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From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: AOGCC Notification: KRU 2L-310 (PTD 210-028) MIT-IA Failed Date:Monday, May 12, 2025 11:41:33 AM Attachments:AnnComm Surveillance TIO for 2L-310.pdf From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Monday, May 12, 2025 11:38 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: AOGCC Notification: KRU 2L-310 (PTD 210-028) MIT-IA Failed Well Name: 2L-310 Facility: CPF2 PTD: 210-028 Well Type: Inj AA Number (if applicable): AIO 16.004 Amended Amended Internal Waiver (Yes/No if applicable): Type of Issue: Failed MIT-IA Maximum Pressure (if applicable): Date of Occurrence (if applicable): 5/11/2025 Hi Chris, KRU 2L-310 (PTD 210-028) with AIO 16.004 Amended Amended failed its diagnostic MIT-IA on 5/11/2025. The well was already shut in and CPAI plans to perform additional shut-in diagnostics. Proper notification for continued injection or corrective action will be submitted once diagnostics have been completed and a plan forward is determined. The TIO and schematic and bleed log are attached. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2L-310 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2L-310 2025-03-07 1400 1000 -400 IA 2L-310 2025-05-08 1610 1000 -610 IA 2L-310 2025-05-08 1842 775 -1067 IA 2L-310 2025-05-09 2000 750 -1250 IA 2L-310 2025-05-09 1910 650 -1260 IA 2L-310 2025-05-09 1900 700 -1200 IA 2L-310 2025-05-09 1960 593 -1367 IA 2L-310 2025-05-11 1908 1900 -8 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 10,104.0 11/18/2019 2L-310 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SET PATCH 4/14/2020 2L-310 condijw Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 112.0 Set Depth (TVD) … 112.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 27.6 Set Depth (ftKB) 3,521.0 Set Depth (TVD) … 2,416.7 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 25.6 Set Depth (ftKB) 10,247.0 Set Depth (TVD) … 5,615.2 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-m Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 23.3 Set Depth (ft… 9,800.0 Set Depth (TVD) (… 5,283.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.3 23.3 0.00 HANGER FMC GEN V TUBING HANGER 2.992 516.4 515.9 4.54 NIPPLE CAMCO DS NIPPLE w/2.875" PROFILE 2.875 9,671.2 5,194.0 48.89 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.812 'D' PROFILE 2.812 9,723.8 5,229.4 46.52 PBR BAKER 80-40 PBR 2.990 9,737.2 5,238.6 46.02 PACKER BAKER FHL PACKER 2.990 9,790.3 5,276.2 44.03 NIPPLE CAMCO 'D' NIPPLE w/ 2.75" NO GO 2.750 9,799.5 5,282.8 43.69 WLEG WIRELINE ENTRY GUIDE 2.920 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 3,653.0 2,476.8 63.09 PATCH - UPR PKR (ME) 2.72" P2P SPACER & ANCHOR LATCH, OAL 25.09' / SN: CPP35228 / CPAL35147) 4/14/2020 1.620 3,657.0 2,478.6 63.14 SPACER 2-1/16" SPACER & ANCHOR LATCH @ 3653' RKB (ME) (OAL 25.09' / SN: CPP35228 / CPAL35147), MITT 3000 PASS. COMPLETE. 4/14/2020 1.620 3,675.0 2,486.7 63.40 SPACER 2.70" PBR, 2-1/16" SPACER PIPE, ANCHOR LATCH, OAL 31.62' / SN: CPPBR35026 / CPAL35118 4/14/2020 1.620 3,708.0 2,501.4 63.87 PATCH - LWR PKR (ME) 2.72" P2P, OAL 4.01' , SN:CPP35254 4/13/2020 1.620 6,938.0 3,929.7 62.90 PATCH 2.72" SOS UPPER PARAGON II PACKER (ser# cpp 35040) W/ 15.49' SPACER PIPE & LATCH ASSEMBLY (ser# cpal 35018) 1/15/2016 1.625 6,953.0 3,936.6 62.92 PATCH 2.72" SOS LOWER PARAGON II PACKER (ser# cpp35043) 1/15/2016 1.625 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 10,005.0 10,019.0 5,434.5 5,444.9 Bermuda, 2L- 310 6/8/2010 6.0 IPERF 2.5" Prospector RDX DP charges, 60 deg phase Frac Summary Start Date 6/10/2010 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 6/10/2010 Top Depth (ftKB) 10,005.0 Btm (ftKB) 10,019.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 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 3,697.2 2,496.6 Camco KBG-2- 9 1 GAS LIFT DMY INT 0.000 4/12/2020 2 8,716.8 4,728.9 Camco KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2010 5:00 3 9,617.2 5,159.3 Camco KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2013 1:00 Notes: General & Safety End Date Annotation 5/15/2014 NOTE: WAIVERED FOR WAG INJ WITH T x IA ON MI. 5/16/2013 NOTE: CONVERTED TO INJECTION (PRE-PRODUCED 3 YEARS) 5/18/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 HORIZONTAL, 2L-310, 4/15/2020 6:01:26 AM Vertical schematic (actual) PRODUCTION; 25.6-10,247.0 IPERF; 10,005.0-10,019.0 FRAC; 10,005.0 PACKER; 9,737.2 GAS LIFT; 9,617.2 GAS LIFT; 8,716.8 PATCH; 6,953.0 PATCH; 6,938.0 PATCH - LWR PKR (ME); 3,708.0 GAS LIFT; 3,697.2 SPACER; 3,675.0 SPACER; 3,657.0 PATCH - UPR PKR (ME); 3,653.0 SURFACE; 27.6-3,521.0 NIPPLE; 516.4 CONDUCTOR; 28.0-112.0 KUP INJ KB-Grd (ft) 33.20 Rig Release Date 5/13/2010 2L-310 ... TD Act Btm (ftKB) 10,252.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032061600 Wellbore Status INJ Max Angle & MD Incl (°) 67.51 MD (ftKB) 2,780.72 WELLNAME WELLBORE2L-310 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2L-310 (PTD 210-028) Report of IA over Operating Pressure Limit Date:Monday, May 12, 2025 7:15:12 AM Attachments:2L-310 90 Day TIO Plot & Schematic.pdf From: NSK Wells Integrity Eng CPF1 & CPF3 <n1617@conocophillips.com> Sent: Friday, May 9, 2025 3:07 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; NSK Wells Integrity Eng CPF2 <n2549@conocophillips.com>; Automation, AK Wells <akwellsautomation@conocophillips.com> Subject: KRU 2L-310 (PTD 210-028) Report of IA over Operating Pressure Limit Well Name: 2L-310 Facility: CPF2 PTD: 210-028 Well Type: Inj AA Number (if applicable): AIO 16.004 Amended Amended Internal Waiver (Yes/No if applicable): No Type of Issue: Suspect Integrity / IA Exceeded OPL Maximum Pressure (if applicable): 2035 Date of Occurrence (if applicable): 5/8/25 Chris, KRU 2L-310 (PTD 210-028) (AIO 16.004 Amended Amended) was reported by Operations yesterday 5/8/25 to have an IA pressure of 2035 psi. The 7 5/8” 29.7 lb/ft, L-80 has a burst rating of 6890 psi (45% burst rating = 3100 psi). The DSO bled the IA pressure multiple times, but the IA has shown quick re-pressurization. The well was shut in and freeze protected 5/8/25. CPAI plans to perform initial diagnostics. Proper notification for continued injection or corrective action will be submitted once diagnostics have been completed and a plan forward is determined. CPAI plans to let the IA pressure stabilize above the operating pressure limit of 2000 psi during diagnostics but will be kept below the 45% burst rating of 3100 psi. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 10,104.0 11/18/2019 2L-310 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SET PATCH 4/14/2020 2L-310 condijw Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 112.0 Set Depth (TVD) … 112.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 27.6 Set Depth (ftKB) 3,521.0 Set Depth (TVD) … 2,416.7 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 25.6 Set Depth (ftKB) 10,247.0 Set Depth (TVD) … 5,615.2 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-m Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 23.3 Set Depth (ft… 9,800.0 Set Depth (TVD) (… 5,283.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.3 23.3 0.00 HANGER FMC GEN V TUBING HANGER 2.992 516.4 515.9 4.54 NIPPLE CAMCO DS NIPPLE w/2.875" PROFILE 2.875 9,671.2 5,194.0 48.89 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.812 'D' PROFILE 2.812 9,723.8 5,229.4 46.52 PBR BAKER 80-40 PBR 2.990 9,737.2 5,238.6 46.02 PACKER BAKER FHL PACKER 2.990 9,790.3 5,276.2 44.03 NIPPLE CAMCO 'D' NIPPLE w/ 2.75" NO GO 2.750 9,799.5 5,282.8 43.69 WLEG WIRELINE ENTRY GUIDE 2.920 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 3,653.0 2,476.8 63.09 PATCH - UPR PKR (ME) 2.72" P2P SPACER & ANCHOR LATCH, OAL 25.09' / SN: CPP35228 / CPAL35147) 4/14/2020 1.620 3,657.0 2,478.6 63.14 SPACER 2-1/16" SPACER & ANCHOR LATCH @ 3653' RKB (ME) (OAL 25.09' / SN: CPP35228 / CPAL35147), MITT 3000 PASS. COMPLETE. 4/14/2020 1.620 3,675.0 2,486.7 63.40 SPACER 2.70" PBR, 2-1/16" SPACER PIPE, ANCHOR LATCH, OAL 31.62' / SN: CPPBR35026 / CPAL35118 4/14/2020 1.620 3,708.0 2,501.4 63.87 PATCH - LWR PKR (ME) 2.72" P2P, OAL 4.01' , SN:CPP35254 4/13/2020 1.620 6,938.0 3,929.7 62.90 PATCH 2.72" SOS UPPER PARAGON II PACKER (ser# cpp 35040) W/ 15.49' SPACER PIPE & LATCH ASSEMBLY (ser# cpal 35018) 1/15/2016 1.625 6,953.0 3,936.6 62.92 PATCH 2.72" SOS LOWER PARAGON II PACKER (ser# cpp35043) 1/15/2016 1.625 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 10,005.0 10,019.0 5,434.5 5,444.9 Bermuda, 2L- 310 6/8/2010 6.0 IPERF 2.5" Prospector RDX DP charges, 60 deg phase Frac Summary Start Date 6/10/2010 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 6/10/2010 Top Depth (ftKB) 10,005.0 Btm (ftKB) 10,019.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 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 3,697.2 2,496.6 Camco KBG-2- 9 1 GAS LIFT DMY INT 0.000 4/12/2020 2 8,716.8 4,728.9 Camco KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2010 5:00 3 9,617.2 5,159.3 Camco KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2013 1:00 Notes: General & Safety End Date Annotation 5/15/2014 NOTE: WAIVERED FOR WAG INJ WITH T x IA ON MI. 5/16/2013 NOTE: CONVERTED TO INJECTION (PRE-PRODUCED 3 YEARS) 5/18/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 HORIZONTAL, 2L-310, 4/15/2020 6:01:26 AM Vertical schematic (actual) PRODUCTION; 25.6-10,247.0 IPERF; 10,005.0-10,019.0 FRAC; 10,005.0 PACKER; 9,737.2 GAS LIFT; 9,617.2 GAS LIFT; 8,716.8 PATCH; 6,953.0 PATCH; 6,938.0 PATCH - LWR PKR (ME); 3,708.0 GAS LIFT; 3,697.2 SPACER; 3,675.0 SPACER; 3,657.0 PATCH - UPR PKR (ME); 3,653.0 SURFACE; 27.6-3,521.0 NIPPLE; 516.4 CONDUCTOR; 28.0-112.0 KUP INJ KB-Grd (ft) 33.20 Rig Release Date 5/13/2010 2L-310 ... TD Act Btm (ftKB) 10,252.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032061600 Wellbore Status INJ Max Angle & MD Incl (°) 67.51 MD (ftKB) 2,780.72 WELLNAME WELLBORE2L-310 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, October 14, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2L-310 KUPARUK RIV U TARN 2L-310 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/14/2024 2L-310 50-103-20616-00-00 210-028-0 W SPT 5238 2100280 3900 1800 1800 1800 1800 521 531 530 530 REQVAR P Josh Hunt 8/6/2024 2-Year MIT-IA Required by AIO 16.004 Required test pressure to pass is the max anticipated injection pressure of 3900 psi 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 U TARN 2L-310 Inspection Date: Tubing OA Packer Depth 700 4210 4090 4070IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240806164818 BBL Pumped:6.3 BBL Returned:6.1 Monday, October 14, 2024 Page 1 of 1 9 9 9 9 99 9 9 999 9 9 9 9 9 2-Year MIT-IA AIO 16.004 James B. Regg Digitally signed by James B. Regg Date: 2024.10.14 16:24:45 -08'00' 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 2L-310 (PTD 210-028) Exceeded IA DNE Date:Wednesday, September 25, 2024 9:00:39 AM From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, September 25, 2024 8:17 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: KRU 2L-310 (PTD 210-028) Exceeded IA DNE Hi Chris, KRU 2L-310 (PTD 210-028) is a waivered WAG injector currently on MI injection. The IA has continued to require bleeds with a stabilized injection pressure and is no longer compliant with AIO 16.004 Amended which limits to 2 non thermal bleeds per month. CPAI will now conduct diagnostics. Please let me know if you have any questions or do not agree with the plan. Thanks, Jaime From: Well Integrity Specialist CPF2 Sent: Monday, September 16, 2024 8:38 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2L-310 (PTD 210-028) Exceeded IA DNE Hi Chris, KRU 2L-310 (PTD 210-028) is a WAG injector currently on MI injection. The IA pressure exceeded the DNE of 2400 psi on September 11, 2024 with a pressure of 2480 psi before being bled by the operations team. The Operations team had increased the injection rate causing raising IA pressure. Following the pressure excursion, the IA was bleed from 2480 psi to 1950 psi. The IA has stabilized at the new injection rate at 2100 psi. The well recently passed a surface casing lead detection on the OA and an MIT-IA to 4210 psi passed. The production casing is 7-5/8” 29.7# L80 with a burst rating of 6890 psi (45% of burst is 3100 psi). CPAI does not intend to conduct diagnostics at this point as it is believed that the increased IA pressure was due to the increase in injection rate. CPAI will continue to monitor this well closely and report as required if any additional anomalies are observed. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2L-310 (PTD 210-028) Exceeded IA DNE Date:Monday, September 16, 2024 9:00:34 AM Attachments:AnnComm Surveillance TIO for 2L-310.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Monday, September 16, 2024 8:38 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2L-310 (PTD 210-028) Exceeded IA DNE Hi Chris, KRU 2L-310 (PTD 210-028) is a WAG injector currently on MI injection. The IA pressure exceeded the DNE of 2400 psi on September 11, 2024 with a pressure of 2480 psi before being bled by the operations team. The Operations team had increased the injection rate causing raising IA pressure. Following the pressure excursion, the IA was bleed from 2480 psi to 1950 psi. The IA has stabilized at the new injection rate at 2100 psi. The well recently passed a surface casing lead detection on the OA and an MIT-IA to 4210 psi passed. The production casing is 7-5/8” 29.7# L80 with a burst rating of 6890 psi (45% of burst is 3100 psi). CPAI does not intend to conduct diagnostics at this point as it is believed that the increased IA pressure was due to the increase in injection rate. CPAI will continue to monitor this well closely and report as required if any additional anomalies are observed. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2L-310 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2L-310 2024-07-02 903.0 727 -176.0 IA 2L-310 2024-07-08 535.0 50 -485.0 IA 2L-310 2024-08-14 430.0 515 85.0 IA 2L-310 2024-08-16 381.0 200 -181.0 OA 2L-310 2024-08-17 367.0 130 -237.0 OA 2L-310 2024-08-18 460.0 210 -250.0 OA 2L-310 2024-08-19 454.0 230 -224.0 OA 2L-310 2024-09-11 2500.0 1950 -550.0 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 10,104.0 11/18/2019 2L-310 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SET PATCH 4/14/2020 2L-310 condijw Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 112.0 Set Depth (TVD) … 112.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 27.6 Set Depth (ftKB) 3,521.0 Set Depth (TVD) … 2,416.7 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 25.6 Set Depth (ftKB) 10,247.0 Set Depth (TVD) … 5,615.2 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-m Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 23.3 Set Depth (ft… 9,800.0 Set Depth (TVD) (… 5,283.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.3 23.3 0.00 HANGER FMC GEN V TUBING HANGER 2.992 516.4 515.9 4.54 NIPPLE CAMCO DS NIPPLE w/2.875" PROFILE 2.875 9,671.2 5,194.0 48.89 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.812 'D' PROFILE 2.812 9,723.8 5,229.4 46.52 PBR BAKER 80-40 PBR 2.990 9,737.2 5,238.6 46.02 PACKER BAKER FHL PACKER 2.990 9,790.3 5,276.2 44.03 NIPPLE CAMCO 'D' NIPPLE w/ 2.75" NO GO 2.750 9,799.5 5,282.8 43.69 WLEG WIRELINE ENTRY GUIDE 2.920 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 3,653.0 2,476.8 63.09 PATCH - UPR PKR (ME) 2.72" P2P SPACER & ANCHOR LATCH, OAL 25.09' / SN: CPP35228 / CPAL35147) 4/14/2020 1.620 3,657.0 2,478.6 63.14 SPACER 2-1/16" SPACER & ANCHOR LATCH @ 3653' RKB (ME) (OAL 25.09' / SN: CPP35228 / CPAL35147), MITT 3000 PASS. COMPLETE. 4/14/2020 1.620 3,675.0 2,486.7 63.40 SPACER 2.70" PBR, 2-1/16" SPACER PIPE, ANCHOR LATCH, OAL 31.62' / SN: CPPBR35026 / CPAL35118 4/14/2020 1.620 3,708.0 2,501.4 63.87 PATCH - LWR PKR (ME) 2.72" P2P, OAL 4.01' , SN:CPP35254 4/13/2020 1.620 6,938.0 3,929.7 62.90 PATCH 2.72" SOS UPPER PARAGON II PACKER (ser# cpp 35040) W/ 15.49' SPACER PIPE & LATCH ASSEMBLY (ser# cpal 35018) 1/15/2016 1.625 6,953.0 3,936.6 62.92 PATCH 2.72" SOS LOWER PARAGON II PACKER (ser# cpp35043) 1/15/2016 1.625 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 10,005.0 10,019.0 5,434.5 5,444.9 Bermuda, 2L- 310 6/8/2010 6.0 IPERF 2.5" Prospector RDX DP charges, 60 deg phase Frac Summary Start Date 6/10/2010 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 6/10/2010 Top Depth (ftKB) 10,005.0 Btm (ftKB) 10,019.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 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 3,697.2 2,496.6 Camco KBG-2- 9 1 GAS LIFT DMY INT 0.000 4/12/2020 2 8,716.8 4,728.9 Camco KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2010 5:00 3 9,617.2 5,159.3 Camco KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2013 1:00 Notes: General & Safety End Date Annotation 5/15/2014 NOTE: WAIVERED FOR WAG INJ WITH T x IA ON MI. 5/16/2013 NOTE: CONVERTED TO INJECTION (PRE-PRODUCED 3 YEARS) 5/18/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 HORIZONTAL, 2L-310, 4/15/2020 6:01:26 AM Vertical schematic (actual) PRODUCTION; 25.6-10,247.0 IPERF; 10,005.0-10,019.0 FRAC; 10,005.0 PACKER; 9,737.2 GAS LIFT; 9,617.2 GAS LIFT; 8,716.8 PATCH; 6,953.0 PATCH; 6,938.0 PATCH - LWR PKR (ME); 3,708.0 GAS LIFT; 3,697.2 SPACER; 3,675.0 SPACER; 3,657.0 PATCH - UPR PKR (ME); 3,653.0 SURFACE; 27.6-3,521.0 NIPPLE; 516.4 CONDUCTOR; 28.0-112.0 KUP INJ KB-Grd (ft) 33.20 Rig Release Date 5/13/2010 2L-310 ... TD Act Btm (ftKB) 10,252.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032061600 Wellbore Status INJ Max Angle & MD Incl (°) 67.51 MD (ftKB) 2,780.72 WELLNAME WELLBORE2L-310 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supervisor To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:Well Integrity Specialist CPF2 Subject:2L-310 Surface casing leak detect 10-426 form from 8-16-24 Date:Sunday, August 18, 2024 11:46:19 AM Attachments:image001.png SCLD KRU 2L-310 08-16-24.xlsx Please see the attached 10-426 form from the surface casing leak detect at 2L-310 from 8-16- 24. If you have any questions or concerns, please let me know. Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .58/ 37' 0,75HSRUWLVWKHLQFRUUHFWIRUPIRUGRFXPHQWLQJDVXUIDFHFDVLQJOHDN GHWHFWWHVW-5HJJ Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2100280 Type Inj N Tubing Type Test P Packer TVD 5239 BBL Pump IA Interval O Test psi 1200 BBL Return OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 2L Pad Waived Fowler / Galle 08/16/24 Notes:Surface casing leak detect per AIO 16.004 Amended. Witnessed waived by Adam Earl. SCLD passed per the 1000' OA fluid level criteria. Notes: 2L-310 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2024-0816_MIT_KRU_2L-310_SCLD &3$,DFFHSWDQFHFULWHULD-5HJJ MEU SCLD passed per the 1000' OA fluid level criteria. &3$,DFFHSWDQFHFULWHULD-5HJJ 1 Regg, James B (OGC) From:Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent:Tuesday, August 30, 2022 11:12 AM To:Regg, James B (OGC); Brooks, Phoebe L (OGC); Wallace, Chris D (OGC); DOA AOGCC Prudhoe Bay Cc:Earhart, Will C Subject:Emailing: SCLD KRU 2N-306 8-28-22.xlsx, SCLD KRU 2L-310 08-25-22.xlsx, SCLD KRU 2L-305 08-26-22.xlsx, SCLD KRU 2L-319 08-27-22.xlsx, SCLD KRU 2N-337C 08-29-22.xlsx Attachments:SCLD KRU 2N-306 8-28-22.xlsx; SCLD KRU 2L-310 08-25-22.xlsx; SCLD KRU 2L-305 08-26-22.xlsx; SCLD KRU 2L-319 08-27-22.xlsx; SCLD KRU 2N-337C 08-29-22.xlsx 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. All Attached are the 10 426 forms for the SCLD that are required for each wells associated administrative approval. Due to the fact that the surface casing leak detects are performed with a gas media there are no "bbls pumped" nor "bbls returned". CPAI's surface casing leak detects have two passing criteria; pass according to the MIT OA criteria to 1200 psi or if the OA fluid level depresses below 1000' without maintain MIT criteria. The wells that passed with MIT criteria will have the numbers input into the "Pressures" boxes as a UIC compliance MIT would. If the OA fluid level depressed below 1000' without meeting the MIT criteria the notation of a passing test is placed in the "Notes" portion of the 10 426. Since this is the first submittal of these types of tests if there is additional information in which you believe to be beneficial or you would rather have these test reported in a different manner please feel free to reach out to discuss. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 265 6218 Cell phone: (907) 830 9777 Submit to: OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2100280 Type Inj W Tubing Type Test O Packer TVD 5239 BBL Pump IA Interval O Test psi 1200 BBL Return OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mec han ical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Surface casing leak detect per AIO 16.004. Witness waived by Sully Sullivan. SCLD passed per the 1000' OA fluid level criteria. Notes: 2L-310 Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 2L Pad Waived Caudle / Galle 08/25/22 Form 10-426 (Revised 01/2017)2022-0825_MIT_KRU_2L-310_OAFL passed per the 1000' OA fluid level criteria.AIO 16.004. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 2, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2L-310 KUPARUK RIV U TARN 2L-310 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 2L-310 50-103-20616-00-00 210-028-0 W SPT 5238 2100280 3900 1810 1810 1810 1810 401 417 415 413 REQVAR P Austin McLeod 8/3/2022 Two year MITIA to MAIP. AIO 16.004 ammended allowing well to remain WAG 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 U TARN 2L-310 Inspection Date: Tubing OA Packer Depth 590 4200 4125 4100IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220804184229 BBL Pumped:6.1 BBL Returned:6.1 Friday, September 2, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 Two year MITIA AIO 16.004 James B. Regg Digitally signed by James B. Regg Date: 2022.09.02 13:28:38 -08'00' From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: CPAI Tarn injector 2L-310 (PTD #210-028-0) IA FL monitor period complete Date:Friday, October 29, 2021 12:46:53 PM Attachments:image001.png 2L-310 90 day TIO plot.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Friday, October 29, 2021 12:46 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI Tarn injector 2L-310 (PTD #210-028-0) IA FL monitor period complete Chris- Tarn injector 2L-310 (PTD #210-028-0) has completed the 60 day IA fluid level monitor period. The IA was loaded with diesel and passed a diagnostic MIT-IA and IA DDT. DHD monitored the IA fluid level which has not shown any indications of fluid fall out. CPAI intends to return the well to normal injection status under AIO 16.004. Please let me know if you have any questions or disagree with the plan. Attached is the current 90 day TIO plot. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, August 25, 2021 2:59 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI Tarn injector 2L-310 (PTD #210-028-0) deep IA FL Chris- Tarn injector 2L-310 (PTD #210-028-0) was identified during the internal waiver compliance IA fluid level surveillance to have a deeper IA fluid level than expected. The well currently operates under AIO 16.004 allowing WAG injection with known TxIA communication while on gas injection. The well has been on water injection since Jan 2021. CPAI intends leave the well on injection during the diagnostic process. If the diagnostics indicate the IA has integrity, the well will be monitored for 60 days to verify if additional IA fluid level fall out occurs. If the diagnostic prove an additional failure, the well will be reported as required per AIO 16.004 and the proper paper work for continued injection or repair will be submitted. Please let me know if you have any questions or disagree with the plan. Attached is a 90 day TIO plot and well bore schematic. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Annular Communication Surveillance 31-Jul-2021Well Name:2L-310 Start Date:31-Jul-2021 29-Oct-2021Days:90 End Date:29-Oct-2021 50 60 70 80 90 100 110 120 130 140 150 0 200 400 600 800 1000 1200 1400 1600 1800 2000 31-Jul-213-Aug-216-Aug-219-Aug-2112-Aug-2115-Aug-2118-Aug-2121-Aug-2124-Aug-2127-Aug-2130-Aug-212-Sep-215-Sep-218-Sep-2111-Sep-2114-Sep-2117-Sep-2120-Sep-2123-Sep-2126-Sep-2129-Sep-212-Oct-215-Oct-218-Oct-2111-Oct-2114-Oct-2117-Oct-2120-Oct-2123-Oct-2126-Oct-2129-Oct-21Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 200 400 600 800 1000 1200 1400 1600 1800 31-Jul-213-Aug-216-Aug-219-Aug-2112-Aug-2115-Aug-2118-Aug-2121-Aug-2124-Aug-2127-Aug-2130-Aug-212-Sep-215-Sep-218-Sep-2111-Sep-2114-Sep-2117-Sep-2120-Sep-2123-Sep-2126-Sep-2129-Sep-212-Oct-215-Oct-218-Oct-2111-Oct-2114-Oct-2117-Oct-2120-Oct-2123-Oct-2126-Oct-21Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: CPAI Tarn injector 2L-310 (PTD #210-028-0) deep IA FL Date:Wednesday, August 25, 2021 3:17:04 PM Attachments:image001.png 2L-310 90 day TIO plot.pdf 2L-310.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, August 25, 2021 2:59 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI Tarn injector 2L-310 (PTD #210-028-0) deep IA FL Chris- Tarn injector 2L-310 (PTD #210-028-0) was identified during the internal waiver compliance IA fluid level surveillance to have a deeper IA fluid level than expected. The well currently operates under AIO 16.004 allowing WAG injection with known TxIA communication while on gas injection. The well has been on water injection since Jan 2021. CPAI intends leave the well on injection during the diagnostic process. If the diagnostics indicate the IA has integrity, the well will be monitored for 60 days to verify if additional IA fluid level fall out occurs. If the diagnostic prove an additional failure, the well will be reported as required per AIO 16.004 and the proper paper work for continued injection or repair will be submitted. Please let me know if you have any questions or disagree with the plan. Attached is a 90 day TIO plot and well bore schematic. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Annular Communication Surveillance 27-May-2021Well Name:2L-310 Start Date:27-May-2021 25-Aug-2021Days:90 End Date:25-Aug-2021 50 60 70 80 90 100 110 120 130 140 150 0 200 400 600 800 1000 1200 1400 1600 1800 2000 27-May-2130-May-212-Jun-215-Jun-218-Jun-2111-Jun-2114-Jun-2117-Jun-2120-Jun-2123-Jun-2126-Jun-2129-Jun-212-Jul-215-Jul-218-Jul-2111-Jul-2114-Jul-2117-Jul-2120-Jul-2123-Jul-2126-Jul-2129-Jul-211-Aug-214-Aug-217-Aug-2110-Aug-2113-Aug-2116-Aug-2119-Aug-2122-Aug-2125-Aug-21Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 200 400 600 800 1000 1200 1400 1600 1800 27-May-2130-May-212-Jun-215-Jun-218-Jun-2111-Jun-2114-Jun-2117-Jun-2120-Jun-2123-Jun-2126-Jun-2129-Jun-212-Jul-215-Jul-218-Jul-2111-Jul-2114-Jul-2117-Jul-2120-Jul-2123-Jul-2126-Jul-2129-Jul-211-Aug-214-Aug-217-Aug-2110-Aug-2113-Aug-2116-Aug-2119-Aug-2122-Aug-21Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD Annular Communication Surveillance 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 2L-310 Annular Communication Surveillance 2L-310 2L-310 2L-310 2L-310 2L-310 Annular Communication Surveillance 2L-310 90-Day Bleed History WELL_ID TIME STR-PRES END-PRES DIF-PRES CASING SERVICE 2L-310 1/20/21 1775 1080 695 INNER PWI 2L-310 9/30/20 2365 1315 1050 INNER MIS 2L-310 8/27/20 592 500 92 OUTER MIS 2L-310 8/19/20 2399 1250 1149 INNER MIS 2L-310 8/10/20 2355 1235 1120 INNER MIS 2L-310 8/3/20 2130 1800 330 INNER MIS 2L-310 7/26/20 2250 1541 709 INNER MIS 2L-310 7/14/20 2020 280 1740 INNER MIS 2L-310 7/13/20 2030 1600 430 INNER MIS 2L-310 6/30/20 550 340 210 OUTER MIS 2L-310 5/5/20 650 1000 -350 INNER PWI 2L-310 5/5/20 540 400 140 OUTER PWI 2L-310 5/3/20 1470 550 920 INNER PWI 2L-310 4/21/20 1501 650 851 INNER PWI 2L-310 4/17/20 1821 740 1081 INNER PWI 2L-310 2/22/20 430 305 125 OUTER MIS 2L-310 2/19/20 480 325 155 OUTER MIS 2L-310 11/16/19 2399 1650 749 INNER MIS 2L-310 11/10/19 2320 1585 735 INNER MIS 2L-310 11/5/19 2245 1600 645 INNER MIS 2L-310 10/31/19 2388 1580 808 INNER MIS 2L-310 10/28/19 2410 1650 760 INNER MIS 2L-310 10/22/19 2330 1500 830 INNER MIS 2L-310 10/11/19 2338 1460 878 INNER MIS 2L-310 10/4/19 2307 1525 782 INNER MIS 2L-310 9/8/19 2215 1200 1015 INNER MIS 2L-310 9/3/19 2250 1660 590 INNER MIS 2L-310 2/20/19 70 1 69 INNER PWI 2L-310 1/12/19 315 1 314 INNER PWI 2L-310 11/28/18 1423 270 1153 INNER PWI 2L-310 11/23/18 2186 890 1296 INNER PWI 2L-310 11/4/18 2189 1000 1189 INNER MIS 2L-310 10/19/18 1873 705 1168 INNER MIS 2L-310 8/12/18 839 240 599 OUTER PWI 2L-310 8/11/18 520 1000 -480 OUTER PWI 2L-310 2/14/17 595 600 -5 INNER PWI 2L-310 1/27/17 745 525 220 INNER PWI 2L-310 2/4/16 750 685 65 INNER PWI 2L-310 2/1/16 832 675 157 INNER PWI Annular Communication Surveillance 2L-310 1/28/16 1655 657 998 INNER PWI 2L-310 1/26/16 1905 636 1269 INNER PWI 2L-310 11/22/15 480 404 76 INNER PWI 2L-310 11/11/15 1667 1650 17 INNER PWI 2L-310 11/10/15 2010 700 1310 INNER PWI 2L-310 7/3/14 730 460 270 INNER PWI 2L-310 5/12/14 665 800 -135 OUTER PWI 2L-310 5/12/14 723 214 509 OUTER PWI 2L-310 5/2/14 275 744 -469 OUTER PWI 2L-310 5/1/14 375 63 312 OUTER PWI 2L-310 5/1/14 375 63 312 OUTER PWI 2L-310 3/10/14 1650 470 1180 INNER PWI 2L-310 3/7/14 2001 1460 541 INNER PWI 2L-310 2/26/14 1991 1228 763 INNER MIS 2L-310 2/5/14 1890 1200 690 INNER MIS 2L-310 1/16/14 2430 1547 883 INNER MIS 2L-310 11/3/13 300 36 264 INNER MIS 2L-310 11/3/13 174 3 171 INNER MIS 2L-310 11/1/13 1986 225 1761 INNER MIS 2L-310 10/14/13 2381 1600 781 INNER MIS 2L-310 9/21/13 2300 1350 950 INNER MIS 2L-310 9/5/13 2950 1475 1475 INNER MIS 2L-310 8/26/13 1956 460 1496 INNER GIN 2L-310 8/24/13 2145 1160 985 INNER GIN 2L-310 7/17/13 1900 1500 400 INNER MIS 2L-310 6/2/13 1810 1000 810 INNER MIS 2L-310 6/2/13 1720 500 1220 INNER MIS 2L-310 5/16/13 1610 800 810 INNER MIS 2L-310 6/23/10 2990 2000 990 INNER GLO Annular Communication Surveillance 2L-310 2L-310 2L-310 2L-310 2L-310 Annular Communication Surveillance WELL_ID DATE_TEST ANNULUS_ PRES_INNE R ANNULUS_ PRES_OUT ER ANNULUS_ PRES_OUT ER2 ANNULUS_ PRES_OUT ER3 WELL_ID 2L-310 5/27/21 1272 457 2L-310 2L-310 5/28/21 1271 457 2L-310 2L-310 5/29/21 1270 457 2L-310 2L-310 5/30/21 1271 457 2L-310 2L-310 5/31/21 1274 458 2L-310 2L-310 6/1/21 1271 457 2L-310 2L-310 6/2/21 1270 457 2L-310 2L-310 6/3/21 1268 457 2L-310 2L-310 6/4/21 1268 457 2L-310 2L-310 6/5/21 1269 457 2L-310 2L-310 6/6/21 1263 456 2L-310 2L-310 6/7/21 1261 456 2L-310 2L-310 6/8/21 1262 457 2L-310 2L-310 6/9/21 1262 457 2L-310 2L-310 6/10/21 1266 457 2L-310 2L-310 6/11/21 1269 456 2L-310 2L-310 6/12/21 1268 456 2L-310 2L-310 6/13/21 1262 455 2L-310 2L-310 6/14/21 1259 455 2L-310 2L-310 6/15/21 1290 461 2L-310 2L-310 6/16/21 1361 466 2L-310 2L-310 6/17/21 1330 460 2L-310 2L-310 6/18/21 1319 459 2L-310 2L-310 6/19/21 1311 453 2L-310 2L-310 6/20/21 1307 451 2L-310 2L-310 6/21/21 1299 443 2L-310 2L-310 6/22/21 1290 438 2L-310 2L-310 6/23/21 1293 437 2L-310 2L-310 6/24/21 1293 431 2L-310 2L-310 6/25/21 1289 426 2L-310 2L-310 6/26/21 1286 421 2L-310 2L-310 6/27/21 1290 417 2L-310 2L-310 6/28/21 1294 414 2L-310 2L-310 6/29/21 1324 416 2L-310 2L-310 6/30/21 1333 411 2L-310 2L-310 7/1/21 1334 407 2L-310 2L-310 7/2/21 1281 401 2L-310 2L-310 7/3/21 1260 398 2L-310 2L-310 7/4/21 1249 395 2L-310 Annular Communication Surveillance 2L-310 7/5/21 1252 393 2L-310 2L-310 7/6/21 1255 390 2L-310 2L-310 7/7/21 1252 388 2L-310 2L-310 7/8/21 1251 386 2L-310 2L-310 7/9/21 1250 385 2L-310 2L-310 7/10/21 1247 383 2L-310 2L-310 7/11/21 1247 382 2L-310 2L-310 7/12/21 1245 380 2L-310 2L-310 7/13/21 1247 379 2L-310 2L-310 7/14/21 1246 377 2L-310 2L-310 7/15/21 1246 376 2L-310 2L-310 7/16/21 1283 386 2L-310 2L-310 7/17/21 1345 387 2L-310 2L-310 7/18/21 1357 382 2L-310 2L-310 7/19/21 1365 379 2L-310 2L-310 7/20/21 1316 368 2L-310 2L-310 7/21/21 1221 362 2L-310 2L-310 7/22/21 1197 362 2L-310 2L-310 7/23/21 1180 361 2L-310 2L-310 7/24/21 1170 361 2L-310 2L-310 7/25/21 1157 359 2L-310 2L-310 7/26/21 1134 356 2L-310 2L-310 7/27/21 1106 354 2L-310 2L-310 7/28/21 1103 356 2L-310 2L-310 7/29/21 1225 373 2L-310 2L-310 7/30/21 1240 366 2L-310 2L-310 7/31/21 1242 364 2L-310 2L-310 8/1/21 1240 363 2L-310 2L-310 8/2/21 1238 362 2L-310 2L-310 8/3/21 1235 362 2L-310 2L-310 8/4/21 1241 362 2L-310 2L-310 8/5/21 1239 361 2L-310 2L-310 8/6/21 1239 361 2L-310 2L-310 8/7/21 1234 360 2L-310 2L-310 8/8/21 1232 359 2L-310 2L-310 8/9/21 1231 359 2L-310 2L-310 8/10/21 1231 360 2L-310 2L-310 8/11/21 1234 360 2L-310 2L-310 8/12/21 1233 361 2L-310 2L-310 8/13/21 1233 361 2L-310 2L-310 8/14/21 1268 369 2L-310 2L-310 8/15/21 1380 376 2L-310 2L-310 8/16/21 1403 378 2L-310 2L-310 8/17/21 1400 379 2L-310 2L-310 8/18/21 1353 374 2L-310 2L-310 8/19/21 1339 375 2L-310 2L-310 8/20/21 1337 377 2L-310 Annular Communication Surveillance 2L-310 8/21/21 1337 378 2L-310 2L-310 8/22/21 1335 379 2L-310 2L-310 8/23/21 1319 377 2L-310 2L-310 8/24/21 1311 378 2L-310 2L-310 8/25/21 1316 380 Annular Communication Surveillance DATE_INJ WHIP_AVG WHT GAS_INJ_VO L MGI_VO L PWI_VO L SWI_VO L 5/27/21 1799 130 0 0 522 0 5/28/21 1796 130 0 0 519 0 5/29/21 1794 131 0 0 517 0 5/30/21 1792 131 0 0 518 0 5/31/21 1791 131 0 0 516 0 6/1/21 1789 130 0 0 520 0 6/2/21 1788 129 0 0 507 0 6/3/21 1785 130 0 0 505 0 6/4/21 1783 130 0 0 501 0 6/5/21 1779 129 0 0 465 0 6/6/21 1777 129 0 0 461 0 6/7/21 1775 129 0 0 477 0 6/8/21 1775 129 0 0 478 0 6/9/21 1774 131 0 0 470 0 6/10/21 1772 132 0 0 459 0 6/11/21 1771 132 0 0 454 0 6/12/21 1767 129 0 0 452 0 6/13/21 1765 129 0 0 449 0 6/14/21 1793 129 0 0 961 0 6/15/21 1846 132 0 0 1357 0 6/16/21 1822 131 0 0 839 0 6/17/21 1819 131 0 0 789 0 6/18/21 1819 130 0 0 757 0 6/19/21 1820 129 0 0 738 0 6/20/21 1814 129 0 0 645 0 6/21/21 1808 129 0 0 592 0 6/22/21 1805 131 0 0 587 0 6/23/21 1802 131 0 0 582 0 6/24/21 1799 130 0 0 573 0 6/25/21 1797 129 0 0 566 0 6/26/21 1795 131 0 0 560 0 6/27/21 1792 133 0 0 542 0 6/28/21 1827 130 0 0 1047 0 6/29/21 1848 129 0 0 1084 0 6/30/21 1852 130 0 0 944 0 7/1/21 1817 127 0 0 452 0 7/2/21 1802 127 0 0 385 0 7/3/21 1791 127 0 0 350 0 7/4/21 1785 131 0 0 349 0 Annular Communication Surveillance 7/5/21 1778 131 0 0 351 0 7/6/21 1772 130 0 0 351 0 7/7/21 1766 130 0 0 347 0 7/8/21 1761 130 0 0 349 0 7/9/21 1757 129 0 0 346 0 7/10/21 1753 129 0 0 349 0 7/11/21 1748 128 0 0 349 0 7/12/21 1745 130 0 0 340 0 7/13/21 1741 129 0 0 345 0 7/14/21 1739 129 0 0 350 0 7/15/21 1765 128 0 0 897 0 7/16/21 1819 129 0 0 1344 0 7/17/21 1842 130 0 0 1308 0 7/18/21 1861 131 0 0 1305 0 7/19/21 1839 129 0 0 674 0 7/20/21 1783 128 0 0 161 0 7/21/21 1760 127 0 0 33 0 7/22/21 1742 0 0 0 0 7/23/21 1728 0 0 0 0 7/24/21 1714 0 0 0 0 7/25/21 1704 0 0 0 0 7/26/21 1691 0 0 0 0 7/27/21 1682 105 0 0 52 0 7/28/21 1691 130 0 0 394 0 7/29/21 1693 130 0 0 362 0 7/30/21 1692 131 0 0 329 0 7/31/21 1690 130 0 0 319 0 8/1/21 1687 130 0 0 305 0 8/2/21 1684 130 0 0 299 0 8/3/21 1684 129 0 0 319 0 8/4/21 1682 129 0 0 318 0 8/5/21 1680 128 0 0 312 0 8/6/21 1679 127 0 0 309 0 8/7/21 1677 127 0 0 298 0 8/8/21 1674 127 0 0 294 0 8/9/21 1672 127 0 0 302 0 8/10/21 1671 127 0 0 314 0 8/11/21 1670 126 0 0 313 0 8/12/21 1668 126 0 0 310 0 8/13/21 1691 129 0 0 730 0 8/14/21 1782 132 0 0 1597 0 8/15/21 1833 132 0 0 1677 0 8/16/21 1845 132 0 0 1433 0 8/17/21 1806 130 0 0 827 0 8/18/21 1801 130 0 0 814 0 8/19/21 1800 130 0 0 797 0 8/20/21 1801 131 0 0 790 0 Annular Communication Surveillance 8/21/21 1802 130 0 0 765 0 8/22/21 1794 130 0 0 627 0 8/23/21 1787 130 0 0 602 0 8/24/21 1787 130 0 0 642 0 Annular Communication Surveillance WELL_NAME DATE_PROD FTP_AVG WHT OIL_VOL+W ATER_VOL Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 10,104.0 11/18/2019 2L-310 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SET PATCH 4/14/2020 2L-310 condijw Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 112.0 Set Depth (TVD) … 112.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 27.6 Set Depth (ftKB) 3,521.0 Set Depth (TVD) … 2,416.7 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 25.6 Set Depth (ftKB) 10,247.0 Set Depth (TVD) … 5,615.2 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-m Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 23.3 Set Depth (ft… 9,800.0 Set Depth (TVD) (… 5,283.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.3 23.3 0.00 HANGER FMC GEN V TUBING HANGER 2.992 516.4 515.9 4.54 NIPPLE CAMCO DS NIPPLE w/2.875" PROFILE 2.875 9,671.2 5,194.0 48.89 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.812 'D' PROFILE 2.812 9,723.8 5,229.4 46.52 PBR BAKER 80-40 PBR 2.990 9,737.2 5,238.6 46.02 PACKER BAKER FHL PACKER 2.990 9,790.3 5,276.2 44.03 NIPPLE CAMCO 'D' NIPPLE w/ 2.75" NO GO 2.750 9,799.5 5,282.8 43.69 WLEG WIRELINE ENTRY GUIDE 2.920 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 3,653.0 2,476.8 63.09 PATCH - UPR PKR (ME) 2.72" P2P SPACER & ANCHOR LATCH, OAL 25.09' / SN: CPP35228 / CPAL35147) 4/14/2020 1.620 3,657.0 2,478.6 63.14 SPACER 2-1/16" SPACER & ANCHOR LATCH @ 3653' RKB (ME) (OAL 25.09' / SN: CPP35228 / CPAL35147), MITT 3000 PASS. COMPLETE. 4/14/2020 1.620 3,675.0 2,486.7 63.40 SPACER 2.70" PBR, 2-1/16" SPACER PIPE, ANCHOR LATCH, OAL 31.62' / SN: CPPBR35026 / CPAL35118 4/14/2020 1.620 3,708.0 2,501.4 63.87 PATCH - LWR PKR (ME) 2.72" P2P, OAL 4.01' , SN:CPP35254 4/13/2020 1.620 6,938.0 3,929.7 62.90 PATCH 2.72" SOS UPPER PARAGON II PACKER (ser# cpp 35040) W/ 15.49' SPACER PIPE & LATCH ASSEMBLY (ser# cpal 35018) 1/15/2016 1.625 6,953.0 3,936.6 62.92 PATCH 2.72" SOS LOWER PARAGON II PACKER (ser# cpp35043) 1/15/2016 1.625 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 10,005.0 10,019.0 5,434.5 5,444.9 Bermuda, 2L- 310 6/8/2010 6.0 IPERF 2.5" Prospector RDX DP charges, 60 deg phase Frac Summary Start Date 6/10/2010 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 6/10/2010 Top Depth (ftKB) 10,005.0 Btm (ftKB) 10,019.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 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 3,697.2 2,496.6 Camco KBG-2- 9 1 GAS LIFT DMY INT 0.000 4/12/2020 2 8,716.8 4,728.9 Camco KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2010 5:00 3 9,617.2 5,159.3 Camco KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2013 1:00 Notes: General & Safety End Date Annotation 5/15/2014 NOTE: WAIVERED FOR WAG INJ WITH T x IA ON MI. 5/16/2013 NOTE: CONVERTED TO INJECTION (PRE-PRODUCED 3 YEARS) 5/18/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 HORIZONTAL, 2L-310, 4/15/2020 6:01:26 AM Vertical schematic (actual) PRODUCTION; 25.6-10,247.0 IPERF; 10,005.0-10,019.0 FRAC; 10,005.0 PACKER; 9,737.2 GAS LIFT; 9,617.2 GAS LIFT; 8,716.8 PATCH; 6,953.0 PATCH; 6,938.0 PATCH - LWR PKR (ME); 3,708.0 GAS LIFT; 3,697.2 SPACER; 3,675.0 SPACER; 3,657.0 PATCH - UPR PKR (ME); 3,653.0 SURFACE; 27.6-3,521.0 NIPPLE; 516.4 CONDUCTOR; 28.0-112.0 KUP INJ KB-Grd (ft) 33.20 Rig Release Date 5/13/2010 2L-310 ... TD Act Btm (ftKB) 10,252.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032061600 Wellbore Status INJ Max Angle & MD Incl (°) 67.51 MD (ftKB) 2,780.72 WELLNAME WELLBORE2L-310 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:DATE: Wednesday, August 12, 2020 Jim Regg C� P.1. Supervisor<Z I �7i�JL J SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2L-310 FROM: Lou L.aubensteln KUPARUK RIV U TARN 2L-310 Petroleum Inspector Src: Inspector Reviewed Bv: P. 1. SuprvI� NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 2L-310 API Well Number 50-103-20616-00-00 Inspector Name: Lou Laubenstein Permit Number: 210-028-0 Inspection Date: 8/3/2020 Insp Num: niitLOL200804104605 Rel Insp Num: Notes: MIT -IA to maximum anticipated injection pressure per A10 16.004 Amended ✓ Initial 15 Min 30 Min 45 Min 60 Min 3320 3320 - 3320 - 4000 3950 3940 565 ' 565- 565 Wednesday, August 12, 2020 Page 1 of I Packer Depth Pretest Well 2L-310 'Type Inj a -TVD 5238 Tubing 3320 PTD 2100280 Type Test SPT Test psi 3700 IA 2130 BBL Pumped: 33 BBL Returned — QA 561 ' Interval RL.3 P/F P Notes: MIT -IA to maximum anticipated injection pressure per A10 16.004 Amended ✓ Initial 15 Min 30 Min 45 Min 60 Min 3320 3320 - 3320 - 4000 3950 3940 565 ' 565- 565 Wednesday, August 12, 2020 Page 1 of I Originated:Delivered to:19-Aug-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Sari 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 Leak Detect Log 2 Plug Setting Record 3 2L-310 50-103-20616-00 906449149 Tarn Packer Setting Record Field-Final 13-Apr-20 0 1 4 2T-37 50-103-20227-00 906480199 Kuparuk Plug Setting Record Field-Final 30-Apr-20 0 1 5 3A-08 50-029-21445-00 906499970 Kuparuk Plug Setting Record Field-Final 17-May-20 0 1 6 Multi Finger Caliper Field-Processed 26-May-20 7 Packer Setting Record Field-Final 27-May-20 8 3H-14B 50-103-20092-02 906486722 Kuparuk Packer Setting Record Field-Final 7-May-20 0 1 9 3K-03 50-029-21602-00 906531280 Kuparuk Plug Setting Record Field-Final 29-May-20 0 1 10 3A-08 50-029-21445-00 906499689 Kuparuk Multi Finger Caliper Field-Processed 16-May-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: 1 3H-03 50-103-20085-00 n/a Kuparuk 0 1 Transmittal Date: 2H-09 50-103-20050-00 906426492 Kuparuk Field-Final 5-Apr-20 0 08/26/2020 Abby Bell Received by the AOGCC 08/26/2020 PTD: 2100280 E-Set: 33688 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophill ips.com> Sent: Monday, July 27, 2020 9:20 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: KRU 2L 310 (PTD 210 028) Update 27 July 2020 Attachments: 2L-310 90 Day TIO plot.pdf Chris, KRU 2L-310 (PTD# 210-028) has completed the 30 day monitor period of MI injection. The IA continued to show signs of TxIA communication while on gas injection however the IA was able to operate under the conditions of less than 2 non -thermal related bleeds within the month to remain below the gas injection IA "do not exceed" pressure of 2400 psi. Therefore, CPAI intends to leave 2L-310 operating under AID 16.004 as a WAG injector with known TxIA communication while on gas injection. Attached is the current 90 day TIO plot for your review. