRIPTION Fir WL2A-08 -CHOKE FLOW TUBING CHOKE •PREV WELL DRILLSITE WELL FEW SCRATCH 42 FLOW TUBING PRESSURE ??????? 2A 08 SCRATCH_42 FLOW TUBING TEMP 7772277 11. NEXT WELL 7?????? Par ??????? ENTRY TYPE OPERATOR 7277777 OPERATOR VERIFIED PP! SCRATCH_42 INNER ANNULUS PRES 7?????? III SYSTEM AUTO ENTRY SCRATCH_42 OUTER ANNULUS PRES ??????? BOTH KUP p 2A -08 ConocoPhillips � O 'r t " ield ' "",' iii irr ±I� p" ?�! i s i t I(Re Xi''. a y 8 ,I - i , it'1C Wellbore A PIIUW I F Name Well Status Inc! r) MD (ftKB) Act Btm (ttKB) ° - e ps 501032004900 KUPARUK RIVER UNIT INJ 53.68 7,325.00 8,500.0 '""' Comment H25 (ppm) Date Annotation End Data KB - Ord (d) Rig Release Date Wet Car 6a: •2A -00 i2i2011 SSSV:LOCKEDOPEN Last WO: 41.20 10/31/1985 Schematic. Adpel Annotation Depth (ttKB) End Date Annotation Last Mod ... End Date Last Tag: 8,189.0 10/24/2010 Rev Reason: SAFETY VLV LOCK OUT DATE ninam 12/1/2011 asi` a Strin . s' qL i 1 ,C , Casing Description String O String ID .. Top (ttKB) Set De ( f . Set Depth (ND) .,. String Wt... String ... String Top Thrd CONDUCTOR 16 15.060 34 110. 110.0 62.50 H WELDED Casing Descripdon String 0... String ID ... Top ( tt K B) Sat Depth (0... Set Depth (ND) ... String Wt... String .. String Top Thrd - SURFACE 95/8 8 765 34 34.7 3,405 7 2,787.0 36.00 J BTC I Casing D escripdo n String O String ID Top (ftKB) Set Depth (1 Set Depth (ND) ... String Wt . String String Top Thrd i ' PR O D UC T ION 7 6 276 32 5 8,459.4 6,151.5 26 00 J-59 BTC l i.. L i' .� IN w iii;, ,n,1 _ HANGER, 33 Tubing Descripdon Siring 0.. String I0 Top (ftKB) Set De _. Set Depth ( TVD ) ... String Wt .. String String Top Thrd ' TUBING 31 29 328 8 5,934.7 9.30 J55 8RD ° a �j[i�� Mika :��,' - �- .�i' :- . t. ri ,. ��i4i £ , Top Depth (ND) Top Mal Nomi... $iii m To p (ttKB) MRS) (1 Item Description Comment ID (in) a`� 32.8 32.8 -0.41 HANGER FMC GEN 111 TUBING HANGER 3.500 1,784.5 1,680.4 35.07 SAFETY VLV BAKER FVL SAFETY VALVE, LOCKED OUT 9/1/98 2.813 CONDUCTOR. 7,985.4 5,781.3 41.81 PBR BAKER PBR 3.000 34 - 110 7,999.1 5,791.5 41.29 PACKER BAKER FHL PACKER 4.000 8,076.0 5,850.1 39.90 BLASTJT 2.992 8,156.6 5,912.1 38.92 NIPPLE PORTED NIPPLE with 2 7/8" CROSSOVER 2.750 8 ,164.2 5,918.1 38.91 LOCATOR BAKER 4.000 SAFETY Vi.v. 8,164.9 5,918.6 38.91 PACKER BAKER FB -1 PACKER 4.000 I 1,785 8,179.4 5,930.0 39.20 NIPPLE CAMCO D NIPPLE 2.250 L 8,184.9 5,934.2 39.11 SOS CAMCO SOS 2.992 Other In :17 i " able!- ; � ., `r m Top Depth _ ... . (ND) Top not Top (111(8) (ttKB) () Description Comment Run Date ID (in) 8,157 5,912 1 38.92 SLEEVE -C AVA. TPI with extended packing area. 10/7/1998 2.313 . ' ° ' .. rr Ir i ��5 ., A ;... ar SURFACE. ° � >:� iii -- Ott _ '�' " �i r . 35 3 408 Shot Top (ND) Btm (ND) Dens Top (ttKB) Btm (ftKB) (ftKB) (ttKB) zone Dote (eh... Type Comment GAS LAT. 8,076 8,139 5,850.1 5,898.5 C-4, 2A -08 11/7/1985 12.0 I PERF 120 deg. phasing; SOS Csg Gun 7,sa3 8,185 8,214 5,934.3 5,956.2 A -3, 2A -08 11/7/1985 4.0 IPERF 90 deg. phasing; SOS Csg Gun _ J & Safe u End Date An tat 9/8/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 PBR, 7,985 PACKER, 7,899 GAB LIFT, r 8,038 tf PERF, 8.078$139 — ' _ ,_„. .„_„ : ._._, , . le .. _., SLEEVE -C, 8,157 NIPPLE, 8,157 LOCATOR, 8,160 P PACKER, 8,165 i 2 , wr I I NIPPLE, 8.179 I � a � ... I ii Px . ' A, mte.kse„a . 'ehi pi' . I ii ' :- Top Depth Top Port SOS, 8,185 _ - (ND) loci OD Valve Latch Size TRO Run Stn Top (ttKB) (ttKB) (1 Make Model (in) Sery Type Type (In) (pal) Run Date Com... 1 7,943.4 5,749.9 42.07 CAMCO MMG - 2 1 GAS LIFT DMY BK 1.500 0.0 11/28/2010 IPERF, 8,i8S8,214 - _. 2 8,037.8 5,820.8 40.30 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 11/28/2010 PRODUCTION. 32 -8.458 ' TD. 8,500 I I • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaaCDalaska.gov; doa .aogcc.orudhoe.bavnalaska.00v; phoebe.brooksC alaska.aov; tom.maunderealaska.gov OPERATOR: ConocoPhillips Alaska Inc. - Re ff - ._- - j FIELD 1 UNIT I PAD: Kuparuk / KRU / 2A DATE: 02/12/12 OPERATOR REP: Colee / Phillips - ASRC AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2A -08 Type Inj. N TVD ' 5,792' Tubing 600 620 620 Interval 0 P.T.D. 1852480 Type test P Test psi 1500 Casing 460 ' 2,200 975 P/F F Notes: Diagnostic MITIA OA 180 190 190 Well 2A -08 • Type Inj. N TVD 5,792' Tubing 620 620 620 Interval 0 P.T.D. 1852480 ' Type test P Test psi 1500 Casing 975 2,200' '850 P/F F Notes: Diagnostic MITIA OA 190 190 190 Well 2A -08 - Type Inj. N TVD ' 5,792' Tubing 620 620 620 620 Interval 0 P.T.D. 1852480 ' Type test P Test psi 1500 Casing 500 510 510 510 P/F P - Notes: Diagnostic MITOA OA 190 1800 1710 1680 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL. Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT KRU 2A - 08 02 - 12 - 12 V65 - 24% WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 15, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 2A -08 Run Date: 8/28/2011 5i,-ANNED SE( 4 LU1 L The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -08 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20049 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 103 - 20049 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 -273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 12 $ Signed: )4 644 D ' O / SE! R NELLGOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 John Peirce Wells Engineer ConocoPhillips Alaska, Inc. mg 2 2 Zat P.O. Box 100360 Anchorage, AK 99510 a.t't g Re: Kuparuk River Field, Kuparuk River Oil Pool, 2A -08 Sundry Number: 311 -074 Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sin .-rel OO Jo • a • O ■1 1 .ioner DATED this (day of March, 2011. Encl. • • • • STATE OF ALASKA ALAS AND GAS CONSERVATION COMMISSI APPLI FOR SUNDRY APPROVA S IA 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Rug Perforations r Perforate r Rill Tubing r Time Extension Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing Other: Install Patch 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 185 -248 3. Address: 6. API Number: Stratigraphic r Service F.7 • P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20049 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes fl No 17 2A -08 . 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25570 • Kuparuk River Field / Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8500 • 6184 • 8377' 6083' Casing Length Size MD ND Burst Collapse CONDUCTOR 76 16 110' 110' SURFACE 3371 9 - 5/8" 3406' 2787' PRODUCTION 8427 7 8459' 6152' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8076- 8139', 8185-8214' 5850'- 5899', 5934' - 5956' 3.5 J - 8185 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - BAKER FHL PACKER MD= 7999 TVD= 5792 PACKER - BAKER FB -1 PACKER MD= 8165 TVD= 5919 SAFETY VLV - BAKER FVL SSSV MD= 1785 TVD= 1680 12. Attachments: Description Sunmary of Proposal J 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/20/2011 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r . GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce © 265 -6471 Printed Name John Peirce Title: Wells Engineer Signature h1 • .�,°••y�� Phone: 265 -6471 Date 2 •*2,9,-1 j Commission Use Only Sundry Number: 31 I_0-i 1 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r MAR 1 1 2011 Other: Alaska Oil & Gas Cons. Commission Subsequent Form Required: /D— yoy ei rcno fage APPROVED BY 3!`! - v Approved by: 1,6 ?Maki N A r r /7. ' ( 10 403 R 2 ��� '�/ j • Proposed 2A -08 Injector Tubing Patch Installation 2A -08 is a C and A sand selective injector. A 7 -11 -10 (PROF shows almost all PWI enters the C sand via an eroded GLM at 8038' RKB. This mandrel prevents proper regulation of a desired C sand split. This mandrel be isolated with a retrievable patch containing a DH Choke Sub to enable the optimization of the C and A sand splits. After a successful patch, the 1 -3/8" ID patch can be logged through to verify proper splits. The top of the patch can be pulled to adjust the DH Choke nozzle size, if needed. 2A -08 is currently on PWI at 6900 BWPD at 2340 WHIP with nearly 100% of PWI to the C sand through an eroded mandrel at 8038' RKB (per 7 -11 -10 IPROF splits). Coil Tubing: 1. RIH with nozzle and perform a fill cleanout to as deep as possible to create rat hole prior to running a tubing patch. There is 11' of fill in the A sand perf interval per last tag of 10- 24 -10. Slickline: 2. RIH & pull the CV from the eroded mandrel at 8038' RKB. Leave pocket open. 3. RIH with gauges and obtain a combined SBHPS at 8200' RKB. No SBHPS has been attained in 2A -08 since 2003. 4. Brush & Flush the 3.5" tubing at 8010 - 8060' RKB in the targeted patch set area. 5. Run a Caliper log from the 3.5" tubing tail at 8185' RKB to surface to determine the integrity of the tubing before running a tubing patch. 2A -08 has 26 yr old J -55 tubing that has never been caliper logged. E -line: Install 20' Retrievable Tubing Patch with a DH Choke as follows: 6. RIH with 2.74" run OD Packer for 3.5" tubing. Set packer in the 3.5" tubing at 8050' RKB (6' below top of a full joint below the eroded mandrel to be patched). Slickline: 7. RIH with a 2.74" run OD Packer, spacer pipe section with 2.75" run OD DH Choke Sub, and Anchor Seal Assembly. Sting and latch into the lower packer at 8050' RKB and set the top packer at 8030' RKB. This puts the top packer 7' above the bottom of a full joint above the eroded mandrel to complete the tubing patch at 8030 - 8050' RKB (seal to seal). RIH with test plug and set it in the packer at 8030' RKB. PT upper packer to 2500 psi. POOH with test plug. RD. Return 2A -08 to injection to obtain a valid injection rate and WHIP. i i • - `-' 0 ��, KUP 2A -08_ ConocoPhilhps a 1 ` Well Attributes Max Angle & MD I TD A� ka Inc W /UWI Field Name Well Status Inc!( °) MD (ftKB) Il ActBlm(866) C,omaii dMlw ; I 501032004900 I KUPARUK RIVER UNIT , INJ 53.68 7,325.00 8,500.0 I Comment 92S (ppm) Date Annotation End Date KB (ft) ' Release Date Welloryfig. - 2A - 0@;11 1v 3 :a� PM ISSSV• LOCKED OPEN Last WO_ 41.20 10831/1985 S 1 Annotation Depth (ftKB) End Date Annotation Last Mod ....,End Date Last Tag: 8,189.0 1 10/24/2010 Rev Reason PULL PLUG, GLV C/0 I Imosbor 11/29/2010 Casing Strings Casing Description 'String 0... ,String ID ....Top OMB) Set Depth (f._ Set Depth (TVD)... (String Wt... String ... 'String Top Thrd CONDUCTOR 16 15.060 34.0 1100 110.0 62.50 11 WELDED - Casing Description Siring 0... String ID Top (ft 03) Set Depth (f._ Set Depth (TVD)... String WI... String ... String Top Thrd c A, SURFACE 9 5/8 8.765 34.7 3,408 7 2 787.0 36.00 J BTC 3 ! - Casing Des iption String 0... String ID Top (ftKB) Set Depth If Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6 151 32.5 8,459 4 i ,1515 26.00 J -55 BTC = Tubing Strings HANGER, 33 Tubing Description Sting 0... String ID Top (ftKB) Set Depth (1 Set Depth (TVD) ... String W1._ String ... String Top Thrd F TUBING ;, 1 I 2992 32.8 8,1856 59347 6-50 3-55 8RD I Completion e Detaw na N Top ( BI tft ) 1 ° ) Item Description Comment ID (in) 32.8 32.8 -0.41 HANGER FMC GEN 111 TUBING HANGER 3.500 1,784.5 1,680.4 35.07 SAFETY VLV BAKER FVLSSSV I 985 4 5, 7,781.3 41.81 PBR BAKER PBR to 1 CONDU R CTO , - I .1 7,999.1 i 5,791.5 41.29 PACKER BAKER FHL PACKER 4.000 8,076.0 5,850.1 39 -90 BLAST JT 2.992 8,156.6 5,912;1 38 -92 NIPPLE PORTED NIPPLE with 2 7!8' CROSSOVER 2.750 8,164.2 5918.1 38.91 LOCATOR BAKER 4.000 SAFETY VIV. 8,164.9 5,918 Y 38.91 PACKER BAKER FB -1 PACKER 4.000 785 Ilk. 8,179.4 5,930.0 39.20 NIPPLE CAMCO 0 NIPPLE 2.250 r 8,18479 5.934.2 39.11 SOS CAMCO SOS �- - 2.992 it Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) , t, Top Depth i (TVD) Top Inch Top(fKB)1 ( (1 Description Comment Run Date ID(in) 8 ,ts 5,912.1 Perforations 1 38.92 SLEEVE C AVA PI with extended packing area. 10/7/1998 2.313 q SURFACE, I, tions .