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210-091
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: CRU CD4-12 (PTD 210-091) 30-day monitor on gas complete AOGCC Notification Date:Wednesday, September 3, 2025 9:45:21 AM Attachments:image001.png AnnComm Surveillance TIO for CD4-12.pdf From: Shulman, Mark <Mark.Shulman@conocophillips.com> Sent: Wednesday, September 3, 2025 9:35 AM To: Automation, AK Wells <akwellsautomation@conocophillips.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com> Subject: CRU CD4-12 (PTD 210-091) 30-day monitor on gas complete AOGCC Notification Well Name: CD4-12 Facility: WNS PTD: 210-091 Well Type: Injector AA Number (if applicable): AIO 18D.005 AMD Internal Waiver (Yes/No if applicable): Yes Type of Issue: Plan forward Maximum Pressure (if applicable): Date of Occurrence (if applicable): 9/3/25 Chris, CRU CD4-12 has successfully completed its 30-day monitor on gas injection. Attached is the TIO plot over the last 90 days. Additionally, CRU CD4-12 passed a SW MIT-IA (4,200 psi) on 7/6/25. CPAI plan is to keep the well on gas injection. A well schematic and 90-day TIO is attached. Please let us know if you have any questions or disagree with this plan. Thanks, Mark Mark Shulman WNS Sr. Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 CD4-12 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD4-12 2025-06-11 1305 280 -1025 IA CD4-12 2025-06-12 317 35 -282 IA CD4-12 2025-06-16 77 0 -77 IA CD4-12 2025-07-06 1345 1300 -45 IA Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD4-12 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull A1, Circ-out, set A1 and Slip Stop on top of A1 CD4-12 6/2/2025 amwombl Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered for water-only injection due to TxIA during gas injection 5/28/2019 kautzr Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 24" Insulated 16 15.2535.0 112.0 112.062.50 H-40 Welded SURFACE 9 5/8 8.83 34.7 2,910.5 2,395.1 40.00 L-80 IBT INTERMEDIATE 7 6.28 34.5 11,497.0 7,383.5 26.00 L-80 BTCM OPEN HOLE 6.151 11,497.0 16,351.0 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.9 Set Depth… 9,980.6 Set Depth… 7,096.7 String Max No… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-M ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.931.90.00 HANGER 10.850 FMC 11" x 4 1/2" TUBING HANGER 3.958 2,177.2 1,980.7 50.29 NIPPLE 5.750 Camco BAL-O LANDING NIPPLE w/ DB PROFILE Camco BAL-O nipple 3.813 7,458.2 5,577.8 45.35 GAS LIFT 5.984 Camco 4 1/2" KBG-2 GLM 3.909" ID CAMCO KBG-2 3.909 9,721.1 6,999.9 66.72 GAS LIFT 5.984 Camco 4 1/2" KBG-2 GLM 3.909" ID CAMCO KBG-2 3.909 9,834.1 7,043.7 67.90 PACKER 5.880 BAKER PREMIER PACKER Baker Premier 3.875 9,894.4 7,066.0 68.56 NIPPLE 5.050 HES 'XN' NIPPLE NO GO Halliburt on XN 3.725 9,979.2 7,096.3 69.91 WLEG 5.250 WIRELINE ENTRY GUIDE (5.25" OD - 4" ID) Unique Machine 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,170.0 1,976.1 50.09 SLIP STOP 4.5" Slip Stop set right above the A1 Inj Vlv to hold A1 in place. (OAL 17") 6/2/2025 2.125 2,177.2 1,980.7 50.29 INJ VALVE 4.5" A1 Injection Valve on Spacer, 3.812" DB Lock (OAL 74") Camco A1 HWS- 211 6/2/2025 1.250 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 7,458.2 5,577.8 45.35 1 GAS LIFT DMY BK-5 1 0.0 12/8/20100.000 9,721.16,999.966.72 2 GAS LIFT DMY BK 1 0.05/31/2025 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 11,497.0 7,383.5 87.85 OPEN HOLE 6.151 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 4,855.0 5,900.0 3,731.9 4,472.4 Intermediate Casing 8/25/2010 7,825.0 11,497.0 5,836.9 7,383.5 Intermediate Casing Cement 8/25/2010 HORIZONTAL, CD4-12, 6/3/2025 5:38:26 AM Vertical schematic (actual) OPEN HOLE; 11,497.0-16,351.0 OPEN HOLE; 11,497.0-16,351.0 INTERMEDIATE; 34.5-11,497.0 Float Shoe; 11,494.9-11,497.0 Float Collar; 11,411.6-11,412.6 CASING Baffle; 11,369.3- 11,370.3 WLEG; 9,979.2 NIPPLE; 9,894.4 PACKER; 9,834.1 GAS LIFT; 9,721.1 Intermediate Casing Cement; 7,825.0 ftKB GAS LIFT; 7,458.2 Collar; 5,900.1-5,902.5 Intermediate Casing; 4,855.0 ftKB SURFACE; 34.7-2,910.5 Float Shoe; 2,908.7-2,910.5 Float Collar; 2,821.5-2,823.0 INJ VALVE; 2,177.2 NIPPLE; 2,177.2 CONDUCTOR 24" Insulated; 35.0-112.0 Casing Hanger; 34.5-37.1 Casing Hanger; 34.8-36.1 HANGER; 31.9 WNS INJ KB-Grd (ft)RR Date 4/3/2002 Other Elev… CD4-12 ... TD Act Btm (ftKB) 16,004.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032041401 Wellbore Status INJ Max Angle & MD Incl (°) 91.73 MD (ftKB) 13,296.53 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 4, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD4-12 COLVILLE RIV UNIT CD4-12 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/04/2025 CD4-12 50-103-20414-01-00 210-091-0 G SPT 7043 2100910 4000 3800 3800 3800 3800 624 650 650 650 REQVAR P Sully Sullivan 7/6/2025 2 year Test to MAIP per AIO 18D.005 (4000psi). Maintained close to 500 DP from tubing. Conoco engineer Requested max of 4250 and I did not see a problem with that. 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:COLVILLE RIV UNIT CD4-12 Inspection Date: Tubing OA Packer Depth 1285 4220 4205 4200IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS250706152405 BBL Pumped:2.7 BBL Returned:2.7 Monday, August 4, 2025 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:WNS Wells Integrity Eng Subject:10-426 form for CD4-pad SI non-witnessed MIT-IA 6-18-25 Date:Thursday, June 19, 2025 7:27:59 AM Attachments:image001.png MIT CRU CD4 PAD SI TESTS 06-18-25.xlsx Morning, Please see the attached 10-426 form from the CD4-pad SI non-witnessed MIT-IA that was performed on 6-18-25. If you have any questions, please let me know. Thanks, Matt Miller/ Bruce Richwine DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com &ROYLOOH5LYHU8QLW&' 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2100910 Type Inj N Tubing 435 795 790 790 Type Test P Packer TVD 7044 BBL Pump 3.3 IA 800 4240 4160 4140 Interval V Test psi 4000 BBL Return 3.4 OA 515 540 540 540 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2120050 Type Inj N Tubing 1180 1510 1510 1510 Type Test P Packer TVD 7291 BBL Pump 3.2 IA 460 3300 3250 3245 Interval V Test psi 3000 BBL Return 3.2 OA 10 14 16 16 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2061450 Type Inj N Tubing 2390 2895 2890 2890 Type Test P Packer TVD 5967 BBL Pump 2.4 IA 970 4220 4130 4120 Interval V Test psi 4000 BBL Return 2.4 OA 470 650 640 635 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 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 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 Notes:MITIA to maximum anticipated injection pressure per AIO 18E.006. CD4-214 Notes:MITIA to maximum gas injection pressure per AIO 28.006 AMENDED Notes: ConocoPhillips Alaska Inc, Alpine / CRU / CD4 PAD Non-witnessed Van Camp 06/18/25 Notes:MITIA to maximum gas injection pressure per AIO 18D.005 AMENDED Notes: Notes: Notes: CD4-12 CD4-213B Form 10-426 (Revised 01/2017)2025-0618_MIT_CRU_CD4-12 9 9 9 9 999 99 99 9 9 -5HJJ CD4-12 ITIA AIO 18D.005 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: MIT-IA for CD4-12 (PTD 2100910) Date:Monday, June 30, 2025 2:52:27 PM Attachments:AnnComm Surveillance TIO for CD4-12.pdf From: NSK Wells Integrity Eng CPF2 <n2549@conocophillips.com> Sent: Monday, June 30, 2025 1:18 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: WNS Wells Integrity Eng <WNSIntegrity@conocophillips.com> Subject: MIT-IA for CD4-12 Hi Chris, I left a message for you but wanted to email in case you are out of the office this week. CD4-12 is WAG injection well operated under AREA INJECTION ORDER 18D.005 AMENDED. CPAI reported suspected TxIA integrity on gas injection on 5/5/2025 and CPAI has completed an IA circulation to fresh fluids and started a 30 day monitor on gas injection as per the plan communicated to the AOGCC. The well is due for its AOGCC State Witnessed MIT-IA on 6/30/2025. The maximum test pressure per the well design envelope is 4250 psi but the well is on gas injection with an injection pressure of 3800 psi. With the 500 psi differential and some additional pressure at the start of pressure fall off, we anticipate we’d need to start the MIT-IA at ~4500 psi to achieve the AOGCC requirements. We wanted to get guidance on the best way to accomplish the intent of the MIT-IA out of these options. 1. CPAI conducted a Shut In MIT-IA to 4240 psi on 6/18/2025. Could this be considered the State Witnessed MIT-IA? 2. The well is currently on a 30 day gas injection monitoring which concludes on 7/20/2025. We could delay the SW MIT-IA until we have WAG’ed the well back to water injection and achieve the dP and max injection pressure targets as the tubing pressure will be lower on water injection. 3. We could conduct a SW MIT-IA on gas injection to 4240 psi without achieving the target dP on the tubing. The tubing pressure would be at 3800 psi. Please give me a call to discuss. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 CD4-12 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD4-12 2025-05-03 2380 2000 -380 IA CD4-12 2025-06-11 1305 280 -1025 IA CD4-12 2025-06-12 317 35 -282 IA CD4-12 2025-06-16 77 0 -77 IA Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD4-12 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull A1, Circ-out, set A1 and Slip Stop on top of A1 CD4-12 6/2/2025 amwombl Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered for water-only injection due to TxIA during gas injection 5/28/2019 kautzr Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 24" Insulated 16 15.2535.0 112.0 112.062.50 H-40 Welded SURFACE 9 5/8 8.83 34.7 2,910.5 2,395.1 40.00 L-80 IBT INTERMEDIATE 7 6.28 34.5 11,497.0 7,383.5 26.00 L-80 BTCM OPEN HOLE 6.151 11,497.0 16,351.0 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.9 Set Depth… 9,980.6 Set Depth… 7,096.7 String Max No… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-M ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.931.90.00 HANGER 10.850 FMC 11" x 4 1/2" TUBING HANGER 3.958 2,177.2 1,980.7 50.29 NIPPLE 5.750 Camco BAL-O LANDING NIPPLE w/ DB PROFILE Camco BAL-O nipple 3.813 7,458.2 5,577.8 45.35 GAS LIFT 5.984 Camco 4 1/2" KBG-2 GLM 3.909" ID CAMCO KBG-2 3.909 9,721.1 6,999.9 66.72 GAS LIFT 5.984 Camco 4 1/2" KBG-2 GLM 3.909" ID CAMCO KBG-2 3.909 9,834.1 7,043.7 67.90 PACKER 5.880 BAKER PREMIER PACKER Baker Premier 3.875 9,894.4 7,066.0 68.56 NIPPLE 5.050 HES 'XN' NIPPLE NO GO Halliburt on XN 3.725 9,979.2 7,096.3 69.91 WLEG 5.250 WIRELINE ENTRY GUIDE (5.25" OD - 4" ID) Unique Machine 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,170.0 1,976.1 50.09 SLIP STOP 4.5" Slip Stop set right above the A1 Inj Vlv to hold A1 in place. (OAL 17") 6/2/2025 2.125 2,177.2 1,980.7 50.29 INJ VALVE 4.5" A1 Injection Valve on Spacer, 3.812" DB Lock (OAL 74") Camco A1 HWS- 211 6/2/2025 1.250 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 7,458.2 5,577.8 45.35 1 GAS LIFT DMY BK-5 1 0.0 12/8/20100.000 9,721.16,999.966.72 2 GAS LIFT DMY BK 1 0.05/31/2025 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 11,497.0 7,383.5 87.85 OPEN HOLE 6.151 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 4,855.0 5,900.0 3,731.9 4,472.4 Intermediate Casing 8/25/2010 7,825.0 11,497.0 5,836.9 7,383.5 Intermediate Casing Cement 8/25/2010 HORIZONTAL, CD4-12, 6/3/2025 5:38:26 AM Vertical schematic (actual) OPEN HOLE; 11,497.0-16,351.0 OPEN HOLE; 11,497.0-16,351.0 INTERMEDIATE; 34.5-11,497.0 Float Shoe; 11,494.9-11,497.0 Float Collar; 11,411.6-11,412.6 CASING Baffle; 11,369.3- 11,370.3 WLEG; 9,979.2 NIPPLE; 9,894.4 PACKER; 9,834.1 GAS LIFT; 9,721.1 Intermediate Casing Cement; 7,825.0 ftKB GAS LIFT; 7,458.2 Collar; 5,900.1-5,902.5 Intermediate Casing; 4,855.0 ftKB SURFACE; 34.7-2,910.5 Float Shoe; 2,908.7-2,910.5 Float Collar; 2,821.5-2,823.0 INJ VALVE; 2,177.2 NIPPLE; 2,177.2 CONDUCTOR 24" Insulated; 35.0-112.0 Casing Hanger; 34.5-37.1 Casing Hanger; 34.8-36.1 HANGER; 31.9 WNS INJ KB-Grd (ft)RR Date 4/3/2002 Other Elev… CD4-12 ... TD Act Btm (ftKB) 16,004.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032041401 Wellbore Status INJ Max Angle & MD Incl (°) 91.73 MD (ftKB) 13,296.53 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NIPPLE CD4-12 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD4-12 2025-02-19 2400 1000 -1400 IA CD4-12 2025-05-03 2380 2000 -380 IA Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD4-12 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull A1, Set New A1 CD4-12 2/23/2025 oberr Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered for water-only injection due to TxIA during gas injection 5/28/2019 kautzr Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 24" Insulated 16 15.2535.0 112.0 112.062.50 H-40 Welded SURFACE 9 5/8 8.83 34.7 2,910.5 2,395.1 40.00 L-80 IBT INTERMEDIATE 7 6.28 34.5 11,497.0 7,383.5 26.00 L-80 BTCM OPEN HOLE 6.151 11,497.0 16,351.0 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.9 Set Depth… 9,980.6 Set Depth… 7,096.7 String Max No… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-M ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.931.90.00 HANGER 10.850 FMC 11" x 4 1/2" TUBING HANGER 3.958 2,177.2 1,980.7 50.29 NIPPLE 5.750 Camco BAL-O LANDING NIPPLE w/ DB PROFILE Camco BAL-O nipple 3.813 7,458.2 5,577.8 45.35 GAS LIFT 5.984 Camco 4 1/2" KBG-2 GLM 3.909" ID CAMCO KBG-2 3.909 9,721.1 6,999.9 66.72 GAS LIFT 5.984 Camco 4 1/2" KBG-2 GLM 3.909" ID CAMCO KBG-2 3.909 9,834.1 7,043.7 67.90 PACKER 5.880 BAKER PREMIER PACKER Baker Premier 3.875 9,894.4 7,066.0 68.56 NIPPLE 5.050 HES 'XN' NIPPLE NO GO Halliburt on XN 3.725 9,979.2 7,096.3 69.91 WLEG 5.250 WIRELINE ENTRY GUIDE (5.25" OD - 4" ID) Unique Machine 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,177.2 1,980.7 50.29 INJ VALVE 4.5" A1 Injection Valve on Spacer, 3.812" DB Lock (OAL79") Camco A1 HSS- 164 2/23/2025 1.250 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 7,458.2 5,577.8 45.35 1 GAS LIFT DMY BK-5 1 0.0 12/8/20100.000 9,721.1 6,999.9 66.72 2 GAS LIFT DMY BK 1 0.0 10/4/2024 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 11,497.0 7,383.5 87.85 OPEN HOLE 6.151 Cement Squeezes Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Des Com Pump Start Date 4,855.0 5,900.0 3,731.9 4,472.4 Intermediate Casing 8/25/2010 7,825.0 11,497.0 5,836.9 7,383.5 Intermediate Casing Cement 8/25/2010 HORIZONTAL, CD4-12, 2/23/2025 7:18:54 PM Vertical schematic (actual) OPEN HOLE; 11,497.0-16,351.0 OPEN HOLE; 11,497.0-16,351.0 INTERMEDIATE; 34.5-11,497.0 Float Shoe; 11,494.9-11,497.0 Float Collar; 11,411.6-11,412.6 CASING Baffle; 11,369.3- 11,370.3 WLEG; 9,979.2 NIPPLE; 9,894.4 PACKER; 9,834.1 GAS LIFT; 9,721.1 Intermediate Casing Cement; 7,825.0 ftKB GAS LIFT; 7,458.2 Collar; 5,900.1-5,902.5 Intermediate Casing; 4,855.0 ftKB SURFACE; 34.7-2,910.5 Float Shoe; 2,908.7-2,910.5 Float Collar; 2,821.5-2,823.0 INJ VALVE; 2,177.2 NIPPLE; 2,177.2 CONDUCTOR 24" Insulated; 35.0-112.0 Casing Hanger; 34.5-37.1 Casing Hanger; 34.8-36.1 HANGER; 31.9 WNS INJ KB-Grd (ft)RR Date 4/3/2002 Other Elev… CD4-12 ... TD Act Btm (ftKB) 16,004.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032041401 Wellbore Status INJ Max Angle & MD Incl (°) 91.73 MD (ftKB) 13,296.53 WELLNAME WELLBORE 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: CRU CD4-12 (PTD# 210-091) circ-out Date:Monday, September 30, 2024 9:45:50 AM From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Thursday, September 26, 2024 9:51 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: CRU CD4-12 (PTD# 210-091) circ-out Chris, CRU CD4-12 (PTD# 210-091) was reported by CPAI for IA pressure exceeded MAOP on 7/26/24. On 9/16, the passed a MIT-IA to 3,025 psi. This well is waivered (AIO 18D.005 Amended) for water alternating gas (WAG) injection with a known tubing by inner annulus (TxIA) pressure communication. The well’s IA will be circulated out with liquid and then the well be brought online with gas injection for monitoring. Let me know if you have any questions or disagree with this plan. Thanks, Mark Shulman WNS Well Integrity Engineer ConocoPhillips Alaska Email Mark.Shulman@conocophillips.com Phone (907) 263-3782 Mobile (602) 513-0775 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: CRU CD4-12 (PTD# 210-091) Date:Monday, July 29, 2024 9:55:24 AM Attachments:AnnComm Surveillance TIO for CD4-12.pdf From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Friday, July 26, 2024 9:00 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: CRU CD4-12 (PTD# 210-091) Chris, CRU CD4-12 (PTD# 210-091) was reported by operations for IA pressure exceeded MAOP (2401psi). This well is waivered (AIO 18D.005 Amended) for water alternating gas (WAG) injection with a known tubing by inner annulus (TxIA) pressure communication. The IA was bled, and operations placed a gas cap. The IA pressure is now at 1800psi. The well will remain online. Attached is the 90-day TIO plot and wellbore schematic. Let me know if you have any questions or disagree with this plan. Thanks, Kate Dodson | Senior Well Integrity Engineer ConocoPhillips Alaska | AK Intervention & Integrity O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD4-12 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull A1, SBHP, Re-set Modified A1CD4-12 10/14/2023 oberr Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered for water-only injection due to TxIA during gas injection 5/28/2019 kautzr Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 24" Insulated 16 15.2535.0 112.0 112.062.50 H-40 Welded SURFACE 9 5/88.83 34.7 2,910.5 2,395.1 40.00 L-80 IBT INTERMEDIATE 7 6.28 34.5 11,497.0 7,383.5 26.00 L-80 BTCM OPEN HOLE 6.15111,497.016,351.0 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 31.9 Set Depth … 9,980.6 Set Depth … 7,096.7 String Max No… 4 1/2 Tubing Description TUBING Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT-M ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 31.931.90.00 HANGER 10.850 FMC 11" x 4 1/2" TUBING HANGER 3.958 2,177.2 1,980.7 50.29 NIPPLE 5.750 Camco BAL-O LANDING NIPPLE w/ DB PROFILE Camco BAL-O nipple 3.813 7,458.2 5,577.8 45.35 GAS LIFT 5.984 Camco 4 1/2" KBG-2 GLM (3.909" ID w/ DV) CAMCO KBG-2 3.909 9,721.1 6,999.9 66.72 GAS LIFT 5.984 Camco 4 1/2" KBG-2 GLM (3.909" ID w/ DCK2 SV) CAMCO KBG-2 3.909 9,834.1 7,043.7 67.90 PACKER 5.880 BAKER PREMIER PACKER Baker Premier 3.875 9,894.4 7,066.0 68.56 NIPPLE 5.050 HES 'XN' NIPPLE NO GO Halliburt on XN 3.725 9,979.2 7,096.3 69.91 WLEG 5.250 WIRELINE ENTRY GUIDE (5.25" OD - 4" ID) Unique Machine 4.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 2,177.21,980.7 50.29 INJ VALVE 4.5" A1 Injection Valve, 37.25" ext, 3.812" DB Lock Camco A1 HSS- 165 10/14/2023 1.250 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 7,458.2 5,577.8 45.35 1 GAS LIFT DMY BK-5 1 0.0 12/8/20100.000 9,721.1 6,999.9 66.72 2 GAS LIFT DMY BK 1 0.0 12/10/20100.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 11,497.0 7,383.5 87.85 OPEN HOLE 6.151 HORIZONTAL, CD4-12, 10/15/2023 6:27:30 AM Vertical schematic (actual) OPEN HOLE; 11,497.0-16,351.0 OPEN HOLE; 11,497.0-16,351.0 INTERMEDIATE; 34.5-11,497.0 Float Shoe; 11,494.9-11,497.0 Float Collar; 11,411.6-11,412.6 CASING Baffle; 11,369.3- 11,370.3 WLEG; 9,979.2 NIPPLE; 9,894.4 PACKER; 9,834.1 GAS LIFT; 9,721.1 Intermediate Casing Cement; 7,825.0 ftKB GAS LIFT; 7,458.2 Collar; 5,900.1-5,902.5 Intermediate Casing; 4,855.0 ftKB SURFACE; 34.7-2,910.5 Float Shoe; 2,908.7-2,910.5 Float Collar; 2,821.5-2,823.0 INJ VALVE; 2,177.2 NIPPLE; 2,177.2 CONDUCTOR 24" Insulated; 35.0-112.0 Casing Hanger; 34.5-37.1 Casing Hanger; 34.8-36.1 HANGER; 31.9 WNS INJ KB-Grd (ft)RR Date 4/3/2002 Other Elev… CD4-12 ... TD Act Btm (ftKB) 16,004.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032041401 Wellbore Status INJ Max Angle & MD Incl (°) 91.73 MD (ftKB) 13,296.53 WELLNAME WELLBORE Annotation Last WO: End DateH2S (ppm)DateComment SSSV: NIPPLE New Plugback Esets 7/15/2024 Well Name API Number PTD Number ESet Number Date CRU C1-07 PB2 50-103-20478-71-00 203-225 T39188 1-29-2007 CRU CD2-467 PB1 50-103-20579-70-00 208-114 T39189 10-31-2008 CRU CD4-12 PB1 50-103-20414-70-00 210-091 T39190 9-20-2010 CRU CD4-210A PB1 50-103-20533-70-00 211-072 T39191 9-9-2011 KRU 1B-15AL3 PB1 50-029-22465-72-00 207-067 T39192 11-23-2009 KRU 1E-12L1 PB1 50-029-20736-70-00 210-004 T39193 5-24-2010 KRU 1E-12L2-01 PB1 50-029-20736-72-00 210-007 T39194 5-24-2010 KRU 3H-12A PB1 50-103-20088-70-00 211-081 T39195 9-9-2012 KRU 3I-11AL2 PB1 50-029-21932-70-00 210-076 T39196 11-1-2010 ODSK-33 PB1 50-703-20562-70-00 207-183 T39197 6-20-2008 OI11-01 50-029-23430-70-00 210-106 T39198 11-2-2010 OP04-07 PB1 50-029-23409-70-00 208-199 T39200 7-6-2010 OP08-04 PB1 50-029-23424-70-00 210-041 T39201 7-28-2010 PBU 06-02A PB1 50-029-20282-70-00 211-026 T39202 7-25-2011 PBU 15-05B PB1 50-029-20731-71-00 211-057 T39203 8-20-2011 PBU 15-16B PB1 50-029-21115-70-00 210-020 T39204 7-8-2010 PBU 18-04B PB1 50-029-20875-70-00 201-090 T39205 12-6-2002 PBU J-16B PB1 50-029-20967-70-00 212-014 T39206 9-28-2012 PBU K-05D PB1 50-029-21418-71-00 211-077 T39207 1-20-2012 PBU V-204L1 50-029-23217-60-00 204-132 T39208 11-13-2006 PBU W-19B PB1 50-029-22006-72-00 210-065 T39209 1-13-2011 PBU W-19BL1 PB1 50-029-22006-73-00 210-066 T39210 1-18-1011 SP23-N03 PB1 50-629-23456-70-00 211-127 T39211 3-5-2012 TBU M-10 PB1 50-733-20588-70-00 209-154 T39212 4-23-2010 CRU CD4-12 PB1 50-103-20414-70-00 210-091 T39190 9-20-2010 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD4-12 COLVILLE RIV UNIT CD4-12 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 CD4-12 50-103-20414-01-00 210-091-0 W SPT 7043 2100910 4000 2564 2562 2560 2561 456 756 742 731 REQVAR P Sully Sullivan 6/11/2023 MITIA to maip per aio 18d.005 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:COLVILLE RIV UNIT CD4-12 Inspection Date: Tubing OA Packer Depth 805 4400 4320 4310IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230612104321 BBL Pumped:3.6 BBL Returned:3.5 Thursday, July 27, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 MITIA James B. Regg Digitally signed by James B. Regg Date: 2023.07.27 12:03:48 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 17, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CD4 -12 COLVILLE RIV UNIT C04-12 Sire: Inspector Reviewed By: 11.1. Supry J Comm Well Name COLVILLE RIV UNIT CD4 -12 API Well Number 50-103-20414-01-00 Inspector Name: Lou Laubenstein Permit Number: 210-091-0 Inspection Date: 6/11/2021 Insp Num: mitLOL210611113801 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4 -12 Type Inj w - TVD 7043 Tubing 2400 zaoo_ 2400 . zaoo _ PTD ')100910 Type Test SPT 'Test psi 3000 IA 1775 3300 32-30- 3220 - BBL Pumped: T 1,6 " BBL Returned: 1.6 OA 469 1 480 Oso - 480 _ Interval REQVAR P/F P Notes: MIT -IA to Maximum Anticipated Injection pressure per AIO 18D.005 Thursday, June 17, 2021 Page I of I MEMORANDUM State of Alaska Inspection Date: 6/202019 Alaska Oil and Gas Conservation Commission TO: Jim Regg 2p P.I. Supervisor ' �j j 7[fll DATE: Tuesday, July 2, 2019 SUBJECT: Mechanical Integrity Tests (( I ConowPhillips Alaska, Inc. 15 Min 30 Min 45 Min 60 Min CD4 -12 FROM: Adam Earl COLVILLE RIV UNIT CD4 -12 Petroleum Inspector 1 7043 Tubing Ste: Inspector 2602 - Reviewed By: 2602- . P.I. Supry —Ti NON -CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD4 -12 API Well Number 50-103-20414-01-00 Inspector Name: Adam Earl Permit Number: 210-091-0 Inspection Date: 6/202019 Insp Num: mitAGE190623114211 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well C134-12 'IType Inj w'TVD 1 7043 Tubing 2601 - 2602 - 2602- 2602- PTD 2100910 ,Type Test) spr Test psi 2900 IA 960 3310 - 3270 3260 - BBL Pumped: 2.1 BBL Returned: 2.1 - OA 476 - 489 488 488 Interval kEQvwa P/F P Notes: MITIA tested as per AIO 18D.005 to MAIP Tuesday, July 2, 2019 Page I of I Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Friday, April 5, 2019 9:31 AM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: RE: CRU CD4 -12 (PTD#210-091) Report of Rising IA Pressure on Gas Injection Chris, CRU CD4 -12 (PTD#210-091) passed a diagnostic MITIA, but has demonstrated sufficient pressure build-up evidence to confirm that the injector in its current state has TxIA communication during MI injection. CPAI intends to WAG the well to water as soon as operationally possible for a 30 -day monitor to confirm if the well has integrity during water injection. Please let me know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity Supervisor, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From: NSK Well Integrity Supv CPF3 and WNS Sent: Sunday, March 24, 2019 9:40 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: CRU CD4 -12 (PTD#210-091) Report of Rising IA Pressure on Gas Injection Good Morning Chris, CRU MI injector CD4 -12 (PTD#210-091) is exhibiting rising IA pressure while on gas injection. This well is currently online and will be placed on a 30 -day monitor period on MI gas injection to perform diagnostics in the suspected leak's active state. CPAI intends to bleed the IA to monitor the buildup rate and will perform pack -off tests as well as an MIT -IA to confirm the integrity of the well. CPAI will correspond with the results of the monitor period. If communication on gas injection is confirmed, CPAI intends to conduct an additional 30 -day monitor period on water -only injection and will continue diagnostics as needed. Please let me know if you have any questions or disagree with this plan forward. Attached is a 90 -day TIO plot and the wellbore schematic for C134-12. Sincerely, Sara.CarWel (Ueb4w) / RacheL Ka r, t� Well Integrity Supervisor, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle(ocop.com Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Sunday, March 24, 2019 9:40 AM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: CRU CD4 12 (PTD#210-091 J Report of Rising IA Pressure on Gas Injection Attachments: CD4-12.pdf, CD4 -12 90 -day TIO.pdf Good Morning Chris, CRU MI injector CD4 -12 (PTD#210-091) is exhibiting rising IA pressure while on gas injection. This well is currently online and will be placed on a 30 -day monitor period on MI gas injection to perform diagnostics in the suspected leak's active state. CPAI intends to bleed the IA to monitor the buildup rate and will perform pack -off tests as well as an MIT -IA to confirm the integrity of the well. CPAI will correspond with the results of the monitor period. If communication on gas injection is confirmed, CPA) intends to conduct an additional 30 -day monitor period on water -only injection and will continue diagnostics as needed. Please let me know if you have any questions or disagree with this plan forward. Attached is a 90 -day TIO plot and the wellbore schematic for CD4 -12. Sincerely, $GWGVCarUslPi Cf(wdki*0 / 12 Yautk Well Integrity Supervisor, WINS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg 2 DATE: Tuesday,June 16,2015 P.I.Supervisor `e 6l(Ill S SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-12 FROM: Johnnie Hill COLVILLE RIV UNIT CD4-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,fag_ NON-CONFIDENTIAL Comm Well Name COLVILLE RIV UNIT CD4-12 API Well Number 50-103-20414-01-00 Inspector Name: Johnnie Hill Permit Number: 210-091-0 Inspection Date: 6/13/2015 Insp Num: mitJWH150613154154 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4-12 Type Inj G TVD 7043 - Tubing 3814 ' 3862 - 3865- 3864 PTD I 2100910 , Type Test SPTITest psi 1761 IA 1999 2808 - 2783 - 2783 - Interval I4'RTST P / OA 544 . 550 551 552 - Notes: 1 bbls diesel used NNEG Tuesday,June 16,2015 Page 1 of 1 CPu ZIOQ9Iv Regg,James B (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, June 15, 2015 8:28 PM To: Regg, James B (DOA) Subject: RE: CD4-PAD MIT-IA Attachments: CD4-319.pdf; CD4-12 90 Day 110 plot.JPG Jim- Attached is an updated copy of the wellbore schematic for CD4-319 (PTD 2051480) and the 90 day TIO plot for CD4-12 (PTD 2101.10). As for the elevated pre-test IA pressure on CD4-12; the well was brought on MI injection on the 2nd of March 2015. The well initially was taking gas at a very minimal and sporadic rate. The well eventually began taking gas at slow but increasing rate which corresponds with the time in which IA pressure also began to increase. The IA increase to just below the "do not exceed" of 2400 psi for a gas injector and a bleed was performed to 1600 psi. The IA pressure from that point appears to have been influenced by changes in the injection rates and temperature as you can see similar increasing and decreasing trends over the 90 day TIO plot. The IA was left at the elevated pressure due to the fact that it was capable of maintaining a substantial differential pressure between the tubing (4000 psi) while not needing additional bleeds to remain under the "do not exceed" of 2400 psi. After the passing state witnessed MIT-IA was performed, the IA was bled below the initial starting pressure and other than what is thought to be rate/thermally influenced changes in the IA it does not show indications of increasing IA pressure at this point in time. If you have any questions or concerns please feel free to contact us. Cheers Dusty Freeborn /Jan Byrne SCANNED JUL 0 22015 Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 WELLS TEAM Conoco philhps From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, June 15, 2015 10:49 AM To: NSK Problem Well Supv Cc: Brooks, Phoebe L (DOA); Wallace, Chris D (DOA) Subject: [EXTERNAL]RE: CD4-PAD MIT-IA CD4-12 (PTD 2100910): pre-test IA pressure was 1999psi. Please explain the high pressure and provide previous 90day TIO plot CD4-319 (PTD 2051480): packer TVD should be 6938 ft based on well file Jim Regg 1 Supervisor, Inspections AOGCC, 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: NSK Problem Well Supv [mailto:n1617©conocophillips.com] Sent: Sunday, June 14, 2015 1:21 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Wallace, Chris D (DOA); Brooks, Phoebe L (DOA) Subject: CD4-PAD MIT-IA Attached is a copy of the SW MIT-lAs that were performed on the 12th of June. Dusty Freeborn /Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 WELLS TEAM c«,« ,ii:iw. 2 w I I 1 U 5. cc UJ U1 UJ - y 0 C9 Ci Ct 2r.nW W 4 (J V7 N ,f, ' w f-- ,f, ' ' a CC 't 1--- .d V 1 V_ o 0 w r-- a VA w N G) V 0 = a ,3 0 a) N w En- en Ci, Ir, w 0-, ,n K 6, M d N CC1- 14 ,r) ,r, 144 O O CJ N N M I- r L' -Y G CN N 1 r J ? 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. cQ LQ - -1 J Well History File Identifier Organizing (done) ❑ Two-sided II 11111 III II III ❑ Rescan Needed II 111111111 liii RES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Dis ttes, No. ❑ Maps: eyscale Items: they, No/Type: Gp NO• I ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: Q� ❑ Other::• BY: _ Maria y Date: !Ica 0 J I LC /s/ 64 P Project Proofing I 111E1111111 11111 BY: ACM Date: `i o.$' 1 L is, Scanning Preparation C...C.-' x 30 = { 50 + 10 = TOTAL PAGES / &O (Count does not include cover sheet) BY: Maria Date: ( I a iliq.• /s/ Production Scanning I I OH Stage 1 Page Count from Scanned File: ` (p 1 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: VYES NO BY: AMP Date: ifasi !Lt. /s/ 04 r 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. 11111111111111111 ReScanned 111111111ND III BY: Maria Date: /s/ Comments about this file: Quality Checked II IlIllIllIlIll 10/00/0(111 \A/exll u,,s,...,MI,.(`,,.,e.D.,,.e A,.,. 