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 wl=LI?AM CbnocoPhEps From: Wetegrity Compliance Specialist CPF1 & 2 Sent: Saturday, ay 16, 2020 6:08 AM To: Wallace, Chris D D) <chris.wallace @alaska.gov> Cc: CPA Wells Supt <n10 conocophillips.com> Subject: KRU 2L-301 (PTD 21 8) Update 5/16/20 Chris, KRU 2L-310 (PTD 210-028) governed under AI 6.004 has completed the 30 day monitor period on water injection and no signs of annular communication were observe The previous plan was to then WAG the well to gas for a 30 day gas injection monitor period, but due to gas limitations du ' g the upcoming Curtailment the gas injection monitor period will be delayed. The plan is to leave the well on water inje 'on for the interim. The gas injection monitor period will be performed once capacity has returned. A 90 day TIO trend anbwellbore schematic are attached. Please let us know if you have any questions or disagree with this plan Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Saturday, May 16, 2020 6:08 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 2L-301 (PTD 210-028) Update S/16/20 Attachments: 2L-310.pdf, 2L-310 90 day TIO trend S.16.20.pdf Chris, KRU 21--310 (PTD 210-028) governed under AIO 16.004 has completed the 30 day monitor period on water injection and no signs of annular communication were observed. The previous plan was to then WAG the well to gas for a 30 day gas injection monitor period, but due to gas limitations during the upcoming Curtailment the gas injection monitor period will be delayed. The plan is to leave the well on water injection for the interim. The gas injection monitor period will be performed once capacity has returned. A 90 day TIO trend and wellbore schematic are attached. Please let us know if you have any questions or disagree with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 .01WELLS TEAM can C';1P +NP% MEMORANDUM State of Alaska Depth Pretest Alaska Oil and Cas Conservation Commission TO: Jim Regg DATE: Monday, May 4, 2020 P.I. Supervisor I\ A Sl %rel,?Z SUBJECT: Mechanical Integrity Tests l ConocoPhillips Alaska, Inc. 1350 1350 2!.310 FROM: Brian Bixby KUPARUK RIV U TARN 2L310 Petroleum Inspector Test psi Src: Inspector Reviewed Bye�� P.I.Supry Jt.�r`-- NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 21-310 API Well Number 50-103-20616-00.00 Inspector Name: Brian Bixby Permit Number: 210-028-0 Inspection Date: 4/26/2020 - IBSp Num: mi[8DB200426122557 Rel Insp Num: Monday, May 4, 2020 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2,-310 Type Inj w TVD 5238 ]Tubing r50 1350- 1350 1350 PTD 2100280 Type Test I SPT Test psi 3500 IA 670 3850 3760 3740 BBL Pumped: 4.8 BBL Returned: 4.5 - OA 540 547 547 146 Interval OTHER - P/F r P Notes: MIT -IA was done per SUNDRY #320.141 post tubing patch and also to MAID per AIO 16.004.` Monday, May 4, 2020 Page I of I 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured feet feet true vertical feet feet Effective Depth measured feet feet true vertical feet feet Perforation depth Measured depth feet True Vertical depth feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: 2. Operator Name: Senior Pet. Engineer: Senior Res. Engineer: CollapseBurstTVDLengthCasing Authorized Signature with date: Authorized Name: 5. Permit to Drill Number: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf measuredPlugs Junk measured STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl measured true vertical Packer WINJ WAG Water-Bbl MD 15. Well Class after work: Exploratory Development Service Stratigraphic 16. Well Status after work: Oil Gas W DSPL a GSTOR GINJ SUSP SPLUG 5.070, 25.071, & 25.283) J G Plug Perforations Fracture Stimulate Pull TubingOperations shutdown Perforate Other Stimulate Alter Casing Change Approved Program Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory StratigraphicService 6. API Number: mber): 8. Well Name and Number: onic data per 20AAC25.071): 10. Field/Pool(s): ry: ured feet feet ticalfeet feet ured feet feet ticalfeet feet epth feet epth feet true vertical depth) d and true vertical depth) summary: lumes used and final pressure: tion: ion: CollapseBurstTVD 5. Permit to Drill Number: Size Gas-Mcf g Ju easu ed 4. W ell Class Before W ork: Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureOil-Bbl ue e ca W ater-Bbl MD Form 10-404 Revised 3/2020 Submit Within 30 days of Operations ConocoPhillips Alaska, Inc. P.O. Box 100360, Anchorage 99540 210-028-0 50103206160000 ADL0380052, ADL0381051 KRU 2L-310 N/A Kuparuk River Field/Tarn Oil Pool 10252 5619 N/A N/A 10104 5588 9739 5239 Conductor 84'16"112' 112' Surface 3493'10-3/4"3521'2417' Production 10221'7-5/8"10,247'5615' 10005'-10019' 5435'-5445' 3.5"L-80 9800'5283 Baker FHL 9737' MD 5239'TVD No SSSV N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A N/A 320-141 Dusty Freeborn Well Integrity and Compliance Specialist Dusty Freeborn/Jan Byrne N1617@conocophillips.com 907-830-9777 Set tubing patch✔✔ ✔ ✔✔ ✔ Dusty Freeborn Digitally signed by Dusty Freeborn Date: 2020.04.27 12:19:06 -08'00' By Samantha Carlisle at 12:40 pm, Apr 27, 2020 DSR-4/27/2020 RBDMS HEW 4/27/2020 VTL 4/28/20 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 27, 2020 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch set across a known tubing leak in KRU 2L-310 (PTD 210-028-0). Please contact Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Dusty Freeborn Digitally signed by Dusty Freeborn Date: 2020.04.27 12:18:10 -08'00' Date Event Summary Executive Summary 2nd tubing patch set from 3675'-3708' over tubing leak. 04/26/20 (SW) STATE WITNESSED (BRIAN BIXBY) MIT-IA POST PATCH TO 3850 PSI (PASSED) 04/14/20 SET 2.70" PBR SPACER & ANCHOR LATCH @ 3675' RKB (OAL 31.62' / SN: CPPBR35026 / CPAL35118), RAN 3 1/2 SLIM TTS TEST TOOL MIT TBG 3000 PSI PASS PULLED PBR SPACER & ANCHOR LATCH FREE W/ TEST TOOL (SEALS DAMAGED ON TEST TOOL ANCHOR SHEARED), SET SAME 2.70" PBR SPACER ANCHOR ASSEMBLY PINED HEAVER @ SAME, MITT 3000 PASS, SET UPPER 2.72" P2P SPACER & ANCHOR LATCH @ 3653' RKB (ME) (OAL 25.09' / SN: CPP35228 / CPAL35147), MITT 3000 PASS. COMPLETE. 04/13/20 LOAD IA W/ 45 BBLS INHIBITED SEAWATER & 88 BBLS DIESEL, DEPLOY 3 1/2 AVA CATCHER, SET 1" BTM LATCH DV @ 3697' RKB, MITIA 3000 PSI PASS, BRUSH n' FLUSH TBG FROM 3700' TO 3600' SLM, SET LOWER 2.72" P2P @ 3708' RKB (ME) (OAL 4.01' / SN:CPP35254), MIT LOWER P2P @ 3708' RKB PASS 01/20/20 Performed HES DTS/DAS FiberLog from surface to 9900'MD. Surveyed well pumping N2 to displace wellbore fluids to formation then initiated log bleeding IA to zero. Shut in IA and pumped N2 2500- scfm at 3000-psi; plan was to build 250-psi on IA to match flowline header pressure then take IA returns to flowline, however, IA rose to only 26-psi after an hour pumping N2 2500-scfm, 3000-psi. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 10,104.0 11/18/2019 2L-310 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SET PATCH 4/14/2020 2L-310 condijw Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 112.0 Set Depth (TVD) … 112.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 27.6 Set Depth (ftKB) 3,521.0 Set Depth (TVD) … 2,416.7 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 25.6 Set Depth (ftKB) 10,247.0 Set Depth (TVD) … 5,615.2 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-m Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 23.3 Set Depth (ft… 9,800.0 Set Depth (TVD) (… 5,283.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.3 23.3 0.00 HANGER FMC GEN V TUBING HANGER 2.992 516.4 515.9 4.54 NIPPLE CAMCO DS NIPPLE w/2.875" PROFILE 2.875 9,671.2 5,194.0 48.89 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.812 'D' PROFILE 2.812 9,723.8 5,229.4 46.52 PBR BAKER 80-40 PBR 2.990 9,737.2 5,238.6 46.02 PACKER BAKER FHL PACKER 2.990 9,790.3 5,276.2 44.03 NIPPLE CAMCO 'D' NIPPLE w/ 2.75" NO GO 2.750 9,799.5 5,282.8 43.69 WLEG WIRELINE ENTRY GUIDE 2.920 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 3,653.0 2,476.8 63.09 PATCH - UPR PKR (ME) 2.72" P2P SPACER & ANCHOR LATCH, OAL 25.09' / SN: CPP35228 / CPAL35147) 4/14/2020 1.620 3,657.0 2,478.6 63.14 SPACER 2-1/16" SPACER & ANCHOR LATCH @ 3653' RKB (ME) (OAL 25.09' / SN: CPP35228 / CPAL35147), MITT 3000 PASS. COMPLETE. 4/14/2020 1.620 3,675.0 2,486.7 63.40 SPACER 2.70" PBR, 2-1/16" SPACER PIPE, ANCHOR LATCH, OAL 31.62' / SN: CPPBR35026 / CPAL35118 4/14/2020 1.620 3,708.0 2,501.4 63.87 PATCH - LWR PKR (ME) 2.72" P2P, OAL 4.01' , SN:CPP35254 4/13/2020 1.620 6,938.0 3,929.7 62.90 PATCH 2.72" SOS UPPER PARAGON II PACKER (ser# cpp 35040) W/ 15.49' SPACER PIPE & LATCH ASSEMBLY (ser# cpal 35018) 1/15/2016 1.625 6,953.0 3,936.6 62.92 PATCH 2.72" SOS LOWER PARAGON II PACKER (ser# cpp35043) 1/15/2016 1.625 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 10,005.0 10,019.0 5,434.5 5,444.9 Bermuda, 2L- 310 6/8/2010 6.0 IPERF 2.5" Prospector RDX DP charges, 60 deg phase Frac Summary Start Date 6/10/2010 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 6/10/2010 Top Depth (ftKB) 10,005.0 Btm (ftKB) 10,019.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 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 3,697.2 2,496.6 Camco KBG-2- 9 1 GAS LIFT DMY INT 0.000 4/12/2020 2 8,716.8 4,728.9 Camco KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2010 5:00 3 9,617.2 5,159.3 Camco KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2013 1:00 Notes: General & Safety End Date Annotation 5/15/2014 NOTE: WAIVERED FOR WAG INJ WITH T x IA ON MI. 5/16/2013 NOTE: CONVERTED TO INJECTION (PRE-PRODUCED 3 YEARS) 5/18/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 HORIZONTAL, 2L-310, 4/15/2020 6:01:26 AM Vertical schematic (actual) PRODUCTION; 25.6-10,247.0 IPERF; 10,005.0-10,019.0 FRAC; 10,005.0 PACKER; 9,737.2 GAS LIFT; 9,617.2 GAS LIFT; 8,716.8 PATCH; 6,953.0 PATCH; 6,938.0 PATCH - LWR PKR (ME); 3,708.0 GAS LIFT; 3,697.2 SPACER; 3,675.0 SPACER; 3,657.0 PATCH - UPR PKR (ME); 3,653.0 SURFACE; 27.6-3,521.0 NIPPLE; 516.4 CONDUCTOR; 28.0-112.0 KUP INJ KB-Grd (ft) 33.20 Rig Release Date 5/13/2010 2L-310 ... TD Act Btm (ftKB) 10,252.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032061600 Wellbore Status INJ Max Angle & MD Incl (°) 67.51 MD (ftKB) 2,780.72 WELLNAME WELLBORE2L-310 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 29, 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 2L-310 (PTD 210-028) to install a tubing patch over a tubing leak. Please contact Dusty Freeborn or me at 659-7224 if you have any questions. Sincerely, Jan Byrne Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. By Samantha Carlisle at 10:40 am, Mar 30, 2020 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): Casing Collapse Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: Perforation Depth MD (ft): TVD BurstMDLength Size Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft): approval: Notify Commission so that a representative may witness Sundry Number: BOP Test Mechanical Integrity Test Location Clearance ection MIT Req'd? Yes No ption Required? Yes No Subsequent Form Required: COMMISSION USE ONLY Contact Name: Contact Email: Contact Phone: Date: e: certify that the foregoing is true and the procedure approved herein will not rom without prior written approval. gnature: me: Date for 15.W ell Status after proposed work: Operations:OIL WINJ WDSPL Suspended proval:Date:GAS WAG GSTOR SPLUG Representative:GINJ Op Shutdown Abandoned nts: Proposal Summary Wellbore schematic13.W ell Class after proposed work: ations Program BOP Sketch Exploratory Stratigraphic Development Servic e SSSV Type:Packers and SSSV MD (ft) and TVD (ft): pth MD (ft):Perforation Depth TVD (ft):Tubing Size:Tubing Grade: Tubing MD (ft): g CollapseTVD BurstMDLength Size D (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): PRESENT WELL CONDITION SUMMARY quest: Abandon Plug Perforations Fracture Stimulate Reppair Well Operations shutdown Suspend Perforate Other Stimulate Pulll Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp W ell Alter Cas Other: ___er Casing ________________ __ ame:4.Current Well Class:5.Perm it to Drill Number: Exploratory Development Stratigraphic Service 6.API Num ber: g:8. Well Name and Number: ation or Conservation Order governs well spac ing in this pool? perforations require a spacing exception?Yes No esignation (Lease Number):10.Field/Pool(s): Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. ConocoPhillips Alaska, Inc. P. O. Box 100360, Anchorage 99510 210-028-0 501032061600 N/A KRU 2L-310 ADL0380052 ADL0381051 Kuparuk River Field / Tarn Oil Pool 10252 5619' Conductor 84' 16" 112' 112' Surface 3493' 10-3/4" 3521' 2417' Production 10221' 7-5/8" 10,247' 5615 10005' - 10019'5435' - 5445' 3.5"L-80 9800' BAKER FHL PACKER, NO SSSV- Shallow nipple MD= 9739' TVD= 5239' MD=516' TVD=516' 04/10/2020 Jan Byrne Well Integrity Compliance Specialist Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: Working remotely from home Date: 2020-03-29 18:55:15 Foxit PhantomPDF Version: 9.7.0 jan.byrne@conoco phillips.com 3/29/2020 Jan Byrne N1617@conocophillips.com 907-659-7224 ✔Tubing Patch ✔ ✔ ✔ ✔ ✔ 320-141320-141 X 10-404 VTL 3/31/20 00 DLB DLB 03/31/20 X DSR-3/31/2020 X GWVComm. Required? Yes No X 4/1/2020 JLC 4/1/2020 General Well Work Request Form GWWRv3.3b 11/30/17 KLM 1 Well: 2L-310 Date of Request:3/28/2020 Request SPOC:CPF2 PE David/Stephanie x7519, pgr 252 Well Type:Injector Req. Written by:Jan Byrne, 659-7224 Job Scope: Shut-In Reason Code:270 Tubing / Casing / Packer Leaks Well Shut in Date (if SI): Prioritization Category:Opportunity/Rate Adding Budget Category: Network: Job / SAP Comment:2L-310 Diagnostic and Repair Well Work is not justified via increased production Preventive Maintenance Program Request Injection Well Data Surrounding Producer Data Current Injection Rate (RVBPD) 0 Total Offset (AOF) Oil Rate (BOPD) Expected Post Job Rate (RVBPD) 0 Total Offset (AOF) Gas Rate (MSCFD) Enter Benefit Correction-cell L18)Offset WC Need Offset-->Total Offset (AOF) Water Rate (BWPD) IGOR for CPF (SCF/STB) 26000 Rate Prediction Engr./Source Gross Oil Benefit (BOPD) Enter Rates NOB (BOPD) Enter Rates Success Probability If job fails, expected rate Zero Est. Duration of Job (SI Days) Risked NOB (BOPD) Enter Rates Est. Number of Equipment Days Risked NOB/Equip. Day Enter Equipment Days Last SBHP 3514 psi Last Tag 10,042'md H2S (PPM): SBHP Date 6/22/2015 Tag Date 11/15/2015 Any Fluid Restriction on Well? SBHP Datum (TVD/SS?)5127 SS Max Inclin.68°Max Dogleg 10° / 100' md Min. I.D (at/above work)1.625''Max Incl. Depth 2,781'md Max Dogleg Depth 1,554'md Ann Comm Kuparuk Base Expense Well Work Justification & Objectives (and date required if appropriate): 2L-310 is waivered to allow for WAG injection due with TxIA communication on gas. The well exceeded the waiver's maximum number of bleeds allowed within a month to maintain the IA pressure below DNE and was reported to the AOGCC on 10/21/19 and shut in. A DAS/DTS log was run and reported a gas leak at 3678'. The leak depth reported is just above a GLM and in blank pipe tubing so the patch is requested to cover both the tubing joint collar above the leak depth and the GLM to eliminate potential sources. Risk/Job Concerns: •Approved 10-403 from AOGCC required prior to setting patch. •TxIA communication on gas •DAS/DTS reported a tubing gas leak at 3678' •Tubing patch at 6938' to 6953' (Min ID 1.625) •Well injection rates; ~2.7 MSCF/day at ~3000 psi Relay or Slickline/Eline 1. Load tubing with 240 bbls of seawater followed by 20 bbls diesel to fully fluid pack tubing and freeze protect. 2. RIH to brush and flush patch set area around 3678'. Pump 20 bbls diesel post brush to eliminate debris. 3. RIH to drift with dummy patch 2.72" OD, ~56' OAL (run in 3 sections ~4', 26' & 26'). 4. RIH to set lower 2.72" P2P mid element at 3708' (middle of 7.8' pup below GLM). 5. RIH with test tool to sting into P2P and perform MITT to 3000 psi. 6. RIH with PBR, spacer pipe, and anchor latch to sting into lower P2P. 7. RIH with test tool to sting into PBR and perform MITT to 3000 psi. 8. RIH with upper P2P, spacer pipe, and anchor latch to sting into PBR. - Patch should be 55' from element to element placing the upper P2P mid element at 3653'. 9. RIH with test tool to sting into upper P2P. 10. Perform MITT to 3000 psi. 11. Perform MITIA to 3000 psi. Record TIOs. 10. RDMO, turn well over to Operations. DHD 1. SW MITIA once well is BOI and stabilized. 2L-310 Tubing patch 3.28.20 JFB.xlsm Printed 3/29/2020 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 10,104.0 11/18/2019 2L-310 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Updated Tag Depth & Replaced DV 11/19/2019 2L-310 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 112.0 Set Depth (TVD) … 112.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 27.6 Set Depth (ftKB) 3,521.0 Set Depth (TVD) … 2,416.7 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 25.6 Set Depth (ftKB) 10,247.0 Set Depth (TVD) … 5,615.2 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-m Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 23.3 Set Depth (ft… 9,800.0 Set Depth (TVD) (… 5,283.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8rdABMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.3 23.3 0.00 HANGER FMC GEN V TUBING HANGER 2.992 516.4 515.9 4.54 NIPPLE CAMCO DS NIPPLE w/2.875" PROFILE 2.875 9,671.2 5,194.0 48.89 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.812 'D' PROFILE 2.812 9,723.8 5,229.4 46.52 PBR BAKER 80-40 PBR 2.990 9,737.2 5,238.6 46.02 PACKER BAKER FHL PACKER 2.990 9,790.3 5,276.2 44.03 NIPPLE CAMCO 'D' NIPPLE w/ 2.75" NO GO 2.750 9,799.5 5,282.8 43.69 WLEG WIRELINE ENTRY GUIDE 2.920 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 6,938.0 3,929.7 62.90 PATCH 2.72" SOS UPPER PARAGON II PACKER (ser# cpp 35040) W/ 15.49' SPACER PIPE & LATCH ASSEMBLY (ser# cpal 35018) 1/15/2016 1.625 6,953.0 3,936.6 62.92 PATCH 2.72" SOS LOWER PARAGON II PACKER (ser# cpp35043) 1/15/2016 1.625 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 10,005.0 10,019.0 5,434.5 5,444.9 Bermuda, 2L- 310 6/8/2010 6.0 IPERF 2.5" Prospector RDX DP charges, 60 deg phase Frac Summary Start Date 6/10/2010 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 6/10/2010 Top Depth (ftKB) 10,005.0 Btm (ftKB) 10,019.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) 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 3,697.2 2,496.6 Camco KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 11/19/2019 9:30 2 8,716.8 4,728.9 Camco KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2010 5:00 3 9,617.2 5,159.3 Camco KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2013 1:00 Notes: General & Safety End Date Annotation 5/18/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 5/16/2013 NOTE: CONVERTED TO INJECTION (PRE-PRODUCED 3 YEARS) 5/15/2014 NOTE: WAIVERED FOR WAG INJ WITH T x IA ON MI. HORIZONTAL, 2L-310, 11/19/2019 5:46:33 PM Vertical schematic (actual) PRODUCTION; 25.6-10,247.0 FRAC; 10,005.0 IPERF; 10,005.0-10,019.0 WLEG; 9,799.5 NIPPLE; 9,790.3 PACKER; 9,737.2 PBR; 9,723.8 SLEEVE-C; 9,671.2 GAS LIFT; 9,617.2 GAS LIFT; 8,716.8 PATCH; 6,953.0 PATCH; 6,938.0 GAS LIFT; 3,697.2 SURFACE; 27.6-3,521.0 NIPPLE; 516.4 CONDUCTOR; 28.0-112.0 HANGER; 23.3 KUP INJ KB-Grd (ft) 33.20 Rig Release Date 5/13/2010 2L-310 ... TD Act Btm (ftKB) 10,252.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032061600 Wellbore Status INJ Max Angle & MD Incl (°) 67.51 MD (ftKB) 2,780.72 WELLNAME WELLBORE2L-310 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 &2 <nl617@conocophillips.com> Sent: Tuesday, October 22, 2019 6:53 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 2L-310 (PTD 210-028) Report of exceeding IA pressure bleed limit Attachments: 2L-310 90 day TIO trend 10.22.19.pdf, 2L-310.pdf Chris, 2L-310 (PTD 210-028) is waivered per AID 16.004 to allow continued WAG injection with known TxIA communication on gas with a maximum of two non -thermal bleeds per month while injecting gas. The bleed frequency has increased requiring more than the allowed number of bleeds per month. The well will be shut in as soon as possible. The proper paperwork for continued injection or repair will be submitted when a path forward has been determined. Attached is a wellbore schematic and a 90 day TIO plot. Please let us know if you have any questions or disagree with the plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM Canac+oRHaps WELL LOG TRANSMITTAL #905508300 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log with ACX: 2L-310 Run Date: 2/21/2019 21 0028 30 72 7 April 12, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2L-310 Digital Data in LAS format, Digital Log file, and Interpretation Report 1 CD Rom 50-103-20616-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: t/5l V Vm Signed: RECE/VIFD MAY 4 8 ?019 ACGCC • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission �/ DATE: Friday,April 21,2017 TO: Jim Regg �e'G� 5 l!7 P.I.Supervisor j( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2L-310 FROM: Lou Grimaldi KUPARUK RIV U TARN 2L-310 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Well Name KUPARUK RIV U TARN 2L-310 API Well Number 50-103-20616-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG170214122816 Permit Number: 210-028-0 Inspection Date: 2/14/2017 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2L-310 Type Inj W• TVD 5244 Tubing 1800 1800 - 1800 - 1800 PTD I 2100280 - Type Test SPT Test psi 1500 IA 596 3295 3245 - 3231 - BBL Pumped: 4.1 - BBL Returned: 4 - OA 402 . 412 414 414 - Interval Required by Variance P/F Pass ,/ Notes: Test required by A1016.004.All required paperwork supplied on location.Good test. SCANNED AUG 1 5 2U!7 Friday,April 21,2017 Page 1 of 1 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,February 10,2016 TO: Jim Regg � Il i P.I.Supervisor '� _ ( ' I (0 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2L-310 FROM: Lou Grimaldi KUPARUK RIV U TARN 2L-310 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 2L-310 API Well Number 50-103-20616-00-00 Inspector Name: Lou Grimaldi Permit Number: 210-028-0 Inspection Date: 2/4/2016 Insp Num: mitLG160205080559 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well; 2L-310 J}Type Inj w TVD ��5238 Tubing 1570 - 1580 1580 _ 1580 -' PTD 2100280 iType Test SPT Test psi 3300 - IA 750 1 3300 - 3250 - 3235 • Interval REQVAR IP/F P ✓I OA 472 477 477 - 476 - Notes: Test required by A.I.O. 16,004.Tubing has had patch installed as per Sundry 315-739.4.0 bbl's diesel pumped,3.9 returned.Good test.All pertinent documentation provided by Roger Mouser(DHD Lead). Pd-ki(AvUeijs 1) zz Ctr —WCL( QED SEP 212016 Wednesday,February 10,2016 Page 1 of 1 \c z J ZL- 31c� MJ z 1 I,(a A C <Jpi' nit itLG1607-0c c 5'i d waljaloyo oo Lo o LO O (y e- e- . N • • : : .• . co . . \- P 10 0 . •. •. I N • LO • • . - a. L 5C.0- : _ - csi . ( — T • . It) Y1• l•I Y I. 119 , 1• ! •1 I *I 1 •, r I•1 1-44-+-1-4-P I •I - Z h_. a_ O O0 O 0O M � O Li O N N It) CC. a 0 0 1 ISd _ • pr, Z(OO Zo KUP INJ 114--`:'c':. 21--310 ConocoPhillips ifi TN'ell Max Aright hi MD TD • Alaska Inc. �1141150,.AFIIUWI FWd Nunn --- Well 011 status I I YD(DNB) tat 110011W TI c‘......5,..... 501032061E00 1 TARN PARTICIPATING AREA i'i.! -,-!,'i 2,78072 10,252.0 ... (Comma,' I a 0-e IAmol.Von End Data IAO'G,d(10 Rig RalRale.*a .Date MJnlaCnrl A.-enc lna.lr l reg l..rii I SSSV.NIPPLE [Last WO: J 3320 &1212010 t ""'Annotation Depth)111(22)i Dale Am.l.6n ast LNod Sy FnO D02..0Last TagSLM 1011042.0 -3.M 11/16/2015 �IW1oesun.PULLEDPLUGO'I"PATCH pproven LT11P1 1 _. • HAhCETt23T -T-F --17-- Caeilp-`Strinrs -. ...-. .__ I Casing Deso,lpUon DD p.1) 004 Top4908) Se[Depia( ) ant Depth MITA_"WtLOO9:'.0004 Top T5..4 f CONDUCTOR ae 15.062 28 0 112 0 i s 1... 62 on 1.43 WELDED Casing Description '01511,1 loon( Top 0111211) Set D.pth MAD) 1Sol Depth(TVD).IWOLm 0...nada Top TMesd i ,--- SURFACE 10 314 0.650 276 3,521.0 2,415.7 -'•.r c,_71 WIC Lasing Description 00(w) IDOal Top tom) sot Depth( B) (Set MO.(ISO)...'Wnlan 7_ cram -Top Thread PRODUCTION 7 518 6.675 25 6 10247.0; 5,615 2 I:: - ; ETC-in li Tubing Strings I( usinjDencdpYOn 0!dnnMe 10)101 Tap MAN) kµln,D++9' 11 111,15 yr 1 Grub Top caln,�lal n.Iu•-•-••-••a'•.a.,..att ds TUBNG I S 172 2.942 2]�3___ 9,8000 0,7113 7, 11 t-86 EUE8rdABNOD Completion Details Nw4,,)Sl Topt--",.."):1 es) Top(LVD)tt�1 lop Ind CI IM.Pas ¢a} - - 2:1:, 25.3 9.00 ILWSCR FMC GEN V TUBINGHANGER" 2992 5:0000 6169 4.54 tuISPLE CAMCO DB NIPPLE w12875'PROALE 2.876 9,871.2 5,1940 M9 SL6tEVE.t"(TAIIERCMUSI.IDING SLEEVE wf2.812'0'PROFILE 2812 •_!•CONDUCTOR 2a0-I12D .u.�.'-A- -_. .. 9,93 8 5229.4 46 52 154) E)AKEH 80-00 PER 110 9,7372 - 5,238.'.....:0:02 PACKER 8k1LER FFAL PACKER -...--.-'-_ 7.917 9,7903 5.2)63- 41 IS MPPLE 'O'NIPPLE w12.75'N000 2750 NIPHF.saes 9,799.5 6,2826 -.73. 49.5113 *RELINE ENTRY GUIDE 2.920 other In Hole(*refine rti1WS fir where,pumps.fish,etc.) -..._ Top WM Top ma 105(01, VW, Drs Gent fan 110Dale nI 6,938 0 3.626 7 62 9n PAT(, •272-SOS UPP--ER ARP, NII PACKER Ned/cap 1115/2016 1.625 35040)W/15.49'SPACER PPE&LATCH ASSEMBLY(sero m81350181 6.9530 3.936 a 67 82 PATCH .2.72'SOS LOWER PARAGON I PACKER(sero '. I'I 1.825 •cpp35043) Perforations&Slots 1 _. I aha Den { Ti GAS LIFT:1.99T] ... IITop MAP) elm POW) 1r�n BIt R(,'IFW( (st1.11 . Wit I)) Two C, 10,005.0 10,019.0 .i',I L .. n_ 11512017 &0l PERF 25'PtDspoctof RIX DP charges.60 deg phase I Stksl uta tiol1s 8 Tr i.:n trn c'it« w._ PATC699290.-- I Mine, bin Bin, l 0.911 1.p- I ul,,.-'r JI I!•••IILIr1 h00114D51B 4 Mani i=On, 1'.010, II:401 lopr 0.1e 10,005.0 10,019.0 5.434.6 5,444.8 FRAC 6/1012010 Pinped 242,62'Ibs of Carbol!Ie.placing 240,7311m behind pipe(lumped 2,602 bS1e of fkidj.Cornplelao FRAC w/9 ppa on Somatic., Mandrel Inserts _. DA91 N'T,e.T1eal tail 13 61 en Tap(I)4O) Vine Loth J'crt San I IC:,nun ` fiTe2tatta)_ (SNS) Mao Jr:- D lin) 6w. 1 rye 11p. On) law) Run Dine Con 9 7 4 8.6 Caar'ao K8G- 1 GAS L111 LYAY 11.11 mono O0 611212615 930 9 �2 8.718.0 ;726.9 l mlo KEG-2 1 GAS LII I Et.;-, 1441 0.000 00 5x1212010 600 9 GAOL1FT.9611.2 3 9,617.2 5,159.3 Comex 103E-2• 1 GAS 1.11-1 L:tt': I'll 0.000 95 511212013 140 9 Notes:General&Safety - End D-. Annotatin_ ...._.�...._. 511872010 NOTE:VIEW SCHEMATIC w/Aleako ScheaoeIic90 571612013 NOTE:CONVERTED TO INJECTION(PRE-PRODUCED 3"EARS SrlEor.496712 I 5/15120)4 NOTE T x 1A ON Ml.WATER INJECTION ONLY. oat).e.ry a *11111(il' . I ,41PPLE,9.7503 - 1 3 WLFg5.709b -I '1 IPERF 14008916,01911, _I sir OF ALASKA TARNDB 2L-310 ALA OIL AND GAS CONSERVATION COM SION r. REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations 1— Fracture Stimulate r Rill Tubing fl Operations Shutdown ri Performed: Suspend 1 Perforate fl Other Stimulate r Alter Casing r Change Approved Program Rug for Redrill r Perforate New Pool Repair Well Re-enter Susp Well r Other:Tubing patch N" 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 210-028-0 3.Address: 6.API Number: Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 50-103-20616-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380052/381051 V49.t..1 TAQi 2L-3ip 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Tarn Oil Pool4ECEIVED 11.Present Well Condition Summary: FEB 10 2016 Total Depth measured 10252 feet Plugs(measured) None true vertical 5619 feet Junk(measured) None1 Effective Depth measured 10084 feet Packer(measured) 9737 true vertical 5493 feet (true vertical) 5239 Casing Length Size MD ND Burst Collapse CONDUCTOR 84 16 112 112 0 0 SURFACE 3493 10.75 3521 2417 0 0 PRODUCTION 10221 7.625 10247 5615 0 0 0 0 0 0 0 0 0 0 0 Sr '' Perforation depth: Measured depth: 10005-10019 True Vertical Depth: 5435-5445 Tubing(size,grade,MD,and TVD) 3.5", L-80, 9800 MD and 5283 TVD 3.5"SOS Paragon Retriveable Patch Set from 6938-6958 Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 9737 MD and 5239 TVD NIPPLE-CAMCO DS NIPPLE w/2.875"PROFILE @ 516 MD and 516 TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 17.. Exploratory fl Development fl Service 17 Stratigraphic fl Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r' Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG p- GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-739 Contact Brent Rogers/ Kelly Lyons Email N1617@Conocophillips.com Printed Name Brent Rogers Title Problem Well Supervisor Signature � Phone:659-7224 Date 2/8/2016 /54Aig 1r TI., 7-It 2/J G A ?/A RBDMS LA- FEB 1 0 2016 Form 10-404 Revised 5/2015 Submit Original Only r • • ConocoPh i l l i ps Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 February 8, 2016 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. Tarn KRU injector 2L-310 (PTD 210-028, AIO 16.004). The report is for a 20' TTS retrievable tubing patch that was set per Sundry#315-739 to repair a tubing leak above the packer. Please call Kelly Lyons or myself at 659-7224 or Dusty Freeborn/Jan Byrne at 659- 7126 if you have any questions. Sincerely, Brent Rogers Problem Well Supervisor Attachments • • • 2L-310 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/14/16 PULLED 2.75" CA-2 PLUG FROM 9790' RKB. RAN 2.80" CENT,3.5" BLB W/2.5" GAUGE RING.B&F FROM 6850' SLM TO 7000' SLM. RAN 2.74"X 33' PATCH DRIFT DOWN TO 8800' SLM. JOB IN PROGRESS. 01/16/16 SET 2.72" SOS LOWER PARAGON II PACKER (ser#cpp35043) @ 6959' RKB. RAN TTS TEST TOOL TO 6958' RKB.LRS PERFORMED CMIT TO 2500 PSI,PASSED. SET 2.72" SOS UPPER PARAGON II PACKER (ser#cpp 35040)W/ 15.49' SPACER PIPE& LATCH ASSEMBLY(ser#cpal 35018) @ 6938' RKB. MIT-IA TO 3000 PSI,PASSED. WELL READY TO POI. PRE CMIT T/I/0=1050/970/413 INITIAL T/I/0=2500/2505/418 15 MINS T/I/0=2475/2470/418 30 MINS T/I/0=2465/2460/418. PRE MITIA T/I/0=1100/975/414 INITIAL T/I/0=1120/3014/420 15 MINS T/I/0=1120/2973/420 30 MINS T/I/0=1120/2967/420 02/04/16 (WC/SW): MITIA PASSED TO 3300 PSI (LOU GRIMALDI/GUY COOK). Initial T/I/O = 1570/750/472, IA FL @ surface Pressurized IA to 3300 psi with 4 bbls of diesel. T/I/O = 1580/3300/477. 15 min reading: 1580/3250/477. (-50) 30 min reading: 1580/3235/476. (-15). Bled IA down to 685 psi (fluid). Final T/I/O = 1580/685/467. Summary A 20' element to element SOS Paragon retrievable tubing patch was set from 6938'to 6958'. An AOGCC witnessed MITIA passed once the well had been brought back on injection and stabilized. • • 2L-310 - DESCRIPTION OF WORK COMPLETED SUMMARY ,. KUP INJ • 2L-310 - ConoccPhillips l.:.- Well Attributes Max Angle&MD TD Alaska,Inc Wellbore API/UWI Field Name Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB) ac.roaaclps• 501032061600 TARN PARTICIPATING AREA INJ 67.51 2,780.72 10,252.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-2L-310,1/18/20161:05:15 PM SSSV:NIPPLE Last WO: 33.20 5/13/2010 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 10,042.0 11/15/2015 Rev Reason:PULLED PLUG and PATCH pproven 1/18/2016 HANGER;23.3--L.immi:_..I Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I_Grade Top Thread I CONDUCTOR 16 15.062 28.0 112.0 112.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I_Grade Top Thread SURFACE 10 3/4 9.950 27.6 3,521.0 2,416.7 45.50 L-80 BTC I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread � PRODUCTION 75/8 6.875 25.6 10,247.0 5,615.2 29.70 L-80 BTC-m • s' Tubing.Strings I.Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..'Set Depth(TVD)(...Wt(IbHt) Grade Top Connection TUBING 31/2 2.992 23.3 9,800.0 5,283.2 9.30 L-80 EUEBr4ABMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 23.3 23.3 0.00 HANGER FMC GEN V TUBING HANGER 2.992 516.4 515.9 4.54 NIPPLE CAMCO DS NIPPLE w/2.875"PROFILE 2.875 I 9,671.2 5,194.0 48.89 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.812'D'PROFILE 2.812 -AA/CONDUCTOR,28.0-112.0 9,723.8 5,229.4 46.52 PBR BAKER 80-40 PBR 2.990 9,737.2 5,238.6 46.02 PACKER BAKER FHL PACKER 2.990 9,790.3 5,276.2 44.03 NIPPLE CAMCO'D'NIPPLE w/2.75"NO GO 2.750 NIPPLE 516.4 9,799.5 5,282.8 43.69 WLEG WIRELINE ENTRY GUIDE 2.920 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Inc! Top(ftKB) (ftKB) (') Des Com Run Date ID(in) 6,938.0 3,929.7 62.90 PATCH 2.72"SOS UPPER PARAGON II PACKER(sent cpp 1/15/2016 1.625 35040)W/15.49'SPACER PIPE&LATCH ASSEMBLY(ser#cpal 35018) 6,953.0 3,936.6 62.92 PATCH 2.72"SOS LOWER PARAGON II PACKER(ser# 1/15/2016 1.625 cpp35043) SURFACE;27.6-3,521.G- Perforations&Slots a Shot .. Dens Top(TVD) Btm(TVD) (shots/f GAS LIFT,3,697 2 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 10,005.0 10,019.0 5,434.5 5,444.9 Bermuda,2L- 6/8/2010 6.0 (PERF 2.5"Prospector RDX DP 310 charges,60 deg phase Stimulations&Treatments PATCH;6,938.0 i Min Top Max Btm I: Depth Depth Top(TVD) Btm(TVD) PATCH;69530 I (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 10,005.0 10,019.0 5,434.5 5,444.9 FRAC 6/10/2010 Pumped 242,621 lbs of Carbolate,placing 240,731 lbs behind pipe(pumped 2,602 bbls of fluid).Completed FRAC wl9 ppa on formation. it Mandrel Inserts GAS LIFT;6716.6 H St all I on Top(TVG) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 3,697.2 2,496.6 Camco KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 5/12/2010 9:30 9 2 8,716.8 4,728.9 Camco KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 5/12/2010 5:00 9 GAS LIFT.9617zII 3 9,617.2 5,159.3 Camco KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 5/12/2013 -1.00 I9 Notes:General&Safety End Date Annotation 5/18/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 5/16/2013 NOTE:CONVERTED TO INJECTION(PRE-PRODUCED 3 YEARS) SLEEVE-C;9,671.2 I 5/15/2014 NOTE:T x IA ON MI.WATER INJECTION ONLY. PBR;6723.6 PACKER;9,737.2 s-a I I I NIPPLE;9,790.3 I W LEG',9799.5 it (PERF;10,005.0-10,019.0-HO �y FRAC;10,005.0 J PRODUCTION',25.6-10247.0 a -LAO- D2. ' 24,nti WELL LOG TRANSMITTAL#902947777 DATA LOGGED 2/tt/201C0 M. K.BENDER To: Alaska Oil and Gas Conservation Comm. January 21, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JAN 2 6 rLJ RE: Leak Detect Log with ACX: 2L-310 OGCC Run Date: 11/28/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2L-310 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-103-20616-00 Leak Detect Log with ACX (Processed Log) 1 Color Log 50-103-20616-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 SCANNED Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: k✓a�L-14L, / 2VO - 32._`g • • WELL LOG TRANSMITTAL# 7g7A LOGGED l /2.1/2014 K.BENDER To: Alaska Oil and Gas Conservation Comm. December 30, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JAN 0 5 2016 RE: Multi Finger Caliper: 2L-310 AOGCC Run Date: 11/27/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2L-310 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20616-00 same PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 12244 t,, o_goteeet • OF rtt • tet„ /7;-s THE STATE Alaska Oil and Gas pf LAsKAConservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 " '*�''' Main: 907.279.1433 OFALAS�� Fax: 907.276.7542 www.aogcc.alaska.gov 1401 CS.; Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. t — 0a P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU TARN 2L-310 Sundry Number: 315-739 Dear Ms. Lyons: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '. Foerster Chair this I gig- DATED ay of December,2015 Encl. RBDMS(.1/ DEC 212015 li • RECEIVED STATE OF ALASKA DEC 0 9 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION aTS 12116'115 APPLICATION FOR SUNDRY APPROVALS AOGGC 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r Operations Shutdow n r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other:'pa}-cli �- 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. , Exploratory r Development r 210-028-0 - 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 17 501032061600 ` 7.If perforating: N/A 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes r No Pi q )0„" rAtta 2L-310 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 380052/381051• Kuparuk River Field/Tarn Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effc'�"e�De,Rth IID: Effective Depth TY,A_ MPSP(psi): Plugs(MD): Junk(MD): 10,252' 5,619' .. 1`�f c, `1 3'(Q/S t i743 3000 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 16" 112' 112' Surface 3,493' 12" 3,521' 2,417' Intermediate Production 10,221' 8" 10,247' 5,615' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,005'-10,019' - 5,435'-5445' 3.500" L-80 9,800' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER FHL PACKER, NO SSSV-Shallow nipple • MD=9737 TVD=5239, MD=516'TVD=516', 12.Attachments: Proposal Summary El Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory r Stratigraphic r Development r Service 17, 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12/20/2015 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG 17 • GSTOR r SPLUG r Commission Representative: N/A GINJ r Op Shutdown r Abandoned I- 17. 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Kelly Lyons/Brent Rogers Email n1617c cop.com Printed Name Title Ke ly Lyons ' Problem Wells Supervisor Signature Phone 659-7224 Date 12/7/2015 COMMISSION USE ONLY Conditions of approval: - " Commission so that a representative may witness Sundry Number: 3t5-139 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: Staff witvtc55c-Gj Ml-r— /fk ,—cgL,i✓ccl af#t0" staJi'/'3col y`i-r rcl-icM - Wutcr-oily I jcct«^ p=v-- .t/a //o. oa"j- Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: /U — 4 04 APPROVED BY i Approved by: COMMISSIONER THE COMMISSION Date:/2_-I g..../,..s."..`c. Ia. /Z /&//syds 111111f1S 0 t' Ipk[Ailaplid Submit Form and Form 10-403 Revised 11/2015 /'� it for 12 mouVos.froryihQ�4ate of approval. ` D`tSchnt Etn l a2filS • RECEIVED ConocoPhillips DEC 092015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 December 7, 2015 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. Tarn KRU injector 2L-310 (PTD 210-028, AIO 16.004). The request is for approval to patch a tubing leak above the packer with a 20' TTS retrievable patch. Please call Brent Rogers or myself at 659-7224 or Dusty Freeborn/Jan Byrne at 659- 7126 if you have any questions. Sincerely, Kelly Lyons Problem Wells Supervisor Attachments • ConocoPhillips Alaska,Inc. KRU Well 2L-310 (PTD 210-028-0,AIO 16.004) SUNDRY NOTICE 10-403 TUBING REPAIR 12/7/15 On November 10, 2015, the AOGCC was initially notified of suspected TxIA communication while on water injection. The well is already waivered for TxIA communication while on gas injection only. On November 11, 2015, the communication was confirmed with a failed MITIA. Well intervention diagnostics have identified a tubing leak at 6946' RKB, which is approximately 2791' above the packer. The repair plan is to set a retrievable patch over the leak point, conduct an MITIA to verify tubing and patch integrity, and return the well to its normal water-only injection status as per AIO 16.004. REPAIR PLAN 1. Set 20' 3.5"retrievable TTS tubing patch over the leak at 6946' RKB. 2. MIT as per AIO 16.004 to the maximum anticipated injection pressure. 3. Submit 10-404 post-repair. NSK Problem Well Supervisor .. KUP INJ • 2L-310 ConocoPhillips Well Attributes Max Angle&MD TD AkISKO ifl/. Wellbore API/UInc'Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) ,, p mps 5010320616003TARN PARTICIPATING AREA INJ 67.51 2,780.72 10,252.0 -- ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-2L-310.12/2/20153:0855 PM SSSV:NIPPLE Last WO: 33.20 5/13/2010 Vertical schematic(actual) Annotation Depth(ORB) End Date Annotation Last Mod By End Date Last Tag:SLM 10,042.0 11/15/2015 Rev Reason:TAG,PLUG,PULLED CHOKE lehallf 12/2/2015 HANGER;23.3 Imam asing rings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 28.0 112.0 112.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ORB) Set Depth(ftKB) Set Depth(TVD)...Wt/Lan(I...Grade Top Thread SURFACE 10 3/4 9.950 27.. 3,521.0 2,416.7 45.50 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 5/8 6.875 25.: 10,247.0 5,615.2 29.70 L-80 BTC-m al E+ Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) et Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 23.3 9,800.0 5,283.2 9.30 L-80 EUEBrdABMOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 23.3 23.3 0.00 HANGER FMC GEN V TUBING HANGER 2.992 . w)2.875" FILE 2.875 I 1 II III 9,671.2516.4 5,194515.90 48.894.54 SLEEVE-CNIPPLE BAKERCAMCO CMUDS SLIDINGNIPPLE SLEEVEPROw/2 1-12'D'PROFILE 2.812 .A.4%./CONDUCTOR;2e.a-112.0 - 9,723.8 5,229.4 46.52 PBR BAKER 80-40 PBR 2.990 9,737.2 5,238.6 46.02 PACKER BAKER FHL PACKER 2.990 9,790.3 5,276.2 44.03 NIPPLE CAMCO'D'NIPPLE w/2.75"NO GO 2.750 NIPPLE;516.4 = 9,799.5 5,282.8 43.69 WLEG WIRELINE ENTRY GUIDE 2.920 INV Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 9,790.0 5,276.0 44.05 PLUG CA-2 PLUG 11/15/2015 Perforations&Slots Shot Dens Top(TVD) 1 Btm(TVD) (shots/f SURFACE;27.6-3,5210- Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 10,005.0 10,019.0 5,434.5 5,444.9 Bermuda,2L- 6/8/2010 6.0 IPERF 2.5"Prospector RDX DP 310 charges,60 deg phase GAS LIFT;3,697.2 Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVD) Bim(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 10,005.0 10,019.0 5,434.5 5,444.9 FRAC 6/10/2010 Pumped 242,621 lbs of Carbolite,placing 240,7311bs behind pipe(pumped 2,602 bbls of fluid).Completed FRAC w/9 ppa on formation. Mandrel Inserts • GAS LIFT;8,716.8 St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) HUM) Make Model OD(in) Sero Type Type (in) (psi) Run Date Corn 1� 3,697.2 2,496.6 Cameo KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 5/12/2010 9 • 2 8,716.8 4,728.9 Cameo KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 5/12/2010 9 GAS LIFT;9,617.2 3 9,617.2 5,159.3 Camco KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 5/12/2013 9 Notes:General& ty End Date Annotation 5/18/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 I 5/16/2013 NOTE:CONVERTED TO INJECTION(PRE-PRODUCED 3 YEARS) SLEEVE-C;9,671.2 5/15/2014 NOTE:T x IA ON MI.WATER INJECTION ONLY. I PBR;9,723.8 PACKER;9,737.2 NIPPLE,9,780.3 , PLUG;9,790.0 WLEG;9,799.5 II FRAC;10,005.0 ' I IPERF;10 ,005.0-10,019.0 PRODUCTION;25.6-10,247.0 • S Bettis, Patricia K (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Saturday, December 12, 2015 1:39 PM To: Bettis, Patricia K(DOA) Subject: RE: KRU 2L-310: Sundry Application Attachments: 2L-310.pdf Patricia- The effective depth of KRU 2L-310 is 10,247' MD and 5,615'TVD. Attached is the well bore schematic for reference. Cheers, Dusty Freeborn I Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 41WEI ELLS TEAM From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, December 11, 2015 10:30 AM To: NSK Problem Well Supv Subject: [EXTERNAL]KRU 2L-310: Sundry Application Good morning Kelly, What is the current effective depth (MD and TVD)for KRU 2L-310? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 i • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Thursday, November 12, 2015 7:28 PM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; Senden, R.Tyler Subject: RE: Report of worsening TxIA communication Tarn injector 2L-310 (PTD 210-028-0, AIO 16.004) 11-10-15 Chris, As a follow up of the initial diagnostics,the packoff testing all passed however the MITIA failed. Further diagnostics will be performed using Slickline, E-Line or Digital Slickline to identify the source of the MITIA failure. Depending on the options for repair, the appropriate paperwork will be submitted at that time. Please let me know if you disagree or would like further information. Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr. 909 WELLS TEAM Corso PMdpa %AWED MAY 1 2016 From: NSK Problem Well Supv Sent: Tuesday, November 10, 2015 8:09 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report of worsening TxIA communication Tarn injector 2L-310 (PTD 210-028-0, AIO 16.004) 11-10-15 Chris, Tarn injector 2L-310 (PTD 210-028-0 A10 16.004) is a well waivered for TxIA communication on gas only. Last night the IA began to rapidly climb while on water injection. The IA pressure continued to recharge rapidly after a bleed attempt and the well is now suspected of demonstrating worsening TxIA communication, no longer only present on gas injection. The well was shut in and freeze protected shortly after midnight on 11/10/15. Initial diagnostics with DHD are currently scheduled for tomorrow to include MIT/packoff testing/IA drawdown testing while the well is shut in. Follow- up email notification with path forward beyond the initial diagnostics will be provided based on the results of the testing. Please let us know if you disagree. Attached are the schematic and 90 day TIO plot. « File: 2L-310 90 day TIO 11-10-15.JPG » « File: 2L-310 schematic.pdf>> Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907) 659-7000 pgr 909 1 Well Name 2L-310 Notes: Start Date 8/1212015 Days 90 End Date 11/10/2015 Annular Communication Surveillance 4000 -- --- — 12( INN P mc• — 12: 2500 OAP 4JHT — .12s 2CCC — 12. 25CC — 12: — 12E tr)' 2CCC .. - 12 1500 — 12: — 12: 1000 t y yr — 12' 500 — 12( 0 I I U I I I 11 Aug-15 Aug-15 Aug-15 Sep-15 Sep-15 Sep-15 Oct-15 Oct-15 Oct-15 No.-15 Nov-15 Nov-1E zrx T ,rte: ,0.-c, n. LLl scc ug-1` -uc-1E Ajit-1` Sep-15 Sep-1` Sep-15 Oct-15 Oct-15 Oct-15 Nov-15 Nov-15 Nov-15 Date Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907) 659-7000 pgr 909 2 • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. L Q - Q . S Well History File Identifier Organizing (done) ❑ Two -sided III IIIII III IIl ❑ Rescan Needed 1 1 1111 I RESCAN DIGITAL DATA OVERSIZED (Scannable) C" or Items: ❑ Di ttes, No. ❑ Maps: Greyscale Items: Other, No/Type: CV N©. 1 ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: /0 /s/ 1 1 Project Proofing I I MI BY: Maria l Date: /1/0/ 1 a /s / Scanning Preparation 1 4 - x 30 = + 1 = TOTAL PAGES 1 3 i (Count does not include cover sheet) BY: Date: O /s/ Production Scanning 1 111111 I (III I Stage 1 Page Count from Scanned File: 1, 3 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: Ir<irES NO BY: Date: /i/i /s/ wt I Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. I I II II I II II 11111 ReScanned I I 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked III (I'IIIIII 11111 12/22/2011 Well History File Cover Page.doc STATE OF ALASKA . F,} ALASKA OIL AND GAS CONSERVATION COMMI SION REPORT OF SUNDRY WELL OPERATIONS A0( Cr 1. Operations Performed: Abandon Re air w ell Plug Perforations Perforate Other E , Oil to WAG r p r 9 C conversion Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n [ 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 _ 210 - 028 - 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service [; 50- 103- 20616 -00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380052, 381051 2L - 310 • 9. Logs (List Togs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Kuparuk River Field / Tarn Oil Pool • 11. Present Well Condition Summary: Total Depth measured 10252 • feet Plugs (measured) None true vertical 5619 feet Junk (measured) None Effective Depth measured 10151 feet Packer (measured) 9737 true vertical 5543 feet (true vertical) 5239 Casing Length Size MD TVD Burst Collapse CONDUCTOR 84 16 112 112 0 0 SURFACE 3493 12 3521 2417 0 0 PRODUCTION 10221 7.625 10247 5615 0 0 Perforation depth: Measured depth: 10005' - 10019' SCANNED JU ± 08203 True Vertical Depth: 5435' - 5445' Tubing (size, grade, MD, and TVD) 3.5, L -80, 9800 MD, 5283 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL PACKER @ 9737 MD and 5239 TVD SSSV - Nipple @ 516 MD and 516 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 1119 739 Subsequent to operation 5697 994 2024 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service [j . Stratigraphic r 16. Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG FF - GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313 -098 Contact Bob Christensen /Darrell Humphrey Email N1139(a»conocophillips.com Printed Name Robert z , Chris e,r -en Title NSK Production Engineering Specialist d er � ' 659 7535 Date f 3 Signature I Ari �` 1V VI RBDMS JUN 14 20 6425 ii 3 Submit Ori final OnI Form 10 -404 Revised 12/2012 9 y • 2L -310 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05116 /13ICommence WAG FOR injection 05/13 /13IPULLED 2.75" CA -2 PLUG BODY. COMPLETE 05/12/13 LOAD TBG & IA WITH INHIBITED SEAWATER W/ DIESEL U -TUBE FREEZE PROTECT; SET DV @ 9617' RKB; MIT TBG TO 3000 PSI / MIT IA TO 2500 PSI ( PASSED) PULLED CATCHER ASS'Y & EQUALIZED PLUG @ 9790' RKB. IN PROGRESS 05/11/13 BRUSH'N FLUSHED TBG & TAGGED @ 10,055' SLM ( EST. 61' OF RAT HOLE ); SET 2.75" CA -2 PLUG & BAITED PULLING TOOL / CATCHER ASS'Y @ 9790' RKB; PULLED OV @ 9617' RKB. IN PROGRESS - ' ° KUP 2L -310 ConocoPhillips &Iota Well Attributes Max Angle & MD TD AIBSka.Iflc. WellboreAPI /UWI iFieldNe a Wall Status Intl( °) MD(RKB) ActBtm(RKB) ca,omllnn,pss 501032061600 1 TARN PARTICIPATING AREA INJ 67.51 2,780.72 10,252.0 ' Comment H2S (ppm) Date Annotation End Date KB-Grd (R) Rig Release Date •• Well Confq. HORIZONTAL -2L -310, 5/'20/20131.02:08 PM SSSV: NIPPLE 20 12/23/2012 Last WO: 33.20 5/13/2010 Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag. SLM 10,055.0 5/11/2013 Rev Reason:GLV 0 /0, TAG, PULL PLUG haggea 5/20/2013 Casing Strings HANGER, 23 7 Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd CONDUCTOR 16 15.062 28.0 112.0 112.0 62.50 H -40 WELDED Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.950 27.6 3,521.0 2,416.5 45.50 L -80 BTC Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 5/8 6.875 25.6 10,247.0 5,615.2 29,70 L -80 BTC -m Tubing Strings Tubing Description String 0... Str ng ID ... Top (RKB) Set Depth (f,.. Set Depth (ND) String Wt.. String ... String Top Thrd T UBIN G t Top Depth 1 2 2 992 23.3 9,800.0 5,283 1 9.30 L -80 EUE8rdABMOD (ND) Top Intl Nomi... Top (ftK8) (RKB) ( °) Rem Description Comment ID (In) 23.3 23.3 -0.02 HANGER - FMC GEN V TUBING HANGER 2.992 516.4 515.9 4.65 NIPPLE CAMCO DS NIPPLE w/2.875" PROFILE 2.875 9,671.2 5,194.5 48.89 SLEEVE -C BAKER CMU SLIDING SLEEVE w/2.812 'D' PROFILE 2.812 CONDUT ^ 9,723.8 5,228.6 44.14 PBR BAKER 80-40 PBR 2.990 2 8 112 9,737.2 5,238.1 43.98 PACKER BAKER FHL PACKER 2.990 9,790.3 5,276.1 43.36 NIPPLE CAMCO 'D' NIPPLE w/ 2.75" NO GO 2.750 9,799.5 5,282.8 43.25 WLEG WIRELINE ENTRY GUIDE 2.920 NIPPLE, 516 - - -- ,; Perforations & Slots Shot Ali Top (ND) etm (ND) Deno i, Top (RKB) etm (RKB) (RKB) (RKB) Zone Date fah °• TYPe Comment ff 10,005.0 10,019.0 5,434.5 5,444.9 Bermuda, 2L -310 6/8/2010 6.0 IPERF 2.5" Prospector RDX DP charges, 60 I deg phase Bottom SURFACE. - Min Top Max Btm Top Depth 28 Depth Depth (ND) (ND) (RKB) (ftK8) (RKB) (ftK8) Type Date Comment 10,005.0 10,019.0 5,434.5 5,444.9 FRAC 6/10/2010 Pumped 242,621 Ibs of Carbolite, placing 240,731)bs behind pipe (pumped 2,602 bbls of fluid). Completed FRAC w/9 ppa on formation GAS LIFT . 3697 Notes: General & Safety End Date Annotation 5/18/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 1232013 NOTE: Drilled as Injector to be Pre - Produced, but has only been on Production since drilled in 2010 GAS LIFT, 8717 GAS LIFT. 9.617 SLEEVE -C, 9,671 1 PBR. 9,724 PACKER, 9,737 NIPPLE, 9,790 Mandrel Details Top Depth Top Port OD Valve Latch Size TRO Run WLEG. 9,800 / N... Top (ftK8) (ftK () Make Model (in) Sery Type Type (in) (psi) Run Date Corn... 1 3,697.2 2,496.5 63.72 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2010 IPERF, 2 8,716.8 4,728.9 64.28 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2010 1°.c46-1°.°19 FRAC 10,005 7. 3 9,617.2 5,159.4 51.34 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2013 PRODUCTION. • 26- 10,247 TD, 10,252 0 • 1 4, ' 1 7 % y' THE STATE Alaska Oil as Conservation Commission - _ -- ALASKA h „ G OVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 (4 ' AL SCANNED MAR 2 0 2013 Main: 907.279.1433 Fax: 907.276.7542 Robert D. Chritensen NSK Production Engineering Specialist 1 ConocoPhillips Alaska, Inc. I D P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, 2L -310 Sundry Number: 313 -098 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this It day of March, 2013. Encl. 3 • STATE OF ALASKA I�� All(A OIL AND GAS CONSERVATION COM ON APPLICATION FOR SUNDRY APPROVALS ;-EB 2 6 2012 20 AAC 25.280 1. Type of Request: Abandon r Rug for,Redrill r Perforate New Pool r Repair well r Char" , c : j- 2, am r j Suspend r Rug Perforations r Perforate ra Rill Tubing r j Time Extension r Operational Shutdow n r Re -enter Susp. Well r j Stimulate r Alter casing r Other: Oil to WAG conversion . 1 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F7, . Exploratory r_j 210 -028 -0 - 3. Address: Stratigraphic r Service 177 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20616 -00 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r 2L -310 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 380052, 381051 Kuparuk River Field / Tam Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 4 10252 5619 10151' 5543' Casing Length Size MD TVD Burst Collapse CONDUCTOR 84 16 112' 112' SURFACE 3493 12 3521' 2417' PRODUCTION 10221 7.625 10247' 5615' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): • 10005' - 10019' 5435' - 5445' 3.5 L - 9800 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL PACKER MD= 9737 TVD= 5239 SSSV = Nipple MD= 516 TVD= 516 12. Attachrrents: Description Sumlrery of Proposal p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/15/2013 Oil ; Gas r WDSPL r Suspended IT 16. Verbal Approval: Date: WIN J r GINJ r WAG F.7. Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Darrell Humphrey Email: N1139 anconocophillids.com Printed Name ./ � R • be D. CO ,�- nsen / Title: NSK Production Engineering Specialist / Signature yi' Ark, of .1.-4 Phone: 659 -7535 Date - 2 -3/`3 6 Commission Use Only f Sundry Number: 31 J i 3 /{ Conditions of approval: Notify Commission so that a representative may witness V v► ` ( Plug Integrity r BOP Test T Mechanical Integrity Test r Location Clearance r _ , Other: 5 1 z! ► 1 r S s it d UL l r 4 1 1-7 s t� 6, 1,3 e c-/ , y�� r c 1 i �L , RBDMS MAR 12 20 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /U _ 4 06 / v APPROVED BY Approved by: 9)..e...444___ COMMISSIONER THE COMMISSION Date: 3 -1/ -/_3 A pproved application is lid for 12 months from the date of approval. Form 10 -403 (Revised 10/2012) F RIGINAL Form a Submit nd Attachments in Duplicate �� 31/1)3 ,olt %, • • 2L -310 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Tarn Well 2L -310 from Oil Production service to WAG Injection service as the well has completed its pre - production period. Well 2L -310 was completed as a Tarn Oil Pool, Bermuda sand, Water alt Gas Injector on June 10, 2010. Oil production rates and bottom hole pressures have declined and warrant converting this well to a service injector. Conversion of well 2L -310 to WAG Injection service will provide pressure support to offset producers 2L -307 and 2L -311. The 16" Conductor was pre - installed (driven). The 10 -3/4" Surface casing (3522' and / 2417' tvd) was cemented with 625 sx AS Lite, 382 sx DeepCRETE. The 7 -5/8 "" Production casing (10247' and / 5615' tvd) was cemented with 750 sx Class "G ". A MIT -IA was last performed on 06/08/10; MITIA 3500 psi, 30 minutes, Passed The injection tubing /casing annulus is isolated via BAKER FHL Packer located @ 9737' and / 5238' tvd. The Top of the Tarn "Bermuda" Sand is 9850' and / 5319' tvd N o (4'1 ie AeteUrl Well was elfro - r tb Qn inJeclbr °, Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK -69 PO Box 196105 C 1 ConocoPhillips Anchorage, AK 99519 -6105 Phone: (907) 659 -7535 Fax: 659 -7314 February 23, 2013 Dan Seamount RECEIVED AOGCC Commissioner FEB 2 6 2012 State of Alaska, Oil & Gas Conservation Commission 33 W. 7 Ave. Ste. 100 AOGCC Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit well 2L- 310 from oil production to WAG injection service. Enclosed you will find 10 -403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 2L -310 (PTD 210- 028 -0). If you have any questions regarding this matter, please contact myself or Darrell Humphrey at 659 -7535. Sincerely, NOP% 44 -_ - Robert D. Christensen Attachments Sundry application Well schematic r �, i KUP 2L -310 Con000Philhips 0- Well Attributes Max Angle & MD TD • A laska, Inc Wellbore API /UWI Field Name Well St !nci (°) MD (ftKB) Act Btm (ftKB) cormmP199ps 501032061600 TARN PARTICIPATING AREA PROD 67.51 2,780.72 10,252.0 Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date "' SSSV: NIPPLE 20 12/23/2012 Last WO: 33.20 5/13/2010 Well Conk' HORIZONTAL -2L- 3101/23/20131:56'. 19 PM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 10,079.0 1/13/2013 Rev Reason: TAG, TIMED C -LOCK IN NIPPLE osborl 1/23/2013 Casing Strings HANGER, 23 Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd a CONDUCTOR 16 15.062 28.0 112.0 112.0 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 103/4 9.950 27.6 3,521.0 2,416.5 45.50 L - 80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd PRODUCTION 75/8 6.875 25.6 10,247.0 5,615.2 29.70 L -80 BTC -m 49 Tubing Strings Tubing Description (String 0... (String ID ..• ITOp (ftKB) (Set Depth (C.. 'Set Depth (TVD) ... (string Wt... (String ... (String Top Thrd TUBING 31/2 2.992 23.3 9,800.0 5,283.1 9.30 L -80 EUE8rdABMOD I Completion Details Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (!n) 23.3 23.3 -0.02 HANGER FMC GEN V TUBING HANGER 2.992 I I I 516.4 515.9 4.65 NIPPLE CAMCO DS NIPPLE w12.875" PROFILE 2.875 9,671.2 5,194.5 48.89 SLEEVE -C BAKER CMU SLIDING SLEEVE w/2.812'0 PROFILE 2.812 CON DUCT0R ,_ 9,723.8 5,228.6 44.14 PBR BAKER 80-40 PBR 2.990 25-1 9,737.2 5,238.1 43.98 PACKER BAKER FHL PACKER 2.990 Il lk 9,790.3 5,276.1 43.36 NIPPLE CAMCO 'D' NIPPLE w/ 2.75" NO GO 2.750 9,799.51 5,282.8 43.25 WLEG WIRELINE ENTRY GUIDE 2.920 NIPPLE, 516 Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Incl Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) 9,790.3 5,276.1 43.36 SLEEVE 2.75" C-LOCK w/DHSIT; SET TO CLOSE 1/23/2013, OPEN 1/4/2013 0.000 1/26/2013 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens SURFACE, . . Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (Shiii Type Comment 28-3,521 _ • 10,005.0 10,019.0 5,434.5 5,444.9 Bermuda, 2L- 310 6/8/2010 6.0 IPERF 2.5" Prospector RDX DP charges, 60 deg phase GAS 3,697 1 LIFT j " 4 Stimulations & Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (ND) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Comment 10,005.0 10,019.0 5,434.5 5,444.9 FRAC 6/10/2010 Pumped 242,621 Ibs of Carbolite, placing 240,7311bs behind pipe (pumped 2,602 bbls of fluid). Completed FRAC w/9 ppa on formation. Notes: General & Safety End Date Annotation GAS LIFT, 5/18/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 8.717 1/23/2013 NOTE: Drilled as Injector to be Pre - Produced, but has only been on Production since drilled in 2010 GAS LIFT, 9,617 r L ___ 1 SLEEVE -C, l I , 9,671 I L_ _■;.., PBR. 9.724 ^ PACKER, 9,737 '''7.1 • SLEEVE, 9,790 NIPPLE, 9,790 I III Mandrel Details _ Top Depth Top Port (ND) Ind OD Valve Latch Size TRO Run WLEG, 9,600 ' N ... Top (ftKB) (SOB) (°) Make Model (!n) Sery Type Type (in) (pai) Run Date Com... 1 3,697.2 2,496.5 63.72 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2010 IPERF, 2 8,716.8 4,728.9 64.28 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2010 10,005 - 10,019\ 1111 FRAC, 10,005 3 9,617.2 5,159.4 51.34 CAMCO KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 6/15/2010 PRODUCTION, • • 28- 10,247 TD, 10,252 prD 21 • • Tarn well 2L -310 Conversion from production to MWAG injection Area of Review Well Summary Tam well 2L -310 was drilled in 2010 and placed in service as a producer of the Bermuda interval. The well was drilled with the intent to convert to MWAG injection after drilling offset development production wells: 2L -306, 2L -312, and 2L -307 CTD sidetracks in 2011. Well 2L -310 was placed on production in 2010 and has produced 461 MBO through January of 2013. The 2L -310 conversion will provide MWAG injection support to four exiting offset Tarn production wells: 2L- 306, 2L -307, 2L -312, and 2L -311. Below, the Area of Review includes the following: • Map with % mile radius shown around the target injection zone; • 2L -310 wellbore schematic; • The mechanical condition of the proposed injection well; • MIT -IA history; and • 2L -310 CBL and interpretation of the cement quality of the subject well (no other wells are located within % mile radius). Area Map with % mile radius around target infection zone Tarn well 2L -310 is located on the Northwest side of the Drilisite 2L Tarn development. The map below shows that there are no other wells located within % mile radius of the 2L -310 penetration of the Bermuda interval. 2L -310 Quarter Mile Radius WO31?V SOWED • • =1.3........... L. L - , : mit 4: 7.era ,........ c.............,. i„„„„ , c r .1016+6 66ta 46 . ::: .eet 1 ED ..... . ..5 .., 1 . - ' r , - e....J (1' -. ,--''' . --" ' . ' , 0* * -...,‘ D. * - %", `---. - - 1 ', ' 0 0* * ) ' k...1 ii L ' / / \--- \ / (.,..---/ ",,,,, CD * * ----- \,.....,(1 / ..---," ..7 -../. = * * - .-- ED* . /------\ ED t. tet txt : I c ' D ,,,, \ j r,r.......„) -, 1/4 " - -- , -- \ .., i .,^ \ or . 16. ■ ' i \ ) --. NM 166- 116 NM 116 In I. 1 -1.-- --, I., , . N u MI IN -, (.) 1., \ / - "-- I ' MN 166 ,,. ......, , . .„,- .•• ......: ..."' , ,_,a. — --........ .. / ''''', .. --. C y ) .,...---,_),_,,,,,_, s-- ' ' ( i -.. .. -'2 2L-4/9 `1.-.36t ) 1 r ( ' 2 , ..-..; 1 ■ a-3ff I.,: 2:: ..2._-•: ; a-307Lt 21,-513 - -3:: •.''FE • : • 2■:-......-■ LL -.323 ::_ -:f 21.-3t74 . t a -32t • • Tam well 2L -310 Wellbore Schematic Tarn well 2L -310 was completed with a single completion having 3 -1/2" 9.3 lbs/ft L -80 tubing by 7 -5/8" 29.7 lbs/ft L -80 production casing. The surface hole was completed with 10 -3/4" 45.5 lbs/ft L -80 casing. The well was perforated in the Bermuda formation from 10,050 — 10,019 ft KB. The top of the Bermuda interval was encountered at 9,880 ft MD. The schematic is attached below. 2L -310 Welbore Schematic Mechanical Condition of Well to be Converted to Injection and MIT Histo ry (2L- 310) The mechanical condition of Tarn well 2L -310 is good. The well is classified as a "Normal Well" meaning that historical MITT and MIT -IA tests have passed. The most recent MITT was tested to 3,500 psi on May 20, 2010 and the MIT -IA was tested to 3,500 psi on June 8, 2010. A new State witnessed MIT -IA will be performed once well 2L -310 is converted, online, and stabilized. 2L -310 CBL and interpretation of the cement quality of the subject well (no other wells are located within % mile radius) As stated above, well 2L -310 was drilled with the intent to convert to injection once offset development wells had been drilled. As part of the drilling procedure a radial cement bond log was performed during the 2L -310 completion. The production casing cement job was designed to place cement at least 500 ft above all significant hydrocarbon bearing zones. The cement job was designed for a calculated top of cement to be located at 7,750 ft MD (using a 50% excess factor) — approximately 2,130 ft above the top of the Bermuda interval (target injection interval). The cement job was pumped as follows (from drilling report): Switched to Schlumberger - Pump 5 bbls H2O - Test lines to 3000 psi - OK - Cont, work pipe 30' strokes. -PUW 250k SOW 130 -Pump 35 bbls CW100 @ 5 bpm, 500 psi -Pump 50 bbls 11.6 ppg Mud Push spacer @ 5 bpm, 520 psi - Drop btm plug -Pump 155 bbls tail at 15.8 ppg C/ G (1.17 yield) - 4 bpm, 500 psi - Drop top plug - Pump 20 bbls H2O w/ DS Washed up before dropping top plug. - Full returns throughout pumping process. Displace w/ Rig pumps using seawater - -7 bpm w/ 1010 psi - Slow to 4 bpm 700 psi -Bump plug w/ 4460 stks (446 bbls) - Pressure to 1700 psi - Hold 3 min -Bleed pressure - Check floats - OK -NOTE: CIP at 10:00 hrs The radial cement bond log indicates that the TOP of cement is located at 7,748 ft (using an AMP less than 6 mV cutoff). The cement is a bit spotty down to 7,882 ft MD, and then looks to be continuous (AMP less than 4 mV) down to TD resulting in a 2,168 ft MD column of cement above the top of the Bermuda Interval. t KUP • 2L -310 Conoco Phillips :; Web Attributes Max Angle & MD TD 1., �.,, ,,. Wollner. APIJUWI Field Name - -- Well Status Teel P) MD (8KB) Act Btm (RKB) p, 501032061600 TARN PARTICIPATING AREA ( PROD 67.51 2,780.72 10,252.0 Comment HES (ppm) Date Annotation End Dab KB-OM (ft) Rig Reigate Deb • "• Well 00098, HORIZONTAL - 2La10, 12320+31: PM SSSV: NIPPLE 20 1223/2012 Last WO: 33.20 5/13/2010 Schematic -Actual Annotation Depth (8KB End Date - I Annotation Last Mod ... End Date Last Tag: SLM 10,079.0 1/13/2013 Rev Reason: TAG, TIMED C -LOCK IN NIPPLE - osborl 1/23/2013 Caslg Strings HANDER, 23 ;.. Caning Description 1Stnng 0 .. String ID ... Top (11(B) Set Depth (f._ Set Depth (TVD) ... String Wt.. String ... String Top That - CONDUCTOR 16 15.062 ' 28.0 112.0 112.0 62.50 11.40 WELDED II Casing Description String 0... String ID ... Top (MB) Set Depth (L.. Sat Depth (ND) -. Sting Wt_. String _. String Top Thrd SURFACE 103/4 9.950 27.6 3,521.0 2,416.5 45.50 L-80 BTC Casing Description Sting 0... String ID ... Top (KKB) get Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd s, PRODUCTION 75/8 6.875 25.6 10,247.0 5,615.2 29.70 L-80 BTC-m Tubing Strings X Tubing Description String 0... String ID ... Top (+1((B) Set Depth (f... Set Depth (TVD) String Wt... String -. String Top Thrd TUBING 312 2.992 23.3 9,800.0 5,283.1 9.30 1-80 EUE8rdABMOD Completion Details Top Depth ...._ _ (TVD) Top Intl Nons.- Top (111(6) (KB) I") item Description Commend ID (In) 23.3 23.3 -0.02 HANGER FMC GEN V TUBING HANGER 2.992 a '. 516.4 515.9 4.65 NIPPLE CAMCO DS NIPPLE w2.875" PROFILE 2.875 -- 9,671.2 5,194.5 48.89 SLEEVE -C BAKER CMU SLIDING SLEEVE w/2.812 'D' PROFILE 2.812 cONDuCTx++z OR - I 9,723.8 5,228.6 44.14 PBR BAKER 8040 P8R 2.990 9,737.2 5,238.1 43.98 PACKER BAKER FHL PACKER 2.990 9,790.3 5,276.1 43.36 NIPPLE CAMCO'0' NIPPLE w/ 2.75" NO GO 2.750 9,799.5 5,282.8 4325 WLEG WIRELINEENTRYGUIDE 2.920 NIPPLE, 518 II -. - Other In Hole (reline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Incl Top (MB) (111(81 C) Deealpdon Comment Run Deb ID (In) 9,790.3 5,276.1 43.36 SLEEVE 2. 75" C- LOCKw/ DHSIT; SET TO CLOSE 1/23/2013, 1/4/2013 0.000 1262013 T Perforations & Slots 1 shot Top (ND) Bin (ND) Dens SURFACE.___.._ ' To MKB) elm(t1KB) (IIKB) (11KB) Zen* Date (eh... Type Comment r __.. ._ -- 10,005.0 10,019.0 5,434.5' 5,444.9 _ Bermuda, 2L-310 6/82010 6.0 _ IPERF 2.5" Prospector RDX DP tllarges, 60 [dog phase Stimulations & Treatments UFT, Bottom 3,897 -_ Min Top Max Btm Top Depth Depth Depth Depth (ND) (TVD) (MB) ' (e1(13) OMB) (KB) Type Date Comment 10,005.0 10,019.0 5,434.5 5,444.9 FRAC 6/102010 Pumped 242,621 lbs of Carbolite, placing 240,731)bs behind pipe (pumped 2,602 bbis of fluid). Completed FRAC w/9 ppa on formation. Notes: General & Safety _ - - - -- .. _ Ertl Date Annotation GAS LIFT, 5/18/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 8, 1/23/2013 NOTE: Drilled as Injector to be Pre- Produced, but has only been on Production since drilled in 2010 • it GA8 UFT, 9,617 SLEEVE -C, 9,671 a_ I PBR, 9.724 PACKER, 9,737 a _ _ SLEEVE, 9,790 NIPPLE, 9,790 -- - Mandrel Details Top Depth Top Pont S_. (ND) Ind OD Valve Latch SK. TRO Run WLEG, 9,800 ____ N_. Top (IK(B) W8) 19 Make Model (M) Sere Type Type (In) (psi) Run Dab Corn.. 1 3,6972 2,496.5 63.72 CAMCO KBG-2 -9 1 GAS UFT DMY INT 0.000 0.0 5/122010 IPERF, 2 8,716.8 4,728.9 64.28 CAMCO KB G2 -9 1 GAS LIFT DMY INT 0.000 0.0 5/122010 10,005 - 10,019 FRAC, 10,005 - - -- ,- ' 3 9,617.2 5,159.4 51.34 CAMCO KBG2 -9 1 GAS LIFT DMY INT 0.000 0.0 6/15/2010 PR0000rI )N, • 2810247 TO, 10,252 • • lor" • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 J-1 O - May 15,2012 al-3/ Commissioner Dan Seamount -44 43 G 2 3 2012 Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU), and the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped in the spring of 2012. The corrosion inhibitor /sealant was pumped in the months of April and May 2012. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, Ges Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • • ConocoPhillips Alaska Inc. , Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Kuparuk Field Date 5/15/2012 1C,1D,1E,2L,3H PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API,# PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal • - 1C-133 50029230130000 2010770 16" 3.9 12" 5/8/2012 6.8 5/14/2012 1D -116 50029229150000 1981720 10" 1.2 10" 5/8/2012 4.3 5/15/2012 1E-123 50029232080000 2040740 5" n/a 18" n/a 5.1 4/9/2012 2L -304 50103206130000 2100110 31" 0.30 20" 3/30/2012 4.3 5/14/2012 2L -306 50103206300000 2101820 8" n/a 8" n/a 3.4 5/14/2012 2L -310 50103206160000 2100280 25" 0.25 12" 3/30/2012 2.6 5/14/2012 2L -312 50103206260000 2101640 13" n/a 13" n/a 2.5 5/14/2012 2L -319 50103205520000 2071120 112" 1.00 20" 3/30/2012 6 5/14/2012 2L -320 50103206270000 2101660 36' 1.00 50" 3/30/2012 3.4 5/14/2012 3H -17 50103200810000 1870990 19" n/a 19" n/a 3.4 4/9/2012 DATA SUBMITTAL COMPLIANCE REPORT 10/26/2011 Permit to Drill 2100280 Well Name /No. KUPARUK RIV U TARN 2L -310 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20616 -00 -00 MD 10252 TVD 5619 Completion Date 6/10/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION / Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: GR / RES, CCL (data taken from Logs Portion of Master Well Data Maint Well Log Information: III Log/ Electr Data Digital Dataset Log Log Run Interval OH/ • Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments i LIS Verification 181 10199 Open 5/24/2010 LIS Veri, RPD, RPS, FET, RPM, RPX, GR, ROP, NCNT, NPHI, FCNT, RHOB, PEF, DRHO 4 C Lis 19678 Induction /Resistivity 181 10199 Open 5/24/2010 LIS Veri, RPD, RPS, FET, RPM, RPX, GR, ROP, NCNT, NPHI, FCNT, RHOB, PEF, DRHO w /graphics Log ✓ Sonic 2 Col 245 10252 Open 5/24/2010 MD BAT, DGR, EWR Log '" Sonic 25 Col 245 5619 Open 5/24/2010 TVD BAT, DGR, EWR Log' Induction /Resistivity 25 Col 245 10252 Open 5/24/2010 MD DGR, EWR, CTN, ALD Log ./ Induction /Resistivity 25 Col 245 5619 Open 5/24/2010 TVD DGR, EWR, CTN, ALD • Log Cement Bond 5 Col 7000 10147 Case 5/24/2010 Radial Cement Bond D C Las 19683 Cement Bond 7000 10184 Case 5/24/2010 Radial Cement Bond, Tens, GR Report: Final Well R 0 0 Open 6/29/2010 Final Well Rep, Tab of Cont, Equip, Well Data, Geo Data, Pres /Form Data, Drill Data, Daily Reps X I C Pdf 19780%ee Notes 110 10252 Open 6/29/2010 Final Well Rep, Tab of Cont, Equip, Well Data, Geo Data, Pres /Form Data, Drill Data, Daily Reps w /Mudlogs graphics Log Mud Log 2 Col 110 10252 Open 6/29/2010 MD Formation log ✓Log Mud Log 2 Col 110 10252 Open 6/29/2010 TVD Formation log ✓ Mud Log 2 Col 110 10252 Open 6/29/2010 MD Combo DATA SUBMITTAL COMPLIANCE REPORT 10/26/2011 Permit to Drill 2100280 Well Name /No. KUPARUK RIV U TARN 2L -310 Operator CONOCOPHILLIPS ALASKA INC API No. 50- 103 - 20616 -00 -00 MD 10252 TVD 5619 Completion Date 6/10/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N og Mud Log 2 Col 110 10252 Open 6/29/2010 TVD Combo X og Mud Log 2 Col 110 10252 Open 6/29/2010 MD Gas Ratio i �-eog Mud Log 2 Col 110 10252 Open 6/29/2010 TVD Gas Ratio Il Mud Log 2 Col 110 10252 Open 6/29/2010 MD Drilling Dynamics .J'Log Mud Log 2 Col 110 10252 Open 6/29/2010 TVD Drilling Dynamics 1 •E1S C Las 19825 - a Pressure 0 1967 Case 7/8/2010 BHPS, Tens, Temp, CCL, III Pres, GR -4.8 to 1967 sec "ED C Las 19838 V erforation 2601 10114 Case 7/8/2010 Perf, Ten, GR, CCL C Directional Survey 27 10252 Open pt Directional Survey 27 10252 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / Daily History Received? a N Chips Received? T717 Formation Tops CDN Analysis "t7 • Received? Comments: - - - - -- - - - - -- - -- Compliance Reviewed By: ___ 14z"-g) _____ Date: oc- / . J i t I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil El Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: June 10, 2010 210 - 0280 / 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 April 25, 2010 50 103 - 20616 - 00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 167' FNL, 646' FEL, Sec. 22, T1ON, R7E, UM May 7, 2010 2L - 310 Top of Productive Horizon: 8. KB (ft above MSL): 141.9' RKB 15. Field /Pool(s): 1164' FNL, 1665' FWL, Sec. 24, T1ON, R7E, UM GL (ft above MSL): 114.9' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1209' FNL, 1931' FWL, Sec. 24, T1ON, R7E, UM 10151' MD / 5543' TVD Tarn Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 461005 y 5927678 Zone 4 10252' MD / 5619' TVD ADL 380052, 380051 TPI: x - 468591 y - 5926646 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 468857 y 5926600 Zone 4 nipple @ 516' MD / 516' TVD 4600, 4599 18. Directional Survey: Yes © No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1500' MD / 1418' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re - drill /Lateral Top Window MD/TVD GR/Res, CCL not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 110' Surf. 110' 24" pre - installed 10.75" 45.5# L -80 Surf. 3522' Surf. 2417' 13.5" 625 sx AS Lite, 382 sx DeepCRETE 7 -5/8" 29.7# L -80 Surf. 10247' Surf. 5615' 9 -7/8" 750 sx Class G 24. Open to production or injection? Yes 0 No ❑ If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) 3.5" 9800' 9737' MD / 5238' TVD 10006- 10019' MD 5435' -5445' TVD 6 spf COMP 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ■ ; DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 1 D `o 10005 10019' 242621# of 16/20 carbolite 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) pre - produced injector - flowback in progress Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AACF I !7 ED NONE JU v 2 6 2010 Alamo 0116 Gas Cons. Corrlmissior. Anchorage Form 10-407 Revised 12/2009 RBDMS JUN 2 3 41 I CONTINUED ON REVERSE Submit original only A,„..._,0 40.e..,,od 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes II No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1500' 1418' needed, and submit detailed test information per 20 AAC 25.071. C -50 6656' 3809' C -40 7554' 4209' C -37 7970' 4399' Top Reservoir 9850' 5319' Base Reservoir 10080' 5490' C -35 10120' 5570' N/A Formation at total depth: Bermuda 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener © 263 - 4820 Printed Name,. G. Alvord Title: Alaska Drilling Manager 3‘...)1.44._ ,� 2_0( C) Signature . /a �-I:'rf —� -- Phone 265 - 6306 Date Z2 1 G� j Sharon Allsup -Drake 1-c (fit t p 11-1 c.�°' 6 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 VI' KUP • 2L -310 CC f l g Well Attributes I Max Angle le & MD TD 1 "" Ala ibo 1 eAPULI I Field Name Well Status Inc/ () IMD (ftKB) Act Btm (ftKB) C cr»eo1R1dR� Wel500320E1 600 ' TARN PARTICIPATING AREA PROD 67 51 _2,780.72 10.252.0 " Icomment I H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date We(LCOn0q:H05j201JT,5L 2L 310,6/12/2010 9`36.16 AM SSSV: NIPPLE Last WO: 3320 5,13/2010 _ Schgnlatc Actual Annotation (Depth (ftK8) End Date Annotation Last Mod.. . End Date Last Tag: SLM 10,133 0 6/7/2010 Rev Reason: Pull RHC, Tag, Perf, Frac, GLV c/o Imosbor 6/12/2010 Casing Strings HANGER, 23 Wg _ Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth String ... String Wt... Strg ... String Top Thrd '° CONDUCTOR 16 15.062 28.0 112.0 112.0 62.50 H WELDED Casing Description String 0... String ID ... Top MKS) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd SURFACE 10 3/4 9.950 27.6 3,521.0 2,416.5 45.50 L BTC Casing Description String 0 . String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd Mt. PRODUCTION 7 5/8 6.875 25.6 10,247.0 5,615.2 29.70 L -80 BTC -m Tubing Strings Tubing Descri String 0... '. Str ID . Top (ftKB) Set Depth (f .. Set Depth (ND) . String Wt_.. String ... String Top Thrd TUBING 3 1/2 i 2.992 23.3 9,800.0 5,283.1 9 L 80 EUESrdABMOD Completion Details Top De pth (N D c/ ) Top In N mi... Top (ftKB (ftK l 9 Item Description comment ID (in) 23.3 23.3 -0.02 HANGER FMC Gen V Tubing Hanger 2.992 516.4 515.9 4.65 NIPPLE Camco DS nipple w/ 2.875" profile 2.875 9,671.2 5, 194.5 48.89 SLEEVE Baker CMU Sliding Sleeve w/ 2.813" DS profile 2.812 '4:' CONDUCTOR,_ 9,723.8 5,228.6 44.14 PBR PBR _ -- 2.990 28 - - 9,737.2 5,238.1 43.98 PACKER Baker 7 -5/8" x 3 -1/2" FHL Packer 2.990 9,790.3 5,276.1 43.36 NIPPLE Camco D Nipple w/ 2.75" NO GO 2.750 9,799.5 5,282.8 43.25 WLEG Wireline Guide 2.992 NIPPLE, 516 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (8KB) (ftKB) (ftKB) Zone Date (sh,, Type Comment 10,005 10,019 5,434.5 5,444.9 Bermuda, 2L- 310 6/8/2010 6.0 IPERF 2.5" Prospector RDX DP charges, 60 I` deg phase I. Stimulations & Treatments Bottom Min Top Max Ben Top Depth Depth SURFACE, '' Depth Depth (ND) (TVD) 28 -3,521 `i (ftKB) (ftK8) (ftKB) ( ftKB ) •e Date Comment 10,005.0 10,019.0 5,434.5 5,444.9 FRAC 6/10/2010 Pumped 242,621 Ibs of Carolite, placing 240,731 behind pipe (pumped 2,602 bbls of fluid). Completed FRAC w/9 ppa on formation. 3,697 x- Notes: General & Safety End Date Annotation 5/18/2010 NOT E INJECTOR WILL BE PRE- PRODUCED '5/182010 INO FE VIEW SCHEMATIC w /Alaska Schemabc9 -0 fit GAS LIFT, 8,717 WI GAS LIFT, -__ 9,617 SLEEVE, 9,671 Ile PBR, 9,724 - - - -- -w.� s,J PACKER, 9,737 - - -- III NIPPLE, 9,790 Mandrel Details Top Depth Top Port J a .. Stn (ND) Inc! OD Valve Latch Size TRO Run WLEG, 9,800 Top(RKB) (8103) (`) Mak. Model (in) Sery TYPe Type (in) (Pei) Run Date Com... 1 3,697.2 2,496.5 63.72 CAMCO KBG - 2 - 9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2010 IPERF, 14005 - 10,01 _, 9 2 8,716.8 4,728.9 64.28 CAMCO KBG -2 9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2010 FRAC, t9,9os " . 3 9,617.2 5,159.4 51.34 CAMCO KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 6/6/2010 I I I PRODUCON, 26- 1 TD, 10,252 • • ConocoPhi!lips Time Log & Summary We/fwew Web Reporting Report Well Name: 2L - 310 Rig Name: DOYON 16 Job Type: DRILLING ORIGINAL Rig Accept: 4/24/2010 8:00:00 PM Rig Release: 5/13/2010 11:59:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/22/2010 24 hr Summary Clean up around well # 2L -304- Wait on Slickline to complete ops on 2L -309- Well prep for 2L -310 00:00 12:00 12.00 0 0 MIRU MOVE PRLO P General clean up around well # 2L-304 -Wait on slickline unit to complete work on well # 2L -309 -Wait on pad prep on Well 3 2L -310 - SIMOPS; Remove flow nipple from 20" hydril - Install flow nipple on alternate 20" hydril - Change out ram on link tilt - Change out 4 way valve on pipe skate - Change out hydraulic motor on rig floor tugger -Work on Doyon Drilling "MP2" work orders 12:00 00:00 12.00 0 0 MIRU MOVE PRLO P Continue site prep - - Rip ice from pad down to gravel in preparation for gravel to raise elevation - SIMOPS; Change out knife valve on diverter system - Remove and repair spinners on Iron Roughneck - Continue working on Doyon Drilling "MP2" workorders - Perform derrick and top drive inspections 04/23/2010 Pad prep for move onto 2L -310 - Rig maintenance - repairs - Prep tubing and casing spools -Prep tree and adapter flange 00:00 12:00 12.00 0 0 MIRU MOVE PRLO P Continue with pad prep - Removing snow & ice from pad down to gravel - Continue with rig maintenance -Attach Adapter flange to tree - Spot on stand in rig cellar area -MU tubing spool to casing spool 12:00 00:00 12.00 0 0 MIRU MOVE PRLO P Continue with pad prep -Haul in gravel to raise elevation - Groom & level gravel for rig mats - Continue rig maintenance -NOTE: AOGCC given 24 hr notice on 4/22/10 @ 13:30 hrs for upcoming diverter test -AOGCC Rep Bob Noble waived witness of test Page 1 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/24/2010 24 hr Summa Prep pad - Lay herc. & mats - NU Diverter - Spot rig over well - Spot support mods -RU MI, MWD & Mud loggers shacks -Load BHA and DP in shed -Take on Spud mud 00:00 03:00 3.00 0 0 MIRU MOVE PRLO P Continue pad prep -Grade gravel to raise elevation for rig 03:00 03:30 0.50 0 0 MIRU MOVE PRLO P Pull rig up & position in front of well 03:30 05:00 1.50 0 0 MIRU MOVE PRLO P Lay herculite and rig mats 05:00 08:00 3.00 0 0 MIRU WHDBO NUND P NU diverter spool and 20" Hydn'j . -Spot wellhead equip. in cellar & secure - Install first section of diverter line 08:00 09:00 1.00 0 0 MIRU MOVE MOB P Begin moving rig over well - Scafolding on well # 2L -309 in way of spotting rig 09:00 10:30 1.50 0 0 MIRU MOVE PRLO P Call out DSM & remove scafolding from 2L -309 10:30 12:00 1.50 0 0 MIRU MOVE PSIT P Spot rig over well # 2L -310 and shim / level 12:00 20:00 8.00 0 0 MIRU MOVE RURD P Lay herculite and mats for support modules -Spot pump, pits and generator modules - RU same - Continue to NU diverter stack, torque bolts and lock down screws - Install and plumb knife valve. Install diverter line -Spot MI, MWD and Epoch support shacks 20:00 00:00 4.00 0 0 MIRU DRILL RURD P Mobilize BHA in pipeshed - - Load 96 jts 5" DP & 14 jts 5" HWT. in pipeshed -Load first load of 8.8 ppg spud mud in pits - Accept rig at 20:00 hrs 04/25/2010 Load Dp & HWT. in shed - PU same and stand back - Press. test lines -PU BHA -Clean out conductor - RU Gyro and drill to 505' 00:00 01:00 1.00 0 0 MIRU WHDBO BOPE P PU 2 joints 5" DP - ,Perform Diverter, function test -NOTE: AOGCC Rep, Bob Noble waived witness of test - Continue to load 5" HWT. & 5" DP in shed - Tagged ice plug in conductor at ±34' 01:00 07:00 6.00 0 0 MIRU DRILL PULD P PU 14 joints HWT. + jars and stand back in derrick -PU 96 joints 5" DP and stand back in derrick 07:00 08:00 1.00 0 0 SURFA( DRILL PULD P PJSM on upcoming spud -MU BHA Page 2 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 09:00 1.00 0 0 SURFA( DRILL PRTS P Fill high pressure lines w/ H2O and test same -Fill hole - inspect Diverter Stack, starting head seal and knife valve - OK 09:00 10:00 1.00 0 245 SURFA( DRILL DDRL P Clean out conductor to ±110' -Drill to 245 w/ 40 rpm 2 -3 k tq - 450 gpm, 450 psi - 3 -10 k WOB 10:00 10:30 0.50 0 0 SURFA( DRILL TRIP P Blow down T.D. - POH 10:30 11:30 1.00 0 0 SURFA( DRILL PULD P PU BHA #1 to MWD 11:30 12:30 1.00 0 0 SURFA( DRILL PULD P Upload MWD 12:30 14:00 1.50 0 0 SURFA( DRILL PULD P Orient Mud Motor to MWD - Continue to PU BHA # 1 14:00 14:30 0.50 0 0 SURFA( DRILL SFTY P PJSM on Gyro rig up 14:30 15:00 0.50 0 185 SURFA( DRILL TRIP P RIH and tag fill at ±185' -LD flex DC 15:00 15:30 0.50 185 185 SURFA( DRILL PULD P Mobilize and RU Gyro 15:30 17:30 2.00 185 245 SURFA( DRILL WASH P PU stand w/ jars - Clean out to 245' w/ 30 rpm, 450 gpm, 800 psi - Dispalce well w/ 8.8 ppg spud mud - Shallow pulse test MWD w/ 505 gpm - OK 17:30 18:00 0.50 245 245 SURFA( DRILL SRVY P Stand back jar stand - PU Flex DC - RIH - Take Gyro survey 18:00 00:00 6.00 245 505 SURFA( DRILL DDRL P PU jar stand -Dir. Drilling f/ 245' to 505' w/ 20k WOB - 475 gpm, 960 psi on, 920 psi off btm -PUW 80k - SOW 80k - ROW 80k - 40 -80 RPM - Run gyro every connection -ART = 1.38 hrs =- AST = 1.73 hrs -Jars 3.11 hrs - Bit 3.11 hrs 04/26/2010 Directional drill f/ 505 to 1863' - Released GYRO at 1863' 00:00 12:00 12.00 505 1,227 SURFA( DRILL DDRL P Continue Dir. Drilling f/ 505' to 1227' MD - Gyro every connection - 650 gpm, 1200 psi off, 1400 psi on btm - 15 -30k WOB -80 RPM w/ 2 -3k tq off, 4 -5k tq on btm - PUW 91 k - SOW 91 k - ROW 90k -AST = 4.68 hrs - ART = 1.04 hrs - Jar hrs - 8.83 hrs - Bit hrs 8.83 hrs 12:00 14:30 2.50 1,227 1,392 SURFA( DRILL DDRL P Continue to Dir. drill f/ 1227' to 1392' MD - Gyro every connection -Same parameters as above 14:30 16:30 2.00 1,392 1,392 SURFA( DRILL CIRC P Circulate and work pipe while discussing w/ town team options about Gyro / MWD survey data 16:30 18:00 1.50 1,392 1,392 SURFA( DRILL SRVY P Obtain "Check Shot" surveys at 1332' and 1362' Page 3 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 1,392 1,863 SURFA( DRILL DDRL P Dir. Drill f/ 1392' to 1863' MD - RD Gyro equip. and release (last gyro suvey at 1190'). - 525 -650 gpm w/ 1000 -1260 psi off, 1270 -1480 psi on btm -WOB 25 -30k - 80 RPM w/ 2 -3k tq off, 4 -6k tq on btm -PUW 95k - SOW 95k - ROW 95k -Max units of gas = 2428 at 1417' MD -ART .52 hrs - Total 2.94 hrs - AST 3.98 hrs - Total 10.39 hrs -Jar hrs total = 13.33 - Bit hrs total = 13.33 04/27/2010 Directional Drill f/1863' to 3535' MD (13 1/2" TD)- Circ. hole clean 00:00 12:00 12.00 1,863 2,740 SURFA( DRILL DDRL P Dir. Drilling f/ 1863' to 2740' MD - WOB 15 -30k -80 RPM w/ 5 -7k tq off, 5 - 11k tq on btm - 650 -730 gpm w/ 1150 -1740 psi off, 1350 -2000 psi on btm -PUW 105k - SOW 94k - ROW 95k -AST = 3.9 hrs - ART = 2.72 hrs -Jar hrs = 19.4 - Bit hrs = 19.94 5 j 12:00 23:00 11.00 2,740 3,535 SURFA( DRILL DDRL P Continue Dir. Drilling f/ 2740' to 3535' MD (13 1/2" TD) - WOB 25k -30k -Mad pass last three connections at 250 FPH per onsite Geo. - 700 -730 gpm, 1780 -2150 psi on - 1670 -1930 psi off btm -80 RPM w/ 4 -10k tq on - 4 -7k tq off btm -PUW 116k - SOW 96k - ROW 102k 23:00 23:30 0.50 3,535 3,535 SURFA( DRILL SRVY P Obtain Check shot surveys 23:30 00:00 0.50 3,535 3,535 SURFA( DRILL CIRC P CBU w/ 730 gpm, 1900 psi - R & R DP w/ 80 rpm -ART = 5.19 - AST = 1.67 -Jar hrs Total = 26.8 - Bit hrs Total = 26.8 04/28/2010 Backream out of hole f/ 3535' to 659' (BHA) -RIH- As precaution, wash & ream last 2 stds to btm -CBU X2 - POH on elevators w/ no issues - LD BHA -RU & run 10 3/4" casing to 287' 00:00 07:30 7.50 3,535 659 SURFA( DRILL REAM P Backreamed out of the hole from 3,535' to 659'. 