$r Slots 35-3,406 I , Shot I- Top (TVD) 1 Btm (TVD) Dens Top (ftKB,! Btm (ftK8) (ftKB) MKS) 1 Zone Date ( Type Comment Gas LIFT ___ 8,076.0 8,139.0 5,850.1 5,898.5 C -4, 2A-08 11/7/1985 12.0 IPERF 120 deg. phasng; SOS Csg Gun • ' 8,185.0 8,214.0 5,934 3 5,956- 2 -3, 2A-08 11/7/1985 4.0 90 deg. phasing, SOS Csg Gun 1 Notes: General & Safety a` End Date Annotation 9/812010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 PBR, 7,985 # PACKER, 7,999 GAS LIFT, �-'■ rG� �� 8,039 1 IPERF, 8,076 -8,139 t SLEEVE -C, 9,157N NIPPLE, 8,157 - • LOCATOR, _ ( 8,186 jk ! �1 PACKER, 8,165 I NIPPLE,8,179 ----' • T .1 ` p" r rp]� v 1lyeyy 8. dw u` .di drv.5r+r. +3$.tl^ .. r.. t � ' °' "x�d4 n 1 iaiKrtt - Top Depth Top Pat SOS, 8,185 - - -- - - - -- ra. (TVD) Inc! OD Valve Latch Sloe TRO Run Stn Top ft B (ftKB) (1 Make Model (in) Sere TYpe TYpe (in) (paI) Run Date Com... 1 7,943.4 5,749.9 42.07 CAMCO MMG -2 1 GAS LIFT DMY BK 1.500 0.0 11/28/2010 IPERF•-- -- ... _., _. ._ 8,1888,214 2 8,037.8 5,820.8 40.30 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 11/28/2010 PRODUCTION, 32 -8,459 TD, 8,500 STATE OF ALASKA ALASKA./ AND GAS CONSERVATION COMMIS* REPORT OF SUNDRY WELL OPERATI6IVS 1. Operations Performed: Abandon r Repair w ell Plug Perforations r Stimulate Other '; Isotherm Alter Casing fl Pull Tubing r Perforate New Pool r Waiver n Time Extension Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory "° ` 185 - 248 3. Address: 6. API Number: Stratigraphic r Service '... P. O. Box 100360, Anchorage, Alaska 99510 4 50 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25570 ' 2A - 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8500 feet Plugs (measured) None true vertical 6184 feet Junk (measured) None Effective Depth measured 8377' feet Packer (measured) 7999, 8165 true vertical 6083' feet (true vertucal) 5792, 5919 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 16 110 110 SURFACE 3371 9 -5/8" 3406 2787' PRODUCTION 8427 7 8459 6152 RE CENED N JAN 1 8 2n DEC 2010 Perforation depth: Measured depth: 8076' 8139', 8185' - 4 m,ISS10rr True Vertical Depth: 5850'- 5899', 5934' -5956' COOS' COm plaSka Q 11 & Gas Analorag Tubing (size, grade, MD, and ND) 3.5, J -55, 8185 MD, 5934 TVD Packers & SSSV (type, MD, and ND) PACKER - BAKER FHL PACKER @ 7999 MD and 5792 TVD PACKER - BAKER FB -1 PACKER @ 8165 MD and 5919 ND SAFETY VLV - BAKER FVL SSSV @ 1785 MD and 1680 ND 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation na na 4534 Subsequent to operation na na 5212 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service Stratigraphic 15. Well Status after work: Oil r Gas r WDSPL fl Daily Report of Well Operations XXX GSTOR r WIND WAG r GINJ r SUSP r SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce (a 265 -6471 Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date 12/2911D RI°mS DEC 2 91010 Form 10 -4 4 Revised 10/2010 7 ,4 / /0 . 30 Submit Original Only � <a !i%`l7D4o 2A -08 Well Summary DATE SUMMARY 10/24/10 'GAUGE 2.77" TO 8156' RKB (ISO EEVE), TAG @ 8189' SLM w/10' x 2.125', MPLETE. 11/14/10 PERFORMED STATIC DOWN LOG WITH PRESSURE AND TEMPERATURE FROM SURFACE TO 8178'. CALIBRATED FIBEROPTIC LINE TO RIH TEMPERATURE SURVEY AT A REFERENCE DEPTH OF 1000'. BEGIN DISTRUBUTIVE TEMPERATURE SURVEY (DTS) USING FIBEROPTIC LINE FROM SURFACE TO 8178' . OPEN WELL TO PRODUCED WATER INJECTION AT 5200 BWPD /2190 PSI AND CONTINUE WITH DTS. CONTINUE 24 HOUR LOGGING OPERATIONS. 11/15/10 CONTINUE WITH 24 HOUR OPERATIONS USING TWO E -LINE CREWS. TOOLS STATIONARY AT 8178' RKB. CONTINUED DTS SURVEY WITH WELL ON INJECTION AT 5200 BPD. REDUCED INJECTION RATE TO 4190 BWPD (80 %). REDUCE INJECTION RATE TO 3200 BWPD (60 %). SHUT -IN FOR 10 HOURS. POOH LOGGING PRESSURE AND TEMPERATURE FROM 8178' RKB TO SURFACE. FREEZE PROTECTED FLOWLINE AND WELL FROM MANIFOLD BLDG WITH 30 BBLS DIESEL. 11/16/10 BRUSH 2.25 "D - NIPPLE @ 8179' RKB, SET 2.25 CA -2, (A TO C SAND CROSS FLOW WAS PUSHING ME UP OUT OF NIPPLE, HAD LRS ASSIST 1.5 BPM, SET), REPLACED CV @ 8037' RKB w/ DV, UNABLE TO GET GOOD TEST, IN PROGRESS. 11/19/10 RUN D &D HOLE FINDER TO TPI, UNABLE TO GET TEST ON TBG, ABLE TO GET TEST ABOVE STA# 2 @ 8009' SLM, IN PROGRESS. 11/20/10 REPLACED DV @ 8037' RKB w/ EXTENDED PACKING DV, RAN D &D, TESTED ON CATCHER @ TPI @ 8156' RKB, FAIL, ABLE TO GET GOOD TEST JUST ABOVE STA# 2 © 8008' SLM, JUST UNDER PKR, IN PROGRESS. 11/22/10 PULLED DV @ 7943' RKB, PULLED CATCHER @ 8156' RKB, READY FOR ISO THERM PROJECT. 11/27/10 FLUSH IA WITH 400 BBLS OF 120 DEGF SEAWATER PUMPING 2 BPM DOWN TUBING, THROUGH OPEN POCKET AT 7943', RETURNS UP Al TO 2A -24 FL. (FIRST 290 W/ 1% CRW- 132, FOLLOWED BY 110 BBLS STRAIGHT SW). LINE UP ROS TO PUMP DOWN IA TAKING RETURNS UP TUBING TO 2A -24 FL. PUMP 106 BBLS ISOTHERM IPF DOWN IA W/ TUBING RETURNS TO 2A -24 FL. BLOCK IN IA. LINE UP ROS TO PUMP DOWN TUBING, PUMP 2 BBLS OF MEOH DOWN TUBING W /OUT TAKING RETURNS FOR FP. FLUSH LINES TO 2A -24 WITH DIESEL. PUMP REPORT IN ATTACHMENTS. 11/28/10 SET DV @ 7943' RKB. PULLED DV @ 8037' RKB AND SET HFCV. MEASURED BHT @ 2000' SLM. PULLED CA -2 PLUG @ 8179' RKB. 12/18/10 RIH WITH DTS AND LOG TEMP / PRES SURVEY IN HOLE TO DEPTH OF 8187' AND PARK WIRELINE DRUM. LOG 12 HOURS CONTINUOUS MODE WITH DTS. 6 HOURS @ 4950 BWPD, AND 6 HOURS @ 3950 BWPD. 12/19/10 ARRIVE LOCATION AND RELIEVE THE CREW. LOG IN CONTINUOUS MODE WITH DTS FOR 12 HOURS. `,. � ` . KUP 0 2A -08 Conoc lhps , Well Attributes 'Max Angle & MD TD Alaska, lrlc_ t Wellborn API /UWI Field Name I Well Status I Inc! r) MD (ftKB) Act Btm (ftKB) / 501032004900 KUPARUK RIVER UNI I INJ , 53 68 7,325 00 8,500 - 0 Comment 1H25 (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date ••• SSSV LOCKED OPEN 1 Las[ WO 41 20 10/31(1985 ;...:.(A„ o 0 374', PM Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date �iterr�tic Last Tag. 1 8,189.0 10/24/2010 Res Reason: PULL PLUG, CLV C/O 1 Imosbor 11/29 /2010 Casing Strings Casing Description String 0... , String ID . Top (ftKB) l Set Depth (f._, Set Depth (TVD)._ String Wt... String ... String Top Thrd CONDUCTOR 16 15.060 34.0 110 -0 110.0 62.50 1140 WELDED as __. _ Cing Description String 0... Siring ID ... Top (HKB) Set Depth (f... Set Depth (TVD)... String YW... String ... String Top Thrd I1 SURFACE 95/8 8765 34.7 3 3,405.7 2,787.0 36.00 J -55 BTC �._ ri � Casing Der String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD)... String M... String ... String Top Thrd Description ,, PRODUCTION 7 6151 32.5 84594 6.151.5 26.00 J-55 BTC Tubing Strings HANGER, 33 Tubing Description String 0 String ID Top (11)(6) Set Depth (f 1 Set Depth (TVD) . String Wt... String String Top Thrd ,' / T UBING 3 112 2 992 32 8 8,185 6 5,934.7 6 50 J-55 1 8RD Completion Details < Top Depth (TVD) Top Inc! Nomi_. To. (MB) 9 8 ) (') Rem Description Comment ID (in) 32.8 32.8 -0.41 FMC GEN III TUBING HANGER 3.500 1,784.5 1,680.4 35.07 SAFETY VLV BAKER FVL SSSV 2.813 -a. CONDUCTOR, 7,985.4 5,781.3 41.81 PBR BAKER PBR 3.000 34 7 ,999.1 5,791.5 41.29 PACKER BAKER FHL PACKER 4.000 j 8,076.0 5,850.1 39.90 BLAST JT -- _- _._ 2.992 8,156.6 5,912.1 38.92 NIPPLE PORTED NIPPLE with 2 718 CROSSOVER 2.750 ` - 2 8,164.2 5,918.1 38.91 LOCATOR BAKER 4.000 SAFETY VLV, n8s _ — 8,164.9 5,918.6 38.91 PACKER BAKER FBA FB -1 P PACKER 4.000 £ . 8,179.4 5,930.0 39.20 NIPPLE CAMCO D NIPPLE 2.250 8,184.9 5,934 2 39.11 SOS CAMCO SOS 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc) f n „ Top Depth (TVD) Top Inc! Top ) (ftKB) (°) De ption Com ment Run Date !D in) 8,156 6 5,912.1 38.92 SLLEVE -C AVA- 1 P! with extended packing area 110/7/1998 2.313 SURFACE, Perforations & Slots 35 -3,406 - 1 Shot Top (TVD) Btm (TVD) Dens Top(ftKBJ . Btm(fIKB)1 (ftKB) (ftKB) Zone Date (eh— Type Comment GAS LIFT. 8,076.0 8,139.0 5,850.1 5,898.5 C4,2A - 08 11/7/1985 12.0 IPERF 120 deg. phasing; SOS Csg Gun 7.943 8,185.0 8,214.0 5934 -3 5,956.2 A -3, 2A -08 11/7/1985 4.0 IPERF 90 deg. phasing; SOS Csg Gun Notes: General & Safety End Date Annotation 9/8/201() NO (E: VIEW SCHEMATIC w /Alaska Schematc9. PBR, 7,985— ■ 26 .'.x..... - - . PACKER, 7,999 -- GAS LIFT, ...i 8,038 a �� IPERF, 8,076 -8,139 SLEEVE-C, - 8,157 NIPPLE, 8,157 LOCATOR, F " - -__ 8,164 tn . 1 PACKER, 8,165 1 NIPPLE, 8,179 - ' - - _ - ' SL v � Top Depth Top Port SOS, 8,185 ------ - .il (TVD) Incl OD Valve Latch Size TRO Run Stn To. - KB IRKS) (1 Make Model (in) SerV Type Type (in) (psi) Run Date Com... 7,943.4 5,749.9 42.07 CAMCO MMG-2 1 GAS LIFT DMY BK 1.500 0.0 11/28/2010 IPERF,_ - --- - 9,185 -8,214 ' 2 8,037.8 5,820.8 40.30 CAMCO KBUG 1 INJ HFCV BK 0.000 0.0 11/28/2010 PRODUCTION,, 32 -8,459 `. TD,8,500 `— Page 1 of 1 Schwartz, Guy L (DOA) From: Peirce, John W [ John .W.Peirce @conocophillips.com] Sent: Wednesday, December 29, 2010 11:39 AM ZA To: Schwartz, Guy L (DOA) le -- 2 y 8 ) Cc: Allsup- Drake, Sharon K C - Subject: RE: 2A -23 Isotherm.. (PTD 193 -142) Guy, Were just testing an MI product called 'Isotherm' in wells located in a subsidence area to try to limit heat loss from wells to the permafrost. The idea is we may be able to mitigate subsidence rates over well service life. Isotherm is a very low thermal conductivity (mineral oil based) fluid were pilot testing first in 2A -23 and 2A -08. Basically we first perform a pre - isotherm baseline distributed temp survey (DTS) at different rates, then we displace / fluid pack the IA with Isotherm, followed by a post- Isotherm placement DTS to determine what change in weilbore fluid temp vs. rate we get. If we see a decent increase in wellbore temp (a few degrees maybe), then we may consider placing Isotherm in many other candidate wells to help mitigate our subsidence issues. I didn't know if we need to be sending 10 -404's over for these jobs but since it's something new I figured I'd send a couple 404's over for the initial jobs. Let me know if you want 404's in the future or not for similar Isotherm jobs. Happy Holidays, John Peirce Wells Engineer CPAI Drilling & Wells (907)- 265 -6471 office From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, December 29, 2010 11:06 AM To: Peirce, John W Subject: 2A -23 Isotherm.. (PTD 193 -142) John, Can you elaborate on the Isotherm DTS work done on 2A -23. What was the purpose? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 12/30/2010 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 2A-08 Run Date: 7/11/2010 E. July 16, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A-08 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20049-00 Injection Profile Log 1 Color Log 50-103-20049-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto , ~ .- Date: ;fit ~ ~ Lil,?' U~ ~= /85 ' ~l '8 l °~~l ~ Signed: _ ~~e~t~ ~~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~/ ~-- - A~~7 ~~ ~ ~~~~ Well Job # Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 08/06/08 1A-22 12097412 GLS ~ -~ ~ 07/22/08 1 1 2G-04 12096519 PROD PROFILE - G 07/23/08 1 1 1A-22 12097413 PROD PROFILE - ~ 07/23/08 1 1 1A-28 11996647 PROD PROFILE ~~ 07/24/08 1 1 1A-25 11996648 PROD PROFILE ~ 07/25/08 1 1 2A-08 11996649 INJECTION PROFILE '~ 07/26/08 1 1 1 E-112 12080408 INJECTION PROFILE 07/27/08 1 1 2W-05 12080409 INJECTION PROFILE 07/28/08 1 1 3J-10 12097408 SBHP SURVEY 07/20/08 1 1 3M-28 12097411 SBHP SURVEY C - ~( 07/21/08 1 1 1 L-15 11982443 PROD PROFILE ~ 07/06/08 1 1 30-OSA 12080407 SBHP SURVEY ~~ i~'}- (93 ~ (~~-(0 07/26/08 1 1 30-09 12080406 SBHP SURVEY ®(® °~-(p~ 07/26/08 1 1 i L-24 11978468 PRODUCTION PROFILE j 07/26/08 1 1 1 F-17 12080410 PRODUCTION PROFILE ~ (p 07/29/08 1 1 30-11 12100430 SBHP SURVEY -py 07/31/08 1 1 2M-06 12100433 INJECTION PROFILE 08/02/08 1 1 1 H-~, a 12100434 INJECTION PROFILE V ZC.. ~ "~ {0 08/03/08 1 1 UGNU DS2-OBI 11996650 TEMPERATURE LOG ~ - 07/27/08 1 1 2X-14 12100432 LDL G _. ~- 08/01/08 1 1 i F-20 12100435 PRODUCTION P OFILE / 08/04/08 1 1 i H-09 12100436 INJECTION PROFILE U 08/05/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ~~ // Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ,, ~I~~, ~ ~~~~ Well Job # Log Description %' J ~ v NO. 4759 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 06/25/08 iG-14 11964620 INJECTION PROFILE ~ ~ ; °~'~~, ~~-1~,/ ~ '~?zx®~y~12! 06/13/08 1 1 3A-16 11964621 LDL ~ '"' -` ~ ` a ~ A° -~,~ 'F 06/14/08 1 1 1 B-14 12061702 LDL ~"? ~ ---_ '~T ~,, j ad ~y .~ r~^ 06/15/08 1 1 2N-327 12061704 PRODUCTION PROFILE ~?~`"j- - °~~ -^=-~ 4"/" .r.~ ~'f"'' 06/17/08 1 1 1 B-04 12061705 INJECTION PROFILE r 3°a '~ -P- ~ ":. p'~1,. ,:~°~ ''(.>~ _„_ ', . 