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E a O a� n as o E E a 2 4 U < U U o9 1 • 2.r1ti HALLIBURTON Sperry Drilling WELL LOG TRANSMITTAL To: State of Alaska July 11, 2012 Alaska Oil and Gas Conservation Commission Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-12 0 AK-MW-0007264438 CD4-12 50-103-20414-01 2"x 5" MD GAMMA-RESISTIVITY Logs: 1 Color Log 2"x 5"TVD GAMMA-RESISTIVITY Logs: 1 Color Log 1"x 5" BAT Cement Log: 1 Color Log SCANNEV PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Buster Bryant 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3539 Fax: 907-273-3535 Buster.Bryant@halliburton.com I Date: 3N'' a.: Signed: 11/ - s r " MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday,July 05,2011 To: Jim Regg P.I.Supervisor 16r‘i 7/14111 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-12 FROM: Matt Herrera COLVILLE RIV UNIT CD4-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv'J NON-CONFIDENTIAL Comm Well Name: COLVILLE RIV UNIT CD4-12 API Well Number: 50-103-20414-01-00 Inspector Name: Matt Herrera Insp Num: mitMFH110701082508 Permit Number: 210-091-0 Inspection Date: 6/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 CD4-12. Type Inj. W TVD 7043 I IA T 340 1 2110 1 2080 1 2070 — P T D1 2100910• TypeTest sPT I Test psi 1761 •1 OA ( 570 I 570 600 600 1 Interval 'WRIST _ P/F P - Tubing I 1376 I 1378 i 1378 1378 Notes: IA was tested to 2100psi.2.9 BBL's ' Tuesday,July 05,2011 Page 1 of WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 2, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: CD4-12 Run Date: 5/6/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline& Perforating, 6900 Arctic Blvd.,Anchorage, AK 99518 CD4-12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20414-01 f PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 Klinton Wood @halliburton.com Date: 13 2‘N L Al . _ oq. � Signed: A ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 01,2011 Commissioner Dan Seamount /� Alaska Oil & Gas Commission c) "" 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). 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 spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped March 13-15 and March 27-28, 2011. The attached spreadsheet presents the well name,top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, //7/1/i? MJ Loveland ConocoPhillips Well Integrity Projects Supervisor r Conoco Phillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Alpine Field Date 04/01/2011 CD4 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 CD4-07 50103205530000 2071180 6" n/a 16" n/a 3.8 3/13/2011 >CD4-12 50103204140100 2100910 13" n/a 36" n/a 11.9 3/13/2011 CD4-23 50103206210000 2100670 28" n/a 28" n/a 8.5 3/13/2011 C04-24 50103206020000 2090970 16" n/a 16" n/a 4.3 3/13/2011 CD4-26 50103206000000 2090490 26" n/a 26" n/a 8.5 3/13/2011 CD4-209 50103205320000 2060650 SF n/a 16" n/a 4.2 3/13/2011 CD4-213 50103205400000 2061730 13" n/a 18" n/a 4.3 3/13/2011 CD4-322 50103205510000 2071010 SF n/a 16" n/a 4.7 3/13/2011 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday,January 26,2011 TO: Jim Regg P.I.Supervisor �LLLL L 1(7 t SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-12 FROM: Bob Noble COLVILLE RIV UNIT CD4-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry��'� NON-CONFIDENTIAL Comm Well Name: COLVILLE RIV UNIT CD4-12 API Well Number: 50-103-20414-01-00 Inspector Name: Bob Noble Insp Num: mitRCN110123114305 Permit Number: 210-091-0 Inspection Date: 1/22/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. p T.DI CD4-12 'IType In j. W ! TVD 7043 . IA 1820 - 2725 - 2700 2700 - Well YP J �- --2100910 T eTest SPT Test psi 2725 - OA 500 575 575 575 I 1 Interval P/F g. woo woo INITAL P Tubing� 1000 1000 i Notes: A;n,rt d 4e4- i 76( 195 Wednesday,January 26,2011 Page 1 of 1 - . STATE OF ALASKA 0 ALASI ilL AND GAS CONSERVATION COMMIS, N REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Fbrforations r Stimulate r Other rv7 Convert to Alter Casing r Pull Tubing r Perforate New Fool Waiver Injector I! Time Extension �` Change Approved Program r Operat.Shutdown r Perforate r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development W Exploratory r 4 210-091 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 .- 50-103-20414-01-00 7 Property Designation(Lease Number): 8.Well Name and Number: ADL 388902,384209,384211 3g007?7? Sm .. CD4-12 9.Field/Pool(s): Colville River Field/Alpine Oil Pool '+ 10.Present Well Condition Summary: Total Depth measured 16004 feet Plugs(measured) None true vertical 7448 feet Junk(measured) None Effective Depth measured 11412 feet Packer(measured) 9834 true vertical 7377 feet (true vertucal) 7044 Casing Length Size MD ND Burst Collapse CONDUCTOR 77 16 112 112 SURFACE 2876 9.625" 2910 2395 INTERMEDIATE 11463 7" 11497 . 7382 , RECEIV Perforation depth: Measured depth: open hole completion JAN 2 5 2011 True Vertical Depth: Alaska ill&Gas Cons.COrtaiSSIOO Tubing(size,grade,MD,and ND) 4.5, L-80,9979 MD,7096 ND Anchorage Packers&SSSV(type,MD,and ND) PACKER-BAKER PREMIER PACKER 98 and 7044 ND NIPPLE-Camco BAL-O LANDING'NIPPLE w/DB PROFILE w/INJECTIONVALVE @ 2177 MD and 1981 ND 11.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3724 4282 0 -- 320 Subsequent to operation na na 7804 — 13.Attachments 14.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service J Stratigraphic r 15.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations_XXX GSTOR r WIND r WAG p- GINJ r SUSP r SPLUG r 16.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt 310-353 Contact Jack Walker 0 265-6268 Printed Name Jack Walker Title Principal Production Engineer Signature Phone:265-6268 Date 2 // j- RBDMS JAN 2 S all d'� �y�- /Z 5-1( Form 10-404 Revised 10/2010 / Submit Original Only ��lY WNS CD4-12 so Iv CO ocaP liiii r Well.Attnbutes Max Angle&MD TD A,lCSK Inc, al T I-.ii Wellborn API/UWI (Field Name (Well Status Inc!(°) IMD(ftKB) Act Bim(ftKB) r.csrr,+rd' 0!u•1^' Il 501032041401 ((ALPINE 1I INJ 91.73 13,296.53 16,004.0 C I ,!Annotation (End Date KB-Grd(ft) Rig Release Date Comment H2S(ppm) Data I Annotation Tag: !Annotation Reason.RESET WO: 4/3/2002 Wei Cdn6;H 5S T 1 .6391M.AM- SSSV NIPPLE Srtremea AgeL-_.;_. _ A Cation Depth(ftK8) End Date Annotation Last Mod.../End Date g: ESET INJ VALVE Imosbor 11 1/24/2011 —._ _ Casing Strings stxe — — � ,. Casing Description String 0... String ID...Top(ftK8) Set Depth(f...Set Depth(ND). String WL..Str ng...String Top Thrd HANGER,32 CONDUCTOR 24" 16 15.250 35.0 112.0 112.0 62.50 H-40 Welded Insulated =r-: Cuing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(ND)...String Wt...String...Suing Top Thrd 0,':> SURFACE 9 5/8 8.835 34.7 2,910.5 2,395.1 40.00 L-80 IBT Casin 9 Description ption String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)..String Wt...String...String Top Thn1 INTERMEDIATE 7 6.276 34.5 11,497.0 7,382.3 26.00 L-80 BTCM ;. llti Casing Description String 0.... String ID...Top(RICE) Sat Depth(1...Set Depth(ND)..String Wt_.String...String Top Thrd - '-'- OPEN HOLE 6.151 11,497.0 16,351.0 __ Tubing Strings Tubing Description String 0... 'String ID..Top(ttKB) Set Depth(f...Set Depth(ND)...String Wt_.String... String Top Thrd I TUBING j 4 1/2 �„3.958...r op 31.9 l 9,980.6...! 7,097.4 12.60 L-80 IBT-M Completion Details Top Depth (ND) Top Inc/ Nomi... CONDUCTOR Top ftK8 ( B) (°) Item Description ID 24'Insulated,— - P( ) pbon Comment (in) 35-112 (` 31.9 31.9 0.00 HANGER FMC ir x 4 1/2"TUBING HANGER 3.958 2,177.2 1,979.9 50.78 NIPPLE Camco BAL-0 LANDING NIPPLE w/DB PROFILE 3.813 9,834.1 7,043.6 67.90 PACKER BAKER PREMIER PACKER 3.875 INJ VALVE, ---. — -- 2, �' 9,894.4 7,065.3 67.91 NIPPLE HES'XN'NIPPLE NO GO 3.725 5 NIPPLE.2,m 177 ------ 3 9,979.2 7,096.9 71.29 WLEG WIRELINE ENTRY GUIDE(5.25"OD-4"ID) 4.000 Other In Hole_MAreline retrievable plugs,valves,pumps fsh,etc," Top Depth _ --- —_-- ,J, (TVD) Top Inc/ ye: Top 149 B) (ftKB) (°) Description Comment Ron Data ID Da) 2,177.2 1,979.9 50.78(NJ VALVE 3.81"DB LOCK ON 4.5"INJ VLV 1.25"BEAN(HABS-0030) 1/16/2011 1.250 w/37.25"SPACER PIPE,OAL=79" Notes:General&Safety End Date Annotation ,: 9/8/2010 NOTE:VIEW SCHEMATIC Alaska Schematic9 0 SURFACE,_ .! 35-2,910 J. lir GAS LIFT, 7,458 I GASiIFT r. ar PACKER,9,634—-- iliii lir NIPPLE.9.894 - .l,T� II I. WLEG,9,979 Mandrel Details — —_ i,:,' L. 4 Top Depth Top Port (TVD) Inel OD Valve Latch Size TRO Run j Stn Top(ftK8). (RKB) (1 Make Model (in) SAW Type Type Dn) (Psi) Run Date Com... i 1 7,458.2 5,577.8 45.49 CAMCO KBG-2 1 GAS LIFT DMY BK-5 0.000 0.0 12/8/2010 2 9,721.1 6,999.7 66.46 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 12/102010 ll ° NTERMEDIATE, 34-11,497 TD(CD4-12), 16,004 OPEN HOLE, - 11,497-16,361 CD4-12 Well Work Summary • D & SUMMARY 12/8/10 PULLED 3.812 WRDP @ 2177' Ri._ ,,S/N:HSS-125). GAUGED TBG TO 3.79'' . 9894' RKB; SET 3.81 SV @ SAME. PULLED HES SPG @ 9721' RKB. PULLED OV @ 7458' RKB, SET DV @ SAME. IN PROGRESS. 12/9/10 PUMPED 261 BBL INHIBITED SW&68 BBL DSL DOWN TBG & UP IA. ALLOWED TO U-TUBE TBG x IA. ATTEMPTED SET DV @ 9721' RKB. IN PROGRESS. 12/10/10 SET DV @ 9721' RKB. PERFORMED 3500 PSI MIT ON IA, PASSED. PULLED SV @ 9894' RKB. SET A-1 INJ VLV @ 2177' RKB. CLOSURE TESTED, PASSED. COMPLETE. 1/16/11 PULLED INJ AND SET 3.81" DB LOCK, 37.25"SPACER PIPE, 4.5"A-1 INJ VLV(NABS-0030) @ 2177' RKB. NO TBG PSI FOR CLOSURE TEST. COMPLETE. Halliburton Sperry Drilling 6900 Arctic Blvd Anchorage, AK 99518 January 13, 2011 AOGCC Christine Mahnken 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Dear Sir or Madam: Subject: CD4-12/CD4-12PB1 Definitive Survey Reports Enclosed are two hard copies(NAD83 and NAD27)of the definitive well path. Also enclosed is a disc containing an electronic export of the survey data. Please acknowledge receipt by sending an email to Avinash.Ramjit @Halliburton.com or by signing and returning a copy of this letter to the following address: Halliburton Sperry Drilling ATTN: Avinash Ramjit 6900 Arctic Blvd Anchorage, AK 9 8 Received by: 1J Date:ML1494.6 it Please contact me at 907.748.3919 with questions or concerns. Regards, Avinash Ramjit Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, September 24, 2010 10:46 AM To: 'Reed, Scott' Cc: Naadland, Gaute; Neville, David J; Schneider, Tim S.; Walker, Jack A; Maunder, Thomas E (DOA); Regg, James B (DOA) Subject: RE: CD4-12 (PTD 210-091) Scott, As long as you are actively pursuing installation of the WRDP we can conditionally waive the 14 day limit for no SSSV. A one week extension will be granted to give you time to troubleshoot the WRDP install. At that point(or when the WRDP install is deemed impossible) touch bases with myself or Tom Maunder for further time needed to set up the K-valve if it is ultimately needed. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Reed, Scott [mailto:Scott.Reed @conocophillips.com] Sent: Friday, September 24, 2010 10:26 AM To: Schwartz, Guy L (DOA) Cc: Naadland, Gaute; Neville, David 3; Reed, Scott; Schneider,Tim S.; Walker,Jack A Subject: CD4-12 (PTD 210-091) Guy, As a follow up to our phone conversation, the following is the summary of events for CD4-12. The problem started when SL had trouble pulling the isolation sleeve from the BAL-O nipple during the post rig well work due to a restriction in the tubing just above the nipple. After recovering the isolation sleeve all attempts to set a WRDP failed. The well was then allowed to flow back and clean up for a period of nine days. The path forward is for SL to swage/broach the restriction in the tubing and attempt to set another WRDP. This work is scheduled to begin today, September 24tH If SL is unsuccessful in setting a WRDP before the 14 day clock expires, we may have to set a K-valve in the well and an extension to the 14 day clock will be needed to acquire the data to properly tune the K-Valve. I am out of the office today. If you need to reach me by phone please call my cell at 907-575-3978 Thanks Scott Scott Reed Production Engineer WNS Subsurface Office: (907)265-6548 Cell: (907) 575-3978 9/24/2010 p , J Zi0 -011 liECHARICAL INTEGRITY REPORT SPUD D::= . OPER & FIELD CAT — A 00 RIG R!LSrSI : • 1/7// b 1:7E11 NUMBER C b'-{- 12– WELL DATA TD: /647I.2al..79Y8 TVD.; ?ETD : /616'1 ?ID TVD 'easing : ct�p/, ,mot Shoe: g./fo MD TVD ; DV : -MID •TVD 7"21:;.k Shoe : /1(f17110 TVG ; TOP . HD TVD Tubing : t, c Packer 7834 'm TVD ; Set at T, Y1 M // ���� ;ale Sits L9/d .k and - X to ( I' Of( /0417 — (60oY • . '•''EC?J N I CAL INTEGRITY - PART 11 2..v • 6 k Annulus Press Test: =.P 35.04) 15 min ; minim. Comments : ` • MECHANICAL INTEGRITY - PART #2 Cement Volumes : Amt. 11.. r Csg 141 S 13t$11STEK Cmt vol to cover perfs Theoretical TOG -73oo ' v/ 3674 e cce Cement Bond Log or No) jI In AOGCC File • J CBL Evaluation, zone above perfs C&34,_ /e` u4E- V hil-c-- Production Log: Type IV1,4-- , Evaluation• ' CONCLUSIONS : / ?irt #1 : ; essei PIT- IA CvNv. ?Art •� 4..ec, rt- - 8 SITATIE O [F ALa 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 Scott Reed WNS Engineer ConocoPhillips Alaska, Inc. ✓ ®� I P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD4-12 Sundry Number: 310-353 Dear Mr. Reed: 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, I Daniel T. Seamount, Jr. Chair DATED this Z'S day of October, 2010. Encl. . STATE OF ALASKA � � 10 I { ALAS'. IL AND GAS CONSERVATION COMMISS , ' APPLICATION FOR SUNDRY APPROVALS Pr��pr,�t 20 AAC 25.280 :y..*,e. a 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Rug Perforations f Perforate r Pull Tubing r Tine Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r After casing Other: Convert to Injector F.' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r - Exploratory r 210-091 . 3.Address: Stratigraphic r Service 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20414-01 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No l✓ CD4-12 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 388902,384209,384211• Colville River Field/Alpine 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): 16004 ' 7448 • 11412' 7377' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 112' 112' SURFACE 2876 9.625 2910' 2395' INTERMEDIATE 11463 7 11497' 7382' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): open hole completion 4.5 L-80 9979 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER PREMIER PACKER MD=9834 TVD=7044 NIPPLE-Camco BAL-O LANDING NIPPLE w/DB PROFILE MD=2177 TVD=1974 12.Attachments: Description Sunmary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development E Service r • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/5/2010 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG • 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: Scott Reed @ 265-6548 Printed Name Scott Reed Title: WNS Engineer t/ Signature d...6 0, O •90-4-1 Phone:265-6548 Date 10/0).Vi Commission Use Only , Sundry Number: 3)0...53 Conditions of approval: Notify Commission so that a representative may witness J V ✓ Plug Integrity r BOP Test r Mechanical Integrity Test Location Clearance r I Other: OCT 2 2 2010 AtasttatTd&aasCcms.Corrissmn Subsequent Form Required: /6 •Li 0 if Anchorage APPROVED MM S /O /2. /v Approved by: ; OCT q COMMISSIONER THE COMMISSION Date: �J�S l rr8 l0 ZS1G /G'�Z io Form 10-403 Revise iZOTW Submit in Duplicate / RIGINAL /II/So/0 • • - • t Description Summary of Proposal CD4-12 (PTD 210-091) 10/21/10 1. Pull WRDP-2 from BAL-O nipple. 2. Circulate inhibited brine down IA. 3. Dummy off both gas lift mandrels. 4. Install Al injection valve and test. • 5. Place well on water injection. 6. State-witnessed MIT once well has stabilized. Scott Reed ConocoPhillips Alaska //11 p�P —prv��tec® /14 ,i ect,-oh U/Q 1( '4 la pc At frecf Ss I 0A27 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION raj. WELL COMPLETION OR RECOMPLETION REPORT AND LOG Pr%a• la.Well Status: Oil'® Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG I WDSPL ❑ No.of Completions: Service Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: . ConocoPhillips Alaska,Inc. orAband.: September 7,2010 ' 210-091 /, 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 August 16,2010 • 50-103-20414-01 , 4a.Location of Well(Governmental Section): 7.Date TD Reached: X14.Well Name and Number: - Surface: 2937 FNL,283'FEL,Sec.24,T11N,R4E, UM September 4,2010 • CD4-12 Top of Productive Horizon: 8.KB(ft above MSL): 55.7'RKB 15.Field/Pool(s): 1336'FSL,2540'FWL,Sec.25,T11N, R4E,UM GL(ft above MSL): 19.6'AMSL Colville River Field ' Total Depth: 9.Plug Back Qttb(MD+T A; 2790'FNL,781'FEL,Sec.36,T11N, R4E, UM D ` $ 1 pa V p f 2"° Alpine Oil Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: • Surface: x-377961 - y- 5957475• Zone-4 . (1 600,1 D/7448'TVD. ADL 388902,384209,384211 TPI: x-375403 y- 5951230 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-377294 y- 5947074 Zone-4 nipple @ 2177'MD/1980'TVD Tobin-932076,932351 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) 795'MD/793'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 r GR/Res not applicable 277..E mpg,((.Z'lapTl'f 23. CASING,LINER AND CEMENTING RECORD ,At) fc Z'.I- 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 37' 114' 37' 114' 20" 11 cu yds Portland Type C 9.625" 40# L-80 37' 2910' 37' 2393' 12.25" 340 sx ASLite,240 sx Class G 7" 26# L-80 35' 11497' 35' 7382' 8.75" 700 sx Class G,210 sx Class G O.ff. --- — 1I4-1q 7 IL oOK 4.425" D 4 /a''Lc 4to ,iy't7— /6aoY 24.Open to production or injection? Yes Q 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) 4.5" 9981' 9834'MD/7044'TVD open hole completion _ 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. ' Lt-.IA i 0 " DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED i ....M9 1 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) September 15,2010 pre-produced injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 9/18/2010 _ 8 hours Test Period—> 2122 1219 100 128 Bean 749 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 453 psi not available 24-Hour Rate-> 6058 4538 _ 297 not available 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 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 AAC 25.071. NONE SEP 2 4 2010 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE ilVOKfrial only/37-2,�5.ro RBDMS SEP g i 2010 _ 7,4-- 1•Z-t-leD/�jl t, 28. GEOLOGIC MARKERS(List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q 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 795' 793' needed,and submit detailed test information per 20 AAC 25.071. Kuparuk C 10009' 7106' Alpine C 11426' 7379' CD4-12PB1 TD 15829' 7409' N/A Formation at total depth: Alpine C 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,directional surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ryan Roberts 265-6318 k Printed Name G Alvord Title: Alaska Drilling Manager Signature Phone 265-6120 Date (7/2 3//U Sharon Allsup-Drake 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 1a: 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 WNS CD4-12 C lips o WeILAttrjbgtes_ Max Angle&MD ITD — AtC.,.. '571^. Wellborn AMA MI Field Name Well Status Inc!(°) ND(MB) Act Btm(ftKB) 501032041401 !ALPINE I INJ 91 731 13,296.53 i 16,004.0 C ent H2S(ppm) Date Annotation [End Date KB-Grd(ft) Rig Release Date Y641-oAtl+CllFtiQa7.0,H)'/1.,CR4dg@/8(291037,511 PM. IILSSSV NIPPLE Last WO: _ 4/3/2002 �..,_SIMBRAIM:Aatuel _W-_ __ Annotation (Depth(ftKB) End Date Annotation Last Mod End Date HLast Tag- Rev Reason:NEW WELL �_Imosbor I 9/8/2010 !Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(ND)...String Wt...String...String Top Thrd HANGER,32-- I CONDUCTOR 24" 16 15.250 35 0 112.0 112.0 62.50 H-40 Welded Insulated r Cuing Description String 0... String ID...Top(ftKB) Set Depth(f..Set Depth(ND)...String Wt...String...String Top Thrd • SURFACE 9 5/8 8.835 , 34.7 2,910.5 2,394.9 40.00 L-80 IBT casing Description String 0... String ID...—Top MKS) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd INTERMEDIATE 7 6.276 34.5 11,497.0 7,382.3 26.00 L-80 BTCM Casing Descriptbn String 0... String ID---Top(MB) Set Depth(f...Set Depth(ND)..._String Wt...`String...String Top Thrd t _� T` OPEN HOLE 6.151 __-11,497.0 16,351.0 Tubing Strings_ Tubing Description 'String 0... String ID Top KB Set Depth i 'Set Depth D 'String Wt. Str n • 9 pif 9 9 P(ft ) P (��� P (TV D) 9 .1St ring Top Thrd TUBING I 4 12 3.958 ! 31 9 ! 9,980.6 ! 7,096 5 12.60 L L-80 IBT-M Completion Details _ Top Depth CONDUCTOR (TVD) Top Inc/ 24'Insulated,--.— >i, Top(ftKB) (ftKB) (1 Item Description Comment ID(in) 35-112 31.9 31.9 59.83 HANGER FMC 11"x 4 1/2"TUBING HANER 3.958 4ItNx''■ 2,177.2 1,995.1 56.89 SAFETY VLV Camco BAL-O LANDING NIPPLE w/DB PROFILE 3.813 9,834.1 7,043.6 67.90 PACKER BAKER PREMIER PACKER 3.875 SAFETY VLV 9,894.4 7,065.3 67.91 NIPPLE HES'XN'NIPPLE NO GO 3.725 2.177 __. a, 9,979.2 7,096.0 69.91 WLEG WIRELINE ENTRY GUIDE(525"OD-4"ID) 4.000 Notes.General&Safety End Date Annotation MI 9/8/2010 (NOTE:VIEW SCHEMATIC Alaska Schematic9.0 SURFACE _._ r 35-22310 t M GAS LIFT, TM 456 rli. ii a GAS LIFT, 9,721 I If II PACKER,9,834 ir NIPPLE,9,894— WLEG,6,979 '-- I Mandrel Details m Top Depth Top Port (ND) Intl OD Valve Latch Size TRO Run 1 Stn Top(f1KB) (ftKB) (') Make Model (in) Sery Type Type (in) (psi) Run Date Corn... y 1 7,458.2 5,577.8 45 49 CAMCO KBG-2 1 GAS LIFT DMY BKS 0.000 0.0 9/6/2010 2 9,721.1 6,999.7 66.46 CAMCO KBG-2 1 GAS LIFT ISOV DCK-2 0.000 0.0 9/6/2010 f I ( NTERMEOIATE. 1 34-11,497`- TD(CD412), 16,11H OPEN HOLE, 11,497-16,351 ConocoPhillips Time Log & Summary Wellwew Web Reporting Report Well Name: CD4-12 Rig Name: DOYON 19 Job Type: DRILLING SIDETRACK Rig Accept: 8/10/2010 4:00:00 AM Rig Release: 9/7/2010 11:59:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/09/2010 24 hr Summary Moved rig f/CD4-23 to CD4-12-Spot sub base 18:00 00:00 6.00 0 0 MIRU MOVE MOB P Blew down service lines-Separate motor&pit complexes&pipe shed- Skid floor to moving position-Move sub base&spot over well 08/10/2010 Continue to Move Rig U CD4-12-Clean Up 1 Bbl LSND Spill-Test BPV in Direction of Flow U 1500 Psi and Tree Adapter U 5,000 Psi-Pull BPV-R/U and Displace Wellbore U 9.8 PPG LSND-OWFF(Static)-Set& Test BPV-N/D Tree-N/U Spacer Spool and BOPE-Begin Testing BOPE w/4'/z'Test Joint to 250/2500 (Annular)and 250/3500(Rams and Choke Manifold)-AOGCC Inspector Bob Noble Waived Witnessing the Test Barriers:Cement Plug, Kill Weight Mud,Casing, BPV and BOPE 00:00 04:00 4.00 0 0 MIRU MOVE MOB P Continue to Move Rig f/CD4-23 to CD4-12-Spot Sub Base,Skid Floor, Lower Cellar Walls and Feet,Spot Pits/Motor Modules-Connect Service Lines and High Line Power- Accept Rig @ 0400 04:00 05:00 1.00 0 0 MIRU MOVE RURD P Continue to R/U Service Lines 05:00 08:30 3.50 0 0 SLOT WHDBO RURD P R/U to Test BPV in Dirction of Flow- Spill of 1 Bbl Into Secondary Containment, PIR Submitted, Non-Agency Reportable 08:30 09:15 0.75 0 0 SLOT WHDBO PRTS P Test BPV U 1500 Psi f/10 Minutes- Test Tree Adaptor U 5,000 Psi f/10 Minutes 09:15 10:00 0.75 0 0 SLOT WHDBO SEQP P Pull BPV w/FMC Lubricator 10:00 11:00 1.00 0 0 SLOT WHDBO RURD P R/U Lines U Dispalce Diesel to Tiger Tank 11:00 11:15 0.25 0 0 SLOT CSGRC'SFTY P PJSM on Displacing Well U 9.8 PPG LSND 11:15 12:45 1.50 0 0 SLOT CSGRC'CIRC P Pressure Test Lines U 5,000 Psi- Displace Well f/6.8 PPG Diesel U 9.8 PPG LSND Taking Returns to the Tiger Tank 12:45 13:15 0.50 0 0 SLOT CSGRC'OWFF P Monitor Well(Static)-Blow Down Lines U Tiger Tank 13:15 15:00 1.75 0 0 SLOT WHDBO SEQP P Remove Tree Cap,Set BPV,Test Annulus U 1,000 Psi f/10 Minutes- Blow Down/Rig Down Lines 15:00 15:15 0.25 0 0 SLOT WHDBO SFTY P PJSM on N/D Tree 15:15 16:00 0.75 0 0 SLOT WHDBO NUND P N/D Gen V Tree 16:00 16:30 0.50 0 0 SLOT WHDBO MPSP P Set Blanking Plug in Adapter Page 1 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 19:15 2.75 0 0 SLOT WHDBO NUND P N/U Spacer Spool, BOPE, Riser, Flow Line, Drain Lines and Hole Fill Line 19:15 00:00 4.75 0 0 SLOT WHDBO BOPE P Test BOPE w/4 W Test Joint as Follows:Test Choke Manifold Valves 1-16,4"Demco, Upper and Lower Rams U 250/3500 Psi-Test Annular Preventer U 250/3500 Psi-Perform Accumulator Test;29 Seconds f/200 Psi Gain,2:48 for Full Charge 08/11/2010 Complete BOP Test. Pull&lay down 69 jnts of 4 1/2"IBT Kill String. Install test plug.test with 3 1/2"&4" test joints 250/3500 PSI.MU Baker bridge plug, RIH to locate&set same at 3045' DPM. POOH, lay down Running tools. MU Baker Multi String cutter. RIH to tag plug on depth, locate casing collar @ 3011'. Position cutters to make cut at 3017'DPM.Observed good pressure drop of 200 PSI.Close annular.Attempt to circulate freeze protect diesel form OA.Observed pressure up to 1300 PSI,with no returns.Observed pumping away 6 BBLS of 9.8 ppg LSND. Bleed pressures, monitor well-static. POOH, breakout inspect& lay down multi-string cutter assembly.Observed 1/8"of cutter milled off indicating good casing cut. Recovered all 3 knives. Install 4 1/2"x 7"VBR's and test same with 5"&7"test joints. 00:00 00:15 0.25 0 0 SLOT WHDBO BOPE P Complete BOPE Test;Tested Blind Rams U 250/3500 and Functioned Remote Panel 00:15 00:45 0.50 0 0 SLOT WHDBO NUND P Pull blanking plug. Lay down test joint and blow down lines. Pull BPV. 00:45 06:30 5.75 0 0 SLOT CSGRC'PULL P Install 4 1/2"joint in hanger. BOLDS. Held PJSM. Pull tbg hanger to floor. UP WT= 107K. Breakout&lay down hanger.Continue POOH with 4 1/2"tbg from 3038'-1100'.Observed frozen mud in string. Install head pin, break circulation and circulate 9.8 ppg LSND mud around.Continue POOH laying down a total of 69 joints. Observed proper hole fill. 06:30 07:15 0.75 0 0 SLOT CSGRC'PULD P Clean&clear rig floor area.Change out elevators. 07:15 10:45 3.50 0 0 SLOT CSGRC'PRTS P Install test plug,and 4"test joint. Fill lines.Test with 4"&3.5"test joints. 250/3500 Psi on top&bottom rams.250/2500 PSI on Anuular. Record on chart. Pull test joints,and test plug. Blow down lines. 10:45 13:00 2.25 0 3,045 SLOT CSGRC'PLUG P Make up Baker 7"bridge plug on DP. Trip in hole to locate same at 3045' DPM. UP WT=115K,SO WT= j 110K. 13:00 13:30 0.50 3,045 3,045 SLOT CSGRC'PLUG P Drop setting ball.Allow to land in setting tool. Pressure to 720 PSI to set bridge plug. Bleed pressure. Release form plug.Stand back 1 stand of DP. 13:30 14:30 1.00 3,045 0 SLOT CSGRC'PLUG P POOH,breakout, inspect and lay down running tools. 14:30 14:45 0.25 0 0 SLOT CSGRC'SFTY P Held PJSM with BOT rep,and crew. Discuss safety&hazard recogniiton issues. Discuss procedure to make up and run multi-string cutter assembly. Page 2 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 16:45 2.00 0 2,963 SLOT CSGRC'CPBO P Make up Baker Multi-string cutter on DP,and RIH to 2963'DPM. UP WT =118K,SO WT= 108K. 16:45 17:45 1.00 2,963 3,017 SLOT CSGRC'CPBO P Establish parameters with pump rates of 500 PSI @ 4 BPM and 5500 ft lbs of TQ.Tag bridge plug on depth at 3045 DPM. Locate casing collar at 3011'DPM. Locate cutters at 3017'DPM. Rotate drill string at 80 RPM's-5500 ft lbs TQ staging pumps up to 4 BPM-600 PSI.after 5 minutes, observed 200 PSI pressure drop with minimal increase in pressure on OA.OA starting pressure=370 PSI. 17:45 18:00 0.25 3,017 3,017 SLOT CSGRC'PRTS P Close Annular.Shut in valves on Tiger tank. Pressure test lines and valves to tank. 18:00 19:00 1.00 3,017 3,017 SLOT CSGRC'CIRC P Attempt to break circulation down DP string through the OA with 9.8 PPG LSND mud. .Observed pressure to 1300 PSI with no OA flow.Observed 6 BBLS pumped away into formation. Monitor well for bleed off. Pressure held at 480 PSI. Bleed pressures,and monitor well- static. Blow down lines. 19:00 21:00 2.00 3,017 0 SLOT CSGRC'CPBO P Decision to POOH. POOH breakout inspect and lay down Multi-string cutter assembly.Observed 1/8"of cutter milled off,with cutters indicating good casing cut. 21:00 00:00 3.00 0 0 SLOT WHDBO BOPE P Change out upper rams to 4 1/2"x 7" VBR's. Install test plug and test same with 5"and 7"test jonits.Test floor valves.test 250/3500 PSI. 08/12/2010 Completed BOPE Ram Test w/7"Test Joint-R/U to Pull 7"Pack-Off Assembly-Checked OA Pressures (80 Psi)Opened Valve and Observed Gas and Diesel Flowing to Tiger Tank-RIH w/4"DP U 2093'MD-Spot 110°Mud in 7"Casing-Close Annular and Attempt to Circulate Through Casing Cut(Unsuccessful)- Continue to Heat and Circulate Mud in Casing-R/U and Pump 40 Bbls Hot Mud Down OA-Monitored Pressures-Bled Pressure From OA-Closed Annular Preventer and Attempt to Circulate Through Casing Cut (Unsuccessful)-Bled Pressures and POOH w/DP-P/U Casing Cutter and RIH U Position Cutters @ 2850' MD-Cut Casing-Close Annular Preventer and Establish Circulation Taking Diesel/Gas/Contaminated Mud Returns to the Tiger Tank-Bleed Pressures,Open Annular and OWFF(Slight Flow Decreasing to Ooze)- POOH w/Casing Cutting Tools(Proper Hole Fill)-OWFF(Static)-Open OA to Tiger Tank and Pull 7" Casing Pack-Off(Pack-Off Sheared at Lower Joint)-OWFF(Static)-M/U Casing Spear and Pull Casing Hanger f/the Well Head-CBU X2-Pull Casing Hanger to the Rig Floor and Retrieve Lower half of Pack-Off- UD Casing Spear and 7"Hanger Barriers Remaining: Kill Weight Mud and BOPE 00:00 01:30 1.50 0 0 SLOT WHDBO BOPE P Continue test with 7"test joint.Test to 250/3500 PSI. Pull test plug. lay down test joint. 01:30 01:45 0.25 0 0 SLOT CSGRC'SFTY P Held PJSM with crew&FMC rep. Discuss safety&hazard recognition issues. Discuss procedure to rig up and pull 7"pack-off. Page 3 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 02:30 0.75 0 0 SLOT CSGRC'RTWH P Rig up to pull 7"packoff with 5"DP joint. Bleed annulus to tiger tank. Observed flow. Diesel&gas returns. Lay down DP joint with packoff pulling tool. 02:30 04:15 1.75 0 2,093 SLOT CSGRC'TRIP P Trip in hole with 4"DP to 2093'DPM. UPWT=103K,SO WT=101K. 04:15 05:15 1.00 2,093 2,093 SLOT CSGRC'CIRC P Circulate hot 9.8 PPG LSND mud into well bore @ 4 BPM-90 PSI. 05:15 08:15 3.00 2,093 2,093 SLOT CSGRC'CIRC P Close Annular. Pump down DP attempt to get circulation with no success.Continue heating mud in pits. 08:15 09:00 0.75 2,093 2,093 SLOT CSGRC'CIRC P Continue pump heated 90 Deg LSND mud into well bore. 73 BBLS total,@ 4 BPM-70 PSI. 09:00 09:30 0.50 2,093 2,093 SLOT CSGRC'CIRC P Continue circulating at 4 BPM-70 PSI,checking OA pressures. 09:30 11:00 1.50 2,093 2,093 SLOT CSGRC'CIRC P Rig up on OA.Test lines to 1000 PSI. Pressure up on OA to 940 PSI. Continue to pump 40 BBLS of 9.8 PPG LSND at.7 BPM-FCP-740 PSI.Observed slight flow on surface. 11:00 12:30 1.50 2,093 2,093 SLOT CSGRC'OWFF P Shut down pumps. Monitor well. Pressure held on OA at 740 PSI. Bleed OA pressure to 0 PSI. 12:30 13:15 0.75 2,093 2,093 SLOT CSGRC'CIRC P Close annular again,and attempt to circulate down DP. Unsuccessful, with pressure holding to 900 PSI, indicating packed off. 13:15 13:45 0.50 2,093 2,093 SLOT CSGRC'CIRC P Circulate mud around down DP up the IA at 5 BPM-100 PSI. Blow down Top Drive&lines. 13:45 14:30 0.75 2,093 0 SLOT CSGRC'TRIP P POOH from 2093'to surface.Observed proper hole fill. 14:30 16:00 1.50 0 2,850 SLOT CSGRC'CPBO P Make up Baker multi-string cutter with new 2 1/4"knives, and RIH to locate collar at 2839'DPM. Position cutters to cut casing at 2850'as planned. 16:00 16:30 0.50 2,850 2,850 SLOT CSGRC'CPBO P Cut casing at 2850'DPM with 5 BPM -600 PSI, 80 RPM's with 5K TQ. Observed pressure drop at 5 minutes to 220 PSI.Continue rotate cutters for 10 minutes to ensure good cut. Observed OA pressure from 0 PSI to 220 PSI. 16:30 17:45 1.25 2,850 2,850 SLOT CSGRC'CIRC P Close annular.Circulate down DP @ 5 BPM-250 PSI,through OA taking returns to tiger tank.Observed diesel,and diesel cut mud returns. Complete circulation. 