730 GPM 2000 PSI 80 RPM. 07:30 08:30 1.00 659 3,400 SURFA( DRILL WPRT P RIH from 659' to 3,400' Hole condition good. 08:30 10:30 2.00 3,400 3,535 SURFA( DRILL CIRC P Washed down from 3,400' to 3,535' Precautionary while circulating 2 BU. 730 GPM 1950 PSI 80 RPM. 10:30 12:00 1.50 3,535 2,078 SURFA( DRILL TRIP P Observed well and POOH on elevators from 3,535' to 2,078'. Hole condition good. Page 4 of 26 0 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 2,078 331 SURFA( DRILL TRIP P Continue to POH on elevators to 659' (BHA) - -Stand back HWT. to 99' 13:00 14:30 1.50 331 88 SURFA( DRILL PULD P LD Flex DC's and BHA to BAT Sonic tool 14:30 15:30 1.00 88 SURFA( DRILL PULD P Download MWD 15:30 17:00 1.50 88 0 SURFA( DRILL PULD P Pull up - Drain BHA - Break bit- RIH and LD BHA 17:00 17:30 0.50 0 0 SURFA( DRILL PULD P Cear floor of equip. not needed for upcoming operation 17:30 20:00 2.50 0 0 SURFA( CASING RURD P PJSM w/ all personnel involved w/ casing run -RU to run 10 3/4" 45.5# surface casing - Function test all equipment 20:00 20:30 0.50 0 0 SURFA( RIGMNT SVRG P Service rig - Grease swivel packing on T.D. - Inspect pipe skate 20:30 22:00 1.50 0 0 SURFA( RIGMN1 RGRP T Change stinger ram on pipe skate 22:00 23:00 1.00 0 120 SURFA( CASING RNCS P PJSM - PU Shoe track - Circulate through same w/ 6 bpm -Check floats - OK 23:00 00:00 1.00 120 287 SURFA( CASING RNCS P Continue to run 10 3/4" 45.5# casing per well program to 287' 04/29/2010 Ran and cemented 10 3/4" 45.5# surface casing (Shoe at 3522' MD - 2420' TVD) -CIP @ 1430 hrs -ND diverter stack 00:00 02:45 2.75 287 1,800 SURFA( CASING RNCS P Continue to run 10 3/4" 45.5# casing per well program to 1,800' 02:45 03:45 1.00 1,800 1,800 SURFA( CASINGCIRC P Circulated and conditioned mud working pumps up to 5 BPM FCP 370 PSI. 03:45 07:00 3.25 1,800 3,522 SURFA( CASING RNCS P Continue to run 10 3/4" 45.5# casing per well program to 3,480'. Made up landing joint and landed casing @ 3.522'. . 07:00 08:30 1.50 3,522 3,522 SURFA( CASING RURD P Rigged down Franks tool and rigged up cement head and lines. 08:30 10:30 2.00 3,522 3,522 SURFA( CEMENT CIRC P Circulated and conditioned mud working pumps up to 7 BPM FCP 480 PSI. Il Page 5 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 13:45 3.25 3,522 3,522 SURFA( CEMEN CMNT P Switched to Schlumberger - Pump 5 bbls H2O - Test lines to 3000 psi - OK - Cont. work pipe 30' strokes. -PUW 190k SOW 120 -Pump 50 bbls CW100 @ 5 bpm, 175 psi -Pump 50 bbls 10.5 ppg Mud Push spacer @ 5 bpm, 380 psi -Drop btm plug -Pump 503 bbls lead at 10.7 ppg ASL (4.51 yield) - 6 bpm, 500 psi -Pump 115 bbls tail at 12.0 ppq DeepCrete (1.62 yield) - 5 bpm, 400 psi -Drop top plug - Pump 20 bbls H2O w/ DS Casing - Stuck while dropping bottom plug PU 125 k over last up wt no movement - set on hanger -Full returns throughout pumping proccess 13:45 15:00 1.25 3,522 3,522 SURFA( CEMEN" DISP P Displace w/ Rig pumps using 9.9 ppg mud - Cement to surface w/ 8 bbls away -7 bpm w/ 840 psi - Slow to 4 bpm 550 psi w/ 302 bbls away -Bump plug w/ 3128 stks (315 bbls) - Pressure to 1100 psi - Hold 10 min -Bleed pressure - Cback floa c - OK -305 bbls cement to surface , -NOTE: CIP at 14:30 hrs 15:00 17:00 2.00 3,522 0 SURFA( CEMEN" RURD P RD and clean cement head, casing elevators - Back out and flush landing joint - LD same -Blow down cement lines - Clear rig floor off all casing equip. - Disconnect knife valve, flush 20" Hydril - SIMOPS: Empty mud pits - -Move Mudloggers shack to make room for well work on 2L -304 17:00 19:30 2.50 0 0 SURFA( WHDBO NUND P ND 20" riser - Flush Annular - Move cement silos -Break down diverter line - Remove knife valve -Break bolts on annular and diverter spool 19:30 00:00 4.50 0 0 SURFA( WHDBO NUND P PJSM - ND diverter stack - ND diverter spool and quick connect -NU casing and tubing spools -FMC Rep test metal to metal seal to 1000 psi f/ 10 min - OK 04/30/2010 NU & test BOPE- RD- Install wear ring - RILDS- PU 138 jts 5" DP -PU BHA #2 00:00 01:30 1.50 0 0 SURFA( WHDBO NUND P Nippled up BOP. Page 6 of 26 4111 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 08:00 6.50 0 0 SURFA( WHDBO BOPE P Tested BOP rams, choke manifold, and floor valves to 250/3500 psi. Tested Bag to 250/2500 psi. Tested closing unit OK. TIW valve failed to test. Replacement on the way. Witness of test waived by John Crisp AOGCC. RD test equipment. 08:00 09:00 1.00 0 0 SURFA( WHDBO RURD P Blew down lines. Installed wear bushing and put on bales. Picked up elevators. 09:00 12:00 3.00 0 2,062 SURFA( DRILL PULD P Made up mule shoe and RIH picking up 5" DP from the pipeshed to 2,062'. 12:00 13:30 1.50 2,062 3,172 SURFA( DRILL PULD P Continue to PU 5' DP from shed f/ 2062' to 3172' MD 13:30 14:30 1.00 3,172 3,172 SURFA( RIGMNT SLPC P Cut & slip 71' of drilling line - Inspect T.D. Saver Sub 14:30 15:00 0.50 3,172 3,172 SURFA( RIGMNT SVRG P Service Rig - Inspect T.D. - Change dies on T.D. 15:00 16:00 1.00 3,172 3,172 SURFA( DRILL PULD P Move HWf. around in derrick - Stand back 3 stands DP - -PU 8 more jts from pipe shed 16:00 17:30 1.50 3,172 0 SURFA( DRILL TRIP P POH w/ 5" DP to surface - Break Muleshoe 17 :30 18:30 1.00 0 945 SURFA( DRILL PULD P MU muleshoe on jt - PU 30 jts of 3.25" ID 5" DP f/ shed to 18:30 19:00 0.50 945 0 SURFA( DRILL TRIP P POH w/ 5" DP to surface - Break Muleshoe 19:00 21:30 2.50 0 0 SURFA( DRILL PULD P Mobilize BHA # 2 to rig floor,- PJSM -PU and break in new DC's w/ 50 -75% of reccommended torque value - Orient Mud motor 21:30 23:00 1.50 0 0 SURFA( DRILL PULD P Upload MWD tools - SIMOPS: Test new Floor Safety Valve to 250 psi low, 3500 psi f/ 5 charted min. each 23:00 00:00 1.00 0 296 SURFA( DRILL PULD P Continue to PU BHA # 2 to 296' 05/01/2010 PU BHA # 2 - Clean out plugged flowline - Continue PU BHA and 5" DP -Test 10 3/4' casing to 3000 psi -Drill out FC, cement and shoe - Clean out rathole to 3535' - Drill 20' of new hole to 3555' - CBU - Perform FIT to 16.0. ppgEMW - Displace well to new LSND mud -Driil to 3575' 00:00 01:00 1.00 296 621 SURFA( DRILL CIRC T RIH to 621'. Shallow tested MWD @ 530 GPM 1100 PSI. Flowline plugged causing Drip pan to overflow less than 1/2 Bbl. of Drilling Mud an estimated 5 gallons was carried by the wind out of containment. Cleaned up spray from snow. 01:00 02:00 1.00 621 0 SURFA( DRILL TRIP T POOH and stood back DC's. Downloaded MWD. 02:00 04:30 2.50 0 0 SURFA( RIGMNT RGRP T Unplug flowline. Page 7 of 26 11 10 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 05:30 1.00 0 621 SURFA( DRILL TRIP T Made up BHA and Upload MWD. RIH to 621' taking returns from IA to Pit 3 using the Cellar Pump. 05:30 08:00 2.50 621 2,143 SURFA( DRILL TRIP P RIH from 621' to 2,143' picking up singles from pipeshed, taking returns from IA to Pit 3 using the Cellar Pump. Continued working on Flowline while Tripping. 08:00 09:00 1.00 2,143 2,143 SURFA( DRILL OTHR T IA plugged with thick Mud. Cleaned out with SS. Tested Flowline OK. 09:00 10:30 1.50 2,143 3,190 SURFA( DRILL TRIP P RIH from 2,143' to 3,190' picking up singles from pipeshed, 10:30 11:00 0.50 3,190 3,190 SURFA( DRILL DHEQ P Tested MWD and CBU. 11:00 13:00 2.00 3,190 3,190 SURFA( DRILL PRTS P Rigged up and tested casing to 3,000 psi for 30 min. OK. -RD test equip - blow down lines 13:00 14:00 1.00 3,190 3,442 SURFA( DRILL WASH P Screw in TD - Obtain parameters - -Wash down f/ 3286' to 3442' (F.C.) w/ 457 gpm, 1260 psi -Small cement stringers encountered -PUW 120k - SOW 70k - ROW 96k 14:00 17:30 3.50 3,442 3,535 SURFA( CEMEN" DRLG P Drill out F.C. - Clean out cement to shoe w/ 430 gpm, 1140 psi -Drill out shoe w/ 2 -5k WOB, 60 RPM - Work through shoe several times -Clean out to 3535' 17:30 18:30 1.00 3,535 3,555 SURFA( DRILL DDRL P Drill new hole f/ 3535' to 3555' MD - -Work pipe to free shoe dedris from around BHA - Trouble shoot MP # 1 18:30 19:00 0.50 3,555 3,555 SURFA( DRILL CIRC P CBU w/ 490 gpm, 1520 psi -MW = 9.6 ppg at bottoms up 19:00 20:30 1.50 3,555 3,555 SURFA( DRILL FIT P PJSM w/ crew - RU and circ. air out of lines - Perform FIT to 16 ppg EMW (805 psi) -MW = 9.6 ppg - Shoe TVD = 2416' -RD test equip. - Continue to work on MP # 1 20:30 22:00 1.50 3,555 3,555 PROD1 DRILL CIRC P Pump 40 bbl spacer and 316 bbls new 9.7 ppg LSND mud -490 gpm, 1520 psi - Continue to work on MP #1 22:00 22:30 0.50 3,555 3,555 PROD1 DRILL CIRC P Empty remaining old mud from pits -Top rinse pits and fill w/ new LSND 22:30 23:00 0.50 3,555 3,555 PROD1 RIGMNI RGRP T Finish repair on MP #1 ( Replace wear plate on # 2 cylinder). 23:00 00:00 1.00 3,555 3,575 PROD1 DRILL DDRL P Obtain Paramters - Orient and Dir. drill f/ 3555' to 3575' MD -80 RPM, 5k tq - 730 gpm 05/02/2010 Dir. Drill f/ 3575' to 4992' - CBU X2 -BROOH f/ 4992' to 3522' (Shoe) -CBU - BROOH to 1800' Page 8 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 3,575 4,669 PROD1 DRILL DDRL P Dir. Drilling f/ 3,575' to 4,669' MD 2,917' TVD- WOB 5 -7 k -100 RPM w/ 5 k tq off, 7 k tq on btm 733 gpm w/ 2700 psi -PUW 121k - SOW 100k - ROW 106 k -AST = .93 hrs - ART = 6.77 hrs 12:00 14:00 2.00 4,669 4,992 PROD1 DRILL DDRL P Dir. Drilling f/ 4669' to 4992" MD (3061' TVD) - WOb 5 -15k -730 gpm, 2600 psi off, 2850 psi on btm -100 RPM w/ 5 -6k tq off, 7 -10k tq on btm -PUW 126k - SOW 102k - ROW 110k -ART = 1.62 hrs - AST = 0 hrs - Jars = 9.32 hrs - Bit = 9.32 hrs 14:00 15:30 1.50 4,992 4,992 PROD1 DRILL CIRC P CBU X2 w/ 730 gpm, 2630 psi 15:30 18:00 2.50 4,992 3,522 PROD1 DRILL REAM P Monitor well - Backream out of hole f/ 4992' to 3522' (Shoe) -650 gpm, 2400 psi - 100 RPM w/ 7k tq 18:00 19:00 1.00 3,522 3,522 PROD1 DRILL CIRC P CBU w/ 650 gpm, 1930 psi - Observe well 19:00 00:00 5.00 3,522 1,800 PROD1 DRILL REAM P Backream out of hole f/ 3522' to 1800' -650 gpm - 60 -70 RPM 05/03/2010 BROOH to 1192'- CBU- POH on elevators- LD BHA #2- PU BHA # 3- Shallow test MWD & Well Commander tool -RIH- Dir. Drill per program to 5583' MD - 3328' TVD 00:00 01:00 1.00 1,800 1,192 PROD1 DRILL REAM P Backream out of hole f/ 1800' to 1192' -650 gpm - 60 -70 RPM 01:00 01:30 0.50 1,192 1,192 PROD1 DRILL CIRC P CBU 650 GPM @ 1890 PSI. 01:30 03:30 2.00 1,192 206 PROD1 DRILL TRIP P POOH on TT to 206'. Drained and checked Stack for clay. 03:30 06:00 2.50 206 0 PROD1 DRILL PULD P Laid down bit and Down load MWD. 06:00 06:30 0.50 0 0 PROD1 RIGMNT SVRG P Serviced Rig and Crown. Cleaned floor. 06:30 11:00 4.50 0 400 PROD1 DRILL PULD P Picked up BHA and uploaded MWD. Tested Geospan to 3500 psi. 11:00 12:00 1.00 400 400 PROD1 DRILL DHEQ P Pulse tested MWD and Blew down TD. Layed down 1 Flex Collar. 12:00 13:00 1.00 400 1,332 PROD1 DRILL TRIP P PJSM - Prep and load sources -RIH w/ HWT. and 6 stds DP to ± 1332' Page 9 of 26 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 14:30 1.50 1,332 1,332 PROD1 DRILL C1RC P Fill pipe - Break in Geo -Pilot at 30,40,50 & 60 RPM - 500 gpm, 950 psi -Drop ball and stage pumps up at 2 bpm increments - Open Well Commander w/ 1950 psi - Confirm open w/ 500 gpm, 210 psi - Drop ball to close - Pressure to 2050 psi to close -Send downlink to Geo -Pilot (good detection observed) - 500 gpm, 1020 psi 14:30 17:00 2.50 1,332 4,709 PROD1 DRILL TRIP P Continue to RIH f/ 1332' to 4709' (fill every 2000') 17:00 17:30 0.50 4,709 4,992 PROD1 DRILL REAM P Screw in T.D. - Obtain parameters As precaution, wash & ream f/ 4709' to btm at 4992' -600 gpm, 1730 psi - 100 - 120 rpm, 6k tq 17:30 00 :00 6.50 4,992 5,583 PROD1 DRILL DDRL P Dir. drilling f/ 4992' to 5583' MD (3328' TVD) - WOB 5 -20k -590 to 730 gpm, 1700 psi -2470 psi off, 1730 -2560 psi on btm -150 rpm w/ 5 -7k tq off, 7 -10k tq on btm -NOTE: Slowed pump rate to 590 & rpm to 120 due to Geo -Pilot roll -Pump Nut plug sweep to clean Geo -pilot - Increase pump rate to 730 gpm, rpm to 150 -PUW 140k - SOW 105k - ROW 115k - ART 3.59 hrs - Bit hrs 3.59 - AST 0 hrs - Jars 12.91 hrs 05/04/2010 Directional Drill 9 -7/8" Prod hole from 5583' MD to 6733' (3841' TVD), hole packed off while backreaming. Pumping slow to find a place to regain circulation. Established circulation with full returns at 6570'. Lost a total of 386 bbls with 96 bbls returned later. Total loss 290 bbls to the formation. Changed dies in the grabber for the top drive (Dies worn on short tool joint hard band). Continue to backream from 6642' to 5606'. Change dies again in the grabber. Continue to backream from 5606' to 4940'. Drop a 2 -1/8" ball to activate and open the circulation sub 1216' above the bit. Pump ball down at 2 bpm w/ 150 psi. Once on seat, increase pressure in 200 psi increments, valve opened at 2600 psi. Pump out of the hole, pumping 878 gpm w/ 1370 psi from 4940' to 3518'. Two tight spots were rotated through (4280' and 4178'). While pulling at 3712', flow meter showed increase flow, monitored well, continued to pull to 3521'. Circulated two bottom's up at 3423' with flow meter reading back to normal. Page 10 of 26 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 5,583 6,695 PROD1 DRILL DDRL P Directional drill 9 -7/8" prod hole f/ 5583' to 6695' MD (3825' TVD) - WOB 8 -18k - Pumping 650 to 750 gpm w/ 2020 to 2790 psi off bottom, 2170 to 2870 psi on btm, ECD's 10.76 to 11.51 PPg• - Rotate 120 to 180 rpm w/ 8 to 15k ft Ibs of torque on btm, 8 to 11k ft Ibs of torque off bottom. -PU 143 to 158k - SO 106 to 111k- Rot 116 to 121k - ART 7.21 hrs - Bit hrs 10.8 - Jars 20.12 hrs Note: Pumped 20 bbl Nut plug sweeps to clean Geo -pilot @ 5600', 5980', and 6262'. Performed a 290 bbl dilution while drilling @ 6000'. Pumped a 40 bbl hi vis sweep while drilling @ 6451'. 12:00 12:30 0.50 6,695 6,733 PROD1 DRILL DDRL P Directional drill 9 -7/8" prod hole f/ 6695' to 6733' MD (3841' TVD) - WOB 10k - Pumping 750 gpm w/ 2870 psi on btm„ 2720 psi off bottom, ECD's 11.67 ppg - Rotate180 rpm w/ 12 to 15k ft Ibs of torque on btm, 11k ft Ibs of torque off bottom -PU 155k - SO 111k - Rot 120k - ART .21 hrs - Bit hrs 11.01 - Jars 20.33 hrs 12:30 13:30 1.00 6,733 6,570 PROD1 DRILL REAM T Backream stand twice, ECD's spiked to 14.5 ppg. Pump pressure went from 2870 to 3500 psi (Packed off). Shut down pumps, then pump @ 2bpm w/ 330 psi, increase to 5bpm w/ 760 psi. Rotate 100 rpm. No returns observed. Monitor well. Lost a total of 386 bbls. Full returns @ 6570'. 13:30 14:00 0.50 6,570 6,570 PROD1 RIGMNT RGRP T Change out dies in the grabber for the top drive due to short boxes on stands, tearing up dies on the hard bands. 14:00 16:30 2.50 6,570 5,606 PROD1 DRILL REAM T Continue to backream from 6642' to 5606'. Rotate 100 rpm w/ 15k ft Ibs of torque. Pumping 600 gpm w/ 1668 psi. Totco -40% flow out. 16:30 17:00 0.50 5,606 5,606 PROD1 RIGMNT RGRP T Change out dies again in the grabber for the top drive. Page 11 of 26 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 19:30 2.50 5,606 4,940 PROD1 DRILL REAM T Continue to backream from 5606' to 4940'. Rotate 100 rpm w/ 15 to 10k ft lbs of torque. Pumping 600 gpm w/ 1740 psi. Totco -40% flow out. Pulling speed 24 to 31' /minute. Note: 386 mud bbls pumped away, well flowed back 96 bbl of lost fluid. Total fluid lost to hole = 290 bbls. 19:30 20:00 0.50 4,940 4,940 PROD1 DRILL CIRC T Drop a 2 -1/8" ball to open the commander circulating sub. Pump down @ 2bpm w/ 150 psi - Totco 14% flow out. Ball on seat w/ 18 bbls pumped. Stage up from 1400 psi in 200 psi increments. Tool opened at 2600 psi. 20:00 23:30 3.50 4,940 3,518 PROD1 DRILL REAM T Pump out of the hole from 4940' to 3518'. Pumping 878 gpm w/ 1370 psi -Totco 49% flow out. Rotated through two tight spots, one at 4280' and 4178'. While pulling at 3712', the flow indicator increased to 71 %, monitored well, then continued to pump out to 3521'. Pulling speed 40 to 50' /minute, slowed to 10' /minute at 3712' to clean up hole. 23:30 00:00 0.50 3,518 3,423 PROD1 DRILL CIRC T Circulate two bottom's up, pumping 878 gpm w/ 1170 psi. Totco flow came back down to 49 %. 05/05/2010 Drop 2 -1/8" ball pump down and close commander circ sub w/ 2600 psi, pump 12.5 ppb nut plug sweep to clean up BHA, PJSM, change out saver sub on the top drive, trip in the hole from 3420' to 6547', precautionary ream from 6547' to TD @ 6733', PJSM, pump 30 bbl hi vis spacer, follow w/ new LSND mud, directional drill 9 -7/8" hole from 6733' to 69s4', service rig, continue to directional drill from 6924' to 7709' (3923' TVD). 00:00 01:00 1.00 3,423 3,420 PROD1 DRILL CIRC T Flowcheck OK. Closed Commander tool (2600 psi) and pumped Nut plug pill (12.5 ppb) at 738 gpm 2570 psi. Note: PJSM while circulating for changing out saver sub. 01:00 03:30 2.50 3,420 3,420 PROD1 RIGMNT RGRP P Changed out saver sub on Top Drive. Had to change dies in Grabber to break sub. 03:30 06:00 2.50 3,420 6,547 PROD1 DRILL TRIP T RIH from 3,420' to 6,547' filling pipe every 20 stands. 06:00 08:00 2.00 6,547 6,733 PROD1 DRILL REAM T Precautionary wash and ream from 6547' to TD @ 6733'. Pumping 700 gpm w/ 2600 psi. Rotate 40 rpm w/ 5k ft lbs of torque. 08:00 08:15 0.25 6,733 6,733 PROD1 DRILL SFTY P Pre job safety meeting on mud displacment. 08:15 09:00 0.75 6,733 6,733 PROD1 DRILL CIRC P Pump 30 bbl hi vis spacer, follow w/ new LSND mud. Pumping 700 gpm w/ 2600 psi, later slowed rate to 448 gpm w/ 1010 psi due to vac trucks keeping up. Continue to circulate @ 428 gpm w/ 860 psi. Page 12 of 26 i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 11:30 2.50 6,733 6,924 PROD1 DRILL DDRL P Directional drill 9 -7/8" prod hole f/ 6733' to 6924' MD (3923' TVD) - WOB4to12k - Pumping 700 to 750 gpm w/ 1890 to 2150 psi on btm, 1900 to 2190 psi off bottom, ECD's 10.21 to 10.19 ppg - Rotate180 rpm w/ 12 k ft Ibs of torque on btm, 11k ft Ibs of torque off bottom -PU 151k - SO 116k - Rot 126k - ART 1.59 hrs - Bit hrs 12.6 - Jars 21.92 hrs Max gas observed on bottom's up at 6735' was 557 units. 11:30 12:00 0.50 6,924 6,924 PROD1 RIGMNT SVRG P Service rig equipment. 12:00 00:00 12.00 6,924 7,709 PROD1 DRILL DDRL P Directional drill 9 -7/8" prod hole f/ 6924' to 7709' MD (3923' TVD) - WOB 2 to 10k - Pumping 700 to 750 gpm w/ 2130 to 2630 psi on btm, 2080 to 2620 psi off bottom, ECD's 10.17 to 10.69 ppg - Rotate180 rpm w/ 9 to 11k ft Ibs of torque on btm, 8 to 9k ft Ibs of torque off bottom -PU 150 to 160k - SO 116 to 120k - Rot 125 to135k - ART 6.42 hrs - Bit hrs 19.02 - Jars 28.34 hrs Max gas observed, @ 7487' (4179' TVD) was 95 units. 05/06/2010 Continue to directional drill 9 -7/8" production hole from 7709' to 8995' (4851'TVD), perform mud dilution (580 bbls), continue to directional drill 9 -7/8" hole from 8995' to 9472' (5072' TVD). Note: The radiator for the rig's Cat 3516 engine, was taken out of service for repairs while drilling at 8995', so limited the flow rate to 700 to 720 gpm and rotary to 100 to 110 rpm. John Patten with Sperry Sun re- modeled the predicted ECD's for the new parameters. Limited ROP to 130 feet per hour. 00:00 12:00 12.00 7,709 8,713 PROD1 DRILL DDRL P Directional drill 9 -7/8" production hole f/ 7,709' to 8,713' MD (4,727' TVD) - WOB3to20k - Pumping 750 gpm w/ 2890 psi on btm, ECD's 10.54 ppg - Rotate170 rpm w/ 13 k ft Ibs of torque on btm, 10 k ft Ibs of torque off bottom -PU 175 k - SO 126 k - Rot 140 k - ADT 8.25 hrs - Bit hrs 27.27 - Jars 36.59 hrs Max gas observed, @ 8614' (4179' TVD) was 77 units. Note: pumped 20 bbl nut plug sweeps @ 7765' and 8146'. Page 13 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:30 2.50 8,713 8,960 PROD1 DRILL DDRL P Directional drill 9 -7/8" production hole f/ 8713' to 8,960' MD (4836' TVD) - WOB5to10k - Pumping 750 gpm w/ 2880 psi on btm, ECD's 10.60 ppg - Rotate170 rpm w/ 12 k ft Ibs of torque on btm, 10 k ft lbs of torque off bottom -PU 175 k - SO 126 k - Rot 140 k - ADT 2.15 hrs - Bit hrs 29.42 - Jars 38.74 hrs Max gas observed, @ 8950' (4831' TVD) was 220 units. 14:30 15:00 0.50 8,960 8,960 PROD1 RIGMNT RGRP T Rig power down. Work, to be able to run with 3 Cat D398 engines and without the Cat D3516 (Radiator problem). 15:00 15:30 0.50 8,960 8,995 PROD1 DRILL DDRL P Directional drill 9 -7/8" production hole f/ 8960' to 8,995' MD (4851' TVD) - WOB10k - Pumping 750 gpm w/ 2890 psi on btm, ECD's 10.60 ppg - Rotate170 rpm w/ 12 k ft Ibs of torque on btm, 10 k ft lbs of torque off bottom -PU 177 k - SO 130 k - Rot 143 k - ADT .36 hrs - Bit hrs 29.78 - Jars 39.1 hrs 15:30 17:00 1.50 8,995 8,995 PROD1 DRILL CIRC P Perform a 580 bbl displacement of new 9.5 ppg mud. Circulate at 718 gpm with 2570 to 2300 psi. 17:00 00:00 7.00 8,995 9,472 PROD1 DRILL DDRL P Directional drill 9 -7/8" production hole f/ 8995' to 9472' MD (5072' TVD) - WOB5to10k - Pumping 700 gpm w/ 2520 psi on btm, ECD's 10.45 ppg - Rotate100 rpm w/ 12 to 16 k ft Ibs of torque on btm, 10 to 11.5 k ft lbs of torque off bottom -PU 180 k - SO 134 k- Rot 148 k - ADT 4.19 hrs - Bit hrs 33.97 - Jars 43.29 hrs Note: The radiator for the rig's Cat 3516 engine, was taken out of service for repairs while drilling at 8995', so limited the flow rate to 700 to 720 gpm and rotary to 100 to 110 rpm. John Patten with Sperry Sun re- modeled the predicted ECD's for the new parameters. Limited ROP to 130 feet per hr. Page 14 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/07/2010 24 hr Summary Directional drill 9 -7/8" production hole f/ 9472' to 10252' MD (5619' TVD)( controlled drilled 50' /hr starting at 9750'), Circulate 3 bottom's up. Lay down a single after first bottom's up, then set back a stand after another bottom's up, then pulling next stand for third bottom's up to 10031'. Pumping 700 gpm w/ 2820 to 2800 psi. Rotate 100 rpm w/ 14k ft Ibs torque. Monitor well- static. Backream out of the hole from 10031' to 8145'. Pumping 700 gpm w/ 2820 @ 10031', pumping 720 gpm w/ 2680 psi @ 8145'. Rotate 100 rpm w/ 14 initial to 12k ft Ibs of torque @ 8145'. Pulling speed 8 to 9 feet per minute due to the Toss of use of the one Cat D3516 engine (Radiator problem) to start with. At 8145' the pulling speed is 20 to 25' min. ECD's @ 8145' is 10.53 ppg. Max gas observed while backreaming was 113 units. Note: The radiator for the rig's Cat 3516 engine, was taken out of service for repairs while drilling at 8995', so limited the flow rate to 700 to 720 gpm and rotary to 100 to 110 rpm while drilling. 00:00 12:00 12.00 9,472 10,065 PROD1 DRILL DDRL P Directional drill 9 -7/8" production hole f/ 9,472' to 10,065' MD (5480' TVD) - WOB3to9k - Pumping 711 gpm w/ 2800 psi on btm, ECD's 10.64 to 10.45 ppg - Rotate100 rpm w/ 15 to 16 k ft Ibs of torque on btm, 9 to 13 k ft Ibs of torque off bottom -PU 215 k - SO 135 k - Rot 158 k - ADT 9.08 hrs, Total bit hrs 43.05, Total jar hrs 52.36 - max gas 440 units @ 10,041'. Note: Started control drilling for Togs at 9750' to 50' /hr penetration rate. A 40 bbl nut plug sweep pumped while drilling @ 9742'. 12:00 15:30 3.50 10,065 10,252 PROD1 DRILL DDRL P Directional drill 9 -7/8" production hole f/ 10065' to 10,252' MD (5619' TVD) - WOB3to14k - Pumping 712 gpm w/ 2860 psi on btm, ECD's 10.45 to 10.52 ppg - Rotate 100 rpm w/ 15 to 17 k ft Ibs of torque on btm, 13 to 14 k ft lbs of torque off bottom - PU216k -SO 140k- Rot 161 k - ADT 2.59 hrs - Totatl bit hrs 45.64, Total jar hrs 54.96 -max gas 192 units @ 10,065'. 15:30 18:00 2.50 10,252 10,031 PROD1 DRILL CIRC P Circulate 3 bottom's up. Lay down a single after first bottom's up, then set back a stand after another bottom's up, then pulling next stand for third bottom's up to 10031'. Pumping 700 gpm w/ 2820 to 2800 psi. Rotate 100 rpm w/ 14k ft Ibs torque. 18:00 18:15 0.25 10,031 10,031 PROD1 DRILL OWFF P Monitor well- static. Page 15 of 26 1 M Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:15 00:00 5.75 10,031 8,145 PROD1 DRILL REAM P Backream out of the hole from 10031' to 8145'. Pumping 700 gpm w/ 2820 @ 10031', pumping 720 gpm w/ 2680 psi @ 8145'. Rotate 100 rpm w/ 14 initial to 12k ft lbs of torque @ 8145'. Pulling speed 8 to 9 feet per minute due to the loss of use of the one Cat D3516 engine (Radiator problem) to start with. At 8145' the pulling speed is 20 to 25' min. ECD's @ 8145' is 10.53 ppg. Max gas observed while _ backreaming was 113 units. 05/08/2010 Continue to backream out of the hole from 8145' to 6730'. Pumping 720 gpm w/ 2680 @ 8145', pumping 720 gpm w/ 2450 psi @ 6730'. Rotate 100 rpm w/ 12 initial to 11.5k ft lbs of torque @ 6730'. At 6730' the pulling speed is 30' min. ECD's @ 6730' is 10.65 ppg. Max gas observed while backreaming was 53 units. Gas units @ 6730' while CBU was down to 31. CBU, monitor well- slight flow to static. Trip in the hole from 6730' to 7959', circulate annular volume f/ 1200' of hole (85 bbls), drop 2 -1/8" ball to open the commander circ tool © 6729' (bit depth 7959'). Open tool w/ 2200 psi, establish circ, increase rate to 900 gpm w/ 2140 psi- appear to be losing mud, shut down, mud returned. Run a stand in the hole from 7959', stage pumps from 520 gpm to 812 gpm - no losses, while back reaming from 8054' to 7959'. Stage pumps from 720 gpm w/ 1260 psi to 895 gpm w/ 1920 psi- appears to be normal- reaming from 7959' to 7854'. Continue to back ream from 7854' to 3521' pumping 895 gpm w/ 1920 to 1180 psi, rotating 35 to 40 rpm. Circulate bottom's up at 3521' pumping 900 gpm w/ 1170 psi. Monitor well- static. Pull out of the hole f/ 3521' to 666', lay down BHA to 136', PJSM on removing nuke sources, remove the sources, continue to L/D BHA, clean floor. Make up stack washing tool, pumping 670 gpm w/ 160 psi- wash stack. Pull FMC wear bushing, install FMC test plug. Remove upper pipe rams (4 -1/2" x 7 "), replace rams w/ 7 -5/8" rams. Note: The radiator for the rig's Cat 3516 engine is being repaired at the rig. 00:00 02:15 2.25 8,145 6,730 PROD1 DRILL REAM P Continue to backream out of the hole from 8145' to 6730'. Pumping 720 gpm w/ 2680 @ 8145', pumping 720 gpm w/ 2450 psi @ 6730'. Rotate 100 rpm w/ 12 initial to 11.5k ft lbs of torque @ 6730'. At 6730' the pulling speed is 30' min. ECD's @ 6730' is 10.65 ppg. Max gas observed while backreaming was 53 units. Gas units @ 6730' while CBU was down to 31. Note: The radiator for the rig's Cat 3516 engine, was taken out of service for repairs while drilling at 8995', so limited the flow rate to 700 to 720 gpm and rotary to 100 to 110 rpm while drilling. 02:15 02:45 0.50 6,730 6,730 PROD1 DRILL CIRC P Circulate bottom's up. Reciprocate f/ 6730' to 6825'. Rotating 100 rpm w/ 11.5 to 9.5k ft lbs of torque. Pumping 720 gpm w/ 2450 psi. Initial ECD's of 10.65 ppg, final of 10.55 ppg. 02:45 03:15 0.50 6,730 6,730 PROD1 DRILL OWFF P Monitor well- slight flow to static. 03:15 04:00 0.75 6,730 7,959 PROD1 DRILL TRIP P Trip in the hole from 6730' to 7959'. 04:00 04:15 0.25 7,959 7,959 PROD1 DRILL CIRC P Circulate to fill pipe, then 85 bbls total for annular volume of 1230' (distance f/ bit to circ sub). Page 16 of 26 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:15 04:45 0.50 7,959 7,959 PROD1 DRILL CIRC P Drop 2 -1/8" ball to open commander circ sub. Pump down at 2 bpm w/ 145 psi. Ball on seat after 36 bbls pumped. Presure up to 1400, then stage up in 200 psi increments. Sheared open at 2200 psi. 04:45 05:00 0.25 7,959 7,959 PROD1 DRILL CIRC P Establish circulation. Bring flow rate up to 900 gpm w/ 2140 psi. Appear to be tossing mud. Shut down. All mud returned 05:00 05:30 0.50 7,959 7,959 PROD1 DRILL CIRC P Run in the hole a stand from 7959' to 8054'. Circulate staging pumps up from 520 gpm w/ 750 psi- Totco 38% flow out, to 812 gpm w/ 1615 psi with 46% Totco flow out. Appears to be normal- no losses. Rotating 35 rpm w/ 8.5k ft Ibs of torque. Pulled out from 8054' to 7959'. 05:30 05:45 0.25 7,959 7,854 PROD1 DRILL CIRC P Circulate staging pumps up from 720 gpm w/ 1260 psi- Totco 45% flow out, to 895 gpm w/ 1920 psi with 49% Totco flow out. Appears to be normal- no losses. Rotating 35 rpm w/ 8.5k ft Ibs of torque. Pulled out from 7959' to 7854'. 05:45 12:00 6.25 7,854 5,228 PROD1 DRILL REAM P Continue to ream /pump out of the hole from 7854' to 5,228'. Rotate 35 to 40 rpm while pulling out. Pumping 895 gpm w/ 1920 to 1480 psi w/ 47 to 49% Totco flow out while pulling. Found washout (pinhole) on 2nd joint of stand 52. 12:00 14:00 2.00 5,228 3,521 PROD1 DRILL REAM P Continue to ream /pump out of the hole from 5228' to 3521'. Rotate 35 to 40 rpm while pulling out. Pumping 895 gpm w/ 1480 to 1180 psi w/ 47 to 49% Totco flow out while pulling. 14:00 14:15 0.25 3,521 3,521 PROD1 DRILL CIRC P Circulate bottom's up. Pumping 900 gpm w/ 1170 psi- Totco 49% flow out. Rotating 50 rpm w/ 4k ft Ibs of torque. 14:15 14:45 0.50 3,521 3,521 PROD1 DRILL OWFF P Monitor well- static. 14:45 16:45 2.00 3,521 666 PROD1 DRILL TRIP P out the Pull f h hole on elevators from 3521' to 666'. Layed down the 9 -7/8" ghost reamer when at 1230'. 5 balls are in ball catcher. Circ sub left in open position. 16:45 17:45 1.00 666 136 PROD1 DRILL PULD P Lay down HWDP, jars and 2 flex collars. 17:45 18:15 0.50 136 136 PROD1 DRILL SFTY P Pre job safety meeting on removing nuke sources. 18:15 20:15 2.00 136 136 PROD1 DRILL PULD P Pick up, then remove nuke sources. Then download Sperry Sun MWD. 20:15 21:45 1.50 136 0 PROD1 DRILL PULD P Continue to lay down BHA #3 from 136'. Break and grade bit. Page 17 of 26 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 22:30 0.75 0 0 PROD1 DRILL CIRC P Make up stack washing tool. Wash stack, pumping 670 gpm w/ 160 psi. Rotate 25 to 30 rpm. Work from below wear bushing to flush all ram cavities. 22:30 23:00 0.50 0 0 PROD1 WHDBO NUND P Pull FMC wear ring, install FMC test plug. 23:00 00:00 1.00 0 0 PROD1 WHDBO NUND P Remove upper pipe rams (4 -1/2" x 7 "), then install 7 -5/8" rams. 05/09/2010 Continue to change upper pipe rams (4 -1/2" x 7 "), replace rams w/ 7 -5/8" rams. Rigged up- attempemted to test, lower test plug leaking, PU /MU upper test plug, attempt to test 7 -5/8" rams, leaking by rams on low test, 3500 psi test OK. Open top doors, change upper seals on rams, close door. Successful test to 250 psi low and 3500 psi high, hold each test 5 minutes, chart test. Witness of test waived by AOGCC inspector Chuck Scheve. Pre job safety meeting on running 7 -5/8" 29.7 ppf L -80 BTC -m casing. Run casing per plan to 3430' (Jt # 85), circulate bottom's up, continuing to run casing f/ 3430' to 6040' (jt # 150), circulate 1.5 bottom's up, continue to run casing f/ 6040' to 8460' (jt # 210), circulate 1.5 bottom's up, continue to run casing f/ 8460' to 8580' at midnight. 00:00 02:00 2.00 0 0 PROD1 WHDBO NUND P Changing upper rams to 7 5/8 ". Rigged up to test. 02:00 07:30 5.50 0 0 PROD1 WHDBO BOPE T Rigged up and attempted to test casing rams. Tested high pressure OK but failed low pressure. Inspected doors and seals. Changed top seals on rams and reinstalled. 07:30 08:30 1.00 0 0 PROD1 WHDBO BOPE T Rigged up and tested 250/3500 psi OK. Rigged down test Jt and blew down test lines. 08:30 09:00 0.50 0 0 COMPZ CASING SFTY P PJSM to run casing. 09:00 12:00 3.00 0 480 COMPZ CASING RNCS P Picked up and ran 12 Jts 7 5/8" L -80 29.7# BTCM casing. (Checked floats OK). Bakerlocked first 4 Jts and ran Hydroform Centralizers per program. 12:00 15:00 3.00 480 3,430 COMPZ CASING RNCS P Continue to run 7 -5/8" 29.7 ppf L -80 BTC -m casing f/ 480' to 3430' (jt # 85 in the hole). Fill pipe w/ Frank's fillup tool. 15:00 16:15 1.25 3,430 3,430 COMPZ CASING CIRC P Circulate bottom's up. Stage pumps up f/ 2 bpm w/ 240 psi to 5 bpm w/ 260 psi. 16:15 18:45 2.50 3,430 6,040 COMPZ CASING RNCS P Continue to run 7 -5/8" 29.7 ppf L -80 BTC -m casing f/ 3430' to 6040' (jt # 150 in the hole). Fill pipe w/ Frank's fillup tool. 18:45 20:00 1.25 6,040 6,040 COMPZ CASING CIRC P Circulate bottom's up. Stage pumps up f/ 3 bpm w/ 260 psi- 15% Totco flow. After 20 bbls go to 4 bpm w/ 300 psi -19% Totco flow, after 30 bbls go to 5 bpm w/ 370 psi- 21 -22% Totco flow out. After pumping 45 bbls total volume, increase rate to 6 bpm w/ 430 to 450 psi -24 to 26% Totco flow out. Circulated 315 bbls total @ 6 bpm. Final MW out 9.6 +. Initial PU wt 170k, SO wt 105k. Final PU wt 157k, SO wt 115k. Max EPOCH gas 102 units. Page 18 of 26 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 22:15 2.25 6,040 8,460 COMPZ CASING RNCS P _ Continue to run 7 -5/8" 29.7 ppf L -80 BTC -m casing f/ 6040' to 8460' (jt # 210 in the hole). Fill pipe w/ Frank's fillup tool. 22:15 23:45 1.50 8,460 8,460 COMPZ CASING CIRC P Circulate bottom's up. Stage pumps up f/ 3 bpm w/ 260 psi- 15% Totco flow. After 25 bbls go to 4 bpm w/ 350 psi -19% Totco flow, after 35 bbls go to 5 bpm w/ 380 psi- 21 -22% Totco flow out. After pumping 50 bbls total volume, increase rate to 6 bpm w/ 470 psi -25 to 27% Totco flow out. Circulated 477 bbls total @ 6 bpm. Final MW out 9.5 +. Initial PU wt 215k, SO wt 127k. Final PU wt 200k, SO wt 130k. Max EPOCH gas 182 units. 23:45 00:00 0.25 8,460 8,580 COMPZ CASING RNCS P Continue to run 7 -5/8" 29.7 ppf L -80 BTC -m casing f/ 8460' to 8580' (jt # 213 in the hole). Fill pipe w/ Frank's fillup tool. 05/10/2010 Continue to run casing 7 -5/8" 29.7 ppf L -80 BTC -m casing f/ 8580 to 10230' (jt # 254), lay down Frank's fillup tool, blow down the top drive, Make up 20' pup jt, run in the hole tag fill at 10248', Make up dowel) crossover, cement head and circulating lines. Initiate circulation stage up f/ 3 bpm to 7 bpm, reciprocate from 10250' to 10220'. PJSM on cementing while circulating. Switched to Schlumberger - Pump 5 bbls H2O - Test lines to 3000 psi - OK - Cont. work pipe 30' strokes. -PUW 250k SOW 130 -Pump 35 bbls CW100 @ 5 bpm, 500 psi -Pump 50 bbls 11.6 ppg Mud Push spacer @ 5 bpm, 520 psi -Drop btm plug -Pump 155 bbls tail at 15.8 ppg CI G (1.17 yield) - 4 bpm, 500 psi -Drop top plug - Pump 20 bbls H2O w/ DS Washed up before dropping top plug. Displace w/ Rig pumps using seawater - -7 bpm w/ 1010 psi - Slow to 4 bpm 700 psi -Bump plug w/ 4460 stks (446 bbls) - Pressure to 1700 psi - Hold 3 min -Bleed pressure - Check floats - OK -NOTE: CIP at 10:00 hrs -Full returns throughout pumping proccess Rig down cement head and lines, prep to lift stack, monitor well on the trip tank while WOC f/ 4 hrs. Nipple down (PU stack), set emergency slips w/ 170k on slips, cut casing, dress, install packoff, torque to 450 ft lbs, NU, test packoff to 3800 psi f/ 10 minutes. Continue to niple up. PJSM, change top pipe rams f/ 7 -5/8" to 2 -7/8" x 5" VBR's, PJSM, RU to test BOPE. 00:00 03:00 3.00 8,580 10,230 COMPZ CASING RNCS P Continue to run 7 -5/8" 29.7 ppf L -80 BTC -m casing f/ 8460' to 8580' (jt # 213 in the hole). Fill pipe w/ Frank's fillup tool. 03:00 03:15 0.25 10,230 10,230 COMPZ CASING PULD P Lay down frank's fillup tool. Blow down the top drive. 03:15 03:30 0.25 10,230 10,248 COMPZ CASING RNCS P Pick up/ Make up 20' pup joint. RIH f/ 10230' to tag fill at 10248'. PU wt 280k, SO wt 137k. 03:30 03:45 0.25 10,248 10,248 COMPZ CEMEN RURD P Make up Dowell/ Schlumberger crossover. 03:45 04:30 0.75 10,248 10,248 COMPZ CEMEN" RURD P Make up Dowell cement head w/ top and bottom plugs loaded. rig up circulating lines. Secure lines and head w/ safety lines. Page 19 of 26 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 06:30 2.00 10,248 10,250 COMPZ CEMEN" CIRC P Initiate circulation, pumping 3 bpm w/ 330 psi -13% Totco flow, stage up to 4 bpm after 30 bbls. 4 bpm w/ 410 psi- Totco flow 18 to 19 %. After 60 bbls pumped stage to 5 bpm w/ 510 psi- 21 to 22% Totco flow. Stage up to 6 bpm after 120 bbls pumped. 6 bpm w/ 600 psi -25% Totco flow. After a total of 270 bbls were pumped, stage pumps to 7 bpm w/ 740 psi -27% Totco flow. Initial PU wt 265k, SO wt 140k. Final PU wt 240k, SO 137k. Recip 30' stroke and wash fill to 10250'. Working f/ 10250' to 10230'. Max EPOCH gas 275 units. 06:30 07:00 0.50 10,250 10,250 COMPZ CEMEN" SFTY P Continue to circulate while holding PJSM for cementing. Circulated a total of 920 bbls. Working pipe f/ 10250' to 10230'. 07:00 08:45 1.75 10,250 10,250 COMPZ CEMEN" CMNT P Switched to Schlumberger - Pump 5 bbls H2O - Test lines to 3000 psi - OK - Cont. work pipe 30' strokes. -PUW 250k SOW 130 - Pump 35 bbls CW100 @ 5 bpm, 500 psi ei -Pump 50 bbls 11.6 ppg Mud Push spacer @ 5 bpm, 520 psi Ly� -Drop btm plug ` Pumg155 bbls tail at 15.8 ppq CI G (1.17 yield) - 4 bpm, 500 psi - Drop top plug - Pump 20 bbls H2O w/ DS Washed up before dropping top plug. -Full returns throughout pumping proccess 08:45 10:00 1.25 10,250 10,250 COMPZ CEMEN' DISP P Displace w/ Rig pumps using seawater - -7 bpm w/ 1010 psi - Slow to 4 bpm 700 psi -Bump plug w/ 4460 stks (446 bbls) - Pressure to 1700 psi - Hold 3 min -Bleed pressure - Check floats - OK -NOTE: CIP at 10:00 hrs 10:00 12:00 2.00 10,250 10,250 COMPZ CEMEN" RURD P Rig down cement head and lines, circulate 35 bbl SAPP pill in BOP stack, blow down kill and choke lines. While wait on cement: Monitor well on the trip tank. Clean and clear rig floor. 12:00 14:00 2.00 10,250 10,250 COMPZ CEMEN" WOC P While WOC: Monitor well on the trip tank. Load, strap and drift 3 -1/2" completion tubing. Prepare to PU stack and set slips. Page 20 of 26 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 16:00 2.00 10,250 10,247 COMPZ WHDBO NUND P Nipple down BOP: PU stack w/ the FMC tubing spool. Set FMC emergency slips w/ 205k on weight indicator. Blocks and top drive = 35k of this weight. 170k on slips. 16:00 17:00 1.00 10,247 0 COMPZ WHDBO CPBO P Cut casing with Wach's cutter. Dress stub. 17:00 18:30 1.50 0 0 COMPZ WHDBO NUND P Rig up and install FMC packoff. Torque Iockdown screws to 450 ft Ibs of torque. 18:30 19:15 0.75 0 0 COMPZ WHDBO NUND P Nipple up tubing spool. Torque w/ ez- torque wrench. 19:15 19:30 0.25 0 0 COMPZ WHDBO PRTS P Test packoff to 3800 psi f/ 10 minutes. Witnessed by Rig Supervisor. 19:30 20:30 1.00 0 0 COMPZ WHDBO NUND P Continue to nipple up: adjust turnbuckles and install riser. 20:30 23:00 2.50 0 0 COMPZ WHDBO NUND P Change top pipe rams from 7 -5/8" to 2 -7/8" x 5" variables. 23:00 23:15 0.25 0 0 COMPZ WHDBO BOPE P Pre job safety meeting on rigging up to test BOPE. 23:15 00:00 0.75 0 0 COMPZ WHDBO BOPE P Rig up to test BOPE. 05/11/2010 Continue to rig up to test BOPE, PJSM, Test BOPE. Witness of test waived by AOGCC inspector Chuck Scheve. Tested 250 psi low and 3500 psi high w/ 3 -1/2" test joint. Chart all tests. Performing complete BOP test. Top (2 -7/8" x 5 ") and bottom (3 -1/2" x 6 ") pipe rams, blinds, annular, choke, choke and kill lines, accumulator. Note: Prior to all tests complete, will start freeze protect of 10 -3/4" x 7 -5/8 ", then sim ops with BOP testing. PJSM, Test lines to 2000 psi. Perform annular LOT, broke down at 415 psi w/ EMW of 12.9 ppg (9.6 ppg mud in the hole, estimated top of cement 7750' (4298' TVD)). Then finish pumping a total of 10 bbls water. Swap to sea water and continue to pump 154 bbls of seawater, while switching back to BOP testing. Continue to test BOPE while flusing and freeze protecting 10 -3/4" x 7 -5/8" annulus. Rig down testing equipment. Blow down choke and kill lines. Pull test plug. Note: Annular did not test. Will change the element after wire line logging (CBL), then test annular to 250 psi low and 3500 psi high. Spot Halliburton e line unit. PJSM w/ Halliburton and rig crew. Calibrate logging tools in free pipe, Con't running in the hole to 1600', make logging pass from 1600', POOH to surface, tighten centralizers. RIH w/ logging tools to 10151' WLM (tagged 15' higher than casing measurements)), log up to 7000'. POOH w/ wireline tools. Located TOC 7621'. Logged to 7000'. Rig down logging tools and equipment. PJSM, Change out the element in the 13 -5/8" annular. Break cap, remove cap, clean up, install new element and Head seal. Rig up to test Annular with a 3 -1/2" test joint. Test annular to 250 psi low and 3500 psi high. Charted tests, held each test 5 minutes. Rig down testing equipment, pull FMC upper test plug. Rig up to run 3 -1/2" completion. 00:00 00:45 0.75 COMPZ WHDBO BOPE P Continue to rig up to test BOPE. Change dies in the iron roughneck to pi.) make up testing equipment. ( 00:45 01:00 0.25 COMPZ WHDBO SFTY P Pre job safety meeting on testing BOP's. Page 21 of 26 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 04:45 3.75 COMPZ WHDBO BOPE P Test BOPE. Witness of test waived by AOGCC inspector Chuck Scheve. Tested 250 psi low and 3500 psi high w/ 3 -1/2" test joint. Chart all tests. Performing complete BOP test. Top (2 -7/8" x 5 ") and bottom (3 -1/2" x 6 ") pipe rams, blinds, annular, choke, choke and kill lines, accumulator. Note: tests are not complete at this time. Will start freeze protect of 10 -3/4" x 7 -5/8 ", then sim ops with BOP testing. 04:45 05:00 0.25 COMPZ WHDBO SFTY P Pre job safety meeting on flush & freeze protecting 10 -3/4" x 7 -5/8" annulus. 05:00 05:30 0.50 COMPZ WHDBO FRZP P Test lines to 2000 psi. Perform La annular LOT, broke down at 415 psi w/ EMW of 12.9 ppg (9.6 ppg mud in the hole, estimated top of cement 7750' (4298' TVD)). Then finish pumping a total of 10 bbls water. Swap to sea water and continue to pump 154 bbls of seawater, while switching back to BOP testing. 05:30 09:00 3.50 COMPZ WHDBO BOPE P Continue to test BOPE while flusing and freeze protecting 10 -3/4" x 7 -5/8" annulus. 09:00 09:30 0.50 COMPZ WHDBO BOPE P Rig down testing equipment. Blow down choke and kill lines. Pull test plug. Note: Annular did not test. Will change the element after wire line logging (CBL), then test annular to 250 psi low and 2500 psi high. 09:30 10:00 0.50 COMPZ DRILL SFTY P Spot Halliburton e line unit. Pre job safety meeting w/ Halliburton and rig crew. 10:00 11:00 1.00 COMPZ DRILL RURD P PU a line tools, Rig up. 11:00 12:00 1.00 0 0 COMPZ DRILL ELOG P Run in the hole with logging tools: C$ Centralizer, CCL, logging tool, centralizer, GR tool, centralizer. Calibrate logging tools in free pipe 12:00 13:00 1.00 0 0 COMPZ DRILL ELOG P Continue running in the hole to 1600', make logging pass from 1600', POOH to surface, tighten centralizers. 13:00 16:00 3.00 0 0 COMPZ DRILL ELOG P Run in the hole with logging tools to 10151' WLM (tagged 15' higher than casing measurements)), log up to 7000'. POOH w/ wireline tools. Located TOC 7621'. Logged to 7000'. Rig down logging tools and equipment. 16:00 16:15 0.25 COMPZ RIGMNT SFTY T Pre job sfety meeting on changing the element in the 13 -5/8" Hydril annular. Page 22 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 21:00 4.75 COMPZ RIGMNT EQRP T Change out the element in the 13 -5/8" annular. Break cap, remove cap, clean up, install new element and Head seal. 21:00 22:00 1.00 COMPZ WHDBO BOPE P Rig up to test Annular with a 3 -1/2" test joint. 22:00 22:30 0.50 COMPZ WHDBO BOPE P Test annular to 250 psi low and 3500 psi high. Charted tests, held each test 5 minutes. 