06/18/08 1 1 2D-05 11964625 INJECTION PROFILE/LDL;, ~--- ~ - ~ " ~'~-l. ~ ~ 06/18/08 1 1 1E-12 11964628 GLS ~ ~ 1d,~~~'; ~~ ~~' ~°~'~ 06/20/08 1 1 3A-06 12061708 INJECTION PROFILE ( •~'~ Y ~~ ~ ~~-~)~ 4'd-~ ~`~~~: 06/21/08 1 1 2A-OB 11964629 INJECTION PROFILE;,~$~,l~~ l~Wt~o--~`~ 06/21/08 1 1 i L-11 11964630 PRODUCTION PROFILE ~''=~` ~ - ~~ ~ ~"° °°`~ ~ ~_ 06/23/08 1 1 ~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ~i MEMORANDUM • To~ Jim Regg P.I. Supervisor ~ ~`'`~G~ ~~~ 5~ ~~j FRONT: John Crisp Petroleum Inspector State of Alaska • .Alaska Oil and Gas Conservation Commission DATE: Wednesday, Niay 07, 2008 SUBJECT: Mechanical [nteg~~ity Tests CONOCOPHILLIPS ALASKA INC 2A-08 KUPARliK RIV [,'NIT zA-OS Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~~~' Comm Well Name: KUPARL'K RN UNIT 2A-08 API Well Number: ~0-103-20049-00-00 Inspector Name: John Crisp Insp Num: mitJCr080s04090201 Permit Number: I85-248-o Inspection Date: ~%~%2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ---- Well ; zA oa TYPe Inj. w' ! TVD j sass ~ IA_ Iz~s_ z6oo _' zs4o z~zo -' _ P.T. ', Iasz4so ,TypeTest. sPT Test psi z6oo !', OA hso ' Aso ' 6so Aso Interval 4YxrsT p~F P Tubing ~ zzzs ~~ zzso ~ 2zso zzso ~ NOteS' 4.4 bbl's pumped for test. L2 ~ n , -1~- ,~ . ,, Wednesday. Nlay 07, 2008 Pale 1 of ! ~ • __ ~. E ~-~ r _; -~ ~~ ~ ~m Alaska P.D. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 15, 2007 ~: F..AI ~ k*..b ~ ~ k~ Mr. Tom Maunder v ~ ~- ~ ~ ~ ~ ~ -- Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 t t `'" `' Anchorage, AK 99501 1~~-~-~ ~ Dear Mr. Maunder: `~{"I° ~ ~~ ~ E" ~. ~ 2017 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCG this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped September 24 & December 12 2007 and the corrosion. inhibitor/sealant was pumped on December 6 & December 14 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ®~ Perry Klein ConocoPhillips Well Integrity Projects Supervisor • Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404j Date Kuparuk Field Well Name PTD # Initial top of cement Vol. of cement um ed Fina! top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor! sealant date ft bbls ft a1 2A-01 184057 SF na SF na 1.5 12/14/2007 ZA-02 184-050 SF na SF na 3.5 12/14/2007 2A-03 184-051 44" na 44" na 50 12!1412007 2A-04 184-053 9'6" 1.2 10" 9/24/2007 3.5 12/14/2007 2A-05 184-067 SF na SF na 5 1215/2007 2A-06 184-064 25'5" 1.5 20" 12/12/2007 8.5 12!14!2007 ZA-08 185-248 SF na SF na 3 1215!2007 2A-09 186-001 SF na SF na 1.75 12!1412007 2A-10 186-002 23' 3.1 11" 9/24/2007 7 12/5/2007 2A-11 186-003 SF na SF na 11 12/5/2007 2A-12 186-004 SF na SF na 6 12/5/2007 2A-13 185-144 SF na SF na 1.75 12/14/2007 2A-14 185-145 SF na SF na 3.5 12!14!2007 2A-17 193-140 SF na SF na 15 12/5/2007 2A-18 195-059 NA na 8' na 35 12!14/2007 2A-21 193-133 5' 0.7 18" 9/24!2007 3 12/5/2007 2A-22 195-068. 39" na 39" na 7.5 12/14/2007 2A-23 193-142 SF na SF na 2 12/5!2007 10/31/05 Schlumbepgep NO. 3513 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil &. Gas Cons Comm Anchorage, AK 99503-2838 i)(;ANNED NOV 2·3 2005 AUn: Helen Warman A TTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk "- Well Job# Log Description Date BL Color CD 1R-16 11015756 PRODUCTION PROFILE 10/24/05 1 2X-10 11015758 PRODUCTION PROFILE 10/26/05 1 1 D-128 11015759 INJECTION PROFILE 10/27/05 1 3J-06 11072927 SBHP SURVEY 10/30/05 1 3J-07 A 11072926 SBHP SURVEY 10/30/05 1 2Z-29 11072924 PRODUCTION PROFILE 10/28/05 1 1A-02 11022938 INJECTION PROFILE 10/18/05 1 1 Q-26 11022937 PRODUCTION PROFILE 10/17/05 1 1G-16 11015753 INJECTION PROFILE 10/21/05 1 ~A-08 11015755 INJECTION PROFILE 10/23/05 1 2G-15 11072919 PRODUCTION PROFILE 10/23/05 1 2N-329 11022935 PRODUCTION PROFILE 10/15/05 1 2Z-07 11022936 PRODUCTION PROFILE 10/16/05 1 3G-02 11056697 PRODUCTION PROFILE 09/20/05 1 2B-03A 11015749 PRODUCTION PROFILE 10/05/05 1 3N-09 (REDO) 11015722 PRODUCTION PROFILE 08/29/05 1 -" 2C-04 11022934 INJECTION PROFILE 10/14/05 1 '~M-07 (REDO) 11015737 INJECTION PROFILE 09/26/05 1 2A-01 A 11072922 INJECTION PROFILE 10/26/05 1 1R-10 11015757 INJECTION PROFILE 10/25/05 1 2Z-08 11072920 INJECTION PROFILE 10/24/05 1 1E-170 11015750 USIT 10/19/05 1 1J-154 11022931 USIT 10/12/05 1 2F-03 1J:j 'NJEoEF'LE 10/31/05 1 SIGNED: DATE: 1'6 N,v ~Ù'\ì C- Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. JR\~· 1, ~IX 2A-08 (PTD 1852480) MITIA data ) ) Subject: 2A-08 (PTD 1852480) MITIA data From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Sun, 26 Jun 200520:46:12 -0800 To: tom _ maunder@admin.state.akus, bob _ fleckenstein@admin.state.akus, jim _regg@admin.state.akus Tom, Bob, & Jim Attached is a passing MITIA for 2A-08. This test was a diagnostic test and no problems were identified. Please let me know if you have any questions. Marie McConnell Problem Well Supervisor 659-7224 «M IT KRU 2A-08 06-24-05.xls» Content-Description: MIT KRU 2A-08 06-24-05.xls KRU 2A-08 06-24-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 SCANNED JUL () 7' 2005 1 of 1 6/27/2005 10:35 AM ) ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk I KRU 12A 06/24/05 Rodgers 1 Sauvageau - AES Packer Depth Pretest Initial 15 Min. 30 Min. Well 2A-08 Type Inj S T.V.D. 5785 Tubing 2220 2220 2220 2220 Interval 0 P.T.D. 1852480 Type Test P T est psi 1500 Casing 1150 3000 2950 2950 P/F P Notes: Diagnostic Test OA: 620 1 700 1 700 1 700 Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Test Details: SCANNE"C ,n \ì n t'¿ 2.Q Ü'~j TYPE INJ codes F = Fresh Water Inj G = Gas I nj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover o = Other (describe in notes) MIT Report Form Revi~ed: 05/19/02 MIT KRU 2A-08 06-24-05.xls 6/27/2005 MEMORANDUM State of Alaska Alaska Oil and Gas Consen'ation Commission TO: Jim Regg P.I. Supervisor .--' I hé1(( t Z.c¡(C4 DA TE: Wednesday. June 23, 2004 Sll BJECT: ~ lechamcallntegrlty Test:; CONOCOPHlLLlPS ALASKA fNC ~""'.O8 FROM: Chuck Scheve Petroleum Inspector KUPARUK RIV UNIT ~A.08 Src: Inspector Reviewed By: P.I. Supn ~']D~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2:\-08 Insp Num: mitCS04062 I 124026 Rellnsp Num: API Well Number: 50-103-20049-00-00 Permit Number: 185-248-0 Inspector Name: Chuck Scheve Inspection Date: 6/20/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2A-08 Type Inj. P TVD 6179 IA 1500 2-1-.\0 2380 2380 P.T. 1851480 TypeTest SPT Test psi 1446 ~5 OA 114ü 1180 1180 1180 Interval 4''RTST P/F P Tubing 1680 1680 1680 1680 Notes: The pretest pressures were observed for 30T minutes and found stable. This Well has a waiver due to 1.'\ x OA communication. No evidence of a leak was obsen'ed during the 30 minute test but the pretest OA appeared to be high. The wai\'er indicated gas or water injection allowed OA pressure not to exceed 1400psi. ,~o A-C(;CC qpfrZ~\ SL~\Mj (CÙ't ~T) rJ 5èt?- \~rednesday. June 23. ~004 Page I of 1 P.T.D.I MEMORANDUM TO: THRU: FROM: Dan Seamount Commissioner Blair Wondzell P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation CommissiOn DATE: Sept. 1,2000 Jeff Jones J~~. Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 2A Pad 2A-01A, 2A-02, 2A-03, ZA-04, ZA-06, 2A-08, -2A-20, 2A-21,2A-23 KRUlKuparuk River Field Packer Depth . Pretest Initial 15 Min. 30 Min.. I 2A-01A I Type,nJ.I G I~'v'°' I 5796 ITubing I 35001 35001 3500 I 3500 I lntervall 4 I ITypetestl P ITestpsil 1449 I Casingl 52o I 17601 17601 1760 I PIE I._P I 184O57O I I Type,ni.I S I~-v-~' I ~,oo:1Tubingl=~°1 =~°1 =~°1 =~o I,.te~va, I 4 ' ITypetestI P I Testpsil 1450 l Casing[ 575-I 171O1 1700l 17-101 PIF I P Notes: WellI P.T.D.I Notes: WellI - P.T.~.I Notes: P.T.D.I Notes: We!q P.T.~.I Notes: w~,I 2^-o~ P.T.D.I 1852480 Notes; We,I 2A-20 P.T.D.I 193151O Notes: P.T.D.I 1931330 Notes: P.T.D.I 1931420 Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING 2A-02 1840500 ' 2A-03 I Typeinj. I G I~'v'o' I 5845 IYubingl~°1~°°1 ~oo I ~oo l lntervall 4 1840510 IT~etestI P ITestpsil 1461 I Casingl.1160 I 1675I 1610I 1610 I 'P/F I EI 2A-04 1840530 I ~""'"i-I ~ I ~.V.D. I ~ I ~u,,.. I ~so I ~,oo~1 ~,oo I ~oo '1I~""all '4I 2A-06 IT~"t"'tl P I Testpsil '~443 I Casingl ~650 I 22001 2200 I =00 I PIF I P ~ 1840640  .'n~.l ~ I~'v'D' I ~"~ I~"~n"l =~=~1 =z~l ~sl ~Z=~ I'n~""a'l" T~eteMI P I Testpsil ~446 ICasingI 95O I 1625 I 1625 I 1625 I.PIF lB I T~e~nj.I s I ~.v.o. I '~z"~ I ~u~,n, I ~,~o ! =,~o. I =~o I ~,~o i,~..a~l ~ IT~etestl P I-Te~psil ~447 ICasin~I ~75I ~700 I ~725 I ~710 I P/FI P  .~n~.I S I ~.V.O. I ~" I~u~in, I ~00 I~00 I~00 I~0°'1~.~"-.~1" T~etestIP I Testpsil ~444 I'Casingl S00 I ~720 I 172511725I P/FIE "'".1 'sI~.v'~. I s~ I~u~"""l ~=~1 ~°1 ~s°! ~o I,~..,I ," T~etestI p ITestpsil ~44~ l casingI 6o0 I ~65o I-~6~°1 ~6oo I' PIF I B Type Test M= Annulus Monitoring ' P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D-- Differential Temperature Test Interval I= Initial Test '4= FourYear Cycle . : V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Wednesday, Atm. 3__.a0 2000: I traveled to Phillips Alaska Inc.'s KRU 2A pad t° witness the 4 year MITs on WellS # 0lA, 0A, 03, 04, 06, 08, 20, 21, 23. Jerry Dethlefs was the PIA rep. In charge of testing. The standard annulus pressure test was performed with all nine wells passing the 30 minute pressure test. Summary: I witnessed nine successful MITs on PIA's KRU 2A pad. M.I.T.'s performed: 9_ Number of FailUres: Attachments: Well schematics 0_ Total Time dUring:tests: 8 hrs cc.' MIT report form 5/12/00 L.G. MIT KRU 2A 8-30-00 JJ.xls 9/5100 ~ STATE OF ALASKA ~,,_.., ALASKA OIL AND GAS CONSERVATION COMMI~ION REPORT OF SUNDRY WELL OPERATIONS ' 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well_ Plugging _ Time extension _ Stimulate__ Change approved program X Pull tubing _ Variance _ Perforate _ Other., 2. Name of Operator ARCO Alaska. In¢, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 717' FSL, 53' FEL, SEC 14, T11N, R8E, UM At top of productive interval 1363' FNL, 1217' FWL, SEC 14, T11N, RSE, UM At effective depth 1213' FNL, 1094' FWL, SEC 14, T11N, R8E, UM At total depth ;1172' FNL, 1039' FWL~ SEC 14, T11N, RSE, UM 6. Datum elevation (DF or KB) 130' RKB 7. Unit or Property name Kuparuk River Unit % feet 8. Well number 9. Permit number 85-248 10. APl number 5o-103-2004~) 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 8497' feet true vertical 61 79' feet Effective depth: measured 8 3 7 7' feet true vertical 6 0 8 4' feet Casing Length Size Structural Conductor 1 I 0' I 6" Surface 34 06' 9 5/8" Intermediate Production 8 4 5 9' 7" Liner Perforation depth: measured 8076'-8139', Plugs (measured) NONE Junk (measured) NONE Cemented 175 SX CS II 800 SX AS III 370 SX CLASS "G" 370 SX CLASS "G" 25O SX PFC 8185'-8214' Measured depth True vertical depth 110' 110' 3406' 2787' 8459' 6150' REE£1VED true vertical 5849'-5897', 5933'-5956' JUL 2 ;5 199: Tubing (size, grade, and measured depth) Alaska 0il & Gas Cons. C0mmiSs~0n 3 1/2", J-55, @ 8186' Anchorage Packers and SSSV (type and measured depth) BAKER FHL PACKER@7992', BAKER FB-1 PACKER @ 8158', BAKER FVL SSSV @ 1777' 14. Pressure Prior to well operation Subsequent to operation 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure/ ! -- convert from production to injection ~,1 ~/o3~/,¢~ Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing 160 30 0 500 200 2000 500 2400 15. Attachments 17. Signed 16. Status of well classification as: Copies of Logs and Surveys run __ Water Injector __ Daily Report of Well Operations. Oil _ Gas Suspended I hereby certify that the foregoing is true and correct to the best of my knowledge. C~ ~k). '/~~~] Title Kuparuk Petroleum Engineer --orm 10-404 Rev 06/15/88 Service WAG Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. Date: RETURN TO: Transmitlal #: 7212 ARCO Alaska, Inc. _ Attn' Brenda K. Miernyk Kuparuk Records Clerk · : ATO-1119 P.O. Box 100360 '- Anchorage, AK 99510-0360 July 1, 1988 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2A-01 Kuparuk Fluid Level Report 6- 23- 8 8 2A-02 Kuparuk Fluid Level Report 6- 23- 8 8 2Ao06 Kuparuk Fluid Level Report 6-23- 8 8- 2A-08 Kuparuk Fluid Level Report 6-23-88 Tubing Tubing Tubing Tubing Receipt Acknowledged' Date' - ............ DISTRIBUTION: D & M S'tate of Alaska Chevron Unocal Mobil SAPC Alaska Oil & Gas Con°. Commission ~ Anchorage ARCO Alaska, Inc Post Offic~. 