17:45 18:30 0.75 2,850 2,850 SLOT CSGRC'OWFF P OWFF(Slight Flow Decreasing t/ Ooze) 18:30 20:00 1.50 2,850 0 SLOT CSGRC'TRIP P POOH f/2,850'MD w/Casing Cutting Tool String&UD Same- Hole Took Proper Fill Page 4 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 21:00 1.00 0 0 SLOT CSGRC'PULD P OWFF(Static)-P/U Casing Handling Tools and Spear Assembly 21:00 22:00 1.00 0 0 SLOT WHDBOOTHR P Check Pressure Reading on OA @ the Well Head(0 Psi)-R/U and Pull 7"Pack-Off-Noted Pack-Off Sheared at Lower Section Joint 22:00 22:15 0.25 0 0 SLOT CSGRC'SFTY P PJSM w/Baker Fishing, Doyon Casing,CPAI Rep, Rig Crew and Service Hands on M/U Spear Assembly and Pulling Casing 22:15 22:45 0.50 0 0 SLOT CSGRC'PULL P Make Up Baker Spear Assembly and RIH-Engage Casing and Unseat Hanger P/U 130 22:45 23:30 0.75 0 2,850 SLOT CSGRC'CIRC P CBU X2; Down 7"and Up 7"X 9 5/8" Annulus-5 BPM w/50 Psi 23:30 00:00 0.50 2,850 2,815 SLOT CSGRC'PULL P OWFF(Static)-Pull Casing Hanger t/Floor, Retrieve Lower Section of Pack-Off and L/D Hanger 08/13/2010 Breakout&lay down 5 3/4"Spear. POOH, lay down 66 jnts of 7"caisng and 10.65'cut jnt. recovered 22 centralizers.Slip&Cut Drilling line. Rig up.Make up S 5 3/4"Spear.TIH with 5"DP to tag&engage fish at 2850'DPM. Engage fish. Pull to 300k straight pull. Fire jars 3 times to free casing stub,and POOH with same. lay down 167'of 7"casing with 3 centralizers. RU&run 14 joints of 3 1/2"tbg for cement stinger with 5"DP to tag cement plug in 7"casing on depth at 3045'DPM. No issues in open hole with 3 1/2"stinger. Circulate 9.8 PPG LSND mud staging up to 7 BPM-175 PSI. 00:00 00:30 0.50 2,815 2,815 SLOT CSGRC'PULD P L/D Casing Spear, Blow Down Top Drive and Change Elevators t/7" 00:30 04:00 3.50 2,815 0 SLOT CSGRC'PULL P Pulled 7"Casing f/the Hole; Pulled 66 Joints(#259-194),22 Straight Blade Centralizers and 10.65'of Joint #193 f/the Hole-All Hardware Accounted for Thus Far P/U 128 04:00 06:15 2.25 0 0 SLOT CSGRC'PULD P L/D Casing Running Tools,Change Elevators,Change Junk Sub f/4' XT39 to 4 1/2 IF-Monitor Well on TT SIMOPS: Place Casing in Designated Area for NORM Testing 06:15 06:30 0.25 0 0 SLOT RIGMNTSFTY P Held PJSM with crew. Discuss safety&hazard recognition issues. Discuss procedure to slip&cut drilling line. 06:30 08:30 2.00 0 0 SLOT RIGMNT SLPC P Slip&Cut 60'of Drill Line/Lube Draw Works&Top Drive 08:30 09:30 1.00 0 0 SLOT CSGRC'PULD P Change out elevators. Break out pup on Spear assembly.Change elevators.Clean&clear rig floor area. Pick up Jars. NORM inspect 4 1/2"tbg, and 7"casing pulled form well. 09:30 09:45 0.25 0 0 SLOT CSGRC'SFTY P Held PJSM with crew. Discuss safety&hazard recognition issues. Discuss procedure to make up Spear assembly and pull 7"casing. Page 5 of 31 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 09:45 11:00 1.25 0 324 SLOT CSGRC'PULD P Make up 5 3/4"Spear assembly with packoff, Bumper Jar,Oil jar,9 joints of 5"HWDP,and Intensifier.Total BHA length=323.99' 11:00 12:45 1.75 324 2,796 SLOT CSGRC'TRIP P Trip in hole with 5"drill pipe picking up 15 joints form pipe shed, continuing form derrick to 2796'DPM 12:45 13:15 0.50 2,796 2,976 SLOT CSGRC'FISH P TIH slowly,tagging up and engaging fish at 3017'DPM.Work spear into casing stump. Pull to verify catch. UP WT-125K,SO WT-118K. Work string to straight pull to 300K, Continnue working string firing jars 3 times to observed free pull with drag up to 75K over and falling off as we pulled up hole. Pull up to 2976'DPM. 13:15 14:00 0.75 2,976 2,976 SLOT CSGRC'CIRC P Circulate bottoms up x 2 with 80 SPM-340 PSI. Monitor well- static. Blow down Top Drive&Lines. 14:00 15:45 1.75 2,976 0 SLOT CSGRC'TRIP P POOH with fish from 2976'- surface. Observed proper hole fill. 15:45 16:00 0.25 0 0 SLOT CSGRC'SFTY P Held PJSM with new crew, and BOT rep. Discuss safety&hazard recognition issues. Discuss procedure to release spear assembly lay down same and 7"casing. 16:00 17:30 1.50 0 0 SLOT CSGRC'PULD P Breakout&lay down jars. Utilize spear to lay down casing stump. Continue POOH lay down 167'of 7" casing. recovered 3 more centralizers. 17:30 18:30 1.00 0 0 SLOT CSGRC'PULD P Clean&clear rig floor area. Lay down&send out fishing tools,and casing equipment. 18:30 19:30 1.00 0 0 SLOT CEMENT PULD P Rig up to run 3 1/2"cement stinger string. RU tongs.Strap tbg and muleshoe. 19:30 20:00 0.50 0 0 SLOT CEMEN'SFTY P Held PJSM with new crew,and BOT rep. Discuss safety&hazard recognition issues. Discuss procedure to run 3 1/2"stinger,and DP for cementing. Held Safety mtg discussing better Communication& Situational Awareness issues.Good feedback from crew. 20:00 20:45 0.75 0 441 SLOT CEMEN"PULD P Make up 3 1/2"mule shoe with slots, and 14 joints of 3 1/2"Tbg. 20:45 22:30 1.75 441 3,045 SLOT CEMENT TRIP P Continue trip in hole with 5"drill pipe from derrick.Continue into OH with no issues. Did not see 7"casing stump and tagged up on the plug at 3045'as expected. 22:30 00:00 1.50 3,045 3,045 SLOT CEMENT CIRC P Circulate 9.8 PPG LSND at 7 BPM- 175 PSI. Page 6 of 31 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 08/14/2010 24 hr Summary Pump&Spot 17 PPG Balanced Cement Plug f/3,045'-2,769'MD-Pull Out of Cement U 2,626'MD @ 20 FPM-Drop Drill Pipe Wiper and Pump 40 Bbl Nut Plug Sweep+Complete Circulation @ 7 BPM, Increased Pump Rate t/10 BPM and CBU-POOH and L/D 3'/i'Cement Stinger-Drift 9/8"Casing U 180'MD w/8.77" Casing Swedge and 8'/,"PDC Bit-Move 4"Drill Pipe in the Derrick-RIH w/14 Stands of 5"DP and 9 5/8" Storm Packer-Set Storm Packer @ 60'MD-Test Packer and Casing t/1500 Psi f/10 Minutes-N/D BOPE,Tubing Spool and Loosened Casing Head-Aligned Casing Head w/Pipe Rack and Install Alpine Gen II Uni-Head-Test Casing Head Seals t/1,000 Psi f/10 Minutes-N/U BOPE Stack 00:00 00:15 0.25 3,045 3,045 SLOT CEMEN'SFTY P PJSM on Setting Balanced Plug w/ SLB,CPAI, MI and Drilling Crew 00:15 00:30 0.25 3,045 3,045 SLOT CEMEN"RURD P RU Cement Lines and Valves, Blow Down Top Drive 00:30 01:00 0.50 3,045 3,045 SLOT CEMEN-CMNT P With Dowell Unit; Pump 2 Bbls Water, Pressure Test Lines U 3,000 Psi, Pump 6.1 Bbls 12 PPG Mud Push II @ 3.3 BPM w/120 Psi,20 Bbls 17 PPG Cement @ 4.4 BPM w/ 150 Psi, Followed by 2 Bbls 12 PPG Mud Push II @ 3.4 BPM w/44 Psi- Displaced Cement w/41.2 Bbls 9.8 PPG LSND @ 7 BPM w/120 Psi for 30 Bbls,Slowed Rate U 3 BPM w/ 60 Psi CIP @ 0100 01:00 01:45 0.75 3,045 2,626 SLOT CEMEN"TRIP P R/D Cement Lines and POOH @ 20 FPM U 2,626'MD-Est.TOC 2,769' MD 01:45 02:30 0.75 2,626 2,626 SLOT CEMEN"CIRC P Drop Drill Pipe Wiper and Pump 40 Bbl 10#/Bbl nut Plug Sweep @ 7 BPM w/150 Psi,Chased Sweep w/ Surface to Surface Circulation @ 7 BPM w/100 Psi,then CBU @ 10 BPM w/200 Psi-OWFF(Static) 02:30 04:00 1.50 2,626 444 SLOT CEMEN'TRIP P Blow Down the Top Drive and POOH U 444'MD-Inspect Tool Joints for Cement Rings-Hole Took Proper Fill 04:00 04:30 0.50 444 444 SLOT CEMEN-RURD P R/U Tubing Handling Equipment- Monitor Hole on TT 04:30 05:15 0.75 444 0 SLOT CEMEN'PULD P L/D Cement Stinger(14 Jts of 3'/z Tubing and Mule Shoe) 05:15 06:30 1.25 0 0 SLOT DRILL PULD P L/D Tubing Handling Equipment and P/U 8.77"OD Casing Swedge for Casing Drift 06:30 07:30 1.00 0 0 SLOT DRILL TRIP P Drift 9 5/8"Casing w/8.77"OD Casing Swage U 180'MD(No Interference)-POOH U Surface- M/U 8'/+"PDC Bit and RIH U Verify Clearance U 80'MD-POOH and L/D Bit 07:30 09:00 1.50 0 0 SLOT CSGRC'PULD P P/U Casing Spear Assembly and Break Apart-Remove Lift Sub f/ Spear-L/D Spear-Clean 7 Clear Rig Floor-Change Elevators U 4" 09:00 10:00 1.00 0 0 SLOT DRILL PULD P Move 32 Stands of 4"DP U the ODS for Pipe Management Page 7 of 31 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 10:00 11:00 1.00 0 0 SLOT WHDBO PACK P P/U 10 W Storm Packer and Break Needed Dual Thread and Equalizing Vavle-UD packer 11:00 13:30 2.50 0 1,390 SLOT WHDBO PACK P RIH w/5"DP t/1330'MD(14 Stands)-PJSM on Packer Handling -M/U and Set Storm Packer @ 60' MD w/Approximately 23,500 Lb Below packer 13:30 14:15 0.75 1,390 1,390 SLOT WHDBO PRTS P Close Annular and Test Packer f/the Top t/500 Psi-Bleed Pressure and Test Casing and Packer f/Below t/ 1500 Psi f/10 Minutes 14:15 14:30 0.25 1,390 1,390 SLOT WHDBOSFTY P PJSM on N/D BOPE,Tubing Spool and Casing Head 14:30 00:00 9.50 1,390 1,390 SLOT WHDBO NUND P N/D BOPE, Remove Tubing Spool and Gen V Casing Head, Loosen and Align Casing Head, Installed Alpine Gen II Upper Uni-Head Section-Tested Casing Head Seals t/1,000 Psi f/10 Minutes-N/U BOPE Stack, Riser, Flow and Hole Fill Lines-Used New API Rings on Each Break 08/15/2010 Continue Body test BOP stack.250/3500 PSI. Pull test plug. Nipple up Riser&lines. Retrieve Storm packer @ 60'. No flow. Breakout&lay down same.Service rig. PU&rack back 5"drill pipe.Test casing to 1500 PSI-30 minutes.Good test. MU 8 3/4"BHA with motor assembly. Upload MWD,and RIH picking up singles of 5"DP from shed.Tag cement stringers at 2937'DPM,with firm cement observed at 2970'DPM. Drill out cement to 2920'DPM.Time drill at 1'/hr from 2920'-2943'DPM for kick off.(Note: End of initial slide for DD) Circulate 9.8 ppg LSND for FIT test. 00:00 00:15 0.25 1,390 1,390 SLOT WHDBO NUND P Continue to N/U BOPE and Associated Lines-Discovered Riser 6"Too Short w/Well Configuration 00:15 01:15 1.00 1,390 1,390 SLOT WHDBO BOPE P Set Test Plug and Test the Following Connections:Casing Head Flange, Tree/BOPE Adaptor Flange,Choke Line and Inner Outer Annulus Valve Against Blind Rams t/250/3500 Psi f/5 Minutes 01:15 02:00 0.75 1,390 1,390 SLOT WHDBO PULD P Drain Stack and Pull FMC Test Plug -Install Bowl Protector SIMOPS: Continuing to Add Material to the Riser 02:00 03:00 1.00 1,390 1,390 SLOT WHDBO NUND P N/U Riser, Flow and Hole Fill Lines 03:00 04:30 1.50 1,390 0 SLOT DRILL PACK P RIH and Remove 9 5/8"Storm Packer-POOH and Stand back 14 Stands of 5"DP Beneath the Packer -UD Packer 04:30 05:00 0.50 0 0 SLOT RIGMN1SVRG P Service Rig 05:00 10:15 5.25 0 0 SLOT DRILL PULD P P/U and Stand Back 54 Stands of DP f/the Shed-Clean Cement Sheath from Pipe Page 8 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:15 12:30 2.25 0 0 SLOT DRILL PRTS P R/U and Test 9 5/8"Casing U 1500 Psi f/30 Minutes(Lost 150 Psi, No Good)-Bleed Pressure-Circulate and Remove Air in System-Test 9 5/8"Casing U 1500 Psi f/30 Minutes (Good) 12:30 12:45 0.25 0 0 SLOT DRILL SFTY P PJSM P/U 8%"BHA 12:45 13:45 1.00 0 0 SLOT DRILL PULD P M/U BHA as Follows:8 3/4"Hughes PDC HCM605Z bit with 3x13's,and 4x14's jets for a TFA of.990 sq in.7" Sperry Lobe 7/8-6.0 stg motor with 1.22 deg bend. Non Mag float sub, Non Mag integral blade stabilizer,6 3/4"DM Collar,6 3/4"EWR-P4 collar,6 3/4"DGR,6 3/4"PWD,6 3/4" HCIM,and 6 3/4"POS Pulser. Sensor distances=Bit to DIR= 39.79' Bit to RES=39.79' Bit to DDSR=69.44' Bit to GR=61.01' Bit to PWD=63.73' 13:45 14:30 0.75 0 0 SLOT DRILL DHEQ P Plug In and Load MWD Data 14:30 15:45 1.25 0 732 SLOT DRILL PULD P Continue to M/U 8%"BHA as follows:3 Non Mag Flex DC's,3-5" HWDP, DNT Jar assembly,and 12 5"HWDP.Total BHA length= 731.19'.Starting jar hours=0. 15:45 18:15 2.50 732 2,631 SLOT DRILL TRIP P RIH w/5'DP f/the Shed t/2631' DPM. Removed Cement Sheath from Drill Pipe as we picked it up. �n 18:15 19:00 0.75 2,631 2,770 SLOT DRILL REAM P Wash&ream down from 2631'DPM, 5 observing cement stringers from 2737'-2770'.Observed firm cement at 2770'DPM. 19:00 20:15 1.25 2,770 2,920 SLOT CEMEN-DRLG P Drill firm cement from 2770'-2920' A DPM,with pumps at 500 GPM's- 1000 PSI. Rotaing 20-50 RPM's. 20:15 23:00 2.75 2,920 2,943 INTRM1 DRILL DDRL P Beging time drilling at 150 Deg Left at 1'/hr from 2920'-2943'DPM. (Note: End of initial slide for kick off) Pumps at 550 GPM's-1650 PSI. 23:00 23:45 0.75 2,943 2,943 INTRM1 DRILL CIRC P Pull up to 2920' DPM.Circulate bottoms up for FIT test. MW=9.8 rip PPG LSND.Obtain gel strengths. 23:45 00:00 0.25 2,943 2,943 INTRM1 DRILL RURD P R/U for LOT 08/16/2010 / Conduct LOT U 13.9 PPG-Displace Well Bore U New 9.8 PPG LSND-Drill U 3070'MD-Well Path Following Nanuq#5 Well Path-Time Drill @ 1.2 to 2 FPH V 3080'MD-Drill U 4255'MD 00:00 00:30 0.50 2,943 2,943 INTRM1 DRILL LOT P Perform LOT as Follows: Pumped Wia9.e 1.6 Bbl of 9.8 PPG LSND @ 7 SPM -Pressure Broke Over at 520 Psi or 13.9 PPG EMW Page 9 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 03:30 3.00 2,943 3,070 INTRM1 DRILL DDRL P Displace Wellbore V Clean 9.8 PPG LSND and Drill 8' 'Intermediate Hole w/Motor V 3070'MD P/U 135,S/O 115, Rot 128 RPM 40 WOB 2 Torque On/Off 8.5/8 ECD 10.5 03:30 08:00 4.50 3,070 3,080 INTRM1 DRILL DDRL P Current Well Path unable to Break Away f/Nanuq#5-Time Drill f/3070' MD at 1.2 FPH U 3071'MD then 2 FPH U 3080'MD P/U 154,S/O 117, Rot 132 WOB7 RPM 0 Torque On/Off 0/0 650 GPM @ 1210 Psi ECD=10.15 08:00 12:00 4.00 3,080 3,185 INTRM1 DRILL DDRL P Drill 8'/."Hole U 3,185'MD P/U 155,S/O 122, Rot 135 WOB 8 RPM 85 Torque On/Off 8/7.5 650 GPM @ 1250 Psi ECD 10.35 12:00 18:00 6.00 3,185 3,767 INTRM1 DRILL DDRL P Drill 8 3/;'Hole V 3,767'MD P/U 163,S/O 130, Rot 145 RPM 100 WOB 10 Torque On/Off 9/8 650 GPM @ 1480 Psi ECD10.71 18:00 00:00 6.00 3,767 4,255 INTRM1 DRILL DDRL P Drill 8%"Hole t/4255'MD P/U 163,S/O 135, Rot 148 RPM 100 WOB 8 Torque On/Off 9.5/8 650 GPM @ 1520 Psi ECD 10.74 08/17/2010 Continue directional Drill 8 3/4"hole from 4255'-5287'MD 4039'TVD.Circulate Hi Visc sweep,and bottoms up x 2. POOH on elevators form 5287'.Observed proper hole fill. Breakout&lay down Motor BHA. RU&Test BOP's. BOP test witnessed by AOGCC rep Jeff Jones. Page 10 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 4,255 4,836 INTRM1 DRILL DDRL P Continue Directional Drill 8 3/4'Hole from 4255'-4836'-'MD 3718'TVD. Pump Hi visc sweeps as needed observing 20%increase in cuttings across shakers. P/U 168,S/O 145, Rot 158 RPM 120 WOB 10 Torque On/Off 9/7.5 650 GPM @ 1600 Psi ECD 10.70 06:00 11:00 5.00 4,836 5,287 INTRM1 DRILL DDRL P Continue Directional Drill 8'/4'Hole from 3718'-5287'MD 4039'TVD. Pump Hi visc sweeps as needed observing 20%increase in cuttings across shakers. P/U 175,S/O 152, Rot 164 RPM 120 WOB 10 Torque On/Off 9/7.5 650 GPM @ 1730 Psi ECD 10.80 11:00 11:30 0.50 5,287 5,287 INTRM1 DRILL CIRC P Circulate Hi Visc Nut Plug sweep at drilling rate. Reciprocate&Rotate drill string.Observed approximately 20%increase in cuttings across shakers. 11:30 11:45 0.25 5,287 5,287 INTRMI DRILL OWFF P Monitor well-Static. 11:45 15:00 3.25 5,287 732 INTRM1 DRILL TRIP P POOH on elevators from 5287'-732'. Observed proper hole fill.Monitor well -Static. 15:00 17:30 2.50 732 0 INTRM1 DRILL PULD P Rack back Flex DC's and 5"HWDP. Download MWD assembly. Breakout Bit, inspect&grade same to 1,1,CT, G,X, 1, NO,TD-Continue breakout &lay down MWD assembly. 17:30 18:30 1.00 0 0 INTRM1 WHDBO BOPE P Clean&clear rig floor area. RU to test BOP's. BOLDS. Pull Wear Bushing. 18:30 00:00 5.50 0 0 INTRM1 WHDBO BOPE P Test BOPE as Follows:Test Annular Preventer w/4", 5"and 7"Test Joints t/250/2500 Psi,Test Upper Rams w/5"and 7"Test Joints U 250/3500 Psi-Test Lower Rams w/4"and 5" Q�p Test Joint t/250/3500 Psi-Test V" 7 Choke Manifold Valves,4"Demco, g Auto&Man IBOP, HCR&Man Choke 7 Kill,4"and 5"Darts and TIWs t/250/3500 Psi-Test Super Choke t/1500 Psi-Perform Accumulator Test-Function Test Remote BOPE Panel-Tested Gas Alarms,Cellar H2S/Meth Failed- Test Witnessed by AOGCC Inspector Jeff Jones Page 11 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/18/2010 24 hr Summary Complete BOPE Test&Repair Gas Alarms-Pull Test Plug,Wash Stack&Well Head,Set Wear Ring-M/U BHA#6-RIH U 2,828'MD-Slip&Cut Drill Line-RIH U 5,119'MD-Wash U 5,287'MD-Drill 8%"Hole U 6,090'MD 00:00 01:30 1.50 0 0 INTRM1 WHDBO BOPE P Continue Testing Lower Rams t/ 250/3500 and Annular U 250/2500 Psi-Repaired Leaking Needle Valve, Recalibrated the Cellar Methane Alarm and Repaired the Cellar H2S Sensor 01:30 04:00 2.50 0 0 INTRM1 WHDBO NUND P Attempt to Pull Test Plug-Junk on Top-Pulled 25K Over and Worked Pipe to Free Plug-Discovered Cement Chunks on Test Plug and the Seal was Left in Hole-P/U Stack Washer and Wash Before Setting Wear Ring-Drain Stack Look for Test Plug Seal(Not Found)- Set Wear Ring 04:00 04:15 0.25 0 0 INTRM1 DRILL SFTY P PJSM on M/U BHA#6 04:15 05:45 1.50 0 75 INTRM1 DRILL PULD P M/U BHA#6 as Follows:8% Bit, Geo-Pilot, NMFDC, EWR, DGR, Smart Stab, PWD, HCIM, Pulser& NMFS 05:45 06:30 0.75 75 75 INTRM1 DRILL DHEQ P Upload MWD Data-Pressrue Test Geo-Span Lines U 3500 Psi 06:30 07:15 0.75 75 273 INTRM1 DRILL PULD P Continue to P/U BHA#6 as Follows; 2-NMFC's,Well Commander Assembly, 1 Std HWDP 07:15 07:45 0.50 273 273 INTRM1 DRILL DHEQ P Shallow Pulse Test MWD-Break In Geo-Pilot Bearings/Seals 07:45 10:00 2.25 273 2,838 INTRM1 DRILL TRIP P P/U Remaining BHA#6 Items:Jars, 10-Stds HWDP,Ghost Reamer, 4-Jts HWDP, 11-Stds 5"DP, Ghost Reamer and 2 Jts 5'DP-RIH w/ BHA#6 on 5'DP U 2,838'MD 10:00 10:15 0.25 2,838 2,838 INTRM1 RIGMN1SFTY P PJSM on Slipping and Cutting Drill Line 10:15 12:00 1.75 2,838 2,838 INTRM1 RIGMN1SLPC P Slip&Cut Drill Line-Service Rig- Adjust Brakes 12:00 13:00 1.00 2,838 5,119 INTRM1 DRILL TRIP P RIH w/BHA#6 U 5,119'MD 13:00 14:00 1.00 5,119 5,287 INTRM1 DRILL WASH P Wash Down U 5,287'MD 600 GPM @ 1500 Psi/120 RPM 14:00 18:00 4.00 5,287 5,595 INTRM1 DRILL DDRL P Drill 8'/:'Hole U 5,595'MD P/U 183,S/O 154, Rot 169 WOB 25-RPM 160 Torque On/Off 9/7.5 650 GPM @ 1700 Psi ECD 10.55 Page 12 of 31 Time Logs • Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:00 00:00 6.00 5,595 6,090 INTRM1 DRILL DDRL P Drill 8'/;'Hole U 6,090'MD P/U 187,S/O 163, Rot 175 WOB 25-RPM 170 Torque On/Off 9.5/7.5 650 GPM @ 1670 Psi ECD 10.61 08/19/2010 Drill 8%"Hole f/6,090'to 8,543'MD 00:00 06:00 6.00 6,090 6,736 INTRM1 DRILL DDRL P Drill 8%"Hole U 6,736'MD P/U 200,S/O 165, Rot 183 WOB 27 RPM 170 650 GPM @ 1640 Psi Torque On/Off 11/9 ECD 10.6 06:00 12:00 6.00 6,736 7,306 INTRM1 DRILL DDRL P Drill 8 3/4"Hole t/7,306'MD P/U 217,S/O 167, Rot 190 WOB 28 RPM 170 650 GPM @ 1520 Psi Torque On/Off 13/10.5 ECD 10.66 12:00 18:00 6.00 7,306 7,972 INTRM1 DRILL DDRL P Drill 8'/;'Hole t/7,972 MD P/U 227,S/O 175, Rot 200 WOB 30 RPM 170 650 GPM @ 1670 Psi Torque On/Off 14/11.5 ECD 10.75 18:00 00:00 6.00 7,972 8,543 INTRM1 DRILL DDRL P Drill 8%"Hole U 8,543'MD-Noticed Gas Unit Increase f/200 Units t/ 5,000 Units After Drilling Rock @ 6,212'TVD/8,353'MD-Remained Elevated Between 1,000 and 3,000 Units Until 6,345'MD TVD/8,543'MD -Flow Check on Connections Static, No Gains, No Alarms,Gas Cut Measured @ 4/10 th's P/U 260,S/O 170, Rot 209 WOB 30 RPM 170 650 GPM @ 1650 Psi Torque On/Off 17/14.5 ECD 10.66 08/20/2010 Continue to Drill 8' Hole f/8,543'-10,570'MD Page 13 of 31 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 8,543 9,145 INTRM1 DRILL DDRL P Drill 8'/,"Hole U 9,145'MD- Completed 550 Bbl Dilution to Bring MW t/10.5 PPG w/Glydril P/U 255, S/O 180, Rot 213 WOB 30 RPM 162 650 GPM @ 2400 Psi Torque On/Off 18/13.5 ECD 11.19 06:00 12:00 6.00 9,145 9,558 INTRM1 DRILL DDRL P Drill 8 3/4'Hole t/9,558'MD P/U 255,S/O 180, Rot 213 WOB 30 RPM 170 650 GPM @ 2680Psi Torque On/Off 16/12.5 ECD 11.42 12:00 18:00 6.00 9,558 10,160 INTRM1 DRILL DDRL P Drill 8'/4'Hole t/10,160'MD P/U 270,S/O 176, Rot 216 WOB 30 RPM 165 650 GPM @ 2840 Psi Torque On/Off 17/13 ECD 11.46 18:00 00:00 6.00 10,160 10,570 INTRM1 DRILL DDRL P Drill 8'/4'Hole t/10,570'MD P/U 270,S/O 175, Rot 210 WOB 30 RPM 165 650 GPM @ 2900 Psi Torque On/Off 17.5/13 ECD 11.49 08/21/2010 Continue to Drill 8 3/4"Hole from 10570'-11507'MD.TVD=7383'. Total Bit HRS=47.83,&Jar HRS= 72.19.Circulate Hi Visc Nut plug sweep+3 x Bottoms up. BROOH at drilling rates to top of HRZ at 9300' MD.Observe Well(Static). RIH on elevators working through tight spots to 11,507'MD. Circulate and condition while weighting up mud to 11 PPG. POOH w/pumps to 10,842'MD 00:00 06:00 6.00 10,570 11,109 INTRM1 DRILL DDRL P Drilled 8'/4'Hole from 11,070'- 11109'MD.TVD=7346'. P/U 280,S/O 180, Rot 210 WOB 30 RPM 165 650 GPM @ 2980 Psi Torque On/Off 18/14 ECD 11.30 06:00 12:15 6.25 11,109 11,507 INTRM1 DRILL DDRL P Drilled 8'/,"Hole from 11,109'- ��7 11507'MD.TVD=7383'.Well TD'd as per Geo. 1‘� P/U 282,S/O 165, Rot 214 WOB 30 RPM 165 650 GPM @ 3030 Psi Torque On/Off 19/14 ECD 11.43 Page 14 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:15 14:45 2.50 11,507 11,507 INTRMI DRILL CIRC P Pump Hi Visc nut plug sweep and 3 x bottoms up. Reciprocate&rotate drill string. Monitor well-static. 14:45 18:45 4.00 11,507 9,300 INTRM1 DRILL REAM P BROOH first 3 stands at slower rate to obtain 3rd bottoms up.Continune BROOH at drilling rates to above HRZ at 9300'MD.Observed proper hole fill and no issues. 18:45 19:00 0.25 9,300 9,300 INTRM1 DRILL OWFF P Monitor well-static. 19:00 20:30 1.50 9,300 11,507 INTRMI DRILL TRIP P RIH t/11,507'MD on TT-Work Through Tight Spots @ 10,252', 10,493', 10,633', 10,685', 10,789'& 10,843'MD 20:30 22:30 2.00 11,507 11,507 INTRMI DRILL CIRC P Pump Hi-vis Sweep and Circ&Cond While Increasing MW t/11.0 PPG 650 GPM @ 3000 Psi 150 RPM 22:30 00:00 1.50 11,507 10,842 INTRMI DRILL TRIP P POOH w/Pumps t/10,824'MD 168 GPM @ 450 Psi 08/22/2010 Continue to POOH w/Pumps U 9,142'MD-RIH on Elevators Working Pipe Through Tight Spots t/11,507' MD-Circ&Condition Mud Standing Back Pipe U 11,043'MD-RIH on Elevators U 11.426'MD-Wash Down U 11,507-Spot Wellbore Strengthening Pill f/11,507'to 9,112'MD-POOH on Elevators U 5,881'MD(Noted Increased Drag)-RIH U 8,828'MD-BROOH U 4,740'MD, Noted Top Stabilizer Pass Casing Stump @ 3,017' MD 00:00 02:30 2.50 10,842 9,142 INTRM1 DRILL TRIP P Continue to POOH w/Pumps t/ 9,142'MD 168 GPM @ 350 Psi 02:30 04:00 1.50 9,142 11,507 INTRM1 DRILL TRIP P OWFF(Static)-RIH on Elevators U 11,507'MD,Took Weight @ 9,885', 10,467', 10930'through 10,945', 10,971'and 11,320'MD-String Took 20-25K Weight Each Time but Able to Pick Up and Work Through w/o Pumps, Noted Increased Drag f/ 11,320'MD(Suspect Dune) 04:00 05:45 1.75 11,507 11,043 INTRMI DRILL CIRC P Circ&Condition Mud for Trip-Stand back 1 Stand Every 15 Minutes After the First BU U 11,043'MD 625 GPM @ 2100 Psi 150 RPM 05:45 06:30 0.75 11,043 11,507 INTRM1 DRILL TRIP P RIH on Elevators U 11,426'MD then Wash U 11,507'MD-Drag on Bottom 5 Stands improved Slightly After Trip 06:30 10:45 4.25 11,507 9,112 INTRM1 DRILL OWFF P OWFF(Static)-Spot WBS Pill f/ 11,507'-9,112'MD-3 BPM @ 550 Psi, Pulling 33 FPM 10:45 15:00 4.25 9,112 5,881 INTRM1 DRILL TRIP P POOH on Elevators U 5,881'MD- Work Trough Tight Spots @ 8160', 7422',6585',6529'-6524'and 6243' MD) Page 15 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 17:00 2.00 5,881 8,828 INTRM1 DRILL TRIP T RIH t/8,828'MD-to BROOH for Tight Spots 17:00 22:30 5.50 8,828 5,881 INTRM1 DRILL REAM T BROOH U 5,881'MD-650 GPM w/ 2700, RPM 130-Pumped Viscosified Nut Plug Sweeps Every 15 Stands w/Minimal Cuttings Increase,Completed 250 Bbl Dilution 22:30 00:00 1.50 5,881 4,740 INTRM1 DRILL REAM P Continue to BROOH t/4740'MD- 130 RPM,650 GPM w/2300 Psi- Noted Top Stabilizer Passing Nanuq #5,7"Casing Stump by Erratic Torque and Weight Readings 08/23/2010 Continue to BROOH U 3,028'MD-Open Well Commander Circ Sub and Circulate 2 Surface to Surface Volumes @ 750 GPM w/1230 Psi(Hole Unloaded Cuttings)-Attempt to Close Circ Sub but Unable- BROOH U 2,933'MD-OWFF(Static)-POOH on Elevators-L/D BHA#6-R/U U Run 7"Casing-Attend 3rd Quarter Safety Assessment-Run Casing U 2,878'MD(69 Joints)-Circ Casing Volume @ 5 BPM w/320 Psi -Continue to Run Casing U 4,366'MD(36 Joints)-Circ Casing Volume+@ 5 BPM w/390 Psi-Run Casing U 4,557(5 Joints-110 Total in Hole) 00:00 04:00 4.00 4,740 3,028 INTRM1 DRILL REAM P Continue to BROOH U 3,028'MD, 650 GPM @ 2150 Psi-Pumped Viscosified Nut Plug Sweep Every 15 Stands with Minimal Cuttings Increase Page 16 of 31 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 04:00 05:15 1.25 3,028 3,028 INTRM1 DRILL CIRC P Establish Circulation and Record Pressures Prior to Opening"Well Commander"Circ Sub 15 BPM @ 1900 Psi 3 BPM @ 240 Psi Drop 2.125"Ball and Circ Down- Ball on Seat @ 110 Strokes, Increase Pressure to 2,000 Psi and Hold for 30 Seconds, Increase Pressure to 2,500 Psi and hold for 30 Seconds, Increase Pressure& Observe Tool Function @ 2,680 Psi- Establish Circ and Record Pressure 3 BPM @ 160 Psi Pump Viscosified nut Plug Sweep and 2 Surface to Surface Circulations to Clean Casing, Hole Unloaded Golf Ball to Base Ball Size Clay-Circ Rates: 650 GPM @ 1010 Psi 700 GPM @ 1140 Psi 750 GPM @ 1230 Psi RPM=100 Drop 2.125"Ball and Attempt to Close Circ Sub, Ball On Seat @ 106 Strokes(3 BPM 160 Psi), Pressure Up to 2,000,2,500 Psi holding 30 Seconds Each Time,Sub Functioned at 2,820 Psi-Checked Pressure v/Rate 3 BPM @ 160 Psi 650 GPM @ 1010 Psi*Sub Still Open* Drop 2.125"Ball and Attempt to Close Sub, Ball On Seat @ 139 Strokes(3 BPM 160 Psi), Pressure Up to 2,000 and 2,500 Psi Holding for 30 Seconds Each Time,Observe Tool Function @ 2,810 Psi-Check Pressure v/Rate 650 GPM @ 980 Psi*Tool Still Open* 05:15 05:30 0.25 3,028 2,933 INTRM1 DRILL REAM P BROOH t/2,933'MD 650 GPM @ 980 Psi, 100 RPM 05:30 05:45 0.25 2,933 2,933 INTRM1 DRILL OWFF P Blow Down Top Drive, Line Up on TT -OWFF(Static) Page 17 of 31 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 05:45 08:30 2.75 2,933 746 INTRM1 DRILL TRIP P POOH on TT U BHA. Breakout&lay down Ghost reamers.Observed blade a littlle damaged on lower reamer,but in gauge.Observed proper hole fill. 08:30 12:00 3.50 746 0 INTRM1 DRILL PULD P Continue POOH,breakout&lay down BHA including Flex DC's. Download MWD ssembly. Breakout, inspect and grade Bit to 1 /1 CT/G/X/I/ER/TD. 12:00 13:00 1.00 0 0 INTRM1 DRILL PULD P Clean&clear rig floor area. Send tools out. BOLDS&pull wear bushing. Flush stack with water. 13:00 14:00 1.00 0 0 INTRM1 CASING RURD P Rig up casing equipment including power tongs,slips,and pneumatic elevators Franks Fill up tool.Verify all casing running equipment via checklist. 14:00 14:30 0.50 0 0 INTRM1 CASING SFTY P Held PJSM with crew, HES rep and casing rep. Discuss safety&hazard recognition issues. Discuss procedure to make up shoe track assembly and run casing. 14:30 16:00 1.50 0 0 INTRM1 CASING SFTY P Stop Operations to Attend 3rd Quarter HSE Assessment w/ Anchorage Based Leadership f/ CPAI, DDI&MI 16:00 20:15 4.25 0 2,878 INTRM1 CASING RNCS P Make up Shoe track assembly with Slyer Bullet Float shoe, HES Super Seal Float collar w/bypass baffle,2 joints and HES Baffle collar. Fill with mud,and check floats.-Continue to RIH U 2,878'MD(69 Joints Total) 20:15 21:00 0.75 2,878 2,878 INTRM1 CASING CIRC P Circulate and Condition Mud-Pump Casing Volume @ 5 BPM w/320 Psi 21:00 22:30 1.50 2,878 4,366 INTRM1 CASING RNCS P Continue to RIH w/Casing t/4,366' MD(36 Joints-105 Total) 22:30 23:30 1.00 4,366 4,366 INTRM1 CASING CIRC P Circulate and Condition Mud-Circ Casing Volume+@ 5 BPM w/390 Psi 23:30 00:00 0.50 4,336 4,336 INTRM1 CASING RNCS P Continue to RIH w/Casing U 4,577' MD(5 Joints-110 Total) P/U 155,S/O 133 aoP 08/24/2010 Continue to RIH w/7"casing f/4577'to 11,295'(272 jts total in hole)Circulated&conditioned mud @ 5893', 1 (.SI 1`� .t 7440',9211'-string took wt.@ 10,337'-Washed&worked pipe down f/10,337'to 11,295'@ 3 bbls/min @ Y' 680 to 340 psi 00:00 01:45 1.75 4,336 5,893 INTRM1 CASING RNCS P '.Continue to RIH w/7"Casing t/ 5,893'MD(32 Joints-142 Total); Installed/Baker Locked HES Stage Collar Between Joints 135/136-PU wt.200 SO wt. 150 01:45 02:30 0.75 5,893 5,893 INTRM1 CASING CIRC P Circ and Condition Mud @ 5 BPM w/ 390 Psi Page 18 of 31 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 02:30 04:30 2.00 5,893 7,472 INTRM1 CASING RNCS P Continue to RIH w/7'Casing f/5893' to 7,472'MD(38 Joints-180 Total) P/U 250,5/0 163 04:30 06:00 1.50 7,472 7,472 INTRM1 CASING CIRC P Circ and Condition Mud,Staging Pumps Up t/5 BPM @ 490 psi 06:00 08:15 2.25 7,472 8,714 INTRM1 CASING RNCS P Continue to RIH w/7"casing f/7472' to 8714'(210 jts total in hole)PU wt 277 SO wt 172(Low drag roller cent. wouldn't pass into 9 5/8"surface casing 08:15 09:00 0.75 8,714 8,630 INTRM1 CASING RNCS T Pulled up&laid down jts#209& 210-removed Low drag roller cent.& replaced w/Boss cent. 09:00 10:00 1.00 8,630 9,211 INTRMI CASING RNCS P Cont. RIH w/7"casing f/8630'to 9211'(222 jts.total in hole)PU wt. 295 SO wt. 175 10:00 11:30 1.50 9,211 9,211 INTRM1 CASING CIRC P Establish circ-Stage pump up to 5 bbls/min&circ btms up plus-ICP 480 psi FCP 620 psi 11:30 12:45 1.25 9,211 10,337 INTRM1 CASING RNCS P Cont. RIH w/7'casing f/9211'to 10337'(249 jts total in hole)string took wt. 12:45 00:00 11.25 10,337 11,295 INTRM1 CASING RNCS T Work&wash casing down f/10,337' to 11,295'(272 jts.total in hole of 276 to run)3 bbls/min @ 680 psi- PU wt.345 SO wt. 80 08/25/2010 ✓ Finish washing 7"casing to btm-Circ&cond. mud for cmt job-Cemented 7"csg-1st stage 700 sks(145 bbls)2nd stage 210 sks(43 bbls)15.8 ppg-RD cmt equip-set&test pack-off-Slip&cut drill line-LD 5" DP f/derrick 00:00 03:00 3.00 11,295 11,459 INTRM1 CASING RNCS P Continue washing casing from 11,296'to 11,459'@ 3 bpm,480 psi. 03:00 03:30 0.50 11,459 11,497 INTRM1 CASING RNCS P Make up landing joint and hanger. Wash down and land hanger with casing shoe @ 11,497' 03:30 04:00 0.50 11,497 11,497 INTRM1 CASING RURD P Rig down Frank's fillup tool and blowdown top drive. R/U cement head 04:00 06:30 2.50 11,497 11,497 INTRMI CEMEN"CIRC P Circulate and condition mud for cement job. ICP=400 psi at 2 bpm, FCP=680 psi @ 5 bpm 06:30 06:45 0.25 11,497 11,497 INTRM1 CEMEN"SFTY P Pre-job safety meeting prior to cement job Page 19 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15 r- 06:45 09:45 3.00 11,497 11,497 INTRM1 CEMEN"CMNT P Cemented 1st stage of 7",casing as follows: Pumped 5 bbls CW-100- Tested lines to 3500 psi-Pumped 35 bbls CW-100-Mixed&pumped 35 bbls(12.5 ppg)MudPush- Dropped btm plug-Pumped remaining 5 bbls(12.5 ppg) MudPush-Loaded cmt head w/top plug-Mixed&pumped 145 bbls 700 sks)15.8 ppg tail slurry-Class G w/0.2%DO46 antifoamer,0.25% DO65 dispersant,0.25%D800 retarder,&0.18% D167 fluid loss additive-Dropped top plug w/20 bbls freah water f/Dowell-Switched over to rig pumps&displaced cmt w/ 417 bbls-11.0 ppg LSND mud @ 5 bbls/min @ 900 psi @ 340 bbls away- slowed pump to 4 bbls/min @ 810 psi @ 400 bbls away slowed pump to 3 bbls/min @ 740 psi- Bumped plug w/1200 psi-CIP @ 0930 hrs-Full returns through out job-reciprocated pipe w/30'stroke until 285 bbls of displacement away- string getting sticky-Checked floats OK 09:45 10:30 0.75 11,497 11,497 INTRM1 CEMEN"CIRC P Loaded top closing plug. Pressure up and opened stage collar @ 5900' w/3450 psi. Circulate bottoms up at 5 bpm,320 psi 10:30 12:00 1.50 11,497 11,497 INTRM1 CEMEN"CMNT P (''mPntatri?nd stage of 7"casing as, L.��► follows: Pumped 5 bbls CW-100- Shy Tested lines to 3500 psi-Pumped remaining 15 bbls CW-100-Mixed& /(a^,k pumped 20 bbls(12.5 ppg) l MudPush-Mixed&pumped 43 bbls (210 sks) 15.8 ppg tail slurry Class G w/0.2%DO46 antifoamer,0.3% DO65 dispersant,&1%SOO2 accelerator-Dropped closing plug w/ 20 bbls fresh water f/Dowell- switched over to rig pumps& displaced cmt w/208 bbls 11.0 ppg LSND mud @ 5 bbls/min @ 300 psi- slowed pump to 2 bbls/min w/195 bbls of displacement pumped- bumped plug @ stage collar & pressured up to 2700 psi to close stage collar-held pressure for 5 mins.-bleed-off&checked for flow- Stage collar closed-CIP @ 1159 hrs.