22:30 23:00 0.50 COMPZ WHDBO BOPE P Rig down testing equipment, pull FMC upper test plug. 23:00 00:00 1.00 COMPZ RPCOM RCST P Rig up to run 3 -1/2" completion. 05/12/2010 Continue to rig up to run 3 -1/2" completion. PJSM on running completion. Pick up/ Make up WLEG with pup jt, 1 jt 9.3 ppf L -80 EUE -m tubing and Baker FHL packer assembly. Pull out to above rig floor. Note: All componets below paker are NOT Bakerlocked. Pre job safety meeting on tesing 7 -5/8" casing. Test 7 -5/8" 29.7 ppf L -80 BTC -m casing to 3625 psi. Hold test 30 minutes. Chart test. Continue to run 3 -1/2" 9.3 ppf L -80 EUE -8rd mod completion per detail from 76' to 8791'. Average MU torque 3000 ft lbs of torque. Use Jet lube Run -N -Seal dope. Note: Little Red pumped 85 bbls diesel in the 10 -3/4" x 7 -5/8" annulus for freeze protection to 2166' MD (1825' TVD). Continue running 3 -1/2" tubing to 9800', rig up, then pump 95 bbls of inhibited sea water to 9514' on the annulus side, pumping 3 bpm w/ 230 psi.drop ball and rod w/ rollers, pressure to 2200 psi to set packer, bleed to 1500 psi, pickup to shear PBR, rig down circ equipment, lay down 8' pup and joint # 306 & # 305, install 6.32' space out pup, joint # 305, then FMC tubing hanger and landing joint. Land tubing w/ 2' space out, torque lockdown screws to 450 psi. Lay down landing joint. Pressure test surface lines to 3500 psi, then test tubing to 3500 psi f/ 30 minutes, bleed pressure to 2000 psi, then test annulus to 3000 psi f/ 30 minutes f/ 30 minutes. Bleed tubing pressure and observed shear with 1350 psi on tubing (1650 differential). Pump 5 bbls of seawater each direction through shear valve. Charted tests, rig down. Install type H back pressure valve, nipple down BOPE, Nipple up FMC 11' x 3- 1/16" adapter w/ WKM 3 -1/8" 5m tree. Test tubing hanger void to 250 psi f/ 10 min., then test to 5000 psi f/ 10 minutes. Witness by Rig supervisor. Pull back pressure valve, install two way check valve. Fill tree with diesel. Testing tree to 250 psi low f/ 10 minutes, then testing to 5000 psi at midnight Charted tests. 00:00 00:30 0.50 0 0 COMPZ RPCOM RURD P Continue to rig up to run 3 -1/2" completion. 00:30 01:00 0.50 0 0 COMPZ RPCOM SFTY P Pre job safety meeting on running completion. 01:00 01:30 0.50 0 0 COMPZ RPCOM RCST P Pick up/ Make up WLEG with pup jt, 1 jt 9.3 ppf L -80 EUE -m tubing and Baker FHL packer assembly. Pull out to above rig floor. Note: All componets below paker are NOT Bakerlocked. 01:30 01:45 0.25 0 0 COMPZ RPCOM SFTY P Pre job safety meeting on tesing 7 -5/8" casing. 01:45 02:30 0.75 0 0 COMPZ RPCOM PRTS P Test 7 -5/8" 29.7 ppf L -80 BTC -m casing to 3625 psi. H old test 30 minutes. Chart test. Page 23 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 12:00 9.50 76 8,791 COMPZ RPCOM RCST P Continue to run 3 -1/2" 9.3 ppf L -80 EUE -8rd mod completion per detail from 76' to 8791'. Average MU torque 3000 ft Ibs of torque. Use Jet tube Run -N -Seal dope. Note: Little Red pumped 85 bbis diesel in the 10 -3/4" x 7 -5/8" annulus for freeze protection to 2166' MD (1825' TVD). 12:00 13:00 1.00 8,791 9,800 COMPZ RPCOM RCST P Continue to run 3 -1/2" 9.3 ppf L -80 EUE mod completion per detail , from 8791' to 9800'. Average MU torque 3000 ft Ibs of torque. Use Jet tube Run -N -Seal dope. PU wt 110k, SO wt 75k. 13:00 13:30 0.50 9,800 9,800 COMPZ RPCOM RURD P Rig up circulating equipemnt. 13:30 14:00 0.50 9,800 9,800 COMPZ RPCOM CRIH P Pump 95 bbis of inhibited sea water down the tubing. to place top of inhibited seawater @ 9514' on the annulus side. Pumping 3 bpm w/ 230 psi. 14:00 14:30 0.50 9,800 9,800 COMPZ RPCOM PACK P Drop ball and rod w/ rollers. Let fall for 15 minutes. Pressure to 2200 psi to set Baker FHLEacker. Bleed pressure to 1500 psi, then pick up and shear PBR w/ 130k PU wt. 14:30 14:45 0.25 9,800 9,800 COMPZ RPCOM RURD P Rig down circulating equipment. 14:45 15:30 0.75 9,800 9,800 COMPZ RPCOM HOSO P Lay down 8' pup joint, jt # 306 and joint #305. Make up 6.01' pup joint, then joint # 305, then FMC hanger and landing joint. PU wt 110k, SO wt 75k, Blocks 40k. 15:30 16:00 0.50 9,800 0 COMPZ RPCOM HOSO P Run in hole and land FMC 3 -1/2" x 11" hanger. Run in lockdown screws, torque screws to 450 ft Ibs of torque. Lay down landing joint. 16:00 18:00 2.00 0 0 COMPZ RPCOM PRTS P Pressure test surface lines to 3500 psi. Pump down tubing and test to 3500 psi f/ 30 minutes. Bleed pressure to 2000 psi, then line up and test annulus to 3000 psi f/ 30 minutes. Bleed tubing pressure and observed shear valve in bottom GLM shear w/ 1350 psi on tubing ( 1650 differential). Reverse circ 2.5 bpm w/ 2000 psi , then pump down the tubing 2.5 bpm w/ 1770 psi. Pumped 5 bbis each way. Charted all tests. 18:00 19:30 1.50 COMPZ WHDBO NUND P Install BPV, blow down surface lines. Nipple down BOPE. 19:30 21:00 1.50 COMPZ WHDBO NUND P Nipple up FMC 11 "x 3- 1/16" 5m adapter and WKM 3 -1/8" 5m tree. 21:00 21:45 0.75 COMPZ WHDBO PRTS P Test tubing hanger void to 250 psi f/ 10 minutes, then test to 5000 psi f/ 10 minutes. Witness of test by rig supervisor. Page 24 of 26 ! i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 22:00 0.25 COMPZ WHDBO SEQP P Pull Type H back pressure valve. Install Two Way Check. 22:00 22:15 0.25 COMPZ WHDBO OTHR P Fill tree w/ diesel. 22:15 00:00 1.75 COMPZ WHDBO PRTS P Test tree to 250 psi f/ 10 minutes, test to 5000 psi f/ 10 minutes. Chart tests. 05/13/2010 Testing tree to 5000 psi , hold test 10 minutes. Charted tests. Remove 4" valves from conductor, install guage on 10 -3/4" x 7 -5/8" annulus (OA), rig up mousehole to lay down 102 stands of 5" drill pipe. Pre job safety meeting on laying down drill pipe. Lay down 30 stands of 5 "drill pipe. Service rig- clean up spill in pipe shed. Continue to lay down 6 more stands of drill pipe. Change dies in iron roughneck, break tight connections requiring 45k ft Ibs to break. Lay down mouse hole, remove tree cap, pull type "H" back pressure valve, rig up to freeze protect w/ Little Red pumping diesel. Pressure test lines to 3500 psi, then freeze protect- pumping 111 bbls of diesel down the annulus @ 1 bpm w/ 300 psi initial and 600 psi final. "U" tube diesel to the tubing, suck down lines, drain tree, install BPV, blow down lines, secure tree. Install mousehole in the rotary table, continue laying down all 5" drill pipe from the derrick. Secure tree /wellhead, install all guages. 00:00 00:30 0.50 COMPZ WHDBO PRTS P Test tree to 250 psi f/ 10 minutes, test to 5000 psi f/ 10 minutes. Chart tests. 00:30 01:00 0.50 COMPZ WHDBO SEQP P Rig down testing equipment, drain tree, pull two way check, set type "H" back P ressure valve. 01:00 01:15 0.25 COMPZ DRILL RURD P Remove 4" cementing lines from the conductor. Install guage flange on the OA (10 -3/4" x 7- 5/8 "). Set mouse hole in the rotary table and secure along the side of the tree in the cellar. 01:15 01:30 0.25 COMPZ DRILL SFTY P Pre job safety meeting on laying down 5" drill pipe from the derrick using mousehole in the rotarty table. 01:30 05:00 3.50 COMPZ DRILL PULD P Lay down 30 stands of 5"drill pipe. 05:00 05:30 0.50 COMPZ RIGMNT SVRG P Service rig- clean up spill in pipe shed. Hyd cylinder on the pipe handling machine leaked 3 quarts of oil. 05:30 06:30 1.00 COMPZ DRILL PULD P Continue to lay down 6 more stands of drill pipe. 06:30 07:30 1.00 COMPZ DRILL PULD P Change dies in iron roughneck, break tight connections requiring 45k ft Ibs to break. 07:30 08:30 1.00 COMPZ DRILL FRZP P Lay down mouse hole, remove tree cap, pull type "H" back pressure valve, rig up to freeze protect w/ Little Red pumping diesel. Pressure test lines to 3500 psi. OA 600 psi, IA zero psi, tubing zero psi. 08:30 10:30 2.00 COMPZ DRILL FRZP P Freeze protect- pumping 111 bbls of diesel down the annulus @ 1 bpm w/ 300 psi initial and 600 psi final. 10:30 12:00 1.50 COMPZ DRILL FRZP P Allow diesel to "U" tube from the annulus to the tubing. 12:00 13:00 1.00 COMPZ DRILL FRZP P Suck down lines, drain tree, install BPV, blow down lines, secure tree. Page 25 of 26 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 23:00 10.00 COMPZ DRILL PULD P Install mousehole in the rotary table, continue laying down all 5" drill pipe from the derrick. Secure tree/wellhead, install all guages. 23:00 00:00 1.00 COMPZ DRILL OTHR P Secure tree/wellhead, install all guages. 3 -1/2" tubing pressure = zero, 7 -5/8" x 3 -1/2" pressure = zero, 10 -3/4" x 7 -5/8" = 600 psi Release rig @ 24:00 5/13/2010 Page 26 of 26 DATE SUMMARY • 2L -310 Post Rig Well Work 6/6/10 PULLED BALL & ROD @ 9781' RKB. PULLED SOV @ 9617' RKB. REPLACED WITH DMY VLV. PULLED RHC PLUG BODY @ 9790' RKB. IN PROGRESS. 6/7/10 OPENED CMU @ 9671' RKB. CIRC OUT 400 BBLS DIESEL TBG TO IA. ** *CLEAN RETURNS * * *. CLOSED CMU @ 9671' RKB. MITIA TO 3500 #. ** *PASS ***. TAG TD WITH 23.5' X 2.5" DMY GUNS © 10133' SLM. READY FOR E -LINE. 6/8/10 PERFORATED BERMUDA SAND 10005 -10019 USING 2.5 " PROSPECTOR RDX DP CHARGES, 6 SPF, 60 DEG PHASING. PERFORATED OVERBALANCED WITH 3000 PSI TUBING PRESSURE AT SURFACE. 6/9/10 PERFORMED STATIC BOTTOM HOLE PRESSURE SURVEY AT MID -PERFS AND AT GLM #3. RESULTS: 2346 PSI AND 141 DEGF AT MID -PERFS 10012', 2201 PSI AND 133 DEGF AT GLM #3 9617'. BOTH SURVEYS TAKEN FOR 30 MINUTES. 6/10/10 PUMPED A TOTAI nF 942,621 LBS OF 16/20 CARBOLITE PLACING 240,731 LBS BEHIND PIPE (PUMPED 2602 BBL OF FLUID). COMPLETED FRAC WITH 9 PPA ON FORMATION. FRAC PUMPED TO 103% DESIGN. FREEZE PROTECTED WELL WITH 44 BBL OF DIESEL. 6/12/10 ATTEMPT TO DRIFT TBG 2.76 ", UNABLE TO WORK PAST 9400' SLM. ATTEMPT TO SET SLIP STOP CATCHER BELOW STA# 2 @ 8717' RKB, UNABLE TO WORK PAST 8000' SLM. JOB SUSPENDED. 6/14/10 PERFORM POST FRAC CLEAN OUT TO 10,050' CTMD (BTM PERF @ 10019' ) W/ SLICK DIESEL AND DIESEL GEL. ABLE TO MAINTAIN 1:1 RETURNS WITH FAIR AMOUNT OF FRAC SAND IN RETURNS. WELL READY FOR SLICKLINE. 6/15/10 GAUGED TBG TO 2.79" TO D NIPPLE @ 9790' RKB. SET CATCHER @ 9790' RKB. PULLED DV @ 9617' RKB, SET OV. PULLED CATCHER @ 9790' RKB. READY FOR FLOW BACK. II • • fi j . ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2L_Pad 2L -310 50103206160000 !: ',- , Sperry Drilling Services Definitive Survey Report 17 May, 2010 1 1 I 11 : i i •. 1 ;g .. Sperry Drilling Services a • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 2L -310 Project: Kuparuk River Unit TVD Reference: 2L -310 @ 141.90ft (D16 (114.9 +25.5 +1.5)) Site: Kuparuk 2L_Pad MD Reference: 2L -310 @ 141.90ft (D16 (114.9 +25.5 +1.5)) Well: 2L - 310 North Reference: True Wellbore: 2L - 310 Survey Calculation Method: Minimum Curvature Design: 2L -310 Database: CPAI EDM Production Project Kuparuk River Unit Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2L - 310 Well Position +N / -S 0.00 ft Northing: 5,927,678.28ft Latitude: 70° 12' 48.103 N +E/ - 0.00 ft Easting: 461,005.00 ft Longitude: 150° 18' 52.163 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 114.90ft Wellbore 2L - 310 1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) (°) (nT) BGGM2009 4/20/2010 21.42 80.70 57,629 Design 2L - 310 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.00 i Vertical Section: Depth From (TVD) +WS +E/-W Direction (ft) (ft) (ft) r) 27.00 0.00 0.00 97.55 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 100.00 817.00 2L -310 (Gyro Run1) (2L -310) GYD -GC -SS Gyrodata gyro single shots 4/25/2010 1; 911.00 1,190.00 2L -310 (Gryo Run2) (2L -310) GYD -GC -MS Gyrodata gyrocompassing m/s 4/26/2010 t 1,270.36 3,484.26 2L -310 (R100) (2L -310) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 4/26/2010 1; 3,575.00 4,951.30 2L -310 (R200) (2L -310) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 5/1/2010 12: 5,001.38 10,214.78 2L -310 (R300) (2L -310) MWD +IFR- AK- CAZ -SC MWD +IFR AK CAZ SCC 5/3/2010 12: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +e -W Northing Easting DLS Section (ft) r) (1 (ft) (ft) (ft) (ft) (ft) (ft) (° /100') (ft) Survey Tool Name I 27.00 0.00 0.00 27.00 - 114.90 0.00 0.00 5,927,678.28 461,005.00 0.00 0.00 UNDEFINED I 100.00 0.42 304.41 100.00 -41.90 0.15 -0.22 5,927,678.43 461,004.78 0.58 -0.24 GYD -GC -SS (1) I 172.00 0.46 303.48 172.00 30.10 0.46 -0.68 5,927,678.74 461,004.32 0.06 -0.73 GYD -GC -SS (1) 261.00 0.96 88.77 260.99 119.09 0.67 -0.23 5,927,678.95 461,004.77 1.53 -0.32 GYD -GC -SS (1) 351.00 2.93 85.26 350.94 209.04 0.88 2.81 5,927,679.15 461,007.82 2.19 2.67 GYD -GC -SS (1) 440.00 4.06 84.82 439.77 297.87 1.35 8.22 5,927,679.59 461,013.22 1.27 7.97 GYD -GC -SS (1) 531.00 4.63 83.03 530.51 388.61 2.09 15.07 5,927,680.29 461,020.08 0.64 14.67 GYD -GC -SS (1) 626.00 4.50 83.20 625.21 483.31 2.99 22.58 5,927,681.16 461,027.59 0.14 21.99 GYD -GC -SS (1) 722.00 5.36 84.65 720.85 578.95 3.86 30.78 5,927,681.98 461,035.80 0.91 30.01 GYD -GC -SS (1) 817.00 9.32 93.03 815.06 673.16 3.87 42.89 5,927,681.92 461,047.90 4.31 42.01 GYD -GC -SS (1) 5/17/2010 9:29:56AM Page 2 COMPASS 2003.16 Build 69 0 • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co - ordinate Reference: Well 2L -310 Project Kuparuk River Unit TVD Reference: 2L -310 © 141.90ft (D16 (114.9 +25.5 +1.5)) Site: Kuparuk 2L_Pad MD Reference: 2L -310 © 141.90ft (D16 (114.9 +25.5 +1.5)) Well: 2L - 310 North Reference: True Welibore: 2L - 310 Survey Calculation Method: Minimum Curvature Design: 2L - 310 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N!S +E! -W Northing Easting DLS Section (ft) (°) r) (ft) (ft) (ft) (ft) (ft) (ft) r!100') (ft) Survey Tool Name 911.00 15.38 101.01 906.84 764.94 1.08 62.75 5,927,679.04 461,067.74 6.68 62.06 GYD -GC -MS (2) 957.00 17.70 103.63 950.94 809.04 -1.73 75.53 5,927,676.16 461,080.51 5.30 75.10 GYD -GC -MS (2) 1,004.00 20.39 104.98 995.36 853.46 -5.53 90.39 5,927,672.28 461,095.34 5.80 90.33 GYD -GC -MS (2) 1,051.00 22.30 103.58 1,039.14 897.24 -9.74 106.97 5,927,667.98 461,111.90 4.21 107.32 GYD -GC -MS (2) 1,098.00 23.04 102.55 1,082.51 940.61 -13.84 124.61 5,927,663.80 461,129.52 1.79 125.35 GYD -GC -MS (2) 1,190.00 24.29 99.88 1,166.77 1,024.87 -21.00 160.83 5,927,656.46 461,165.70 1.79 162.19 GYD -GC -MS (2) 1,270.36 27.39 89.05 1,239.13 1,097.23 -23.53 195.62 5,927,653.75 461,200.48 7.01 197.02 MWD +IFR -AK- CAZ -SC (3) 1,313.99 29.14 86.98 1,277.55 1,135.65 -22.80 216.27 5,927,654.36 461,221.12 4.60 217.39 MWD +IFR -AK- CAZ -SC (3) 1,365.60 30.48 87.21 1,322.33 1,180.43 -21.50 241.89 5,927,655.53 461,246.75 2.61 242.62 MWD +IFR -AK- CAZ -SC (3) 1,459.38 34.61 83.60 1,401.38 1,259.48 -17.37 292.14 5,927,659.40 461,297.01 4.86 291.89 MWD +IFR -AK- CAZ -SC (3) 1,554.19 43.39 78.78 1,475.00 1,333.10 -8.02 350.97 5,927,668.45 461,355.88 9.79 348.98 MWD +IFR -AK- CAZ -SC (3) 1,604.52 47.50 78.89 1,510.31 1,368.41 -1.07 386.15 5,927,675.21 461,391.09 8.17 382.94 MWD +IFR -AK- CAZ -SC (3) 1,649.14 47.45 78.46 1,540.47 1,398.57 5.38 418.39 5,927,681.50 461,423.37 0.72 414.06 MWD +IFR -AK- CAZ -SC (3) 1,744.06 50.80 83.60 1,602.60 1,460.70 16.49 489.24 5,927,692.24 461,494.27 5.40 482.84 MWD +IFR -AK- CAZ -SC (3) 1,795.89 54.23 87.40 1,634.14 1,492.24 19.68 530.23 5,927,695.22 461,535.27 8.81 523.04 MWD +IFR -AK- CAZ -SC (3) 1,838.73 55.10 87.98 1,658.92 1,517.02 21.09 565.15 5,927,696.45 461,570.19 2.31 557.48 MWD +IFR -AK- CAZ -SC (3) 1,931.50 57.43 89.77 1,710.44 1,568.54 22.59 642.27 5,927,697.55 461,647.31 2.98 633.74 MWD +IFR -AK- CAZ -SC (3) 2,028.44 59.81 92.02 1,760.92 1,619.02 21.27 725.01 5,927,695.81 461,730.03 3.15 715.93 MWD +IFR -AK- CAZ -SC (3) 2,117.55 62.85 97.00 1,803.69 1,661.79 15.08 802.90 5,927,689.21 461,807.89 5.97 793.96 MWD +IFR -AK- CAZ -SC (3) 2,168.55 63.62 100.57 1,826.66 1,684.76 8.12 847.89 5,927,682.02 461,852.84 6.43 839.47 MWD +IFR -AK- CAZ -SC (3) 2,214.09 63.24 101.88 1,847.03 1,705.13 0.19 887.84 5,927,673.89 461,892.74 2.70 880.12 MWD +IFR -AK- CAZ -SC (3) 2,310.15 65.08 105.01 1,888.90 1,747.00 -19.92 971.91 5,927,653.34 461,976.69 3.50 966.10 MWD +IFR -AK- CAZ -SC (3) 2,404.45 63.55 105.27 1,929.77 1,787.87 -42.12 1,053.94 5,927,630.73 462,058.60 1.64 1,050.33 MWD +IFR -AK- CAZ -SC (3) 2,499.11 62.82 103.63 1,972.48 1,830.58 -63.20 1,135.74 5,927,609.22 462,140.28 1.73 1,134.20 MWD +IFR -AK- CAZ -SC (3) 2,594.38 62.88 99.44 2,015.97 1,874.07 -80.14 1,218.77 5,927,591.85 462,223.22 3.91 1,218.74 MWD +IFR -AK- CAZ -SC (3) 2,688.57 66.89 97.01 2,055.94 1,914.04 -92.31 1,303.16 5,927,579.25 462,307.53 4.86 1,303.99 MWD +IFR -AK- CAZ -SC (3) I 2,780.72 67.51 96.35 2,091.65 1,949.75 - 102.19 1,387.53 5,927,568.93 462,391.85 0.94 1,388.93 MWD +IFR -AK- CAZ -SC (3) 2,877.34 66.67 95.58 2,129.26 1,987.36 - 111.44 1,476.05 5,927,559.23 462,480.30 1.14 1,477.89 MWD +IFR -AK- CAZ -SC (3) 2,972.07 63.73 94.24 2,169.00 2,027.10 - 118.81 1,561.71 5,927,551.41 462,565.92 3.36 1,563.78 MWD +IFR -AK- CAZ -SC (3) 3,066.90 63.36 94.65 2,211.24 2,069.34 - 125.39 1,646.36 5,927,544.40 462,650.52 0.55 1,648.56 MWD +IFR -AK- CAZ -SC (3) 3,162.99 62.86 93.84 2,254.70 2,112.80 - 131.74 1,731.82 5,927,537.61 462,735.94 0.91 1,734.11 MWD +IFR -AK- CAZ -SC (3) 3,251.89 62.87 94.31 2,295.25 2,153.35 - 137.36 1,810.73 5,927,531.58 462,814.82 0.47 1,813.08 MWD +IFR -AK- CAZ -SC (3) 3,347.18 62.49 94.76 2,338.98 2,197.08 - 144.05 1,895.13 5,927,524.46 462,899.17 0.58 1,897.63 MWD +IFR -AK- CAZ -SC (3) 3,439.73 63.77 96.36 2,380.81 2,238.91 - 152.06 1,977.29 5,927,516.03 462,981.28 2.07 1,980.13 MWD +IFR -AK- CAZ -SC (3) 3,484.26 63.94 96.28 2,400.44 2,258.54 - 156.46 2,017.02 5,927,511.42 463,020.99 0.41 2,020.09 MWD +IFR -AK- CAZ -SC (3) 3,575.00 62.76 94.54 2,441.14 2,299.24 - 164.11 2,097.76 5,927,503.35 463,101.67 2.15 2,101.13 MWD +IFR -AK- CAZ -SC (4) 3,624.63 62.68 95.38 2,463.89 2,321.99 - 167.93 2,141.70 5,927,499.31 463,145.59 1.51 2,145.20 MWD +IFR -AK- CAZ -SC (4) 3,720.57 64.05 96.50 2,506.90 2,365.00 - 176.80 2,226.99 5,927,489.99 463,230.83 1.77 2,230.92 MWD +IFR -AK- CAZ -SC (4) 3,813.32 64.23 95.40 2,547.35 2,405.45 - 185.46 2,310.01 5,927,480.92 463,313.79 1.08 2,314.35 MWD +IFR -AK- CAZ -SC (4) 3,908.99 63.69 98.45 2,589.36 2,447.46 - 195.81 2,395.32 5,927,470.12 463,399.04 2.92 2,400.28 MWD +IFR -AK- CAZ -SC (4) 1 5/17/2010 9:29:56AM Page 3 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co -ordinate Reference: Well 2L -310 Protect: Kuparuk River Unit TVD Reference: 2L -310 @ 141.90ft (D16 (114.9 +25.5 +1.5)) Site: Kuparuk 2L_Pad MD Reference: 2L -310 @ 141.90ft (D16 (114.9 +25.5 +1.5)) Well: 2L - 310 North Reference: True Weilbore: 2L - 310 Survey Calculation Method: Minimum Curvature Design: 2L - 310 Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E!-W Northing Easting DLS Section (ft) ( °) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') - (ft) Survey Tool Name 4,004.77 63.57 99.48 2,631.90 2,490.00 - 209.18 2,480.09 5,927,456.31 463,483.73 0.97 2,486.07 MWD +IFR -AK- CAZ -SC (4) 4,097.26 64.75 100.21 2,672.22 2,530.32 - 223.42 2,562.10 5,927,441.65 463,565.66 1.46 2,569.24 MWD +IFR -AK- CAZ -SC (4) 4,193.22 65.39 98.43 2,712.67 2,570.77 - 237.51 2,647.97 5,927,427.12 463,651.44 1.81 2,656.22 MWD +IFR -AK- CAZ -SC (4) 4,289.24 65.41 98.34 2,752.64 2,610.74 - 250.24 2,734.34 5,927,413.95 463,737.74 0.09 2,743.51 MWD +IFR -AK- CAZ -SC (4) 4,382.06 65.37 98.86 2,791.29 2,649.39 - 262.86 2,817.78 5,927,400.90 463,821.10 0.51 2,827.89 MWD +IFR -AK- CAZ -SC (4) 4,479.56 64.57 99.09 2,832.54 2,690.64 - 276.64 2,905.04 5,927,386.67 463,908.28 0.85 2,916.20 MWD +IFR -AK- CAZ -SC (4) 4,573.54 63.15 101.00 2,873.95 2,732.05 - 291.35 2,988.11 5,927,371.54 463,991.27 2.37 3,000.48 MWD +IFR -AK- CAZ -SC (4) 4,667.95 63.12 100.35 2,916.61 2,774.71 - 306.95 3,070.87 5,927,355.51 464,073.94 0.62 3,084.58 MWD +IFR -AK- CAZ -SC (4) 4,762.43 63.32 100.49 2,959.18 2,817.28 - 322.20 3,153.82 5,927,339.83 464,156.81 0.25 3,168.82 MWD +IFR -AK- CAZ -SC (4) 4,853.04 63.38 100.64 2,999.82 2,857.92 - 337.05 3,233.44 5,927,324.57 464,236.33 0.16 3,249.69 MWD +IFR -AK- CAZ -SC (4) 4,951.30 63.78 100.63 3,043.54 2,901.64 - 353.29 3,319.92 5,927,307.89 464,322.72 0.41 3,337.56 MWD +IFR -AK- CAZ -SC (4) 5,001.38 64.04 101.39 3,065.57 2,923.67 - 361.88 3,364.07 5,927,299.07 464,366.82 1.46 3,382.45 MWD +IFR -AK- CAZ -SC (5) 5,097.19 63.42 101.59 3,107.97 2,966.07 - 378.99 3,448.26 5,927,281.52 464,450.92 0.67 3,468.16 MWD +IFR -AK- CAZ -SC (5) 5,193.52 62.36 102.88 3,151.87 3,009.97 - 397.16 3,532.06 5,927,262.92 464,534.61 1.62 3,553.62 MWD +IFR -AK- CAZ -SC (5) 5,286.80 61.42 103.52 3,195.82 3,053.92 - 415.95 3,612.16 5,927,243.73 464,614.61 1.18 3,635.50 MWD +IFR -AK- CAZ -SC (5) 5,379.43 63.07 103.80 3,238.96 3,097.06 - 435.30 3,691.81 5,927,223.96 464,694.15 1.80 3,717.00 MWD +IFR -AK- CAZ -SC (5) 5,475.60 63.84 103.60 3,281.94 3,140.04 - 455.68 3,775.40 5,927,203.15 464,777.62 0.82 3,802.54 MWD +IFR -AK- CAZ -SC (5) 5,575.27 63.76 102.25 3,325.94 3,184.04 - 475.68 3,862.56 5,927,182.70 464,864.67 1.22 3,891.57 MWD +IFR -AK- CAZ -SC (5) 5,668.41 63.82 99.10 3,367.09 3,225.19 - 491.16 3,944.66 5,927,166.81 464,946.68 3.03 3,975.00 MWD +IFR -AK- CAZ -SC (5) 5,762.28 62.82 95.55 3,409.25 3,267.35 - 501.86 4,027.83 5,927,155.67 465,029.78 3.54 4,058.85 MWD +IFR -AK- CAZ -SC (5) 5,857.32 62.19 95.35 3,453.12 3,311.22 - 509.87 4,111.75 5,927,147.23 465,113.66 0.69 4,143.10 MWD +IFR -AK- CAZ -SC (5) 5,950.58 61.99 96.54 3,496.78 3,354.88 - 518.40 4,193.72 5,927,138.28 465,195.57 1.15 4,225.48 MWD +IFR -AK- CAZ -SC (5) 6,044.68 60.97 97.99 3,541.71 3,399.81 - 528.85 4,275.73 5,927,127.40 465,277.52 1.73 4,308.15 MWD +IFR -AK- CAZ -SC (5) 6,139.67 62.18 99.11 3,586.93 3,445.03 - 541.28 4,358.34 5,927,114.56 465,360.05 1.64 4,391.67 MWD +IFR -AK- CAZ -SC (5) 6,233.75 63.37 99.49 3,629.96 3,488.06 - 554.80 4,440.89 5,927,100.61 465,442.53 1.31 4,475.29 MWD +IFR -AK- CAZ -SC (5) 6,325.65 63.98 97.46 3,670.72 3,528.82 - 566.93 4,522.36 5,927,088.06 465,523.92 2.09 4,557.64 MWD +IFR -AK- CAZ -SC (5) 6,419.88 64.20 97.80 3,711.90 3,570.00 - 578.19 4,606.37 5,927,076.37 465,607.86 0.40 4,642.40 MWD +IFR -AK- CAZ -SC (5) 6,512.40 65.47 97.00 3,751.24 3,609.34 - 588.97 4,689.41 5,927,065.16 465,690.84 1.58 4,726.14 MWD +IFR -AK- CAZ -SC (5) 6,610.64 66.80 97.01 3,790.98 3,649.08 - 599.92 4,778.57 5,927,053.74 465,779.94 1.35 4,815.97 MWD +IFR -AK- CAZ -SC (5) 6,701.39 66.35 96.11 3,827.06 3,685.16 - 609.44 4,861.30 5,927,043.80 465,862.60 1.04 4,899.23 MWD +IFR -AK- CAZ -SC (5) 6,796.40 64.66 94.83 3,866.45 3,724.55 - 617.69 4,947.36 5,927,035.11 465,948.61 2.16 4,985.62 MWD +IFR -AK- CAZ -SC (5) 6,891.69 62.84 95.72 3,908.60 3,766.70 - 625.54 5,032.45 5,927,026.82 466,033.66 2.09 5,071.01 MWD +IFR -AK- CAZ -SC (5) 6,986.66 62.96 98.65 3,951.87 3,809.97 - 636.11 5,116.32 5,927,015.82 466,117.46 2.75 5,155.54 MWD +IFR -AK- CAZ -SC (5) 7,077.27 62.99 99.64 3,993.04 3,851.14 - 648.94 5,196.01 5,927,002.58 466,197.07 0.97 5,236.23 MWD +IFR -AK- CAZ -SC (5) 7,173.92 62.72 100.46 4,037.14 3,895.24 - 663.95 5,280.69 5,926,987.14 466,281.67 0.80 5,322.15 MWD +IFR -AK- CAZ -SC (5) 7,265.31 62.74 101.22 4,079.01 3,937.11 - 679.22 5,360.47 5,926,971.45 466,361.37 0.74 5,403.25 MWD +IFR -AK- CAZ -SC (5) 7,358.54 62.67 102.02 4,121.77 3,979.87 - 695.91 5,441.62 5,926,954.34 466,442.42 0.77 5,485.89 MWD +IFR -AK- CAZ -SC (5) 7,457.41 63.49 101.72 4,166.53 4,024.63 - 714.04 5,527.90 5,926,935.77 466,528.59 0.87 5,573.79 MWD +IFR -AK- CAZ -SC (5) 7,551.69 63.95 99.53 4,208.28 4,066.38 - 729.63 5,610.97 5,926,919.76 466,611.58 2.14 5,658.20 MWD +IFR -AK- CAZ -SC (5) 7,643.53 63.20 98.27 4,249.15 4,107.25 - 742.35 5,692.23 5,926,906.61 466,692.75 1.48 5,740.42 MWD +IFR -AK- CAZ -SC (5) 5/17/2010 9:29 :56AM Page 4 COMPASS 2003.16 Build 69 • • ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co- ordinate Reference: Well 2L -310 Protect: Kuparuk River Unit TVD Reference: 2L -310 © 141.90ft (D16 (114.9 +25.5 +1.5)) Site: Kuparuk 2L_Pad MD Reference: 2L -310 © 141.90ft (D16 (114.9 +25.5 +1.5)) Well: 2L - 310 North Reference: True Weilbore: 2L - 310 Survey Calculation Method: Minimum Curvature P I Production Design: 2L - 310 Database: C A EDM Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) ( °) ( (ft) (ft) (ft) (ft) (ft) (ft) (° /100') (ft) Survey Tool Name 7,737.70 62.31 97.87 4,292.26 4,150.36 - 754.11 5,775.12 5,926,894.43 466,775.58 1.02 5,824.13 MWD +IFR -AK- CAZ -SC (5) 7,831.54 62.45 97.28 4,335.76 4,193.86 - 765.07 5,857.54 5,926,883.05 466,857.93 0.58 5,907.28 MWD +IFR -AK- CAZ -SC (5) 7,925.73 63.35 96.75 4,378.67 4,236.77 - 775.31 5,940.76 5,926,872.38 466,941.09 1.08 5,991.12 MWD +IFR -AK- CAZ -SC (5) 8,023.70 63.96 96.05 4,422.15 4,280.25 - 785.09 6,028.00 5,926,862.15 467,028.27 0.89 6,078.90 MWD +IFR -AK- CAZ -SC (5) 8,115.62 63.60 95.99 4,462.76 4,320.86 - 793.74 6,110.01 5,926,853.08 467,110.23 0.40 6,161.33 MWD +IFR -AK- CAZ -SC (5) 8,209.78 63.50 95.73 4,504.70 4,362.80 - 802.35 6,193.87 5,926,844.04 467,194.04 0.27 6,245.60 MWD +IFR -AK- CAZ -SC (5) 8,305.98 63.56 96.03 4,547.58 4,405.68 - 811.17 6,279.54 5,926,834.77 467,279.64 0.29 6,331.68 MWD +IFR -AK- CAZ -SC (5) 8,400.37 63.28 95.71 4,589.81 4,447.91 - 819.80 6,363.51 5,926,825.71 467,363.56 0.42 6,416.05 MWD +IFR -AK- CAZ -SC (5) 8,494.94 63.64 96.26 4,632.07 4,490.17 - 828.62 6,447.65 5,926,816.45 467,447.65 0.64 6,500.63 MWD +IFR -AK- CAZ -SC (5) 8,587.74 64.12 96.71 4,672.93 4,531.03 - 838.03 6,530.44 5,926,806.61 467,530.38 0.68 6,583.93 MWD +IFR -AK- CAZ -SC (5) 8,679.91 64.46 97.03 4,712.91 4,571.01 - 847.97 6,612.89 5,926,796.25 467,612.77 0.48 6,666.97 MWD +IFR -AK- CAZ -SC (5) 8,770.73 64.01 97.70 4,752.39 4,610.49 - 858.45 6,694.00 5,926,785.35 467,693.82 0.83 6,748.76 MWD +IFR -AK- CAZ -SC (5) 8,870.60 63.77 99.12 4,796.34 4,654.44 - 871.57 6,782.71 5,926,771.78 467,782.45 1.30 6,838.43 MWD +IFR -AK- CAZ -SC (5) 8,964.49 63.62 99.63 4,837.95 4,696.05 - 885.28 6,865.76 5,926,757.64 467,865.42 0.51 6,922.55 MWD +IFR -AK- CAZ -SC (5) 9,057.14 63.66 100.01 4,879.09 4,737.19 - 899.44 6,947.56 5,926,743.07 467,947.13 0.37 7,005.50 MWD +IFR -AK- CAZ -SC (5) 9,155.79 63.84 100.21 4,922.72 4,780.82 - 914.97 7,034.66 5,926,727.09 468,034.15 0.26 7,093.89 MWD +IFR -AK- CAZ -SC (5) 9,247.56 63.22 98.61 4,963.63 4,821.73 - 928.40 7,115.70 5,926,713.24 468,115.11 1.70 7,175.99 MWD +IFR -AK- CAZ -SC (5) 9,343.51 61.10 97.81 5,008.43 4,866.53 - 940.52 7,199.67 5,926,700.68 468,199.00 2.33 7,260.83 MWD +IFR -AK- CAZ -SC (5) 9,438.82 58.14 97.01 5,056.63 4,914.73 - 951.13 7,281.19 5,926,689.65 468,280.47 3.19 7,343.04 MWD +IFR -AK- CAZ -SC (5) 9,533.45 54.71 97.02 5,108.95 4,967.05 - 960.76 7,359.43 5,926,679.62 468,358.65 3.62 7,421.87 MWD +IFR -AK- CAZ -SC (5) 9,627.91 50.85 96.97 5,166.08 5,024.18 - 969.92 7,434.08 5,926,670.08 468,433.24 4.09 7,497.07 MWD +IFR -AK- CAZ -SC (5) 9,723.16 46.54 98.18 5,228.94 5,087.04 - 979.33 7,504.99 5,926,660.31 468,504.09 4.62 7,568.60 MWD +IFR -AK- CAZ -SC (5) 9,816.73 43.05 99.17 5,295.33 5,153.43 - 989.25 7,570.15 5,926,650.05 468,569.20 3.80 7,634.50 MWD +IFR -AK- CAZ -SC (5) 9,909.72 41.96 98.99 5,363.88 5,221.98 - 999.17 7,632.20 5,926,639.81 468,631.18 1.18 7,697.31 MWD +IFR -AK- CAZ -SC (5) 10,001.68 42.31 98.98 5,432.08 5,290.18 - 1,008.80 7,693.13 5,926,629.86 468,692.06 0.38 7,758.99 MWD +IFR -AK- CAZ -SC (5) 10,095.33 41.90 99.73 5,501.56 5,359.66 - 1,019.01 7,755.09 5,926,619.34 468,753.96 0.69 7,821.74 MWD +IFR -AK- CAZ -SC (5) 10,191.17 41.32 99.80 5,573.22 5,431.32 - 1,029.80 7,817.81 5,926,608.22 468,816.62 0.61 7,885.34 MWD +IFR -AK- CAZ -SC (5) 10,214.78 41.18 100.47 5,590.97 5,449.07 - 1,032.54 7,833.13 5,926,605.40 468,831.92 1.96 7,900.89 MWD +IFR -AK- CAZ -SC (5) 10,252.00 41.18 100.47 5,618.98 5,477.08 - 1,036.99 7,857.23 5,926,600.83 468,856.00 0.00 7,925.37 PROJECTED to TD 5/17/2010 9:29:56AM Page 5 COMPASS 2003.16 Build 69 • • Conoco Phillips TRANSMITTAL FROM: Sandra D. Lemke, AT01808 Christine Mahnken ConocoPhillips Alaska AOGCC P.O. Box 100360 333 W. 7 Ave., Suite 100 Anchorage AK 99510 -0360 Anchorage, Alaska 99501 RE: KRU 2L -310 DATE: 06/16/2010 mail Transmitted: Kuparuk River Unit, Alaska 2L -310 Hardcopy report and CD digital data Final Well Report Mud logging data; 2L -310; CANRIG; 5/25/2010; TOC, Equipment and crew, well data, geological data, pressure /formations strength data, drilling data, daily reports, formation logs; Formation logs MD and TVD 110-10252' and LWD Combo Log MD and TVD 110-10252' and Gas Ratio Log MD and TVD 110 - 10252' and Drilling Dynamics MD and TVD 110-10252' and CD contains final well report, morning reports, LAS data, PDF files, DML data, remarks file and TIFF files. Please sign, can and return transmittal via e-mail promptly CC: 2L -310 well dat. transmittal file REC 11. ;,; Receipt: Atk. Date: • Arctic-rage .1/2 • 175S- Upstream Applications & Data 1 conccoPhi /Gips Anchorage, Alaska Ph, 902,2656947 Sandra .D.Lemke &Conocoph / ///ps com �� b —d07) WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 25, 2010 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 2L -310 Run Date: 6/9/2010 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 2L -310 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20616 -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 0` C1-69-5 Office: 907- 273 -3527 `�` Fax: 907 - 273 -3535 � Z a`� rafael.barreto @h r 9 ;41 • Date: Signed: /�-✓ :ate. C, cr age i • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 25, 2010 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2L -310 Run Date: 6/8/2010 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 2L -310 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20616 -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. Si 0 0 Anchorage, Alaska 99518 / Office: 907 - 273 -3527 Fax: 907 -27 rafael.barret �� r. � ill `to) cl jUi i Date: Signed: • tlas Cam. :r a i; n WELL LOG TRANSMITTAL To: State of Alaska May 18, 2010 Alaska Oil and Gas Conservation Commission Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 -3539 RE: LWD Formation Evaluation Logs: 21 -310 AK -MW- 0007076015 21 -310 50- 103 - 20616 -00 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 2" x 5" TVD TRIPLE COMBO Logs: 1 Color Log 2" x 5" MD SONIC VDL Logs: 1 Color Log 2" x 5" TVD SONIC VDL Logs: 1 Color Log Digital Log Images & LWDG- formatted LIS Data w /verification listing; 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3536 Fax: 907 -, 7 a ..- .1') liburton.com / Date: Signed: r • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 18, 2010 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: 2L -310 Run Date: 5/11/2010 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 2L -310 Data in LAS format, Digital Log Image files 1 CD Rom 50 -103- 20616 -00 Cement Bond Log 1 Color Log 50 -103- 20616 -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. ©( b -6 Anchorage, Alaska 99518 ` ) 'S 3 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 rafael.barret Date: Signed: " ArieherSgo • • sitollE LiT immA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 Re: Kuparuk River Field, Tarn Oil Pool, 2L -310 ConocoPhillips Alaska, Inc. Permit No: 210 -028 Surface Location: 167' FNL, 646' FEL, Sec. 22, T1ON, R7E, UM Bottomhole Location: 1212' FNL, 1921" FWL, Sec. 24, T1ON, R7E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, • ` I Dan', . Seamount, Jr. Chair DATED this /t day of March, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via e -mail) RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 1 0 2010 PERMIT TO DRILL 0184asCces.coninission 20 AAC 2 005 ../,, Aftthaage la. Type of Work: 1 b. Proposed Well Class: Development - Oil F ] • ervice - Winj ❑ Single Zone IVr lc. Specify if well is proposed for: Drill EI • Re -drill ❑ Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Re -entry ❑ Exploratory ❑ Service - WAG V Service - Disp ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: U Blanket u Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59 - 52 - 180 . 2L - 310 3. Address: 6. Proposed Depth: 12. Field /Pool(s): , P.O. Box 100360 Anchorage, AK 99510 - 0360 MD: 10193' • TVD: 5600' Kuparuk River Field . 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 167' FNL, 646' FEL, Sec. 22, T1ON, R7E, UM • ADL 380052, 380051 Tarn Oil Pool . Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1174' FNL, 1680' FWL, Sec. 24, T1ON, R7E, UM 4600, 4599 4/12/2010 Total Depth: 9. Acres in Property: 14. Distance to 1212' FNL, 1921' FWL, Sec. 24, T1ON, R7E, UM • 2560 Nearest Property: 5447' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: • 140 feet 15. Distance to Nearest Well Open Surface: x - 461005 y - 5927678 Zone 4 GL Elevation above MSL: , etl Same Pool: 2L -311 , 1164' @10193' 16. Deviated wells: Kickoff depth: 330 . ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) • Maximum Hole Angle: 63.7° d Downhole: 3001 psig Surface: 2414 psig • 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 164.8# B -35 Welded 130' Surf Surf 130' ' 130' driven 13.5 10.75" 45.5# L -80 BTC 3500' Surf Surf 3500' • 2434' 600 sx ASLite, 370 sx Class G 9.875" 7.625" 29.7# L -80 BTCM 10193' Surf Surf 10193' 5600' • 700 sx GasBLOK Class G 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Liner • Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program 111 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 E { 500 requirements 21. Verbal Approval: Commission Representative: Date: �; / 22. I hereby certify that the foregoing is true and correct. Contact Mike Greener @ 2663 - -4 0 Printed Name G. Alvord Title Alaska Drilling Manager , / Signature (' A Phon 26 G • Date 3 r1' 1 . /G• Commission Use Only Permit to Drill ,,�� API Number: Permit Approval See cover letter Number: 2_ (1 2.. 50-/(:)7-3 - 2.6,• 6_' cl - Date: for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Er 4 3500 P Sci '_ Q Mud log req'd: Yes 111 No � P �G St Samples req'd: Yes ❑ No Other: 1 *z 5 PS` � A n ', ,,,G,- 7 i �1 ( Hy2�S measures: Yes 0 No El Directional svy req'd: / Yes [� No ❑ �(T ;n OD a e- . Lg." ta � l :-i'�- A 1G M IT t C sv y req ho] re? No El �--4 I - APPROVED BY THE COMMISSION • 3 ," ,27 DATE: �r' �� , COMMISSIONER TO F m 10 - 401 ( evised 7/2009) This permit is valid f 4 • s . t e : ate bF royal (20 AAC 25.005(g)) Submit in Duplicate Post Office Box 100360 CONTIIl Anchorage, Alaska 99510 -0360 Chip Alvord Phone (907) 265 -6120 RECEIVED Email: Chip.Alvord @conocophillips.com March 8, 2010 MAR 1 0 2010 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 AMMON& Gas Cow Commission Anchorage, Alaska 99501 Anchorage RE: Application for Permit to Drill 2L-310 Dear Commissioners, ConocoPhillips Alaska, Inc hereby applies for a Permit to Drill for the onshore pre - produced injection well 2L -310. The well will be drilled and completed using Doyon Rig #16. The well will then be put on production, with the plan being to convert the well to injection at a later date. The planned spud date for 2L -310 is Apr. 12 2010. Please fmd attached for the review of the Commission forms 10 -401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information, please contact Mike Greener at 907 - 263 -4820 or Drew Huck at 907 - 265 -6828. Sincerely, Aet Chip Alvord Drilling Manager Ation for Permit to Drill, Well 2L -310 Saved: 8- Mar -10 Permit It — Tarn Well 2L -310 Application for Permit to Drill Document r" T• T �� moximizo W v Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005 (0 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Requirements of 20 AAC 25.050(b) 2 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005 (c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 3 Requirements of 20 AAC 25.005 (c)(5) 3 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c) (6) 4 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c) 4 8. Drilling Fluid Program 4 Requirements of 20 AAC 25.005(c)(8) 4 9. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005 (c)(9) 5 10. Seismic Analysis 5 Requirements of 20 AAC 25.005 (c)(10) 5 11. Seabed Condition Analysis 5 Requirements of 20 AAC 25.005 (c)(11) 5 12. Evidence of Bonding 5 Requirements of 20 AAC 25.005 (c)(12) 5 13. Proposed Drilling Program 5 Requirements of 20 AAC 25.005 (c)(13) 5 2L -310 APD Page ORIGINAL 8 -Mar - Printed: 8- Mar -10 0 • Al Dation for Permit to Drill, Well 2L -310 Saved: 8- Mar -10 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 6 Requirements of 20 AAC 25.005 (c)(14) 6 15. Attachments 6 Attachment 1 Directional Plan 6 Attachment 2 Drilling Hazards Summary 6 Attachment 3 Well Schematic 6 Attachment 4 Cement Summary 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated b) the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with nnihiple well branches, each branch must similarly be identified by a u name and API number by adding a suffix to the name designated_ for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 2L -310. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items. except for an item already waffle with the commission and identified in the application: (2) a plat idenl f ing the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation. and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the suface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth: Location at Surface 167' FNL, 646' FEL, Sec 22, T1ON, R7E, UM • NAD 1927 RKB Elevation 140.4' AMSL Northings: 5,927,678 Eastings: 461,005 • Pad Elevation 114.9' AMSL Location at Top of Productive Interval 1,174' FNL, 1,680' FWL, Sec 24, T1ON, R7E, UM . (Bermuda) Nad 1927 Measured Depth, RKB: 9,827' Northings: 5,926,636 Eastings: 468,606 Total Vertical Depth, RKB: 5,327' Total Vertical Depth, SS: 5,187' Location at Total Depth 1,212' FNL, 1,921' FWL, Sec 24, T1ON, R7E, UM • Nad 1927 Measured Depth, RKB: 10,193' Northings: 5,926,597 Eastings: 468,848 Total Vertical Depth, RKB: 5,600' Total Vertical Depth, SS: 5,459' and (D) other ii formation required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10 -401) nmst (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellhore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (4) list the naives of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been famished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 2L -310 APD Page 2 of 7 Printed: 8- Mar -10 OR !GINAL • Ap ion for Permit to Drill, Well 2L -310 Saved: 8- Mar -10 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill Hurst be accompanied by each of the following items. except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035. 20 AAC 25.036, or 20 A.4C 25.037, as applicable: Please reference BOP schematics on file for Doyon 16. . 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill Hurst be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (.4) the maximum downhole pressure that may be encountered criteria used to determine it, and maximum potential surface pressure based on a methane gradient: The maximum potential reservoir pressure for 2L -310 could be influenced by offset injector 2L -317A, which would be 3,000 psi at the reservoir depth of 5,327' TVD. This is not a likely scenario. Equivalent Mud Weight @ TD = 3,000 / (5,327 *.052) = 10.82 ppg = 0.563 psi/ft The maximum potential surface pressure (MPSP) while drilling 2L -310 is calculated using the predicted 3,000 psi reservoir pressure, a 0.11 psi/ft gas gradient, and a Bermuda sand top TVD of 5,327' (estimated top of reservoir in 2L -310). MPSP = (5,327 ft TVD) *(0.563 - 0.11 psi/ft) = 2,414 psi - (B) data on potential gas zones: The well bore is not expected to penetrate any gas zones. - and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking: Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(/): Drill out surface casing shoe and perform LOT test or FIT in accordance with the Kuparuk LOT / FIT procedure that ConocoPhillips Alaska has on file with the Commission. 2L -310 APD Page 3 of 7 C GI►L Printed: 8- Mar -10 • Al ',ion for Permit to Drill, Well 2L -310 Saved: 8- Mar -10 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c) (6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre perforated liner, or screen to be installed; Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD ;. lS•C OD (in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program Driven 16 24 164.8 B -35 Welded 130' Surf 130' / 130' - Cemented to Surface with 4.5 10 -3/4 13 -1/2 45.5 L -80 BTC 3,500' Surf 3,500' / 2,434', 600 sx ASLite Lead 10.7 ppg, t .ro y 370 sx Tail Slurry 12.0 ppg Cement Top planned @ 7,750' MD / 7 -5/8 9 -7/8 29.7 L -80 BTCM 10,193' Surf 10,193' / 5,600' 4,327' ND. Cemented w/ /.17 700 sx GasBLOK Class "G" 15.8 ppg 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h) (2); Please reference diverter schematic on file for Doyon 16. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission caul identified in the application: (8) a drilling fluid program:, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done using mud systems having the following properties: Surface 110' — 3,500 ' Density (ppg) 9.0 — 9.8 Funnel Viscosity (seconds) 75 -250 Yield Point (cP) 60 — 80 pH 9.0 — 9.5 API Filtrate(cc) NC — 8.0 ,. -. Chlorides (mg /l) <1000 Intermediate/Production 3,500' — 10,193' 1 <, ' ! � , 0 ' 'rA Density (ppg) 9.4 — 10.0 / ` kp ' Yield Point (cP) 20 — 28 I Plastic Viscosity (lb /100 sJ) 10 -14 pH 10.0 — 10.5 API filtrate 4 — 6 Solids ( %) 6 — 7 Diagram of Doyon 16 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 2L -310 APD Page 4 of 7 1 7> '°� • 1 1 A Printed: 8- Mar -10 • A41110tion for Permit to Drill, Well 2L -310 Saved: 8- Mar -10 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the conunission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally' geo-pressured strata as required by 20 AAC 25.033(/); N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill Hurst be accompanied by each of the following items, except for an item already on file - with the commission and identified in the application: (10) for an exploratory or stratigraphic test well. a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the conunission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom founded structure, jack -up rig. or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); N/A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill n be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding; have been met: Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. , 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items. except for an item already on file with the conunission and identified in the application: The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Doyon 16 on 2L -310 Conductor. 