100360 Anchorage, A'm-~ka 99510-0360 Telephone 907 276 1215 May 2, 1988 Mr. C. V. Chatterton Alaska Oil and Gas Comnission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Subject: Kuparuk River Field Water Injection Surveys In compliance with Rule 4 Conservation Order Number 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk water injection wells for the first quarter of 1988. The data is provided in the form of separate zone surveys, as or spinner logs listed in Attachment I. The spinner logs will be ~ent separately. Injection rates determined by separate zone surveys are also listed in Attachment I. If you have any questions concerning' the information reported, please contact me at (907) 263-4978. Sincerely, ~4. H. Kraly Operations Engineer MHK/SPT:pg'0163 Attachments ARCO Almlkl, Inc. Il · Sublldlmry ol AllanllcRIchlleldCompany 3---.?-g ? ~ STATE OF ALASKA ALASK~_.OIL AND GAS CONSERVATION COMIV,.._.~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program~ Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator ARCO Alaska. :[nc. 3. Address P.O. Box 100360~ Anchor`a§e~ Alaska 99510 4. Location of well at surface 717' FSL, 53' FEL, Sec. 14, T11N, R8E, UM 5. Datum elevation (DF or KB) RKB 130' 6. Unit or Property name Kupar'uk River` Unit 7. Well number 2A-08 At top of productive interval 1353' FNL, 1217' At effective depth 1213' FNL, 1094' At total depth 1172' FNL~ 1039' FWL~ Sec. 14~ 11. Present well condition summary Total depth: measured true vertical FWL, Sec. 14, FWL, Sec. 14, T11N, R8E, UM T11N, R8E, UM T11N~ R8E~ UM 8497' feet 6179' feet Plugs (measured) 8. Permit number 85-248 9. APl number 50- 029-20049 10. Pool Kuparuk River Oil feet Pool Effective depth: measured true vertical 8377' feet 6084' feet Junk (measured) Casing Length Structural Conductor 110 ' Surface 3406' Intermediate Production 8459' Liner Perforation depth: measured Size Cemented Measured depth 16" 175 Sx Cold Set II 9-5/8" 800 Sx AS III 370 Sx Class G 7" 370 Sx Class G 250 Sx PFC 8076'-8139', 8185' -8214' MD 110' 3406' 8459' True Vertical depth 110' 2787 6150' RECEIVED true vertical 5849'-5897', 5933'-5956' TVD Tubing (size, grade and measured depth) 3-1/2", 0-55, at. 8186' · Packers and SSSV (type and measured depth) Baker' FHL @ 7992'. Baker' FB-1 @ 8158'. Baker' FVL SSS¥ ~ 1777'. 12.Attachments Description summary of proposal~ Detailed operations program [] Gas Cons. ~ch~:'~.~e BOP sketch [] 13. Estimated date for commencing operation Febr'uar'y 7, 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge S, g n ed/.~f~-¢~ ~'.'~J~/-~. ~.,~/'..¢~-~.~ Title Commission Use Only Conditions of approval Notify commission so representative may witness Approved by Form 10-403 Rev 12-1-85 Date [] Plug integrity [] BOP Test [] Location clearance _ .A. pproved Copy ~ J~e.qchani.c.al JnteQrlty. ~jj Returned ORIGINAL SIGNED BY I fINNIE C. SMITH Commissioner I Approval No. ~:::;"'-'; 7 by order of the commission Date~-~~2 Submit in triplicate Kuparuk Well 2A-8 Well 2A-8 is a selective single completion currently utilized as an A Sand producer. Surface modifications will be performed to convert the well from A Sand production to A Sand, and/or C Sand injection. ARR'tc-O036 RECEIVED .Oil & Gas Cons, Oommissio,~ ARCO Alaska. Inc. Post Office ~ 100360 Anchorage. AlasKa 99510-0360 Telephone 907 276 1215 RETUP~N TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 03-11-86 TRANSMITTAL # 5595 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints/ Schl/ CET or CBL's/ One ~lQ-12 01-21-85 Run #1 3536-6934  A-8 11-02-85 Run #1 6986-8362 D-13 12-17-84 Run #1 5425-7488 ~2D-14 17-12-84 Run #1 6288-8136 '~2H-11 11-28-85 Run #1 4850-6642 ~g2H-12 11-28-85 Run #1 5500-6776 ~W-15 02-02-85 Run #1 6500-8096 ~3A-4 11-03-85 Run #1 6792-8329 ~3F-4 11-12-85 Run #1 4770-6734 '~F- 7 11-14-85 Run #1 4950-7876 * of each PT,EASE NOTE: These logs were received from the vender today 03-11-86. Receipt Acknowledged: ~ a~'-0 f AK*bl/se Vault*~films NSK Clerk*bl ARCO Alaska. Inc. ts · Subs,diary of AtllnticRicRflel(~Compadqy ARCO Alaska, Inc. Post Office B~'x'"100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 11, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2A-8 Dear Mr. Chatterton' Enclosed is a copy of the 2A-8 Well Well Completion Report, dated 1/9/86. please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU13/L96 Enclosure cc' 2A-8 Well File History to include with the If you have any questions, A!ask~. 0:,! & Gas Oons. C,orCm~'ssi°n . Ancho?aga ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily worl( prior to sl~udding should be summarized on Ihs form giving inclusive dates 0nly. District Field Alaska ICounty, parish or borough North Slope Borough Lease or Unit ADL 25570 Title Drill IState Alaska Kuparuk River Auth. or W.O. no. AFE 703419 Parker 191 IWell no. 2A-8 AP1 50-103-20049 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded IDate 10/20/85 ]Hour Date and depth aa of 8:00 a.m. lO/2O/85 thru 10121185 lO/22/85 10/23/85 10124185 Complete record for each day reported 2245 hrs. IARCO W.I. Prior statue if a W.O. 56.24% 16" @ 93' 1000' (907'), Dyna Drlg Wt. 9.7, PV 194 YP 28, PH 10.0, WL 10.7, Sol 6 Moving f/3J-8, Acpept rig @ 1400 hfs, 10-20-85. NU diverter sys. Spud @ 2245 hrs.., 10-20-85. DD f/93'-1000'. 705', 8.3°, N78.6W, 704.51TVD, 11.85 VS, N2.66, W13.19 16" @ 93' 2151', (1151'), Drlg Wt. 9.5, PV 14, YP 56, PH 9.0, WL 11, Sol 7 DD & surv to 2151'. 885', 14°. N69.4W, 881.11TVD, 43.72 VS, 12.25N, 46.65W 1244', 25.9°, N60 2W' 1217 11TVD, 167 13 va' 75.89N, 154.20W 1625', 31.0°, N47.4W, 1547.47 TVD, 356.02 VS, 191.61N, 303.64W 1930', 39.6°, N43.9W, 1796.16 TVD, 531.49 VS, 314.68N, 429.53W 16" @ 93' 3426', (1275'), C&C f/csg Wt. 9.9, PV 19, YP 52, PH 9.0, WL 9.0, Sol 10 Drl f/2151'-2336', circ, TOH, hole sloughing. Pmp out f/1800'-1526', circ, pmp pill, fin TOH. TIE w/locked assy, hit bridge drl to bridge 2295', 2730', 3220', @ 1711', wsh & rm to 1953'. RIH to 2212', wsh to btm, 3426', 20 std short trip, tight f/2259'-2197'. TIH, hit @ 1924', wsh & rm to 2197', fin TIH, C&C f/csg. 48.8°, N45.SW, 2057.55 TVD, 784.46 VS, 495.35N, 608.32W 49.4°, N44W, 2342.36 TVD, 1111.71VS, 728.85N, 839.79W 48.3°, N46.7W, 2664.79 TVD, 1479.25 VS, 988.12N, 1102.25W 9-5/8" @ 3405' 3426', (0'), Pick up BHA Wt. 9.0, PV 7, YP 9, PH 9.5, WL 8, Sol 3 Drop surv, pmp pill, TOH. RU & rn 86 its 9-5/8", 36#, J-55, HF/ERW, BTC csg, FS @ 3406f, FC @ 3324' Cmt w/800~$x AS III w/10#sx Kolite @ 12.0 ppg~ollowed by ~70 sx CL "G", + 2%.S1, + .2% D-46, @ 15.8 ppg. CIP @ 1945 hrs, 10-23-85. Bmp plug w/1750 psi; OK. RD cmt head, ND lnd'g joint & annl. RU pmp 16 bbl wtr, followed w/l14 sx AS I, @ 15.7 ppg. NU BOPE &tst. Set wear bsh'g. The above is correct - Fo~ form preparation and di~ibution, see Procedures Manual, Secllbn 10, Drilling, Pages 86 and 87. [D"'"1~.4.85 ITitle Drilling Superintendent ARCO Oil and Gas Company ~, Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion, Report official or represenlalive test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Alaska I County or Parish JState North Slope Borough Alaska I Lease or Unit Well no. · ADL 25570 2A-8 Kuparuk River Date and depth as of 8:00 a.m. 10/25/85 2069.67W 10/26/85 thru 10/28/85 10/29/85 10/30/85 Complete record for each day while drilling or workover in progress 9-5/8" @ 3405' 5246', (1820'), Drlg Wt. 9.0, PV 6, YP 14, PH 10.5, WL 9, Sol 3 TIH to FC w/BHA, tst csg to 2000 psi, DO flt equip & cmt. Displ hole w/9.0 ppg mud. Conduct formation tst to 12.5 ppg EMW. Turbine drl 8½" hole to 5246'. 3625', 47.8°, N44.7W, 2935.18 TVD, 1779.24 VS, 1198.38N, 1317.59W 4118', 48.5°, N41.7W, 3264.10 TVD, 2143.61VS, 1466.05N, 1568.95W 4517', 49.3°, N49.9W, 3526.39 TVD, 2443.10 VS, 1675.48N, 1784.32W 5015', 49.6°, N48W, 3850.15 TVD, 2821.38 VS, 1923.97N, 9-5/8" @ 3405' 8385', (3139'), Drlg Wt. 11.8, PV 19, YP 15, PH 9.5, WL 4.5, Sol 11 Drl & surv 8½" hole to 7386', hole taking mud, mx & spot LCM pill, TOH. Cut mud wt to 10.5 ppg. Stage in hole cond'g mud f/ll.2 ppg - 10.5 ppg. Drl to 7868' w/no fluid loss, C&C mud to 10.8 ppg. Rn WL surv, left surv instrument in hole; no surv. C&C mud, raise mud wt to 10.8 ppg. Retrv surv. Drl to 7957', C&C mud f/10.8 ppg - 11.7 ppg w/no fluid loss. Drl to 8385'. 5511', 49.7°, N51.4W, 4171.29 TVD, 3199.30 VS, 2168.43N, 2357.92W 6259', 49.0°, N52.5W, 4658.56 TVD, 3766.57 VS, 2518.20N, 2804.81W 6757', 50.5°, N53.5W, 4980.32 TVD, 4146.22 VS, 2746.93N, 3108.35W 7261', 52.7°, N53.3W, 5293.36 TVD, 4540.60 VS, 2982.42N, 3425.83W 7828', 45.0°, N50W, 5666.18 TVD, 4967.35 VS, 3247.09N, 3760.36E 9-5/8" @ 3405' 8497', (112'), TOH to log Wt. 11.9, PV 20, YP 17, PH 9.5, WL 4.9, Sol 12 Drl to 8497', 32 std short trip, C&C, TOH to 9-5/8" csg; hole flowing. TIH, C&C mud to 11.9 ppg, TOH f/logs. 9-5/8" @ 3405' 8497' (0'), LD BHA , Wt. 11.9, PV 18, YP 11, PH 9.5, WL 4.7, Sol 12 TOH. RU $chl, rn DiL/SF4/FDC/CNL/GR to 8501' WLM, RD Schl. Make wiper trip, C&C f/7", TOH, LD BHA. The above is correct For form preparation and diitribution see Procedures Manual Section 10. Drilling, Pages 86 and 87 IDate ITitle Drilling Superintendent 'ARCO Oil and Gas Company Daily Well History-Final Report Inslructions; Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" shoutd be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation it space is available. District ICcunty or Parish I Alaska Field ~Lease or Unit I Kuparuk River Auth. or W.O. no. ~Title I AFE 703419 Accounting cost center code State North Slope Borough Alaska ADL 25570 Drill IWell no. 2A-8 Parker 191 AP1 50-103-20049 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded A.R.Co. W.I. 56.24% Date 10/20/85 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our I Prior status if a W.O. I 2245 hrs. Date and depth as of 8:00 a.m. 10/31/85 Complete record for each day reported 7" @ 8459' 8377' PBTD, Arctic Pak 11.7 ppg NaCl/NaBr Chg rams to 7", tst to 3000 psi. RU & rn 201 its, 7", 26#, J-55 HF/ERW csg w/FS @ 8459', FC @ 8377', Mkr @ 81~7'. Cmt w/370 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ using rig pmps, bump plug. CIP @ 2310 hrs, 10/30/85. BOPE, NU & tst tree to 3000 psi. Prep to Arctic Pak well. 11/01/85 7" @ 8459' 8377' PBTD, RR 11.7 ppg NaC1/NaBr Arctic Pak w/250 sx AS I. f/rig move to PUC DS 4-29. Old TD New TD 8497' TD (10/28/85 Released rig Date RR @ 1000 hfs, 10/31/85. Prep rig ND PB Depth 8377' PBTD I K nd of rig Rotary 1000 hrs. Classifications (oil, gas, etc.) 0il Producing method Flowin$ Polenttal test data 10/31/85 IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands W~II no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, gPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct IDate ITitle Drilling Superintendent For form preparation and~istribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, Inc. Post Office Bo'x~'100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 10, 1986 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2A-8 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for 2A-8. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/mh GRU13/L171 Enclosures RECEIVED A!asl<a Oil & Gas Cons, 6ommissior~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA t._._ AND GAS CONSERVATION CO-~.vllSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-248 '3. Address 8. APl I~umber P. 0. Box 100360, Anchorage, AK 99510 50_iO~.9,z~9~-20049 4. Location of well at surface LOCA'rI©N5i 9. Unit or Lease Name 717' FSL, 53' FEL, Sec.14, T11N, R8E, UM VERIFIED ! Kuparuk River Unit At Top Producing Interval Surf. ~.~,~ ~d,~ I 10. Well Number 1363' FNL, 1217' FWL, Sec.14, TllN, RSE, UM I~.H. 2A-8 At Total Depth 11. Field and Pool 1172' FNL, 1039' FWL, Sec.14, T11N, R8E, UH Kuparuk River Field , 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i ] Pool 129' RKBI ADL 25570 ALK 2668 12. Date Spudded10/20/85 13. Date T.D. Reached1 0/28/85 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re [ 16' N°' °f C°mpleti°nsl 0/31/85w N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8497'HD, 6179'TVD 8377'HD, 6083'TVD YES I~X NO [] 1784 feet MDI 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/FDC/CNL/GR, CET, CCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE! WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 175 sx CS II 9-5/8" 36.0# J-55 Surf 3406' 12-1/4" 800 sx AS Ill & 370 sx ~lass G Top job performed w/114 sx AS I 7" 26.0# J-55 Surf 8459' 8-1/2" 370 sx Class G & 250 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8214' - 8185' w/4 spf, 90° phasing 3-1/2" 8186' 8165' 8139' - 8076' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ ~low Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITy-APl (corr) Press. 