-Full circ through out job / 12:00 12:45 0.75 11,497 0 INTRM1 CEMEN"RURD P Blow down lines, Rig down cement equipment. Clear floor and lay down landing joint Page 20 of 31 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 12:45 14:00 1.25 0 0 INTRM1 WHDBO PULD P Pick up 5"test joint and pull wear ring. Set pack off and lay down 5" test joint 14:00 15:30 1.50 0 0 INTRMI RIGMN7 SLPC P Slip and cut drilling line. Service rig - 15:30 17:00 1.50 0 0 INTRM1 WHDBO NUND P Change pipe rams and saver sub t ,' (p 17:00 18:15 1.25 0 0 INTRM1 WHDBO BOPE P Rig up and tested upper pipe rams 7 w/5"test jt to 250 psi low and 3500 psi high. Rig down and pull test plug &set wear bushing 18:15 00:00 5.75 0 0 INTRM1 DRILL PULD P Rig up and lay down 5"drill pipe f/ derrick via mouse hole(56 stds) 08/26/2010 MU clean out assembly-RIH picking up 4"DP to 5722'-Test casing to 1000 psi for 10 mins.-Clean out stage collar @ 5900'to 5903'-Wash down to 6107'-re-test csg to 1000 psi-POOH w/BHA#3-RU&test BOPE-MU BHA#4(6 1/8"Geo-pilot w/Bat Sonic-Up load MWD 00:00 00:30 0.50 0 0 INTRM1 DRILL OTHR P Changed heads in Iron Roughneck to 4"and Changed elevators to 3-1/2" 00:30 02:15 1.75 0 0 INTRM1 DRILL PULD P Make up BHA#3(dumb iron clean out assembly) 02:15 07:15 5.00 0 5,722 INTRM1 DRILL PULD P Pick up 4"drill pipe from pipe shed. to 5722' 07:15 08:00 0.75 5,722 5,722 INTRM1 DRILL PRTS P Fill drill pipe. Rig up and test casing to 1000 psi for 10 minutes. Blow down lines and rig down 08:00 10:45 2.75 5,722 6,107 INTRM1 CEMEN"DRLG P Make up top drive and wash from 5722 to 5900'@ 265 gpm, 1130 psi, 50 rpm, Drill stage collar at 5900'to 5903'-wash down f/5903'to 6107' 10:45 11:15 0.50 6,107 6,007 INTRM1 DRILL CIRC P Stand back one stand to 6007'and circulate bottoms up at 260 gpm, 1220 psi. 50 rpm. 11:15 12:00 0.75 6,007 6,007 INTRM1 DRILL PRTS P Blow down top drive. R/U and test casing to 1000 psi for 10 minutes Pump dry job and blow down top drive 12:00 14:30 2.50 6,007 276 INTRM1 DRILL TRIP P Pull out of the hole from 6007'to 276' 14:30 15:15 0.75 276 0 INTRM1 DRILL PULD P Lay down BHA 15:15 15:45 0.50 0 0 INTRM1 DRILL OTHR P Clear floor and pull wear ring 15:45 16:30 0.75 0 0 INTRM1 WHDBO RURD P Rig up test equipment. Set test plug and fill stack with water 16:30 21:00 4.50 0 0 INTRM1 WHDBO BOPE P Test BOPE. Test choke manifold , rams,TIW valve, IBOP to 250 psi/3500 psi. Tested Annular to 250 De psi/2500 psi. Test pipe rams and (� annular with 3-1/2"and 4"test joints. q,AL Function tested remote BOPE control station. Pulled test plug. Bob Noble,AOGCC,waived witnessing the BOP test 21:00 21:45 0.75 0 0 INTRM1 WHDBO RURD P Blow down lines. Set wear ring per wellhead rep 21:45 00:00 2.25 0 127 INTRM1 DRILL PULD P MU BHA#4(6 1/8"Geo-Pilot assembly w/BAT SONIC tool-Up load MWD Page 21 of 31 Time Logs Date From To Dur • S. Depth E. Depth Phase Code Subcode T Comment 08/27/2010 24 hr Summary MU BHA#4-RIH picking 246 jts 4"DP f/shed to 8208'-RIH w/DP f/derrick to 10,594'-MADD pass f/ 10,594'to 11,340'for BAT SONIC tool-Change over to 9.0 ppg Flow Pro-Clean out shoe track&Drill 20' new hole to 11,527'-Perform FIT to 12.5 ppg EMW-Drilled 6 1/8"hole to 11,549' 00:00 01:30 1.50 127 127 INTRM1 DRILL PULD P Continue picking up BHA and shallow test at 200 gpm @ 840 psi. Break in bearings in Geo-pilot 01:30 08:30 7.00 127 8,208 INTRM1 DRILL TRIP P Trip in hole picking up 4"drillpipe out of the pipe shed to 8208' 08:30 09:30 1.00 8,208 10,594 INTRM1 DRILL TRIP P Run in the hole with drillpipe out of the derrick from 8208'to 10594' P/U=235k,S/0=130k 09:30 12:45 3.25 10,594 11,340 INTRM1 DRILL TRIP P Run in the hole at 300 fph while making MADD pass with BAT Sonic tool from 10594'to11340' 12:45 14:45 2.00 11,340 11,340 INTRMI DRILL CIRC P Displace well with 9.0 ppg Flo-Pro mud 14:45 16:15 1.50 11,340 11,340 INTRM1 DRILL PRTS P Blowdown top drive and rig up and test casing to 3500 psi for 30 minutes. Blowdown lines and rig down test equipment 16:15 20:15 4.00 11,340 11,507 INTRM1 CEMEN-DRLG P Drill shoe track and float equiopment to 11507' _ 20:15 20:30 0.25 11,507 11,527 INTRM1 DRILL DDRL P Drill 20'of new hole to 11527' TVD= 7383' ADT-.24 hrs. ECD-10.06 ppg WOB 8/12 k RPM 70 GPM 220 @ 1330 psi 20:30 21:30 1.00 11,527 11,527 INTRM1 DRILL CIRC P Circulate and condition mud at 220 gpm @ 1150 psi.70 rpm, Blow down top drive )� 21:30 22:30 1.00 11,527 11,527 INTRMI DRILL FIT P Rig up and perform FIT to 12.5 ppg EMW. 1350 psi @ 7383'TVD w/9.0 ppg mud 22:30 00:00 1.50 11,527 11,549 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP f/11,527'to 11,549'MD 7385'TVD ADT-.60 ECD-10.20 ppg Footage-22' WOB 5/8 k RPM 70 GPM 220 @ 1500 psi String wt. PU 230 SO 145 ROT 185 Torque on/off btm.-13/12 k 08/28/2010 Drilled 6 1/8"hole w/GP f/11,549'to 12,979' Page 22 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 11,549 12,216 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP from 11549' to 12216' (7400'TVD) ADT-7.89 hrs ECD 10.52 ppg Footage 667' WOB 5/15 k RPM 120 GPM 225 @ 1560 psi String wt. PU 220 SO 160 ROT 188 Torque on/off btm.-11,500/8,000 ft/lbs At 11740'noticed slight pit gain and flow increase. Picked up and shut down pump. Monitored well-static. Mud appears to be severely aireded Increased mud weight to 9.2 ppg while drilling. 12:00 00:00 12.00 12,216 12,979 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP from 12216' to 12,979'MD 7406'TVD ADT 8.02 hrs ECD-10.67 ppg Footage 763' WOB 5/8 k RPM 130 GPM 225 @ 2000 psi String wt. PU 225 SO 160 ROT 188 Torque on/off btm.-8,500/7,500 f/lbs 08/29/2010 Drilled 6 1/8"hole w/GP f/12,979'to 13742' 00:00 12:00 12.00 12,979 13,291 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP f/12,979'to 13,291'MD 7402'ND ADT-8.47 hrs. ECD 10.55 ppg Footage 312' WOB 6/18 k RPM 120 GPM 230 @2160 psi String wt. PU230 SO 155 ROT 190 Torque on/off bmt.-11,000/8,500 ft/lbs 12:00 00:00 12.00 13,291 13,742 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP f/13,291'to 13,742'MD 7396'ND ADT-9.53 hrs. ECD 10.83 ppg Footage 451' WOB 6/9 k RPM 120 GPM 230 @ 2260 psi String wt. PU230 SO 157 ROT 190 Torque on/off bmt.-10,000/8,000 ft/lbs 08/30/2010 Drilled 6 1/8"hole w/GP f/13,742'to 15,268' Hole taking fluid @ average 20 bbls/hrs loss rate Total for last 24 hrs.491 bbls 9.0 ppg FloPro Page 23 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 13,742 14,462 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP f/13,742'to 14,462' MD 7394'ND ADT-8.09 hrs. ECD 10.91 ppg Footage 720' WOB 6/9 k RPM 120 GPM 230 @ 2300psi String wt. PU 240 SO 150 ROT 190 Torque on/off bmt.-11000/10500 ft/lbs •Fluid losses for 12 hr tour= 141 bbls 12:00 00:00 12.00 14,462 15,265 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP f/14,462'to 15,265' MD 7408'ND ADT-8.2 hrs. ECD 11.30 ppg Footage 806' WOB 6/12 k RPM 130 GPM 220 @ 2460 psi String wt. PU 238 SO 150 ROT 192 Torque on/off bmt.-11,500/10,000 ft/lbs Losses for 12 hour tour= 350 bbls Total losses last 24 hrs.491 bbls 9.0 ppg FloPro Average lose rate 20 bbls/hr. 08/31/2010 Drilled 6 1/8"hole w/GP f/15,268'to 15,799' Hole still taking fluid @ 45 bbls/hr average loss rate-Lost 1098 bbls past 24 hrs. Total losses to date 1589 bbls 9.0 opg Flo Pro 00:00 06:00 6.00 15,265 15,555 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP from 15,526'to 15,555' ND=7410' ADT-4.05 hrs. ECD-11.61 Footage-287' WOB 8/12 k RPM 130 GPM 220 @2510 psi String wt. PU 245 SO 145 ROT 190 Torque on/off btm.-12,500/11,500 ft/lbs 06:00 06:15 0.25 15,555 15,555 PROD1 DRILL CIRC P Circulate and condition mud at 200 gpm,2060 psi. 130 rpm 12k ft-lbs torque, Noticed flow out increasing- Checked viscosity @ 62 s/qt.-No gas 06:15 06:30 0.25 15,555 15,555 PROD1 DRILL OWFF P Shut down-well flowing- take returns to trip tank-well went static in 6 mins.w/9 bbls of mud to trip tank-Well appears to be breathing Page 24 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 12:00 5.50 15,555 15,749 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP from 15555' to 15749' MD 7409'TVD. ADT=3.04 hrs. ECD 10.98 ppg Footage-194' WOB 8/14 k RPM 130 GPM 200 @ 2040 psi String wt. PU 250 SO 145 ROT 190 Torque On/off btm.- 12,000/10,500 ft/lbs Losses for 12 hrs=678 bbl. 12:00 00:00 12.00 15,749 15,799 ROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP from 15Z492.10_1529.92...Md 7409'TVD. ADT-10.58 hrs. ECD-10.64 ppg Footage-50' WOB 12/18 k RPM 60/120 GPM 200 @ 2050 psi String wt PU 250 SO 145 ROT 190 Torque on/off btm.-12,000/10,500 ft/lbs. Losses for 12 hrs=420 bbl. Total losses for last 24 hrs. 1098 bbls Total losses to well 1589 bbls-9.0 ppg FloPro 09/01/2010 Drilled very hard UJU f/15,799'to 15,813', Decision made to trip for bit-Flow ck well static in 2 mins.&fluid level dropping slightly-BROOH to 11,453'(inside 7"casing)-Flow ck well static-Attempt to POOH on TT- well swabbing-Circ btms up-Flow ck static-POOH w/pump 10 stds to 10,498'-POOH on TT to 387' 00:00 07:15 7.25 15,799 15,813 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP f/15,799'to 15,813'MD 7408'TVD ADT-4.72 hrs ECD-10.84 ppg Footage-14' WOB 25 k RPM 90 GPM 200 @ 2150 psi String wt. PU 250 SO 145 ROT 190 Torque on/off btm.-12,000/10,5001' ft/lb 07:15 14:30 7.25 15,813 11,453 PROD1 DRILL TRIP T Flow ck(well static in 2 mins.)- BROOH f/15,813'to 11,453'@ 100 rpm-200 gpm @ 2200 psi Losses for past 12 hrs 301 bbls. 14:30 14:45 0.25 11,453 11,453 PROD1 DRILL OWFF T Monitor well- Fluid level dropping 14:45 15:00 0.25 11,453 11,453 PROD1 DRILL TRIP T Attempt to POOH on elevators-hole swabbing 15:00 16:00 1.00 11,453 11,453 PROD1 DRILL CIRC T Circulate bottoms up. 16:00 16:15 0.25 11,453 11,453 PROD1 DRILL OWFF T Monitor well--static 16:15 17:15 1.00 11,453 10,498 PROD1 DRILL TRIP T Pump out of the hole from 11453'to 10498'(10 stands) Page 25 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 17:30 0.25 10,498 10,498 PROD1 DRILL OWFF T Monitor well--static 17:30 00:00 6.50 10,498 387 PROD1 DRILL TRIP T POOH on TT from 10498'to 387'- PU wt.85 SO wt 80 Lost 42 bbls last 12 hrs. Total losses for last 24 hrs.343 bbls Total losses to well-1932 bbls 9.0 ppg FloPro 09/02/2010 Finish POOH&LD BHA#3 Geo-Pilot w/Hughes 6 1/8"bit-MU BHA#4 Geo-Pilot w/SDBS 6 1/8"-RIH to 11,322'(filling pipe every 20 stds)Slip&cut drill line&service rig-RIH to 14,374'(took wt.)wash&ream f/ 14,374'to 14,469'-RIH to 15,907'-Precuationary wah&ream to 15,813'-Drilled 6 1/8"hole w/GP f/15,813' to 15,824'(P rate 4'/hr) 00:00 02:00 2.00 387 0 PROD1 DRILL TRIP T Flow ck @ HWDP static-Std back HWDP-LD bumper sub-Std back NM flex DC's w/BAT Sonic tool- Pull up&break bit&service GeoPilot while down loading MWD- LD MWD tools&Geo-Pilot 02:00 02:15 0.25 0 0 PROD1 DRILL PULD T Clean&clear rig floor-PU 02:15 02:30 0.25 0 0 PROD1 DRILL SFTY T PJSM on picking up BHA 02:30 05:45 3.25 0 448 PROD1 DRILL PULD T MU BHA#4-bit(FMF3543ZZ) Geo-Pilot-Stab-Slim phase 4- Stab-DM-PWD-Pulser-float sub -Up load MWD-LD BAT Sonic tool -MU NM flex DC's-RIH w/HWDP w/jars&bumper sub-PU 3 jts 4" DP f/shed to 448'-Shallow pulse MWD tools-Break in Geo-Pilot bearings 05:45 11:00 5.25 448 11,332 PROD1 DRILL TRIP T Cont. RIH f/448'-PU 2 stds 4"DP f/ shed-RIH w/DP f/derrick f/729'to 11,332' 11:00 12:45 1.75 11,332 11,332 PROD1 RIGMN1 SLPC T Slip and cut 60'of drilling line. Service rig and top drive 12:45 14:00 1.25 11,332 11,332 PROD1 DRILL CIRC T Circulate bottoms up @ 200gpm, 1560 psi 14:00 15:15 1.25 11,332 13,707 PROD1 DRILL TRIP T Run in the hole from 11,332'to 13,707'. P/U=235k,S/O= 150k 15:15 16:45 1.50 13,707 13,707 PROD1 DRILL CIRC T Stage pump up to 200 gpm @ 1610 psi. and circulate bottoms up 16:45 17:15 0.50 13,707 14,374 PROD1 DRILL TRIP T Run in the hole from 13,707'to 14,374'. P/U=235k,S/O= 150k, Hit bridge and picked up w/70k overpull 17:15 18:15 1.00 14,374 14,469 PROD1 DRILL WASH T Wash and ream from 14,374'to 14,469' @ 200 gpm, 1780 psi,90 rpm, 18:15 19:00 0.75 14,469 15,709 PROD1 DRILL TRIP T Run in the hole from 14,469'to 15709' P/U=235k,S/O=150k. 19:00 19:30 0.50 15,709 15,813 PROD1 DRILL WASH T Wash and ream from 15,709'to 15,813'at 200 gpm,2120 psi, 110 rpm, Page 26 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 00:00 4.50 15,813 15,824 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP f/15,813'to 15,824'MD 7408'ND ADT 2.82 hrs. ECD 10.35 ppg Footage-11' WOB 7/10 k RPM 110 GPM 200 @2120 psi String wt. PU 235 SO 150 ROT 180 Torque on/off btm.-11,500/10,000 ft/lbs. Losses last 24 hrs.43 bbls Total losses to date-1975 bbls-9,0 ppg FloPro 09/03/2010 PY I Drilled 6 1/8"hole to 15,829'-Decision made to pull up&attempt to sidetrack well(cutting samples indicated _ gL`t well path went into Alpine D shale)BROOH to 15,465'-Trough f/15,465'to 15,481'-Began time drilling @ SO IB 15,481'&time drilled to 15,509'-Down&165 L oo 00:00 01:45 1.75 15,824 15,829 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP f/15,824'to 15,829'MD 7408'ND ADT-2.01 hrs. ECD- 10.35 ppg Footage-5' WOB- 10/12 k RPM 90 GPM 200 @ 2120 psi String wt. PU 235 SO 150 ROT 180 Torque on/off btm.-11,500/10,000 ft/lbs. 01:45 02:45 1.00 15,829 15,465 PROD1 DRILL TRIP T BROOH f/15,829'to 15,465'-190 gpm @ 1750 psi w/100 rpm's- torque 9 k 02:45 03:30 0.75 15,465 15,481 PROD1 DRILL DDRL T Trough f/15,465'to 15,481'-prep to side track well 03:30 12:00 8.50 15,481 15,492 PROD1 DRILL DDRL T Time drill f/15,481'to 15,492'- ND 7411' ADT-9.94 hrs ECD-10.57 ppg Footage-11' WOB 2/3 k RPM 130 GPM 200 @ 1840 psi String wt. ROT 175 Torque 10 k Hole took 192 bbls last 12 hrs. NOTE: Held discussion with crew about Nordic 3 hand incident Page 27 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 15,492 15,509 PROD1 DRILL DDRL T Time drilled f/15492'to 15,509'MD 7411'ND ADT-11.72 hrs ECD-10.62 ppg Footage-17' WOB 2 k RPM 130 GPM 200 @ 1890 psi String wt. ROT 175 Torque 10 k Hole took 249 bbls last 12 hrs. Total losses past 24 hrs.441 bbls Total looses to date-2416 bbls-9.0 ppg FloPro NOTE: Reviewed Nordic 3 PIR where man hurt his hand on rails of bridge crane. 09/04/2010 Time drilled to 15,519'(Back into Alpine C sand)-Drilled 6 1/8"hole 15,519'to 16,004'MD 7448'ND- logged base of Alpine C-Circ&BROOH to 15,042'-POOH w/pump f/15,042'to 13,134' 00:00 04:15 4.25 15,509 15,519 PROD1 DRILL DDRL T Time drill from 15,509'to 15519' 04:15 12:00 7.75 15,519 15,785 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP from 15519' to 15785' MD 7430'ND ADT=6.16 hrs ECD-10.89 ppg Footage-266' WOB 5/8 k RPM 130 GPM 200 @ 1840 psi String wt. PU 260 SO 150 ROT 190 Torque on/off btm.-11,000/10,000 ft/lbs Lost 230 bbls to formation last 12 hrs. Reviewed PIR from Nordic 3 concerning mashed fingers. 12:00 17:15 5.25 15,785 16,004 PROD1 DRILL DDRL P Drilled 6 1/8"hole w/GP from 15785' to 16004'MD 7448'ND ADT-4.19 hrs. ECD-11.07 ppg Footage-219' WOB 8/12 k RPM 130 GPM 200 @ 2040 psi String wt. PU 248 SO 150 ROT 192 Torque on/off btm.-11,500/10,000 ft/lb Lost 283 bbls to formation last 12 hrs. Total losses last 24 hrs.-513 bbls Total losses to date-2929 bbls 9.0 ppg Flo Pro 17:15 18:45 1.50 16,004 16,004 PROD1 DRILL CIRC P CBU @ 200 gpm, 1940 psi,90 rpm, ECD=10.82 ppg EMW Page 28 of 31 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 18:45 19:00 0.25 16,004 16,004 PROD1 DRILL OWFF P Monitor well-fluid level dropping 19:00 21:00 2.00 16,004 15,042 PROD1 DRILL TRIP P Back ream out of the hole from 16004'to 15042'@ 200 gpm @ 1760 psi w/90 rpm's-Torque 9 k-ECD's 10.69 ppg 21:00 00:00 3.00 15,042 13,134 PROD1 DRILL TRIP P POOH w/pump f/15,042'to 13,134'- 200 gpm @ 1700 psi-PU wt.230 09/05/2010 Finished POOH and laid down BHA. Tested BOPE with 4-1/2"test joint. Rigged up and started running 4-1/2"production tubing 00:00 02:30 2.50 13,134 11,418 PROD1 DRILL TRIP P Cont. POOH f/13,134'to 11,418'w/ pump @ 200 gpm @ 1550 psi-PU wt.225 SO wt. 145 02:30 03:30 1.00 11,418 11,418 PROD1 DRILL CIRC P Circ btms up @ 200 gpm @ 1550 psi 03:30 03:45 0.25 11,418 11,418 PROD1 DRILL OWFF P Monitor well-Static 03:45 05:15 1.50 11,418 11,418 PROD1 DRILL CIRC P Displace well f/9.0 ppg Flo Pro to 9.2 ppg brine-210 gpm @ 1250 psi w/90 rpm's torque 9 k 05:15 05:45 0.50 11,418 11,418 PROD1 DRILL OWFF P Blow down TD-Flow ck-well static -Monitor well on TT-no gain/no loss 05:45 07:45 2.00 11,418 11,418 PROD1 DRILL SFTY P Monitor well on TT-Shut down ops- Held Safety Stand Down in rig camp w/crew 07:45 08:15 0.50 11,418 11,418 PROD1 DRILL CIRC P Pump hi-vis pill-Spot 5 bbls out drill string @ 200 gpm @ 1170 psi 08:15 12:00 3.75 11,418 6,643 PROD1 DRILL TRIP P POOH on TT f/11,418'to 6643' 12:00 13:45 1.75 6,643 6,643 PROD1 DRILL SFTY P Monitor well on Trip Tank Shut down Op's Hold Safety Stand-down with DDI crew, MI,ASRC,Sperry. 13:45 16:30 2.75 6,643 352 PROD1 DRILL TRIP P Pull out of the hole on elevators from 6643'to 352'. Monitor well--static. Stand back 2 stands of HWDP 16:30 17:00 0.50 352 292 PROD1 DRILL PULD P Lay down two NMFC 17:00 17:30 0.50 292 292 PROD1 DRILL PULD P Plug in and download MWD. Break bit 17:30 18:30 1.00 292 0 PROD1 DRILL PULD P Continue laying down BHA 18:30 19:00 0.50 0 0 COMPZ WHDBOOTHR P Pull wear ring (? 19:00 20:30 1.50 0 0 COMPZ WHDBO BOPE P Spt test plug. Make up 4-1/2"test f 1 joint. Test annular to 250/2500 psi. Test both sets of pipe rams to 250/3500 psi. Pull test plug 20:30 21:00 0.50 0 0 COMPZ WHDBO OTHR P Set completion wear ring 21:00 21:30 0.50 0 0 COMPZ RPCOM RURD P Rig up tubing equipment 21:30 21:45 0.25 0 0 COMPZ RPCOM SFTY P Safety meeting on running tubing 21:45 00:00 2.25 0 850 COMPZ RPCOM RCST P Run in the hole with tubing.packer. WLEG,GLM to 850' Page 29 of 31 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 09/06/2010 24 hr Summary Finished running 4-1/2"completing including BAL-O nipple with dual control lines. Land tubing and test m/m seals to 5000 psi. Nippled down BOPE and nippled up Tree. Tested tree to 5000 psi for 15 minutes. Rigged up and displaced well with 110 bbl brine, 140 bbl inhibited brine and 194 bbl diesel. Rigged up lubricator and dropped ball&rod. Set packer with 4000 psi and tested tubing to 4000 psi for 30 minutes. Bled tubing pressure to 2000 psi 00:00 05:30 5.50 850 7,788 COMPZ RPCOM RCST P Continue running in the hole from 850'to 7788'. P/U=155k,5/0= 125k 05:30 06:45 1.25 7,788 7,788 COMPZ RPCOM PULD P Make up BAL-0 nipple and control lines. Test lines to 5000 psi for 10 minutes 06:45 09:45 3.00 7,788 9,945 COMPZ RPCOM RCST P Continue running in the hole from 7788'to 9945' P/U=283k,S/0= 128k 54 S/S bands used to attach control lines 09:45 10:15 0.50 9,945 9,945 COMPZ RPCOM PULL P Pull wear ring 10:15 12:00 1.75 9,945 9,945 COMPZ RPCOM THGR P Make up tubing hanger and terminate control lines. 12:00 13:45 1.75 9,945 9,945 COMPZ RPCOM THGR P Land hanger and run in lock-down screws. Test metal-to-metal seals to 5000 psi for 10 minutes 13:45 14:00 0.25 9,945 9,945 COMPZ WHDBO SFTY P Pre-job safety meeting on nippling down BOPE 14:00 17:00 3.00 9,945 0 COMPZ WHDBO NUND P Nipple down BOPE; N/U Tree 17:00 18:00 1.00 0 0 COMPZ WHDBO PRTS P Test tree to 5000 psi for 15 minutes 18:00 18:45 0.75 0 0 COMPZ WHDBO RURD P Pull two-way check via FMC lubricator 18:45 19:15 0.50 0 0 COMPZ WELLPF RURD P Rig up hardline and squeeze manifold 19:15 19:30 0.25 0 0 COMPZ DRILL SFTY P Pre-job safety meeting on displacing 19:30 19:45 0.25 0 0 COMPZ DRILL PRTS P Fill lines and pressure test to 5000 psi with cement unit 19:45 22:15 2.50 0 0 COMPZ DRILL CIRC P Displace with 110 bbl brine, 140 bbl inhibited brine and 140 bbl diesel. 22:15 23:00 0.75 0 0 COMPZ DRILL RURD P Bleed tubing pressure off and rig up lubricator. Drop ball&rod 23:00 00:00 1.00 0 0 COMPZ DRILL PRTS P Pressure up on tubing to 4000 psi. Set packer. Test packer and tubing to 4000 psi for 30 minutes. Bled tubing pressure to 2000 psi 09/07/2010 Pressure Test IA t/3500 Psi f/30 Minutes-Shear DCK Valve-Set BPV-Secure Well-L/D 4"DP and HWDP-Reposition Remaining DP in the Derrick for Move-Prep Rig for Move SITP 1800 Psi, IA 1000 Psi *SIMOPS*Move Ball Mill Rig Released @ Midnight 00:00 00:45 0.75 0 0 COMPZ DRILL PRTS P Pressure Test IA to 3500 Psi f/20 Minutes-Bleed Tubing Pressure of Shear DCK Valve-SITP 1800 Psi/ IA 1,000 Psi 00:45 01:30 0.75 0 0 COMPZ DRILL RURD P Flush&Blow Down Surface Lines- R/D Manifold and Hard Lines Page 30 of 31 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 01:30 02:00 0.50 0 0 COMPZ DRILL MPSP P Test Lubricator t/2800 Psi-Set BPV 02:00 02:30 0.50 0 0 COMPZ DRILL OTHR P Secure Well 02:30 02:45 0.25 0 0 COMPZ DRILL SFTY P PJSM on Laying Down Drill Pipe& Installing the Mouse Hole 02:45 04:30 1.75 0 0 COMPZ DRILL PULD P Install Mouse Hole and L/D 4"DP 04:30 05:00 0.50 0 0 COMPZ RIGMNT SVRG P Service Rig 05:00 16:45 11.75 0 0 COMPZ DRILL PULD P Continue to L/D 4"DP via the Mouse Hole 16:45 17:15 0.50 0 0 COMPZ RIGMNTSVRG P Service Rig 17:15 21:30 4.25 0 0 COMPZ DRILL PULD P Continue to L/D 4"DP via the Mouse Hole(Total 174 Stds 4"DP and 2 Stds of 4"HWDP) 21:30 23:00 1.50 0 0 COMPZ DRILL OTHR P Reposition 40 Stds of DP in the Derrick for Rig Move 23:00 00:00 1.00 0 0 COMPZ DRILL DMOB P Clean&Clear Rig Floor-Release Rig at Midnight Page 31 of 31 CD4-12 Post Rig Well Summary DATE SUMMARY 9/9/10 JARRED 70 MIN TO FREE ISO SLEEVE @ 2177' RKB FROM BAL-O NIPPLE; NO GO& PKG DEEPLY SCARRED. PULLED BALL& ROD FROM RHC @ 9894' RKB. MEASURED BHP @ 9882' SLM: 3115.49 PSI /TEMP 150.12. DRIFTED THROUGH BAL-O NIPPLE WITH 3.805"GAUGE; LIGHT MARKS ON GAUGE RING. IN PROGRESS. 9/10/10 RAN 3.625" MAGNET TO 9894' RKB; RECOVERED FINE MEDAL SHAVINGS. PULLED SOV @ 9721' RKB; SET HES SPG @ SAME. PULLED DV @ 7458' RKB, SET 1/4" PORT OV @ SAME. PULLED RHC PLUG BODY @ 9894' RKB. ATTEMPTED SET 3.812 DB LOCK @ 2177' RKB. PULLED 3.812 DB LOCK @ SAME: EVEN WEAR AROUND NO GO, TWO SCARS IN NO GO. IN PROGRESS. 9/11/10 SWAGE OUT TIGHT SPOT @ 2150' SLM TO 3.81". ATTEMPTED SET 3.812 DB LOCK IN BAL-O NIPPLE @ 2177' RKB, NO SUCCESS. SET 2.75" ID ISO SLEEVE @ 2177' RKB. JOB SUSPENDED FOR FLOW BACK OPERATIONS. s ConocoPhilli Alaska p � ) Inc. Western North Slope CD4 Nanuq Pad CD4-12 r , , eilling Definitive Survey Report 14 September, 2010 1 � 1 HALLIBURTON Sperry e r#UUin X11 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD4-12 Project Western North Slope TVD Reference: CD4-12 @ 55.68ft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-12 @ 55.68ft(Doyon 19) Well: CD4-12 North Reference: True Wellbore: CD4-12 Survey Calculation Method: Minimum Curvature Design: CD4-12 Database: EDM Alaska Prod v16 Project Western North Slope 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 CD4-12 'Well Position +N/-S 0.00 ft Northing: 5,957,475.10 ft Latitude: 70°17'32.430 N +E/-W 0.00 ft Easting: 377,960.89 ft Longitude: 150°59'16.970 W 'Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.60ft Wellbore CD4-12 Magnetics Model Name Sample Date Declination Dip Angle Field Strength CI l°) (nT) BGGM2009 8/15/2010 16.49 79.63 57,337 Design CD4-12 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 15,395.32 'Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) r) 36.08 0.00 0.00 182.74 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 116.98 2,831.27 Nanuq 5(Nanuq 5) MWD MWD-Standard 7/12/2002 12:C 2,920.00 5,246.84 MWD Run 100(CD4-12PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/11/2010 12:C 5,282.96 11,480.61 MWD Run 200(CD4-12PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/19/2010 12:C 11,579.16 15,395.32 MWD Run 300(CD4-12PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/30/2010 12:C 15,481.00 16,004.00 MWD Run 500(CD4-12) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/7/2010 12:00 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.08 0.00 0.00 36.08 -19.60 0.00 0.00 5,957,475.10 377,960.89 0.00 0.00 UNDEFINED 116.98 0.00 0.00 116.98 61.30 0.00 0.00 5,957,475.10 377,960.89 0.00 0.00 MWD(1) 205.89 0.95 74.52 205.89 150.21 0.20 0.71 5,957,475.29 377,961.60 1.07 -0.23 MWD(1) 299.00 1.19 71.97 298.98 243.30 0.70 2.37 5,957,475.76 377,963.27 0.26 -0.81 MWD(1) 388.21 1.05 79.43 388.17 332.49 1.14 4.06 5,957,476.17 377,964.96 0.23 -1.33 MWD(1) 478.49 1.52 113.89 478.43 422.75 0.81 5.97 5,957,475.81 377,966.86 0.98 -1.09 MWD(1) 568.28 3.62 155.51 568.13 512.45 -2.26 8.23 5,957,472.71 377,969.08 2.99 1.86 MWD(1) 658.90 5.90 171.16 658.44 602.76 -9.46 10.13 5,957,465.47 377,970.86 2.87 8.97 MWD(1) 748.70 7.38 167.31 747.63 691.95 -19.65 12.11 5,957,455.26 377,972.67 1.72 19.05 MWD(1) 834.96 10.06 166.34 832.89 777.21 -32.38 15.11 5,957,442.48 377,975.46 3.11 31.62 MWD(1) 9/14/2010 3:24:56PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD4-12 Project Western North Slope TVD Reference: CD4-12 @ 55.68ft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-12©55.68ft(Doyon 19) Well: CD4-12 North Reference: True Wellbore: CD4-12 Survey Calculation Method: Minimum Curvature Design: CD4-12 Database: EDM Alaska Prod v16 1 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 928.61 13.61 165.00 924.53 868.85 -50.98 19.89 5,957,423.81 377,979.95 3.80 49.97 MWD(1) 1,020.99 16.94 165.48 1,013.64 957.96 -74.51 26.08 5,957,400.18 377,985.75 3.61 73.18 MWD(1) 1,115.89 18.39 164.82 1,104.06 1,048.38 -102.34 33.47 5,957,372.24 377,992.68 1.54 100.63 MWD(1) 1,208.06 20.29 164.28 1,191.02 1,135.34 -131.76 41.60 5,957,342.69 378,000.34 2.07 129.62 MWD(1) 1,302.47 22.20 162.33 1,279.02 1,223.34 -164.52 51.45 5,957,309.78 378,009.66 2.16 161.87 MWD(1) 1 312.19 -201.89 63.48 5 957 272.2 378 021.08 3.38 198.63 MWD(1) 1,399.63 25.48 162.01 1,367.87 2 1,497.80 28.87 161.21 1,455.19 1,399.51 -244.43 77.64 5,957,229.47 378,034.55 3.47 240.44 MWD(1) 1,594.71 30.33 160.93 1,539.45 1,483.77 -289.70 93.17 5,957,183.95 378,049.34 1.51 284.92 MWD(1) 1,689.39 32.99 162.75 1,620.04 1,564.36 -336.92 108.63 5,957,136.49 378,064.03 2.98 331.35 MWD(1) 1,784.60 36.54 163.12 1,698.24 1,642.56 -388.82 124.55 5,957,084.35 378,079.10 3.74 382.42 MWD(1) I 1,879.42 40.02 163.05 1,772.66 1,716.98 -445.01 141.64 5,957,027.89 378,095.27 3.67 437.73 MWD(1) 1,972.06 43.95 161.96 1,841.51 1,785.83 -504.09 160.29 5,956,968.52 378,112.96 4.31 495.86 MWD(1) 2,069.99 47.25 161.62 1,910.02 1,854.34 -570.54 182.16 5,956,901.72 378,133.74 3.38 561.19 MWD(1) 2,164.97 49.95 163.81 1,972.83 1,917.15 -638.57 203.29 5,956,833.37 378,153.77 3.33 628.12 MWD(1) 2,259.76 52.56 163.63 2,032.15 1,976.47 -709.53 224.02 5,956,762.09 378,173.34 2.76 698.01 MWD(1) 2,354.76 54.61 163.02 2,088.54 2,032.86 -782.75 245.96 5,956,688.52 378,194.09 2.22 770.11 MWD(1) 2,451.30 56.24 161.66 2,143.33 2,087.65 -858.49 270.08 5,956,612.41 378,216.97 2.05 844.61 MWD(1) I 2,546.79 56.68 162.94 2,196.09 2,140.41 -934.31 294.28 5,956,536.21 378,239.93 1.21 919.18 MWD(1) 2,640.86 56.78 163.04 2,247.69 2,192.01 -1,009.52 317.29 5,956,460.65 378,261.72 0.14 993.21 MWD(1) 2,737.15 56.59 163.11 2,300.58 2,244.90 -1,086.50 340.71 5,956,383.30 378,283.89 0.21 1,068.98 MWD(1) 2,831.27 57.29 161.84 2,351.93 2,296.25 -1,161.72 364.47 5,956,307.71 378,306.42 1.35 1,142.98 MWD(1) 2,920.00 56.50 162.10 2,400.39 i 2,344.71 -1,232.39 387.47 5,956,236.68 378,328.27 0.92 1,212.48 MWD+IFR-AK-CAZ-SC(2) 2,967.27 55.80 161.42 2,426.72 2,371.04 -1,269.68 399.76 5,956,199.20 378,339.95 1.90 1,249.13 MWD+IFR-AK-CAZ-SC(2) 3,061.86 55.67 163.22 2,479.98 2,424.30 -1,344.15 423.50 5,956,124.36 378,362.48 1.58 1,322.39 MWD+IFR-AK-CAZ-SC(2) 3,157.54 52.53 165.16 2,536.08 2,480.40 -1,418.71 444.64 5,956,049.48 378,382.40 3.67 1,395.84 MWD+IFR-AK-CAZ-SC(2) 3,251.66 48.77 167.19 2,595.75 2,540.07 -1,489.35 462.06 5,955,978.57 378,398.67 4.33 1,465.58 MWD+IFR-AK-CAZ-SC(2) 3,343.54 47.15 171.42 2,657.29 2,601.61 -1,556.37 474.75 5,955,911.36 378,410.27 3.85 1,531.91 MWD+IFR-AK-CAZ-SC(2) 3,441.28 47.17 175.10 2,723.76 2,668.08 -1,627.52 483.15 5,955,840.09 378,417.52 2.76 1,602.57 MWD+IFR-AK-CAZ-SC(2) ' 3,534.61 45.75 180.47 2,788.07 2,732.39 -1,695.07 485.80 5,955,772.51 378,419.07 4.44 1,669.92 MWD+IFR-AK-CAZ-SC(2) 3,632.43 44.07 184.90 2,857.37 2,801.69 -1,764.02 482.61 5,955,703.63 378,414.76 3.63 1,738.95 MWD+IFR-AK-CAZ-SC(2) 3,725.36 44.21 189.21 2,924.07 2,868.39 -1,828.21 474.66 5,955,639.57 378,405.77 3.23 1,803.45 MWD+IFR-AK-CAZ-SC(2) 3,822.09 43.37 192.82 2,993.91 2,938.23 -1,893.90 461.89 5,955,574.11 378,391.94 2.72 1,869.67 MWD+IFR-AK-CAZ-SC(2) 3,917.07 42.80 198.90 3,063.31 3,007.63 -1,956.25 444.20 5,955,512.06 378,373.23 4.41 1,932.80 MWD+IFR-AK-CAZ-SC(2) 4,011.76 43.67 202.62 3,132.30 3,076.62 -2,016.88 421.20 5,955,451.82 378,349.25 2.84 1,994.45 MWD+IFR-AK-CAZ-SC(2) 4,105.14 45.08 205.98 3,199.06 3,143.38 -2,076.37 394.31 5,955,392.78 378,321.41 2.93 2,055.16 MWD+IFR-AK-CAZ-SC(2) 4,201.68 45.38 211.16 3,267.07 3,211.39 -2,136.51 361.55 5,955,333.18 378,287.68 3.82 2,116.80 MWD+IFR-AK-CAZ-SC(2) 4,296.09 45.67 211.98 3,333.22 3,277.54 -2,193.91 326.28 5,955,276.37 378,251.48 0.69 2,175.82 MWD+IFR-AK-CAZ-SC(2) 4,392.23 45.53 215.58 3,400.49 3,344.81 -2,250.98 288.10 5,955,219.92 378,212.39 2.68 2,234.65 MWD+IFR-AK-CAZ-SC(2) 4,485.27 43.74 221.44 3,466.72 3,411.04 -2,302.12 247.48 5,955,169.46 378,170.94 4.82 2,287.67 MWD+IFR-AK-CAZ-SC(2) 4,581.82 43.95 223.06 3,536.36 3,480.68 -2,351.62 202.51 5,955,120.69 378,125.18 1.18 2,339.26 MWD+IFR-AK-CAZ-SC(2) 9/14/2010 3:24:56PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD4-12 Project Western North Slope TVD Reference: CD4-12 @ 55.68ft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-12 @ 55.68ft(Doyon 19) Well: CD4-12 North Reference: True Wellbore: CD4-12 Survey Calculation Method: Minimum Curvature Design: CD4-12 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N!S +E/-W Northing Easting DLS Section (ft) (°) C) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,677.19 43.76 228.15 3,605.15 3,549.47 -2,397.82 155.33 5,955,075.27 378,077.26 3.70 2,387.66 MWD+IFR-AK-CAZ-SC(2) 4,771.81 44.97 233.36 3,672.82 3,617.14 -2,439.62 104.11 5,955,034.31 378,025.37 4.06 2,431.86 MWD+IFR-AK-CAZ-SC(2) 4,867.04 44.40 237.95 3,740.54 3,684.86 -2,477.40 48.86 5,954,997.44 377,969.52 3.44 2,472.23 MWD+IFR-AK-CAZ-SC(2) 4,961.47 45.08 236.77 3,807.62 3,751.94 -2,513.25 -7.11 5,954,962.51 377,912.98 1.14 2,510.72 MWD+IFR-AK-CAZ-SC(2) 5,056.79 45.19 236.22 3,874.86 3,819.18 -2,550.54 -63.44 5,954,926.14 377,856.06 0.42 2,550.66 MWD+IFR-AK-CAZ-SC(2) 5,151.59 44.72 237.01 3,941.95 3,886.27 -2,587.40 -119.37 5,954,890.19 377,799.54 0.77 2,590.15 MWD+IFR-AK-CAZ-SC(2) 5,246.84 44.47 236.66 4,009.77 3,954.09 -2,623.98 -175.35 5,954,854.53 377,742.98 0.37 2,629.36 MWD+IFR-AK-CAZ-SC(2) 5,282.96 44.53 237.08 4,035.54 3,979.86 -2,637.82 -196.55 5,954,841.04 377,721.56 0.83 2,644.20 MWD+IFR-AK-CAZ-SC(3) 5,375.88 44.67 237.55 4,101.70 4,046.02 -2,673.05 -251.46 5,954,806.70 377,666.09 0.39 2,682.01 MWD+IFR-AK-CAZ-SC(3) 5,473.95 44.28 236.61 4,171.68 4,116.00 -2,710.39 -309.14 5,954,770.31 377,607.82 0.78 2,722.06 MWD+IFR-AK-CAZ-SC(3) 5,564.74 45.42 235.99 4,236.04 4,180.36 -2,745.92 -362.40 5,954,735.65 377,553.99 1.34 2,760.10 MWD+IFR-AK-CAZ-SC(3) 5,663.95 45.35 237.38 4,305.72 4,250.04 -2,784.70 -421.42 5,954,697.83 377,494.36 1.00 2,801.66 MWD+IFR-AK-CAZ-SC(3) 5,755.63 45.18 237.06 4,370.25 4,314.57 -2,819.97 -476.17 5,954,663.47 377,439.04 0.31 2,839.49 MWD+IFR-AK-CAZ-SC(3) 5,852.80 44.90 237.40 4,438.91 4,383.23 -2,857.18 -533.99 5,954,627.20 377,380.63 0.38 2,879.43 MWD+IFR-AK-CAZ-SC(3) 5,949.80 44.73 237.69 4,507.72 4,452.04 -2,893.87 -591.68 5,954,591.46 377,322.36 0.27 2,918.83 MWD+IFR-AK-CAZ-SC(3) 6,044.14 44.66 239.56 4,574.79 4,519.11 -2,928.41 -648.32 5,954,557.84 377,265.17 1.40 2,956.04 MWD+IFR-AK-CAZ-SC(3) 6,139.70 44.47 239.50 4,642.87 4,587.19 -2,962.42 -706.12 5,954,524.78 377,206.83 0.20 2,992.77 MWD+IFR-AK-CAZ-SC(3) 6,234.52 45.41 239.79 4,709.99 4,654.31 -2,996.26 -763.91 5,954,491.88 377,148.50 1.01 3,029.34 MWD+IFR-AK-CAZ-SC(3) 6,329.15 45.33 238.96 4,776.47 4,720.79 -3,030.57 -821.86 5,954,458.52 377,090.01 0.63 3,066.37 MWD+IFR-AK-CAZ-SC(3) 6,424.08 44.88 238.17 4,843.47 4,787.79 -3,065.64 -879.24 5,954,424.39 377,032.07 0.76 3,104.14 MWD+IFR-AK-CAZ-SC(3) 6,519.08 44.54 237.15 4,910.99 4,855.31 -3,101.39 -935.71 5,954,389.57 376,975.04 