2. NU and function test diverter system and prepare spud mud. 3. Place warning signs on location indicating the rig has diverter equipment rigged up. - 4. Spud and directionally drill 13 -1/2" hole to the 10 -3/4" surface casing point (3,500' MD/ 2,434' TVD) . according to the directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. • 5. Run and cement 10 -3/4" 45.5# L -80 BTC casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. Perform top job if required to bring cement to surface. 6. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE and test to 3,500 psi. Notify state of BOP test. Record results. 7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. 8. Drill out cement and 20' minimum to 50' maximum of new hole. Perform LOT. 9. Directionally drill 9-7/8" hole to 10,193' MD / 5,600' TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 10. POOH with DP and rack back. Run 7 -5/8" 29.7# L -80 BTCM casing to 10,193' MD / 5,600' TVD and cement. 2L -310 APD Page 5 of 7 0 R I G I N AL Printed: 8- Mar -10 1 Alltion for Permit to Drill, Well 2L -310 Saved: 8- Mar -10 11. Run a cement bond log of 7 -5/8" casing to verify bond. ✓ 12. Run 3 -1/2" completion tubing with packer and set at +/- 9,850' MD. 13. LD DP and associated equipment. 14. ND BOP and rig up tree. Test tree and freeze protect annulus. Rig down and move out rig. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the followrmg items except for an item already on file with the conimission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authnri_ation under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II - disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska does intend to request authorization for the use of this well for annular disposal operations at a later date provided the well meets the regulatory requirements. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary 2L -310 APD N �t ! I r L Printed: 8- Mar -10 • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad Plan: 2L -310 (Oscar) 2L -310 (Oscar) Plan: 2L -310 (wp02) Standard Proposal Report 05 March, 2010 HAL LIBURTON Sperry Drilling Services ORIGINAL 1 • HAI_L.IBURTOIV Project: Kuparuk River Unit WELL DETAILS: Plan:2L- 310(Oscar) Site: Kuparuk 2L Pad Ground Level: 114.90 Well: Plan: 2L -310 (Oscar) +N / -S +E / -W Northing Easting Latittude Longitude Slot Sperry Drilling Wellbore: 2L -310 (Oscar) 0.00 0.00 5927678.20 461004.90 70° 12' 48.102 N 150 18' 52.165 W Plan: 2L -310 (wp02) REFERENCE INFORMATION Co- ordinate (N/E) Reference: Well Plan: 2L -310 (Oscar), True North Vertical (TVD) Reference: Staked: 2L -310 tt 140.40ft (016 (114.9 +25.5)) Measured Depth Reference: Staked: 2L -310 (8j 140.40ft (D16 (114.9 +25.5)) Calculation Method: Minimum Curvature 500 I 1 1 1 CASING DETAILS _ - 25 0 SHL: 167' FNL, 646' FEL - Sec22,TION,RO7E 0 - _ice - - - - -- TVD TVDSS MD Size Name -� -- 2434.03 2293.63 3500.00 10 -3/4 10 3/4" _ -0° ' 5599.52 5459.12 10192.92 7 -5/8 7 5/8" 111:11 500 — — _ 10° 1000 _ �� — - -- — — - - ti5 I 1500 - - - - -- -- o$- Sfc Csg @ 3500' MD, 2434' TVD: 335' FNL, 1411' FWL- Sec23,T10N,R07E ___- ___-- -_ -,__ DDI = L •^ L r� _ rvo DDI - v GVG 2000 — .- — 1 • _ :. O 2434 2061 o e O ,c t- - e 2500 — — — — t _ 10 3/4" Q 3000 - R — - -- -- - - 1111 .- - - -- ' - 1°b O 4-2 ' r Top S -8 @ 9827 MD, 5327 TVD: 1174' FNL, 1680' FWL- Sec24,T1ON,R07E t 3500 -- — y _ 11 t. ec y - t �e e 4000— E — 11 1 t ' -1 -4- 4500 1. — — — — — ' -- — -- — eg a 5000 — - - - -- _ 5327 7673 2L_310� +p02 SS _ _ - b5 pz 5500 1 1 ..___........_.._.____._____ 11_11. — __ - _11_11._ ____ — _ ___ __ --- 2131033/3071 l ; SI \c, - ___ — _ - 1111___.__ - - -- _ 7 5/8"; ' 2L-310 (wp02) 6000 — — r 4 i - -- BHL @ 10193' MD, 5600' TVD: 1212 FNL, 1921' FWL - Sec24,TION,RO7E _ 1 111 1111 1111 1111 1111 1111 1111 I 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 -500 -0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 Vertical Section at 97.55° (1500 ft/in) 1875 - -_ �� 1111■■ • 1500 -- SHL. 167 FNL, 646' FEL - Sec22,TION,R07E -- - -- -- -- - -- -- 1125 -- - - - - -- - - -- +-- III Sfc Csg @ 3500' MD, 2434' TVD: 335' FNL, 1411' FWL - Sec23,TION,R0 -- — - - -- -- ---- ___ -__ -_ _� 1 750 — — — — -- 2. .-. _ ■ 1111__. Top S -8 @ 9827 MD, 5327' TVD: 1174' FNL, 1680' FWL- Sec24,T10N,R07E c 3 7 5 — ■ a �� . - + -375 _ - - -- i �la�_ _' — v ry o --- _ s _ : III - 10 3/4" 111111111111 v '^ ° a c WI o -750 = 11 — 11 1111 T -1125 - S.. ' -- - 21.- 310,002 Ss 1 1 vi -1 -- -_ 7 5 /g" _71-31 1 0,0 - 11 T - 2L- 310vp0'_ 5 1 1 { -1875 I1 Ill! - - 1 t - -- -2250 _ �11 11111111 -gneh Field ' -2625 111 Dip . . ngle: '9.65° BHL @ 10193' MD, 5600' TVD: 1212' FNL, 1921' FWL - Sec24,T1ON,R07E Da e: 3/21/2010 1111 _ 1! - - --- - - -- 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 1111 - 1500 -1125 -750 -375 0 375 750 1125 1500 1875 2250 2625 3000 3375 3750 4125 4500 4875 5250 5625 6000 6375 6750 7125 7500 7875 8250 8625 9000 9375 West( - )/East( +) (1500 ft/in) ConocoPPhiHHips Alaska ORIGINAL • 0 Halliburton Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co Reference: Well Plan: 2L -310 (Oscar) Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Staked: 2L -310 @ 140.40ft (D16 (114.9 +25.5)). Project: Kuparuk River Unit MD Reference: Staked: 2L -310 @ 140.40ft (D16 (114.9 +25.5)) Site: Kuparuk 2L Pad North Reference: True Well: Plan: 2L -310 (Oscar) Survey Calculation Method: Minimum Curvature Welibore: 2L -310 (Oscar) Design: 2L -310 (wp02) Kuparuk River Unit, North Slope Alaska, Project uparu e U t, rt i Sop s , United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2L Pad Site Position: Northing: 5,927,695.13ft Latitude: 70° 12' 48.272 N From: Map Easting: 461,077.91 ft Longitude: 150°18' 50.048 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: - 0.30 ° Well Plan: 2L -310 (Oscar) Well Position +N / - 0.00 ft Northing: 5,927,678.20 ft • Latitude: 70° 12' 48.102 N +E / -W 0.00 ft Easting: 461,004.90 ft , Longitude: 150° 18' 52.165 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 114.90ft Welibore 2L - 310 (Oscar) Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) l (nT) BGGM2009 3/29/2010 16.96 79.65 57,335 Design 2L -310 (wp02) Audit Notes: Version: Phase: PLAN Tie On Depth: 25.50 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 25.50 0.00 0.00 97.55 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N / -S +El -W Rate Rate Rate Tool Face (ft) (°) ( (ft) ft (ft) (ft) ( °I100ft) (1100ft) ( ° /100ft) (°) 25.50 0.00 0.00 25.50 - 114.90 0.00 0.00 0.00 0.00 0.00 0.00 330.00 0.00 0.00 330.00 189.60 0.00 0.00 0.00 0.00 0.00 0.00 846.68 15.50 90.00 840.40 700.00 0.00 69.46 3.00 3.00 0.00 90.00 1,239.15 31.20 90.00 1,199.60 1,059.20 0.00 224.53 4.00 4.00 0.00 0.00 1,339.15 31.20 90.00 1,285.14 1,144.74 0.00 276.33 0.00 0.00 0.00 0.00 1,936.18 55.00 87.04 1,717.98 1,577.58 12.82 681.05 4.00 3.99 -0.50 -6.00 2,264.67 63.65 98.56 1,885.82 1,745.42 -2.21 962.19 4.00 2.63 3.51 51.95 9,283.82 63.65 98.56 5,000.74 4,860.34 - 938.60 7,182.22 0.00 0.00 0.00 0.00 9,827.20 41.92 98.79 5,327.40 5,187.00 - 1,003.37 7,607.48 4.00 -4.00 0.04 179.58 10,193.03 41.92 98.79 5,599.60 5,459.20 - 1,040.72 7,849.01 0.00 0.00 0.00 0.00 3/5/2010 9:25:58AM Page 2 COMPASS 2003.16 Build 69 ORIGINAL • 0 Halliburton T®N Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co - ordinate Reference: Well Plan: 2L -310 (Oscar) Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Staked: 2L -310 @ 140.40ft (D16 (114.9 +25.5)) Project: Kuparuk River Unit MD Reference: Staked: 2L -310 @ 140.40ft (D16 (114.9 +25.5)) Site: Kuparuk 2L Pad North Reference: True Well: Plan: 2L -310 (Oscar) Survey Calculation Method: Minimum Curvature Wellbore: 2L -310 (Oscar) Design: 2L -310 (wp02) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +Ei-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) - 114.90 25.50 0.00 0.00 25.50 - 114.90 0.00 0.00 5,927,678.20 461,004.90 0.00 0.00 SHL: 167' FNL, 646' FEL - Sec22,T10N,R07E 100.00 0.00 0.00 100.00 -40.40 0.00 0.00 5,927,678.20 461,004.90 0.00 0.00 200.00 0.00 0.00 200.00 59.60 0.00 0.00 5,927,678.20 461,004.90 0.00 0.00 300.00 0.00 0.00 300.00 159.60 0.00 0.00 5,927,678.20 461,004.90 0.00 0.00 330.00 0.00 0.00 330.00 189.60 0.00 0.00 5,927,678.20 461,004.90 0.00 0.00 400.00 2.10 90.00 399.98 259.58 0.00 1.28 5,927,678.19 461,006.18 3.00 1.27 500.00 5.10 90.00 499.78 359.38 0.00 7.56 5,927,678.16 461,012.46 3.00 7.50 600.00 8.10 90.00 599.10 458.70 0.00 19.05 5,927,678.10 461,023.95 3.00 18.89 700.00 11.10 90.00 697.69 557.29 0.00 35.73 5,927,678.02 461,040.62 3.00 35.42 800.00 14.10 90.00 795.27 654.87 0.00 57.54 5,927,677.90 461,062.43 3.00 57.04 846.68 15.50 90.00 840.40 700.00 0.00 69.46 5,927,677.84 461,074.35 3.00 68.86 900.00 17.63 90.00 891.50 751.10 0.00 84.67 5,927,677.76 461,089.55 4.00 83.93 1,000.00 21.63 90.00 985.67 845.27 0.00 118.26 5,927,677.59 461,123.14 4.00 117.23 1,100.00 25.63 90.00 1,077.27 936.87 0.00 158.34 5,927,677.38 461,163.22 4.00 156.97 1,200.00 29.63 90.00 1,165.84 1,025.44 0.00 204.71 5,927,677.14 461,209.59 4.00 202.93 1,239.15 31.20 90.00 1,199.60 1,059.20 0.00 224.53 5,927,677.04 461,229.40 4.00 222.58 1,300.00 31.20 90.00 1,251.65 1,111.25 0.00 256.05 5,927,676.88 461,260.92 0.00 253.83 1,339.15 31.20 90.00 1,285.14 1,144.74 0.00 276.33 5,927,676.77 461,281.20 0.00 273.93 1,400.00 33.62 89.54 1,336.51 1,196.11 0.14 308.94 5,927,676.74 461,313.81 4.00 306.25 1,434.98 35.01 89.30 1,365.40 1,225.00 0.33 328.66 5,927,676.84 461,333.53 4.00 325.77 Base Permafrost 1,500.00 37.60 88.90 1,417.79 1,277.39 0.94 367.15 5,927,677.25 461,372.02 4.00 363.85 1,600.00 41.59 88.37 1,494.83 1,354.43 2.48 430.86 5,927,678.45 461,435.72 4.00 426.80 1,700.00 45.58 87.91 1,567.25 1,426.85 4.73 499.75 5,927,680.35 461,504.62 4.00 494.79 1,800.00 49.57 87.51 1,634.71 1,494.31 7.68 573.49 5,927,682.92 461,578.36 4.00 567.50 1,900.00 53.56 87.16 1,696.86 1,556.46 11.33 651.71 5,927,686.17 461,656.60 4.00 644.57 1,936.18 55.00 87.04 1,717.98 1,577.58 12.82 681.05 5,927,687.50 461,685.93 4.00 673.45 2,000.00 56.60 89.45 1,753.86 1,613.46 14.43 733.80 5,927,688.84 461,738.69 4.00 725.54 2,100.00 59.19 93.04 1,807.02 1,666.62 12.55 818.45 5,927,686.52 461,823.32 4.00 809.70 2,200.00 61.87 96.45 1,856.22 1,715.82 5.31 905.19 5,927,678.84 461,910.01 4.00 896.64 2,264.67 63.65 98.56 1,885.82 1,745.42 -2.21 962.19 5,927,671.02 461,966.97 4.00 954.13 2,300.00 63.65 98.56 1,901.50 1,761.10 -6.92 993.50 5,927,666.15 461,998.25 0.00 985.79 2,400.00 63.65 98.56 1,945.87 1,805.47 -20.26 1,082.11 5,927,652.35 462,086.78 0.00 1,075.39 2,500.00 63.65 98.56 1,990.25 1,849.85 -33.60 1,170.73 5,927,638.56 462,175.32 0.00 1,164.99 2,600.00 63.65 98.56 2,034.63 1,894.23 -46.94 1,259.34 5,927,624.76 462,263.86 0.00 1,254.59 2,700.00 63.65 98.56 2,079.01 1,938.61 -60.28 1,347.96 5,927,610.96 462,352.39 0.00 1,344.19 2,800.00 63.65 98.56 2,123.38 1,982.98 -73.62 1,436.57 5,927,597.17 462,440.93 0.00 1,433.79 2,900.00 63.65 98.56 2,167.76 2,027.36 -86.96 1,525.19 5,927,583.37 462,529.47 0.00 1,523.39 3,000.00 63.65 98.56 2,212.14 2,071.74 - 100.31 1,613.80 5,927,569.57 462,618.00 0.00 1,612.99 3,100.00 63.65 98.56 2,256.52 2,116.12 - 113.65 1,702.42 5,927,555.78 462,706.54 0.00 1,702.59 3,200.00 63.65 98.56 2,300.89 2,160.49 - 126.99 1,791.03 5,927,541.98 462,795.07 0.00 1,792.19 3,300.00 63.65 98.56 2,345.27 2,204.87 - 140.33 1,879.65 5,927,528.18 462,883.61 0.00 1,881.79 3,400.00 63.65 98.56 2,389.65 2,249.25 - 153.67 1,968.26 5,927,514.39 462,972.15 0.00 1,971.39 3/5/2010 9:25:58AM Page 3 COMPASS 2003.16 Build 69 f • • Halliburton HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co - ordinate Reference: Well Plan: 2L -310 (Oscar) Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Staked: 2L -310 @ 140.40ft (D16 (114.9 +25.5)) Project: Kuparuk River Unit MD Reference: Staked: 2L -310 @ 140.40ft (D16 (114.9 +25.5)) Site: Kuparuk 2L Pad North Reference: True Well: Plan: 2L -310 (Oscar) Survey Calculation Method: Minimum Curvature Wellbore: 2L -310 (Oscar) Design: 2L -310 (wp02) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/ -W Northing Easting DLS Vert Section (ft) C) C) (ft) ft (ft) (ft) (ft) (ft) 2,293.63 3,500.00 63.65 98.56 2,434.03 2,293.63 - 167.01 2,056.88 5,927,500.59 463,060.68 0.00 2,060.99 Sfc Csg @ 3500' MD, 2434' TVD: 335' FNL, 1411' FWL - Sec23,T10N,R07E - 10 3/4" 3,600.00 63.65 98.56 2,478.40 2,338.00 - 180.35 2,145.49 5,927,486.79 463,149.22 0.00 2,150.59 3,649.57 63.65 98.56 2,500.40 2,360.00 - 186.96 2,189.42 5,927,479.95 463,193.10 0.00 2,195.00 C - 80 3,700.00 63.65 98.56 2,522.78 2,382.38 - 193.69 2,234.11 5,927,473.00 463,237.76 0.00 2,240.18 3,791.53 63.65 98.56 2,563.40 2,423.00 - 205.90 2,315.22 5,927,460.37 463,318.79 0.00 2,322.20 CAMP SST 3,800.00 63.65 98.56 2,567.16 2,426.76 - 207.03 2,322.72 5,927,459.20 463,326.29 0.00 2,329.78 3,900.00 63.65 98.56 2,611.54 2,471.14 - 220.37 2,411.34 5,927,445.40 463,414.83 0.00 2,419.38 4,000.00 63.65 98.56 2,655.91 2,515.51 - 233.71 2,499.96 5,927,431.61 463,503.37 0.00 2,508.98 4,100.00 63.65 98.56 2,700.29 2,559.89 - 247.05 2,588.57 5,927,417.81 463,591.90 0.00 2,598.58 4,200.00 63.65 98.56 2,744.67 2,604.27 - 260.39 2,677.19 5,927,404.01 463,680.44 0.00 2,688.18 4,300.00 63.65 98.56 2,789.05 2,648.65 - 273.73 2,765.80 5,927,390.22 463,768.98 0.00 2,777.78 4,400.00 63.65 98.56 2,833.42 2,693.02 - 287.07 2,854.42 5,927,376.42 463,857.51 0.00 2,867.38 4,500.00 63.65 98.56 2,877.80 2,737.40 - 300.41 2,943.03 5,927,362.62 463,946.05 0.00 2,956.98 4,600.00 63.65 98.56 2,922.18 2,781.78 - 313.75 3,031.65 5,927,348.83 464,034.59 0.00 3,046.58 4,700.00 63.65 98.56 2,966.56 2,826.16 - 327.09 3,120.26 5,927,335.03 464,123.12 0.00 3,136.18 4,800.00 63.65 98.56 3,010.93 2,870.53 - 340.43 3,208.88 5,927,321.23 464,211.66 0.00 3,225.78 4,900.00 63.65 98.56 3,055.31 2,914.91 - 353.78 3,297.49 5,927,307.44 464,300.19 0.00 3,315.38 5,000.00 63.65 98.56 3,099.69 2,959.29 - 367.12 3,386.11 5,927,293.64 464,388.73 0.00 3,404.98 5,100.00 63.65 98.56 3,144.07 3,003.67 - 380.46 3,474.72 5,927,279.84 464,477.27 0.00 3,494.58 5,200.00 63.65 98.56 3,188.44 3,048.04 - 393.80 3,563.34 5,927,266.04 464,565.80 0.00 3,584.18 5,300.00 63.65 98.56 3,232.82 3,092.42 - 407.14 3,651.95 5,927,252.25 464,654.34 0.00 3,673.78 5,400.00 63.65 98.56 3,277.20 3,136.80 - 420.48 3,740.57 5,927,238.45 464,742.88 0.00 3,763.38 5,500.00 63.65 98.56 3,321.58 3,181.18 - 433.82 3,829.18 5,927,224.65 464,831.41 0.00 3,852.98 5,600.00 63.65 98.56 3,365.96 3,225.56 - 447.16 3,917.80 5,927,210.86 464,919.95 0.00 3,942.58 5,700.00 63.65 98.56 3,410.33 3,269.93 - 460.50 4,006.41 5,927,197.06 465,008.49 0.00 4,032.18 5,800.00 63.65 98.56 3,454.71 3,314.31 - 473.84 4,095.03 5,927,183.26 465,097.02 0.00 4,121.78 5,900.00 63.65 98.56 3,499.09 3,358.69 - 487.18 4,183.65 5,927,169.47 465,185.56 0.00 4,211.38 6,000.00 63.65 98.56 3,543.47 3,403.07 - 500.52 4,272.26 5,927,155.67 465,274.10 0.00 4,300.98 6,100.00 63.65 98.56 3,587.84 3,447.44 - 513.86 4,360.88 5,927,141.87 465,362.63 0.00 4,390.58 6,200.00 63.65 98.56 3,632.22 3,491.82 - 527.20 4,449.49 5,927,128.08 465,451.17 0.00 4,480.18 6,300.00 63.65 98.56 3,676.60 3,536.20 - 540.54 4,538.11 5,927,114.28 465,539.71 0.00 4,569.78 6,400.00 63.65 98.56 3,720.98 3,580.58 - 553.88 4,626.72 5,927,100.48 465,628.24 0.00 4,659.38 6,500.00 63.65 98.56 3,765.35 3,624.95 - 567.22 4,715.34 5,927,086.69 465,716.78 0.00 4,748.98 6,567.71 63.65 98.56 3,795.40 3,655.00 - 576.26 4,775.34 5,927,077.35 465,776.72 0.00 4,809.65 C - 50 6,600.00 63.65 98.56 3,809.73 3,669.33 - 580.56 4,803.95 5,927,072.89 465,805.31 0.00 4,838.58 6,700.00 63.65 98.56 3,854.11 3,713.71 - 593.91 4,892.57 5,927,059.09 465,893.85 0.00 4,928.18 6,800.00 63.65 98.56 3,898.49 3,758.09 - 607.25 4,981.18 5,927,045.30 465,982.39 0.00 5,017.78 6,900.00 63.65 98.56 3,942.86 3,802.46 - 620.59 5,069.80 5,927,031.50 466,070.92 0.00 5,107.38 7,000.00 63.65 98.56 3,987.24 3,846.84 - 633.93 5,158.41 5,927,017.70 466,159.46 0.00 5,196.98 7,100.00 63.65 98.56 4,031.62 3,891.22 - 647.27 5,247.03 5,927,003.91 466,248.00 0.00 5,286.58 7,200.00 63.65 98.56 4,076.00 3,935.60 - 660.61 5,335.64 5,926,990.11 466,336.53 0.00 5,376.18 3/5/2010 9:25:58AM Page 4 COMPASS 2003.16 Build 69 O1G1 • • Halliburton HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co - ordinate Reference: Well Plan: 2L -310 (Oscar) Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Staked: 2L -310 © 140.40ft (D16 (114.9 +25.5)) Project: Kuparuk River Unit MD Reference: Staked: 2L -310 © 140.40ft (D16 (114.9 +25.5)) Site: Kuparuk 2L Pad North Reference: True Well: Plan: 2L -310 (Oscar) Survey Calculation Method: Minimum Curvature Wellbore: 2L -310 (Oscar) Design: 2L -310 (wp02) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N /-S +E/ -W Northing Easting DLS Vert Section (ft) r) ( *) (ft) ft (ft) (ft) (ft) (ft) 3,979.97 7,300.00 63.65 98.56 4,120.37 3,979.97 - 673.95 5,424.26 5,926,976.31 466,425.07 0.00 5,465.78 7,400.00 63.65 98.56 4,164.75 4,024.35 - 687.29 5,512.87 5,926,962.52 466,513.61 0.00 5,555.38 7,491.60 63.65 98.56 4,205.40 4,065.00 - 699.51 5,594.04 5,926,949.88 466,594.70 0.00 5,637.45 C 7,500.00 63.65 98.56 4,209.13 4,068.73 - 700.63 5,601.49 5,926,948.72 466,602.14 0.00 5,644.98 7,600.00 63.65 98.56 4,253.51 4,113.11 - 713.97 5,690.10 5,926,934.92 466,690.68 0.00 5,734.58 7,700.00 63.65 98.56 4,297.88 4,157.48 - 727.31 5,778.72 5,926,921.13 466,779.22 0.00 5,824.18 7,800.00 63.65 98.56 4,342.26 4,201.86 - 740.65 5,867.33 5,926,907.33 466,867.75 0.00 5,913.78 7,900.00 63.65 98.56 4,386.64 4,246.24 - 753.99 5,955.95 5,926,893.53 466,956.29 0.00 6,003.38 7,942.28 63.65 98.56 4,405.40 4,265.00 - 759.63 5,993.41 5,926,887.70 466,993.72 0.00 6,041.26 C 8,000.00 63.65 98.56 4,431.02 4,290.62 - 767.33 6,044.57 5,926,879.74 467,044.82 0.00 6,092.98 8,100.00 63.65 98.56 4,475.39 4,334.99 - 780.67 6,133.18 5,926,865.94 467,133.36 0.00 6,182.58 8,200.00 63.65 98.56 4,519.77 4,379.37 - 794.01 6,221.80 5,926,852.14 467,221.90 0.00 6,272.18 8,300.00 63.65 98.56 4,564.15 4,423.75 - 807.35 6,310.41 5,926,838.35 467,310.43 0.00 6,361.78 8,400.00 63.65 98.56 4,608.53 4,468.13 - 820.69 6,399.03 5,926,824.55 467,398.97 0.00 6,451.38 8,500.00 63.65 98.56 4,652.90 4,512.50 - 834.04 6,487.64 5,926,810.75 467,487.51 0.00 6,540.98 8,600.00 63.65 98.56 4,697.28 4,556.88 - 847.38 6,576.26 5,926,796.96 467,576.04 0.00 6,630.58 8,700.00 63.65 98.56 4,741.66 4,601.26 - 860.72 6,664.87 5,926,783.16 467,664.58 0.00 6,720.18 8,800.00 63.65 98.56 4,786.04 4,645.64 - 874.06 6,753.49 5,926,769.36 467,753.12 0.00 6,809.78 8,900.00 63.65 98.56 4,830.41 4,690.01 - 887.40 6,842.10 5,926,755.57 467,841.65 0.00 6,899.38 9,000.00 63.65 98.56 4,874.79 4,734.39 - 900.74 6,930.72 5,926,741.77 467,930.19 0.00 6,988.98 9,100.00 63.65 98.56 4,919.17 4,778.77 - 914.08 7,019.33 5,926,727.97 468,018.73 0.00 7,078.58 9,200.00 63.65 98.56 4,963.55 4,823.15 - 927.42 7,107.95 5,926,714.18 468,107.26 0.00 7,168.18 9,283.82 63.65 98.56 5,000.74 4,860.34 - 938.60 7,182.22 5,926,702.61 468,181.47 0.00 7,243.28 9,300.00 63.01 98.57 5,008.01 4,867.61 - 940.75 7,196.52 5,926,700.39 468,195.76 4.00 7,257.74 9,400.00 59.01 98.60 5,056.47 4,916.07 - 953.81 7,282.99 5,926,686.89 468,282.15 4.00 7,345.18 9,500.00 55.01 98.64 5,110.91 4,970.51 - 966.37 7,365.90 5,926,673.90 468,364.99 4.00 7,429.02 9,600.00 51.01 98.68 5,171.07 5,030.67 - 978.39 7,444.85 5,926,661.47 468,443.86 4.00 7,508.86 9,700.00 47.01 98.72 5,236.65 5,096.25 - 989.81 7,519.45 5,926,649.67 468,518.39 4.00 7,584.31 9,800.00 43.01 98.78 5,307.33 5,166.93 - 1,000.56 7,589.33 5,926,638.56 468,588.21 4.00 7,655.00 9,827.20 41.92 98.79 5,327.40 5,187.00 - 1,003.37 7,607.48 5,926,635.66 468,606.35 4.00 7,673.36 Top S @ 9827' MD, 5327' TVD: 1174' FNL, 1680' FWL - Sec24,T10N,R07E - S - 2L 310wp02 58 9,900.00 41.92 98.79 5,381.57 5,241.17 - 1,010.80 7,655.54 5,926,627.98 468,654.37 0.00 7,721.99 10,000.00 41.92 98.79 5,455.97 5,315.57 - 1,021.01 7,721.57 5,926,617.43 468,720.33 0.00 7,788.78 10,016.70 41.92 98.79 5,468.40 5,328.00 - 1,022.72 7,732.60 5,926,615.66 468,731.35 0.00 7,799.93 71.5 10,078.52 41.92 98.79 5,514.40 5,374.00 - 1,029.03 7,773.41 5,926,609.14 468,772.13 0.00 7,841.23 C35 10,100.00 41.92 98.79 5,530.38 5,389.98 - 1,031.22 7,787.59 5,926,606.87 468,786.30 0.00 7,855.57 10,192.92 41.92 98.79 5,599.52 5,459.12 - 1,040.71 7,848.94 5,926,597.07 468,847.59 0.00 7,917.64 7 5/8" 10,193.03 . 41.92 98.79 5,599.60 , 5,459.20 - 1,040.72 7,849.01 5,926,597.06 468,847.66 0.00 7,917.71 3/5/2010 9:25:58AM Page 5 COMPASS 2003.16 Build 69 RI 1P. A 1 • • Halliburton HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co - ordinate Reference: Well Plan: 2L -310 (Oscar) Company: 14 .40ft D16 114.9 +25.5 o nocoPhilli s Alaska Inc. -Ku p2 TVD Reference Staked: 2L 310 0 ( ( )) Y P (Alaska) p @ Project: Kuparuk River Unit MD Reference: Staked: 2L -310 © 140.40ft (D16 (114.9 +25.5)) Site: Kuparuk 2L Pad North Reference: True Well: Plan: 2L -310 (Oscar) Survey Calculation Method: Minimum Curvature Welibore: 2L -310 (Oscar) Design: 2L -310 (wp02) Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/ -W Northing Easting - Shape ( ( °) (ft) (ft) (ft) (ft) (ft) 2L- 310wp02 S8 0.00 0.00 5,327.40 - 1,003.37 7,607.48 5,926,635.66 468,606.35 - plan hits target center - Point 2L- 310wp02 T1.5 0.00 0.00 5,468.40 - 1,022.73 7,732.60 5,926,615.66 468,731.35 - plan hits target center - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (') ( 3,500.00 2,434.03 10 3/4" 10 -3/4 12 -1/4 10,192.92 5,599.52 7 5/8" 7 -5/8 9 -7/8 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology ( °) (°) 6,567.71 3,795.40 C -50 0.00 3,791.53 2,563.40 CAMP _ SST 0.00 9,827.20 5,327.40 S -8 0.00 7,942.28 4,405.40 C -37 0.00 3,649.57 2,500.40 C -80 0.00 1,434.98 1,365.40 Base Permafrost 0.00 7,491.60 4,205.40 C -40 0.00 10,078.52 5,514.40 C35 0.00 10,016.70 5,468.40 T1.5 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N /S +E/ -W (ft) (ft) (ft) (ft) Comment 25.50 25.50 0.00 0.00 SHL: 167' FNL, 646' FEL - Sec22,T10N,R07E 3,500.00 2,434.03 0.00 0.00 Sfc Csg @ 3500' MD, 2434' TVD: 335' FNL, 1411' FWL - Sec23,T10N,R07E 9,827.20 5,327.40 0.00 69.46 Top S -8 @ 9827' MD, 5327' TVD: 1174' FNL, 1680' FWL - Sec24,T10N,R07E 10,193.03 5,599.60 0.00 224.53 BHL @ 10193' MD, 5600' TVD: 1212' FNL, 1921' FWL - Sec24,T10N,R07E 3/5/2010 9:25:58AM Page 6 COMPASS 2003.16 Build 69 0R1G1NAL ConocoPhilll aaska ConocoPhillips Alaska, Inc. • Kuparuk River Unit Kuparuk 2L Pad 7 Plan: 2L -310 (wp02) 1/4 Mile Pool Scan Sperry Drilling Services re March 9, 2010 • HAL..L.IBURTON 0 Sperry Drilling Closest in POOL Closest Approach: Reference Well: 2L -310 (wp02) Plan Offset Well: 2L -311 3 -D ctr-ctr Horizontal Subsea Meas. Subsea Coords. - ASP View VS Meas. Subsea Coords. - ASP View VS Distance. Distance Difference Depth Incl. Angle TRUE Azi. TVD N( +)/S( -) E( +)/W( -) (97.551 Comments Depth Incl. Angle TRUE Azi. TVD N( +) /S( -) E( +)/W( -) (97.55 °) Comments POOL Min Distance POOL Min Distance (1164.07 ft) in POOL (1164.07 ft) in POOL (5187 - 5459.72 (5187 - 5459.72 TVDss) to 2L -311 TVDss) to 2L -310 (5194 - 5518.85 (wp02) Plan (5194 - 1164.07 1131.94 - 271.6152 10192.92 41.92 98.79 5459.72 5926345.83 1608881.74 7917.32 TVDss) 11037.06 55.33 98.17 5188.10 5925710.75 1609818.73 8946.32 5518.85 TVDss) Closest Approach: Reference Well: 2L -310 (wp02) Plan Offset Well: 2L -307 3 -D ctr-ctr Horizontal Suh<ea Meas. Subsea Coords. - ASP View VS Meas. Subsea Coords. - ASP View VS Distance. Distance Difference Depth Incl. Angle TRUE Azi. TVD N( +) /S( -) E( +)AN( -) (97.55 °) Comments Depth Incl. Angle TRUE Azi. TVD N( +) /S( -) E( +)/W( -) (97.55 °) Comments POOL Min Distance POOL Min Distance (2174.75 ft) in POOL (2174.75 ft) in POOL (5187 - 5459.72 (5187 - 5459.72 TVDss) to 2L -307 TVDss) to 2L -310 • (5174 - 5613.28 (wp02) Plan (5174 - 2174.75 2171.99 109.50354 9827.10 41.92 98.79 5187.52 5926384.45 1608640.40 7672.98 TVDss) 9165.40 55.42 131.95 5297.02 5924826.54 1607126.97 6344.34 5613.28 TVDss) Closest Approach: Reference Well: 2L -310 (wp02) Plan Offset Well: 2L -304 (wp06) C / 3 -D ctr-ctr Horizontal Subsea Meas. Subsea Coords. - ASP View VS Meas. Subsea Coords. - ASP View VS Distance. Distance Difference Depth Incl. Angle TRUE Azi. TVD N( +) /S( -) E( +)/W( -) (97.55 °) Comments Depth Ind. Angle TRUE Azi. TVD N( +)/S( -) E( +)/W( -) (97.55 °) Comments POOL Min Distance POOL Min Distance (4089.5 ft) in POOL (4089.5 ft) in POOL (5187 - 5459.72 (5187 - 5459.72 G ") TVDss) to 2L -304 TVDss) to 2L -310 ,, J (wp06) (5260 - (wp02) Plan (5260 - 4089.5 - 4084.15 - 209.1252 10192.92 41.92 98.79 5459.72 5926345.83 1608881.74 7917.32 5512.92 TVDss) 13836.50 56.76 144.51 5250.59 5926097.85 1612958.35 11905.57 5512.92 TVDss) e • POOL Summary Templatel.bs 3/9/2010 8:12 AM 1-IALLUBURTON Project: Kuparuk River Unit WELL DETAILS: Plan 2L-310 (Oscar) Site: Kuparuk 2L Pad Ground Level: 114.90 Sperry Drain. !ivory's's& Well: Plan: 2L -310 (Oscar) +NI -S +E/ -W Northing Easting Latittude Longitude Slot Wellbore: 2L -310 (Oscar) 0.00 0.00 5927427.42 1601038.64 7E 12' 46.967 N 150° 19' 3.316 W - Plan: 2L -310 (wp02) REFERENCE INFORMATION 1500- Co-ordinate (N/E) Reference: Well Plan: 2L -310 (Oscar), True North - Vertical (TVD) Reference: Staked: 2L-310 @ 140.400 (D16 (114.9025.5)) - Measured Depth Reference: Staked: 2L-310 @ 140.400 (D16 (114.9 +25.5)) - 1000— Calculation Method: Minimum Curvature 500- - 4 - 10 3/4" 10 3/4" 121- 310wp02 1/4 Mile' -500— " 7 5/8" -1000 ' - - 21-310 (wp0) o') II _ / j ?A\ -1500— � ti ti - 81 /2"4. .. y' r..., 51/2" y T, - 2000 — 31/2" A -2500 o - V -3000 — y 0 -3500 — - r 4000 — ~ o _ -4500 — • -5000 - -5500— • -6000— 7" -6500— " -' � -7000— - T M Azimuths to True North CASING DETAILS Magnetic North: 21.45° - TVD TVDSS MD Size Name -7500— Magnetic Field 2434.03 2293.63 3500.00 10 -3/4 10 3/4" Strength: 4snT Dip Angle: gle' 80.70° 5599.60 5459.20 10192.92 7 -5/8 7 5/8" Date: 3/29/2010 -8000— Model: BGGM2009 III I II ijiiiiiiiIIIIIII I IIIII iii ii[ 111I11r1 1 11111111111 111I1111I[IIliii i iiiiii IIIIIIIIIII IIIIIIIIII II I II IIII IIII I IIIII III 1111 IIIIIIII II I II II IIIII -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 17000 17500 15000 West( - )/East( +) (1500 ft/in) ConocOPhi lips Ala.). Project: Kuparuk River Unit Conoc oP11 Site: Kuparuk 2L Pad VI lU4Vr"� p Well: Plan: 2L -310 (Oscar) Wellbore: 2L-310 (Oscar) V32C HAL.LtBEJRTON Plan: 2L-310 (wp02) (Plan: 2L -310 (Oscar) /2L -310 (Oscar)) around Level: 114.90 RKB: Staked: 2L310 @ 140.40tt (D16 (114.9 +25.5)) NorthingIASP Y: 5927427.42 Eanting /ASP X: 1601038.64 III 0 frs \ 1500 ...................... 9 5h 9 10 3/4" • 3000 r~ ......... 8 1/2" Open Hole 5 1/2" '�I ice" 3 1/2" ....... 7 5/8" • 2L- 309PB1 7 5/8" ' • 7 2L 311 — ---_ 1/2'r - ---__ 2L -304 (wp06) .,..... . • -310 0 2L-309 1 1500 0 _ soc o _soc co CT 4 o o o o° o —B 0 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad Plan: 2L -310 (Oscar) 2L -310 (Oscar) 2L -310 (wp02) • Sperry Drilling Services Clearance Summary Anticollision Report 04 March, 2010 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2L Pad - Plan: 2L-310 (Oscar) - 2L-310 (Oscar) - 2L -310 (wp02) Well Coordinates: 5,927,427.42 N, 1,601,038.64 E (70° 12' 46.97" N, 150° 19' 03.32" W) • Datum Height: Staked: 2L-310 @ 140.40ft (D16 (114.9 +25.5)) Scan Range: 0.00 to 10,192.92 ft. Measured Depth. Scan Radius is 1,216.74 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 69 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services SURVEY PROGRAM ConocoPhillips (Alaska) Inc. -Kup2 ANTI - COLLISION SETTINGS Date: 2010-03-02T00:00:00 Validated: Yes Version: Calculation Method: Minimum Curvature Interpolation Method: MD, interval: 25.00 Error System: ISCWSA Depth Range From: 25.50 To 10192.92 Depth FromDepth To Survey/Plan Tool Scan Method: Tray. Cylinder North Centre Distance: 1216.74 25.50 1199.60 2L-310 (wp02) (21-310 (Oscar)) CB- GYRO -SS Error Surface: Elliptical Conic Reference: Plan: 2L-310 (wp02) (Plan: 2L-310 (Oscar) /2L -310 (Oscar 1199.60 3499.60 21-310 (wp02) (21-310 (Oscar)) MWD +EFR- AK -CAZ-SC Warning Method: Rules Based 3499.60 10192.33 21-310 (wp02) (21-310 (Oscar)) MWD +IFR- AK -CAZ-SC GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100 /1000 of reference 12L-03I o 0. I 2L -300 330 ; -- v � 30 2L-304 I2L -31@ MEE ' , .. q 330 ]r: 30 if Wko illp F y %' . -,. From Colour To MD I I. * 300 III u ♦ j : �� 300 i� ' { r- � i . �i e i '� 2L304 (wp0 25 2 f �, 4, - ,i. .►' ' 60 .,,y, ,,::,. . d. / / - - t i ► • � �'� 250 500 � 24/� ��fFf�tt� 0, f i,l 500 750 �I' ,,;!! " \" 750 1000 I l I 27 P1))1'1::'}, I it 1000 1250 + o ��I + ] ' r l I`I�� r11�1ti A +r� V / / /�/ ) 1 1250 1500 ° itll��h r •n .r..+ I2L -30 - �r /t «. v � , Ili(' NN41.. ,( u _ 15 1750 * • ; v b►t aa` 0 , , r �' 1750 2000 ` * �'� �:'�: i� � �� I 2L 32 _ or^ amp r .s :� :. ,�� `� \� .'. r r _ { ', \ � J 2000 3000 24 � s w p'S 8 F ,. . . 4 • \�\ I2L -32�' c I f 0 s - wov a + a \� a 4 y y' 4r r , - ' 1 > se '' .« c tm \ / 120 e J l F i y sis' +Wk o+ • a+.r. „ - i' Lh $ r A 3000 - 4000 ' 2L -31- 2 49 �� °' r , � = 40 00 5000 • ° `` i "s. ,,,+ tv � ''At*,' \ \1 t ` t ( 0 ) 120 t 2L 322wp�1 � ; r " ,� 5000 6000 2 1 0 0 6 : 4+ 1 1 ' / l ' r , t 150 .• ; 6000 8000 180 • SZE 2L -31; •.. 8000 10000 2L -307 I r" I2L -30 2L -307 210 EXIII 2L- 309PBII Travelling Cylinder (TFO+AZI) Separation 150 ) 180 g �' ( ) ( °] vs Centre to Centre Se aration 50 fUn 2L -30' Travelling Cylinder Azimuth (TFO+AZI) [ °] vs Centre to Centre Separation [200 ft/in] SECTION DETAILS Sec MD I + +E Se 1 25.50 0.00 nc 0,00 Azi 25.50 TVD 0.00 N / -S 0.00 E / -W 0.00 DLeg TFa 0 Vc .00 0.00 00 Target 2 .... 3 846.68 330.00 15.50 0.00 90.00 0.00 840.40 330.00 0.00 0.00 69.46 000 3.00 000 90.00 000 68.86 0 4 1239.15 31.20 90.00 1199.60 0.00 224.53 4.00 0.00 222.58 Details: Plan: 2L - 310 (Oscar) North American Datum 1983 Alaska Zone 4 5 1339.15 31.20 90.00 1285.14 0.00 276... 6 1936.18 55.00 87.04 1717.98 12.82 681.05 33 4 00 -6 .00 673.46 273.94 7 2264.60 63.65 98.56 1885.78 - 2.19 962.13 4.00 51.94 954.07 Ground Level: 114.90 8 9283.72 63.65 98.56 5000.75 - 938.11 7182.19 0.00 0.00 7243.18 +N / - S +E / - W Northing Easting Latittude Longitude Slot 9 9827.10 41.92 98.79 5327.40 - ...9t 02 S8 0.00 0.00 5927427.42 1601038.64 70 12' 46.967 N 150° 19' 3.316 W to 10192.92 41.82 98.79 5599.60 - toao 86 7ba8.s7 760744 0.00 400 17 0.00 .58 7617.60 7673.26 2L -310w ConocoPhillips (Alaska) Inc. -Kup2 HALLI B U RT ©N Kuparuk River Unit Anticollision Report for Plan: 2L -310 (Oscar) - 2L -310 (wp02) Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2L Pad - Plan: 2L -310 (Oscar) - 2L -310 (Oscar) - 2L -310 (wp02) Scan Range: 0.00 to 10,192.92 ft. Measured Depth. Scan Radius is 1,216.74 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft Kuparuk 2L Pad • 2L -03 - 2L -03 - 2L -03 816.79 91.58 816.79 76.10 800.00 5.916 Centre Distance Pass - Major Risk 2L-03 - 2L -03 - 2L -03 842.18 91.63 842.18 75.64 825.00 5.731 Clearance Factor Pass - Major Risk 2L -301 - 2L -301 - 2L -301 822.79 110.82 822.79 94.25 800.00 6.688 Centre Distance Pass - Major Risk _- -1 2L -301 - 2L -301 - 2L -301 848.54 111.05 848.54 94.04 825.00 6.530 Clearance Factor Pass - Major Risk °-) 2L -305 - 2L -305 - 2L -305 829.82 43.65 829.82 28.19 825.00 2.824 Centre Distance Pass - Major Risk . 3 2L -305 - 2L -305 - 2L -305 854.52 44.17 854.52 28.17 850.00 2.760 Clearance Factor Pass - Major Risk �,. 2L -307 - 2L -307 - 2L -307 140.40 45.19 140.40 42.76 152.05 18.583 Centre Distance Pass - Major Risk k ...; 2L -307 - 2L -307 - 2L -307 1,650.28 63.96 1,650.28 23.81 1,625.00 1.593 Clearance Factor Pass - Major Risk 2L -309 - 2L -309 - 2L -309 25.50 14.94 25.50 14.03 33.98 16.382 Centre Distance Pass - Major Risk e e 2L - 309 - 2L - 309 - 2L - 309 769.99 21.00 769.99 6.04 775.00 1.404 Clearance Factor Pass - Major Risk 4 2L - 309 - 2L 309PB1 - 2L 309PB1 25.50 14.94 25.50 14.03 33.98 16.382 Centre Distance Pass - Major Risk 2L - 309 - 2L 309PB1 - 2L 309PB1 769.99 21.00 769.99 6.04 775.00 1.404 Clearance Factor Pass - Major Risk i 2L -311 - 2L -311 - 2L -311 396.64 12.32 396.64 4.97 400.00 1.675 Centre Distance Pass - Major Risk 2L -311 - 2L -311 - 2L -311 446.34 12.87 446.34 4.58 450.00 1.553 Clearance Factor Pass - Major Risk 2L -313 - 2L -313 - 2L -313 140.40 44.78 140.40 42.22 146.05 17.479 Centre Distance Pass - Major Risk 2L -313 - 2L -313 - 2L -313 368.47 45.22 368.47 38.52 375.00 6.746 Clearance Factor Pass - Major Risk 2L -315 - 2L -315 - 2L -315 140.40 75.04 140.40 72.48 146.10 29.288 Centre Distance Pass - Major Risk • 2L -315 - 2L -315 - 2L -315 319.29 77.02 319.29 71.16 325.00 13.129 Clearance Factor Pass - Major Risk 2L -317 - 2L -317 - 2L -317 479.76 97.55 479.76 88.46 500.00 10.727 Centre Distance Pass - Major Risk 2L -317 - 2L -317 - 2L -317 575.00 98.55 575.00 87.46 600.00 8.880 Clearance Factor Pass - Major Risk 2L -317 - 2L -317A - 2L -317A 479.76 97.55 479.76 88.46 500.00 10.727 Centre Distance Pass - Major Risk 2L -317 - 2L -317A - 2L -317A 575.00 98.55 575.00 87.46 600.00 8.880 Clearance Factor Pass - Major Risk 2L -319 - 2L -319 - 2L -319 1,624.05 62.73 1,624.05 27.43 1,750.00 1.777 Centre Distance Pass - Major Risk 2L -319 - 2L -319 - 2L -319 1,647.03 63.09 1,647.03 26.70 1,775.00 1.733 Clearance Factor Pass - Major Risk 2L -321 - 2L -321 - 2L -321 343.19 163.92 343.19 157.66 350.00 26.150 Centre Distance Pass - Major Risk 2L -321 - 2L -321 - 2L -321 366.27 164.11 366.27 157.40 375.00 24.480 Clearance Factor Pass - Major Risk 2L -323 - 2L -323 - 2L -323 343.01 194.47 343.01 188.16 350.00 30.842 Centre Distance Pass - Major Risk 2L -323 - 2L -323 - 2L -323 365.75 194.70 365.75 187.97 375.00 28.910 Clearance Factor Pass - Major Risk 04 March, 2010 - 14:56 Page 2 of 5 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 HALLI BU RT ©N Kuparuk River Unit Anticollision Report for Plan: 2L -310 (Oscar) - 2L -310 (wp02) Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2L Pad - Plan: 2L -310 (Oscar) - 2L -310 (Oscar) - 2L -310 (wp02) Scan Range: 0.00 to 10,192.92 ft. Measured Depth. Scan Radius is 1,216.74 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft 2L -325 - 2L -325 - 2L -325 140.40 224.94 140.40 222.38 146.20 87.795 Centre Distance Pass - Major Risk 2L -325 - 2L -325 - 2L -325 319.17 227.45 319.17 221.63 325.00 39.099 Clearance Factor Pass - Major Risk Plan: 2L -304 (Tango) - 2L -304 - 2L -304 (wp06) 1,297.86 82.57 1,297.86 57.80 1,250.00 3.332 Centre Distance Pass - Major Risk • Plan: 2L -304 (Tango) - 2L -304 - 2L -304 (wp06) 1,322.86 82.61 1,322.86 57.56 1,275.00 3.297 Clearance Factor Pass - Major Risk Plan: 2L -322 - Plan: 2L -322 - 2L- 322wp01 319.20 179.94 319.20 173.06 325.00 26.185 Centre Distance Pass - Major Risk Plan: 2L -322 - Plan: 2L -322 - 2L- 322wp01 365.90 180.29 365.90 172.39 375.00 22.810 Clearance Factor Pass - Major Risk ,,, . Survey tool program eta.' >" From To Survey /Plan Survey Tool ,....� (ft) (ft) 25.50 1,199.60 2L -310 (wp02) CB- GYRO -SS 1,199.60 3,499.60 2L -310 (wp02) MWD +IFR- AK- CAZ -SC 3,499.60 10,192.33 2L -310 (wp02) MWD +IFR- AK- CAZ -SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. • Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 04 March, 2010 - 14:56 Page 3 of 5 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 HALLIBURTDN Kuparuk River Unit Anticollision Report for Plan: 2L -310 (Oscar) - 2L -310 (wp02) Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Staked: 2L -310 @ 140.40ft (D16 (114.9 +25.5)). Northing and Easting are relative to Plan: 2L -310 (Oscar). Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is - 150.00°, Grid Convergence at Surface is: -0.30 °. Ladder PI at _ • n •a r,;, � 4I � � LEGEND , , i" �, �i� i FA � �, • - 2L-03, 2L-03, 2L -03 V2 1050 t ' „ ��' ► _ O ► , r 1 il �' ' $ 2L -301, 2L -301, 2L -301 VO p I � ► 1 i� „�' $ 2L -305, 2L -305, 2L -305 V2 CO " - 1 :, �, ❑ 0 : (' i $ 2L -307, 2L -307, 2L -307 V2 C ,;t p „ I O �,1 �� $ 2L -309, 2L - 2L -309 V5 p 31 p .d � -'" : - 1 -e- 2L -309, 2L-309PB1, 2L-309PB1 V6 �a 700 al �o �� , • -_- 2 311,2L- 311,2E -311 VO 7. N 1 . i ', 1 : rA i - ( I -4- 2L -313, 2L -313, 2L -313 V2 N , -011 $ 2L -317, 2L -317A 2L- 317AV6 O 350 10 � " V % � _ - � 2L-319, 2E -319, 2L-319 V4 N f I i A � , " , i� , i $ 2L -321, 2L -321, 2L -321 V2 -a' . , �� $ 2L -323, 2L -323, 2L -323 V2 0 N '! , -$- 2L -325, 2L -325, 2L -325 V2 m ; • ►�. • ■ $ Plan: 2L -304 (Tango), 2L -304, 2L -304 (wp06) V0 44 E; -;. = � : 1 , , , , $ Plan: 2L -322, Plan: 2L -322, 2L- 322wp01 V2 0 - -1- -8- 2L-310 (wp02) 0 2000 4000 6000 8000 10000 Measured Depth (2000 ft/in) 04 March, 2010 - 14:56 Page 4 of 5 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 HALL I B U RTD N Kuparuk River Unit Anticollision Report for Plan: 2L -310 (Oscar) - 2L -310 (wp02) Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor 0 I f 10.n I i �1 - - - Irr� Ea I I t • i �j �� LEGEND 8.7 ; rj ,� 0 a il , I _ ` I. :.' �, it -E- 2L -03, 2L -03, 2L -03 V2 ,� �. r � -9- 2L301,2L301,2L301 VO 2 7. ' , ' �� = I r, ..................._ -8- 2L-305, 2L-305, 2L-305 V2 ,7 " 2L307, 2L307, 2L-307 V2 pe ... 5e , : t � -9- 2L309, 2L309, 2L-309 V5 1 , -e- 2L309,2L309PB1,2L309PB1V6 .o.a Il , �° ��: ``� $ 2L311,2L311,2L311V0 ., 1:' I (/ ► "� = ` i , � � /.. ei � 7 - - - J 1 = �i • ,:: - - $ 2L317, 2L-317A, 2L317AV6 « 4 ; � � I: � -F 2L319, 2L319, 2L319 V4 I '' $ 2L321,2L321,2L321V2 � �� - - 2L323, 2L323, 2L323 V2 A� �� ( 1 $ 2L325, 2L -325, 2L325 V2 1.25_ _ i $ Plan: 2L304 (Tango), 2L304, 2L304 (vp06) VO III -4- Plan: 2L-322, Plan: 2L-322, 2L-322wp01 V2 _ -9- 2L310(wp02) 0.00 1 1 1 1 11 1 1 1 1 1 1 1 1 1 11 1 1 1 1 1 1 III, 1 1 1 1 i 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 i 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 Measured Depth (2000 ft/in) 04 March, 2010 - 14:56 Page 5 of 5 COMPASS • • 2L -310 Drilling Hazards Summary 13 -1/2" Hole / 10 -3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate • If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Lecithin. Gravel / Sand Sloughing Moderate Increase mud weight / viscosity, High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill (use of Trips trip sheets), Pumping out of hole as needed. Lost Circulation Low Prevent by keeping hole clean. If losses occur - reduce pump rates and mud rheology, use LCM 9 -7/8" Hole / 7 -5/8" Casing Interval Event Risk Level Mitigation Strategy Shale stability in HRZ and K -1 Moderate Control with higher MW and proper drilling practices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills, Shut -in Drills, PWD Tools, Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. t R 2L -310 Hazards.doc P repared by Mike Greener Page 1 of 1 1 Iv" I 2L-310 Pre-Produced Injector tcnixxoPhillips , 3-1/2" Completion String ....... .•..•.• •:• •:•: :;: .:. :•: :.:. :•: ::: ::: :::: ::: ::: •:• •:•: •.• •.•. ::: ::: ••• • • :i:,:: .•: :•:• ::• .:•: 3 1/2" Cameo 'DS Nipple w/ 2.875" No-Go Profile, EUE 8RD 16' 164,821? ::: : i: :•: :•:• • : • • :• : mod. at -500' MD : • • : • : ... .... SCI1100 .....4 : • . • .. ::: ..:: :.: Drift tubing with 2.91" above DS Nipple 110' MD • :: :•: • :• • :• :::. :• • :: • : 3 1 9.3AI L-80 EUE 8RD mod tubing ,. • : • ::: ::• ::: . • : ::- :;: ... : • : ... r • :•: . . • :• . • • : :. • . . . • : • : • : . . . : i: -. • • : • ...- , 10-1'4" 45.56 L-80 BTC ® ..j.: „„i :: GLMit Ilmg, Setting Depth (TVD-RK13 Valve Type +/- 3,500' MD / 2,434' TVD I KBMG 2,400' Dummy Set depth depends 2 KBMG 3,600' Dummy ......... . • 3 KBMG 4,400' Dummy upon Campanian :::: • • 4 KBMG I it above Sliding Sleeve SQV ;::: •• :• . • . Sand top :•:• •::: ..... :: ::•: :::: ,. ..• r --- : •:•: .. ::i: • :::: •: :::: :• :::: •: :• •:•: • : • : A .... ••.• :• :ii •: .•.• :: •:•: •••• ' •.•. •• 3- Baker '(M1 7 Sliding Sleeve (closed) with Cameo 2.813" 'DS' profile, EUE 8RD mod, located I joint above PBR .•.• :: : MI : • :: ........, :. : • • • ilia : M 3- x 7-518" Baker FfIL Packer with PBR, EUE 8RD mod, • ::: ISINIIIIII .. :: :. :. placed <200' MD above the perforated interval - • • :•:• ••• • :• : • . :: : • 3-1/2" Cameo 'D' Nipple w12.75" No-Go Profile and RIIC plug, .• : • .. EUE 8RD mod, located 1 full joint below packer :::: • . : • :::: • : • : .: : • :• 3 'A" Wireline Entry Guide, EUE 8RD mod, located 50' MD ::.: • : above top of Bermuda :::: • : ••: • . . 0:',.....-- „. . . -. 7-5/8” 29.7P L-80 BTCM ;:;: ORIGINAL ,,,..10,193' MD i 5,600' TVD ,.:•24:.: • 9 2L-310 Schlumberger CemCADE Preliminary Job Design 10 -3/4" Surface Casing (WP -01) V1 Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 16 Volume Calculations and Cement Systems Location: Tarn Clieent: t: C PAI Volumes are based on excess Vol bd 300% in the permafrost and 50% excess below the Revision Date: 02/03/2010 permafrost. The top of the tail slurry is designed to be at 2,500' MD. Prepared by: Mike Martin Location: Anchorage, AK Lead Slurry Minimum pump time: 280 min. (pump time plus 120 min.) Phone: (907) 263 -4207 ARCTICSET Lite @ 10.7 ppg - 4.51 ft3 /sk Mobile: (907) 748 -6900 email: martin13 @slb.com 0.4293 ft /ft x (130') x 1.00 (no excess) = 56 ft 3 0.3637 ft /ft x (1605' - 130') x 4.00 (300% excess) = 2146 ft I < TOC at Surface 0.3637 ft /ft x (2500' - 1605') x 1.50 (50% excess) = 488 ft 56 ft + 2146 ft 488 ft = 2690 ft 2690 ft / 4.51 ft /sk = 597 sks Round up to 600 sks Have -270 sacks additional ASL on location for Top Out stage, if necessary. Previous Csg. Tail Slurry Minimum pump time: 190 min. (pump time plus120 min.) ' 111 < 16", 164.82# casing 12.0 ppg DeepCRETE + additives - 1.64 ft3 /sk at 130' MD 0.3637 ft /ft x (3500' - 2500') x 1.50 (50% excess) = 546 ft 0.53997 ft /ft x 80' (Shoe Joint) = 43 ft 546 ft + 43 ft = 589 ft 589 ft 1.64 ft /sk = 360 sks i Round up to 370 sks BHST = 69'F, Estimated BHCT = 65 'F. (BHST calculated using a gradient of 2.0F/100 ft. from surface • Base of Permafrost at ( 9 ' 9 surface) 1,605 MD (1,500' TVD) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW100 5.0 10.0 2.0 2.0 < Top of Tail at Pressure test lines 0.0 0.0 10.0 12.0 2,500' MD CW100 5.0 40.0 8.0 20.0 MUDPUSH II 5.0 50.0 10.0 30.0 Drop bottom plug 0.0 0.0 5.0 35.0 ASL 6.0 479.1 79.8 114.8 DeepCRETE Tail 6.0 104.9 17.5 132.3 Drop top plug 0.0 0.0 5.0 137.3 Water 5.0 20.0 4.0 141.3 Switch to rig 0.0 0.0 3.0 144.3 < 10 -3/4 ", 45.5# casing Mud 8.0 302.9 37.9 182.2 in 13 -1/2" OH Slow & bump plug 3.0 6.0 2.0 184.2 MUD REMOVAL TD at 3,500' MD (2,434' TVD) Expected Mud Properties: 9.8 ppg, P < 25, T < 35 Spacer Properties: 10.5 ppg MudPUSH* II, P = 20 -25, T = 30 -35 Centralizers: As per CPAI program. Recommend minimal per joint on Shoe and 1 per joint thru tail cement column Mark of Schlumberger ORIGINAL . . • 2L-310 Schlumberger CemCADE Preliminary Job Design 7 -5/8" Longstring (WP -01) V1 Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 16 Location: Alpine Client: CPAI Revision Date: 02/03/2010 Volume Calculations and Cement Systems Prepared by: Mike Martin o Location: Anchorage, AK Volumes are based on 50% excess. The top of the tail slurry is designed to be Phone: (907) 263 -4207 -7,750' MD (approximately 1000' TVD above T3- Bermuda). Mobile: (907) 748 -6900 email: martin13 @slb.com Tail Slurry Minimum pump time: 220 min. (pump time plus 120 min.) 15.8 ppg Class G + 2.0 gps D600G + 0.2 %D46, 0.6 %D65, 0.03 gps D177 - 1.17 ft3 /sk 0.2148 ft /ft x (10193' - 7750') x 1.50 (50% excess) = 787 ft 0.2578 ft /ft x 80' (Shoe Joint) = 21ft 787 ft + 21 ft = 808 ft 808 ft 1.17 ft /sk = 691 sks Previous Csg. Round up to 700 sks < 10 -3/4 ", 45.5.