24-HOUR RATE ~1~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10407 * NOTE: Tubing was run & wel 1 perforated 11/9/85. TEMP3/WC45 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. :~" 'f' .30. . GEOLOGIC MARKERs : FORMATION TESTS · · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8074' 5846' N/A Base Kuparuk C 8140' 5897' Top Kuparuk A 8150' 5904' Base Kuparuk A 8291 ' 6015' . 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed_ .... 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 TEMP3/WC45a ARCO Alaska, Inc. Post Office Bc-x-~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2A-8 Dear Mr. Chatterton: Enclosed is an addendum to the 2A-8 Well History to include with the Well Completion Report dated 12/13/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L162 Enclosure Alaska Oil & Ga.s Cons. 6ornrnissio:-~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany ADDENDUM WELL: 11/01/85 11/o5/85 2A-8 Arctic Pak w/41 bbls AS I, followed by 58 bbls Arctic Pak. Rn CET log f/8377'-6986'. Rn GCT gyro f/8295'-surf. Drillin~ Superintendent Dhte ADDENDUM WELL: 11/01/85 11/05/85 2A-8 Arctic Pak w/41 bbls AS I, followed by 58 bbls Arctic Pak. Rn CET log f/8377'-6986'. Rn GCT gyro f/8295'-surf. ~Dri~rintendent ARCO Alaska, Inc.~,,._., Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 Date; 12-19-85 Transmittal No: 5481 A RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. BOX 100360 Anchorage AK 99510-0360 Transmitted herewith are the f~ltowing items. return one signed copy of this transmittal. Open Hole Final Prints/ Schl/ One * of each 2A-8 ~'~5" DIL/SFL-GR 1G-29-85 Run #1 '~'~2" DIL/SFL-GR 10-29-85 Run #1 ........ ~J5" Den/Neu (poro) 10-29-85 Run #1 '~2" Den/Neu (poro) 10-29-85 Run #1 ..... ~" Den/Neu (raw) 10-29-85 Run #1 ~-~o2" Den/Neu (raw) 10-29-85 Run #1 -'--~Cyberlook 10-29-85 Run #1 2M-12 .,~'~% 5'' DIL/SFL-GR 11-07-85 Run #1 '~2" DIL/SFL-GR 11-07-85 Run #1 ~5" Den/Neu (poro) 11-07-85 ~un #1 2" Den/Neu (poro). 11-07-85 Run #-1 5" Den/Neu (raw) 11-07-85 Run #1 "~ 2" Den/Neu (raw) 11-07-85 Run #1 ~'~ ~Cyberlook 11-07-85 Run #1 3c-1~ '~.~5" DIL/SFL-GR 10-26-85 Run #1 ~2" DIL/SFL-~R 10-26-85 Run #1 ~5" Den/Neu (poro) 10-26-85 Run #1 ~2" Den/Neu (poro) 10-26-85 Run #1 ~5" Den/Neu (raw) 18-26-85 Run #1 ~ 21' Den/Neu (raw) 10-26-85 Run #1 ~ Cyberiook 10-2,7-85 Run #1 Please acknowledge receipt and 3407-8492 3407~8492 3407-8466 3407-8466 3407-8466 3407-8466 7850-8443 2743-6829 2743-6829 5500-6803 5500-6803 §500-6803 5500-6803 6300-6780 2698-9420 2698-9420 8750-9394 8750-9394 8750-9394 8750-9394 9024-9315 ~'~A~- ?3/Alaska Oil & 6as Cons. Comrnissior~ Receipt Acknowledged: State of AK *bl/se Rathmell *bl NSK Clerk *bl Drilling *bl Vault *Films DeGloyer & MacNaughton *bl Date: ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office B'8~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 16, 1985 Mr. C. V. Chatterton Commi ss ioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2A-8 Dear Mr. Chatterton: Enclosed is the Well Completion Report for 2A-8. The bottomhole location, TVDs, and geologic markers will be submitted when the gyroscopic survey is received. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU12/L133 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA t~,._ AND GAS CONSERVATION CC.-~411SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-248 3. Address 8. APl Number _ P. 0. Box 100360, Anchorage, AK 99510 50- ~49 4. Location of well at surface 9. Unit or Lease Name 717' FSL, 53' FEL, Sec.14, T11N, R8E, UM (approx) Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is received. 2A-8 At Total Depth 11. Field and Pool To be submitted when gyro is received. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 129' RKBI ADL 25570 ALK 2668 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. ,15. Water Depth, ifoffshore ,16. No. of Completions 10/20/85 10/28/85 10/31/85*I IN/A feet MSL 1 17. TOtal Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8497'MD 8377 'MD YES i-~X NO [] 1784 feet MDI 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/FDC/CNL/GR, CET, GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5// H-40 Surf 110' 24" 175 sx CS II 9-5/8" 36.0// J-55 Surf 3406' 12-1/4" 800 sx AS I!1 & 370 sx ',lass G Top job performed w/114 sx AS I 7" 26.0// J-55 Surf 8459' 8-1/2" 370 sx Class G & 250 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8214' - 8185' w/4 spf, 90° phasing 3-1/2" 8186' 8165' 8139' - 8076' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. , 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.¢.~ ? Form 10-407 * NOTE: Tubing was run & well perforated 11/9/85. TEMP3/WC08 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. '30. GEOLOGIC MARKERS ' ' FOR~,TI6N -[:EST'~. . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. To be submitted wY~n gyro is receiced. N/A . 31. LIST OF ATTACHMENTS Well History (completion details) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed__ ............ ~. ~ ~ Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and Correct well completion report and log on all types of lands and leases in Alaska. Item 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 cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on Ihs first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska State Alaska r county, parish or borough North Slope Borough Field ~L-eas~ Or U~it Kuparuk River I ADL 25570 Auth. or W.O. no. ~Title AFE 703419 I Completion Nordic 1 API 50-103-20049 IWell no. 2A-8 Operator ARCO Alaska, Inc. IDate I Hour Complete 11/6/85 2130 hrs. IARCO W.I. Prior status if a W.O. 56.24% Spudded or W.O. begun Date and depth as of 8:0~ a.m. 11/o7/85 11/08/85 Complete record for each day reported 7" @ 8459' 8377' PBTD, Loading pipe shed. 11.7 ppg NaC1/NaBr Accept ri~ @ 2130 hfs, 11/6/85. shed. NU & tst BOPE. Load pipe 7" @ 8459' 8377' PBTD, POOH w/gauge ring & JB 11.7 ppg NaCl/NaBr Prep 3½" tbg. RIH w/2 csg scrprs & rev circ @ 8377', POOH. RU Schl, perf w/4" gun, 4 SPF f/8185.-8214'. Perf w/5" gun, 12 SPF f/8076'-8139'. RD Schl. Total fluid loss = 2.5 bbls. RIH w/6-1/8" gauge ring & JB. The above is correct Signature For form preparation and dlstribulJ~, see Procedures Manual, Section 10; Drilling, Pages 86 and 87. IDate I Title ll- ~O-z~ Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operalions are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data. in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting District or Parish I State Alaska County North Slope Borough Field Lease or Unit Kuparuk River ADL 25570 Auth. or W.O. no. JT tie AFE 703419 I Completion COSt center code Alaska IWell no. 2A-8 Nordic 1 Operator I A.R.Co. ARCO Alaska, Inc. Spudded or W.O. begun IDate I Complete Date and depth Complete record for each day reported as of 8;00 a.m. 11/09/85 API 50-103-20049 W.I. ~otal number of wells (active er inactive) on this Icost center prior to plugging and I 56.24% Jabandonment of this well I IHour . I Prior status if a W.O. 11/6/85 ! 2130 hrs. I 7" @ 8459' 8377' PBTD, Operations suspended, RR Diesel RIH w/Bkr FB-1 pkr, set @ 8158' WLM. RIH w/253 its, 3½", 9.3#, J-55 EUE 8RD ABM tbg. Set pkr, space out & ind. Tst tbg & ann. ND BOPE. NU & tst tree. Displ well w/diesel. Set BPV. RR @ 0230 hfs, 11/9/85. SSSV @ 1784', FHL Pkr @ 7999', FB-1 Pkr @ 8165', TT @ 8186'. Old TD New TD Released rig Date 0230 hrs. Classifications (oil. gas, etc.) Oil Flowin~ Producing method Potential test data IPB Depth 1/9/85I iKind of rig IType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 8377' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production .Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature ,~f'.,~"~ ~ , For form preparation and dislributio~ see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date Title l i - f_z) Drilling Superintendent L! SUB. SURFACE DIRECTIONAL ~URVEY [~UIDANCE [~ONTINUOU$ [~]OOL Company , Well Name Fleld/Loc&tlon ARCO ALASKA INCORPORATED 2A-8 (717' FSL, 53' FEL, S~,4 TllN R8E UM] ,, , , ,, ~ ; ;, ,KUPA~,UK, NO,RTH SLOPE, ALASKA, No. 71087 HALFACRE I Oate 17-DECEMBER-85 CUDNEY GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ,~RCD ALASKA, INC. 2~-8 KUPARUK NORTH SLDPE~ALASKA SURVEY DATE: 02-NOV-85 ENGINEER: H&LFACRE METHODS OF CgMPU'T&TION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERP2LATIgN: LINEAR VERTICAL SECTIDN: ~ORIZ. DIST. PRDJECTED 0~T0 ~ TARGET AZIMUTH DF NDRTH 50 gE~ 18 MIN NEST ARCO ALASKA, INC. 2~-8 KUPARUK NORTH SLOPE,ALaSKA COMPUTATI3N DATE: 17-DEC-85 PAGE 1 DATE OF SURVEY: O2-N2V-85 KELLY BUSHING ELE¢'~TION: 129.00 ENGINEER: HALFACRE ~T INTERPOL&TEO VALUES FOR EVEN 100 TRUE SdB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH FEET OF MEASURED DEPTH 0.00 0.00 -129.00 100.00 100.00 -29.00 200.00 200.00 71.00 300.00 300.00 171.00 400.00 400.00 271.00 500.00 500.00 371.00 600.00 599.92 470.92 700.00 699.30 570.30 800.00 798.03 669.03 900.00 895.64 766.64 COURS= VERTICAL DOGLEG RECTANGULAR DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH DEG MIN DEG MIN FEET DEG/IO0 FEET 1000.00 991.56 862.56 1100.00 1035.68 955.68 1200.00 1178.28 1049.23 1300.00 1268.53 1139.53 1400.00 1356.19 1227.19 1500.00 1441.50 1312.50 1600.00 1526.65 1397.68 1700.00 1611.50 1482.50 1800.00 1694.53 1565.53 1900.00 1774.53 1645.53 0 0 N 0 0 E 0.00 0 8 S 35 58 W -0.02 0 6 S 50 20 W -0.05 0 6 N 23 8 W 0.02 0 12 N 60 54 E 0.11 0 21 N 41 13 W 0.12 4 12 N 64 1 W 3.48 8 2 N 79 44 W 13.42 10 23 N 72 46 W 27.53 14 40 N 69 9 W 47.76 2000.00 1851.39 1722.39 2100.00 1926.02 1797.02 2200.00 1997.15 1868.15 2300,00 2064.44 1935.44 2400.00 2129.38 2000.38 2500.00 2194.20 2065.20 2500.00 2259.07 2130.07 2700.00 2324.16 2195.16 2800.00 2389.39 2260.39 2900.00 2455.01 2328.01 18 9 N 59 57 W 75.06 20 59 N 57 35 W 108.50 23 26 N 59 29 W 145.84 27 18 N 58 38 W 188.26 30 24 N 52 17 W 236.14 31 46 N 48 50 W 288.29 31 38 N 47 51 W 340.64 32 32 N 47 2 W 393.55 35 18 N 46 31 W 449.15 38 24 N 46 23 W' 508.98 3000.00 2520.55 2391.55 3100.00 2586.25 2457.25 3200.00 2652.29 2523.29 3300.00 2718.97 2589.97 3400.00 27~6.22 2657.22 3500.00 2853.70 2724.70 3500.00 2920.82 2791.82 3700.00 2987.78 2~58.78 3~00.00 3054.56 2925.56 3900.00 3121.18 2992.18 40 42 N 46 6 W 572.79 43 5 N 45 59 W 639.15 46 15 N 45 55 W 709.22 48 59 N 45 49 W 782.96 49 2~ N 45 56 W 858.78 49 40 N 45 50 W 934.70 49 25 N 45 48 W 1010.57 49 26 N 45 42 W 1086.25 49 5 N 45 58 W 1161.81 48 59 N 46 7 W 1237.06 49 2 N 46 10 W 1312.38 48 47 N 46 18 W 1387.59 48 26 N 46 21 W 1462.50 48 0 N 45 13 W 1536.84 47 27 N 46 8 W 1610.66 47 47 N 46 19 W 1584.2? 4? 52 N 46 36 W 1T58.23 48 0 N 46 49 W 1832.36 48 9 N 46 54 W' 1906.65 4~ 16 N 46 56 W 1981.11 COORDINATES HDRIZo DEPARTURE ~AST/WEST DIST, ~ZIMUTH FEET FEET. DEG MIN 0.00 0.00 N 0.08 0.12 S 0.43 0.33 S 0.2? 0.31 S 0.25 0.07 S 1.34 0.12 N 5.19 1.97 N 2.40 4.82 N 3.82 8.30 N 4.36 15.44 N 0.00 E 0.00 0.08 W 0.14 0.21 W 0.39 0.28 W 0.42 0.20 W 0.21 0.06 W 0.13 2.89 W 3.