0.84 3,142.55 MWD+IFR-AK-CAZ-SC(3) 6,613.54 44.52 236.97 4,978.33 4,922.65 -3,137.41 -991.30 5,954,354.46 376,918.87 0.14 3,181.19 MWD+IFR-AK-CAZ-SC(3) 6,709.55 45,19 236.96 5,046.39 4,990.71 -3,174.32 -1,048.07 5,954,318.47 376,861.51 0.70 3,220.77 MWD+IFR-AK-CAZ-SC(3) 6,803.72 44.97 237.66 5,112.88 5,057.20 -3,210.34 -1,104.19 5,954,283.38 376,804.82 0.58 3,259.43 MWD+IFR-AK-CAZ-SC(3) 6,899.89 44.55 236.82 5,181.17 5,125.49 -3,246.98 -1,161.14 5,954,247.67 376,747.29 0.75 3,298.75 MWD+IFR-AK-CAZ-SC(3) 6,994.93 44.09 237.27 5,249.16 5,193.48 -3,283.10 -1,216.85 5,954,212.46 376,691.00 0.59 3,337.49 MWD+IFR-AK-CAZ-SC(3) 7,090.33 45.27 237.30 5,317.00 5,261.32 -3,319.35 -1,273.29 5,954,177.13 376,633.99 1.24 3,376.40 MWD+IFR-AK-CAZ-SC(3) 7,184.90 44.55 236.98 5,383.97 5,328.29 -3,355.58 -1,329.37 5,954,141.82 376,577.33 0.80 3,415.26 MWD+IFR-AK-CAZ-SC(3) 7,280.16 44.62 237.17 5,451.82 5,396.14 -3,391.93 -1,385.50 5,954,106.39 376,520.62 0.16 3,454.25 MWD+IFR-AK-CAZ-SC(3) 7,375.08 44.98 237.19 5,519.17 5,463.49 -3,428.18 -1,441.71 5,954,071.06 376,463.84 0.38 3,493.14 MWD+IFR-AK-CAZ-SC(3) 7,470.20 45.40 236.83 5,586.21 5,530.53 -3,464.92 -1,498.31 5,954,035.25 376,406.65 0.52 3,532.55 MWD+IFR-AK-CAZ-SC(3) 7,564.82 44.67 236.71 5,653.07 5,597.39 -3,501.61 -1,554.31 5,953,999.48 376,350.07 0.78 3,571.87 MWD+IFR-AK-CAZ-SC(3) 7,660.22 45.35 237.91 5,720.52 5,664.84 -3,538.04 -1,611.09 5,953,963.97 376,292.71 1.14 3,610.97 MWD+IFR-AK-CAZ-SC(3) 7,755.83 45.17 236.38 5,787.82 5,732.14 -3,574.88 -1,668.14 5,953,928.06 376,235.07 1.15 3,650.50 MWD+IFR-AK-CAZ-SC(3) 7,851.13 44.14 235.19 5,855.61 5,799.93 -3,612.54 -1,723.53 5,953,891.32 376,179.09 1.39 3,690.76 MWD+IFR-AK-CAZ-SC(3) 7,945.98 44.47 235.75 5,923.49 5,867.81 -3,650.09 -1,778.11 5,953,854.66 376,123.91 0.54 3,730.87 MWD+IFR-AK-CAZ-SC(3) 8,041.30 44.01 237.06 5,991.78 5,936.10 -3,686.89 -1,833.50 5,953,818.77 376,067.93 1.07 3,770.27 MWD+IFR-AK-CAZ-SC(3) 8,136.63 45.50 240.14 6,059.48 6,003.80 -3,721.83 -1,890.78 5,953,784.76 376,010.09 2.76 3,807.91 MWD+IFR-AK-CAZ-SC(3) 8,230.86 44.57 239.42 6,126.07 6,070.39 -3,755.38 -1,948.40 5,953,752.15 375,951.95 1.13 3,844.18 MWD+IFR-AK-CAZ-SC(3) 8,327.77 45.27 237.42 6,194.70 6,139.02 -3,791.22 -2,006.68 5,953,717.27 375,893.09 1.63 3,882.76 MWD+IFR-AK-CAZ-SC(3) 9/14/2010 3:24:56PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD4-12 Project Western North Slope TVD Reference: CD4-12 @ 55.68ft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-12 @ 55.68ft(Doyon 19) Well: CD4-12 North Reference: True Wellbore: CD4-12 Survey Calculation Method: Minimum Curvature Design: CD4-12 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,418.32 45.43 236.69 6,258.33 6,202.65 -3,826.25 -2,060.74 5,953,683.12 375,838.48 0.60 3,920.34 MWD+IFR-AK-CAZ-SC(3) 8,515.51 45.55 234.96 6,326.47 6,270.79 -3,865.18 -2,118.08 5,953,645.13 375,780.52 1.28 3,961.96 MWD+IFR-AK-CAZ-SC(3) 8,612.20 47.29 229.16 6,393.15 6,337.47 -3,908.25 -2,173.24 5,953,602.97 375,724.67 4.70 4,007.62 MWD+IFR-AK-CAZ-SC(3) 8,705.80 48.23 223.88 6,456.10 6,400.42 -3,955.92 -2,223.47 5,953,556.13 375,673.68 4.29 4,057.63 MWD+IFR-AK-CAZ-SC(3) 8,802.58 49.46 218.17 6,519.82 6,464.14 -4,010.87 -2,271.23 5,953,501.96 375,625.03 4.62 4,114.80 MWD+IFR-AK-CAZ-SC(3) 8,897.61 50.41 216.00 6,580.99 6,525.31 -4,068.89 -2,315.08 5,953,444.67 375,580.26 2.01 4,174.85 MWD+IFR-AK-CAZ-SC(3) 8,991.40 52.38 213.94 6,639.51 6,583.83 -4,128.95 -2,357.06 5,953,385.30 375,537.30 2.71 4,236.85 MWD+IFR-AK-CAZ-SC(3) 9,087.03 54.32 211.45 6,696.59 6,640.91 -4,193.52 -2,398.48 5,953,321.42 375,494.85 2.91 4,303.32 MWD+IFR-AK-CAZ-SC(3) 9,182.51 57.25 207.63 6,750.29 6,694.61 -4,262.20 -2,437.35 5,953,253.38 375,454.87 4.51 4,373.78 MWD+IFR-AK-CAZ-SC(3) 9,277.33 58.82 206.50 6,800.49 6,744.81 -4,333.84 -2,473.95 5,953,182.35 375,417.12 1.94 4,447.08 MWD+IFR-AK-CAZ-SC(3) 9,371.88 60.76 204.97 6,848.06 6,792.38 -4,407.44 -2,509.41 5,953,109.34 375,380.47 2.48 4,522.29 MWD+IFR-AK-CAZ-SC(3) 9,466.91 62.77 203.43 6,893.02 6,837.34 -4,483.80 -2,543.72 5,953,033.55 375,344.93 2.55 4,600.21 MWD+IFR-AK-CAZ-SC(3) 9,562.23 64.69 203.44 6,935.21 6,879.53 -4,562.22 -2,577.71 5,952,955.70 375,309.67 2.01 4,680.16 MWD+IFR-AK-CAZ-SC(3) 9,657.57 66.45 202.53 6,974.64 6,918.96 -4,642.13 -2,611.60 5,952,876.36 375,274.49 2.04 4,761.60 MWD+IFR-AK-CAZ-SC(3) 9,752.65 66.86 200.98 7,012.32 6,956.64 -4,723.21 -2,643.95 5,952,795.83 375,240.83 1.56 4,844.13 MWD+IFR-AK-CAZ-SC(3) 9,847.47 68.07 199.04 7,048.66 6,992.98 -4,805.50 -2,673.91 5,952,714.04 375,209.54 2.28 4,927.76 MWD+IFR-AK-CAZ-SC(3) 9,943.01 69.06 195.32 7,083.58 7,027.90 -4,890.44 -2,700.17 5,952,629.54 375,181.91 3.77 5,013.86 MWD+IFR-AK-CAZ-SC(3) 10,037.54 71.29 190.81 7,115.66 7,059.98 -4,977.04 -2,720.24 5,952,543.29 375,160.44 5.07 5,101.32 MWD+IFR-AK-CAZ-SC(3) 10,086.77 71.29 188.11 7,131.45 7,075.77 -5,023.03 -2,727.90 5,952,497.43 375,152.03 5.19 5,147.62 MWD+IFR-AK-CAZ-SC(3) 10,129.76 71.28 186.54 7,145.24 7,089.56 -5,063.41 -2,733.09 5,952,457.14 375,146.19 3.46 5,188.21 MWD+IFR-AK-CAZ-SC(3) 10,228.31 73.03 183.27 7,175.45 7,119.77 -5,156.86 -2,741.10 5,952,363.84 375,136.67 3.62 5,281.93 MWD+IFR-AK-CAZ-SC(3) 10,320.75 74.19 181.11 7,201.54 7,145.86 -5,245.47 -2,744.48 5,952,275.31 375,131.84 2.57 5,370.60 MWD+IFR-AK-CAZ-SC(3) 10,416.99 75.21 177.35 7,226.94 7,171.26 -5,338.27 -2,743.23 5,952,182.51 375,131.59 3.91 5,463.24 MWD+IFR-AK-CAZ-SC(3) 10,510.76 76.24 173.19 7,250.07 7,194.39 -5,428.81 -2,735.73 5,952,091.86 375,137.62 4.44 5,553.32 MWD+IFR-AK-CAZ-SC(3) 10,608.09 77.37 170.54 7,272.29 7,216.61 -5,522.61 -2,722.32 5,951,997.87 375,149.51 2.89 5,646.36 MWD+IFR-AK-CAZ-SC(3) 10,697.93 79.08 166.00 7,290.63 7,234.95 -5,608.69 -2,704.43 5,951,911.51 375,165.99 5.30 5,731.49 MWD+IFR-AK-CAZ-SC(3) 10,756.02 79.71 165.54 7,301.32 7,245.64 -5,664.04 -2,690.40 5,951,855.95 375,179.13 1.33 5,786.11 MWD+IFR-AK-CAZ-SC(3) 10,795.81 80.52 165.08 7,308.16 7,252.48 -5,701.95 -2,680.45 5,951,817.88 375,188.45 2.33 5,823.50 MWD+IFR-AK-CAZ-SC(3) 10,889.73 82.20 160.75 7,322.27 7,266.59 -5,790.68 -2,653.18 5,951,728.73 375,214.28 4.90 5,910.83 MWD+IFR-AK-CAZ-SC(3) 10,985.34 82.45 160.39 7,335.04 7,279.36 -5,880.04 -2,621.66 5,951,638.88 375,244.34 0.46 5,998.58 MWD+IFR-AK-CAZ-SC(3) 11,082.89 84.44 157.89 7,346.18 7,290.50 -5,970.59 -2,587.15 5,951,547.79 375,277.38 3.26 6,087.37 MWD+IFR-AK-CAZ-SC(3) 11,177.90 85.12 157.22 7,354.82 7,299.14 -6,058.03 -2,551.02 5,951,459.78 375,312.07 1.00 6,172.99 MWD+IFR-AK-CAZ-SC(3) 11,273.27 84.51 157.26 7,363.44 7,307.76 -6,145.62 -2,514.28 5,951,371.62 375,347.39 0.64 6,258.72 MWD+IFR-AK-CAZ-SC(3) 11,368.12 83.02 157.81 7,373.74 7,318.06 -6,232.75 -2,478.25 5,951,283.92 375,381.99 1.67 6,344.03 MWD+IFR-AK-CAZ-SC(3) 11,461.83 86.86 158.59 7,382.00 7,326.32 -6,319.40 -2,443.59 5,951,196.72 375,415.24 4.18 6,428.93 MWD+IFR-AK-CAZ-SC(3) 11,480.61 87.85 158.04 7,382.87 7,327.19 -6,336.83 -2,436.66 5,951,179.18 375,421.88 6.03 6,446.01 MWD+IFR-AK-CAZ-SC(3) 11,579.16 87.84 157.24 7,386.58 7,330.90 -6,427.91 -2,399.20 5,951,087.52 375,457.86 0.81 6,535.19 MWD+IFR-AK-CAZ-SC(4) 11,675.80 88.83 156.98 7,389.38 7,333.70 -6,516.90 -2,361.62 5,950,997.94 375,493.98 1.06 6,622.29 MWD+IFR-AK-CAZ-SC(4) 11,769.29 89.69 157.31 7,390.59 7,334.91 -6,603.04 -2,325.32 5,950,911.22 375,528.88 0.99 6,706.60 MWD+IFR-AK-CAZ-SC(4) 11,866.31 89.45 152.85 7,391.32 7,335.64 -6,691.00 -2,284.45 5,950,822.62 375,568.32 4.60 6,792.51 MWD+IFR-AK-CAZ-SC(4) 9/14/2010 3:24:56PM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD4-12 Project Western North Slope TVD Reference: CD4-12 @ 55.68ft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-12 @ 55.68ft(Doyon 19) Well: CD4-12 North Reference: True Wellbore: CD4-12 Survey Calculation Method: Minimum Curvature Design: CD4-12 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (") (') (ft) (ft) (ft) (ft) (ft) (ft) (°H00') (ft) Survey Tool Name 11,920.62 89.69 148.76 7,391.73 7,336.05 -6,738.40 -2,257.96 5,950,774.80 375,594.03 7.54 6,838.59 MWD+IFR-AK-CAZ-SC(4) 11,962.66 88.71 146.55 7,392.32 7,336.64 -6,773.91 -2,235.47 5,950,738.93 375,615.93 5.75 6,872.98 MWD+IFR-AK-CAZ-SC(4) 12,013.42 89.14 144.99 7,393.27 7,337.59 -6,815.87 -2,206.93 5,950,696.52 375,643.79 3.19 6,913.53 MWD+IFR-AK-CAZ-SC(4) 12,060.75 88.64 144.17 7,394.18 7,338.50 -6,854.44 -2,179.50 5,950,657.52 375,670.59 2.03 6,950.74 MWD+IFR-AK-CAZ-SC(4) 12,109.16 88.70 144.31 7,395.31 7,339.63 -6,893.71 -2,151.22 5,950,617.79 375,698.23 0.31 6,988.61 MWD+IFR-AK-CAZ-SC(4) 12,152.38 88.71 144.48 7,396.29 7,340.61 -6,928.84 -2,126.06 5,950,582.26 375,722.81 0.39 7,022.50 MWD+IFR-AK-CAZ-SC(4) 12,247.95 89.26 147.18 7,397.98 7,342.30 -7,007.89 -2,072.40 5,950,502.35 375,775.17 2.88 7,098.90 MWD+IFR-AK-CAZ-SC(4) 12,343.36 89.08 149.00 7,399.36 7,343.68 -7,088.87 -2,021.97 5,950,420.57 375,824.27 1.92 7,177.38 MWD+IFR-AK-CAZ-SC(4) 12,439.06 88.65 150.69 7,401.26 7,345.58 -7,171.60 -1,973.91 5,950,337.08 375,870.98 1.82 7,257.72 MWD+IFR-AK-CAZ-SC(4) 12,534.36 89.20 154.49 7,403.04 7,347.36 -7,256.17 -1,930.06 5,950,251.82 375,913.46 4.03 7,340.10 MWD+IFR-AK-CAZ-SC(4) 12,630.24 88.83 156.87 7,404.69 7,349.01 -7,343.52 -1,890.58 5,950,163.84 375,951.51 2.51 7,425.46 MWD+IFR-AK-CAZ-SC(4) 12,724.80 89.51 156.81 7,406.06 7,350.38 -7,430.45 -1,853.39 5,950,076.33 375,987.28 0.72 7,510.52 MWD+IFR-AK-CAZ-SC(4) 12,820.16 90.06 156.58 7,406.42 7,350.74 -7,518.03 -1,815.67 5,949,988.16 376,023.57 0.63 7,596.19 MWD+IFR-AK-CAZ-SC(4) 12,916.67 90.37 156.51 7,406.06 7,350.38 -7,606.57 -1,777.25 5,949,899.02 376,060.54 0.33 7,682.79 MWD+IFR-AK-CAZ-SC(4) 13,009.87 90.87 159.20 7,405.05 7,349.37 -7,692.88 -1,742.13 5,949,812.15 376,094.26 2.94 7,767.33 MWD+IFR-AK-CAZ-SC(4) 13,104.08 89.14 157.98 7,405.04 7,349.36 -7,780.58 -1,707.74 5,949,723.91 376,127.21 2.25 7,853.29 MWD+IFR-AK-CAZ-SC(4) 13,201.21 90.99 156.58 7,404.93 7,349.25 -7,870.17 -1,670.22 5,949,633.73 376,163.26 2.39 7,940.98 MWD+IFR-AK-CAZ-SC(4) ' 13,296.53 91.73 155.59 7,402.67 7,346.99 -7,957.28 -1,631.60 5,949,546.01 376,200.47 1.30 8,026.14 MWD+IFR-AK-CAZ-SC(4) 13,392.16 91.30 154.46 7,400.14 7,344.46 -8,043.94 -1,591.23 5,949,458.72 376,239.42 1.26 8,110.77 MWD+IFR-AK-CAZ-SC(4) 13,486.55 89.20 155.01 7,399.73 7,344.05 -8,129.29 -1,550.95 5,949,372.73 376,278.31 2.30 8,194.11 MWD+IFR-AK-CAZ-SC(4) 13,582.98 91.12 153.51 7,399.46 7,343.78 -8,216.15 -1,509.08 5,949,285.22 376,318.76 2.53 8,278.86 MWD+IFR-AK-CAZ-SC(4) 13,678.10 91.49 153.08 7,397.29 7,341.61 -8,301.10 -1,466.34 5,949,199.59 376,360.11 0.60 8,361.67 MWD+IFR-AK-CAZ-SC(4) 13,772.76 91.06 153.90 7,395.19 7,339.51 -8,385.78 -1,424.10 5,949,114.24 376,400.97 0.98 8,444.24 MWD+IFR-AK-CAZ-SC(4) 13,869.11 89.69 153.17 7,394.56 7,338.88 -8,472.03 -1,381.16 5,949,027.31 376,442.49 1.61 8,528.34 MWD+IFR-AK-CAZ-SC(4) 13,964.12 89.82 149.77 7,394.96 7,339.28 -8,555.49 -1,335.79 5,948,943.13 376,486.50 3.58 8,609.54 MWD+IFR-AK-CAZ-SC(4) 14,059.76 90.93 150.35 7,394.34 7,338.66 -8,638.36 -1,288.06 5,948,859.50 376,532.88 1.31 8,690.04 MWD+IFR-AK-CAZ-SC(4) 14,154.71 89.94 151.49 7,393.62 7,337.94 -8,721.34 -1,241.91 5,948,775.79 376,577.67 1.59 8,770.71 MWD+IFR-AK-CAZ-SC(4) 14,250.37 89.45 151.42 7,394.13 7,338.45 -8,805.37 -1,196.20 5,948,691.04 376,622.00 0.52 8,852.47 MWD+IFR-AK-CAZ-SC(4) 14,346.43 90.00 152.79 7,394.59 7,338.91 -8,890.27 -1,151.26 5,948,605.43 376,665.56 1.54 8,935.12 MWD+IFR-AK-CAZ-SC(4) 14,441.45 89,02 154.58 7,395.40 7,339.72 -8,975.43 -1,109.14 5,948,519.60 376,706.28 2.15 9,018.17 MWD+IFR-AK-CAZ-SC(4) 14,536.68 89.20 156.68 7,396.88 7,341.20 -9,062.16 -1,069.86 5,948,432.25 376,744.15 2.21 9,102.93 MWD+IFR-AK-CAZ-SC(4) 14,631.94 88.89 158.68 7,398.47 7,342.79 -9,150.27 -1,033.69 5,948,343.58 376,778.89 2.12 9,189.20 MWD+IFR-AK-CAZ-SC(4) 14,727.30 89.57 159.02 7,399.75 7,344.07 -9,239.19 -999.28 5,948,254.11 376,811.84 0.80 9,276.39 MWD+IFR-AK-CAZ-SC(4) 14,821.91 89.20 157.93 7,400.76 7,345.08 -9,327.20 -964.57 5,948,165.56 376,845.11 1.22 9,362.63 MWD+IFR-AK-CAZ-SC(4) 14,917.63 88.95 157.34 7,402.31 7,346.63 -9,415.71 -928.15 5,948,076.48 376,880.09 0.67 9,449.30 MWD+IFR-AK-CAZ-SC(4) ' 15,013.95 88.83 156.64 7,404.17 7,348.49 -9,504.35 -890.51 5,947,987.25 376,916.28 0.74 9,536.04 MWD+IFR-AK-CAZ-SC(4) 15,109.49 88.71 157.52 7,406.23 7,350.55 -9,592.32 -853.31 5,947,898.69 376,952.05 0.93 9,622.14 MWD+IFR-AK-CAZ-SC(4) 15,204.11 89.51 158.62 7,407.70 7,352.02 -9,680.08 -817.98 5,947,810.37 376,985.95 1.44 9,708.11 MWD+IFR-AK-CAZ-SC(4) 15,298.87 89.45 157.67 7,408.56 7,352.88 -9,768.03 -782.71 5,947,721.88 377,019.78 1.00 9,794.27 MWD+IFR-AK-CAZ-SC(4) 15,395.29 89.14 157.44 7,409.74 7,354.06 -9,857.14 -745.90 5,947,632.19 377,055.14 0.40 9,881.52 MWD+IFR-AK-CAZ-SC(4) 9/14/2010 3:24:56PM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD4-12 Project Western North Slope TVD Reference: CD4-12©55.68ft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-12©55.68ft(Doyon 19) Well: CD4-12 North Reference: True Wellbore: CD4-12 Survey Calculation Method: Minimum Curvature Design: CD4-12 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (1 (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 15,481.00 89.64 156.62 7,410.65 7,354.97 -9,936.05 -712.45 5,947,552.75 377,087.30 1.12 9,958.74 MWD+IFR-AK-CAZ-SC(5) 15,549.10 86.54 156.72 7,412.92 7,357.24 -9,998.54 -685.50 5,947,489.84 377,113.23 4.55 10,019.87 MWD+IFR-AK-CAZ-SC(5) 15,645.10 86.35 155.85 7,418.88 7,363.20 -10,086.26 -646.96 5,947,401.51 377,150.33 0.93 10,105.65 MWD+IFR-AK-CAZ-SC(5) 15,738.95 85.30 155.64 7,425.71 7,370.03 -10,171.60 -608.51 5,947,315.57 377,187.39 1.14 10,189.05 MWD+IFR-AK-CAZ-SC(5) 15,835.76 85.11 155.33 7,433.80 7,378.12 -10,259.37 -568.48 5,947,227.16 377,225.98 0.37 10,274.82 MWD+IFR-AK-CAZ-SC(5) 15,930.96 85.12 155.05 7,441.91 7,386.23 -10,345.47 -528.68 5,947,140.43 377,264.38 0.29 10,358.91 MWD+IFR-AK-CAZ-SC(5) 16,004.00 85.12 155.05 7,448.12 7,392.44 -10,411.45 -497.98 5,947,073.97 377,294.00 0.00 10,423.36 MWD+IFR-AK-CAZ-SC(5) 9/14/2010 3:24:56PM Page 7 COMPASS 2003.16 Build 69 1 ConocoPhillips(Alaska) Inc. Western North Slope CD4 Nanuq Pad CD4-12PB1 Sperry ,... rilling Definitive Survey Report 14 September, 2010 HALLIBURTON j Sperry Drilling ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD4-12 Project Western North Slope TVD Reference: CD4-12©55.68ft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-12©55.68ft(Doyon 19) Well: CD4-12 North Reference: True Wellbore: CD4-12PB1 Survey Calculation Method: Minimum Curvature Design: CD4-12PB1 Database: EDM Alaska Prod v16 Project Western North Slope 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 CD4-12 I Well Position +N/-S 0.00 ft Northing: 5,957,475.10 ft Latitude: 70°17'32.430 N +E/-VV 0.00 ft Easting: 377,960.89 ft Longitude: 150°59'16.970 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.60ft Wellbore CD4-12PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°l (°) (nT) BGGM2009 8/15/2010 16.49 79.63 57,337 Design CD4-12PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 2,831.27 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction I (ft) (ft) (ft) r) 36.08 0.00 0.00 154.00 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 116.98 2,831.27 Nanuq 5(Nanuq 5) MWD MWD-Standard 7/12/2002 12:C 2,920.00 5,246.84 MWD Run 100(CD4-12PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/11/2010 12:C 5,282.96 11,480.61 MWD Run 200(CD4-12PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/19/2010 12:C 11,579.16 15,747.29 MWD Run 300(CD4-12PB1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8/30/2010 12:C 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 36.08 0.00 0.00 36.08 -19.60 0.00 0.00 5,957,475.10 377,960.89 0.00 0.00 UNDEFINED 116.98 0.00 0.00 116.98 61.30 0.00 0.00 5,957,475.10 377,960.89 0.00 0.00 MWD(1) 205.89 0.95 74.52 205.89 150.21 0.20 0.71 5,957,475.29 377,961.60 1.07 0.13 MWD(1) 299.00 1.19 71.97 298.98 243.30 0.70 2.37 5,957,475.76 377,963.27 0.26 0.41 MWD(1) 388.21 1.05 79.43 388.17 332.49 1.14 4.06 5,957,476.17 377,964.96 0.23 0.76 MWD(1) 478.49 1.52 113.89 478.43 422.75 0.81 5.97 5,957,475.81 377,966.86 0.98 1.89 MWD(1) 568.28 3.62 155.51 568.13 512.45 -2.26 8.23 5,957,472.71 377,969.08 2.99 5.64 MWD(1) 658.90 5.90 171.16 658.44 602.76 -9.46 10.13 5,957,465.47 377,970.86 2.87 12.95 MWD(1) 748.70 7.38 167.31 747.63 691.95 -19.65 12.11 5,957,455.26 377,972.67 1.72 22.97 MWD(1) 834.96 10.06 166.34 832.89 777.21 -32.38 15.11 5,957,442.48 377,975.46 3.11 35.72 MWD(1) 928.61 13.61 165.00 924.53 868.85 -50.98 19.89 5,957,423.81 377,979.95 3.80 54.54 MWD(1) 9/14/2010 3:18:37PM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD4-12 Project Western North Slope TVD Reference: CD4-12 @ 55.68ft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-12 @ 55.68ft(Doyon 19) Well: CD4-12 North Reference: True Wellbore: CD4-12PB1 Survey Calculation Method: Minimum Curvature Design: CD4-12PB1 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (f) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,020.99 16.94 165.48 1,013.64 957.96 -74.51 26.08 5,957,400.18 377,985.75 3.61 78.40 MWD(1) 1,115.89 18.39 164.82 1,104.06 1,048.38 -102.34 33.47 5,957,372.24 377,992.68 1.54 106.66 MWD(1) 1,208.06 20.29 164.28 1,191.02 1,135.34 -131.76 41.60 5,957,342.69 378,000.34 2.07 136.66 MWD(1) 1,302.47 22.20 162.33 1,279.02 1,223.34 -164.52 51.45 5,957,309.78 378,009.66 2.16 170.42 MWD(1) 1,399.63 25.48 162.01 1,367.87 1,312.19 -201.89 63.48 5,957,272.22 378,021.08 3.38 209.29 MWD(1) 1,497.80 28.87 161.21 1,455.19 1,399.51 -244.43 77.64 5,957,229.47 378,034.55 3.47 253.72 MWD(1) 1,594.71 30.33 160.93 1,539.45 1,483.77 -289.70 93.17 5,957,183.95 378,049.34 1.51 301.23 MWD(1) 1,689.39 32.99 162.75 1,620.04 1,564.36 -336.92 108.63 5,957,136.49 378,064.03 2.98 350.44 MWD(1) 1,784.60 36.54 163.12 1,698.24 1,642.56 -388.82 124.55 5,957,084.35 378,079.10 3.74 404.07 MWD(1) 1,879.42 40.02 163.05 1,772.66 1,716.98 -445.01 141.64 5,957,027.89 378,095.27 3.67 462.06 MWD(1) 1,972.06 43.95 161.96 1,841.51 1,785.83 -504.09 160.29 5,956,968.52 378,112.96 4.31 523.34 MWD(1) 2,069.99 47.25 161.62 1,910.02 1,854.34 -570.54 182.16 5,956,901.72 378,133.74 3.38 592.65 MWD(1) 2,164.97 49.95 163.81 1,972.83 1,917.15 -638.57 203.29 5,956,833.37 378,153.77 3.33 663.06 MWD(1) 2,259.76 52.56 163.63 2,032.15 1,976.47 -709.53 224.02 5,956,762.09 378,173.34 2.76 735.92 MWD(1) 2,354.76 54.61 163.02 2,088.54 2,032.86 -782.75 245.96 5,956,688.52 378,194.09 2.22 811.36 MWD(1) 2,451.30 56.24 161.66 2,143.33 2,087.65 -858.49 270.08 5,956,612.41 378,216.97 2.05 890.00 MWD(1) 2,546.79 56.68 162.94 2,196.09 2,140.41 -934.31 294.28 5,956,536.21 378,239.93 1.21 968.76 MWD(1) 2,640.86 56.78 163.04 2,247.69 2,192.01 -1,009.52 317.29 5,956,460.65 378,261.72 0.14 1,046.44 MWD(1) 2,737.15 56.59 163.11 2,300.58 2,244.90 -1,086.50 340.71 5,956,383.30 378,283.89 0.21 1,125.90 MWD(1) 2,831.27 57.29 161.84 2,351.93 2,296.25 -1,161.72 364.47 5,956,307.71 378,306.42 1.35 1,203.92 MWD(1) 2,920.00 56.50 162.10 2,400.39 2,344.71 -1,232.39 387.47 5,956,236.68 378,328.27 0.92 1,277.53 MWD+IFR-AK-CAZ-SC(2) 2,967.27 55.80 161.42 2,426.72 2,371.04 -1,269.68 399.76 5,956,199.20 378,339.95 1.90 1,316.42 MWD+IFR-AK-CAZ-SC(2) 3,061.86 55.67 163.22 2,479.98 2,424.30 -1,344.15 423.50 5,956,124.36 378,362.48 1.58 1,393.77 MWD+IFR-AK-CAZ-SC(2) 3,157.54 52.53 165.16 2,536.08 2,480.40 -1,418.71 444.64 5,956,049.48 378,382.40 3.67 1,470.04 MWD+IFR-AK-CAZ-SC(2) 3,251.66 48.77 167.19 2,595.75 2,540.07 -1,489.35 462.06 5,955,978.57 378,398.67 4.33 1,541.17 MWD+IFR-AK-CAZ-SC(2) 3,343.54 47.15 171.42 2,657.29 2,601.61 -1,556.37 474.75 5,955,911.36 378,410.27 3.85 1,606.97 MWD+IFR-AK-CAZ-SC(2) 3,441.28 47.17 175.10 2,723.76 2,668.08 -1,627.52 483.15 5,955,840.09 378,417.52 2.76 1,674.60 MWD+IFR-AK-CAZ-SC(2) 3,534.61 45.75 180.47 2,788.07 2,732.39 -1,695.07 485.80 5,955,772.51 378,419.07 4.44 1,736.48 MWD+IFR-AK-CAZ-SC(2) 3,632.43 44.07 184.90 2,857.37 2,801.69 -1,764.02 482.61 5,955,703.63 378,414.76 3.63 1,797.05 MWD+IFR-AK-CAZ-SC(2) 3,725.36 44.21 189.21 2,924.07 2,868.39 -1,828.21 474.66 5,955,639.57 378,405.77 3.23 1,851.27 MWD+IFR-AK-CAZ-SC(2) 3,822.09 43.37 192.82 2,993.91 2,938.23 -1,893.90 461.89 5,955,574.11 378,391.94 2.72 1,904.71 MWD+IFR-AK-CAZ-SC(2) 3,917.07 42.80 198.90 3,063.31 3,007.63 -1,956.25 444.20 5,955,512.06 378,373.23 4.41 1,952.99 MWD+IFR-AK-CAZ-SC(2) 4,011.76 43.67 202.62 3,132.30 3,076.62 -2,016.88 421.20 5,955,451.82 378,349.25 2.84 1,997.40 MWD+IFR-AK-CAZ-SC(2) 4,105.14 45.08 205.98 3,199.06 3,143.38 -2,076.37 394.31 5,955,392.78 378,321.41 2.93 2,039.08 MWD+IFR-AK-CAZ-SC(2) 4,201.68 45.38 211.16 3,267.07 3,211.39 -2,136.51 361.55 5,955,333.18 378,287.68 3.82 2,078.78 MWD+IFR-AK-CAZ-SC(2) 4,296.09 45.67 211.98 3,333.22 3,277.54 -2,193.91 326.28 5,955,276.37 378,251.48 0.69 2,114.90 MWD+IFR-AK-CAZ-SC(2) 4,392.23 45.53 215.58 3,400.49 3,344.81 -2,250.98 288.10 5,955,219.92 378,212.39 2.68 2,149.47 MWD+IFR-AK-CAZ-SC(2) 4,485.27 43.74 221.44 3,466.72 3,411.04 -2,302.12 247.48 5,955,169.46 378,170.94 4.82 2,177.62 MWD+IFR-AK-CAZ-SC(2) 4,581.82 43.95 223.06 3,536.36 3,480.68 -2,351.62 202.51 5,955,120.69 378,125.18 1.18 2,202.40 MWD+IFR-AK-CAZ-SC(2) 4,677.19 43.76 228.15 3,605.15 3,549.47 -2,397.82 155.33 5,955,075.27 378,077.26 3.70 2,223.24 MWD+IFR-AK-CAZ-SC(2) 9/14/2010 3:18:37PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD4-12 Project: Western North Slope TVD Reference: CD4-12 @ 55.68ft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-12©55.68ft(Doyon 19) Well: CD4-12 North Reference: True Wellbore: CD4-12PB1 Survey Calculation Method: Minimum Curvature Design: CD4-12PB1 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/1l)0') (ft) Survey Tool Name 4,771.81 44.97 233.36 3,672.82 3,617.14 -2,439.62 104.11 5,955,034.31 378,025.37 4.06 2,238.36 MWD+IFR-AK-CAZ-SC(2) 4,867.04 44.40 237.95 3,740.54 3,684.86 -2,477.40 48.86 5,954,997.44 377,969.52 3.44 2,248.09 MWD+IFR-AK-CAZ-SC(2) 4,961.47 45.08 236.77 3,807.62 3,751.94 -2,513.25 -7.11 5,954,962.51 377,912.98 1.14 2,255.78 MWD+IFR-AK-CAZ-SC(2) 5,056.79 45.19 236.22 3,874.86 3,819.18 -2,550.54 -63.44 5,954,926.14 377,856.06 0.42 2,264.60 MWD+IFR-AK-CAZ-SC(2) 5,151.59 44.72 237.01 3,941.95 3,886.27 -2,587.40 -119.37 5,954,890.19 377,799.54 0.77 2,273.21 MWD+IFR-AK-CAZ-SC(2) 5,246.84 44.47 236.66 4,009.77 3,954.09 -2,623.98 -175.35 5,954,854.53 377,742.98 0.37 2,281.55 MWD+IFR-AK-CAZ-SC(2) 5,282.96 44.53 237.08 4,035.54 3,979.86 -2,637.82 -196.55 5,954,841.04 377,721.56 0.83 2,284.69 MWD+IFR-AK-CAZ-SC(3) 5,375.88 44.67 237.55 4,101.70 4,046.02 -2,673.05 -251.46 5,954,806.70 377,666.09 0.39 2,292.29 MWD+IFR-AK-CAZ-SC(3) 5,473.95 44.28 236.61 4,171.68 4,116.00 -2,710.39 -309.14 5,954,770.31 377,607.82 0.78 2,300.56 MWD+IFR-AK-CAZ-SC(3) 5,564.74 45.42 235.99 4,236.04 4,180.36 -2,745.92 -362.40 5,954,735.65 377,553.99 1.34 2,309.15 MWD+IFR-AK-CAZ-SC(3) 5,663.95 45.35 237.38 4,305.72 4,250.04 -2,784.70 -421.42 5,954,697.83 377,494.36 1.00 2,318.14 MWD+IFR-AK-CAZ-SC(3) 5,755.63 45.18 237.06 4,370.25 4,314.57 -2,819.97 -476.17 5,954,663.47 377,439.04 0.31 2,325.83 MWD+IFR-AK-CAZ-SC(3) 5,852.80 44.90 237.40 4,438.91 4,383.23 -2,857.18 -533.99 5,954,627.20 377,380.63 0.38 2,333.93 MWD+IFR-AK-CAZ-SC(3) 5,949.80 44.73 237.69 4,507.72 4,452.04 -2,893.87 -591.68 5,954,591.46 377,322.36 0.27 2,341.62 MWD+IFR-AK-CAZ-SC(3) 6,044.14 44.66 239.56 4,574.79 4,519.11 -2,928.41 -648.32 5,954,557.84 377,265.17 1.40 2,347.84 MWD+IFR-AK-CAZ-SC(3) 6,139.70 44.47 239.50 4,642.87 4,587.19 -2,962.42 -706.12 5,954,524.78 377,206.83 0.20 2,353.06 MWD+IFR-AK-CAZ-SC(3) 6,234.52 45.41 239.79 4,709.99 4,654.31 -2,996.26 -763.91 5,954,491.88 377,148.50 1.01 2,358.15 MWD+IFR-AK-CAZ-SC(3) 6,329.15 45.33 238.96 4,776.47 4,720.79 -3,030.57 -821.86 5,954,458.52 377,090.01 0.63 2,363.58 MWD+IFR-AK-CAZ-SC(3) 6,424.08 44.88 238.17 4,843.47 4,787.79 -3,065.64 -879.24 5,954,424.39 377,032.07 0.76 2,369.94 MWD+IFR-AK-CAZ-SC(3) 6,519.08 44.54 237.15 4,910.99 4,855.31 -3,101.39 -935.71 5,954,389.57 376,975.04 0.84 2,377.32 MWD+IFR-AK-CAZ-SC(3) 6,613.54 44.52 236.97 4,978.33 4,922.65 -3,137.41 -991.30 5,954,354.46 376,918.87 0.14 2,385.33 MWD+IFR-AK-CAZ-SC(3) 6,709.55 45.19 236.96 5,046.39 4,990.71 -3,174.32 -1,048.07 5,954,318.47 376,861.51 0.70 2,393.62 MWD+IFR-AK-CAZ-SC(3) 6,803.72 44.97 237.66 5,112.88 5,057.20 -3,210.34 -1,104.19 5,954,283.38 376,804.82 0.58 2,401.39 MWD+IFR-AK-CAZ-SC(3) 6,899.89 44.55 236.82 5,181.17 5,125.49 -3,246.98 -1,161.14 5,954,247.67 376,747.29 0.75 2,409.36 MWD+IFR-AK-CAZ-SC(3) 6,994.93 44.09 237.27 5,249.16 5,193.48 -3,283.10 -1,216.85 5,954,212.46 376,691.00 0.59 2,417.40 MWD+IFR-AK-CAZ-SC(3) 7,090.33 45.27 237.30 5,317.00 5,261.32 -3,319.35 -1,273.29 5,954,177.13 376,633.99 1.24 2,425.24 MWD+IFR-AK-CAZ-SC(3) 7,184.90 44.55 236.98 5,383.97 5,328.29 -3,355.58 -1,329.37 5,954,141.82 376,577.33 0.80 2,433.22 MWD+IFR-AK-CAZ-SC(3) 7,280.16 44.62 237.17 5,451.82 5,396.14 -3,391.93 -1,385.50 5,954,106.39 376,520.62 0.16 2,441.28 MWD+IFR-AK-CAZ-SC(3) 7,375.08 44.98 237.19 5,519.17 5,463.49 -3,428.18 -1,441.71 5,954,071.06 376,463,84 0.38 2,449.22 MWD+IFR-AK-CAZ-SC(3) 7,470.20 45.40 236.83 5,586.21 5,530.53 -3,464.92 -1,498.31 5,954,035.25 376,406.65 0.52 2,457.43 MWD+IFR-AK-CAZ-SC(3) 7,564.82 44.67 236.71 5,653.07 5,597.39 -3,501.61 -1,554.31 5,953,999.48 376,350.07 0.78 2,465.86 MWD+IFR-AK-CAZ-SC(3) 7,660.22 45.35 237.91 5,720.52 5,664.84 -3,538.04 -1,611.09 5,953,963.97 376,292.71 1.14 2,473.71 MWD+IFR-AK-CAZ-SC(3) 7,755.83 45.17 236.38 5,787.82 5,732.14 -3,574.88 -1,668.14 5,953,928.06 376,235.07 1.15 2,481.82 MWD+IFR-AK-CAZ-SC(3) 7,851.13 44.14 235.19 5,855.61 5,799.93 -3,612.54 -1,723.53 5,953,891.32 376,179.09 1.39 2,491.38 MWD+IFR-AK-CAZ-SC(3) 7,945.98 44.47 235.75 5,923.49 5,867.81 -3,650.09 -1,778.11 5,953,854.66 376,123.91 0.54 2,501.21 MWD+IFR-AK-CAZ-SC(3) 8,041.30 44.01 237.06 5,991.78 5,936.10 -3,686.89 -1,833.50 5,953,818.77 376,067.93 1.07 2,510.00 MWD+IFR-AK-CAZ-SC(3) 8,136.63 45.50 240.14 6,059.48 6,003.80 -3,721.83 -1,890.78 5,953,784.76 376,010.09 2.76 2,516.29 MWD+IFR-AK-CAZ-SC(3) 8,230.86 44.57 239.42 6,126.07 6,070.39 -3,755.38 -1,948.40 5,953,752.15 375,951.95 1.13 2,521.19 MWD+IFR-AK-CAZ-SC(3) 8,327.77 45.27 237.42 6,194.70 6,139.02 -3,791.22 -2,006.68 5,953,717.27 375,893.09 1.63 2,527.85 MWD+IFR-AK-CAZ-SC(3) 8,418.32 45.43 236.69 6,258.33 6,202.65 -3,826.25 -2,060.74 5,953,683.12 375,838.48 0.60 2,535.64 MWD+IFR-AK-CAZ-SC(3) 9/14/2010 3:18:37PM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD4-12 Project Western North Slope TVD Reference: CD4-12 @ 55.68ft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-12 @ 55.68ft(Doyon 19) Well: CD4-12 North Reference: True Wellbore: CD4-12PB1 Survey Calculation Method: Minimum Curvature Design: CD4-12PB1 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/-W Northing Easting DLS Section (ft) (°) (°l (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 8,515.51 45.55 234.96 6,326.47 6,270.79 -3,865.18 -2,118.08 5,953,645.13 375,780.52 1.28 2,545.50 MWD+IFR-AK-CAZ-SC(3) 8,612.20 47.29 229.16 6,393.15 6,337.47 -3,908.25 -2,173.24 5,953,602.97 375,724.67 4.70 2,560.03 MWD+IFR-AK-CAZ-SC(3) 8,705.80 48.23 223.88 6,456.10 6,400.42 -3,955.92 -2,223.47 5,953,556.13 375,673.68 4.29 2,580.85 MWD+IFR-AK-CAZ-SC(3) 8,802.58 49.46 218.17 6,519.82 6,464.14 -4,010.87 -2,271.23 5,953,501.96 375,625.03 4.62 2,609.30 MWD+IFR-AK-CAZ-SC(3) 8,897.61 50.41 216.00 6,580.99 6,525.31 -4,068.89 -2,315.08 5,953,444.67 375,580.26 2.01 2,642.23 MWD+IFR-AK-CAZ-SC(3) 8,991.40 52.38 213.94 6,639.51 6,583.83 -4,128.95 -2,357.06 5,953,385.30 375,537.30 2.71 2,677.81 MWD+IFR-AK-CAZ-SC(3) 9,087.03 54.32 211.45 6,696.59 6,640.91 -4,193.52 -2,398.48 5,953,321.42 375,494.85 2.91 2,717.68 MWD+IFR-AK-CAZ-SC(3) 9,182.51 57.25 207.63 6,750.29 6,694.61 -4,262.20 -2,437.35 5,953,253.38 375,454.87 4.51 2,762.38 MWD+IFR-AK-CAZ-SC(3) 9,277.33 58.82 206.50 6,800.49 6,744.81 -4,333.84 -2,473.95 5,953,182.35 375,417.12 1.94 2,810.72 MWD+IFR-AK-CAZ-SC(3) 9,371.88 60.76 204.97 6,848.06 6,792.38 -4,407.44 -2,509.41 5,953,109.34 375,380.47 2.48 2,861.33 MWD+IFR-AK-CAZ-SC(3) 9,466.91 62.77 203.43 6,893.02 6,837.34 -4,483.80 -2,543.72 5,953,033.55 375,344.93 2.55 2,914.92 MWD+IFR-AK-CAZ-SC(3) 9,562.23 64.69 203.44 6,935.21 6,879.53 -4,562.22 -2,577.71 5,952,955.70 375,309.67 2.01 2,970.50 MWD+IFR-AK-CAZ-SC(3) 9,657.57 66.45 202.53 6,974.64 6,918.96 -4,642.13 -2,611.60 5,952,876.36 375,274.49 2.04 3,027.47 MWD+IFR-AK-CAZ-SC(3) 9,752.65 66.86 200.98 7,012.32 6,956.64 -4,723.21 -2,643.95 5,952,795.83 375,240.83 1.56 3,086.16 MWD+IFR-AK-CAZ-SC(3) 9,847.47 68.07 199.04 7,048.66 6,992.98 -4,805.50 -2,673.91 5,952,714.04 375,209.54 2.28 3,146.98 MWD+IFR-AK-CAZ-SC(3) 9,943.01 69.06 195.32 7,083.58 7,027.90 -4,890.44 -2,700.17 5,952,629.54 375,181.91 3.77 3,211.83 MWD+IFR-AK-CAZ-SC(3) 10,037.54 71.29 190.81 7,115.66 7,059.98 -4,977.04 -2,720.24 5,952,543.29 375,160.44 5.07 3,280.86 MWD+IFR-AK-CAZ-SC(3) 10,086.77 71.29 188.11 7,131.45 7,075.77 -5,023.03 -2,727.90 5,952,497.43 375,152.03 5.19 3,318.84 MWD+IFR-AK-CAZ-SC(3) 10,129.76 71.28 186.54 7,145.24 7,089.56 -5,063.41 -2,733.09 5,952,457.14 375,146.19 3.46 3,352.86 MWD+IFR-AK-CAZ-SC(3) 10,228.31 73.03 183.27 7,175.45 7,119.77 -5,156.86 -2,741.10 5,952,363.84 375,136.67 3.62 3,433.34 MWD+IFR-AK-CAZ-SC(3) 10,320.75 74.19 181.11 7,201.54 7,145.86 -5,245.47 -2,744.48 5,952,275.31 375,131.84 2.57 3,511.50 MWD+IFR-AK-CAZ-SC(3) 10,416.99 75.21 177.35 7,226.94 7,171.26 -5,338.27 -2,743.23 5,952,182.51 375,131.59 3.91 3,595.46 MWD+IFR-AK-CAZ-SC(3) 10,510.76 76.24 173.19 7,250.07 7,194.39 -5,428.81 -2,735.73 5,952,091.86 375,137.62 4.44 3,680.12 MWD+IFR-AK-CAZ-SC(3) 10,608.09 77.37 170.54 7,272.29 7,216.61 -5,522.61 -2,722.32 5,951,997.87 375,149.51 2.89 3,770.30 MWD+IFR-AK-CAZ-SC(3) 10,697.93 79.08 166.00 7,290.63 7,234.95 -5,608.69 -2,704.43 5,951,911.51 375,165.99 5.30 3,855.51 MWD+IFR-AK-CAZ-SC(3) 10,756.02 79.71 165.54 7,301.32 7,245.64 -5,664.04 -2,690.40 5,951,855.95 375,179.13 1.33 3,911.41 MWD+IFR-AK-CAZ-SC(3) 10,795.81 80.52 165.08 7,308.16 7,252.48 -5,701.95 -2,680.45 5,951,817.88 375,188.45 2.33 3,949.85 MWD+IFR-AK-CAZ-SC(3) 10,889.73 82.20 160.75 7,322.27 7,266.59 -5,790.68 -2,653.18 5,951,728.73 375,214.28 4.90 4,041.56 MWD+IFR-AK-CAZ-SC(3) 10,985.34 82.45 160.39 7,335.04 7,279.36 -5,880.04 -2,621.66 5,951,638.88 375,244.34 0.46 4,135.69 MWD+IFR-AK-CAZ-SC(3) 11,082.89 84.44 157.89 7,346.18 7,290.50 -5,970.59 -2,587.15 5,951,547.79 375,277.38 3.26 4,232.20 MWD+IFR-AK-CAZ-SC(3) 11,177.90 85.12 157.22 7,354.82 7,299.14 -6,058.03 -2,551.02 5,951,459.78 375,312.07 1.00 4,326.63 MWD+IFR-AK-CAZ-SC(3) 11,273.27 84.51 157.26 7,363.44 7,307.76 -6,145.62 -2,514.28 5,951,371.62 375,347.39 0.64 4,421.46 MWD+IFR-AK-CAZ-SC(3) 11,368.12 83.02 157.81 7,373.74 7,318.06 -6,232.75 -2,478.25 5,951,283.92 375,381.99 1.67 4,515.56 MWD+IFR-AK-CAZ-SC(3) 11,461.83 86.86 158.59 7,382.00 7,326.32 -6,319.40 -2,443.59 5,951,196.72 375,415.24 4.18 4,608.64 MWD+IFR-AK-CAZ-SC(3) 11,480.61 87.85 158.04 7,382.87 7,327.19 -6,336.83 -2,436.66 5,951,179.18 375,421.88 6.03 4,627.35 MWD+IFR-AK-CAZ-SC(3) 11,579.16 87.84 157.24 7,386.58 7,330.90 -6,427.91 -2,399.20 5,951,087.52 375,457.86 0.81 4,725.63 MWD+IFR-AK-CAZ-SC(4) 11,675.80 88.83 156.98 7,389.38 7,333.70 -6,516.90 -2,361.62 5,950,997.94 375,493.98 1.06 4,822.08 MWD+IFR-AK-CAZ-SC(4) 11,769.29 89.69 157.31 7,390.59 7,334.91 -6,603.04 -2,325.32 5,950,911.22 375,528.88 0.99 4,915.42 MWD+IFR-AK-CAZ-SC(4) 11,866.31 89.45 152.85 7,391.32 7,335.64 -6,691.00 -2,284.45 5,950,822.62 375,568.32 4.60 5,012.40 MWD+IFR-AK-CAZ-SC(4) 11,920.62 89.69 148.76 7,391.73 7,336.05 -6,738.40 -2,257.96 5,950,774.80 