# casing at 3,500' MD BHST = 141F, Estimated BHCT = 112'F. (BHST calculated using a gradient of -2.1F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW100 5.0 30.0 6.0 6.0 MUDPUSH II 5.0 40.0 8.0 14.0 Pause 0.0 0.0 5.0 19.0 GasBLOK Slurry 6.0 143.9 24.0 43.0 Pause 0.0 0.0 5.0 48.0 Water 5.0 10.0 2.0 50.0 Pause 0.0 0.0 3.0 53.0 Mud 8.0 448.2 56.0 109.0 < Top of Cement at Mud 3.0 6.0 2.0 111.0 7,750' MD MUD REMOVAL Expected Mud Properties: 10.0 ppg, P < 15, T < 15. < 7 - 58 ", 29.7# casing in 9 off Spacer Properties: 11.5 ppg MudPUSH* II, P = 20 - 25, T = 35 - 40 Centralizers: As per CPAi program TDat 10,193' MD (5,600' TVD) ORIG!NAL Page 1 of 2 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, March 16, 2010 8:59 AM To: ' Scott.L.Lowry@conocophillips.com' Cc: Maunder, Thomas E (DOA) Subject: RE: 2L -310 Questions (PTD - 210 -028) Scott, The responses below answered my questions for the PTD application. I re- checked on the well class and will change to a WAG injector even though it will be pre - produced for an extended time.... This allows us to flag it for AOR, CBT cement log, MIT -IA, etc. & UIC compliance as it is being permitted so there are no surprises down the road when it is converted. When the 10-407 is generated it can have the well service checked off as a development during pre-production ment well durin the re- roduction p hase. Once the flowback is complete well service can be swapped to WAG with a 10-403 sundry request. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Lowry, Scott L [mailto:Scott.L.Lowry@conocophillips.com] Sent: Monday, March 15, 2010 5:16 PM To: Schwartz, Guy L (DOA) Cc: Huck, Drew Subject: 2L -310 Questions Guy, Here are answers to your questions. Please reply back to let me know you received this information, and /or if you need more information. We plan to pre - produce 2L -310 for 12 -18 months prior to putting it on injection. The well will be fractured when it is completed. The 2L -311 well is the only well within 1 /4 mile at the top of the producing reservoir. A CBL wasn't run on 2L -311. The top of cement with 50% annular excess is estimated to be 903' MD (318' TVD) above the top perforation, based on the cement volumes actually pumped (see calculations below). No fluid losses were observed during primary cementation of the production string on this well. Thus, we should have good isolation of the reservoir interval in 2L -311. In the procedure, please note the following: Prior to running 7 5/8" casing, we will change one set of pipe rams to fit around 7 5/8" pipe. Thus we will have the annular preventer and one set of pipe rams for the casing run. We will pressure test the rams prior to 250 psi /3500 psi after installation. Thanks, Scott Lowry Supervising Drilling Engineer 3/16/2010 Page 2 of 2 • • ConocoPhillips Alaska, Inc. Phone: 907 263 4247 Cell: 907 240 5322 Fax: 918 662 4498 Office Location: ATO 1504 With a 50% excess: Cement Pumped (bbl) 88.7 3 -1/2" Float Assembly Length (ft) 93 5- 1/2 "X3 -1/2" Crossover Depth (ft) 11016 TD (ft) 11605 a L - 3 / ( Hole Size (in) 8.5 (7ATA Top Perf Depth (ftMD) 11240 r f Top Perf Depth (ftTVDSS) 5305 2./6./o 3 -1/2" Float Assembly Volume (bbl) 0.81 Annular Cement Volume (bbl) 87.89 3 -1/2" Annular Volume (bbl) 34.33 5 -1/2" Annular Volume (bbl) 53.56 Total Cement Height (ft) 1268 TOC (ftMD) 10337 TOC (ftTVD) 4987 Height Over Top Perf (MD) 903 Height Over Top Perf (TVD) 318 Drew Huck Kuparuk Drilling & Wells Junior Engineer ConocoPhillips Alaska, Inc. 907 - 265 -6828 303 - 328 -5835 (Cell) 3/16/2010 • TRANSMITTAL LETTER CHECKLIST WELL NAME iek £ PTD# 2 / O Development Service Exploratory Stratigraphic Test Non - Conventional Well _ �. FIELD: c / C - 7 6-L -v /t_.. Ki Lr " r POOL: /a V %'( ( c !i Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 r ` Field & Pool KUPARUK RIVER, TARN OIL - 490165 Well Name: KUPARUK RIV U TARN 2L- 310 Program DEV Well bore seg ❑ PTD #: 2100280 Company CONOCOPHILLIPS ALASKA INC Initial Class /Type DEV / PEND GeoArea Unit 11160 - -_ On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Surface location in ADL 380052; top prod interval & TD in ADL 380051 3 Unique well name and number Yes 4 Well located in a defined pool Yes KUPARUK RIVER, TARN OIL - 490165, governed by CO 430A. 5 Well located proper distance from drilling unit boundary Yes Conforms to Conservation Order No. 430A Rule 3, which specifies 10 -acre spacing. 6 Well located proper distance from other wells Yes 17 Sufficient acreage available in drilling unit Yes Well will lie within the KRU, about 4000' from the KRU boundary. 8 If deviated, is wellbore plat included Yes 19 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 1 12 Permit can be issued without administrative approval Yes SFD 3/10/2010 1 Can permit be approved before 15 -day wait Yes • 114 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For Yes AIO 16 15 All wells within 1/4 mile area of review identified (For service well only) Yes KRU 2L -304, KRU 2L -311 16 Pre- produced injector: duration of pre production less than 3 months (For service well only) Yes 17 Nonconven. gas conforms to AS31.05.0306.1.A),(j.2.A -D) NA 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs NA No Aquifers... 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg No TOC planned for 7750' and in production casing ( 7 5/8 ") 1 22 CMT will cover all known productive horizons Yes 123 Casing designs adequate for C, T, B & permafrost Yes 124 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. All drilled wells pass major risk. 127 If diverter required, does it meet regulations Yes Diverter required Appr Date 1 28 Drilling fluid program schematic & equip list adequate Yes Max. Formation press = 3001 psi (10 ppg EMW) Will drill with 10ppg mud... with ability to raise MW. GLS 3/15/2010 1 29 BOPEs, do they meet regulation Yes (LSND MUD...can weight up mud easily to max fm ... expect fm pressure is 9-10 ppg) 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 2414 psi . Will test BOP to 3500 psi 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S on 2L pad. Rig has sensors and alarms. 1 34 Mechanical condition of wells within AOR verified (For service well only) Yes 2L -311 is only well in 1/4 mile radius... Cement is adequate for isolation. 35 Permit can be issued w/o hydrogen sulfide measures No Measures required: H2S is present in reservoir per latest KRU H2S surveys (2L -Pad wells vary from 5 to 50 ppm) Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure may be as great as 10.8 ppg; plans are to drill with 10.0 ppg mud. Appr Date 1 37 Seismic analysis of shallow gas zones NA SFD 3/10/2010 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA 1 Geologic Engineering Public Commissioner: Date: Commissioner: Date Com )'. - Date • S 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. • • Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue May 11 14:28:30 2010 Reel Header Service name LISTPE Date 10/05/11 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 10/05/11 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Field MWD /MAD LOGS WELL NAME: 2L -310 API NUMBER: 501032061600 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 11- MAY -10 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: MW- 000707601 MW- 000707601 MW- 000707601 LOGGING ENGINEER: B. STEPHENS B. SCHULZE B. SCHULZE OPERATOR WITNESS: G. WHITLOCK L. HILL L. HILL SURFACE LOCATION SECTION: 22 TOWNSHIP: 10N RANGE: 7E FNL: 167 FSL: FEL: 646 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 141.90 GROUND LEVEL: 114.90 • • WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.500 2ND STRING 9.880 10.750 3521.0 3RD STRING 9.880 10.750 3521.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 -2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER - MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR -P4), AND DRILLSTRING DYNAMICS SENSOR (DDSr) . MWD RUN 1 ALSO INCLUDED A BI -MODAL ACOUSTIC (BAT) SENSOR AND MWD RUN 2 ALSO INCLUDED A PRESSURE WHILE DRILLING (PWD) SENSOR. 4. MWD RUN 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER - MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE -4 (EWR4), AZIMUTHAL LITHO- DENSITY (ALD), COMPENSATED THERMAL NEUTRON POROSITY (CTN), DRILLSTRING DYNAMICS SENSOR (DDSr), PRESSURE WHILE DRILLING (PWD), AND AT -BIT GAMMA (ABG) UTILIZING SCINTILLATION DETECTORS, BEHIND A GEOPILOT ROTARY STEERABLE ASSEMBLY. 5. DATA FROM AT -BIT GAMMA (ABG) WAS SPLICED FROM 12,215' MD, 5,591' TVD TO 10,247.5' MD, 5,615' TVD ONTO SGRC. 6. MWD DATA ARE CONSIDERED PDC AS PER AN E -MAIL FROM PATRICK DOHERTY(CPAI) TO BRYAN BURINDA (SPERRY DRILLING) ON 10 -MAY -2010. 6. MWD RUNS 1 -3 REPRESENT WELL 2L -310 WITH API #: 50- 103 - 20616 -00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10,252'MD, 5,619'TVD. SEXP = EWR PHASE -4 9" 2 MHZ PHASE SHIFT RESISTIVITY SESP = EWR PHASE -4 15" 2 MHZ PHASE SHIFT RESISTIVITY SEMP = EWR PHASE -4 27" 2 MHZ PHASE SHIFT RESISTIVITY SEDP = EWR PHASE -4 39" 1 MHZ PHASE SHIFT RESISTIVITY SFXE = FORMATION EXPOSURE TIME EWR PHASE -4 SROP = RATE OF PENETRATION WHILE DRILLING SGRC = GAMMA RAY COMBINED • SNP2 = NEAR DETECTOR PE FACTOR (RAPID SAMPLE) LOW COUNT RATE BIN. SBD2 = BULK DENSITY COMPENSATED (RAPID SAMPLE) LOW COUNT RATE BIN SCO2 = DELTA -RHO (RAPID SAMPLE) LOW COUNT RATE BIN TNPS = THERMAL NEUTRON POROSITY - SANDSTONE MATRIX CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE DTCP = COMPRESSIONAL SLOWNESS PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: FIXED 9.875" MUD WEIGHT: 9.5 TO 9.7 PPG WHOLE MUD CHLORIDES: 100 TO 600 PPM CL MUD TYPE: WBM FORMATION WATER SALINITY: 19,149 PPM CL FLUID DENSITY: 1.0 G /CC MATRIX DENSITY 2.65 G /CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE SMOOTHED WITH A 1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. $ File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/05/11 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 181.5 10199.0 RPS 181.5 10199.0 FET 181.5 10199.0 RPM 181.5 10199.0 RPX 181.5 10199.0 GR 189.0 10247.5 ROP 245.0 10252.0 DTC 267.5 3436.0 NCNT 4903.0 10163.0 NPHI 4903.0 10163.0 FCNT 4903.0 10163.0 RHOB 4916.5 10176.5 PEF 4916.5 10176.5 DRHO 4916.5 10176.5 BASELINE CURVE FOR SHIFTS: . III 411 I CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 245.0 3535.0 MWD 2 3535.0 4992.0 MWD 3 4992.0 10252.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 DTC MWD USPF 4 1 68 12 4 RHOB MWD G /CC 4 1 68 16 5 DRHO MWD G /CC 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 RPM MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPX MWD OHMM 4 1 68 36 10 FET MWD HR 4 1 68 40 11 GR MWD API 4 1 68 44 12 PEF MWD B/E 4 1 68 48 13 ROP MWD FPH 4 1 68 52 14 NPHI MWD PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 181.5 10252 5216.75 20142 181.5 10252 FCNT MWD CP30 572.49 2039.27 841.091 10521 4903 10163 NCNT MWD CP30 116959 166023 133829 10521 4903 10163 DTC MWD USPF 107.8 180.9 149.544 6338 267.5 3436 RHOB MWD G /CC 2.061 2.768 2.34558 10521 4916.5 10176.5 DRHO MWD G /CC 0.005 0.341 0.0712597 10521 4916.5 • 10176.5 RPD MWD OHMM 1.19 2000 14.7499 19956 181.5 10199 RPM MWD OHMM 1.14 2000 11.0449 19956 181.5 10199 RPS MWD OHMM 0.24 583.81 8.85616 19956 181.5 10199 RPX MWD OHMM 0.97 105.95 7.1349 19956 181.5 10199 FET MWD HR 0.23 97.15 1.33009 19956 181.5 10199 GR MWD API 15.6 192.26 104.297 20118 189 10247.5 PEF MWD B/E 1.89 6.93 3.36448 10521 4916.5 10176.5 ROP MWD FPH 0.87 435.61 146.311 20015 245 10252 NPHI MWD PU 11.09 45.45 29.6374 10521 4903 10163 First Reading For Entire File 181.5 Last Reading For Entire File 10252 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/05/11 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/05/11 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SESP 181.5 3470.5 SFXE 181.5 3470.5 SEDP 181.5 3470.5 SEXP 181.5 3470.5 SEMP 181.5 3470.5 SGRC 189.0 3478.0 SROP 245.0 3535.0 DTCP 267.5 3436.0 I LOG HEADER DATA DATE LOGGED: 27- APR -10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 3535.0 TOP LOG INTERVAL (FT): 181.5 BOTTOM LOG INTERVAL (FT): 3535.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 67.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 280554 EWR4 EWR Phase -4 77613 BAT Bi -Modal Acoustic 164683 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 13.500 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: Native /Spud Mud MUD DENSITY (LB /G): 9.50 MUD VISCOSITY (S): 187.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 650 FLUID LOSS (C3): 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 5.900 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 4.448 92.4 MUD FILTRATE AT MT: 3.600 68.0 MUD CAKE AT MT: 6.100 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined III • Frame Spacing P g 60 .lIN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 DTC MWD010 USPF 4 1 68 4 2 RPD MWD010 OHMM 4 1 68 8 3 RPM MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPX MWD010 OHMM 4 1 68 20 6 FET MWD010 HR 4 1 68 24 7 GR MWD010 API 4 1 68 28 8 ROP MWD010 FPH 4 1 68 32 9 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 181.5 3535 1858.25 6708 181.5 3535 DTC MWD010 USPF 107.8 180.9 149.544 6338 267.5 3436 RPD MWD010 OHMM 1.99 2000 31.0107 6579 181.5 3470.5 RPM MWD010 OHMM 2.14 2000 24.3923 6579 181.5 3470.5 RPS MWD010 OHMM 2.24 583.81 18.2432 6579 181.5 3470.5 RPX MWD010 OHMM 2.26 105.95 13.3687 6579 181.5 3470.5 FET MWDO10 HR 0.23 4.78 1.03108 6579 181.5 3470.5 GR MWD010 API 15.6 143.97 78.1974 6579 189 3478 ROP MWD010 FPH 0.87 435.61 156.131 6581 245 3535 First Reading For Entire File 181.5 Last Reading For Entire File 3535 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/05/11 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header • Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/05/11 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 3478.5 4945.5 SFXE 3511.0 4937.5 SEXP 3511.0 4937.5 SESP 3511.0 4937.5 SEDP 3511.0 4937.5 SEMP 3511.0 4937.5 SROP 3535.5 4992.0 LOG HEADER DATA DATE LOGGED: 02- MAY -10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL- TIME): Memory TD DRILLER (FT): 4992.0 TOP LOG INTERVAL (FT): 3478.5 BOTTOM LOG INTERVAL (FT): 4992.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 62.7 MAXIMUM ANGLE: 65.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 275518 EWR4 EWR Phase -4 11179702 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.880 DRILLER'S CASING DEPTH (FT): 3521.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB /G): 9.60 MUD VISCOSITY (S): 48.0 MUD PH: 9.8 MUD CHLORIDES (PPM): 175 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.750 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.164 113.2 MUD FILTRATE AT MT: 2.000 68.0 MUD CAKE AT MT: 1.800 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3478.5 4992 4235.25 3028 3478.5 4992 RPD MWD020 OHMM 1.77 2000 15.7221 2854 3511 4937.5 RPM MWD020 OHMM 1.3 37.82 4.98537 2854 3511 4937.5 RPS MWD020 OHMM 0.24 30 4.79941 2854 3511 4937.5 RPX MWD020 OHMM 2.01 26.91 4.50752 2854 3511 4937.5 FET MWD020 HR 0.23 97.15 2.39794 2854 3511 4937.5 GR MWD020 API 40.88 142.3 101.879 2935 3478.5 4945.5 ROP MWD020 FPH 1 289.48 175.801 2914 3535.5 4992 First Reading For Entire File 3478.5 Last Reading For Entire File 4992 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/05/11 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.004 Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/05/11 Maximum Physical Record 65535 File Type LO Previous File Name STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TNPS 4903.0 10163.0 CTNA 4903.0 10163.0 CTFA 4903.0 10163.0 SBD2 4916.5 10176.5 SCO2 4916.5 10176.5 SNP2 4916.5 10176.5 SEDP 4938.0 10199.0 SEXP 4938.0 10199.0 SFXE 4938.0 10199.0 SEMP 4938.0 10199.0 SESP 4938.0 10199.0 SGRC 4946.0 10247.5 SROP 4992.5 10252.0 LOG HEADER DATA DATE LOGGED: 07- MAY -10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL - TIME): Memory TD DRILLER (FT): 10252.0 TOP LOG INTERVAL (FT): 4903.0 BOTTOM LOG INTERVAL (FT): 10252.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG S S MINIMUM ANGLE: 41.2 MAXIMUM ANGLE: 66.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 10718512 EWR4 EWR Phase -4 228269 CTN Comp Thermal Neutron 181187 ALD Azimuthal Litho Dens 126973 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.880 DRILLER'S CASING DEPTH (FT): 3521.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB /G): 9.55 MUD VISCOSITY (S): 43.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.800 65.0 MUD AT MAX CIRCULATING TERMPERATURE: .915 134.4 MUD FILTRATE AT MT: 1.850 65.0 MUD CAKE AT MT: 1.900 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD030 CP30 4 1 68 4 2 NCNT MWD030 CP30 4 1 68 8 3 RHOB MWD030 G /CC 4 1 68 12 4 DRHO MWD030 G /CC 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 III • FET MWD030 HR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 B/E 4 1 68 44 12 ROP MWD030 FPH 4 1 68 48 13 NPHI MWD030 PU 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4903 10252 7577.5 10699 4903 10252 FCNT MWD030 CP30 572.49 2039.27 841.091 10521 4903 10163 NCNT MWD030 CP30 116959 166023 133829 10521 4903 10163 RHOB MWD030 G /CC 2.061 2.768 2.34558 10521 4916.5 10176.5 DRHO MWD030 G /CC 0.005 0.341 0.0712597 10521 4916.5 10176.5 RPD MWD030 OHMM 1.19 18.85 4.31995 10523 4938 10199 RPM MWD030 OHMM 1.14 19.77 4.34349 10523 4938 10199 RPS MWD030 OHMM 1.09 19.09 4.0876 10523 4938 10199 RPX MWD030 OHMM 0.97 19.25 3.95011 10523 4938 10199 FET MWD030 HR 0.24 28.18 1.22742 10523 4938 10199 GR MWD030 API 46.33 192.26 121.159 10604 4946 10247.5 PEF MWD030 B/E 1.89 6.93 3.36448 10521 4916.5 10176.5 ROP MWD030 FPH 1 299.44 132 10520 4992.5 10252 NPHI MWD030 PU 11.09 45.45 29.6374 10521 4903 10163 First Reading For Entire File 4903 Last Reading For Entire File 10252 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/05/11 Maximum Physical Record 65535 File Type LO Next File Name STSLIB.005 Physical EOF Tape Trailer Service name LISTPE • Date 10/05/11 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 10/05/11 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Napp" C onocoPhilli ps Alaska, Inc. FINAL WELL REPORT MUDLOGGING DATA 2L -310 Provided by: CANRIG [)RIl.1.1\r, LTI). Approved by: Lisa M. Wright Compiled by: Lees F. Browne Jr. Tollef Winslow Distribution: May 25, 2010 Date: April 14, 2010 410 d �a Conoco Phillips • Alaska. Inc 2L -310 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW 2 1.1 EQUIPMENT SUMMARY 2 2 WELL DETAILS 3 2.1 WELL SUMMARY 3 2.2 HOLE DATA 3 2.3 DAILY ACTIVITY SUMMARY 4 3 GEOLOGICAL DATA 6 3.1 LITHOSTRATIGRAPHY 6 3.2 MUDLOG SUMMARY 7 3.3 CONNECTION GASES 12 3.4 TRIP (WIPER) GASES 12 3.5 SAMPLING PROGRAM / SAMPLE DISPATCH 13 3.6 ISOTUBE GAS SAMPLES 14 4 PRESSURE / FORMATION STRENGTH DATA 16 4.1 PORE PRESSURE GRADIENT EVALUATION 16 4.2 QUANTITATIVE METHODS 1 5 DRILLING DATA 1 8 5.1 SURVEY DATA 18 • 5.2 BIT RECORD 22 5.3 MUD RECORD CONTRACTOR: MI SWACO 23 6 DAILY REPORTS 24 Enclosures 2 "/100' Formation Log (MD/TVD) 2 "/100' Drilling Dynamics Log (MD/TVD) 2 "/100' FIT Gas Log (MD 2 "/100' LWD / Lithology Log (MD/TVD) Final Data CD • CANRIG 1 ConocoPhilliips 0 Alaska, Inc. 2L-310 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Comments Downtime QGM Agitator and Gas Trap gas (Mounted in possum belly) Ditch as 0 Flame ionization total gas and chromatography. Effective Circulating Density Pressure While Drilling 0 (ECD) (PWD) Hook Load / Weight on bit Totco WITS Feed 0 Intermittent throughout well. Mud Flow In Derived from Strokes /Minute 0 and Pump Output Mud Flow Out Totco WITS Feed 0 Mudlogging unit computer HP Compaq Pentium 4 0 system (x2: DML & Rigwatch) Mudlogging unit Acromeg In -unit data 0 box collection /distribution center Pit Volumes, Pit Gain /Loss Totco WITS Feed 0 Pump Pressure Totco WITS Feed 0 Pump stroke counters Totco WITS Feed 0 • Totco Well Monitoring Totco computer networked 0 Components in Mudlogging Unit Rate of penetration Totco WITS Feed 0 RPM Totco WITS Feed 0 Sensor inoperable Torque Totco WITS Feed 0 and /or out of calibration Crew Unit Type : Arctic Unit Number : ML056 Years Days Sample Days Mudloggers 9 *2 Catchers Years *2 Technician Days Lees Browne 30 19 Zach Beekman 2 17 Howard Lamp 3 Tollef Winslow 2 19 Steven Franzen 1 17 Allen Williams 1 *1 Years experience as Mudlogger *2 Days at wellsite between spud and total depth of well • 2 CANRIG ConocoPhillips Alaska, Inc. 2L-310 • 2 WELL DETAILS 2.1 Well Summary Well: 2L -310 API Index #: 50- 103 - 20616 -00 -00 Field: Kuparuk River Unit Surface Co- Ordinates: 167' FNL, 646' FEL, Tam Oil Pool Sec 22, T1 ON, R7E, UM Borough: North Slope Primary Target Depth: 9,827' MD / 5,327'TVD State: Alaska Total Depth: 10,187' MD/ 5,600' TVD Rig Name / Type: Doyon 16, Arctic Triple Suspension Date: May 13, 2010 Primary Target: Bermuda Formation License: N/A Spud Date: April 25, 2010 Ground Elevation: 114.9' AMSL Completion Date: RT Elevation: 140.4' AMSL Completion Status: Completed Producer Secondary Target: None Depth: Classification: Injector TD Date: May 7, 2010 TD Formation: Bermuda / Tango (S8) Days Testing: Days Drilling: 12 2.2 Hole Data Maximum Depth Mud Shoe Depth Hole TD Casing/ LOT • MD TVDSS Weight a MD TVDSS Section (ft) (ft) Formation (ppg) (Dev. Inc) Liner (ft) (ft) (ppg) 13W 3535 -3395 9.7 63° 10 3521' -3381 16.0 9%" 10252' -10112 C35 9.6 41° 7 1 Additional Comments: Logging Crew released once casing was on bottom. No information available on last LOT • 3 CANRIG Conoc Alaska. Inc 2L -310 • 2.3 Daily Activity Summary 4/26/10 Load HWDP and 5" drill pipe into the pipe shed. Pick up 14 joints of HWDP and 96 joints of 5" drill pipe and stand back in the derrick. Make up BHA from 34' to 245' and download MWD and orientate the MWD tool. Pick up and make up BHA #1. Make up the gyro tool and drill out the conductor pipe and new formation from surface to 245'. Displace the hole to spud mud and shallow test the MWD. Take a gyro survey and drill and slide formation to midnight. 4/27/10 Drill and slide formation to 1392' and circulate and condition the hole. Wait on town for instructions on close approach and take gyro surveys and proceed to drill and slide to midnight. 4/28/10 Drill and slide formation to 3535'. Make a mad pass of the final three stands. Circulate bottom's up and make sure all samples have been cleaned out of the hole. 4/29/10 Back ream out of the hole from 3535' to 659'. Run in the hole to 3400' and wash to bottom. Circulate bottoms up twice with a wiper gas of 1182 units. Monitor the well and then pull out of the hole from 3535' to 659'. Stand back four stands of HWDP and lay down the BHA and download the MWD data. Pull out of the hole to the bit and break it off. Lay down the rest of the BHA and clean the rig floor and service the rig. Rig up to run 10.75" casing. Make up float equipment and test the same. Run in the hole with the 10.75" casing to 287'. 4/30/10 Run casing to 3480' and make up the landing joint. Make up the cement head and circulate and condition the mud. Trip gas was 2025 units recorded at 1320' while tripping in the hole (gas migration). Trip gas at TD was 486 units. Pump cement to the hole and rig down the cement head. Clean and clear the rig floor and start to nipple down the diverter line. 5/1/10 Nipple up the BOPE and test the same. Make up the mule shoe and run in the hole with single drill pipe (from the pipe shed) to 3172'. Slip and cut new drill line and service the rig and top drive. Pull out of the hole with the drill pipe from 3172' to surface and rack in the derrick. Make up BHA #2 and download the MWD and shallow test the MWD tool. 5/2/10 The flow line is found to be plugged, so stood back the HWDP and drill collars and down loaded the MWD and cleaned out the flow line. Make up the BHA and downloaded the MWD and run in the hole from 621' to 2143', in which the IA plugged up. Clean out the IA and run in the hole to 2238'. The IA plugged again. Clean out the IA and run in the hole to 3190'. Circulate bottoms up and rig up to test the casing. Test the casing and rig down the test lines. Wash down from 3266' to 3442'. Trip gas was 82 units. Notice a few cement stringers on the way in. Drill out the float equipment, shoe track and rat hole plus 20' of new hole to 3555'. Run a FIT to 16.0 ppg EMW and swap out the spud mud for new LSND mud. Repair mud pump #1 and test the same. Drill new formation to midnight. 5/3/10 Drill formation to 4993'. Circulate bottoms up twice and monitor the well. Back ream out of the hole to 3522'. Circulate bottoms up with a maximum gas of 27 units. The maximum gas back reaming out of the hole to the shoe was 15 units. 5/4/10 Back ream out of the hole from 1800' to 1192' and circulate bottoms up at 650'. Monitor the well and stand back the HWDP and drill collars. Lay down the BHA and clean and clear the rig floor. Service the top drive and the rig. Down load the MWD tool and make up the geo- pilot. Pulse test the MWD tool and load the nuke sources. Run in the hole with the HWDP and down link to the geo - pilot. Run in the hole from 1332' to 4709' and wash down to bottom. Trip gas was 76 units. Drill formation to midnight. • 4 CANRIG ConocoPhillips Alaska. Inc. 2L -310 5/5/10 Drill formation to 6735' and back ream out one stand. The ECD spiked to 14.5 and the psi jumped from 2870 to 3500. Shut down the rig pumps and staged up the rig pumps slowly with lost returns. Lost 305 barrels, moved the drill pipe and got all 305 barrels back at 6570'. Back ream out of the hole from 6642' to 5000'. The well is breathing and giving back any lost mud. Maximum gas noted back reaming out to the shoe was 252 units. Abundant clay noted over the shale shakers while circulating at the shoe. 5/6/10 Monitor the well at the shoe and pump a 20 bbl nut plug sweep. Change out the savor sub and inspect and service the top drive. Clean the mud pits and fill with new drilling mud. Run in the hole from 3521' to 6547'. Wash down to 6735' with wiper gas of 557 units. Displace the drilling mud and fill the pits with new drilling mud. Circulate and then drill formation to 6924'. Service the rig and drill formation to 7770'. 5/7/10 Drill formation 24 hours. 5/8/10 Drill formation to 9755'. Begin control drilling at 50 ft/hr to 10100'. Drill formation to 10252' and circulate bottoms up and back ream out of the hole to 8252'. Maximum gas back reaming to 8252' was 113 units. 5/9/10 Back ream out of the hole from 8242' to 6735' and monitor the well ten minutes. Circulate bottoms up with a maximum gas of 95 units. Monitor the well 15 minutes and run in the hole from 6735' to 8054'. Back ream out of the hole to 3521'. Circulate bottoms up with a maximum gas of four units. Monitor the well 15 minutes and pull out of the hole to 666'. Lay down the HWDP, jars and drill collars. Remove the nukes and down load the MWD tool. Clean and clear the rig floor and install the 7 5/8" rams and prepare to run casing. 5/10/10 Rig up casing equipment and clean the rig floor. Rig up test equipment for the top rams and test the same. Test plug did not hold. Pull test plug and drain the stack. Rig up to test the top rams and test. The test failed. Retest and the test is good. Rig down the test equipment and inspect the rams. Replace the top seals and rig up to test the top rams. Test is good and rig down the test equipment. Make up the shoe joint, float collar and run in the hole to 3436'. Circulate bottoms up with a maximum gas of 14 units. Run in the hole to 6047' and circulate bottoms up with a maximum gas of 101 units. Run in the hole to 8467' and circulate bottoms up with a maximum gas of 181 units. Continue to run in the hole with 7 5/8" casing. S 5 CANRIG ConocoPhillips Alaska. Inc 2L -310 • 3 GEOLOGICAL DATA 3.1 Lithostratiyraphv All tops provided by ConocoPhillips Operations Geologist. HORIZON PROGNOSED LWD PICK MD TVD MD TVD (ft) (ft) (ft) (ft) 10 %" Casing Shoe 3500' 2429' 3522' 2420' C -80 (K10) 3660' 2500' 3700' 2498' Top of Campanian sand 3802' 2563' 3837' 2558' C -50 6570' 3795' 6656' 3809' C -40 7491' 4205' 7554' 4209' C -37 7940' 4405' 7970' 4399' S8 — Top Reservoir 9821' 5327' 9850' 5319' T1.5 — Base Reservoir 10010' 5468' 10080' 5490' 0-35 10072' 5514' 10120' 5570' TD 10187' 5600' 10252' 5621' S 6 CANRKG ConocoPhillips Alaska, Inc 2L -310 • 3.2 Mudloq Summary Surface to top of C -80 (0' MD to 3700' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 672 5 159 2595 0 445 This interval is made up predominantly of interbedded clays, claystones, sand, and conglomerates with alternating proportions of each. The clays and claystones in this section are light gray; very soft; malleable to sectile; flexible to elastic; lumpy to clumpy; clustered to clotted; mushy to pasty; non to slightly cohesive; moderate to very adhesive; very hydrophilic; amorphous fracture; massive habit; dull earthy luster; clayey texture; massive homogeneous beds of slightly silty clay composed of 90% clay, 10% silt; continued homogeneous hydrophilic clay. The sands and conglomerates in this section are salt and pepper and various colors; clast size range from pebble to coarse lower; angular bit impacted clasts to sub round; poor to moderate developed sphericity; poor sorting; no abundant size faction; polish to chip textures; mature nature; unconsolidated; clean; arenaceous; no visible matrix material; dominant grain support; composed of 50% lithic fragments: greenstone, silic coal, volcanics, metamorphics, feldspar; good estimated porosity and permeability gradational coarse grained sands; trace woody fragments; thin very carbonaceous material to sub lignitic coal at 550'. Several strong gas peaks were recorded and sampled in this interval. These are likely attributed to organics IP and methane hydrates above the base of the permafrost. Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 1843' 2595 498560 0 0 0 0 0 0 C -80 to top of Campanian sand (3700' to 3837' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 210 22 184 68 8 32 The C -80 to the top of the Campanian sand is characterized by clay. The clay is grayish brown; very soft to soft; malleable to sectile; flexible to elastic; lumpy to clumpy; clustered to clotted; gelatinous in part mushy to pasty; tacky to slimy; slightly cohesive; moderate to very adhesive; amorphous fracture; massive habit; dull earthy luster; clayey texture; massive homogeneous bed of silty clay; composed of 80% clay, 20% silt and moderate detrital material. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 3735' 68 13447 42 0 0 0 0 0 S 7 CANRIG ConocoPhillips Alaska, Inc 2L-310 • Campanian sand to to of C50 (3837' to 6656' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 846 26 172 114 0 26 From the top of the Campanian sand to the top of the C -50 is comprised of clay, siltstones with a small oil show in the Campanian Sand. The Campanian Sand is salt & pepper; clast size medium lower grading to silt; sub round; moderate developed sphericity; poor sorting; some discoidal and prolated grains; polished texture; immature nature; unconsolidated but heavily interbedded in clay; dominant clay matrix support; composed of 50% dark lithics, 50% quartz and minor chert70% moderate even light green sample fluorescence; no petroleum order; instant blue white moderate streaming cut, fast developed to translucent bright blue white cut; moderate to strong light yellow green residue stain; very faint straw visible stain. The clay is grayish brown; very soft to soft; malleable to sectile; flexible to elastic; lumpy to clumpy in parts; slightly cohesive; moderate to very adhesive; amorphous fracture; massive to sub nodular habit; some shape being discovered; hydrophilic globs; dull earthy luster; clayey texture; massive homogeneous clay being slightly silty; composed of 80% clay, 20% silt and very minor very fine grained sand interbedded. The siltstone is light grayish brown; very poor to poorly indurated; brittle; crumbly to crunchy; non to very slightly cohesive; slightly adhesive; earthy fracture; sub nodular habit; earthy luster; silty to gritty texture; massive homogeneous silt with minor thin beds and interbedded very fine to fine grained sand; • interbedded very fine grained sandstone; hard to discern between siltstone and very fine grained sandstone; gradational. Gas is generally low and associated with the Campanian Sand. Peaks Depth TG C1 C2 C3 C4I C4N C5l C5N 3853 114 15527 178 19 3 0 0 0 C50 to top of C40 (6656' to 7554' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 548 47 132 95 0 35 This interval between these two markers in the Seabee formation is siltstone followed by clay. The siltstone is dark bluish gray to very dark bluish gray; poorly to moderately poorly indurated; tenacity is crumbly to crunchy; earthy fracture; sub nodular cuttings habit; luster is dull to earthy; texture is silty to gritty; structure is massive or micro laminations; reddish, brown carbonaceous material; shell fragments; hydrophilic clays present; sand grains create inter bedding layers in scattered cuttings; no oil. The clay is greenish gray to light greenish gray; cohesive and adhesive; lumpy to clumpy consistency; elastic to flexible tenacity; irregular fracture; massive cuttings habit; waxy to greasy luster; clayey to smooth texture; massive structure; interbedded with siltstone; no oil. Gas is generally low. S 8 CANRIG Conoc P hillips Alaska, Inc. 2L-310 • Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 7448' 95 8127 244 50 3 17 0 0 C40 to C37 (7554' to 7970' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 358 52 130 80 1 32 This interval is comprised predominantly of carbonaceous siltstone. Carbonaceous siltstone is gray mottled dark brown; very poor to poorly indurated; brittle; crumbly; very slight cohesiveness; non adhesive; planar fracture along carbonaceous partings; sub tabular habit; earthy mottled greasy luster; silty texture; massive uniform micro laminated very carbonaceous silt; trace loose sand, calcite and bentonite. Gas is generally low. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 7690 80 13148 678 207 28 26 0 0 • C37 to S8 — Top Reservoir (7970' to 9850' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 219 25 119 220 4 46 This interval is comprised of siltstones, carbonaceous siltstone and sand /sandstone Siltstone is gray to greenish gray; poorly to moderately poorly indurated; tenacity is brittle to dense; fracture is irregular; cuttings habit is massive; luster is dull to waxy; texture is silty to clayey; structure is massive; siltstone grades between carbonaceous and no carbonaceous; no oil. The carbonaceous siltstone is gray mottled dark brown; very poor to poorly indurated; brittle; non to slightly cohesive; non adhesive; planar fractures along carbonaceous laminations; planar orientation; sub tabular habit; earthy luster; silty texture; slightly hydrophilic; homogeneous carbon laminated silts; trace clay beds and very fine grained sands. Te sand / sandstone samples appear gray to light gray; upper fine to lower fine in size; sphericity is spherical to sub discoidal; roundness is sub angular to sub rounded; moderately well sorted; unconsolidated sand; matrix is missing; cement is missing; grain supported; texturally immature; compositionally sub mature; quartz sand with chert and pink volcanics; porosity and permeability visually estimated to be good; no oil. Gas is generally low but increases as depth in increases. Peaks Depth I TG I C1 I C2 C3 I C41 C4N I C5l C5N Ili 9 CANRIG Conoc Phillips Alaska. Inc. 2L -310 • 8938 I 220 35402 I 2214 879 123 262 I 0 0 S8 — Top Reservoir to T1.5 — Base Reservoir (9850' to 10080' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 165 28 50 439 30 186 This is the target reservoir sandstone. The sandstone grades from gray to light gray to very dark greenish gray to dark greenish gray; upper very fine grained to lower very fine grained; spherical to sub discoidal sphericity; angular to sub rounded roundness; moderately to moderately well sorted; friable to poorly consolidated; matrix is siliceous; grain supported; texturally immature; compositionally sub mature; composed of quartz and analcite with some carbonaceous material; carbonaceous material and sand grains at time form interbedded layers a few grains thick; carbonaceous siltstone increases as the interval increases; sandstone fluoresces a light bright green; very, very faint oil odor; no free oil on shakers; medium streaming to blooming cut, medium bluish white; faint white /yellow residual cut; no visible staining; porosity and permeability visually estimated to be good. Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 10042' 439 40427 8069 5109 640 1809 383 490 T1.5 — Base Reservoir to Top of C35 (10080' to 10120' MD) • Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 146 29 82 56 45 54 This interval consists of carbonaceous siltstone which is very dark greenish gray to dark greenish gray; very poorly to poorly indurated; tenacity is crumbly to crunchy; planar fracture; sub tabular cuttings habit; earthy to dull luster; silty to gritty texture; laminae structure formed by carbonaceous micro laminations; 25% light bright green fluorescence, no cut. Gas is generally low. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 10080' 56 5109 877 824 149 465 121 190 C35 to TD (10120' to 10252' MD) Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 143 26 97 137 56 96 This interval consists of carbonaceous siltstone which is very dark greenish gray to dark greenish gray; very poorly to poorly indurated; tenacity is crumbly to crunchy; planar fracture; sub tabular cuttings habit; earthy to S 10 CAN RIG ConocoPhillips Alaska, Inc. 2L-310 • dull luster; silty to gritty texture; laminae structure formed by carbonaceous micro laminations; 25% light bright green fluorescence, no cut. Gas is generally low. Peaks Depth TG C1 C2 C3 C4l C4N C5l C5N 10138' 137 18173 1636 993 168 546 159 224 • S 11 CANRIG ConocoPhillips Alaska, Inc, 2L -310 • 3.3 Connection Gases 1 unit = 0.05% Methane Equivalent Depth Gas over BGG (feet) (units) 1412' 350 1608' 800 1704' 567 1795' 709 1790' 695 2085' 350 2175' 50 2360' 789 2738' 1020 2925' 112 3618' 13 4328' 26 7393' 15 3.4 Trip (Wiper) Gases 1 unit = 0.02% Methane Equivalent Depth Trip to Gas (feet) (feet) (units) 3535' SURFACE 2025 3535' BHA 1182 4993' SURFACE 557 6733' SHOE 76 10252' 6700' • 12 CANRIG Conoc Phillips Alaska, Inc. 2L-310 3.5 Sampling Program / Sample Dispatch Set Type / Purpose Frequency Interval Dispatched to Washed, screened, 50' 250' — 9,800' CPAI, ABV 100 and dried reference 10,100' — 10252' Bayview Warehouse A samples 619 E. Ship Creek Ave. Anchorage, AK 99501 Attn: D. Przywojski /M. McCracken Set owner: CPAI 10' 9800'— 10,100' (907) 263 -4859 Washed, screened, 250' — 9,800' CPAI, ABV 100 and dried reference 50' 10,100' — 10,252' Bayview Warehouse B samples 619 E. Ship Creek Ave. Anchorage, AK 99501 10' 9800'— 10,100' Attn: D. Przywojski /M. McCracken Set owner: CPAI (907) 263 -4859 500' 500' — 9,800' Gas Isotubes IsoTech Laboratories, Inc. C ConocoPhilips Contact = Albert Holba Court Set owner: CPAI 30' Champaign IL 61821 • 9800' - 10252' Sample frequency was locally altered according to drill rate constraints and zones of interest. • 13 CANRIG ConocoPhilhiips Alaska, Inc. 2L-310 • 3.6 Isotube Gas Samples Box/ Depth TG C1 C2 C3 C4I C4N C5I C5N Sample (MD/TVD) (units) (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) (ppm) 1 -1 500'/499' 2 355 1 -2 1000'/991' 14 2841 1 -3 1363'/1321' 729 127533 1 -4 1500'/1435' 647 122930 1 -5 1781'/1625' 2088 415188 1 -6 2000'/1784' 1965 369073 1 -7 2500'/1974' 1089 209880 1 -8 2733'/2074' 525 99614 148 1 -9 2744'/2078' 1535 314647 273 24 11 1 -10 3007'/2185' 76 15312 21 1 -11 3500'/2408' 7 9085 2 • 1 -12 4000'/2629' 8 2463 3 1 -13 4500'/2841' 32 6454 49 1 -14 4993'/3062' 26 6058 37 1 -15 5500'/3292' 13 2462 26 1 -16 6000'/3519' 20 3500 49 1 -17 6500'/3746' 56 10982 168 20 1 -18 7000'/3957' 35 6688 136 18 1 -19 7500'/4185' 26 4479 212 65 1 -20 8000'/4411' 20 3234 180 72 13 15 1 -21 8515'/4640' 77 13139 686 236 32 31 1 -22 9000'/4853' 31 6529 337 138 19 35 1 -23 9500'/5088' 32 4518 386 188 20 70 4 8 1 -24 9800'/5281' 34 5077 613 340 41 132 33 42 • 14 CANRIG ConocoPhillips Alaska, Inc • 2L-310 "" 1 -25 9810'/5288' 36 4274 658 371 41 135 16 38 2 -1 9820'/5297' 37 4083 644 347 43 135 23 15 2 -2 9830'/5305' 40 6005 644 327 38 126 21 34 2 -3 9860'/5326' 41 5826 533 241 31 97 24 15 2 -4 9890'/5348' 98 12656 1653 763 81 223 17 50 2 -5 9920'/5371' 219 35246 4151 2125 218 607 115 264 2 -6 9950'/5393' 340 37727 5822 4179 455 1265 247 310 2 -7 9980'/5416' 285 34206 6394 3862 444 1230 246 316 2 -8 10010'/5438' 216 20158 4342 2985 396 1140 259 327 2 -9 10040'/5460' 260 21258 3893 2491 314 391 186 324 2 -10 10070'/5482' 132 12365 2338 1781 273 818 211 281 2 -11 10100'/5505' 47 3866 678 804 176 468 174 230 2 -12 10130'/5527' 58 15498 1054 711 136 537 159 231 2 -13 10160'/5549' 127 17115 1946 1060 157 484 139 183 • 2 -14 10180'/5564' 93 10494 1494 886 123 420 120 169 • 15 CANRIG 0 0 0 ConocoPhillips Alaska, Inc. 2L-310 4 PRESSURE / FORMATION STRENGTH DATA 4.1 Pore Pressure Gradient Evaluation Primary Secondary Interval Tops Pore Pressure (EMW) Trend Formation ry Lithology Indicators Lithology o ( / °) MDRKB TVD TVDSS Min Max Interval ( %) (ft) (ft) (ft) (PPM (PR) CG, C -80 (K10) CLAY 80% SLTST 20 %% 3700' 2498' -2356' 9 7 9.7 EVEN BG, HC MW Top of Camp. sand SLTST 80% SD 20% 3837' 2558' -2416' EVEN BG, CG, MW, 9.5 9.5 HC C -50 SLTST 50% CLAY 50% 6656' 3809' -3667' EVEN BG, CG, MW, 9.8 9.8 HC C -40 CARB SLT SLST 10% 7554' 4209' -4067' EVEN BG, CG, MW, 90% 9.5 9.5 HC C -37 SD 70% SLTST 30% 7970' 4399' -4257' 9.5 9.5 EVEN BG S -8 Top of Reservoir SNDST SLTST 10% 9850' 5319' -5177' SL BG, HC 90% 9.6 9.6 INCR T 1.5 Base of Reservoir SNST 70% SLTST 30% 10080' 5490' -5348' 9.6 9.6 EVEN BG, HC C 35 CARB ST SLTST 30% 10120' 5570' -5428' SL BG 70% 9.6 9.6 INCR TD CARB ST SLTST 30% 10252' 5621' -5481' EVEN BG, HC 70% 9.6 9.6 NOTE: Clst = Claystone /Clay, Sd = Sand, Sltst = Siltstone, Sh = Shale, Sndst = Sandstone, n/a = not addressed 16 CANRK3 • • ConocoPhillips Alaska, Inc. 2L -310 4.2 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight (MW) and effective circulating density (ECD), including increases in background gas (BG), appearance and trends of connection gas (CG), and magnitudes of trip gas (TG) and wiper gas (WG). Regional pore pressure trends from sonic data, provided by ConocoPhillips, and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Epoch, and then modified using the indicators described above, and DXC and resistivity (RES) data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD — (0.6- ((.001 *TLGSU) + (0.05 *DX))) The formula has certain limitations, such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However, the formula proved useful in helping formulate a PPG range, when estimating trends, as with DXC data, with data points in shale intervals. 