~9 13.45 W 14.29 28.90 W 30.06 49.26 W 51.62 4.16 27.48 N 2.47 45.33 N 3.89 65.09 N 3.82 86.67 N 4.05 113.97 N 1.55 147.16 N 0.68 182.15 N 1.86 21?.93 N 2.73 256.16 N 3.22 297.46 N 74.74 W 79.53 103.38 W 112.88 135.52 W 150.34 172.73 W 193.26 212.30 W 240.95 252.52 W 292.28 291.51 W 343.74 330.58 W 395.95 371.10 414.58 W 510.25 1.39 341.64 N 3.35 387.86 N 2.94 436.69 N 2.17 488.18 N 0.70 541.13 N 0.37 594.16 N 0.62 647.19 N 0.32 700.17 N 0.26 752.97 N 0.28 805.34 N 460.83 W 573.65 508.?1 W 539.70 559.2~ W 709.54 612.33 W 783.11 666.91 W 858.83 721.56 W 934.70 T76.15 W 1010.57 830.51 W 1086.28 884.89 W 1161.89 939.22 W 1237.22 0.71 857.71 0.24 909.85 0.35 961.66 0.30 1013.14 1.09 1064.39 0.36 1115.48 0.27 1166.56 0.33 1217.46 0.14 1268.35 0.19 1319.27 N 993.64 W 1312.63 N 1048.11 W 1387.93 N 1102.44 W 1462.93 N 1156.33 W 1537.39 N 1209.73 'W 1611.32 N 1262.99 W 1685.06 N 1316.70 W 1759.14 N 1370.79 W 1833.38 N 1425.10 W 1907.78 N 1479.60 W 1982.34 N 0 0 E S 33 25 W S 32 12 W S 42 10 W S 70 58 W N 25 0 ~' N 55 43 N 70 17 W N 73 58 W N 72 35 W N $9 48 W N 66 19 W ~ 64 20 W N 63 21 W N 61 46 W N 59 46 W N 58 OW N 55 36 W N 55 23 W N 54 20 W N 49 11 W N 49 2 W N 48 54 W N 4.8 46 W N 48 39 W N 4.8 32 W N 48 27 W N 48 23 W N 48 19 W N ~+8 16 W COMPUT$TI3~ ~RCO 4LASK6, INC. 2~-8 'KUPARUK NORTH SLOPE,AL~S.qA INTERPOLATEO TRUE SUB-SEA ME&SURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 4000.00 3187.76 3058.76 4100.00 3254.39 3125.39 4200.00 3320.72 3191.72 4300.00 3386.50 3257.60 %$00.00 3452.08 3323.08 4500.00 3517,~8 338~.48 4500,00 3582.77 3453.77 4700.00 3647.91 3518.91 4800.00 3712.97 3583.97 4900.00 3778,05 3649.05 5000.00 3843. D7 3714.07 5100.00 3908.11 3779.11 5200,00 3973.06 3844,06 5300,00 4038,14 3909.14 5400.00 a103.57 3974.67 5500,00 4168.92 %039.92 5600.00 4234.02 4105.02 5700.00 4299,10 4170.10 5800,00 4364.18 4235,18 5900.00 4429.08 ~300.08 6000.00 4493.93 4364.93 6100.00 4558.98' 4429.98 6Z00.00 4624.6'9 4495.69 6300.00 4690.51 $561.51 6400.00 4756.06 ~527.06 6500.00 4821.19 4692.19 6600.00 48~6.10 4757,10 6700.00 4950,$1 4821.41 6800.00 5014.25 4885.25 6900,00 5077.50 4948,60 70.00,00 5139,97 5010,97 7100.00 5201.52 5072,52 7200,00 5262.57 5133,67 7300,00 5323.15 5194.15 7400,00 5382,95 5253.95 7500.00 5444.48 5315.48 7600,00 5508,71 5379,71 7700,00 5575,58 5446.58 7800,00 5644,81 5515,81 7900.00 5716.15 5587,15 VALOES FOR COURSE DEVIATION AZIMUTH DEG MIN DEG MIN 48 6 N %6 38 W 48 18 N 46 39 W 48 32 N 46 52 W 49 4 N 48 ZO W 49 3 N 49 9 W 49 15 N 51 24 W 49 19 N 52 0 W 49 22 N 52 9 W 49 23 N 52 ll W 49 26 N 52 8 W 49 23 N 52 13 W 49 27 N 52 10 W 49 29 N 52 11 W 49 11 N 53 9 W %'9 7 N 54 31 W 49 23 N 55 39 W 49 20 N 55 ~,2 W 49 17 N 55 42 W 49 27 N 55 34 W 49 36 N 55 32 W 49 36 N 55 9 W 49 4 N 54 57 W 48 52 N 54 59 W 48 50 N 55 10 W 49 17 N 55 19 W 49 23 N 55 34 W 49 44 N 55 $Z W 50 8 N 56 10 W 50 30 N 56 27 W 50 54 N 56 38 W 51'52 N 56 45 W 52 1 N 57 2 W 52 32 N 57 5 W 53 4 N 57 13 W 52 58 N 57 1~ W 50 58 N 55 37 W 48 58 N 53 51 W 46 59 N 52 20 W 4'5 26 N 51 20 W 43 ~5 N 46 58 ~ DAf:: 17-9EC-85 EVEN 100 VERTICAL SECTION FEET Zo55.5s R130.O0 2204.69 2279.82 2355.38 2431.02 2505.73 2582.58 2658.48 2734,35 2810.29 2836.21 2962.21 3038.08 3113.47 3188,97 3264,54 3340,13 3415,72 3491,48 3567.30 3642.99 3718.12 3793.14 3868.38 3943.96 ~019.69 $095.89 4172.42 ~249.34 4327.02 4405,31 4483,88 4562,95 4642.51 ~720,85 $797,25 4871.51 4943.64 $013.70 FEET OF DOGLEG SEVERITY OEG/IO0 0,54 0,36 0,57 1.15 0,77 1.77 0.34 0.18 0.33 0.37 0,58 0.06 0.27 1,37 1,59 0,55 0.24 0.49. 0.15 0.31 0,88 0,65 0,43 0.40 0,41 0,57 0,35' 0,54 0,43 1,03 1.13 0.29 0.82 0.60 1.28 1.83 2.46 2.13 1,75 2.38 PAGE Z DATE OF SURVEY: O2-NOV-85 KELLY 3USHING ELEVATION: 129.00 FT ENGINEER: HALFACRE MEASURED DEPTH RECTANGULAR COORDINATES HDRIZ. DEPARTURE NORTH/SOUTH E4ST/WEST DIST. AZIMUTH FEET FEET FEET DEG MIN 1370,31 N 1534,02 W 2056,93 N 48 13 W 1421.53 N 1588.22 W 2131.48 N 48 10 W 1472.83 N 1642.70 W 2206.29 N 48 7 W 1523.66 N 1698.15 W 2281.$1 N 48 6 W 1573.43 N 1755.03 W 2357.08 N 48 7 W 1~21.90 N 1813.10 W 2~32.67 N 48 11 ~ 1668.66 N 1872.69 W 2503.27 N 48 17 ,, 1855.02 N 2112.51 W 2811.37 N 48 42 W 1901.58 N 2172.53 W 2887.20 N 48 48 W 1948.21 N 2232.59 W 2963.11 N 48 53 W 1994,40 N 2292.85 W 3038,88 N 48 58 W 2039,06 N 2353,77 W 3114,16 N 49 5 W 2082.29 N 2416,00 W 3189.51 N 49 14 W 2125.08 ~ 2~78.59 W 3264.95 N 49 23 W 216'7.85 N 2541.43 W 3340.42 N 49 32 W 2210.72 N 2604.09 ~ 3415.93 N 49 40 W 2253.70 N 266~.88 W 3491,62 N 49 47 W 2296,95 N 2729,50 W 3567.37 N 49 55 W 2340.47 N 2791.74 W 3643.03 N 50 1 W 2383.72 N 2~53,49 W 3718,14 N 50 7 W 2426.86 N 2915.18 W 3793.15 N 50 13 W 2469,91 N 2977,24 W 386~,38 N 50 19 W 2512,99 N 3039,70 W 3943,97 N 50 25 W 2555.80 N 3102,58 W 4019,72 N 50 31 ~ 2598,63 N 3166,06 W 4095,95 N 50 37 ~ 2641,24 N 3230,16 W 4172,54 N 50 43 W 2~83,90 N 3294,71 W 4249,52 N 50 50 W 2726.86 N 3360.01 W 4327.2'9 N 50 56 W 2769.81 N 3426.10 W 4405.68 N 51 2 W 2812.85 N.3492.50 W 4%84.38 N 51 9 W 2856.05 N 3559.39 W 4563.59 N 51 15 W 2899.40 N 3626.81 W 4643.30 N 51 21 W 2942,83 N 3692,58 W 4721,80 N 51 26 W 2987,01N 3755,20 W 4798,31 N 51 30 W 3031.73 N 3814.59 W 4~72.62 N 51 31 W 3076,33 N 3871,31 W 4944,78 N 51 31 W 3121,12 N 3925,18 W 5014,82 N 51 30 W ARCO ALASKA, INC. 2~-8 KUPARUK NORTH SLOPE,ALASKA COMPUTATION OATE: 17-0EC-85 P~GE 3 DATE OF SURVEY: O2-N2V-85 KELLY BUSHING ELEVATION: 129.00 FT ENSINEER: HALFACRE INTERPOLATED VALUES FOR EVEN 100 FEET DF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN SO00.O0 5?89.88 5560.88 41 27 8100.00 5865.31 5?36.81 39 58 8200.00 5942.9? 5813.97 38 52 8300.00 5021.78 5892.78 37 16 8400.00 6101.35 5972.35 37.16 8497.00 6178.53 6049.53 37 16 N 46 37 W 5081.17 N 4~ 33 W 5145.01 N 43 51 W 5209.27 N 42 13 W 5270.37 N 42 13 W 5330.34 N 42 13 W 538~.51 3.28 0.99 1.50 O.OO 0.00 0.00 3166.44 N 3975.25 W 5082.22 N 51 27 W 3212.07 N 4021.64 W 5146.94 N 51 23 W 3257.68 N 4065.99 W 5210.06 N 51 17 W 3302.52 N 4108.17 W 5271.02 N 51 12 ~ 3347.37 N 4148.88 W 5330.86 N 51 6 ~ 3390.88 N 4188.37 W 5388.92 N 51 0 ('" COMPUTATION ARCO ALASKA, INC. 2~-B KUPARUK N3RTH SLOPE,ALaSKA DATE: l?-DEC-85 INTERPOLATED VALUES FOR EVBN 1000 FEET DF C3JRSE VERTICAL DOGLEG DEVIATION AZIMUTH SECTION SEVERITY DEG MIN DEG MIN FEET DEG/IO0 TRUE SUB-SEA ME&SURE) VERTICAL VERTICAL 35PTH DEPTq DEP[H O0 -129.00 56 862.56 39 1722.39 55 2391.55 76 3058.76 O? 3714.07 93 4364,93 9? 5010.97 88 5660.88 53 6049.53 0 0 N O 0 E 0.00 0.00 18 9- N 59 57 W 75.06 4.16 40 %2 N 46 6 ~ 572.79 1.39 49 2 N 46 10 W 1312.38 0.71 48 6 N 46 38 W 2055.58 .0,54 49 23 N 52 13 W 2810.29 0.58 49 36 N 55 9 W 3507,30 0,88 51 52 N 5§ 45 W ~327.02 1.13 41 27 N 46 37 W 5081.17 3,28 37 16 N 42 13 W 5388,51 g. OO 0.00 O. 1000.00 991. 2000.00 1851. 3000.00 2520. 4000.00 3187. 5000.00 3843. 6000.00 4493. 7000.00 5139. 8000.00 5789. 8~97.00 5178. MEASU RECTA NORTH FE 0 Z7 857 1370 1855 2296 2726 3166 3390 PAGE 4 DATE DF SURVEY: 02-NOV-85 KELLY BUSHING ELEVATION: 129.00 ENGINEER: HALFACRE F1 ED OEPT GULAR COORDINATES HDRIZ. DEPARTURE SOUTH EAST/WEST DIST. AZIMUTH T FEET FEET DEG MIN O0 N 0,00 E 0,00 N 0 0 E 48 N 74.74 W 79,63 N 69 48 W 64 N 460,83 W 573,65 N 53 26 W 71 N 993,6~ W 1312,63 N 49 11 N 31 N 1534,02 W 2056,93 N 48 13 W 02 N 2112.51 W 2811.37 N 48 42 ( 95 N 2729.50 W 3567.37 N 49 55 86 N 3360,01 W 4327.29 N 50 56 ~ 44 N 3975.25 W 5082.22 N 51 27 W 88 N 4183.37 W 5388,92 N 51 0 W COMPUT.~TION DATE: 17-0EC-85 ARCO ALASKA, INC. KJPARUK NORTH SLOPE~ALASKA INTERPOL~T:D VALUES FOR EVEN 100 FEET TRUE SdS-SEA ME~SUREO VERTICAL VERTICAL gEPTH DEPTH DEPTH COdRS6 VSRTICAL 20GL DEVIATION AZIMUTH SECTION SEVE DEG MIN DEG MIN FEET DEG! 0.00 0.00 -129.00 29.00 29.00 -100.00 129.00 129.00 0.00 229.00 229.00 100.00 329.00 329.00 200.00 429.00 429.00 300.00 529.00 529.00 400.00 629.19 629.00 500.00 730.03 729.00 600.00 831.55 829.00 700.00 0 0 1 5 8 11 0 0 N 0 O £ 0.00 0 0 6 S 88 57 W 0.00 0 0 8 S 37 41 W -0.01 0 0 2 S 66 59 W -0.04 0 8 N 1 57 .I 0.07 0 12 N 67 42 E 0.06 0 0 N 49 41 W 0.43 3 30 N 70 55 W 5.83 5 40 N 79 18 W 17.24 1 36 N 71 2 W 33.11 4 934.59 929.00 800.00 1039.55 1029.00 900.00 1146.60 1129.00 1000.00 1255.77 1229.00 1100.00 1368.66 1329.00 1200.00 1485.29 1429.00 1300.00 1602.73 1529.00 1400.00 1720.81 1629.00 1500.00 1842.57 1729.00 1600.00 1970.54 1829.00 1700.00 15 51 N 56 37 W 55.47 3 19 27 N 58 11 W 87.69 3 22 8 N 58 21 W 125.50 1 25 49 N 60 10 W 168.69 3 29 18 N 54 10 W 220.57 31 48 N 49 16 W 280.54 1 31 39 N 47 50 W 342.07 0 33 1 N 46 53 W 404.79 2 36 36 N 46 30 W 474.07 3 40 15 N 46 14 W 553.70 2104.06 1929.00 1800.00 2246.62 2029.00 I900.00 2399.42 2129.00 2000.00 2553.67 2229.00 2100.00 2707.45 2329.00 2200.00 2860.36 2429.00 2300.00 3012.87 2529.00 2400.00 3164.85 2629.00 2500.00 3314.99 2729.00 2600.00 3463.25 2829.00 2700.00 43 12 N 45 59 ~ 641.90 3 47 36 N 45 54 'W 743.16 3 49 28 N 45 55 W 858.34 0 49 33 N 45 49 W 975.43 0 49 26 N 45 43 W 1091.88 0 48 57 N 46 3 W 1207.22 0 49 0 N 46 12 W 1322.07 0 48 36 N 46 22 W 1435.23 0 47 55 N 46 13 ~ 1547,95 0 47 40 N 46 11 W 1657.13 0 3512.19 2929.00 2800.00 3761.6~ 3029.00 2900.00 3911.7~ 3129.00 3000.00' 4061.86 3229.00 3100.00 4212.52 3329.00 3200.00 4364.78 3429.00 3300.00 4517.64 3529.00 3400,00 4570.97 3629.00 3500.00 4824.65 3729.00 3600.00 4978.38 3829,00 3700,00 47 53 N 46 38 W 1767.25 48 8 N 46 50 W 1878,15 48 16 N 46 56 W 1989,85 48 15 N 46 37 W 2101.60 4~ 35 N 46 56 W 2214.06 49 5 N 48 55 W 2328.77 49 13 N 51 42 W 2444.37 49 21 N 52 6 W '2560.56 49 25 N 52 11 W 2677.19 49 24 N 52 12 W 2793.88 PaGE 5 DaTE OF SURVEY: 02-N3V-85 KELLY BUSHING ELEVATION: 129.00 FT ENGINEER: HALEACRE OF SUB-SEA DEPTH EG RECTANSULAR CODRD RITY NORTH/SOOTH EAST/ 100 FEET FEET .00 0.00 N O. .00 0.00 N O. .25 0.17 S O. .13 0.34 S O. .1~ 0.25 S O. .09 0,03 S O. · 09 0.33 N O. · 09 2.91 N 5. .74 5.61 N 17. .73 10.19 N 34. .77 18.86 N 57. .75 34,09 N 85. .93 54.44 N 117. .95 76.66 N 155. .99 104.61 N 199. .80 142.08 N 246. · 72 183.10 N 292. · 6~ 225.61 N 338. .46 273.34 N 389. · 88 328,38 N 447. .53 389.77 N 510. · 31 460.3~ N 583. .72 540.83 N 666. · 42 622.62 N 750. · 30 704.12 N 834, ,36 784.59 N 917. ,44 864,43 N 1000. .62 943.50 N 1083. .51 1020.84 N 1164. .79 1096.67 N 1243. · 38 1172.77 N 1323. .19 1248.84 N 1404. .26 1325.25 N 1486. .42 1401.98 N 1567. °69 1479.24 N 1649, .55 1555.98 N 1734, ',98 1630.18 N 1823. .30 1701.78 N 1915. .51 17'73.36 N 2007. .48 1844.96 N 2099. INATES HDRIZ. WEST DIST. FEET. O0 E 0.00 O0 E 0.00 12 W 0.21 23 W 0.41 29 W 0.39 11W 0.11 29 W 0.44 17 W 5,93 75 W 18.62 57 W 36.04 74 W 60.74 56 W 92.20 91 W 129.87 61W 173.47 83 W 225.55 67 W 284.$6 57 W 345.15 ~0 W 407.05 22 W 475.61 02 W 554,57 69 W 642,44 68 W 743,40 59 W 85~,39 87 W 975.43 56 W 1091,92 67 W 1207.35 65 W 1322,33 38 W 1436.63 37 W 1548,51 32 W 1657.87 27 W 1768.17 25 W 1879.23 O0 W 1991.10 53 W 2103.02 55 W 2215.67 94 W 2330,47 58 W 2446,00 15 W 2562.00 31 W 2678.4,5 $4 W 2794.98 DEPARTURE AZIMUTH DEG MIN N 0 0 E N 90 0 E S 35 52 d S 34 12 W S 49 35 W S 74 34 / N z,O 51t,, N 60 37 W N 72 28 W N 73 35 W N 71 54 W N 68 17 W N 65 13 W N 63 46 W N 62 22 W N 60 3 W N 57 57 W N 56 20 W N 54 55 W N 53 41 W N 52 38 W N 51 44 W N 50 56 W N 50 20 W N 49 50 W N 49 28 ¥ N 49 10~' N 48 56 W N 48 45 W N 48 35 W N 48 27 .W N 48 21 W N 48 16 W N 48 11W N 48 6 W ,N 48 6 W N 48 12 W N 48 22 W N 48 32 W N 48 41 W C~MPUT~TZON ARCO ALASKA, INC. KUPARUK NORTH SLOPE,ALASKA INTERPOLATED VALUES FOR MEASURED DEPTH TRUE SUB-SEA VERTICAL VERTICAL DEPTH DEPTH COURSE DEVIATION AZIMUTH DEG MIN DEG MIN 5132.13 3929.00 3800.00 5285.99 4029.00 3900.00 5%38.76 4129.00 4000.00 5592.29 4229.00 ~100.00 5745.89 4329.00 4200.00 5899.88 ~429.00 4300.00 6054.11 %529.00 4400.00 6206.55 4629.00 '4500.00 6358.60 %729.00 4600.00 5511.98 4829.00 %700.00' 49 29 N 52 11 W 49 16 N 52 57 W 49 16 N 55 5 W 49 19 N 55 42 W 49 25 N 55 38 ~ 49 36 N 55 32 W 49 23 N 55 0 W 48 52 N 54 58 W 49 2 N 55 15 W 49 23 N 55 38 W 6686.53 4929.00 4800.00 6823.21 5029.00 %900.00 5982.27 5129.00 5000.00 7144.74 5229,00 5100.00 7309.75 5329.00 5200.00 7%75.32 5429.00 5300.00 7530.74 5529.00 5400.00 7777.40 5629.00 5500.00 7917.65 5729.00 5600.00 8051.78 5829.90 5700.00 50 2 N 56 2 W 50 36 N 56 28 W 51 45 N 56 40 W 52 17 N 57 1W 53 ? N 57 14 W 51 25 N 56 5 W 48 25 N 53 16 W 45 46 N 51 35 W 43 5 N 48 34 W 40 34 N 45 26 W 8182.03 5929.00 5800.00 8309.07 5029.00 $900.00 8%34.75 5129.00 6000.00 8497.00 5178.53 5049.53 39 7 N 43 56 W 37 16 N 42 13 W 3'7 16 N 42 13 W 37 16 N 42 13 W DATE: 17-DEC-$5 EVEN 100 FEET VfRTICAL SECTION FEET PAGE 6 DATE OF SURVEY: 02-N3V-85 KELLY BUSHING ELEVATION: 129.00 ENGINEER: HALFACRE 2910.62 3027.46 3142.72 3253.72 3374.79 3491.39 3508.36 3723.04 3837.17 3953.01 4070.42 4190.24 4313.18 4440.37 4570.69 4701.72 4820.31 4927,51 5025.80 5115.01 5198.03 5275.91 5351.18 5388.51 OF SUB-SEA DEPTH 90GLE3 SEVERITY DEG/IO0 .28 .41 .10 .ZO .50 .31 .15 .47 .45 .62 .40 .68 .50 .22 .24 .77 .03 .78 .57 .24 FT .Wl .00 .00 .00 RECTAN NORTH/ FEE GULAR COORDINATES SOUTH EAST/WEST D T FEET F HORIZ. IST. EET 1916.55 N 2191.83 W 2911.57 1988.01 N 2284.36 W 3028.28 2055.96 N 2377.75 W 3143.35 2121.79 N 2473.36 W 3259.14 2187.49 N 2570.18 W 3375.05 2253.65 N 2666.80 W 3491.53 2320.5~ N 2763.29 W 3608.42 2386.56 N 2857.53 W 3723.05 2452.08 N 2951,48 W 3837.17 2518.13 N 3047.19 W 3953.02 35 N 3144.82 W 407 15 N 3245.09 W 419 21 N 3348.37 W 431 02 N 3455.72 W 444 27 N 3565.95 W 457 04 N 3676.57 W 470 73 N 3773.78 W 482 28 N 3858.68 W 492 09 N 3934.28 W 502 02 N 3999.66 W 511 2584. 2651. 2719. 2789. 2860. 2932. 3000. 3066. 3129. 3190. DEPARTURE AZIMUTH DEG MIN N 48 49 W N 48 58 W N 49 9 W N 49 22 ,~ N 49 35 W N 49 47 /' N 49 58.'