375,594.03 7.54 5,066.61 MWD+IFR-AK-CAZ-SC(4) 9/14/2010 3:18:37PM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD4-12 Project Western North Slope TVD Reference: CD4-12 @ 55.68ft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-12 @ 55.68ft(Doyon 19) Well: CD4-12 North Reference: True Wellbore: CD4-12PB1 Survey Calculation Method: Minimum Curvature Design: CD4-12PB1 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Az' TVD TVDSS +N/S +E/-W Northing Easting DLS Section (ft) r) r) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,962.66 88.71 146.55 7,392.32 7,336.64 -6,773.91 -2,235.47 5,950,738.93 375,615.93 5.75 5,108.39 MWD+IFR-AK-CAZ-SC(4) 12,013.42 89.14 144.99 7,393.27 7,337.59 -6,815.87 -2,206.93 5,950,696.52 375,643.79 3.19 5,158.61 MWD+IFR-AK-CAZ-SC(4) 12,060.75 88.64 144.17 7,394.18 7,338.50 -6,854.44 -2,179.50 5,950,657.52 375,670.59 2.03 5,205.30 MWD+IFR-AK-CAZ-SC(4) 12,109.16 88.70 144.31 7,395.31 7,339.63 -6,893.71 -2,151.22 5,950,617.79 375,698.23 0.31 5,252.99 MWD+IFR-AK-CAZ-SC(4) 12,152.38 88.71 144.48 7,396.29 7,340.61 -6,928.84 -2,126.06 5,950,582.26 375,722.81 0.39 5,295.60 MWD+IFR-AK-CAZ-SC(4) 12,247.95 89.26 147.18 7,397.98 7,342.30 -7,007.89 -2,072.40 5,950,502.35 375,775.17 2.88 5,390.17 MWD+IFR-AK-CAZ-SC(4) 12,343.36 89.08 149.00 7,399.36 7,343.68 -7,088.87 -2,021.97 5,950,420.57 375,824.27 1.92 5,485.06 MWD+IFR-AK-CAZ-SC(4) 12,439.06 88.65 150.69 7,401.26 7,345.58 -7,171.60 -1,973.91 5,950,337.08 375,870.98 1.82 5,580.49 MWD+IFR-AK-CAZ-SC(4) 12,534.36 89.20 154.49 7,403.04 7,347.36 -7,256.17 -1,930.06 5,950,251.82 375,913.46 4.03 5,675.72 MWD+IFR-AK-CAZ-SC(4) 12,630.24 88.83 156.87 7,404.69 7,349.01 -7,343.52 -1,890.58 5,950,163.84 375,951.51 2.51 5,771.54 MWD+IFR-AK-CAZ-SC(4) 12,724.80 89.51 156.81 7,406.06 7,350.38 -7,430.45 -1,853.39 5,950,076.33 375,987.28 0.72 5,865.97 MWD+IFR-AK-CAZ-SC(4) 12,820.16 90.06 156.58 7,406.42 7,350.74 -7,518.03 -1,815.67 5,949,988.16 376,023.57 0.63 5,961.23 MWD+IFR-AK-CAZ-SC(4) 12,916.67 90.37 156.51 7,406.06 7,350.38 -7,606.57 -1,777.25 5,949,899.02 376,060.54 0.33 6,057.64 MWD+IFR-AK-CAZ-SC(4) 13,009.87 90.87 159.20 7,405.05 7,349.37 -7,692.88 -1,742.13 5,949,812.15 376,094.26 2.94 6,150.62 MWD+IFR-AK-CAZ-SC(4) 13,104.08 89.14 157.98 7,405.04 7,349.36 -7,780.58 -1,707.74 5,949,723.91 376,127.21 2.25 6,244.52 MWD+IFR-AK-CAZ-SC(4) 13,201.21 90.99 156.58 7,404.93 7,349.25 -7,870.17 -1,670.22 5,949,633.73 376,163.26 2.39 6,341.48 MWD+IFR-AK-CAZ-SC(4) 13,296.53 91.73 155.59 7,402.67 7,346.99 -7,957.28 -1,631.60 5,949,546.01 376,200.47 1.30 6,436.71 MWD+IFR-AK-CAZ-SC(4) 13,392.16 91.30 154.46 7,400.14 7,344.46 -8,043.94 -1,591.23 5,949,458.72 376,239.42 1.26 6,532.29 MWD+IFR-AK-CAZ-SC(4) 13,486.55 89.20 155.01 7,399.73 7,344.05 -8,129.29 -1,550.95 5,949,372.73 376,278.31 2.30 6,626.67 MWD+IFR-AK-CAZ-SC(4) 13,582.98 91.12 153.51 7,399.46 7,343.78 -8,216.15 -1,509.08 5,949,285.22 376,318.76 2.53 6,723.09 MWD+IFR-AK-CAZ-SC(4) 13,678.10 91.49 153.08 7,397.29 7,341.61 -8,301.10 -1,466.34 5,949,199.59 376,360.11 0.60 6,818.18 MWD+IFR-AK-CAZ-SC(4) 13,772.76 91.06 153.90 7,395.19 7,339.51 -8,385.78 -1,424.10 5,949,114.24 376,400.97 0.98 6,912.81 MWD+IFR-AK-CAZ-SC(4) 13,869.11 89.69 153.17 7,394.56 7,338.88 -8,472.03 -1,381.16 5,949,027.31 376,442.49 1.61 7,009.15 MWD+IFR-AK-CAZ-SC(4) 13,964.12 89.82 149.77 7,394.96 7,339.28 -8,555.49 -1,335.79 5,948,943.13 376,486.50 3.58 7,104.05 MWD+IFR-AK-CAZ-SC(4) 14,059.76 90.93 150.35 7,394.34 7,338.66 -8,638.36 -1,288.06 5,948,859.50 376,532.88 1.31 7,199.46 MWD+IFR-AK-CAZ-SC(4) 14,154.71 89.94 151.49 7,393.62 7,337.94 -8,721.34 -1,241.91 5,948,775.79 376,577.67 1.59 7,294.27 MWD+IFR-AK-CAZ-SC(4) 14,250.37 89.45 151.42 7,394.13 7,338.45 -8,805.37 -1,196.20 5,948,691.04 376,622.00 0.52 7,389.83 MWD+IFR-AK-CAZ-SC(4) 14,346.43 90.00 152.79 7,394.59 7,338.91 -8,890.27 -1,151.26 5,948,605.43 376,665.56 1.54 7,485.84 MWD+IFR-AK-CAZ-SC(4) 14,441.45 89.02 154.58 7,395.40 7,339.72 -8,975.43 -1,109.14 5,948,519.60 376,706.28 2.15 7,580.85 MWD+IFR-AK-CAZ-SC(4) 14,536.68 89.20 156.68 7,396.88 7,341.20 -9,062.16 -1,069.86 5,948,432.25 376,744.15 2.21 7,676.02 MWD+IFR-AK-CAZ-SC(4) 14,631.94 88,89 158.68 7,398.47 7,342.79 -9,150.27 -1,033.69 5,948,343.58 376,778.89 2.12 7,771.07 MWD+IFR-AK-CAZ-SC(4) 14,727.30 89.57 159.02 7,399.75 7,344.07 -9,239.19 -999.28 5,948,254.11 376,811.84 0.80 7,866.08 MWD+IFR-AK-CAZ-SC(4) 14,821.91 89.20 157.93 7,400.76 7,345.08 -9,327.20 -964.57 5,948,165.56 376,845.11 1.22 7,960.39 MWD+IFR-AK-CAZ-SC(4) 14,917.63 88.95 157.34 7,402.31 7,346.63 -9,415.71 -928.15 5,948,076.48 376,880.09 0.67 8,055.91 MWD+IFR-AK-CAZ-SC(4) 15,013.95 88.83 156.64 7,404.17 7,348.49 -9,504.35 -890.51 5,947,987.25 376,916.28 0.74 8,152.08 MWD+IFR-AK-CAZ-SC(4) 15,109.49 88.71 157.52 7,406.23 7,350.55 -9,592.32 -853.31 5,947,898.69 376,952.05 0.93 8,247.46 MWD+IFR-AK-CAZ-SC(4) 15,204.11 89.51 158.62 7,407.70 7,352.02 -9,680.08 -817.98 5,947,810.37 376,985.95 1.44 8,341.82 MWD+IFR-AK-CAZ-SC(4) 15,298.87 89.45 157.67 7,408.56 7,352.88 -9,768.03 -782.71 5,947,721.88 377,019.78 1.00 8,436.33 MWD+IFR-AK-CAZ-SC(4) 15,395.29 89.14 157.44 7,409.74 7,354.06 -9,857.14 -745.90 5,947,632.19 377,055.14 0.40 8,532.56 MWD+IFR-AK-CAZ-SC(4) 15,489.93 89.69 156.54 7,410.71 7,355.03 -9,944.24 -708.90 5,947,544.50 377,090.71 1.11 8,627.06 MWD+IFR-AK-CAZ-SC(4) 9/14/2010 3:18:37PM Page 6 COMPASS 2003.16 Build 69 ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well CD4-12 Project Western North Slope TVD Reference: CD4-12 @ 55.68ft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-12 @ 55.68ft(Doyon 19) Well: CD4-12 North Reference: True Wellbore: CD4-12PB1 Survey Calculation Method: Minimum Curvature Design: CD4-12PB1 Database: EDM Alaska Prod v16 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/S +E/-W Northing Easting DLS Section (ft) (0) (0) (n) (ft) (ft) (ft) (ft) (ft) (°H00.) (ft) Survey Tool Name 15,585.47 90.06 155.07 7,410.92 7,355.24 -10,031.39 -669.75 5,947,456.74 377,128.44 1.59 8,722.55 MWD+IFR-AK-CAZ-SC(4) 15,680.71 90.06 153.13 7,410.82 7,355.14 -10,117.06 -628.15 5,947,370.41 377,168.64 2.04 8,817.79 MWD+IFR-AK-CAZ-SC(4) 15,747.29 90.93 152.98 7,410.24 7,354.56 -10,176.41 -597.98 5,947,310.59 377,197.84 1.33 8,884.35 MWD+IFR-AK-CAZ-SC(4) 15,829.00 90.93 152.98 7,408.92 7,353.24 -10,249.19 -560.87 5,947,237.22 377,233.77 0.00 8,966.04 PROJECTED to TD 9/14/2010 3:18:37PM Page 7 COMPASS 2003.16 Build 69 WELL LOG TRANSMITTAL To: State of Alaska September 17, 2010 Alaska Oil and Gas Conservation Commission Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-12_PB1 AK-MW-0007264438 CD4-12 50-103-20414-01 2" x 5" MD GAMMA-RESISTIVITY Logs: 1 Color Log 2" x 5"TVD GAMMA-RESISTIVITY Logs: 1 Color Log 1" x 5" BAT Cement Log: 1 Color Log CD4-12 PB1 50-103-20414-70 2" x 5" MD GAMMA-RESISTIVITY Logs: 1 Color Log 2" x 5"TVD GAMMA-RESISTIVITY Logs: 1 Color Log Digital Log Images & LWDG-formatted LIS Data w/verification listing: 1 CD Rom Digital Log Images 1" x 5" BAT Cement Log 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bl�r $rtC a l Reg com Date: Signed: 0, 33 `36/ odaml SEAN PARNELL, GOVERNOR 0 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: Colville River Field, Alpine Oil Pool, CD4-12 ConocoPhillips Alaska, Inc. Permit No: 210-091 Surface Location: 2937' FNL, 283' FEL, Sec. 24, T11N, R4E, UM Bottomhole Location: 3107' FNL, 604' FEL, Sec. 36, T11N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to re-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, Daniel . Seamount, Jr. r p Chair DATED this t day of July, 2010. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA J U I, 0 7 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska O';t;&.3 C .:.Commission 20 AAf"- ^^` AfTt1O1',190 la.Type of Work: • lb.Proposed Well Class: Development-Oil L Service-vain) ❑ Single Zone Q • 1c.Specify if well is proposed for: Drill ❑ Re-drill El Stratigraphic Test ❑ Development-Gas❑/ Service-Supply ❑ Multiple Zones Coalbed Gas ❑ Gas Hydrates❑ 4.1%.77.■6 Re-entry ❑ Exploratory ❑ Service-WAG Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 " CD4-12 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 16351' • TVD: 7346' • Colville River Field ' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): /0 7 /q . gv� /e%nc.. "I'2937'FNL,283'FEL,Sec.24,T11N,R4E,UM • /DL 384209,388902k 3 tJ J/ .J=i Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 3891'FNL,2764'FEL,Sec.25,T11N,R4E,UM Tobin-932076 and 932351 7/20/2010 Total Depth: 9.Acres in Property: 14.Disrca ar st Prope a,4,,,t,t4_-. 3107'FNL,604'FEL,Sec. 36,T11N,R4E,UM 2560 +/-1.25 miles to A LD 390672,A 7,7 2115 /j 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL:7541 sl9.1ieet 15.Distance to Nearest Well O en i GL Elevationa�ove MSL: 12.6'(eet dp Z-5 pea'We `{ 175t 0 u u,I Surface:x- 377961.0 • y- • 5957475.0 Zone- 4 /5A 7•I to j la* to Same Pool Cam .;:/6 7 L/4 16.Deviated wells: Kickoff depth: 2920• ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90° • deg Downhole:3323 psig • Surface:2589 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" 62.5 H-40 Welded 77 37 37 114 114 Pre Installed 12.25" 9.625" 40 L-80 BTC-M 2877 37 37 2914• 2397 Installed while drilling Nanuq#5 8.75" 7" 26 L-80 BTC-M 11326 37 37 11363 7288 1st-664 sx 15.8'G' 2nd-185 sx 15.8 G 4.5" 12.6 L-80 IBT-M .1E268- 11L)2,, ,,,3.e' 16300 7,347 4.5"slotted liner 6.125" N/A 16319 32 32 16351 7346 Open Hole 94 19 PRESENT WELL CONDITION SUMMARY 7' (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 77.00 16" Pre-Installed 114 114.00 Surface 2,877.00 12.25" 272 bbl lead,50 bbl tail-Class G 2914 2,397.00 Intermediate - - - - - Production 11,326.00 7" 1st-81 bbl,2nd-29 bbl-LiteCrete 11003 7,708.00 Liner - - - - - Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program Q Time v.Depth Plot❑ Shallow Hazard Analysis Q Diverter Sketch❑ Seabed Report❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Ryan Robertson-265.6318 Printed Name Chip Alvord Title Alaska Drilling Manager Signature 0 Phone 265-6120 Date 7 /// 2t,,o Commission Use Only I l� 1 Permit to Drill API Number: / Permit AppfJ val See cover letter Number: 2 1C-/ ' I 50-/03-�t // "&/ _� Date: i 0 for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales: LJ j 1 3506 to s. BoP �sf Samples req'd: Yes ❑ No M Mud log req'd: Yes ❑ No IL��I Other: PF Z s� rS� Aoin aa.(wr r;',51.-( 2Sgneasures: Yes ❑ No R" Directional svy req'd: Yes No ❑ -60-661.14.4- o tl'e'r'cA'•m.. i i 4 c conk LW /r,i 0 i 1 - /� I T t CC..►,..,� '-1' I cos 7 // .., APPROVED BY THE COMMISSION S 0 DAT - ,COMMISSIONER A> -7'7./t' Form 10-401 (Revised 7/2009) This permit is valid 21 gto1 . 7 hecoT y�eilatg of pproval(20 AAC 25.0 5(g)) Submit in Duplicate �� t \)) -7.9-rd �/ 4o Ei '. : c CD4-12 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 8-3/4" Hole / 7" Casing Interval Event Risk Level Mitigation Strategy Abnormal Pressure in Low BOPE drills. Mud weight of 9.6 ppg or higher. Flow Surface Formations checks during connections. Mud weight increase if >2000'TVD needed. Lost circulation Low Reduced pump rates and trip speeds. Real time equivalent circulating density(ECD)monitoring. Engineered mud rheology. Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced tripping speeds. Engineered mud properties. Ensure proper hole fill. Pump out of hole if needed. Monitor real time equivalent circulating density(ECD). Use of weighted sweeps. Abnormal Reservoir Low Well control drills. Increase mud weight. No mapped Pressure • faults occur within 700'of the planned wellbore. Hydrogen Sulfide gas Low H2S drills. Detection systems and alarms. Use standard well control practices. Employ mud scavengers. 6-1/8" Hole / Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation moderate Reduced pump rates and trip speeds. Real time equivalent circulating density(ECD)monitoring. Engineered mud rheology. Lost circulation material available if needed. Hole swabbing on trips Moderate Reduced trip speeds. Pump out to 7"shoe. Engineered mud properties. Ensure proper hole fill. Pump out of hole if need. Monitor real time equivalent circulating density(ECD). Use weighted sweeps. Abnormal Reservoir Medium BOPE drills. Keep mud weight above 8.8 ppg. Pressure • Check for flow during connections and if needed. Increase mud weight if necessary. Perform well control drills. Hydrogen Sulfide gas Low H2S drills. Detection systems and alarms. Use standard well control practices. Employ mud scavengers. Pre Rig 1. Little Red to perform casing test to 2,500 psi for 30 minutes. OA and IA to be monitored for pressure. 2. FMC to test current 7"pack off. Rio Procedure 3. Move Doyon 19 onto Nanuq 5 well. 4. Pull back pressure valve. 5. Displace existing 6.7 ppg diesel by circulating 9.8 ppg LSND kill weight fluid through tubing kill string at 3,038' MD 6. Set back pressure valve. 7. Nipple down tree. 8. Nipple up BOPE and perform full BOP test to 250 psi low/ 3,500 psi high (annular preventer—2,500 psi high) using 4-1/2"test joint. 9. Pick up 4-1/2"landing joint and engage tubing hanger. 10. Pull 4-1/2"tubing hanger and 4-1/2"tubing to surface. 11. Set test plug and pressure test pipe rams and annular preventer with 5"test joint to 250 psi low/3,500 psi high (annular high pressure—2,500 psi). Lay down test plug 12. Run in hole with 5"drill pipe and set bridge plug at 3,024'MD. Pull out of hole and lay down running tools. 13. Cut existing 7" intermediate casing with casing cutter at ±3,014' MD. Circulate outside annulus with 9.8 ppg LSND. Pull out of hole and lay down casing cutter. 14. Swap out top pipe rams to 7"casing rams. Set test plug and pressure test pipe rams and annular preventer with 7"test joint to 250 psi low/3,500 psi high(annular high pressure—2,500 psi). Lay down test plug. 15. Engage 7"casing with spear. Pull 7"casing to surface and lay down. 16. Swap 7"casing rams to 3-1/2"x 6"VBR pipe rams. Set test plug and pressure test rams with 5"test plug to 250 psi low/3,500 psi high. 17. RIH with cement stinger and set cement plug from the top of the bridge plug to inside surface casing. 18. Run storm packer and pressure test to 1,500 psi for 10 minutes. 19. Nipple down BOPE. 20. Swap out Prudhoe Gen V tubing head for Alpine Gen II tubing head. 21. Nipple up BOPE and pressure test flange breaks. p /� 22. Pull storm packer from hole. r 23. Pressure test cement plug to 1,500 psi for 10 minutes to confirm integrity. 24. Open hole sidetrack below surface casing at 2,920'MD with 8-3/4"drilling assembly. 25. Drill out 20'MD of new hole and perform leak off test. 26. Drill 8-3/4"hole to intermediate casing point in the Alpine C formation. (LWD Program:GR/RES/PWD). rr2 27. Run and cement 7"casing as per program. Perform leak off test down the 9-5/8"x 7"casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 28. Set test plug and pressure test pipe rams and annular preventer with 4" and 4-1/2" test joint to 250 psi low / 3,500 psi high(annular high pressure—2,500 psi) 29. Lay down testing plug 30. Pick 4"drillpipe and 6-1/8"drilling assembly. ' 31. Run in hole and perform cement bond log with BAT Sonic tool to evaluate intermediate cement job. c.9L `/ 32. Drill out 8-3/4"shoe track and 20'of new hole. Perform formation integrity test. - 33. Drill 6-1/8"horizontal section to well TD(LWD Program: GR/RES/PWD). • 34. Circulate and condition the hole. Pull out to surface. . 35. Run 4-1/2", 12.6#, IBT slotted liner if deemed necessary due to excursions out of zone. - 36. Run 3-'/z,9.3#, L-80 upper completion with TRMAXX-5E SSSV, Premier packer,and XN nipple. Land hanger. . 37. Install 2 way check and pressure test hanger seals to 5,000 psi. Nipple down BOP. - 38. Install tubing head adapter assembly. Pressure test adapter assembly to 5,000 psi. Remove two way check. ' 39. Circulate tubing to diesel and install freeze protection in the annulus. . 40. Drop ball and rod,set packer and test tubing and annulus to 3,500 psi/30 mins. - 41. Set BPV and secure well. 42. Move rig off location CD4-12. - Rice Procedure 1. Move Doyon 19 onto Nanuq 5 well. 2. Pull back pressure valve. 3. Displace existing 6.7 ppg diesel by circulating 9.8 ppg LSND kill weight fluid through tubing k' string at 3,038' MD 4. Set back pressure valve. 5. Nipple down tree. 6. Nipple up BOPE. Body test BOP and flange break. 7. Pick up 4-1/2"landing joint and engage tubing hanger. 8. Pull 4-1/2"tubing hanger and 4-1/2"tubing to surface. 9. Set test plug and perform full BOP test to 250 psi low/3500 psi •igh(annular high pressure-2,500 psi) 10. Lay down testing plug 11. Run in hole and set bridge plug at 3,024' MD. 12. Cut existing 7"intermediate casing with chemical cutt-rat±3,014' MD. 13. Pull 7"casing to surface and lay down. 14. RIH with cement stinger and set cement plug fr.m the top of the bridge plug to inside surface casing. Pi A 15. Swap out Prudhoe Gen V tubing head for A .ine Gen I I tubing head. 16. Open hole sidetrack below surface casin; at 2,920' MD with 8-3/4"drilling assembly. • 17. Drill out 20' MD of new hole and perfor leak off test. 18. Drill 8-3/4" hole to intermediate casi g point in the Alpine C formation. (LWD Program: GR/RES/PWD). • 19. Run and cement 7" casing as p- program. Perform leak off test down the 9-5/8" x 7" casing annulus to confirm yl� the fracture pressure reference• to the casing shoe. Freeze protect casing annulus and casing. 20. BOPE test to 3500 psi. 21. Drill out 8-3/4" shoe track .nd 20'of new hole. Perform formationSUPERCEDE 22. Drill 6-3/4" horizontal seftion to well TD(LWD Program: GR/RES/PWD).ite lO 23. Circulate and conditio the hole. Pull out to surface. 24. Run 4-1/2", 12.6#, I:T slotted liner if deemed necessary due to excursions out of zone. 25. Run 3-'/z, 9.3#, L-8' upper completion with TRMAXX-5E SSSV, Premier packer, and XN nipple. Land hanger. 26. Install 2 way the and pressure test hanger seals to 5,000 psi. Nipple down BOP. 27. Install tubing h-.d adapter assembly. Pressure test adapter assembly to 5,000 psi. Remove two way check. 28. Circulate tubing to diesel and install freeze protection in the annulus. 29. Drop ball and rod, set packer and test tubing and annulus to 3,500 psi/30 mins. 30. Set BPV and secure well. 31. Move rig off location CD4-12. OR !L'■ ! GINAL WELL PROXIMITY RISKS Directional drilling and collision avoidance information as required by 20 ACC 25.050(b) is provided in following attachments. CD4-214 is the nearest existing well to the CD4-12 plan with 76.42'ellipse to ellipse separation at 9,075' MD. .P/au, re.Qw.w prast. DRILLING AREA RISKS 74 P-i-/a Su.uoea # 310 -,Zoet There are no high-risk events. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material is expected to be effective in dealing with lost circulation. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. ANNULAR PUMPING OPERATIONS: Incidental fluids developed from drilling operations on well CD4-12 will be injected into a permitted annulus on the CD4 pad, or the class 2 disposal well on CD1 pad. The CD4-12 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000'TVD. Significant hydrocarbon zones include the Nechelik reservoir, and potentially the Qannik and Kuparuk reservoir. The first stage cement job will place 500' MD of cement above the top of the Albian 96 formation. This formation is the shallowest hydrocarbon bearing zone that can be effectively cemented during the first stage job. A secondary cement job will be executed to isolate the Qannik reservoir, placing an additional 500' MD of cement above the hydrocarbon bearing zone as per regulations. Once CD4-12 has been drilled and completed, consideration may be given to permit this well for annular injection. An application for Sundry Operations form 10-403 would then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing is set near the base of the Schrader Bluff Formation (C-40). These 450-500'thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg)*(0.052)*(Surface Shoe TVD)+ 1,500 psi =(12.0 ppg)*(0.052)*(2,400')+ 1,500 psi =2,997 psi Pore Pressure = 1,086 psi Therefore Differential =2,997 psi— 1,086 psi = 1911 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85%collapse and burst ratings listed in the following table: Wt Connection 85%of 85%of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 40 L-80 3 BTC 3,090 psi 2,626 psi 5,750 psi 4,888 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi flG1NAL DRILLING FLUID PROGRAM Intermediate hole to 7" Production Hole casing point—8 3/4" Section—6 1/8" Density 9.6— 10.2 ppg ✓ 9.0 ppg PV 10— 16 7—12 YP 13- 16 10- 15 Funnel Viscosity 30-35 Initial Gels 8— 10 6-9 10 minute gels <20 8- 12 API Filtrate 5— 12 cc/30 min (drilling) HPHT Fluid Loss 10 cc/30 min PH 9.0- 10.0 9.0-9.5 KCL 6 % Intermediate Hole Section: A fresh water polymer mud system is to be used for the intermediate section due to expected soft formations and higher rates of penetration. Good hole cleaning will be aided by pumping regular sweeps and maximizing fluid annular velocity. The potential for lost circulation exists, particularly after the Alpine C reservoir is penetrated. Mud weight will be maintained at or below 10.2 ppg to minimize losses, and lost circulation material will be introduced to the system if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids(by diluting as required)will all be beneficial in maintaining wellbore stability. Production Hole Section: The horizontal production interval will be drilled with a MI Swaco's Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. ORIGINAL CD4-12 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005( c )(3,4)and as required in 20 ACC 25.035(d)(2)) The following presents data used for calculation of anticipated surface pressure(ASP)during drilling of this well: Casing Setting Fracture Pore Casing Size Depth Gradient pressure ASP Drilling (in) MD/TVD(ft) (ppg) (psi) (psi) 9-5/8" 2914/2397 14.5 1085 1568 ;' P14"- C u4' Y *L5) 7" 11363/7344 16.0 3323 • 2589 • N/A 16351 /7346 16.0 3324 N/A • NOTE: Doyon 19's 5,000 psi BOP equipment is adequate. Test BOP's to 3,500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE(ASP): ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP= [(FG x 0.052)-0.1]D Where: ASP=Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.1 = Gas gradient in psi/ft D=True vertical depth of casing seat in ft RKB OR 2) ASP= FPP—(0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP= 0.4525 x TVD ASP CALCULATIONS 1. Drilling below surface casing (9-5/8") ASP= [(FG x 0.052)—0.1] D = [(14.5 x 0.052)—0.1]x 2397 = 1568 psi OR ASP= FPP—(0.1 x D) = 3147—(0.1 x 6954')=2451 psi 2. Drilling below intermediate casing (7") ASP= FPP—(0.1 x D) = 3323—(0.1 x 7344')=2589 psi ORIGINAL Cementing Program: Abandonment/Kick Off Plug. Cement open hole and into existing surface casing from±3,024' MD to 2,814' (210' of fill) with Class G+Adds @ 17.0 PPG.Assume 125% excess in the open hole and 0% exess inside surface casing. Plug: (3,024'-2,914') x 0.3941 ft3/ft x 1.25 (25% excess) = 54 ft3 in open hole 2,914' —2,814' x 0.4258 ft3/ft x 1.0 (0% excess) =43 ft3 inside surface casing Total volume= 54 ft3 +43 ft3 =97 ft3 => 97 Sx @ 1.00 ft3/sk System: 100 Sx Class G @ 17.0 PPG 7"Intermediate Casing run to 11,363' MD/7,825' TVD: Cemented in two stages Cement from 11,363' MD to 7825' MD (500' MD above top of the Nanuq reservoir)with Class G+adds @ 15.8 PPG.Assume 40% excess annular volume. First Stage: Lead: (11,363' —7825'3) x 0.1503 ft3/ft x 1.4 (40% excess) = 745 ft3 annular vol. 120' X 0.2148 ft /ft=26 ft3 shoe joint volume Total volume= 745 + 26= 771 ft3 => 664 Sx @ 1.16 ft3/sk System: 664 Sx Class G+0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a stage tool set 500' below the aannik 2) interval to +/-500' above the K2 interval with Class G+additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (5,880' —4,852') X 0.1503 ft3/ft X 1.4 (40% excess) =216 ft3 annular vol. Total Volume= 216 ft3=> t85 Sk @ 1.17 ft3/sk System: 185 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk I NI GNAL Nanuq 5 Well Schematic After Suspension 4 FMC Gen.V Wellhead 1 I; ALI I Updated 7/13/05 _ , 16"Conductor to 114' ` I '`?. 1 Ii 1' j`` 9-5/8"40 ppf L-80 BTC j A i Surface Casing @2910'MD/2393'ND cemented to surface 4-'/:tubing circulation string t4 3038'MD with diesel cap 1 and brine from 3038'-6297' MD roc @ 6550' Mo 11 (500'MD above top K2) Completion MD ND ; Tubing Hanger 32' 32 Ili 4-W, 12.6 ppf IBTM tubing 3038' 2464' 1 I WEG(+/-57.2°) Top K2 sand at 1 X10:.. 4111 81 bbls of 11 PPG LiteCrete cement w/additives Assume 6050'MD iii 1111119' ��j�. 75%excess annular volume.IR Bottom K2 sand at qil.� 6160' MD Top of Cement @ 8950'MD Stage Tool set @ 110 7"7"RMLS Latch Coupling at 9665'and 9163' �� 6297'MD 'I ' ;Iii, Note:6.140"ID(Baker-loc connection) '' hl '�4 1 I i, Nanuq @ 9950'MD I 41 II Kuparak @ 11608'MD li v a° =A 7"26 ppf L-80 BTC Mod Production Casing @ 11003'MD/7708'ND @ 57.6° __ , ) tt; -- C9f Colville River Field Nanuq #5 Proposed Plug and Abandon Schematic Prior to Sidetrack of CD4-12 16"Conductor to 114' Updated 07/08/10 • Existing , a Proposed—9.8 LSND to Surface 9-5/8"40 ppf L-80 BTC-Mod .. i 2814' MD Surface Casing 2914' MD/2397'TVD E.,`'. , ,a•:,fia; Proposed Cemented to Surface IHNNOMINNIIIIIII—T°2138°1f4ervirriDent '1. ' '' f`" IIMINHIMMiiiiiii 4--- Proposed CD4-12 KOP 2920' MD "` i Lii:4 Proposed 7"Casing Cut 3014' MD Proposed Top of Bridge Plug 3024' MD Existing 4 Top of Cement Top of K2 Sand 6550' MD 6050' MD Bottom of K2 Sand 6160' MD �:..', O O Top of Stage Tool/Cement 6,297' MD Was not drilled out Existing Top of Cement 8950' MD Nanuq-9950' MD 4—Top of Shoe Track at 10,915' MD Was not drilled out 7"26 ppf L-80 BTC Mod Production Casing 11003'MD/7708'TVD Kuparuk—11608' MD 2(.v— °r( Colville River Field Nanuq #5 Proposed Plug and Abandon Schematic Prior to Sidetrack of CD4-12 #r Updated 07/2/10 A ;� 16"Conductor to 114' Existing Proposed—9.8 LSND to Surface 9-5/8"40 ppf L-80 BTC-Mod 2814'MD Surface Casing 2914'MD/2397'TVD MUMUMEI Proposed Cemented to Surface Top of Cement 2814'MD €" 4 Proposed 'D4-12 KOP •20'MD • Proposed 7"Casing Cut 3014'MD Proposed Top of Bridge Plug 3024'MD Existin �, Top of Cement SUPERCEDED Top of K2 Sand 6550'MD `�, _ 6050'MD r' �r �6 Bottom of K2 Sand ((// 6160'MD Stage Tool ~- 6,297'MD Existing 1—Top of Cement 8950'MD Nanuq 9950'MD 7"26 ppf L-80 BTC Mod Production Casing 11003'MD/7708'TVD Kuparuk—11608'MD ORIGINAL 2,. (t, _• � 1 Colville River Field CD4-12 Pre-Produced Injection Well Completion Schematic '•` 16"Conductor to 114' Updated 07/2/10 L Sperry Drilling WP06 4-'/z"space out pups in °a"0 ii I 32"x 4-%2"cross-over,2 jts below 4-'/2"hanger 3-1/2"Camco TRMAXX-5E SSSV Nipple(2.813"ID) Packer Fluid mix: Diesel in tubing and annulus 9-5/8"40 ppf L-80 BTC-Mod Surface Casing Ulmer Completion MD TVD 2914'MD/2397'TVD 1) Tubing Hanger 32' 32' 2) 4'/"12.6#/ft IBT-Mod Tubing(2) Cement to Cemented to Surface 3) 4-Y:"12.6#/ft IBT-Mod SPACE OUT PUPS +/-4,852'MD/ 4) 3-%2"x 4-14"Crossover 3,732'TVD 5) 3-1/2",9.3#/ft,EUE-Mod Tubing 6) Camco TRMAXX-5E SSSV(2.812"ID) 2200' 1995' Qannik interval top+/- with control line to surface 5352'MD/4087'TVD 7) 3-1/2",9.3#/ft,EUE-Mod Tubing 8) Camco KBMG GLM(2.867"ID)w/dummy 7539' 5639' ` 9) 3-1/2",9.3#/ft,EUE-Mod Tubing 10) Camco KBMG GLM(2.867"ID)w/DCK2 shear 9750' 7016' O 0 HES Stage Tool 11) 3-%"9.3#/ft,EUE-M (1) +/-5880'MD/4406'TVD 12) Baker 3.5"X 7-5/8"Premier Packer 9800' 7036' 13) 3-%"9.3#/ft,EUE-M (2) 14) HES"XN"(2.75"min ID)@ 68° 9900' 7073' 15) 3-%"9.3#/ft,EUE-M 0 16) 3-1/2"9.3#/ft,EUE-M BOT Stinger w/fluted 11247' 7339' GL J WLEG stinger stung 10 ft into tieback extension Lower Completion: Top MD TVD 17) Baker 5"x7"Flexlock Liner Hanger w/setting sleeve(Min 150'up from shoe) 11250' 7339' 18) 4-1/2"12.6#/ft L-80 SLHT Liner 19) 4'1/2"12.6#/ft L-80 SLHT Slotted Liner 20) Orange Peel Shoe 16300' 7347' 3'1/2"Camco KBMG GLM (2.867"DRIFT ID) 0 w/DCK-2 shear valve NOTE:Packer set high in casing to / :...„.:. z keep XN at SL accessable angle. TOC @+/-7825' ®` 6-1/8"Open Hole MD/5842'TVD Att 16 Well TD at Nanuq 8325'MD/6196'ND .� z° 16351'MD/ . Kuparuk C 9923'MD/7080'TVD ' 7347'ND 4'/2"12.6#/ft L-80 IBTM Top Alpine C 11210'MD 17336'TVD 7"26 ppf L-80 BTC Mod Casing Slotted/Blank liner 11363'MD/7345'TVD @ 87° IF EXCURSIONS OCCUR WHILE DRILLING PRODUCTION HOLE OR ! NAL ConocoPhillips(Alaska) Inc. Western North Slope CD4 Nanuq Pad Nanuq 5 Plan: CD4-12 Plan: CD4-12wp06 Standard Proposal Report Permit Apa 29 June, 2010 Large File De NO T Print HALLIBURTON Sperry Drilling Services ORIGINAL 8 m 112 xa��_niiTg I _ 1_. I 8.88 8x8400° LLy.o�11 .. U 000°0000aoo y 9 8.ssissss2�s.� m Inn'iNgIne m gn�, � m o a<8°.98-F-8888S� m ' mm Mm.888°888 V088888888 vi 0 • ° � m _ °rvrvry • N � s<immiglISH A i ry N V \ . 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U M 0 U _ - m N —. a CO 1:" U - a co o � N I�1 \\� � R V M O 111110 I M_C _ `� - C W— y tr d LLI - N U 0 — a> U N U Z ■ m ON co v a U `r • U - p o U p U v — • o U N o — o d m - O C O-a - co , R a _ Y Cr 0 0 1 v R C 0 - aZ4o - _ 0 o .�Z — = wo LE U U o� - - o- C - o - U - - 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 II I 1 1 I I I 1 I I I I 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 (u1/41 005£) 6u141-poN RIGII L I ' ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Nanuq 5 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+19.6 @ 55.90ft(Doyon 19) . Project: Western North Slope MD Reference: Plan:36.3+19.6 @ 55.90ft(Doyon 19) Site: CD4 Nanuq Pad North Reference: True Well: Nanuq 5 Survey Calculation Method: Minimum Curvature . Wellbore: Plan:CD4-12 Design: CD4-12wp06 Project Western North Slope 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 CD4 Nanuq Pad Site Position: Northing: 5,957,908.57ft Latitude: 70° 17'36.666 N From: Map Easting: 377,794.25ft Longitude: 150°59'22.031 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.93° 'Well Nanuq 5 Well Position +N/-S 0.00 ft Northing: 5,957,475.10 ft ' Latitude: 70° 17'32.430 N +El-W 0.00 ft Easting: 377,960.89 ft • Longitude: 150°59'16.970 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 19.60ft . Wellbore Plan:CD4-12 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 6/29/2010 16.53 79.63 57,331 Design CD4-12wp06 Audit Notes: Version: 1 Phase: PLAN Tie On Depth: 2,920.