17 CANRIG Conoc Alaska, Inc. 2L -310 • 5 DRILLING DATA 5.1 Survey Data Measured Incl. Azim. True N( +) / S(-) E( +) / W(-) Vertical Dogleg Depth ° ° Vertical Section Rate (ft) () () Depth (ft) (ft) (ft) (ft) 0100ft) 27.00 0.00 0.00 27.00 0.00 0.00 0.00 0.00 100.00 0.42 304.41 100.00 0.15 -0.22 -0.24 0.58 172.00 0.46 303.48 172.00 0.46 -0.68 -0.73 0.06 261.00 0.96 88.77 260.99 0.67 -0.23 -0.32 1.53 351.00 2.93 85.26 350.94 0.88 2.81 2.67 2.19 440.00 4.06 84.82 439.77 1.35 8.22 7.97 1.27 531.00 4.63 83.03 530.51 2.09 15.07 14.67 0.64 626.00 4.50 83.20 625.21 2.99 22.58 21.99 0.14 722.00 5.36 84.65 720.85 3.86 30.78 30.01 0.91 817.00 9.32 93.03 815.06 3.87 42.89 42.01 4.31 911.00 15.38 101.01 906.84 1.08 62.75 62.06 6.68 957.00 17.70 103.63 950.94 -1.73 75.53 75.10 5.30 1004.00 20.39 104.98 995.36 -5.53 90.39 90.33 5.80 1051.00 22.30 103.58 1039.14 -9.74 106.97 107.32 4.21 • 1098.00 23.04 102.55 1082.51 -13.84 124.61 125.35 1.79 1190.00 24.29 99.88 1166.77 -21.00 160.83 162.19 1.79 1270.36 27.39 89.05 1239.13 -23.53 195.62 197.02 7.01 1313.99 29.14 86.98 1277.55 -22.80 216.27 217.39 4.60 1365.60 30.48 87.21 1322.33 -21.50 241.89 242.62 2.61 1459.38 34.61 83.60 1401.38 -17.37 292.14 291.89 4.86 1554.19 43.39 78.78 1475.00 -8.02 350.97 348.98 9.79 1604.52 47.50 78.89 1510.31 -1.07 386.15 382.94 8.17 1649.14 47.45 78.46 1540.47 5.38 418.39 414.06 0.72 1744.06 50.80 83.60 1602.60 16.49 489.24 482.84 5.40 1795.89 54.23 87.40 1634.14 19.68 530.23 523.05 8.81 1838.73 55.10 87.98 1658.92 21.09 565.15 557.48 2.31 1931.50 57.43 89.77 1710.44 22.59 642.27 633.74 2.98 2028.44 59.81 92.02 1760.92 21.27 725.01 715.93 3.15 2117.55 62.85 97.00 1803.69 15.08 802.90 793.96 5.97 2168.55 63.62 100.57 1826.66 8.12 847.89 839.47 6.43 2214.09 63.24 101.88 1847.03 0.19 887.84 880.12 2.70 2310.15 65.08 105.01 1888.90 -19.92 971.91 966.10 3.50 2404.45 63.55 105.27 1929.77 -42.12 1053.94 1050.33 1.64 2499.11 62.82 103.63 1972.48 -63.20 1135.74 1134.20 1.73 2594.38 62.88 99.44 2015.97 -80.15 1218.77 1218.74 3.91 18 II CANRIG ConocoPhillips Alaska. Inc 2L -310 • 2688.57 66.89 97.01 2055.94 -92.31 1303.16 1303.99 4.86 2780.72 67.51 96.35 2091.65 - 102.19 1387.53 1388.93 0.94 2877.34 66.67 95.58 2129.26 - 111.44 1476.05 1477.89 1.14 2972.07 63.73 94.24 2169.00 - 118.82 1561.71 1563.78 3.36 3066.90 63.36 94.65 2211.24 - 125.40 1646.36 1648.56 0.55 3162.99 62.86 93.84 2254.70 - 131.74 1731.82 1734.12 0.91 3251.89 62.87 94.31 2295.25 - 137.36 1810.73 1813.08 0.47 3347.18 62.49 94.76 2338.98 - 144.06 1895.13 1897.63 0.58 3439.73 63.77 96.36 2380.81 - 152.06 1977.29 1980.13 2.07 3484.26 63.94 96.28 2400.44 - 156.46 2017.02 2020.10 0.41 3575.00 62.76 94.54 2441.14 - 164.11 2097.76 2101.13 2.15 3624.63 62.68 95.38 2463.89 - 167.93 2141.70 2145.20 1.51 3720.57 64.05 96.50 2506.90 - 176.81 2226.99 2230.92 1.77 3813.32 64.23 95.40 2547.35 - 185.46 2310.01 2314.35 1.08 3908.99 63.69 98.45 2589.36 - 195.81 2395.32 2400.29 2.92 4004.77 63.57 99.48 2631.90 - 209.19 2480.09 2486.07 0.97 4097.26 64.75 100.21 2672.21 - 223.42 2562.10 2569.24 1.46 4193.22 65.39 98.43 2712.66 - 237.51 2647.97 2656.22 1.81 4289.24 65.41 98.34 2752.64 - 250.24 2734.34 2743.51 0.09 4382.06 65.37 98.86 2791.29 - 262.86 2817.78 2827.89 0.51 0 4479.56 64.57 99.09 2832.54 - 276.64 2905.04 2916.20 0.85 4573.54 63.15 101.00 2873.95 - 291.35 2988.11 3000.48 2.37 4667.95 63.12 100.35 2916.61 - 306.95 3070.87 3084.58 0.62 4762.43 63.32 100.49 2959.18 - 322.20 3153.82 3168.82 0.25 4853.04 63.38 100.64 2999.82 - 337.05 3233.44 3249.69 0.16 4951.30 63.78 100.63 3043.54 - 353.29 3319.92 3337.56 0.41 5001.38 64.04 101.39 3065.57 - 361.88 3364.07 3382.45 1.46 5097.19 63.42 101.59 3107.97 - 379.00 3448.26 3468.16 0.67 5193.52 62.36 102.88 3151.87 - 397.16 3532.06 3553.62 1.62 5286.80 61.42 103.52 3195.82 - 415.95 3612.16 3635.50 1.18 5379.43 63.07 103.80 3238.96 - 435.31 3691.81 3717.00 1.80 5475.60 63.84 103.60 3281.94 - 455.68 3775.40 3802.54 0.82 5575.27 63.76 102.25 3325.94 - 475.69 3862.56 3891.57 1.22 5668.41 63.82 99.10 3367.09 - 491.16 3944.66 3975.00 3.03 5762.28 62.82 95.55 3409.24 - 501.86 4027.83 4058.85 3.54 5857.32 62.19 95.35 3453.12 - 509.87 4111.75 4143.10 0.69 5950.58 61.99 96.54 3496.78 - 518.41 4193.72 4225.48 1.15 6044.68 60.97 97.99 3541.71 - 528.86 4275.73 4308.15 1.73 6139.67 62.18 99.11 3586.92 - 541.28 4358.34 4391.67 1.64 6233.75 63.37 99.49 3629.96 - 554.80 4440.90 4475.29 1.31 6325.65 63.98 97.46 3670.72 - 566.94 4522.36 4557.64 2.09 • 19 CANRIG Conoc P hillips Alaska, Inc. 2L -310 0 6419.88 64.20 97.80 3711.90 - 578.19 4606.37 4642.40 0.40 6512.40 65.47 97.00 3751.24 - 588.97 4689.41 4726.14 1.58 6610.64 66.80 97.01 3790.98 - 599.93 4778.57 4815.97 1.35 6701.39 66.35 96.11 3827.06 - 609.44 4861.30 4899.23 1.04 6796.40 64.66 94.83 3866.45 - 617.69 4947.36 4985.63 2.16 6891.69 62.84 95.72 3908.60 - 625.54 5032.45 5071.02 2.09 6986.66 62.96 98.65 3951.87 - 636.12 5116.32 5155.54 2.75 7077.27 62.99 99.64 3993.04 - 648.94 5196.01 5236.23 0.97 7173.92 62.72 100.46 4037.14 - 663.95 5280.69 5322.15 0.80 7265.31 62.74 101.22 4079.01 - 679.23 5360.48 5403.25 0.74 7358.54 62.67 102.02 4121.76 - 695.92 5441.63 5485.89 0.77 7457.41 63.49 101.72 4166.53 - 714.05 5527.90 5573.79 0.87 7551.69 63.95 99.53 4208.27 - 729.63 5610.98 5658.20 2.14 7643.53 63.20 98.27 4249.15 - 742.36 5692.23 5740.42 1.48 7737.70 62.31 97.87 4292.26 - 754.11 5775.12 5824.14 1.02 7831.54 62.45 97.28 4335.76 - 765.07 5857.54 5907.28 0.58 7925.73 63.35 96.75 4378.67 - 775.31 5940.76 5991.13 1.08 8023.70 63.96 96.05 4422.14 - 785.09 6028.01 6078.90 0.89 8115.62 63.60 95.99 4462.76 - 793.74 6110.01 6161.33 0.40 8209.78 63.50 95.73 4504.70 - 802.35 6193.88 6245.60 0.27 0 8305.98 63.56 96.03 4547.58 - 811.17 6279.54 6331.68 0.29 8400.37 63.28 95.71 4589.81 - 819.81 6363.51 6416.06 0.42 8494.94 63.64 96.26 4632.07 - 828.63 6447.65 6500.63 0.64 8587.74 64.12 96.71 4672.92 - 838.04 6530.44 6583.94 0.68 8679.91 64.46 97.03 4712.91 - 847.97 6612.89 6666.98 0.48 8770.73 64.01 97.70 4752.39 - 858.46 6694.00 6748.77 0.83 8870.60 63.77 99.12 4796.34 - 871.57 6782.72 6838.43 1.30 8964.49 63.62 99.63 4837.95 - 885.28 6865.76 6922.55 0.51 9057.14 63.66 100.01 4879.08 - 899.44 6947.56 7005.51 0.37 9155.79 63.84 100.21 4922.72 - 914.97 7034.66 7093.89 0.26 9247.56 63.22 98.61 4963.62 - 928.41 7115.70 7176.00 1.70 9343.51 61.10 97.81 5008.43 - 940.53 7199.67 7260.83 2.33 9438.82 58.14 97.01 5056.63 - 951.14 7281.19 7343.04 3.19 9533.45 54.71 97.02 5108.95 - 960.77 7359.43 7421.87 3.62 9627.91 50.85 96.97 5166.08 - 969.93 7434.08 7497.07 4.09 9723.16 46.54 98.18 5228.94 - 979.33 7504.99 7568.60 4.62 9816.73 43.05 99.17 5295.33 - 989.26 7570.16 7634.51 3.80 9909.72 41.96 98.99 5363.88 - 999.17 7632.20 7697.31 1.18 10001.68 42.31 98.98 5432.07 - 1008.81 7693.13 7758.99 0.38 10095.33 41.90 99.73 5501.55 - 1019.01 7755.09 7821.75 0.69 10191.17 41.32 99.80 5573.21 - 1029.81 7817.81 7885.34 0.61 20 0 CANRIG Conoc Phillips Alaska, Inc 2L-310 • 10214.78 41.18 100.47 5590.96 - 1032.55 7833.13 7900.89 1.96 10252.00 41.18 100.47 5618.98 - 1037.00 7857.23 7925.37 0.00 • 21 • CANRIG 0 • S ,... _ ConocoP'hillips Alaska, Inc. 2L -310 5.2 Bit Record Type / Jets Depth In Total Bit Avg. Avg. Avg Avg. Bit Size Make Serial # / MD/TVD Footage Hours ROP WOB RPM PP Wear BHA TFA (ft/hr) (Klbs) (psi) #1 13.5" HTC MXL- 5155540 1x16, 112'/112' 3423 26:26 159 N/A 39/ 1466 1- 2- WT- A- 0- 1 -NO -TD #1 1X 3x18 SLIDE HYCA #2 9.88" DSX619M 124653 6X13 2423/ 1458 19:22 172 N/A S $ D 2238 0- 1- CT- G- X -I -NO -BHA #2 B10 SDBS 4993' #3 9.88" FX65 11491162 6X15 3062/ 5262 45:38 140 N/A 154 2358 0- 0- NO- A- X- I -NO -TD #3 22 CANRIG • • ,.- • ConocoPhillips Alaska, Inc. 2L -310 5.3 Mud Record Contractor: MI SWACO Mud Type: Spud Mud CD Date Depth /TVD MW VIS PV YP Gels FL FC Sol O/W Sd Alk CI Ca (at TD's) 4/25/2010 386/384 9.0 287 29 30 25/43/ 10.8 2/ 4.5 1/95 0.1 0.2 550 80 9.32 4/26/2010 1698/1674 9.8 187 56 63 20/43/ 5.5 1/- 9 /91 0.7 0.1 200 60 10.09 4/27/2010 3493/2423 9.8 219 60 71 19/44/66 5.5 1/- 9.5 /91 2.0 0.06 150 60 10.41 4/28/2010 3535/2423 9.8 198 57 63 19/43/65 5.3 1/- 9.5 /91 1.5 0.07 100 40 9.8 4/29/2010 3535/2423 9.9 77 27 14 19// 5.4 1/ 9.5 /91 1 - 150 20 9.9 4/30/2010 3535/2423 9.6 68 19 22 19/20/22 5 1/- 8 /92 1 - 150 40 - Mud Type: Conditioned Drill Out Spud Mud 5/1/10 I 3555/2426 I 9.7 I 53 I 12 1 20 I 9/10/11 I 4.4 1 1/ I 5.5 4/91 1 - I 0.4 I 250 1 20 I 10.21 Mud Type: LSND 5/2/10 4993/3061 9.6 49 12 26 9/15/22 4.2 1/- 6.5 4/90 - 3 175 80 10.31 5/3/10 5266/3186 9.6 49 13 23 8/15/17 3.8 1/- 7.5 4/89 0.5 0.3 100 60 10.1 5/4/10 6735/3837 9.8 54 13 28 10/13/14 4.2 1/- 8.5 3/89 TR 0.25 150 60 10.61 5/5/10 7418/4221 9.5 43 10 20 9/10/11 4.8 1/- 6 3/91 TR 0.2 300 40 N/A 5/6/10 9381/5027 9.6 42 10 19 8/10/12 4.4 1/- 7 3/91 TR 0.2 200 40 N/A 5/7/10 10252/5619 9.6 40 7 19 7/9/10 4.8 1/- 8 3/90 TR 0.2 200 40 N/A 5/8/10 10252/5619 9.7 44 11 20 8/9/11 4.4 1/- 8 2/90 TR 0.25 200 40 N/A 5/9/10 10252/5619 9.7 47 17 20 12/12/15 4.2 1/- 8 2/90 TR 0.2 200 40 N/A Abbreviations MW = Mud Weight Gels = Gel Strength O/W = Oil to Water ratio Ca = Calcium (Hardness) VIS = Funnel Viscosity FL = Filtrate (Fluid) Loss Sd = Sand Content ( %) ECD = Effective Circulating Density PV = Plastic Viscosity FC = Filter Cake Alk = Alkalinity (mud) YP = Yield Point Sol = Solids ( %) CI = Chlorides 23 CANRIG 6 DAILY REPORTS • • 24 CANRKG Daily Report Page 1 of 1 • Conoco Phillips Alaska, Inc. EPOCH DAILY WELLSITE REPORT 2L -310 REPORT FOR GUY WHITLOCK DATE Apr 26, 2010 DEPTH 570.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 112.00000 24 HOUR FOOTAGE 458' CASING INFORMATION 16" @ 112' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 13.5" HTC MXL -1X 5155540 1X16, 3X18 SURFACE 2:54 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 671.6 @ 516.00000 11.8 @ 407.00000 116.2 199.47914 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM 87 @ 331.00000 86 @ 563.00000 30.8 87.00000 RPM PUMP PRESSURE 1056 @ 350.00000 253 @ 265.00000 491.3 812.00000 PSI DRILLING MUD REPORT DEPTH 500' MW 9.0 VIS 266 PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS • GAS SUMMARY (units) DITCH GAS HIGH LOW 7 @ AVERAGE 371.00000 0 @ 460.00000 0.9 TRIP GAS 0 @ 112' CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 1276 @ 370.00000 28 @ 400.00000 156.4 CONNECTION GAS HIGH 0 ETHANE (C -2) 0 @ 570.00000 0 @ 570.00000 0.0 AVG 0 PROPANE (C -3) 0 © 570.00000 0 @ 570.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 570.00000 0 @ 570.00000 0.0 CURRENT BACKGROUND /AVG 1 PENTANE (C -5) 0 @ 570.00000 0 @ 570.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SAND, CONGLOMERATE SAND, CONGLOMERATE, CLAY, CARBONACEOUS MATERIAL PRESENT LITHOLOGY 570' = 60% CONGLOMERATE, 30% CONGLOMERATE SAND, 10% CARBONACEOUS MATERIAL. DAILY LOAD HWDP AND 5" DRILL PIPE INTO PIPE SHED, PICK UP 14 JOINTS OF HWDP AND 96 JOINTS OF 5" DRILL PIPE AND STAND ACTIVITY BACK IN THE DERRICK, MAKE UP BHA FROM 34' TO 245', DOWN LOAD MWD AND ORIENTATE, PICK UP AND MAKE UP BHA #1, SUMMARY MAKE UP GYRO, DRILL OUT CONDUCTOR AND FORMATION FROM SURFACE TO 245', DISPLACE HOLE TO SPUD MUD AND SHALLOW TEST MWD, TAKE GYRO SURVEY AND DRILL AND SLIDE FORMATION TO MIDNIGHT. EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW + 2 SC DAILY COST $3320 REPORT BY LEES F. BROWNE JR. • file: / /C: \Documents and Settings\EpochAdmin\My Documents \My Wells \CONOCOPHILI... 4/26/2010 Daily Report Page 1 of 1 • ConocoPhillips Alaska, Inc. DAILY WELLSITE REPORT EPOCH 2L -310 REPORT FOR GUY WHITLOCK DATE Apr 26, 2010 DEPTH 570.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 112.00000 24 HOUR FOOTAGE 458' CASING INFORMATION 16" @ 112' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 13.5" HTC MXL -1X 5155540 1X16, 3X18 SURFACE 2:54 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 671.6 @ 516.00000 11.8 @ 407.00000 116.2 199.47914 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM 87 @ 331.00000 86 @ 563.00000 30.8 87.00000 RPM PUMP PRESSURE 1056 @ 350.00000 253 @ 265.00000 491.3 812.00000 PSI DRILLING MUD REPORT DEPTH 500' MW 9.0 VIS 266 PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS • GAS SUMMARY (units) DITCH GAS HIGH LOW AVERAGE 7 @ 371.00000 0 @ 460.00000 0.9 TRIP GAS 0 @ 112' CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 1276 @ 370.00000 28 @ 400.00000 156.4 CONNECTION GAS HIGH 0 ETHANE (C -2) 0 @ 570.00000 0 @ 570.00000 0.0 AVG 0 PROPANE (C -3) 0 @ 570.00000 0 @ 570.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 570.00000 0 @ 570.00000 0.0 CURRENT BACKGROUND /AVG 1 PENTANE (C -5) 0 @ 570.00000 0 @ 570.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SAND, CONGLOMERATE SAND, CONGLOMERATE, CLAY, CARBONACEOUS MATERIAL PRESENT LITHOLOGY 570' = 60% CONGLOMERATE, 30% CONGLOMERATE SAND, 10% CARBONACEOUS MATERIAL. DAILY LOAD HWDP AND 5" DRILL PIPE INTO PIPE SHED, PICK UP 14 JOINTS OF HWDP AND 96 JOINTS OF 5" DRILL PIPE AND STAND ACTIVITY BACK IN THE DERRICK, MAKE UP BHA FROM 34' TO 245', DOWN LOAD MWD AND ORIENTATE, PICK UP AND MAKE UP BHA #1, SUMMARY MAKE UP GYRO, DRILL OUT CONDUCTOR AND FORMATION FROM SURFACE TO 245', DISPLACE HOLE TO SPUD MUD AND SHALLOW TEST MWD, TAKE GYRO SURVEY AND DRILL AND SLIDE FORMATION TO MIDNIGHT. EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW + 2 SC DAILY COST $3320 REPORT BY LEES F. BROWNE JR. • file: / /C:\Documents and Settings\EpochAdmin\My Documents \My Wells \CONOCOPHILI... 4/26/2010 Daily Report Page 1 of 1 • ConocoPhillips Alaska, Inc. DAILY WELLSITE REPORT EPOCH 2L -310 REPORT FOR WHITLOCK/HABERTHUR DATE Apr 27, 2010 DEPTH 1891.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 570.00000 24 HOUR FOOTAGE 1321' CASING INFORMATION 16" @ 112' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1270 27.39 89.05 1239.13 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 13.5" HTC MXL -1X 5155540 1X16, 3X18 SURFACE 13 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 545.7 @ 1571.00000 4.6 @ 1396.00000 161.5 170.09213 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM 88 @ 1026.00000 SLIDE @ 923.00000 13.1 0.00000 RPM PUMP PRESSURE 1559 @ 1889.00000 812 @ 570.00000 1238.9 1436.00000 PSI DRILLING MUD REPORT DEPTH 1900' MW 9.8 VIS 150 PV 53 YP 43 FL 5.5 Gels CL- FC SOL 9 SD OIL MBL pH 9 Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS • GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 2595 @ 1843.00000 0 @ 656.00000 402.2 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 2428 @ 1417' METHANE (C -1) 500409 @ 1838.00000 38 @ 656.00000 75070.7 CONNECTION GAS HIGH 800 @ 1605 ETHANE (C -2) 12 @ 1661.00000 0 @ 1736.00000 0.1 AVG 500 PROPANE (C -3) 0 @ 1891.00000 0 @ 1891.00000 0.0 CURRENT 670 BUTANE (C -4) 0 @ 1891.00000 0 @ 1891.00000 0.0 CURRENT BACKGROUND /AVG 2200 PENTANE (C -5) 0 @ 1891.00000 0 @ 1891.00000 0.0 HYDROCARBON SHOWS HYDRATES ENCOUNTERED AT 1322' WITH ELEVATED GAS AND CG TO MIDNIGHT INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION 1322' TO PRESENT 80 -100% CLAY BEFORE 50 CURRENTLY 2200 VERY SOFT CLAY SLIGHTLY SILTY. ALL C -1 METHANE LITHOLOGY CLAY, SILT, SAND, COAL, CARBON MATERIAL PRESENT LITHOLOGY 1890' = 90% CLAY, 10% SILT DAILY ACTIVITY DRILL AND SLIDE FORMATION TO 1392', CIRCULATE AND CONDITION THE HOLE AND WAIT ON TOWN INSTRUCTIONS, TAKE SUMMARY GYRO SURVEYS AND DRILL AND SLIDE TO MIDNIGHT EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW + 2 SC DAILY COST $3320 REPORT BY LEES F. BROWNE JR. III file: / /C:\Documents and Settings\EpochAdmin\My Documents \My Wells \CONOCOPHILI... 4/27/2010 Daily Report Page 1 of 1 • ConocoPhillips Alaska, Inc. DAILY WELLSITE REPORT EPOCH 2L -310 REPORT FOR WHITLOCK/HABERTHUR DATE Apr 28, 2010 DEPTH 3535.00000 PRESENT OPERATION CIRC @ 3535 TD TIME 24 HOURS YESTERDAY 1891.00000 24 HOUR FOOTAGE 1644' CASING INFORMATION 16" @ 112' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3535 2423.96 SURVEY DATA 3439.73 63.77 96.36 2381.98 3162.99 62.86 93.84 2255.86 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 13.5" htc mxl -lx 5155540 1x16, 3x18 112 3535 3423 26:26 n/a TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 488.0 @ 1899.00000 5.6 @ 2766.00000 155.7 79.07917 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM 88 @ 2363.00000 1 @ 3407.00000 58.7 85.00000 RPM PUMP PRESSURE 2178 @ 3358.00000 1226 @ 1984.00000 1802.3 2140.00000 PSI DRILLING MUD REPORT DEPTH 3530' MW 9.8 VIS 219 PV 60 YP 71 FL 5.5 Gels 19/44 CL- FC SOL 9.5 SD OIL MBL pH 8.6 Ca+ CCI MWD SUMMARY • INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 2488 @ 1891.00000 0 @ 3378.00000 611.4 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 479471 @ 1891.00000 114 @ 3378.00000 112461.5 CONNECTION GAS HIGH 1020 @ 2740' ETHANE (C -2) 791 @ 2885.00000 0 @ 3378.00000 27.3 AVG 150 PROPANE (C -3) 83 @ 2885.00000 0 @ 3156.00000 1.5 CURRENT 0 @ 3493' BUTANE (C -4) 31 @ 2885.00000 0 @ 2907.00000 0.3 CURRENT BACKGROUND /AVG 25 CIRC @ TD PENTANE (C -5) 0 @ 3535.00000 0 @ 3535.00000 0.0 HYDROCARBON SHOWS HYDRATE GAS / ELEVATED BACKGROUND GAS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION TO 2800' CLAY AND SAND 300 TO 2500 UNITS BACKGROUND GAS W/ CG's CONTINUED ELEVATED HYDRATE GAS TO 2800' LITHOLOGY SAND, SILT, CLAY PRESENT LITHOLOGY 3535' = 90% CLAY, 10% SAND DAILY ACTIVITY DRILL/SLIDE FORMATION TO 3535', MAD PASS THE FINAL THREE STANDS, CIRCULATE BOTTOM'S UP AND SAMPLES SUMMARY OUT OF THE HOLE. EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW + 2 SC DAILY COST $3320 REPORT BY LEES F. BROWNE JR. • file: / /C:\Documents and Settings\EpochAdmin\My Documents \My Wells \CONOCOPHILI... 4/28/2010 Daily Report Page 1 of 1 1 ConocoPhillips Alaska, Inc. DAILY WELLSITE REPORT EPOCH 2L -310 REPORT FOR HILL/HABERTHUR DATE Apr 29, 2010 DEPTH 3535.00000 PRESENT OPERATION RUN 10.75" CSG TIME 24 HOURS YESTERDAY 3535.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 16" @ 112' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3535 2423.96' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 13.5" HTC MXL -1X 5155540 1X16, 3X18 112 3535 3423 26:26 1- 2- WT- A- O -1 -NO TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 3493' MW 9.8 VIS 219 PV 60 YP 71 FL 5.5 Gels 19/44/66 CL- 150 FC 1/- SOL 9.5 SD 2 OIL -/91 MBL 36 pH 8.7 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS • GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 1182 @ 3535 WG 1 @ TIH 75 TIH TRIP GAS - CUTTING GAS @ @ WIPER GAS 1182 @ 3535' CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ @ AVG - PROPANE (C -3) @ @ CURRENT - BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 9 (TIH W/ CSG PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 3535' = 90% CLAY, 10% SAND BACK REAM OUT OF THE HOLE FROM 3535' TO 659', RUN IN THE HOLE TO 3400' AND WASH TO BOTTOM, CIRCULATE BOTTOMS UP DAILY TWICE, WIPER GAS WAS 1182 UNITS, MONITOR THE WELL, PULL OUT OF THE HOLE FROM 3535' TO 659', STAND BACK 4 STANDS ACTIVITY OF HWDP, LAY DOWN THE BHA AND DOWN LOAD THE MWD, PULL OUT OF THE HOLE TO THE BIT AND BREAK OFF, LAY DOWN THE SUMMARY REST OF THE BHA, CLEAN THE RIG FLOOR AND SERVICE THE RIG, RIG UP TO RUN 10.75" CASING, MAKE UP FLOAT EQUIPMENT AND TEST, RUN IN THE HOLE WITH 10.75" CASING TO 287' EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW + 2 SC DAILY COST $3320 REPORT BY LEES F. BROWNE JR. S file: / /C:\Documents and Settings\EpochAdmin\My Documents\My Wells \CONOCOPHILI... 4/29/2010 Daily Report Page 1 of 1 III ConocoPhillips Alaska, Inc. DAILY WELLSITE REPORT EPOCH 2L -310 REPORT FOR HILUHABERTHUR DATE Apr 30, 2010 DEPTH 3535.00000 PRESENT OPERATION NIPPLE DOWN DIVERTER TIME 24 HOURS YESTERDAY 3535.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 10.75" @ 3480' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3535 2423.96' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS IIII GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 2025 @ 1320' (TG) 1 @ TIH 112 TRIP GAS 2025 @ TG CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ @ AVG - PROPANE (C -3) @ @ CURRENT - BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG - PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 100% CEMENT DAILY RUN CASING TO 3480', MAKE UP LANDING JOINT, MAKE UP CEMENT HEAD, CIRCULATE AND CONDITION MUD, TRIP GAS WAS ACTIVITY 2025 UNITS RECORDED AT 1320 TRIPPING IN THE HOLE WITH CASING (GAS MIGRATION) TRIP GAS AT TD WAS 486 UNITS, PUMP SUMMARY CEMENT TO THE HOLE, RIG DOWN THE CEMENT HEAD, CLEAN AND CLEAR RIG FLOOR, START TO NIPPLE DOWN THE DIVERTER LINE. EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW + 2 SC DAILY COST $3320 REPORT BY LEES F. BROWNE JR. • file: / /C: \Documents and Settings\EpochAdmin\My Documents \My Wells \CONOCOPHILI... 4/30/2010 Daily Report Page 1 of 1 IP ConocoPhillips Alaska, Inc. DAILY WELLSITE REPORT EPOCH 2L -310 REPORT FOR HILL/HABERTHUR DATE May 01, 2010 DEPTH 3535.00000 PRESENT OPERATION MAKE UP BHA #2 TIME 24 HOURS YESTERDAY 3535.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 10.75" @ 3480' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3535' 2423.96' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 9.88" HYCA DSX619MB10 6X13 3535 0 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH SWAP TO LSND @ 3555' MW VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO • TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ @ AVG - PROPANE (C -3) @ @ CURRENT - BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG - PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 100% CEMENT DAILY NIPPLE UP BOPE AND TEST THE SAME, 250 LOW /3500 HIGH, 2500 ANNULAR, MAKE UP MULE SHOE, RUN IN THE HOLE WITH ACTIVITY SINGLE DRILL PIPE FROM THE PIPE SHED TO 3172', SLIP AND CUT NEW DRILL LINE, SERVICE THE RIG AND TOP DRIVE, PULL SUMMARY OUT OF THE HOLE WITH DRILL PIPE FROM 3172' TO SURFACE, MAKE UP BHA #2, DOWNLOAD MWD AND SHALLOW TEST MWD TOOL. EPOCH PERSONNEL BROWNE, WINSLOW + 2 SC DAILY COST: $5580 w/ R/U +R/D UNIT REPORT BY LEES F. BROWNE JR. file: / /C:\Documents and Settings\EpochAdmin\My Documents \My Wells \CONOCOPHILIP... 5/1/2010 Daily Report Page 1 of 1 • ConocoPhillips Alaska, Inc. DAILY WELLSITE REPORT EPOCH 2L -310 REPORT FOR HILUHABERTHUR DATE May 02, 2010 DEPTH 3575.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 3535.00000 24 HOUR FOOTAGE 40' CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3535 2423.96' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 9.88" HYCA DSX619MB10 124653 6X13 3535 1 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 195.0 @ 3574.00000 10.3 @ 3552.00000 87.4 163.45062 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM 85 @ 3535.00000 66 @ 3572.00000 68.3 68.00000 RPM PUMP PRESSURE 2140 @ 3535.00000 992 @ 3552.00000 1245.3 1735.00000 PSI DRILLING MUD REPORT DEPTH 3535' MW 9.4 VIS PV YP FL Gels CL- FC SOL SD OIL MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS • GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 15 @ 3575.00000 0 @ 3536.00000 9.8 TRIP GAS 82 @ 3535' CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 2742 @ 3551.00000 62 @ 3536.00000 1747.7 CONNECTION GAS HIGH 0 ETHANE (C -2) 17 @ 3554.00000 0 @ 3536.00000 4.3 AVG 0 PROPANE (C -3) 0 @ 3575.00000 0 @ 3575.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 3575.00000 0 @ 3575.00000 0.0 CURRENT BACKGROUND /AVG 18 PENTANE (C -5) 0 @ 3575.00000 0 @ 3575.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY CLAY PRESENT LITHOLOGY 100% CLAY SHALLOW TEST MWD, FLOW LINE PLUGGED, STAND BACK HWDP AND DRILL COLLARS, DOWNLOAD MWD, CLEAN OUT FLOW LINE, DAILY MAKE UP BHA AND DOWNLOAD MWD, RUN IN THE HOLE FROM 621' TO 2143', IA PLUGGED UP, CLEAN OUT IA AND RUN IN THE ACTIVITY HOLE TO 2238', IA PLUGGED AGAIN, CLEAN OUT, RUN IN THE HOLE TO 3190', CIRCULATE BOTTOMS UP, RIG UP TO TEST CASING, SUMMARY TEST CASING, RIG DOWN TEST LINES, WASH DOWN FROM 3266' TO 3442', TRIP GAS WAS 82 UNITS, FEW CEMENT STRINGERS NOTED, DRILL OUT FLOAT EQUIPMENT, SHOE TRACK AND RAT HOLE AND 20' OF NEW FORMATION TO 3555', RUN A F.I.T. AND SWAP OUT SPUD MUD FOR NEW LSND MUD, REPAIR MUD PUMP #1 AND TEST, DRILL FORMATION TO MIDNIGHT. EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW + 2 SC DAILY COST $3320 REPORT BY LEES F. BROWNE JR. III file: / /C:\Documents and Settings\EpochAdmin \My Documents \My Wells \CONOCOPHILIP... 5/2/2010 Daily Report Page 1 of 1 ConocoPhillips Alaska, Inc. • DAILY WELLSITE REPORT EPOCH 2L -310 REPORT FOR HILL/HABERTHUR DATE May 03, 2010 DEPTH 4993.00000 PRESENT OPERATION TRIP OUT FOR BHA TIME 24 HOURS YESTERDAY 3575.00000 24 HOUR FOOTAGE 1418' CASING INFORMATION 10.75" @ 3521' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 4951.30' 63.78 100.63 3043.54' SURVEY DATA 4573.54 63.15 101.00 2873.95' 3908.99' 63.69 98.45 2589.36' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 9.88" HYCA DSX619MB10 124653 6X13 3535 9:22 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 506.3 @ 4671.00000 22.1 @ 3763.00000 174.4 224.69106 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM 110 @ 3953.00000 67 @ 3667.00000 88.7 108.00000 RPM PUMP PRESSURE 2801 @ 4945.00000 1716 @ 3577.00000 2267.1 2527.00000 PSI DRILLING MUD REPORT DEPTH 3555' MW 9.7 VIS 53 PV 12 YP 20 FL 4.4 Gels 9/10/11 CL- 250 FC 1/ SOL 5.5 SD - OIL 4/91 MBL - pH 9.9 Ca+ 20 CCI MWD SUMMARY • INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 114 @ 3853.00000 0 @ 4718.00000 28.8 TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 101289 @ 4093.00000 12 @ 4718.00000 5953.1 CONNECTION GAS HIGH 13 ETHANE (C -2) 412 @ 4101.00000 0 @ 4046.00000 27.0 AVG 0 -5 PROPANE (C -3) 21 @ 3852.00000 1 @ 3856.00000 0.1 CURRENT 0 BUTANE (C -4) 3 @ 3852.00000 0 @ 3856.00000 0.0 CURRENT BACKGROUND /AVG 8 POOH PENTANE (C -5) 0 @ 4993.00000 0 @ 4993.00000 0.0 HYDROCARBON OIL SHOW SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION 3847 -3857' 60% SAND 40% CLAY SAND HAS ABNT BEFORE 14 MAX SN: MED LWR -V FN LWR; ABNT CLAY INTBD; MTX SUP; 70% MOD CLAY MATRIX; MATRIX SUPPORTED 114 AFTER 15 EVN LTGRN SMPL FLOR; INST BLUWHT STRMG CT; FST DEVELP; STRONG UV RESD STN LITHOLOGY SILT, CLAY, CARBONACEOUS MATERIAL; SAND PRESENT LITHOLOGY 4990' = 100 % SILTSTONE DAILY ACTIVITY DRILL FORMATION TO 4993', CIRCULATE BOTTOMS UP TWICE, MONITOR THE WELL; BACK REAM OUT OF THE HOLE TO 3522'; SUMMARY CIRCULATE BOTTOMS UP, MAX GAS 27 UNITS; MAX GAS BACK REAMING TO THE SHOE = 15 EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW + 2 SC DAILY COST $3320 REPORT BY LEES F. BROWNE JR. • file: / /C:\Documents and Settings\EpochAdmin\My Documents\My Wells \CONOCOPHILIP... 5/2/2010 Daily Report Page 1 of 1 0 ConocoPhillips Alaska, Inc. DAILY WELLSITE REPORT EPOCH 2L -310 REPORT FOR HILUHABERTHUR DATE May 04, 2010 DEPTH 5604.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 4993.00000 24 HOUR FOOTAGE 611' CASING INFORMATION 10.75" @ 3521' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4993 3062.09' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 9.88" HYCA DSX619MB10 124653 6X13 3535 4993 1458 19:22 0- 1- CT- G- X -I -NO BHA 3 9.88" SOBS FX65 11491162 6X15 4993 4 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 845.7 @ 5318.00000 39.4 @ 4994.00000 180.9 173.23517 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM 160 @ 5034.00000 32 @ 5265.00000 123.3 129.00000 RPM PUMP PRESSURE 2560 @ 5074.00000 1311 @ 5239.00000 2009.0 2046.00000 PSI DRILLING MUD REPORT DEPTH 5266' MW 9.6 VIS 49 PV 13 YP 23 FL 3.8 Gels 8/15/17 CL- 100 FC 1/- SOL 7.5 SD 0.5 OIL 4/89 MBL 11 pH 9.9 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 42 @ 5424.00000 0 @ 5052.00000 12.0 TRIP GAS 76 @ 4993' CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 7668 @ 5423.00000 25 @ 5052.00000 2124.0 CONNECTION GAS HIGH 0 ETHANE (C -2) 40 @ 5119.00000 0 @ 4995.00000 17.1 AVG 0 PROPANE (C -3) 0 @ 5604.00000 0 @ 5604.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 5604.00000 0 @ 5604.00000 0.0 CURRENT BACKGROUND /AVG 34 PENTANE (C -5) 0 @ 5604.00000 0 @ 5604.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SILTSTONE, SAND, SANDSTONE PRESENT LITHOLOGY 5605' = 100% SILTSTONE BACK REAM OUT OF THE HOLE FROM 1800' TO 1192', CIRCULATE BOTTOMS UP @ 650', MONITOR THE WELL, STAND BACK THE DAILY HWDP AND DRILL COLLARS, LAY DOWN THE BHA, CLEAN AND CLEAR THE RIG FLOOR, SERVICE THE TOP DRIVE AND RIG, ACTIVITY DOWNLOAD THE MWD TOOL AND MAKE UP THE GEO- PILOT, PULSE TEST MWD TOOL, LOAD NUKES, RUN IN THE HOLE WITH SUMMARY HWDP, DOWN LINK TO GEO- PILOT, RUN IN THE HOLE FROM 1332' TO 4709', WASH DOWN TO BOTTOM, TRIP GAS WAS 76 UNITS, DRILL FORMATION TO MIDNIGHT. EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW + 2 SC DAILY COST $3320 REPORT BY LEES F. BROWNE JR. • file: / /C:\Documents and Settings\EpochAdmin \My Documents \My Wells \CONOCOPHILIP... 5/4/2010 Daily Report Page 1 of 1 11111 ConocoPhillips Alaska, Inc. DAILY WELLSITE REPORT EPOCH 2L -310 REPORT FOR HILUHABERTHUR DATE May 05, 2010 DEPTH 6735.00000 PRESENT OPERATION CIRCULATE AT THE SHOE TIME 24 HOURS YESTERDAY 5604.00000 24 HOUR FOOTAGE 1131' CASING INFORMATION 10.75" @ 3521' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 6735 3839.82 SURVEY DATA 6610.64 66.80 97.01 3790.98 6419.88 64.20 97.80 3711.90 6233.75 63.37 99.49 3629.96 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 9.88" SDBS FX65 11491162 6X15 4993 11 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 364.0 @ 6201.00000 34.3 @ 6511.00000 167.9 188.07800 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM 195 @ 6299.00000 106 @ 6075.00000 164.5 193.00000 RPM PUMP PRESSURE 2804 @ 6728.00000 1590 @ 6168.00000 2357.9 2516.00000 PSI DRILLING MUD REPORT DEPTH 6735' MW 9.8 VIS 54 PV 13 YP 28 FL 4.2 Gels 10/13 CL- FC SOL 8.5 SD OIL MBL pH 9.3 Ca+ CCI MWD SUMMARY 0 INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 73 @ 6553.00000 0 @ 6692.00000 29.8 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 252 MAX GAS BROOH METHANE (C -1) 13516 @ 6618.00000 649 @ 6045.00000 5550.0 CONNECTION GAS HIGH 0 ETHANE (C -2) 226 @ 6553.00000 6 @ 6045.00000 65.4 AVG 0 PROPANE (C -3) 22 @ 6618.00000 0 @ 6099.00000 3.5 CURRENT 0 BUTANE (C -4) 0 @ 6735.00000 0 @ 6735.00000 0.0 CURRENT BACKGROUND /AVG 5 CIRC @ SHOE PENTANE (C -5) 0 @ 6735.00000 0 @ 6735.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SILT, CLAY, SAND, SANDSTONE PRESENT LITHOLOGY 6690' = 100% SILTSTONE DRILL FORMATION TO 6735', BACK REAM OUT ONE STAND, ECD SPIKED TO 14.5, PSI JUMPED FROM 2870 TO 3500, SHUT DOWN DAILY THE RIG PUMPS AND STAGE UP PUMPS SLOWLY WITH NO RETURNS, LOST 305 BBLS, MOVE DRILL PIPE AND GOT ALL 305 BBLS ACTIVITY BACK AT 6570', BACK REAM OUT OF THE HOLE FROM 6642' TO 5000', WELL IS BREATHING AND GIVING BACK ANY MUD LOST, SUMMARY MAXIMUM GAS NOTED BACK REAMING TO THE SHOE WAS 252 UNITS, ABUNDANT CLAY OVER THE SHAKERS WHILE CIRCULATING AT THE SHOE. EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW + 2 SC DAILY COST $3320 REPORT BY LEES F. BROWNE JR. S file: / /C:\Documents and Settings\EpochAdmin\My Documents \My Wells \CONOCOPHILIP... 5/5/2010 Daily Report Page 1 of 1 • ConocoPhillips Alaska, Inc. DAILY WELLSITE REPORT EPOCH 2L -310 REPORT FOR HILL/RISNEK DATE May 06, 2010 DEPTH 7770.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 6735.00000 24 HOUR FOOTAGE 1035' CASING INFORMATION 10.75" @ 3521' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 7077.27 62.99 99.64 3993.04 6891.69 62.84 95.72 3908.60 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 9.88" SDBS FX65 1141162 5X15 4993 18 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 548.5 @ 7476.00000 47.0 @ 7304.00000 127.7 146.28795 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM 196 @ 6736.00000 87 @ 7303.00000 189.8 180.00000 RPM PUMP PRESSURE 2535 @ 7762.00000 1458 @ 6831.00000 2144.8 2344.00000 PSI DRILLING MUD REPORT DEPTH 7418' MW 9.5 VIS 43 PV 10 YP 20 FL 4.8 Gels 9/10/11 CL- 300 FC 1/- SOL 6 SD TR OIL 3/91 MBL 5 pH 9.4 Ca+ 40 CCI MWD SUMMARY INTERVAL TO 10 TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 95 @ 7488.00000 2 @ 7118.00000 35.4 TRIP GAS - CUTTING GAS @ @ WIPER GAS 557 @ 6735' CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) 13418 @ 7690.00000 465 @ 7585.00000 6177.4 CONNECTION GAS HIGH 15 ETHANE (C -2) 705 @ 7467.00000 7 @ 6736.00000 200.3 AVG 0 -5 PROPANE (C -3) 207 @ 7690.00000 0 @ 6752.00000 42.3 CURRENT 0 BUTANE (C -4) 55 @ 7691.00000 0 @ 7435.00000 4.6 CURRENT BACKGROUND /AVG 40 PENTANE (C -5) 0 @ 7770.00000 0 @ 7770.00000 0.0 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SILT, CLAY, SAND, CARBONACEOUS SILT PRESENT LITHOLOGY 7770' = 90% CARBONACEOUS SILTSTONE, 10% SAND DAILY MONITOR THE WELL, PUMP A 20 BBL NUT PLUG SWEEP, CHANGE OUT SAVOR SUB, INSPECT AND SERVICE THE TOP DRIVE, ACTIVITY CLEAN PITS, FILL WITH NEW MUD, RUN IN THE HOLE FROM 3521' TO 6547', WASH DOWN TO 6735' WIPER GAS 557 UNITS, SUMMARY DISPLACE MUD AND FILL PITS WITH NEW MUD, CIRCULATE AND THEN DRILL FORMATION TO 6924', SERVICE THE RIG, DRILL FORMATION TO 7770' (MIDNIGHT). EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW + 2 SC DAILY COST $3320 REPORT BY LEES F. BROWNE JR. • file: / /C: \Documents and Settings \EpochAdmin\My Documents \My Wells \CONOCOPHILIP... 5/6/2010 Daily Report Page 1 of 1 • ConocoPhillips Alaska, Inc. DAILY WELLSITE REPORT EPOCH 2L -310 REPORT FOR HILURISNEK DATE May 07, 2010 DEPTH 9507.00000 PRESENT OPERATION DRILLING TIME 24 HOURS YESTERDAY 7770.00000 24 HOUR FOOTAGE 1737' CASING INFORMATION 10.75" @ 3521' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 8870.60' 63.77 99.12 4796.34' SURVEY DATA 8679.91 64.46 97.03 4712.91' 8494.94 63.64 96.26 4632.07' 8209.78 63.50 95.73 4504.70' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 9.88" SDBS FX65 1141162 6X15 4993' 34 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 253.2 @ 7772.00000 24.8 @ 8619.00000 124.4 106.17277 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM 184 @ 8056.00000 105 @ 8993.00000 158.5 106.00000 RPM PUMP PRESSURE 2820 @ 8936.00000 1678 @ 9376.00000 2541.0 2397.00000 PSI DRILLING MUD REPORT DEPTH 9381' MW 9.6 VIS 42 PV 10 YP 19 FL 4.4 Gels 8/10/12 CL- 200 FC 1/- SOL 7 SD TR OIL 3/91 MBL 14 pH 9.4 Ca+ 40 CCI MWD SUMMARY al INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 220 @ 8938.00000 1 @ 7955.00000 41.5 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C -1) 35402 @ 8938.00000 183 @ 7955.00000 6700.5 CONNECTION GAS HIGH 0 ETHANE (C -2) 2214 @ 8938.00000 15 @ 7955.00000 404.7 AVG 0 PROPANE (C -3) 879 @ 8938.00000 6 @ 7947.00000 159.3 CURRENT 0 BUTANE (C -4) 385 @ 8938.00000 2 @ 7947.00000 65.3 CURRENT BACKGROUND /AVG 45 PENTANE (C -5) 71 @ 9371.00000 0 @ 8799.00000 6.2 HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY SILT, CLAY, SAND, SANDSTONE, CARBON SILT PRESENT LITHOLOGY 9500' = 30% SAND, 30% CLAY, 30% SILT, 10% CARBON SILT DAILY ACTIVITY SUMMARY DRILLING FORMATION WITH ROUTINE CONNECTIONS EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW + 2 SC DAILY COST $3320 REPORT BY LEES F. BROWNE JR. • file: / /C:\Documents and Settings\EpochAdmin\My Documents \My Wells \CONOCOPHILIP... 5/7/2010 Daily Report Page 1 of 1 41, ConocoPhillips Alaska, Inc. DAILY WELLSITE REPORT EPOCH 2L -310 REPORT FOR HILL/RISNEK DATE May 07, 2010 DEPTH 10252.00000 PRESENT OPERATION BACK REAM OUT OF THE HOLE TIME 24 HOURS YESTERDAY 9507.00000 24 HOUR FOOTAGE 745' CASING INFORMATION 10.75" @ 3521' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 10252' 41.18 100.47 5618.98' SURVEY DATA 10191.17' 41.32 99.80 5573.21' 10001.68' 42.31 98.98 5432.07' 9816.73 43.05 99.17 5295.33' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 9.88" SDBS FX65 1141162 6X15 4993' 10252' 5262' 45:38 N/A TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG I RATE OF PENETRATION 146.8 @ 10096.00000 25.7 @ 10132.00000 118.9 115.23730 FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM 109 @ 9849.00000 61 @ 10036.00000 106.7 108.00000 RPM PUMP PRESSURE 2673 @ 10222.00000 1902 @ 9761.00000 2521.2 2603.00000 PSI DRILLING MUD REPORT DEPTH 10252' MW 9.6 VIS 40 PV 7 YP 19 FL 4.8 Gels 7/9/10 CL- 200 FC 1/- SOL 8 SD TR OIL 3/90 MBL 14 pH 9.3 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 439 @ 10042.00000 15 @ 9588.00000 102.4 TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C -1) 40427 @ 10042.00000 2100 @ 9791.00000 12316.5 CONNECTION GAS HIGH 0 ETHANE (C -2) 8564 @ 9988.00000 194 @ 9588.00000 1679.1 AVG 0 PROPANE (C -3) 5268 @ 10052.00000 74 @ 9588.00000 967.3 CURRENT 0 BUTANE (C -4) 2508 @ 10015.00000 33 @ 9588.00000 480.9 CURRENT BACKGROUND /AVG 77 BROOH PENTANE (C -5) 944 @ 10015.00000 4 @ 9588.00000 196.4 HYDROCARBON S8 RESEVOIR OIL SHOW SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION 9870 TO 10075' SANDSTONE BEFORE 35 MAX SS = VFU -VFL, GRN SUP, 95% BRI LTGRN SMPL FLOR, V FNT PETRO ODR, N STN, N 439 AFTER 55 FREE OIL, INST MED STRMG CT, MOD DEVLP TO BLU/WHT CT,MOD RESD STN, G PORO + PERM, FAIR TO GOOD OIL SHOWS LITHOLOGY SILT, CARBON SILT, CLAY, SAND, SANDSTONE PRESENT LITHOLOGY 10252' = 80% CARBONACEOUS SILT, 10% SILT, 10% SANDSTONE DAILY ACTIVITY DRILL FORMATION TO 9755', CONTROL DRILL AT 50 FT /HR TO 10100', DRILL FORMATION TO 10252', CIRCULATE BOTTOMS UP SUMMARY AND BACK REAM OUT OF THE HOLE TO 8252', MAX GAS BACK REAMING TO 8252' WAS 113 UNITS EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW + 2 SC DAILY COST $3320 REPORT BY LEES F. BROWNE JR. • file: / /C:\Documents and Settings\EpochAdmin\My Documents \My Wells \CONOCOPHILIP... 5/8/2010 Daily Report Page 1 of 1 • ConocoPhillips Alaska, Inc. DAILY WELLSITE REPORT Ell EPOCH 2L -310 REPORT FOR HILURISNEK DATE May 09, 2010 DEPTH 10252.00000 PRESENT OPERATION RIG UP TO RUN CASING TIME 24 HOURS YESTERDAY 10252.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 10.75" @ 3521' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 10252' 41.18 100.47 5618.98' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 9.88" SDBS FX65 1141162 6X15 4993' 10252' 5262' 45:38 0- 0- NO- A- X -I -NO TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10252' MW 9.7 VIS 44 PV 11 YP 20 FL 4.4 Gels 8/9/11 CL- 200 FC 1/- SOL 8 SD TR OIL 2/90 MBL 19 pH 9.2 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS • GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 95 @ 6735' 0 @ RIH 17 POOH TRIP GAS - CUTTING GAS @ @ WIPER GAS 95 @ 6735' CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ @ AVG - PROPANE (C -3) @ @ CURRENT - BUTANE (C -4) @ @ CURRENT BACKGROUND /AVG 0 PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 10252' = 80% CARBONACEOUS SILT, 10% SANDSTONE, 10% SILTSTONE BACK REAM OUT OF THE HOLE FROM 8242' TO 6735', MONITOR THE WELL 10 MINUTES, CIRCULATE BOTTOMS UP, MAX GAS 95 DAILY UNITS, MONITOR THE WELL 15 MINUTES, RUN IN THE HOLE FROM 6735' TO 8054', BACK REAM OUT OF THE HOLE TO 3521', ACTIVITY CIRCULATE BOTTOMS UP, MAX GAS 4 UNITS, MONITOR THE WELL 15 MINUTES, PULL OUT OF THE HOLE TO 666', LAY DOWN SUMMARY HWDP, JARS AND DRILL COLLARS, REMOVE NUKES, DOWN LOAD THE MWD TOOL, CLEAN AND CLEAR THE RIG FLOOR, INSTALL 7 5/8" RAMS AND PREP TO RUN CASING. EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW + 2 SC DAILY COST $3520 REPORT BY LEES F. BROWNE JR. III file: / /C:\Documents and Settings\EpochAdmin\My Documents \My Wells \CONOCOPHILIP... 5/9/2010 Daily Report Page 1 of 1 • ConocoPhillips Alaska, Inc. DAILY WELLSITE REPORT E1 EPOCH 2L -310 REPORT FOR HILURESNEK DATE May 09, 2010 DEPTH 10252.00000 PRESENT OPERATION RUN 7 5/8" CASING TIME 24 HOURS YESTERDAY 10252.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 10.75" @ 3521' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 10252' 41.18 100.47 5618.98' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 10252' MW 9.7 VIS 47 PV 17 YP 20 FL 4.2 Gels 12/12/15 CL- 200 FC 1/- SOL 8 SD TR OIL 2/90 MBL 20 pH 9.0 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS • GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 181 @ 8467 0 @ TIH 55 TIH CIRC TRIP GAS - CUTTING GAS @ @ WIPER GAS - CHROMATOGRAPHY (ppm) SURVEY - METHANE (C -1) @ @ CONNECTION GAS HIGH - ETHANE (C -2) @ @ AVG - PROPANE (C -3) @ @ CURRENT - BUTANE (C-4) @ @ CURRENT BACKGROUND /AVG 7 TIH PENTANE (C -5) @ @ HYDROCARBON SHOWS NO SHOWS THE LAST 24 HOURS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 10252' = 80% CARBONACEOUS SILT, 10% SANDSTONE, 10% SILT RIG UP CASING EQUIPMENT, CLEAN RIG FLOOR, RIG UP TEST EQUIPMENT, TEST TOP RAMS, TEST PLUG DID NOT HOLD, PULL DAILY TEST PLUG AND DRAIN STACK, RIG UP TO TEST, TEST FAILED, RETEST, TEST GOOD, RIG DOWN TEST EQUIPMENT, INSPECT ACTIVITY RAMS, REPLACE TOP SEALS, RIG UP TO TEST TOP RAMS, TEST, RIG DOWN TEST EQUIPMENT, MAKE UP SHOE JOINT, FLOAT SUMMARY COLLAR AND RUN IN THE HOLE TO 3436', CIRCULATE BOTTOMS UP, MAX GAS WAS 14 UNITS, RUN IN THE HOLE TO 6047', CIRCULATE BOTTOMS UP, MAX GAS WAS 101 UNITS, RUN IN THE HOLE TO 8467', CIRCULATE BOTTOMS UP, MAX GAS WAS 181 UNITS, RUN IN THE HOLE. EPOCH PERSONNEL ON BOARD BROWNE, WINSLOW DAILY COST $2670 REPORT BY LEES F. BROWNE JR. S file: / /C: \Documents and Settings\EpochAdmin\My Documents \My Wells \CONOCOPHILI... 5/10/2010