~,. ,950 7 W N 50 16 W N 50 25 W 0.47 N 50 35 W 0.37 N 50 45 W 3.43 N 50 55 W 0.79 ~ 51 5 W 1.34 N 51 16 W 2.63 N 51 25 W 1.39 m ~ 5 I 30 W 8.64 N 51 31 ~ 6,91 N 51 30 W 5.00 N 51 25 W 3249.52 N 4058.15 W 5198.84 3306.59 N 4111.86 W 5276.45 3362.96 N 4163.03 W 5351.66 3390.88 N 4188.37 W 5388.92 N 51 18 W N 51 11 W N 51 4 W N 51 0 W ARCO ALASKA, INC. KUPARUK NORTH SLOPE,ALASKA MARKER TOP KUPARUK C ~ASE KUPARUK C TOP KUPARUK & BASE KUmARUK A TD COMPUTATION DATE: 17-DEC-85 INTERPOLATED VALUES FOR SHDSEN H2RIZDNS ORIGIN: MEASURED DEPTH TVD 3ELOW KB FROM KB 717 ° SUB-SEA 8074.00 5845.92 5718.92 8140.00 $898.54 5767.54 8150.00 5904.23 5775.23 8291.00 6014.60 5885,50 8377.00 6083.05 5954.05 8~97.00 6178.53 5049.53 PAGE 7 DATE OF SURVEY: OZ-N]V-85 KELLY BUSHING ELEVATION: 129.00 ENGINEER: HALFACRE FSL,53' SURFACE LOCATION AT FEL ,SEC 14~TJlN,RSE,UM RECTANGULAR COORDINATES NORTH/SOUT~ EAST/WEST 3200.17 N 4009.87 W 3230.37 N 4039.57 W 3234.93 N 4044.04 W '" 3298.49 N 4104.50 W { 3337.05 N 4139.52 W 3390.88 N 4188.37 W FT ~CO ALAS~A~ lNG. 2~-8 KdPARUK NORTH SLOPE,ALASKA COMPUTATION OAT~: 17-DEC-85 DATE OF SURVEY: 02-NOV-85 KELLY BUSHING ELEVATION: 129.00 ENGINEER: HAL~ACRE TOP EASE TOP PBTD TD MARKER KUPARUK C KUPARUK C KUPARUK A KUPARUK A ORIGIN: 717' MEASURED DEPTH TVD 5ELOW KB FRSM KB SJB-SEA 50T4.00 5845.92 5716.92 ~140.~0 5896.54 575T.54 81~0.00 5904.23 5775.23 8291.00 6014.60 5885.60 8377.00 6083.05 5954.05 8497.00 6178.53 6049.53 FSL,53' FEL REC NO SU T~ RT 20 2~ 23 29 33 39 RFA SEC NGU H/S 0.1 0.3 4.9 8.4 7.0 0.8 2E LOCATION 14,TllN,RSE,UM LAR COORDINATES DUTM EAST/~EST 4009.87 4039.57 4044.04 4104.50 4139.52 4188.37 W W (,' W W W FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEC MIN 8497.00 5178.53 5049.53 5385.92 ~ 51 0 W FT SCHLUMBEROER 0 1RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 2A-8 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOED REFERENCE 00007]087 WELL NAME: 2A-8 SURFACE LOCATION: 717' FSL, 53' FEL, S14, TllN, R8E UM 129. -lO00 0 0 1000 _2TItm3__ 3000 4000 ~iii i iii 7~-'iii~ -~~i i iii~ ...'--!i! ~½~--~+++-,-i...i-~+~-i.--i-+-~-..ki..-~---!-..~ ...... ~-..~-~-.i-F~--.~-..i.-.~..- ~ ~ ~ ~.~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~+-~.-~.~-~--?-.?~--+--~--~?t--~-?"~-~-'~-t-~"T-'~'"+ ..... *'"~"'~'"~'"t"~'"~'";"?" _.~-~-~.~,.~.-~.~-~-~, .~ ~ ~ ~ ~.,, ~ : ~ ~ .~ ~ ~-,--~-~-~- -~--~-~---~--?-.~-~--, ,..~.~..~--.~ ...... ~,_~.-~.~.-.,~...~.-~.,.~,.-,.~,,,~,~...~-. .... ~ .......... ~L3~,~: : [~ ~~.. ~=.~.~_I~-~.-~-~-~-.~-.~4-~-.-~4...~-..~...~-.~...~ ................ ~ .................. ~ ...... ~_~.~ ~~T~~ ~~.~+..+~+~.H+++.b.~..+..+.~..l+.+.~++.~...+ ...... ~'"}"H ...... ~'"+'"?'~ ~t f-%-~-%~ [~]i~ ~] ~ [~ ~]~}[] ~[~'r'~--rr??--'-?-~?-~?-~ ..... ?'~'? ..... ??"-"r'FF~ ...... {'"~-~'":" ]~ . ~ ~ ~ [~ ~]~ ~_ ~$ ~_~~ ~~_...L~L.~._.]~.L~ ....... 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SCALED IN VER~ICAL DEPTHS HORIZ SCALE = 1/1000 IN/FT ' WELL NAME: 2A-8 SURFACE LOCATION: 717' FSL, 53' FEL, S14, TllN, R8E, UM NOI~'rH SO00 RI='F 00007 ~ 087 ~ooo 4000 9OOO 2OOO lOOO -1000 SI~JTH -2000 -6000 WEST HORIZONTAL PROJECTION 6CP, t..£ = l / ! 000 l N/FT -BO00 -4000 -9000 -2000 -1000 0 000 2000 E~T Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. ~P~,ATOR, WEL~ ~N~A~E AND Reports and Materials to be received by: Date Required Date Received Remarks Complet ion Repomt y Samples Core'Description. ": . .,-~-~,. ~gistered Surve~ Plat~ ..h. ..... Inclination Survey Directional Survey ~ ..... , ..... ~ Drill Stem Test Reports ~f ,~'~ .... · , , , Production Test Reports l' Digitized Data .-~ L.FJ.04 ARCO Alaska, Inc. ... Post Office ~oox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 - ...' ~j.'. -~,. '.~ . - · ..-.... '--.-..'.?~_:~.. . _.. RETURN TO: 'ARCO' ALASKA, INC. KUPARUK OPERATIONS ENGINEERING R~CORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 DATE:il-19-85 TRANSMITTAL NO:5453 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND R~TURN ONE SIGNED COPY OF THIS TRANSMITTAL. OPEN HOLE LIS TAPES PLUS LISYING/ $CHL/ ON~ COPY OF EACH 3F-7 11-03-85 RUN ~1 3F-6 . 10-27-~.5 RUN ~1 3C-13 10-26-85 RUN %1 3A-8 10-30-85 RUN gl 3A-1 09-30-85 ~{UN ~1 2A-8 10-29-85 RUN ~1 3456.0-8045. 3384.0-7689. 3134 0-7117 RECEIPT ACKNOWLEDGED: BPAE B. CURRIER CHEVRON D & M DRILLING L. JOHNbT~N MOBIL NSK CLEkK DISTRIBUTION: W. PASHER EXXON PHILLIPS OIL J. RAThMELL UNION VAULT/ANO ARCO Alaska. Inc. i, a Subs,aiary of At. lanlicRichfielclCompany ARCO Alaska, Inc. Post Office B[,,..~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 15, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are the October monthly reports for the following wells' 1B-1 (workover) 3A-7 3C-15 3J-6 9-24 L2-3 2A-8 3A-8 3F-3 3J-7 9-36 L2-13 2D-12 (workover) 3C-6 3F-4 3J-8 16-17 L3-5 3A-5 3C-13 3F-5 4-21 16-18 L3-11 3A-6 3C-14 3F-6 4-22 18-6 (workover) If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU12/L80 Enclosures [ ECEiVED NOV y> J. 85 Alaska Oil & Bas Cons. Cor,qmJssion Anchorag9 ARCO Alaska, Inc. is a Subsidiary ol Atlar~licRichfieldCompany · STATE OF ALASKA ALASKA OY~'AN D GAS CONSERVATION COM..-~ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wel~(~ Workover operation [] Name of operator 7. Permit No. ARCO Alaska, Inc. 85-248 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20049 4. Location of Well atsurface 717' FSL, 53' FEL, 5ec.14, T11N, RSE, UN (approx) 9. Unit or Lease Name Kuparuk River Unit 5. Elevation in feet (indicate KB, DF, etc.) 129' RKB 6. Lease Designation and Serial No. ADL 25570 ALK 2668 10. Well No. 2A-8 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of October ,19 85 12. Depth atend of month, footagedrilled, fishingjobs, directionaldrillingproblems, spud date, remarks Spudded well @ 2245 hrs, 10/20/85. Drilled 12-1/4" hole to 3426'. Ran, cmtd & tstd 9-5/8" csg. Performed top job, Drilled 8-1/2" hole to 8497'TD (10/28/85). Ran logs. Ran, cmtd & tstd 7" csg. Arctic packed well. PBTD = 8377'. Secured well & RR @ 1000 hrs, 10/31/85, 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40 weld conductor set @ 110'. Cmtd w/175 sx CS II. 9-5/8", 36#/ft, J-55, BTC csg w/shoe ~ 3406'. Cmtd w/800 sx AS Ill & 370 sx Class "G". Performed top job w/114 sx AS I. 7", 26#/ft, J-55, BTC csg w/shoe ~ 8459'. Cmtd w/370 sx Class "G". Arctic packed w/250 sx AS I. 14. Coring resume and brief description None 15. Logs run and depth where run Triple combo f/8501' - 3406' 6. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED NOV' 5 1985 Alaska 0il & Gas Cons. O0mm!ssJ0n Anch0rag-~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED //~_,/~'t,,, /~o~)4..~¢.,~.~ TITLE Associate Engi neet DATE / t-14-Z~ // NOTE--Report(~n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 DRH/MR49 Submit in duplicate MEMORANOUM TO: THRU: State f Alaska ALASKA 0IL AND GAS CONSERVATION CO~,94ISSION 0. v. Chairman Lonnie C. Smith Commissioner DATE: October 28, 1985 FILE NO: D. HRH. 85 TELEPHONE NO: FROM: Harold R. Hawkins Petroleum Inspector SUBJECT: BOPE Test ARCO 2A-8 KRU Permit No. 85-248 Kuparuk River Field Thursday, October 24, 1985: I left ARCO's DS 3F-6 KRU, subject of another rep~'rt, to ARCO'S'-' DS 2A-8 well K.R.U. I witnessed the BOPE Test on ARCO's 2A-8 well. There were no failures. I filled out an A.O.G.C.C. report which is attached, In summary, I witnessed the BOPE Test that Parker 191 crew performed for ARCO on 2A-8 Well K.R.U. The tests were satisfactory. Attachment 02-00IA(Rev. 10179) o&¢ ~4 -5/84 Inspector STATE OF ALASKA ALASKA 0IL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Well .o Operator .~ J~ ~'~ .~_~/~_5~1~'/~ /~L~, · . Well 7 ~-~ /'( ~,~ Loc~t~o~: Se~ / ~ T/Id ~ ~ ~ .,, Drillin8 Contractor ~~/~f~ Ri Location, General~ ~/~ Well Sign General Housekeeping ~/~ Rig Reserve Pit . Mud ,Systems Trip Tank Pit.Gauge Flow Monitor Gas' Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Visual Audio · o~ Test Results: Failures, Test Pressure ~0~0 Representative, ~~ &'~/,~t44c ive ~/ ACCUMULATOR SYSTEM Full Charge Pressure 2~ ~ psis Pressure After Closure f'~ ~ psis Pump incr. clos. pres. 200 psis ~ mi~g) sec. . Full Charge Pressure Attained: /// min ~sec. N2,,~/~TX,~% ~/=F~$~ 2nfo psis Controls: Maste~ Remote ~/~ Blinds switch cover ~/~ Kelly and Floor Safety Valves Upper Kelly Test Pressure ~ Lower KellM Test Pressure Ball Type Test Pressure Inside BOP Test Pressure Choke Manifold Test Pressure No. Valves / 7 No. flanges Adjustable Chokes ~~ . ~ ,drauica,lly ,operated choke ~~ .~ Repair or Replacement of failed equipment to be made within :--'---days and Inspector/ Commission office notified. Remarks: _f/~-/~ 5/ ~ 0~ .~__~2.~ ~- / ~ Distribution orig. - A0&GCC cc - Operator cc - Supervisor Inspector . , October 17, 1985 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2A-8 ARCO Alaska, Inc. Permit No. 85-248 Sur. Loc. 717:FSL, 53'FEL, Sec. 14, TllN, RSE, UM. Btmhole Loc. l164'FNL, !132'~4L, Sec. 14, TllN, RSE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very trllly~y~urs, J , C. V. Chatte~t.~n Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COM~4ISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office Bo~-.i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 11, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2A-8 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 2A-8, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plot A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment We estimate spudding this well on October 20, !985. If you have any questions, please call me at 263-4970. Sincerely, Regional Drilling Engineer JBK/LST/tw PD/L180 Enclosures RECEIVED Alaska Oil & Gas Cons. Commfssion Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASKA (3r~ AND GAS CONSERVATION CO~-,~IlSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE MULTIPLE ZONE [] 9. Unit or lease name Kuparuk River 2. Name of operator ARCO Alaska, Inc, 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 717' FSL, 53' FEL, Sec. 14, TllN, R8E, UM At top of proposed producing interval 1382' FNL, 1395' FWL, Sec. 14, TllN, RSE, UM At total depth 1164' FNL, 1132' FWL, See.14, TllN, RSE, UM 10. Well number ~:~ 2A-8 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 129', PAD 94' ADL 25570 ALK 2668 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $5007000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed I 30 mi. NW of Deadhorse miles 53' @ Surface feet 2A-Twell 60' @ Surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date i 8428 ' MD, 6168' TVD feP. t 2560 10/20/85 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures 3050' psig@ ROOF Surface KICK OFF POINT ~-~'~. ?eet. MAXIMUM HOLE ANGLE 42 o (see 20 AAC 25.035 (c) (2) ~,F, OO' psig@ 58_~9, ft. TD (TVD) ~'- ~t~/~,~',~..Proposed Casing, Liner and Cementing Program SIZE Hole Casing [24" 16" 112-114" 9-5/8" 8-1/2" 7" Weight 62,5# 36.0# 26.0# CASING AND LINER Grade Coupling H-40 Weld J-55 BTC HF-ERW J-55 BTC ~ HF-ER~ 22. Describe proposed program: Length SETTING DEPTH QUANTITY OF CEMENT M D TOP TV D 80' 36' I 36' I 3344' 36' 36' I I 35' I 35' 8393' MD BOTTOM TVD 116'I 116~ 3380'I 2779' I 8/+28'1 6168' I I (include stage data) · 200 cf 670 sx AS II1 370 sx Class "G" 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8428' MD (6168' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack' will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3500 psig upon installation and weekly thereafter. Expected maximum surface pressure is 3050 psi. Pressure calculations are based on recent static bottom-hole pressures in nearby gas injection wells. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented'annuli through the permafrost interval. 2A-8 will be 60' away from 2A~7 at Surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left ' with a non-f[,~Z,~ng fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby c~'~ify tt)/at the foregoing is true add correct to the best of my knowledge SIGNED TITLE Regional Drillinq Engineer DATE The space x~ ~r ~/rn~i/~n us'~ y- CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required APl number I--lYES ~J~lO I--~YES I~NO [~j~rY ES UNO 50-/O~- O 0 L/~ Permit number ~ , . Approval date ~.~,,¥~ ~ ~0/~ SEECOVER LETTER FOR OTHER REQUIREMENTS APPROVED BY~ 4~~~~~ Form 10~01 ~nv 7-1 -R~ ,COMMISSIONER DATE October 17, ]985 by order of the Commission Submit in triplicate PERMIT TO DRILL 2A-8 Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. [ ECEIVED Alaska Oil & Gas Cons. Commission Anchorage ---:~'-:;:-':-;. PAD. 2A,.:-.WELL:-~O + ......... KUP ARUK-- F , ......... EASTMAN-i./HIPSTOCK~--INC .... t ,~ F-L4 ~-~---'%-~-~---~-- - t · , , , , ., , ........... ~ ............ · ..... ~ ......... ~i ! ' ': · ..... ~ ........ ~ ................ ~ ........... , . .. , i - ; ...... ~ .... ~ ............ - ~ - - 2'YT-EYY--g-F-" ~_-7'_'.' ~ ' .- ~ ''-'~" - ''~ ~ - ]': .... ' ~ ~TVD=25-79 ~T~~083 DEP= ...... ~. ~ ................... . _ ~ ........ ~ ........................................ ~ ........... ; ......... ~ ~ - -:' _ 4.000 .... ~ .......................... ._ ~ ~ ........ , ....... ' .......... _ .~ .................................... ...................... ~ ............. ~ ..... ~ ....... [ ...... ......... T/-~:ZONE'~C -T-VD=5859--T~D=7968 DEP~4980 , .... TARGET-.-CN TR-~TVD= 5947--TffD= 8099-DEP- 5078 ~ ...... /D-~-(LOO-~iPT) .... ~T-VD 6 68-TMD=84 8wDEP 5322 , , ~ ~ 7eoo:' ~ ', --.] i ' { I ; i, ,. -.b:~--:?L~-~L-~'ooo~ ~. ' ~ 2000 ~ooo_ i ~ooo ~ ...... ~ .... ~ ' i ' .......... ~ ...................... ~ i ~ ' ~ ~ ~ ' . i ' ~ . . . i . . ~ , . J · . . ~ - . f, ' ' i I : . ;r KUPARUK RIVER UNIT 20" DIVEETER SCHEMATIC DESCR I PT I ON I. 16' C~CTOR. 2. TAI~O STARTER IWE~. 3. TAI~O SAVER SUB. 4. TANKO LOWER QUI CK-C~CT ASSY. 5. TAha<O UPPER OU!CK-C~CT ASSYo 6. 20' 2000 PSI DRILL!NG SPOOL Vi/!0' OUTLETS. ?. I0' HCR BALL VALVES W/lO' DIVERTER LINES. VALVES OPEN AUTOMATICALLY UPON CLOSURE OF AI',~t~K_ AR PREVENTER. 8. 20" 2000 PSI Aht~ILAR PREVENTER. 6 btAINTENANCE & OPERATION 2 I. UP-ON INITIAL INSTALLATION. CLOSE PREVENTER AND VERIFY THAT VALVES " HAVE OPENED PROPERLY. 2. CLOSE AhI~JLAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3, CLOSE ANINULAR PREVENTER IN THE EVENT 'THAT AN linc'LUX OF WELLBORE FLUIDS OR GAS IS DETECTED. IF · -.-NECESSARY, MAhaJALLY OVERRIDE AND CLOSE APPROPR I ATE VALVE TO ACHIEVE ~IND DIVERSION. RECE VED Do NOT SHUT IN ~r.c~ ~ ~,~ UNi~R ANY C I RCUI~3TANCES. · . Alaska Oil & Gas Ct-ins, Co"~mJssJo~ Anchorage ' sl~ R'4 -, DTAORAM #1 13-5/8"'~5CX30 PSI RSRRA BOP ~TACK < < 7 > I. 16' - 2.CX~ PSI TAN<CO STARTING hF_AD I1' - ~ PSI X I,:,',',',',',',',',~-~,/8m - 4. 1~8' - ~ 5. 1~8' - ~ h 3 CE VED 2 A~ATCR CAPACITY TE~$T I. Q-ECX AN:) FILL A~TQR .~OIR TO LEVEL WITH HYDRAULIC FLUID. 2. A. SSLI4E THAT A~TCR P~ IS 3003 PSI WITH 3. ~ TIIVE, ~ CI.C~ ALL UNITS SI~JLTAN[CLJSLY 4. I:~O::RD CH NADC REPC:RTo TI-E ACC:EPT~ L~ IS '45 ~ CLOSING TZlv[ ~ 1200 PSI REMAINING PR?_SSLRE. 13-5/8" BCP STACK TEST FILL BCP STACX AhD Q-K]<E MANIF(].D WITH ARCTIC DIESEL. C3-[CX THAT ALL LOCX DOM4 SCREYeS IN ~1:~ L~EAD ARE FULLY RETRACTED. SEAT TEST PLUG IN WITH RUN4I~ JT AhD RL~ IN LCX:XDC:I~ SCREY~. LI~ VALVES ADJACE3NT TO BCP STACX. ALL 4. PRE~ UP TO 250 PSI AhD HOLD FOR I0 MZN. IN- CREASE ~ TO 30:X3 PSI AND HOLD FOR I0 MINg B[~'n PRESSLRE TO 0 PSI. LII~ VALVES. CLOSE TO= PIPE RA~ ~ HC~ VALVES ~ K~LL AN:) Q-O<E LIt,ES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7.. CO~[I~I.JE TESTING ALL VALVES° LII~.So AN:) CHO<ES WITH A 250 PSI LO~ AhD 3000 PSI HIOH. TEST AS IN STEP 4. DO NOT P~~ TEST ANY ~ THAT ES Nor A FLI..L CLOSING POSITIVE SEAL Q-EXE. CN.Y FI.JN~I(:]N TP..ST CHCKF_~ THAT DO AI3T FULLY CLOSE. OPEN TO° PIPE RNV6 AND CLOSE BOI'rCM PIPE RNaS. TEST BOTTCt,4 PIPE RAMS TO 250 PSI A~ 3000 PSI. CLOSE BLIP:) RN,4S A~D TEST TO 250 PSI AN3 3000 -PSI. FLUID. ~ ALL VALVES IN mIU.[NG ~2. TEST S'rA~CPIPE VALVES, ~ t Y° ~ I ¥ COO<S, mZLL PIPE SAFETY VALVE° A~D ~,SIa[ SC~ TO 250 PSI A~ 30O0 PSI. 13. ~ECCRD TEST It, FCRI~TICN CN BL~ AqEVENTER TEST FOI:~, SIGN, AND S~D TO DRILLING SUSIe. 14. PSRF~ ~ BC~ TEST AFTER NIPPLING UP AND W55KLY THSRSAFT~R ~ICI~LLY C):~RAI'~ B(~ DAILY. Gu ,1,; ..... Anchora. os ARCO Alaska, Ir Post Offic_ Jo"6~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 April 9, 1984 Hrs. Elaine Johnson State of Alaska Alaska ~lil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2A-Pad Wells 1-8 Dear Elaine' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG6/L85'tw Enclosure ARCO Alaska, Inc. is a Subsidiary ol AllanticRIchlieldCompany 12 0 ~ 0 ~o0 90 ? (3 ~ 0 5 0 OF~ 0 O! OZ' 0:5 04, 25 I 24. LOCATED IN SECTIONS · · TIlN,. RBE. UMIAT MERIDIAN. I;5, 14, 25, i./J'~lt I... ,.31 I r_.. (-.-~"~ k~L.,/l"Jl.,/gk,,, ., BUILT LOCATIONS ,. WELL-I y = ~,96o, t3s. z3s LA'['., ?0°18'083S 73' X · 498,G2Qg96 LONG= 150° 00' 40Zll'" Z ZT'FWL, 711¥SL EL '- ~4.;5, 06'-89,9 Y = 5,960,078.4Z0 X: 498,6ZO. 914 227' FY/t., $$7'FSL I.. AT: 70° 18'07778 9" ' LONG: 150° 00'40213" EL:94.4,0G :89.8 WELL-3 '-5,960,018.185 LAT: 70°18'071865' · 498,620.912 LONG ,, 1500 00'40213" 2Z?'F~I'L, 597'FCjL ' EL= 94.4,0G:89.6 WELL-4 Y: 5,9 5':J, 958.355 LAT · 70c~ 18' 065~80' X= 4g-~,GZO.959 LONG= 150°00'40ZII" ZZ7'FWL, 537'FSL ' £L=D4.5,0G=90.4 WELL -5 Y=5,959, 958 ?-$1 LAT: 70e11~'065965" X'- 498,340.910 LOJ~G-'ISOc~ 00'48376" $3'FEL , 537'F~1. EL,: 94.0~ OG= 89. $ WELL-$ Y = 5,960,018.341 LAT=70° 18'071874' X'- 498,340.956 LONG'-150°O0'48376' 5$'FEL,SCJT'FSI- ' £L'-93.9, OG~.89. E. WELL-7' Y :.5,960,078. Z 81 X · 498,3443.906 53'FEL, 657'FSL ' LAT= 70° 18'OZ77&9' LONG = 150~00' 4 8577'" EL =95.8~ 0i3: 88.? WELL-8 y :5~960,13 8.371 X = 498~ 340.93~. 53'FEt.~ 717 FSI. LAT'- 70el 8'0836 LONG'IS0~00' 4 837 7" .~- EL=93.7~ OG = 87.8 D.S 2.A DAVID FILUCCi 5276-S - LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ' /I ALASKA ~ THaT THIS PLAT REPRESENTS A SURVEY MADE .. ~$ 18' !~ UNDER MY DIRECT SUPERVISION & THAT. ALL DETAILS ARE CORRECT AS OF'_ . .... ARco-Ala-sk- i' TH' R,¥EY ¢ ~.~~']'"~ _~~: 'Kuparuk Project North Slop. Drilling CONDUCTOR AS- 8uIL'T' LOOATI ONS l_ .,, .... oo, Draughtsman: MC D*g. no.: NSK 9.05.201 dl (2)'Loc. ~~ =/°~/~'~2. Is ~ell to be located ~n a defined pool ,' .......... ~,' Is well located Proper disLance f~om o~her wells , Is su~icien~ undedicated aczeage available in ~his pool (~' thru 12)' 10. . .. 11. .. '(10 and 12) ,12. (13 thru 21) .' (22 thru 26) 13. .14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Is well to be deviated and is Wellbore plat included ................ Is Operator the Only affected party ' "~ Can permit be approved before ten-day wait .......................... · Does operator have a bond in force , . Is a conservation order needed · .~.ee.ele®®eeeeeee.eeeee.ee®ee.ee®®®®e Is administrative approval needed .®eeee®ee.eeeee.eeeeeee®e®eeeee®ee®e.., Is the lease number appropriate eeee®®eeeeeeee.ee.eeeeeeee®ee~le®.®.® .,. Is conductor string provided ........ , ................................. Is. enough cement used to circulate on conductor and surface ......... Will cement tie in'surface· and intermediate'or production strings ...'//4/ Will cement'cover all known productive horizons ................ ; .... Will surface casing protect fresh water zones ..~ .................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to, be kicked off from .an existing wellbore ...... , ...... Is old wellbore abandonment procedure included on 10-403 ..... ' ........ Is adequate wellbore separation proposed ........................... , /~ . Is a diverter sYstem required ee®eeee®eeeeeee.ee.eeeee.eeee.e.eeeeeee Are necessary diagrams of diverter and BOP,equipment attached ....... Does BOPE have sufficient pressure ratimg - Test to '.~.~OO psig .. Does the choke manifold Comply w/API RP-53 (Feb.?8) .................. Is the presence of H2S gas probable . ®e.leleeleeeeleeeee.eee.e.eeeeee®e Additional requirements .......................................... :.. ~ I,-I Additional Remarks: Geology: Eng~iin~. WVA ' ' MTM~ HJH ~ JAL ~~ rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF · POOL CLASS STATUS AREA NO. SHORE 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. .,.'".,."' RECEIVED ............ ............ ::: ;"""' .............................. '" "" "' '" '" '" '" '~' '" ':~ ::~ '"~ '"~ NOV., ~ S I585 " " Alaska Oil & Gas Cons, "'"'"""'" ........... ""'" .... ~': :;: ;'~; Anchorage LIS T .~,:P E V ER.!FIC.'aT!ON LISTING LVP O1,3.HO~ V~i=IC~TI]N LiSTiN~ PA~= 1 X: WELL SITE D.4T~ AND 'T~SLES 4R6 NOT INCLUOED IN THIS LISTING :',~ ~ W4V~POR~S AND F~ST CH.~NNE.L DAT~ ~R:E NO'T INCLUDED IN THIS LISTING )',: LVP OlO.H02 VF-RiFiCATION LISTING PAGE 2 .......,-.,- REEL SERVICE NAME :EOIT D,aTE :85/II/ ORIGIN : REEL NAME :149249 CONTINUATION ~ :01 PREVIOUS REEL : COMMENTS :LIBRARY TAPs ;::'"o,. T-APE HEADER ...... ~-.-~. S:RVIC:,_ . NAM=_ .-r-niT DATE :85/11/ ORIGIN :FS1A TAPE NAME : CONTINUATION ,~ :01 PREVIOUS TAPE : CDMMENTS :LI"BR~RY TAPE ...... FILE HEADER -i~ -~- ~iL5 NAME :EDIT .001 SERVICE NAME : VERSICN ~ DATE : M~XZMUM L=,NGTH ': 1024 ~ZLE TYPE PREVIOUS FILE : ......COMMENTS "'"' ::~ SCHLUM~ ERGE~ ~',~ -'-.,. ALASKA C'~,MPUTING~ CENTER. COMPANY = ARCO ALASKA INC. WELL : 2A-8 FIELD = KUPARUK COUNTY : NORTH SLOPE BOROUGH STATE = ,&LASK4 LVP OlO.H02 VFRiFICATiSN LISTING PA'SE 3 JOB NUMBER AT ACC: 70925 RUN ~ONE, DATE LO.$GED: 29-0CT-55 LOP: C. WILKIE CASING TYPE FLUID DENSITY VISCOSITY PH ¢LUID LOSS MATRIX SANDSTONE : 9.525" @ 36.00' - BiT SIZE = 8.5" TO 8497.0' : POLYMER-WEiG"T;D : 11.9 LS/G RM : 3.46 ~ 68.0 DF : 42.0 S RMF : 3.53 ~ 68-0 DF = 9.5 RMC : 2.92 @ 68.0 DF : 4.9 C3 RM AT BHT : 1.7'42 ~ 142.0 OF =:: :~ ~: ;;: :k MAIN LOG - THIS DATA HAS NOT BEEN OEPTH SHIFTED ....................... ~ .: ........... , ..... ,.' ................... ~,::...,:..:: ....... ~. ........................... SCHLUHBER.GER L~GS INCLUDED Wi'TH THIS MAGN'ETIC T~PE: ~:~ DUAL INDUCTION SPHERICALLY :F~OCUSED LOG (OIL) '.:-' FORMATION OfiNSITY COMP'ENS~TED LOG ,(FON) -,'~ COMPfiNS.~'TED NEUTR'DN LOG (FDN) -,- LVP OiO.HOZ VERiFiCATiON LISTING PASE 4 <:'4: DATA FORMAT =NTRY BLOCKS TYPE 15 0 DATUM SPECIFIC,6TION MNEM SERVICE SERVICE ID 09DER ~ O~PT~ GR DIL SFLU OIL iLM DIL ILD OIL SP DIL NPHI FON GR ~DN NRAT FON NCNL FON FCNL FDN RNRA FDN RHOB ORHD FDN C~LI SiZE 1 1 1 1 BL~CKS UNIT APl aPi A~.! L2G TYPE CLASS FT O0 000 O0 GAPl O0 310 O1 gHMM O0 220 O1 ~MM O0 120 OHMM O0 120 46 MV O0 010 Oi °U O0 890 O0 G~PI O0 310 O1 O0 ~20 O1 CPS O0 330 31 CPS O0 330 30 O0 000 O0 G/C3 O0 350 02 G/C3 O0 356 01 IN O0 280 O1 REPR CgDE 66 73 55 66 66 API FILE HOD NO. 0 0 '0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SI ENTRY 0 1 ,lIN 1 0 ZE .4 4 4 4 4 4 4 4 4 4 4 4 SPL REPR CODE 1 1 t 1 1 1 68 1 68 ! 68 1 68 1 68 ! 68 1 6B ,1 68 I 68 mRDCESS (OCTAL) 68 00000000000000 68 O0000000OO0000 68 00000000000000 68 00000000000000 68 00000000000000 68 O00000000000OO 00000000000000 00000000000000 O000000000000O OOOOOO00000000 00000000000000 00000000000000 00000000000000 O0000OO0000000 00000000000000 OEPT ILO NRAT RHOB 8527.5000 GR 3.0198 .SP ,2,8245 NCNL 2,0,295 DRHO DEPT ILD NRAT RHOB 8000.0000 ER 1.7520 SP 3,6780 NCNL 2.3635 ORHO 9EPT ILO '7000.0000 GR 2,2092 SP 89.1523 -38.1133 2'533,5000 0.0195 111.2773 -41.4258 .1954.6875 0.0.566 106.Zt~8 -31.4328 SFLU NPHI FCNL CALI SFLU NPHI FCNL CALI S F ,L U NPH I 2.3,4'79 31.2500 8~7.3125 8.5020 1.9493 43.&082 516.8125 10.5410 2,0175 38,.4277 !LM GR RNRA ILM GR RNRA ! LM GR 2.32.64 89 15.3 2.9885 1.8301 111.2773 3.78'15 2.250m 106. 2148 LVP O!O.H02 VERIFICATION LiSTi~& PAGE 5 NR~T 3.4475 NCNL RHO~ 2,4299 DRHG 05~T 6000.0003 GR !LO 3,8811 SP NRAT 3,5784 NCNL RHOB 2.3186 DRHO OEPT 5000,0000 GR !LQ 2,1252 SP NRAT 3.?112 NCNL RHOB 2.2283 DRMQ OEOT 4000.0000 GR iLO 6,8562 Sm NRAT 3,6233 NCNL RHOB 2.1194 DRHO OEPT 3392.5000 GR ILO 10.2520 SP NR,~T 4.2546 NCNL RMO~ 2.0491 DRHO 21~1,5000 O,070a 157.5625 -45.2070 20~3.5875 0.025z, 90.7148 -47.5133 2403.5000 -0.0059 73.5898 -64.2852 2167.5000 0.0112 48.4805 -31,9639 1543.6875 -0.3330 FCNL CALl SFLU NPH! FCNL CALI SFLU NPHZ FCNL CALl SFLU NPHZ FCNL CALl SFLU NPHi FCNL CALI ~:~ FILE TRATLER ...... FILE NAME :EDIT .001 SERVICE N~ME : VERSION ~ : DATE : M&XiMUM LENGTH : iOZ4 FILE TYPE : NEXT FILE NAME : *;:-' TAPE TRAILER ;~ SERVICE NAME :EDIT DATE :85/11/ 8 ORIGIN :FS1A TAPE NAME : CONTINU,AT!ON ~ :O1 NEXT TAPE NAME : C~MENTS :LIBRARY T~PE ;',-~:-' REEL TRAILER SERVICE N.&ME :EDIT DATE :85/11/ 8 'JRIGIN : ~EEL NAME :1492.49 CONTiNUaTION ~ :Oi NEXT REEL N~ME : COMMENTS :LIBRARY TAPE ~97.9125 11.7285 4.0320 42.575B 475.1406 9.7935 1.4044 44.7266 596.8125 10.0410 6.8054 44.0430 52~.3125 9.4395 5.4304 .56,9~24 345.6406 8.4941 ILM GR RNR~ !LM 3R RNR6 iLM GR RNRA GR RNRA 3.6487 3.98~6 157.5625 4.3015 2.0334 90.7148 4.0242 6.5534 73.5898 4.1023 2000.6875 4.4656 LVP 010.~02 VERIFICATI2N LISTING