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 36.30 0.00 0.00 154.00 Plan Sections Measured Vertical TVD° Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (0) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (0) 2,920.00 56.50 162.10 2,400.48 2,344.58 -1,232.22 387.41 0.00 0.00 0.00 0.00 2,970.00 55.86 162.56 2,428.31 2,372.41 -1,271.80 400.02 1.50 -1.30 0.91 150.00 3,020.00 55.14 163.81 2,456.63 2,400.73 -1,311.24 411.95 2.50 -1.42 2.50 125.00 4,870.00 44.79 237.65 3,743.99 3,688.09 -2,481.85 43.83 3.00 -0.56 3.99 124.80 8,330.80 44.79 237.65 6,200.00 6,144.10 -3,786.42 -2,016.09 0.00 0.00 0.00 0.00 8,400.80 45.09 236.76 6,249.55 6,193.65 -3,813.20 -2,057.66 1.00 0.43 -1.28 -65.00 9,240.32 57.65 204.79 6,780.90 6,725.00 -4,307.77 -2,462.92 3.30 1.50 -3.81 -74.15 9,616.77 65.18 204.79 6,960.90 6,905.00 -4,607.64 -2,601.44 2.00 2.00 0.00 0.00 11,070.62 87.00 157.00 7,328.60 7,272.70 -5,965.24 -2,593.96 3.50 1.50 -3.29 -72.44 11,362.87 87.00 157.00 7,343.90 7,288.00 -6,233.89 -2,479.92 0.00 0.00 0.00 0.00 11,635.72 90.06 154.26 7,350.90 7,295.00 -6,482.29 -2,367.39 1.51 1.12 -1.00 -41.88 16,350.65 90.06 154.29 7,345.90 7,290.00 -10,729.85 -320.74 0.00 0.00 0.00 86.70 6/29/2010 3:30:40PM Page 2 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Nanuq 5 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+19.6 @ 55.90ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+19.6 @ 55.90ft(Doyon 19) Site: CD4 Nanuq Pad North Reference: True • Well: Nanuq 5 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD4-12 Design: CD4-12wp06 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 2,344.58 l • 2,920.00 56.50 162.10 2,400.48 2,344.58 -1,232.22 387.41 5,956,236.85 378,328.21 0.92 1,277.34 KOP:DLS 1.50 TFO 150.00 2,970.00 55.86 162.56 2,428.31 2,372.41 -1,271.80 400.02 5,956,197.08 378,340.18 1.50 1,318.44 Start DLS 2.50 TFO 125.00 3,000.00 55.43 163.30 2,445.25 2,389.35 -1,295.48 407.29 5,956,173.29 378,347.06 2.50 1,342.91 3,020.00 55.14 163.81 2,456.63 2,400.73 -1,311.24 411.95 5,956,157.45 378,351.46 2.50 1,359.12 Start DLS 3.00 TFO 124.80 3,100.00 53.80 166.25 2,503.13 2,447.23 -1,374.13 428.78 5,956,094.31 378,367.26 3.00 1,423.02 3,200.00 52.19 169.42 2,563.32 2,507.42 -1,452.17 445.63 5,956,016.01 378,382.84 3.00 1,500.55 3,300.00 50.67 172.73 2,625.68 2,569.78 -1,529.38 457.78 5,955,938.62 378,393.74 3.00 1,575.27 3,400.00 49.25 176.18 2,690.02 2,634.12 -1,605.55 465.20 5,955,862.34 378,399.93 3.00 1,646.99 3,500.00 47.93 179.77 2,756.18 2,700.28 -1,680.48 467.88 5,955,787.39 378,401.38 3.00 1,715.51 3,600.00 46.73 183.51 2,823.97 2,768.07 -1,753.95 465.79 5,955,713.97 378,398.11 3.00 1,780.63 3,700.00 45.66 187.40 2,893.20 2,837.30 -1,825.77 458.96 5,955,642.27 378,390.11 3.00 1,842.18 3,800.00 44.72 191.41 2,963.68 2,907.78 -1,895.74 447.39 5,955,572.51 378,377.40 3.00 1,900.00 3,900.00 43.93 195.56 3,035.23 2,979.33 -1,963.66 431.12 5,955,504.86 378,360.03 3.00 1,953.92 4,000.00 43.30 199.81 3,107.65 3,051.75 -2,029.36 410.19 5,955,439.52 378,338.05 3.00 2,003.79 4,100.00 42.82 204.15 3,180.73 3,124.83 -2,092.65 384.66 5,955,376.66 378,311.50 3.00 2,049.48 4,200.00 42.51 208.55 3,254.28 3,198.38 -2,153.35 354.61 5,955,316.46 378,280.46 3.00 2,090.87 4,300.00 42.37 212.99 3,328.09 3,272.19 -2,211.31 320.10 5,955,259.07 378,245.03 3.00 2,127.83 4,400.00 42.40 217.44 3,401.97 3,346.07 -2,266.35 281.25 5,955,204.67 378,205.29 3.00 2,160.28 4,500.00 42.61 221.87 3,475.70 3,419.80 -2,318.34 238.15 5,955,153.39 378,161.35 3.00 2,188.11 4,600.00 42.98 226.25 3,549.10 3,493.20 -2,367.13 190.92 5,955,105.38 378,113.34 3.00 2,211.26 4,700.00 43.52 230.56 3,621.95 3,566.05 -2,412.58 139.69 5,955,060.77 378,061.38 3.00 2,229.65 4,800.00 44.22 234.77 3,694.06 3,638.16 -2,454.58 84.61 5,955,019.68 378,005.63 3.00 2,243.25 4,870.00 44.79 237.65 3,743.99 3,688.09 -2,481.85 43.83 5,954,993.07 377,964.42 3.00 2,249.89 Start 3460.80 hold at 4870.00 MD 4,900.00 44.79 237.65 3,765.28 3,709.38 -2,493.16 25.97 5,954,982.05 377,946.38 0.00 2,252.23 4,985.42 44.79 237.65 3,825.90 3,770.00 -2,525.36 -24.87 5,954,950.68 377,895.03 0.00 2,258.88 K-3 Marker 5,000.00 44.79 237.65 3,836.25 3,780.35 -2,530.86 -33.55 5,954,945.33 377,886.26 0.00 2,260.01 5,100.00 44.79 237.65 3,907.21 3,851.31 -2,568.55 -93.07 5,954,908.61 377,826.14 0.00 2,267.80 5,200.00 44.79 237.65 3,978.18 3,922.28 -2,606.25 -152.59 5,954,871.89 377,766.02 0.00 2,275.59 5,299.65 44.79 237.65 4,048.90 3,993.00 -2,643.81 -211.91 5,954,835.29 377,706.11 0.00 2,283.35 Basal K-3 5,300.00 44.79 237.65 4,049.15 3,993.25 -2,643.94 -212.11 5,954,835.17 377,705.90 0.00 2,283.38 5,351.79 44.79 237.65 4,085.90 4,030.00 -2,663.47 -242.94 5,954,816.15 377,674.76 0.00 2,287.41 K-2 Qannik 5,400.00 44.79 237.65 4,120.11 4,064.21 -2,681.64 -271.63 5,954,798.45 377,645.78 0.00 2,291.17 5,500.00 44.79 237.65 4,191.08 4,135.18 -2,719.33 -331.15 5,954,761.72 377,585.66 0.00 2,298.95 5,501.16 44.79 237.65 4,191.90 4,136.00 -2,719.77 -331.84 5,954,761.30 377,584.96 0.00 2,299.04 Basal K-2 5,600.00 44.79 237.65 4,262.05 4,206.15 -2,757.03 -390.68 5,954,725.00 377,525.54 0.00 2,306.74 5,700.00 44.79 237.65 4,333.01 4,277.11 -2,794.73 -450.20 5,954,688.28 377,465.42 0.00 2,314.53 5,800.00 44.79 237.65 4,403.98 4,348.08 -2,832.42 -509.72 5,954,651.56 377,405.30 0.00 2,322.32 6/29/2010 3:30:40PM Page 3 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Nanuq 5 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+19.6 @ 55.90ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+19.6 @ 55.90ft(Doyon 19) Site: CD4 Nanuq Pad North Reference: True Well: Nanuq 5 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD4-12 Design: CD4-12wp06 I Planned Survey f I Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EI-W Northing Easting DLS Vert Section j (ft) (°) (0) (ft) ft (ft) (ft) (ft) (ft) 4,419.04 5,900.00 44.79 237.65 4,474.94 4,419.04 -2,870.12 -569.24 5,954,614.84 377,345.18 0.00 2,330.11 6,000.00 44.79 237.65 4,545.91 4,490.01 -2,907.81 -628.76 5,954,578.12 377,285.06 0.00 2,337.89 6,100.00 44.79 237.65 4,616.88 4,560.98 -2,945.51 -688.28 5,954,541.40 377,224.94 0.00 2,345.68 6,200.00 44.79 237.65 4,687.84 4,631.94 -2,983.20 -747.80 5,954,504.68 377,164.82 0.00 2,353.47 6,300.00 44.79 237.65 4,758.81 4,702.91 -3,020.90 -807.33 5,954,467.96 377,104.70 0.00 2,361.26 6,400.00 44.79 237.65 4,829.78 4,773.88 -3,058.59 -866.85 5,954,431.23 377,044.58 0.00 2,369.05 6,500.00 44.79 237.65 4,900.74 4,844.84 -3,096.29 -926.37 5,954,394.51 376,984.45 0.00 2,376.83 6,600.00 44.79 237.65 4,971.71 4,915.81 -3,133.99 -985.89 5,954,357.79 376,924.33 0.00 2,384.62 6,700.00 44.79 237.65 5,042.68 4,986.78 -3,171.68 -1,045.41 5,954,321.07 376,864.21 0.00 2,392.41 6,800.00 44.79 237.65 5,113.64 5,057.74 -3,209.38 -1,104.93 5,954,284.35 376,804.09 0.00 2,400.20 6,900.00 44.79 237.65 5,184.61 5,128.71 -3,247.07 -1,164.46 5,954,247.63 376,743.97 0.00 2,407.99 7,000.00 44.79 237.65 5,255.58 5,199.68 -3,284.77 -1,223.98 5,954,210.91 376,683.85 0.00 2,415.77 7,100.00 44.79 237.65 5,326.54 5,270.64 -3,322.46 -1,283.50 5,954,174.19 376,623.73 0.00 2,423.56 7,200.00 44.79 237.65 5,397.51 5,341.61 -3,360.16 -1,343.02 5,954,137.47 376,563.61 0.00 2,431.35 7,300.00 44.79 237.65 5,468.48 5,412.58 -3,397.85 -1,402.54 5,954,100.74 376,503.49 0.00 2,439.14 7,400.00 44.79 237.65 5,539.44 5,483.54 -3,435.55 -1,462.06 5,954,064.02 376,443.37 0.00 2,446.92 7,500.00 44.79 237.65 5,610.41 5,554.51 -3,473.24 -1,521.58 5,954,027.30 376,383.25 0.00 2,454.71 7,600.00 44.79 237.65 5,681.37 5,625.47 -3,510.94 -1,581.11 5,953,990.58 376,323.13 0.00 2,462.50 7,700.00 44.79 237.65 5,752.34 5,696.44 -3,548.64 -1,640.63 5,953,953.86 376,263.01 0.00 2,470.29 7,800.00 44.79 237.65 5,823.31 5,767.41 -3,586.33 -1,700.15 5,953,917.14 376,202.89 0.00 2,478.08 7,860.02 44.79 237.65 5,865.90 5,810.00 -3,608.95 -1,735.87 5,953,895.10 376,166.80 0.00 2,482.75 Albian 97 7,900.00 44.79 237.65 5,894.27 5,838.37 -3,624.03 -1,759.67 5,953,880.42 376,142.77 0.00 2,485.86 8,000.00 44.79 237.65 5,965.24 5,909.34 -3,661.72 -1,819.19 5,953,843.70 376,082.65 0.00 2,493.65 8,100.00 44.79 237.65 6,036.21 5,980.31 -3,699.42 -1,878.71 5,953,806.97 376,022.52 0.00 2,501.44 8,200.00 44.79 237.65 6,107.17 6,051.27 -3,737.11 -1,938.23 5,953,770.25 375,962.40 0.00 2,509.23 8,300.00 44.79 237.65 6,178.14 6,122.24 -3,774.81 -1,997.76 5,953,733.53 375,902.28 0.00 2,517.02 8,325.03 44.79 237.65 6,195.90 6,140.00 -3,784.24 -2,012.65 5,953,724.34 375,887.24 0.00 2,518.97 Albian 96 8,330.80 44.79 237.65 6,200.00 6,144.10 -3,786.42 -2,016.09 5,953,722.22 375,883.76 0.00 2,519.42 Start DLS 1.00 TFO-65.00 8,400.00 45.09 236.77 6,248.98 6,193.08 -3,812.89 -2,057.18 5,953,696.42 375,842.25 1.00 2,525.19 8,400.80 45.09 236.76 6,249.55 6,193.65 -3,813.20 -2,057.66 5,953,696.12 375,841.77 1.00 2,525.27 Start DLS 3.30 TFO-74.15 8,500.00 46.07 232.38 6,318.99 6,263.09 -3,854.27 -2,115.35 5,953,655.99 375,783.43 3.30 2,536.89 8,600.00 47.22 228.13 6,387.66 6,331.76 -3,900.76 -2,171.21 5,953,610.42 375,726.82 3.30 2,554.18 8,700.00 48.52 224.04 6,454.76 6,398.86 -3,952.20 -2,224.59 5,953,559.86 375,672.62 3.30 2,577.01 8,800.00 49.96 220.12 6,520.06 6,464.16 -4,008.41 -2,275.31 5,953,504.48 375,620.99 3.30 2,605.31 8,900.00 51.53 216.37 6,583.35 6,527.45 -4,069.23 -2,323.20 5,953,444.46 375,572.13 3.30 2,638.97 9,000.00 53.21 212.78 6,644.42 6,588.52 -4,134.43 -2,368.11 5,953,380.00 375,526.18 3.30 2,677.89 9,100.00 54.99 209.35 6,703.06 6,647.16 -4,203.81 -2,409.87 5,953,311.31 375,483.29 3.30 2,721.94 9,200.00 56.87 206.07 6,759.09 6,703.19 -4,277.14 -2,448.36 5,953,238.63 375,443.62 3.30 2,770.98 9,240.32 57.65 204.79 6,780.90 6,725.00 -4,307.77 -2,462.92 5,953,208.24 375,428.57 3.30 2,792.12 Start DLS 2.00 TFO 0.00 6/29/2010 3:30:40PM 0 Rafe IN L COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Nanuq 5 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+19.6 @ 55.90ft(Doyon 19) Project: Western North Slope MD Reference: Plan: 36.3+19.6 @ 55.90ft(Doyon 19) Site: CD4 Nanuq Pad North Reference: True Well: Nanuq 5 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD4-12 Design: CD4-12wp06 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (0) (ft) ft (ft) (ft) (ft) (ft) 6,735.00 I 9,259.11 58.02 204.79 6,790.90 6,735.00 -4,322.20 -2,469.59 5,953,193.92 375,421.67 2.00 2,802.17 HRZ 9,300.00 58.84 204.79 6,812.31 6,756.41 -4,353.83 -2,484.20 5,953,162.53 375,406.54 2.00 2,824.20 9,400.00 60.84 204.79 6,862.54 6,806.64 -4,432.32 -2,520.46 5,953,084.64 375,369.02 2.00 2,878.85 1 9,500.00 62.84 204.79 6,909.73 6,853.83 -4,512.36 -2,557.42 5,953,005.23 375,330.76 2.00 2,934.58 9,593.16 64.71 204.79 6,950.90 6,895.00 -4,588.22 -2,592.47 5,952,929.94 375,294.50 2.00 2,987.41 Base HRZ 9,600.00 64.84 204.79 6,953.81 6,897.91 -4,593.84 -2,595.06 5,952,924.37 375,291.81 2.00 2,991.31 9,616.77 65.18 204.79 6,960.90 6,905.00 -4,607.64 -2,601.44 5,952,910.68 375,285.21 2.00 3,000.93 Start DLS 3.50 TFO-72.44 9,700.00 66.09 201.75 6,995.24 6,939.34 -4,677.28 -2,631.38 5,952,841.55 375,254.15 3.50 3,050.39 9,738.96 66.53 200.35 7,010.90 6,955.00 -4,710.57 -2,644.20 5,952,808.46 375,240.79 3.50 3,074.70 K-1 Marker 9,800.00 67.26 198.16 7,034.85 6,978.95 -4,763.57 -2,662.70 5,952,755.78 375,221.43 3.50 3,114.22 9,900.00 68.51 194.63 7,072.51 7,016.61 -4,852.43 -2,688.84 5,952,667.36 375,193.86 3.50 3,182.62 9,923.04 68.81 193.83 7,080.90 7,025.00 -4,873.23 -2,694.11 5,952,646.65 375,188.24 3.50 3,199.01 Kuparuk C 9,950.93 69.17 192.86 7,090.90 7,035.00 -4,898.56 -2,700.12 5,952,621.42 375,181.83 3.50 3,219.14 LCU-Miluveach 10,000.00 69.83 191.17 7,108.09 7,052.19 -4,943.51 -2,709.69 5,952,576.63 375,171.53 3.50 3,255.35 10,100.00 71.22 187.76 7,141.44 7,085.54 -5,036.49 -2,725.17 5,952,483.93 375,154.55 3.50 3,332.13 10,200.00 72.67 184.41 7,172.44 7,116.54 -5,131.01 -2,735.23 5,952,389.59 375,142.95 3.50 3,412.68 10,300.00 74.17 181.11 7,200.98 7,145.08 -5,226.73 -2,739.83 5,952,293.97 375,136.80 3.50 3,496.69 10,400.00 75.73 177.86 7,226.95 7,171.05 -5,323.28 -2,738.95 5,952,197.43 375,136.11 3.50 3,583.85 10,500.00 77.32 174.66 7,250.26 7,194.36 -5,420.30 -2,732.60 5,952,100.32 375,140.88 3.50 3,673.84 10,600.00 78.96 171.50 7,270.82 7,214.92 -5,517.43 -2,720.80 5,952,003.02 375,151.11 3.50 3,766.31 10,700.00 80.62 168.37 7,288.55 7,232.65 -5,614.32 -2,703.59 5,951,905.88 375,166.74 3.50 3,860.94 10,800.00 82.32 165.27 7,303.38 7,247.48 -5,710.59 -2,681.04 5,951,809.26 375,187.72 3.50 3,957.35 10,900.00 84.04 162.20 7,315.26 7,259.36 -5,805.89 -2,653.24 5,951,713.53 375,213.97 3.50 4,055.20 10,936.98 84.67 161.07 7,318.90 7,263.00 -5,840.81 -2,641.64 5,951,678.42 375,225.00 3.50 4,091.67 Alpine D 11,000.00 85.77 159.15 7,324.15 7,268.25 -5,899.87 -2,620.27 5,951,619.04 375,245.40 3.50 4,154.11 11,070.62 87.00 157.00 7,328.60 7,272.70 -5,965.24 -2,593.96 5,951,553.25 375,270.65 3.50 4,224.41 Start 292.25 hold at 11070.62 MD 11,100.00 87.00 157.00 7,330.14 7,274.24 -5,992.25 -2,582.49 5,951,526.06 375,281.68 0.00 4,253.71 11,200.00 87.00 157.00 7,335.38 7,279.48 -6,084.17 -2,543.47 5,951,433.52 375,319.19 0.00 4,353.43 11,210.01 87.00 157.00 7,335.90 7,280.00 -6,093.38 -2,539.57 5,951,424.25 375,322.95 0.00 4,363.42 Alpine C 11,300.00 87.00 157.00 7,340.61 7,284.71 -6,176.10 -2,504.46 5,951,340.98 375,356.71 0.00 4,453.16 11,362.87 87.00 157.00 7,343.90 7,288.00 -6,233.89 -2,479.92 5,951,282.80 375,380.30 0.00 4,515.86 Start DLS 1.51 TFO-41.88-7"x 8-3/4" 11,400.00 87.42 156.63 7,345.71 7,289.81 -6,267.98 -2,465.32 5,951,248.49 375,394.35 1.51 4,552.90 11,500.00 88.54 155.62 7,349.24 7,293.34 -6,359.36 -2,424.87 5,951,156.47 375,433.30 1.51 4,652.76 11,600.00 89.66 154.62 7,350.81 7,294.91 -6,450.07 -2,382.81 5,951,065.10 375,473.89 1.51 4,752.73 6/29/2010 3:30:40PM Page 5 COMPASS 2003.16 Build 69 OrR , GINAL ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Nanuq 5 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+19.6 @ 55.90ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+19.6 @ 55.90ft(Doyon 19) Site: CD4 Nanuq Pad North Reference: True Well: Nanuq 5 Survey Calculation Method: Minimum Curvature Weilbore: Plan:CD4-12 Design: CD4-12wp06 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (0) (°) (ft) ft (ft) (ft) (ft) (ft) 7,295.00 11,635.72 90.06 154.26 7,350.90 7,295.00 -6,482.29 -2,367.39 5,951,032.63 375,488.77 1.51 4,788.45 Start DLS 0.00 TFO 68.15-UJU 11,700.00 90.06 154.26 7,350.83 7,294.93 -6,540.19 -2,339.48 5,950,974.29 375,515.74 0.00 4,852.73 11,800.00 90.06 154.26 7,350.73 7,294.83 -6,630.27 -2,296.05 5,950,883.52 375,557.70 0.00 4,952.73 11,900.00 90.06 154.26 7,350.62 7,294.72 -6,720.35 -2,252.62 5,950,792.76 375,599.65 0.00 5,052.73 12,000.00 90.06 154.26 7,350.52 7,294.62 -6,810.43 -2,209.20 5,950,702.00 375,641.61 0.00 5,152.72 12,100.00 90.06 154.26 7,350.41 7,294.51 -6,900.51 -2,165.77 5,950,611.23 375,683.56 0.00 5,252.72 12,200.00 90.06 154.26 7,350.31 7,294.41 -6,990.59 -2,122.35 5,950,520.47 375,725.52 0.00 5,352.72 12,300.00 90.06 154.26 7,350.20 7,294.30 -7,080.67 -2,078.93 5,950,429.70 375,767.47 0.00 5,452.72 12,400.00 90.06 154.26 7,350.10 7,294.20 -7,170.75 -2,035.50 5,950,338.93 375,809.42 0.00 5,552.72 12,500.00 90.06 154.26 7,349.99 7,294.09 -7,260.83 -1,992.08 5,950,248.17 375,851.37 0.00 5,652.72 12,600.00 90.06 154.27 7,349.89 7,293.99 -7,350.91 -1,948.66 5,950,157.40 375,893.32 0.00 5,752.72 12,700.00 90.06 154.27 7,349.78 7,293.88 -7,440.99 -1,905.24 5,950,066.63 375,935.27 0.00 5,852.72 12,800.00 90.06 154.27 7,349.68 7,293.78 -7,531.07 -1,861.82 5,949,975.87 375,977.21 0.00 5,952.72 12,900.00 90.06 154.27 7,349.57 7,293.67 -7,621.16 -1,818.40 5,949,885.10 376,019.16 0.00 6,052.71 13,000.00 90.06 154.27 7,349.47 7,293.57 -7,711.24 -1,774.99 5,949,794.33 376,061.10 0.00 6,152.71 13,100.00 90.06 154.27 7,349.36 7,293.46 -7,801.32 -1,731.57 5,949,703.56 376,103.05 0.00 6,252.71 13,200.00 90.06 154.27 7,349.26 7,293.36 -7,891.41 -1,688.16 5,949,612.79 376,144.99 0.00 6,352.71 13,300.00 90.06 154.27 7,349.15 7,293.25 -7,981.49 -1,644.74 5,949,522.02 376,186.94 0.00 6,452.71 13,400.00 90.06 154.27 7,349.04 7,293.14 -8,071.58 -1,601.33 5,949,431.25 376,228.88 0.00 6,552.71 13,500.00 90.06 154.27 7,348.94 7,293.04 -8,161.66 -1,557.91 5,949,340.48 376,270.82 0.00 6,652.71 13,600.00 90.06 154.27 7,348.83 7,292.93 -8,251.75 -1,514.50 5,949,249.71 376,312.76 0.00 6,752.71 13,700.00 90.06 154.27 7,348.73 7,292.83 -8,341.83 -1,471.09 5,949,158.94 376,354.70 0.00 6,852.71 13,800.00 90.06 154.27 7,348.62 7,292.72 -8,431.92 -1,427.68 5,949,068.17 376,396.64 0.00 6,952.70 13,900.00 90.06 154.27 7,348.51 7,292.61 -8,522.01 -1,384.27 5,948,977.40 376,438.58 0.00 7,052.70 14,000.00 90.06 154.27 7,348.41 7,292.51 -8,612.09 -1,340.86 5,948,886.62 376,480.51 0.00 7,152.70 14,100.00 90.06 154.27 7,348.30 7,292.40 -8,702.18 -1,297.46 5,948,795.85 376,522.45 0.00 7,252.70 14,200.00 90.06 154.27 7,348.20 7,292.30 -8,792.27 -1,254.05 5,948,705.08 376,564.38 0.00 7,352.70 14,300.00 90.06 154.27 7,348.09 7,292.19 -8,882.36 -1,210.64 5,948,614.30 376,606.32 0.00 7,452.70 14,400.00 90.06 154.28 7,347.98 7,292.08 -8,972.45 -1,167.24 5,948,523.53 376,648.25 0.00 7,552.70 14,500.00 90.06 154.28 7,347.88 7,291.98 -9,062.53 -1,123.83 5,948,432.76 376,690.18 0.00 7,652.70 14,600.00 90.06 154.28 7,347.77 7,291.87 -9,152.62 -1,080.43 5,948,341.98 376,732.11 0.00 7,752.69 14,700.00 90.06 154.28 7,347.66 7,291.76 -9,242.71 -1,037.03 5,948,251.21 376,774.04 0.00 7,852.69 14,800.00 90.06 154.28 7,347.56 7,291.66 -9,332.80 -993.63 5,948,160.43 376,815.97 0.00 7,952.69 14,900.00 90.06 154.28 7,347.45 7,291.55 -9,422.90 -950.23 5,948,069.65 376,857.90 0.00 8,052.69 15,000.00 90.06 154.28 7,347.35 7,291.45 -9,512.99 -906.83 5,947,978.88 376,899.83 0.00 8,152.69 15,100.00 90.06 154.28 7,347.24 7,291.34 -9,603.08 -863.43 5,947,888.10 376,941.76 0.00 8,252.69 15,200.00 90.06 154.28 7,347.13 7,291.23 -9,693.17 -820.03 5,947,797.32 376,983.68 0.00 8,352.69 15,300.00 90.06 154.28 7,347.03 7,291.13 -9,783.26 -776.63 5,947,706.55 377,025.61 0.00 8,452.69 15,400.00 90.06 154.28 7,346.92 7,291.02 -9,873.36 -733.24 5,947,615.77 377,067.53 0.00 8,552.68 15,500.00 90.06 154.28 7,346.81 7,290.91 -9,963.45 -689.84 5,947,524.99 377,109.46 0.00 8,652.68 15,600.00 90.06 154.28 7,346.70 7,290.80 -10,053.54 -646.45 5,947,434.21 377,151.38 0.00 8,752.68 15,700.00 90.06 154.28 7,346.60 7,290.70 -10,143.64 -603.05 5,947,343.43 377,193.30 0.00 8,852.68 15,800.00 90.06 154.28 7,346.49 7,290.59 -10,233.73 -559.66 5,947,252.65 377,235.22 0.00 8,952.68 15,900.00 90.06 154.28 7,346.38 7,290.48 -10,323.83 -516.27 5,947,161.87 377,277.14 0.00 9,052.68 6/29/2010 3.30:40PM Page 6 COMPASS 2003.16 Build 69 ORIGiNAL ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Nanuq 5 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan: 36.3+19.6 @ 55.90ft(Doyon 19) Project: Western North Slope MD Reference: Plan: 36.3+19.6 @ 55.90ft(Doyon 19) Site: CD4 Nanuq Pad North Reference: True Well: Nanuq 5 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD4-12 Design: CD4-12wp06 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 7,290.38 16,000.00 90.06 154.28 7,346.28 7,290.38 -10,413.92 -472.88 5,947,071.09 377,319.06 0.00 9,152.68 16,100.00 90.06 154.28 7,346.17 7,290.27 -10,504.02 -429.49 5,946,980.31 377,360.98 0.00 9,252.68 16,200.00 90.06 154.29 7,346.06 7,290.16 -10,594.12 -386.10 5,946,889.53 377,402.90 0.00 9,352.67 16,300.00 90.06 154.29 7,345.95 7,290.05 -10,684.21 -342.71 5,946,798.74 377,444.81 0.00 9,452.67 16,350.65 90.06 154.29 7,345.90+ 7,290.00 -10,729.85 -320.74 5,946,752.77 377,466.04 0.00 9,503.32 CD4-12wp05 Toe 6/29/2010 3:30:40PM aO7G1NAL e 7 COMPASS 2003.16 Build 69 ConocoPhillips HALLIBURTON Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Nanuq 5 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+19.6 @ 55.90ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+19.6 @ 55.90ft(Doyon 19) Site: CD4 Nanuq Pad North Reference: True Well: Nanuq 5 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD4-12 Design: CD4-12wp06 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (') (1 (ft) (ft) (ft) (ft) (ft) CD4-12wp05 Toe 0.00 0.00 7,345.90 -10,729.85 -320.74 5,946,752.77 377,466.04 -plan hits target center -Point CD4-12wp05 GeoPoly 0.00 0.00 7,347.00 -6,143.86 -2,337.66 5,951,370.50 375,524.00 1 -plan misses target center by 166.20ft at 11335.79ft MD(7342.48 TVD,-6208.99 N,-2490.49 E) -Polygon Point 1 7,347.00 -6,143.86 -2,337.66 5,951,370.50 375,524.00 Point 2 7,347.00 -6,313.96 -2,252.12 5,951,199.05 375.606.76 Point 3 7,347.00 -6,537.29 -2,139.81 5,950,973.95 375,715.42 Point 4 7,347.00 -6,760.58 -2,027.43 5,950,748.88 375,824.15 Point 5 7,347.00 -6,983.85 -1,914.99 5,950,523.83 375,932.94 Point 6 7,347.00 -7,207.07 -1,802.50 5,950,298.84 376,041.79 Point 7 7,347.00 -7,430.29 -1,689.97 5,950,073.84 376,150.67 Point 8 7,347.00 -7,653.47 -1,577.39 5,949,848.88 376,259.60 Point 9 7,347.00 -7,876.64 -1,464.77 5,949,623.93 376,368.57 Point 10 7,347.00 -8,099.79 -1,352.12 5,949,399.00 376,477.58 Point 11 7,347.00 -8,322.92 -1,239.43 5,949,174.09 376,586.62 Point 12 7,347.00 -8,546.04 -1,126.71 5,948,949.18 376,695.69 Point 13 7,347.00 -8,769.13 -1,013.95 5,948,724.31 376,804.81 Point 14 7,347.00 -8,992.22 -901.19 5,948,499.44 376,913.92 Point 15 7,347.00 -9,215.30 -788.40 5,948,274.58 377,023.07 Point 16 7,347.00 -9,438.36 -675.56 5,948,049.73 377,132.26 Point 17 7,347.00 -9,661.41 -562.74 5,947,824.90 377,241.44 Point 18 7,347.00 -9,884.46 -449.87 5,947,600.06 377,350.66 Point 19 7,347.00 -10,107.50 -336.99 5,947,375.24 377,459.90 Point 20 7,347.00 -10,330.52 -224.10 5,947,150.43 377,569.14 Point 21 7,347.00 -10,553.54 -111.20 5,946,925.63 377,678.40 Point 22 7,347.00 -10,787.46 -566.28 5,946,699.15 377,219.62 Point 23 7,347.00 -10,562.11 -674.67 5,946,926.21 377,114.91 Point 24 7,347.00 -10,336.78 -783.07 5,947,153.25 377,010.19 Point 25 7,347.00 -10,111.45 -891.48 5,947,380.29 376,905.46 Point 26 7,347.00 -9,886.12 -999.90 5,947,607.33 376,800.72 Point 27 7,347.00 -9,660.82 -1,108.36 5,947,834.35 376,695.94 Point 28 7,347.00 -9,435.51 -1,216.82 5,948,061.37 376,591.17 Point 29 7,347.00 -9,210.23 -1,325.32 5,948,288.36 376,486.35 Point 30 7,347.00 -8,984.95 -1,433.84 5,948,515.35 376,381.51 Point 31 7,347.00 -8,759.69 -1,542.37 5,948,742.33 376,276.66 Point 32 7,347.00 -8,534.43 -1,650.94 5,948,969.30 376,171.77 Point 33 7,347.00 -8,309.21 -1,759.54 5,949,196.24 376,066.85 Point 34 7,347.00 -8,083.99 -1,868.17 5,949,423.17 375,961.89 Point 35 7,347.00 -7,858.79 -1,976.85 5,949,650.09 375,856.89 Point 36 7,347.00 -7,633.62 -2,085.56 5,949,876.97 375,751.86 Point 37 7,347.00 -7,408.46 -2,194.30 5,950,103.85 375,646.80 Point 38 7,347.00 -7,183.33 -2,303.10 5,950,330.70 375,541.68 Point 39 7,347.00 -6,958.23 -2,411.94 5,950,557.52 375,436.52 Point 40 7,347.00 -6,733.15 -2,520.85 5,950,784.31 375,331.28 • Point 41 7,347.00 -6,508.11 -2,629.83 5,951,011.08 375,225.98 Point42 7,347.00 -6,336.71 -2,712.85 5,951,183.79 375,145.76 CD4-12wp06 Heel 0.00 0.00 7,343.90 -6,244.67 -2,533.82 5,951,272.90 375,326.24 -plan misses target center by 53.83ft at 11351.75ft MD(7343.32 TVD,-6223.67 N,-2484.26 E) -Point 6/29/2010 3:30:40PM Page 8 COMPASS 2003.16 Build 69 nnirfmAl ConocoPhillips I-1 A I.:.,LI BU RTO N Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Nanuq 5 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Plan:36.3+19.6 @ 55.90ft(Doyon 19) Project: Western North Slope MD Reference: Plan:36.3+19.6 @ 55.90ft(Doyon 19) Site: CD4 Nanuq Pad North Reference: True Well: Nanuq 5 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD4-12 Design: CD4-12wp06 I Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 2,913.59 2,396.95 9-5/8"x 12-1/4" 9-5/8 12-1/4 11,362.87 7,343.90 7"x 8-3/4" 7 8-3/4 16,351.01 7,345.90 4-1/2"x 6-1/8" 4-1/2 6-1/8 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (0) (0) 9,738.96 7,010.90 K-1 Marker 9,593.16 6,950.90 Base HRZ 9,259.11 6,790.90 HRZ I 11,210.01 7,335.90 Alpine C I 9,923.04 7,080.90 Kuparuk C 5,351.79 4,085.90 K-2 Qannik 9,950.93 7,090.90 LCU-Miluveach 5,501.16 4,191.90 Basal K-2 4,985.42 3,825.90 K-3 Marker 7,860.02 5,865.90 Albian 97 5,299.65 4,048.90 Basal K-3 10,936.98 7,318.90 Alpine D 8,325.03 6,195.90 Albian 96 11,635.72 7,350.90 UJU Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 2,920.00 2,400.48 -1,232.22 387.41 KOP:DLS 1.50 TFO 150.00 2,970.00 2,428.31 -1,271.80 400.02 Start DLS 2.50 TFO 125.00 3,020.00 2,456.63 -1,311.24 411.95 Start DLS 3.00 TFO 124.80 4,870.00 3,743.99 -2,481.85 43.83 Start 3460.80 hold at 4870.00 MD 8,330.80 6,200.00 -3,786.42 -2,016.09 Start DLS 1.00 TFO-65.00 8,400.80 6,249.55 -3,813.20 -2,057.66 Start DLS 3.30 TFO-74.15 9,240.32 6,780.90 -4,307.77 -2,462.92 Start DLS 2.00 TFO 0.00 9,616.77 6,960.90 -4,607.64 -2,601.44 Start DLS 3.50 TFO-72.44 11,070.62 7,328.60 -5,965.24 -2,593.96 Start 292.25 hold at 11070.62 MD 11,362.87 7,343.90 -6,233.89 -2,479.92 Start DLS 1.51 TFO-41.88 11,635.72 7,350.90 -6,482.29 -2,367.39 Start DLS 0.00 TFO 68.15 16,351.01 TD at 16351.01 6/29/2010 3:30:40PM Page 9 COMPASS 2003.16 Build 69 ORIGINAL Z w co 0 - I UJ mW figli -J M o Qz i.- = to CO -0 _� 1 _ O A N • co C N O d N c c0 0 N U N N 0 C7 O O _ O d fl W O 03 N Ce N 0 in �_ r O lin t L 7 Z O Cl Z U v o Cl) N O LIIIII t RI 0.1 •t- E CNI O U o t N 3 O N• d W n %MOO III MU CI) c . o o y cam- a, Q — U▪ c Q ■_ C 16 f� p LL Q _ O Z m d W ■ C m a `- 6 .` � a • O a 0 '�• a z g °. 1° as ,^ ■■ Y 7 N M U Lt 13•V/ 73 E A N + 0 N CP F • O2 Tr ^ p n Ti. 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N • O. - CD I / I E' U 0 30- - c U / , 0 1 I 1 I I I I I I 1 I I I I i I I 1 I I I I I 1 I 1 1 - 3000 3200 3400 3600 3800 4000 Measured Depth LEGEND p CD4-214,CD4-214,CD4-214 V3 -e-- CD4-17,CD4-17,CD4-17 V13 -a- CD4-318,CD4-318A,CD4-318A V5 -s-- CD4-208,CD4-208,CD4-208 V7 Plan:CD4-303,Plan:CD4-303,CD4-303wp06 V7 _48._ CD4-24,CD4-24PB1,CD4-24PB1 VO -i-- CD4-318,CD4-318PB1,CD4-318PB1 V3 -0- CD4-209,CD4-209,CD4-209 V4 - Plan:CD4-303,Plan:CD4-303PB1,CD4-303PB1wpBXV8 CD4-24,CD4-24PB2,CD4-24PB2 VO -8- CD4-16,CD4-16,CD4-16 V2 -X- CD4-211,CD4-211,CD4-211 V2 - CD4-301,CD4-301,CD4-301 VO -A- CD4-24,CD4-24,CD4-24 VO -e- CD4-213,CD4-213,CD4-213wp06 VO -A- CD4-302,CD4-302,CD4-302 V3 - CD4-301,CD4-301B,CD4-3018 VO -i- CD4-306,C04-306,CD4-306 V1 _49- CD4-213,CD4-213,CD4-213 V4 -I- CD4-210,CD4-210,CD4-210 V3 -X- CD4-301,CD4-301A,CD4-301A VO -B- CD4-304,CD4-304,CD4-304 V6 X Rig:C04-23,Rig:CD4-23,CD4-23 RigSurveys VO-El- CD4-320,CD4-320,CD4-320 V7 CD4-319,CD4-319,CD4-319 V5 _e_ CD4-304,CD4-304P61,CD4-304PB1 V16 --At- CD4-321,CD4-321,CD4-321 V16 _e_ CD4-320,CD4-320P81,CD4-320PB1 V4 - CD4-07,CD4-07,CD4-07 V1 -0- CD4-215,CD4-215,CD4-215 V4 -I- Nanuq 5,Nanuq 5,Nanuq 5 V1 -0- CD4-05,CD4-05,CD4-05 VO - CD4-322,CD4-322,CD4-322 V8 -X- CD4-318,CD4-318,CD4-318 V6 _e_ CD4-208,CD4-208PB1,CD4-208PB1 V6 -8- CD4-12wp06 f.°�'' I i I . 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C 1....., 1 I 00001 9141141 IIIIIM � 91so141 r ®R 0006 9196041 �� _. v /7,' 9149041 N $ dd a °a .°o g N a $ p N 4 ^ ^ 4 1 000e §591 (-)41noS/(+)4YoN b c o 0009 a m m N a 6 0 A 0 > s Z 0005 m u 4 N I 3o 0 O> MIK 0 2 7,' 000b e � ; O o orapoi �� 000E in co g / aooz Nc 9 1 , ` M O a M o & N O o 0001 u U d in 0 I t0 2 I1 O a <> 0001 0 4 4 3 c x > a) 0 0 0 > 0 0 V c . 000Z 0 t> i6 E 000E- L K d g Uldec 10011.0A enil wels6S U 0 AP4 g2 ( / \ ~ 5 le0A { , r9 '2 31 0 0 \ } \ co / \ ) zw ) / 2 CO \ ) C•1 cn < ■ § ) O \ I L | ) 22 ; \) 2 § / _§ >- U § } a S ` / \ q �• \ \ \ £ C ) R ° .. u % CI) ct - < 8 = 3 a)• - < N- o J 20 U 0 a $ � f - • t5 $ 1 0 2i [ ) R | G | N A L I_ CD4-12wp06 Surface Location n CPAI Coot climate Converter From: , To: , Datum: INAD83 H Region: Ialaska 2:j Datum: NAD27 _..7.j Region: I 1 ialaska ■■• 1 ' r Latitude/Longitude !Decimal Degrees .....1 r Latitude/Longitude Decimal Degrees zi l I (-- UTM Zone: I E South r LI T M Zone: I ITrue r South i';' State Plane Zone: 1,.FE,.. Units: L.F.ir E. r State Plane Zone: r-r—ru-E.,---,,-1 Llnits: F.,75--.71 C Leal Description INAD 2;,'L:nlyr (;- Legal Description(NAD27 only) Starting Coordinates: -- Legal Description X. 11517994.40 Township: [ill IN H Range: 1004 frA ..);: 15957222.25 Meridian: 1T-----;1 Section:124 ----- , !RC - 2937.0284 FE .-"-•J 1283.08034 Transform I Quit I Help 1 [ CD4-12wp06 Intermediate Casing In CPAI Coordinate Converter 1— 1 ,El LiJ- 1 _... , From: To: Datum: I INAD83 .- Region: I ialaska J Datum: I INAD27 21 Region: lalaska ...7.1 C.- Latitude/Longitude !Decimal Degrees ■ C- Latitude/Longitude !Decimal Degrees .2.1 C- UTM Zone: I 7 South r UTM Zone: I i True 1 4.- State Plane Zone: 14-71 Units: W-76----: ....I I State Plane Zone: Units: I_Fii. ._.. Legal Description(NAD27 only) Starting Coordinates: Legal Description ..-X. 11515413.50 Township: r oll F.:.A. Range: I 1004 1TE Y: 15951030.03 Meridian: F_T-- ---;:i 5...125 FT,, F991.1725 FEL -rj 12763.8145 Transform Quit I Help 1 f R r CD4-12wp06 TD CRAI Coordinate Converter - • L.,..._. 11::JUti From: _._—,-- —To: 1 Datum: INAD33 +I Region: Ialaska + Dab-am: NAD27 Region: �alaska ■+� I r- Latitude/Longitude 'Decimal Degree:.: ■' C Latitude/Longitude 'Decimal Degrees J 1. LITM Zone: I South C LITIVi Zone: True 1r South r: State Plane Zone: Fr +I Units: us-fk {` State Plane gone: True Units: us ft tei" Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 1151 7500.00 Township: 011 N Range: 004 E + Y: 15946500.00 Meridian. II— Section:136 FhJL ■ 1 +3106.3974 FEL + 1604.23730 Transform I Quit I Help I REV DATE BY CK _ APP DESCRIPTION REV DATE BY APP DESCRIPTION 8 2/25/08 CZ GD C.A. UPDATED PER K080010ACS 9 4/02/09 CZ DB C.A. UPDATED PER K090003ACS N 1° _ /r \< t% ' \ ��• CD4 TO ALPINE 9 _ •'' fir. 1 te ACCESS ROAD (,y �� R1 i ' � o r„Aidirdk LOCATION OF 5 / m .m.4A, � THIS SURVEY \ <� 7„... -rd kl 11 G .P1ItiItL® CD4 /O°`Q mil "" vilis ALPINE SATELLITE DEVELOPMENT MCI VICINITY MAP NOT TO SCALE A C7R R�0 GP�ES DESIGN SHOUL°ER OF PAD—` CD-4 PAD Ns o�°%'`d CN MIFp M m -_I0 p∎,• • 'M00 LE / i • a vs Ml �� PRHEATER�� PIGGING V LE Z 1 Na-0 ' 'SMpDU V SK PLANT CD-4 TO ALPINE N PIPELINE ASN PC 13'2750" • LCMF 41 id Lo c / Z Z LEGEND: K U U K P I K N ° 0 PROPOSED CONDUCTOR 0 LCMFU. w o • EXISTING CONDUCTOR N N A EXISTING WELLHEAD 130E.51 et Ave.•Anchorage.Alaska 80503•(007)2731830 o ABANDONED WELL Al lne 011lce (907)670<79 Alpine Survey Office yV ALPINE MODULE:CD40 UNIT: CD C.noc.Phillips ALPINE PROJECT CD-4 WELL CONDUCTORS Alaska, Inc. AS—BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05-03-03-1B-1 10/11/05 CE—CD 40-121 1 OF 3 9 11 t A) MINAL , REV DATE BY CK APP DESCRIPTION REV DATE BY APP DESCRIPTION 5 2/25/08 CZ GD C.A. UPDATED PER K080010ACS 6 4/02/09 CZ DB C.A. UPDATED PER K090003ACS1 ALL CONDUCTORS ARE LOCATED IN PROTRACTED SEC.24, T 11 N, R 4 E, U.M. SEC.LINE 0/S EXIST. WELL 'Y' 'X' LAT.(N) LONG.(W) FSL FEL GND PAD CD4-X98 5,957,282.22 ,518,247.43 70' 17' 31.873" 150' 59' 20.893" 2407' 31' 12.4 19.1 CD4-X99 5,957,277.98 ,518,227.75 70' 17' 31.828" 150' 59' 21.464" 2402' 51' 12.4 19.0 CD4-301B 5,957,273.28 ,518,208.24 70' 17' 31.779" 150° 59' 22.030" 2397' 70' 12.4 19.0 CD4-302 5,957,268.38 ,518,188.64 70' 17' 31.728" 150' 59' 22.599" 2392' 90r 12.4 19.6 CD4-303 5,957,263.99 ,518,169.26 70' 17' 31.681" 150° 59' 23.162" 2387' 109' 12.4 19.6 CD4-304 5,957,259.26 ,518,149.87 70' 17' 31.632" 150' 59' 23.725" 2382' 128' 12.4 19.5 CD4-05 5,957,254.43 ,518,130.28 70' 17' 31.581" 150° 59' 24.293" 2377' 148' 12.4 19.5 CD4-306 5,957,249.76 ,518,110.87 70' 17' 31.532" 150° 59' 24.857" 2372' 167' 12.4 19.6 CD4-07 5,957,245.29 ,518,091.49 70' 17' 31.485" 150' 59' 25.419'x`° 2367' 186' 12.4 19.7 CD4-208 5,957,240.13 ,518,071.80 70' 17' 31.431" 150' 59' 25.991" 2362' 206' 12.4 19.8 CD4-209 5,957,235.77 ,518,052.15 70' 17' 31.385" 150' 59' 26.561" 2357' 226' 12.4 19.7 CD4-210 5,957,230.92 ,518,032.98 70' 17' 31.334" 150' 59' 27.118" 2352' 245' 12.4 19.6 CD4-211 5,957,226.94 ,518,013.75 70' 17' 31.292" 150' 59' 27.676" 2348' 264' 12.4 20.0 I_CD4-212 5.957.222.25 .517.994.40 70' 17' 31.243" 150° 59' 28.238" 2343' 283 12.4 19.6 CD4-213 5,957,217.19 ,517,974.60 70' 17' 31.190" 150' 59' 28.812" 2337' 303 12.4 19.9 0D4-214 5,957,212.46 ,517,955.51 70' 17' 31.140" 150' 59' 29.367" 2332' 322' 12.4 19.8 CD4-215 5,957,208.07 ,517,935.87 70' 17' 31.094" 150' 59' 29.937" 2327' 341' 12.4 19.8 CD4-16 5,957,203.17 ,517,916.63 70' 17' 31.043" 150° 59' 30.495" 2322' 361' 12.4 19.5 CD4-17 5,957,198.80 ,517,897.14 70' 17' 30.997" 150' 59' 31.061" 2318' 380' 12.4 19.5 CD4-318A 5,957,193.71 ,517,877.38 70' 17' 30.944" 150' 59' 31.634" 2312' 400' 12.4 19.6 CD4-319 5,957,189.64 ,517,857.90 70' 17' 30.900" 150' 59' 32.200" 2308' 419' 12.4 19.7 CD4-320 5,957,185.03 ,517,838.65 70' 17' 30.852" 150' 59' 32.759" 2303' 438' 12.4 19.7 CD4-321 5,957,180.22 ,517,819.26 70' 17' 30.802" 150' 59' 33.322" 2298' 458' 12.4 19.0 CD4-322 5,957,175.24 ,517,799.90 70' 17' 30.749" 150' 59' 33.884" 2292' 477' 12.4 19.0 CD4-X23 5,957,170.76 ,517,780.38 70' 17' 30.702" 150' 59' 34.450" 2288' 496' 12.4 19.0 CD4-X24 5,957,166.23 ,517,760.82 70' 17' 30.655" 150' 59' 35.018" 2283' 516' 12.4 19.0 0D4-X25 5,957,161.34 ,517,741.31 70' 17' 30.603" 150' 59' 35.584" 2278' 535' 12.4 19.0 CD4-X26 5,957,157.10 ,517,721.97 70' 17' 30.558" 150' 59' 36.146" 2273' 554' 12.4 19.5 0D4-227 5,957,151.94 ,517,702.56 70' 17' 30.505" 150' 59' 36.709" 2268' 574' 12.4 19.6 CD4-X27 5,957,150.77 ,517,697.37 70' 17' 30.492" 150' 59' 36.860" 2266' 579' 12.4 18.4 CD4-X28 5,957,146.24 ,517,678.39 70' 17' 30.445" 150' 59' 37.411" 2261' 598' 12.4 18.8 NOTES: '(.6\ KUUKPIK COORDINATES ELEVATIONS SHOWN HEREON ARE ALASKA STATE PETROLEUM MEANPSEAELEVEL (B 4, NAD P.M S.L.) I..CPIF.. 2. Alpine Survey Office ALPINE MODULE:CD40 UNIT: CD CenocePhillips ALPINE PROJECT CD-4 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE N0. DRAWING NIQ. PART: REV: 05-03-03-1B-2 10/11/05 ( E'-C�4�0-121 2 of 3 6 • REV DATE BY _ CK APP DESCRIPTION REV DATE BY APP DESCRIPTION 5 5/25/08 CZ CD C.A. UPDATED PER K080010ACS 6 4/02/09 CZ DB C.A. UPDATED PER K090003ACS NOTES: 1 . ALL COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 83. 2. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS WERE DERIVED FROM THE AVERAGE ELEVATION ALONG THE TOE OF THE CD-4 GRAVEL PAD. 3. BASIS OF COORDINATES: ALPINE PERMANENT CONTROL MONUMENTS PER SURVEY BY KUUKPIK/LCMF, OCTOBER 2005 4. DATES OF AS-BUILT SURVEYS: WELL CONDUCTORS CD4-208, CD4-209, CD4-210 CD4-318A, CD4-319, 10/11/05, FB 2005-26 PGS. 30-31; CD4-05, CD4-306, CD4-07, 04/13/06, FB 2006-10, PGS 26, CD4-320, 04/14/06, PG 29; CD4-302, CD4-303. CD4-304, CD4-16, CD4-17, 04/18/06, PG 47; CD4-211, CD4-213, CD4-214, CD4-215, 04-26-06, FB 2006-10, PGS 65-66; CD4-301B, CD4-321, 5/13/06, FB 2006-13, PG. 27; CD4-322, CD4-X23, CD4-X24 CD4-X25, 03/30/07, FB 2007-08, PGS. 4-5; CD4-X26, 5/3/07, FB 2007-09, PG. 42; CD4-X98 & CD4-X99, 4/2/09, FB 2009-05, PG. 41; CD4-X27 & CD4-X28, 4/9/09, FB2009-05, PG. 55. 5. CD4-212 IS EXISTING WELL NANUQ #5. REFERENCE DRAWING CE-AP00-162. CD4-227 IS EXISTING WELL NANUQ #3 (ABANDONED). REFERENCE DRAWING CEA-M1 XX-60D380. ry SURVEYORS CERTIFICATE • ♦♦♦♦swiss% I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED ♦♦♦ �E OF .q(q ��� TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS ♦ �P ej...' - ♦ AS-BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT • ,••••� •••.9 1 SUPERVISION, THAT THE MONUMENTS SHOWN HEREON ACTUALLY EXIST •• � .. ♦ AS DESCRIBED, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE • *� 49th �� **.t V CORRECT. • • DATE: REGISTRATION NO. LS-5077 0, t Donald G. Bruce ' ce ��:�FPF••.••No. LS-5O77•••...„$"i .................•Pao . KU U K P I K L � 199 E51et Ave.-Mchom9.Anoka 89609-(907)2!}7890 p,e Office (901)670-4739 Alpine Survey Office ALPINE MODULE:CD40 UNIT: CD C.noc.Phillips ALPINE PROJECT CD-4 WELL CONDUCTORS Alaska, Inc. AS-BUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: 05-03-03-1B-3 10/11/05 CE CD40-121 3 OF 3 6 Startlt Alaska v3.2-06-21-10 IDENTIFY Opportunity&Request Prospect Appraisal bigletha Weil Gulu� Prospect Description Responsible: Nick Pysz O Complete Prospect Name CD4-12 Project Start Date 3/17/2010 Legal Well Name CD4-12 Proposed Spud Date 7/19/2010 Unique Well ID Project Coordinator Nick Pysz Business Unit Alaska Project Class V Operator ConocoPhillips Risk and Cost Category .. Job Number JOB01 at 2010 Drilling Criticality Ranking Country/State/Province Alaska County/Parish North Slope Borough Area/Field/Block WNS-Alpine Pad/Lease/Platform CD4-Pad AFE Number WCP.W3A.3013.Project GeoPressure Critical ❑ Proposed Work This MaxBook is in support of a proposed Alpine Horizontal C Sand Injector which will provide support for CD4-23 an Alpine C Sand Horizontal Producer located in the Southwest C Sand Development Area. This well will sidetrack the Nanuq#5 to the intended target. Item Description Comments Depth(Units of Measure) Feet Onshore/Offshore Onshore Elevation(ft) 20 Reference Datum(ft) Ground Level Rig Type/Major Equip-WI Land Rig D19 Rig Name Doyon 19 Doyon 19 Rig Representative Well Type Slot Recovery This new well will utilize the existing Nanuq 5 slot via sidetrack Well Service Water Injector WAG injector Shallow Hazards None Directional Hole Yes Estimated MD(ft) 15,000 Estimated TVD(ft) 7,300 Departure Range(ft) 5000-10,000 (Help UVH.e rnax Documentation o.aioo Comments FEL1 Timeline Active APPRAISE/SELECT GoForlt N/A In established development area Reviewlt N/A In established development area Risklt N/A In established development area FEL2 FinderWell N/A _ In established development area OPTIMIZE Justifylt N/A In established development area Selectlt N/A In established development area PreDA N/A In established development area t Planit Active Geology Active Data Active FEL3 Drilling Active DEFINE Completion _ Active HSE Active Facility Active NonRigWork Active COPlanit N/A EXECUTE Wraplt N/A D5W Cost Overrun Notification N/A Startlt Review Reviewed By Status Date Comments Scott Lowry No Objection Gaute Naadland No Objection :t 3,. F Related Links Description Relative Address Southwest C Sand Development Overview file:\\S:\ANC\Lonoterm\Aloine\WNS Teams\Satellites\+Aloine\AFE Documents FIN100 7 ORIGiNAL Project Timeline CD4-12 Recommended Documentation maxwen ea Maximize m•it ectixi• Well Name CD4-12 Project Start Date 3/17/10 Unique Well ID Project Class Business Unit Alaska Project Coordinator Nick Pysz Project Status In Progress Anticipated Spud 19-Jul-10 Calc.Spud 6/10/10 I Duration I Start I Finish I Status I Responsible PLANNING ACTIVITIES 5 17-Mar-10 22-Mar-10 Startlt Reviewed I 5 I 17-Mar-10 I 22-Mar-10 I Complete I FEL1 APPRAISE 12 22-Mar-10 3-Apr-10 GoForit 10 I 22-Mar-10 I 1-Apr-10 N/A 1 GoForlt Reviewed 2 1-Apr-10 3-Apr-10 N/A Pyp FEL2 SELECT 70 1-Apr-10 10-Jun-10 Prepare AFD 10 1-Apr-10 11-Apr-10 N/A Procure Long Lead Items 60 11-Apr-10 10-Jun-10 N/A Risklt 10 1-Apr-10 11-Apr-10 N/A Justifylt 5 1-Apr-10 6-Apr-10 N/A Selectlt 20 1-Apr-10 21-Apr-10 N/A Pysz,Nick Selectlt Reviewed 2 21-Apr-10 23-Apr-10 N/A Pysz,Nick PreDrill Analysis Reviewed 17-Apr-10 _ 17-Apr-10 N/A Noel,Brian FEL3 DEFINE 27 23-Apr-10 20-May-10 Final Project Objectives Prioritized 2 25-Apr-10 Complete Pysz,Nick Geologic Summary 10 23-Apr-10 3-May-10 Complete Knock,Doug Pore Pressure Analysis 10 23-Apr-10 3-May-10 Complete Pysz/Knock Data Acquisition Summary 10 23-Apr-10 3-May-10 Complete Knock,Doug Drilling Summary 10 23-Apr-10 3-May-10 Complete Anderson,Nina Final Directional Profile 10 23-Apr-10 3-May-10 Complete Anderson,Nina Completion Summary 10 23-Apr-10 3-May-10 Complete Jasser,Rami HSE Summary 10 23-Apr-10 . 3-May-10 Incomplete DeGeorge/Soria Facility Summary 10 23-Apr-10 „1, 3-May-10 Incomplete Lyden/Dobson Non-Rig Well Work Summary 10 23-Apr-10 ' 3-May-10 Incomplete Herrmann,Daniel Complete Time&Cost Estimates 2 3-May-10 5-May-10 Complete Anderson,Nina Planit Finalized 5 5-May-10 10-May-10 Complete Pysz,Nick Planit Reviewed 10-May-10 10-May-10 Lock Planit Pysz,Nick Prepare AFE 5 10-May-10 15-May-10 Pysz,Nick Submit AFE for Review 5 15-May-10 20-May-10 Pysz,Nick AFE Reviewed 20-May-10 20-May-10 Pysz,Nick EXECUTE 81:,i 20-May-10 9-Aug-10 Prepare Drilling Permit 7 20-May-10 27-May-10 Anderson,N Submit Drilling Permit for Review 30 27-May-10 26-Jun-10 Anderson,Nina Drilling Permit Approved 26-Jun-10 26-Jun-10 Anderson,Nina Prepare Well Plan 14 20-May-10 3-Jun-10 Robertson,Ryan Submit Well Plan for Review 7 3-Jun-10 10-Jun-10 Robertson,Ryan Well Plan Approved 10-Jun-10 10-Jun-10 Robertson,Ryan Conduct Pre-Rig Work 10-Jun-10 10-Jun-10 Peirce,John 30 10-Jun-, 10-Jul-10 Lyden/Dobson Conduct Post-Rig Work 10-Jul-IC 10-Jul-10 Conduct Facilities Work 30 10-Jul-IC 9-Aug-10 OPERATE 60 9-Aug-10 8-Oct-10 Wraplt I 60 I 9-Aug-10 I 8-Oct-10 I N/A PostDrill Analysis Reviewed I 9-Aug-10 I 9-Aug-10 I N/A 6/29/2010C; " ,' ixii 4 A L Planit CD4-12 011••DEFINE Requirements & Finalize Plans ell �w Responsible: Pysz, Nick El Complete Well Name CD4-12 Project Start Date 3/17/10 Unique Well ID Project Class Business Unit Alaska Project Coordinator Nick Pysz Review Board* Team Members* Position Individual Position Individual Position Individual Supervisor WNS Dev Gaute Naadland Completion Engineer Rami Jasser Land Dora Soria Staff Drilling Engineer Scott Lowry Drilling Engineer Ryan Robertson Operations Rep Warren Dobson Drilling Engineer Mike Winfree Operations Rep Mike Lyden Drilling Supervisor Scott Lowry Materials Spec Andy Koosman Facilities Engineer Eryn Boone HSE/EIA Rep DeGeorge,Lynn Geologist Doug Knock Drilling Engineer Nina Anderson Geophysicist Jerry Veldhuis Production Engineer Tim Schneider MaxWell Coordinator Patrick Way DSPE Jack Walker Production Engineer Scott Reed Project Coordinator Nick Pysz Reservoir Engineer Nick Pysz Well Works Engineer Daniel Herrmann Proposed Work Steps This MaxBook is in support of a proposed Alpine Horizontal C Sand Injector which will provide support for CD4-23 an Alpine C Sand Horizontal Producer located in the Southwest C Sand Development Area.The Nanuq#5 well will be used to access this BHL via Final Project Objectives Prioritized* Responsible: Pysz,Nick Status:I Complete Deliver projected rate forecast and reserves Complete well within time&budget Use offset drilling data to minimize risk Flowback through portable test equipment to clean up well prior to establishing injection Pre-production option desired if reservoir pressure is>3200 psi.Base decision on static survey data. Key Risks, Uncertainties&Assumptions* Description Comments Alpine C sand continuity CD4-24 is only penetration in amplitude/incision targeted by CD4-12 Alpine C sand reservoir quality CD4-24 is only penetration in amplitude/incision targeted by CD4-12 Seismic amplitude is a good indicator of sand presence This assumption was largely validated with the CD4-24 penetration in the C sand. High pressure Kuparuk sand This well will penetrate the Kuparuk-1500'East from active CD4-319 injector;will manage pressure in injector to reduce risk. High pressure Nanuq sand CD4-12 will penetrate Nanuq sand-300'East of Nanuq horizontal injector CD4- 214;will manage injection to reduce pressure<3500 psi Nanuq#5 slot recovery(drilled 2002) Cut&pull 7";sidetrack below surface shoe. FEL3 Estimated Time Time Category P10(small) P50(base) P90(large) Comments Estimator Date Pre-Rig Work Rig Mobilization 0.40 0.50 0.60 Well to Well move on CD4 _ N.Anderson 15-Apr-10 Drilling 22.00 25.00 27.50 Drill&Complete N.Anderson 15-Apr-10 Completion Post-Rig Work Facilities Total Estimated Time 22 26 28 6/29/2010 11:29 AM ORIGINAL Planit GD4-12 Geologic Summary 'T, Responsible: Knock,Doug Surface Location* Coordinate System: I X/Y(ASP)Coord. Surface location:X=1517994,Y=5957222 Sec24,T11 N,R4E,2936 FNL, 28:i ,4E, TD:Sec36,T11 N,R4E,3108 FNL,604 FEL Latitude:(Decimal Degrees) I Longitude: (Decimal Degrees) Geologic Target(s) TVD Desired Hole Target Formation (SS)(ft) MD(ft) X Y Angle Boundaries Comments 7"Casing point 7,288 11,100 1,515,281 5,951,214 86-87 100'radius TD 7 290 16.31 r 1.517.50n 5.945.500 90 100'radius Geologic Target Di: C04-12 is a horizontal injector targeting the Alpine C sand southwest of CD4 pad. Planned lateral length is 5,200'(heel 11,100,toe 16,311). No significant faults fall within 500'of the planned lateral although small faults below seismic resolution are possible. Top Alpine C depth uncertainty is 25'tvd. Apparent Alpine dip along the lateral is expected to range from 0 to 1 degrees with overall deepening to the south. The lateral targets the east edge of the Alpine C seismic amplitude penetrated by CD4-24.CD4-24,approximately 3,600'west-southwest of the heel of CD4-12 found 35'gross and 28'net of Alpine C sand.Alpine C amplitude is weak over the final 1,000-1,500'of the lateral. If drilling conditions permit,top Alpine C will be penetrated near the planned TD to gather depth and thickness data. Geologic Prognosis Gross Formation (SS)(ft) MD(ft) Two-Way Time Uncertainty Thickness Net Pay Temp Porosity Perm Comments (ft) (ft) (miliseconds) (ft) (ft) (ft) (deg C) (%) (mD) Base Permafrost 1,500 C-30 2,340 C-20 2,710 K-3 Marker 3,770 Basal K-3 3,993 K-2 Qannik 4,030 Basal K-2 4,136 Albian 97 5,810 Albian 96 6,140 50 30 HRZ 6,735 Base HRZ 6,895 K-1 Marker 6,955 Kuparuk C 7,025 10 8 LCU-Miluveach 7,035 Alpine D 7,263 Alpine C 7,280 15 UJU 7.295 Geologic Prognosis Discussion Gross Alpine C sand thickness is expected to be-15 ft at the landing point with a net to gross of approximately 80%. The heel section of the lateral begins near the eastern edge of a seismically mappable erosional scour as defined by the UJU(base Alpine C)reflector. Alpine C sand seismic indicators(lambda rho and far offset amplitude)are continuous over most of the first 4,000'of the planned lateral. Seismic detection for Alpine C sand is fairly good above 20'gross thickness. Alpine C sand continuity and reservoir quality over the proposed lateral are the main geologic risks. Slant well CD4-24 is the only Alpine C penetration in the amplitude/incision targeted by the CD4-12 lateral. CD4-24 found 29'of net pay averaging 10.6 and permeability,however,lower permeability(<5 and perm)and lower net to gross sands were found in the southern CD2 laterals. Top Alpine C depth uncertainty is+/-25'. The well will be landed in the upper 5-10'of the Alpine C sand at roughly 87 degrees. The lateral section will target 15-20 ohm resistivity sand. If drilling conditions permit,top Alpine C will be penetrated near the planned TD to gather depth and thickness data. CD4-12 will penetrate the Kuparuk C sand approximately 1,500'east of Kuparuk horizontal injector CD4-319. 10'of Kuparuk C sand is expected. Kuparuk pressure will be managed in CD4-319 prior to drilling CD4-12. The Nanuq sand will be penetrated rou.hl 300'east of Nanu.horizontal in'ector CD4-214. Qannik is ex..cted to contain 8'of oil net.a . Pole, -Ure Executive Summary" Complete The expected reo be CD4-12(Alpine C Sand)vicinity is c -.+3100-3500 psi(7.5-9."ppge). This is based on limited SBHP data from CD4-24 ,fo the West)and various other analog data. Offset Pore Pressure-Fracture Gradient Profile* Fracture Pore Pressure Well Name or Seismic Line TVD(SS)(ft) Gradient (EMS Measurement Method (EMW) 6/29/, 01 1: 9 6AI NAL Nanuq#3&Nanuq#2 K-2 4,050 12.50 Nanuq#3,Nanuq#2 RFT's&0.65 psi/ft frac grad ROT Nanuq#2 Nanuq Sand 6,150 10.60 9.50 Nanuqk#2&Nanuq sand data frac Kuparuk 7,100 12.50 9.50 0.65 psi/ft frac grad ROT Initial SBHP;well is currently being pre-produced;0.65 psi/ft CD4-24 C Sand 7,350 12.50 10.20 frac grad ROT Expected Pore Pressure-Fracture Gradient Profile* Fracture Abnormal Pressure Marker(s) TVD(SS)(ft) Gradient Pore r ure Comments (EMW) Nanuq-Nanuq 6,140 10.60 9.50 will be managed to be below 3500 psi or 9.5 lb/gal Kuparuk 7,025 12.50 9.50 will be managed to be below 3500 psi or 9.5 lb/gal CD4-12 Alpine C(heel) 7,280 12.50 8.50 3200 psi expected;no heel to toe variance is anticipated CD4-12 Alpine C(Toe) 7,280 12.50 8.50 0.65 psi/ft frac grad ROT Related Links Description Relative Address Geology Overview fi le:\\S:\ANC\Longterm W l pine\W NS Teams\Satellites\+Alpine\AFE Documents FIN 100 7Y\CD4! /R°1° ThiAL Planit CD4-12 Data Acquisition Summary Maxwell Max'Value I I e W e l Responsible: Knock, Doug OComplete Requirements • MWD/LWD ❑ Open Hole Logs ❑ Wireline Formation Testing ❑ Mud Logging 2 Cased Hole Logs ❑ DST/Testing Program E Cuttings Sampling ❑ Conventional Coring MWD/LWD Tool Description From(ft) To(ft) Hole Section Realtime Data Justification GR/Res Intermediate Yes Landing Casing GR/Res Horizontal section Yes Geo-steering ADR or Periscope Horizontal section Yes Geo-steering-Dependent upon Hall.Re-work Cuttings Sampling Type From(ft) To(ft) Hole Section Frequency Justification Cuttings Sampling Horizontal section 50' Reservoir Description;Geo-steering Cased Hole Logging Tool Description From(ft) To(ft) Hole Section Realtime Data Justification CBL-Cement Bond Log Log from Int Casing to TOC No State Requirement Q R9!2G1ftL . " Plan It CD4-12 ie ,A Drilling Summary w:,'■1,70■2.: Responsible: Anderson, Nina Casing Program Minimum Calculated Safety Factor Weight, Setting Hole Casing Grade, Burst Collapse Tension Tri-axial Depth TVD(SS) TVD(RKB) Size(in.) Size(in.) Thread (MD)(ft) (ft) (ft) 42 16 12.25 9.625 8.75 11309.56 .. 6.125 z-:1, 16310.97 Fluids From MD To MD Mud Viscosity Fluid Loss (RKB)(ft) (RKB)(ft) Type Density(PPG) (sec/quart) (CC/30 min) Comments LSND 9.6-10 Fresh water,gel/polymer WBM 8.5-9.1 FloPro Mud System Final Directional Profile Responsible: Anderson,Nina Status: From MD To MD Desired Hole Max Hole (RKB)(ft) (RKB)(ft) Azimuth Max DLS Angle Angle Comments 3,010 4,960 56 3 45 45 KOP 3010'MD.Build to 3 deg/100 4,960 8,510 235 3 45 45 Hold angle and azimuth 8,510 11,310 153.73 3.5 90 Turn and Build to land in the Alpine C sand 11,310 16.311 153.73 90 Directionally drill horizontal Drilling Issues Issue Detailed Description Mitigation Reservoir Quality uncertainty Edge of amplitude,thin zone Run liner if exit zone,shorten lateral? High Kuparuk Pressure(Upper zone)?? Near CD4-319(In)) Injection into CD4-319 will be managed to reduce pre: Mud&Cuttings disposal If unable to permit annulus for AD on CD4 Haul drilling fluids to CD1-19A Cut&Pull 7",drill out below surface csg shoe High Nanuq Pressure Near CD4-214(IN) Injection into CD4-214 will be managed to reduce pre: 0 [6/29/2010 11:29 AM PlanIt CD4-12 Summary Completion ary Su Well Value Responsible: Jasser,Rami CI Complete Description Item Description Comments Completion Category _ Oil Horizontal Open Hole 3-1/2"Slotted Liner possible depending on Log evaluation Completion Type Packer Pre-Producer that will be switched into an injector Completion String Single Sand Control No-Open Hole Other SLHT threads preferred on Liner Fluids Item Description Comments Drill-in Flo Thru Completion Fresh Water Based Annulus/Packer Brine 2000'TVD Diesel+KCL Brine Other Mechanical Item Description Comments Tubing Size(inches) 3.5",9.3#/ft L-80 Tubing Tubing Connection EUE Mod Wellhead/Pressure Rating Surface/Rating=5,000 psi Alpine Horizontal Well Type New Wellhead Tree/Pressure Rating Conventional/Rating=5,000 psi Minimum ID 2.75 "XN"Nipple below Premier Packer SSSV None 3-1/2"TRMAXX-5E SSSV with 2.812""X"Nipple Profile Packer Premier Packer 3.5"x 7"Premier Packer Corrosion Control Chemical Inhibition Baker Petrolite Corrosion Inhibitor Hydrate Control No Viscosity Control No Permanent DH monitor No Casing/Annulus Packers No Metallurgy L-80 Selectivity Required No Profile Nipples "X"Nipple @ 2000'TVD;'XN'Nipple below Premier Pack Blast Joints No Flow Couplings No Other 3-1/2"Slotted Liner possible depending on Log evaluatio SLHT Threads on Slotted Liner Perforation ❑ Not Applicable 0 R1°GffA L • • Potnis, Brij P (Halliburton) From: Robertson, Ryan G Sent: Monday, June 28, 2010 1:31 PM To: Potnis, Brij P (Halliburton) Cc: 'Scott Brunswick' Subject: CD4-12 Well Plan Follow Up Flag: Follow up Flag Status: Red Brij, Please adjust the CD4-12 wellplan and create a permit pack using the following: Kick Off Point: 2,920' MD (10 ft outside of existing surface shoe) Kick Off Orientation: 150°Right We will cut the casing at 3,010' MD and use a 7" motor to drill this section of the hole with. Let me know if you have any questions. Ryan Drilling Engineer I ConocoPhillips Alaska I Direct:(907)265-6318 I Mobile:(907)980-5107 ORIGINAL ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 June 28th, 2010 Alaska Oil and Gas Conservation Commission RECEIVED 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 J U L p 7 2 010 Re: Application for Permit to Drill CD4-12 Alaska Oil&COs Cfiz.amm Commission Anchlrag0 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore well from the CD4 pad. The intended spud date for this well is July 20th, 2010. It is intended that Don Rig 19 be used to drill the well. CD4-12 is intended to be a horizontal Alpine C injector. It will be drilled from the existing Nanuq 5 surface • location. Nanuq 5 is an exploration well that was drilled in 2002. In order to drill the CD4-12 well, the existing 7" intermediate casing will be cut and pulled from the wellbore. The Nanuq 5 will then be plugged and abandoned, setting up the CD4-12 well for sidetracking operations below the existing surface casing. After the intermediate section has been sidetracked and drilled, 7" intermediate casing will be set. The horizontal section will then be drilled and the well completed as an Alpine C injector. Once completed. the well - will be pre-produced for approximately 6 months prior to converting it over to injection. It is expected that the K2 (Qannik)sand could be considered a significant hydrocarbon bearing zone. It is • planned to pump lead cement through the intermediate casing shoe and then open a stage tool and pump a second cement job to isolate the K2 formation with 500' of cement above and below the interval. This will leave a mud gap between the two cement stages. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005(a). 2. A proposed drilling program. 3. Request for approval of future annular pumping operations. 4. A drilling fluids program summary. 5. A proposed plug back schematic. 6. A proposed final completion diagram. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Cementing program. 9. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. { If you have any questions or require further information, please contact Ryan Robertson at 265-6318 or Chip Alvord at 265-6120. Sincerely Ryan Robertson Drilling Engineer Attachments: cc: CD3-122 Well File/Sharon Allsup Drake ATO 1530 Scott Lowry ATO 1504 Mark Chambers ATO 1566 Mike A. Winfree ATO 1706 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation Page 1 of 2 Schwartz, Guy L (DOA) From: Reed, Scott[Scott.Reed @conocophillips.com] Sent: Friday, July 09, 2010 10:30 AM pT p 2. to -t() To: Schwartz, Guy L(DOA) Subject: RE: Backflow CD4-214 p rc.ssu fc C&)14—/2 Guy, Per our phone conversation: CD4-214 was shut in on 6/29/10 when it was identified as a possible drilling hazard for the upnoming well rn4- 12. A SBHP was measured on 7/4/10 and recorded a pressure of 3747 psi at 5993 TVD (3818 psi converted to the datum). This is a —12 ppge pressure environment at that depth and represents a large drilling risk because the mud weight required for the Nanuq is 3 ppg higher then the reservoir they will land CD4-12 in. A 2.5 ppge reduction in reservoir pressure is needed to mitigate the drilling risk for CD4-12. Drilling anticipates crossing this horizon in 3 weeks and natural pressure decline in the area will not be sufficient to lower the pressure. Back flowing CD4-214 will allow us to depressurize the over pressured Nanuq faster. CD4-214 has been on water since 2/18/10 and the prior gas slug began on 12/26/09. Thanks Scott From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent:Thursday, July 08, 2010 11:05 AM To: Reed, Scott Cc: Maunder, Thomas E (DOA) Subject: RE: Backflow CD4-214 Scott, Could you submit your plan in writing so I have a better idea of what you want to do? You mentioned the well has an injection valve downhole ( not a TRSSSV) so this is an issue as this will have to be pulled. Also what are you doing at surface as far as piping , manwatch etc. You will need to submit a 403 sundry to convert well to a Development( production) ... this sundry should include the safety and operational steps needed to do the backflow also. Hope this helps... call me back later today. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Reed, Scott [mailto:Scott.Reed @conocophillips.com] Sent: Wednesday, July 07, 2010 9:38 AM To: Schwartz, Guy L(DOA) Cc: Pysz, Nick P; Robertson, Ryan G Subject: Backflow CD4-214 Guy, The CD4-12 well plan penetrates the Nanuq-Nanuq — 300 ft away from the Nanuq-Nanuq injector CD4-214. Due 7/9/2010 Page 2 of 2 to the tight rock we have not had much luck getting the pressure down around that injector. Drilling estimates that they will penetrate that horizon in 3 weeks. I would like to backfiow CD4-214 to reduce the pressure in that area and subsequently lower the drilling risk. What do you recommend as the best way to make this happen? Thanks Scott Reed Scott Reed Production Engineer WNS Subsurface Office: (907)265-6548 Cell: (907) 575-3978 7/9/2010 Page 1 of 2 Schwartz, Guy L (DOA) From: Robertson, Ryan G [Ryan.G.Robertson @conocophillips.com] Sent: Thursday, July 08, 2010 8:08 PM To: Schwartz, Guy L(DOA) Subject: RE: Nanuq#5 Sundry Permit and CD4-12 PTD Attachments: CD4-12 -Permit to Drill - Revised -07.08.10.pdf; CD4-12 -Sundry to Abandon - Revised - 07.08.10.pdf Guy, Here are the updated procedures as requested for the Nanuq#5 Sundry and CD4-12 PTD. Thanks for your help today, Ryan From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Thursday, July 08, 2010 4:23 PM To: Robertson, Ryan G Subject: RE: Nanuq #5 Sundry Permit and CD4-12 PTD Ryan, Also need a Cement bond log done on the 7" intermediate. All injection wells need one. Didn't see anything in the procedure. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L(DOA) Sent: Thursday, July 08, 2010 4:06 PM To: 'Robertson, Ryan G' Subject: RE: Nanuq #5 Sundry Permit and CD4-12 PTD Ryan, After pulling storm packer you do not mention pressure testing the shallow(3000' md ) cement plug. Pulling the storm packer and testing the cement plug should also be included in the procedure. I think it might be easier at this point to make the changes to the steps and resend just those pages. I would also make PTD and Sundry steps mirror images... add the pre-rig steps to the PTD procedure so both have the same number of operation step numbers. Guy Schwartz Senior Petroleum Engineer AOGCC 7/9/2010 Page 2 of 2 793-1226 (office) 444-3433 (cell) From: Robertson, Ryan G [mailto:Ryan.G.Robertson @conocophillips.com] Sent: Thursday, July 08, 2010 11:42 AM To: Schwartz, Guy L (DOA) Subject: Nanuq #5 Sundry Permit and CD4-12 PTD Guy, As we discussed verbally, CPAI proposes to make the following adjustments to the filed Nanuq#5 Sundry to Abandon permit application and CD4-12 permit to drill application: • For the Sundry permit to abandon Nanuq#5, after step 16 listed in the Rig Procedure, Doyon 19 will run a storm packer into the 9-5/8" casing. At that point, a 2,500 psi pressure test for 10 minutes will be performed to insure wellbore integrity. By doing so, the wellbore will have kill weight fluid and the storm packer as well control barriers. For the CD4-12 permit to drill application, this step will be inserted after step 14 in the Rig Procedure. • Regarding the request to only body test the BOP prior to pulling the 4-1/2"tubing, CPAI would like to withdraw this request. Instead, once the BOP is initially nippled up (step 8 on Sundry permit, step 6 on permit to drill), a full BOP test using a 4-1/2"test joint will be performed against a blanking plug. This will negate step 11 in the Sundry permit and step 9 in the Permit to drill. • After the 7"casing has been cut, and the casing cutter pulled from the hole, the top pipe rams will be swapped out to 7" casing rams and pressure tested to 250/3,500 psi and the annular preventer to 250/ 2500 psi. This will take place after step 14 on the sundry to abandon and step 12 on the permit to drill. Regarding the pool scan for the Alpine C reservoir, there are 3 wells that fall within %4 mile of the proposed CD4- 12 wellplan—CD4-319, CD4-215 and CD4-214. These three wells have been drilled and completed in pools shallower than the Alpine C—Kuparuk and Nanuq formations. The CD4-24 wellbore is the closest in pool to the proposed CD4-12 injector at 3,816 ft away. All four wells had successful intermediate cement jobs, with full returns throughout, the plugs bumping and floats holding. As per our conversation, an updated schematic for the sundry permit of the Nanuq#5 wellbore has been attached to better illustrate its condition after the well has been plugged and abandoned. The schematic now includes the cement on top of the HES second stage cementing tool, as well as the 1st stage shoe track. Both of these cement plugs are still in place as they were never drilled out after the cement job. Thanks, Ryan Drilling Engineer I ConocoPhillips Alaska I Direct(907)265-6318 i Mobile(907)980-5107 7/9/2010 Page 1 of 1 Schwartz, Guy L (DOA) From: Robertson, Ryan G [Ryan.G.Robertson©conocophillips.com] Sent: Thursday, July 08, 2010 11:42 AM To: Schwartz, Guy L(DOA) Subject: Nanuq#5 Sundry Permit and CD4-12 PTD Attachments: Nanuq P&A-7.08.10.pdf Guy, As we discussed verbally, CPAI proposes to make the following adjustments to the filed Nanuq#5 Sundry to Abandon permit application and CD4-12 permit to drill application: • For the Sundry permit to abandon Nanuq#5, after step 16 listed in the Rig Procedure, Doyon 19 will run a storm packer into the 9-5/8"casing. At that point, a 2,500 psi pressure test for 10 minutes will be performed to insure wellbore integrity. By doing so, the wellbore will have kill weight fluid and the storm packer as well control barriers. For the CD4-12 permit to drill application, this step will be inserted after step 14 in the Rig Procedure. • Regarding the request to only body test the BOP prior to pulling the 4-1/2"tubing, CPAI would like to withdraw this request. Instead, once the BOP is initially nippled up (step 8 on Sundry permit, step 6 on permit to drill), a full BOP test using a 4-1/2"test joint will be performed against a blanking plug. This will negate step 11 in the Sundry permit and step 9 in the Permit to drill. A • After the 7"casing has been cut, and the casing cutter pulled from the hole, the top pipe rams will be swapped out to 7" casing rams and pres ure testes • 50/3,500 psi and the annular preventer to 250/ Thi talc- . -- i a 14 • esund to :•- •• - • - _• 'I. p sundry on ep- � ' • : Regarding the pool scan for the Alpine C reservoir, there are 3 wells that fall within 1/4 mile of the proposed CD4- 12 wellplan—CD4-319, CD4-215 and CD4-214. These three wells have been drilled and completed in pools shallower than the Alpine C—Kuparuk and Nanuq formations. The CD4-24 wellbore is the closest in pool to the proposed CD4-12 injector at 3,816 ft away. All four wells had successful intermediate cement jobs, with full returns throughout, the plugs bumping and floats holding. As per ou onversation, - pdate• ematic or the sundry permit of the Nanuq we •• - -- - -'ached to better illustrate its condition after the well has been plugged and abandoned. The schematic now includes the cement on top of the HES second stage cementing tool, as well as the 1st stage shoe track. Both of these cement plugs are still in place as they were never drilled out after the cement job. Thanks, Ryan Drilling Engineer{ConocoPhilllps Alaska i Direct (907)265-6318 Mobile:(907)980--5107 7/8/2010 TRANSMITTAL LETTER CHECKLIST WELL NAME avp I L// /01/'( ! ?� PTD# 2 G Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD6,477,4 K i[ r POOL: I�2�, O€ ( C).0 Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The ermit is for a new wellbore segment of existing g g 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. 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'C' a)as a OU m .0 a) aai a°i N m a o �c L a c m ° .m �° 3 0 0 a c o a@ c °c E O 7 m m m m m m E m 3 7 > o ° m m - m _ E 0 m = c _U m u) m ° c z c U ° ° o m o ° ° ° a`� ° u o c v m o o - ° m o m s N n E .3 N C o -0 0•(A p N o 0 0 '� m a`) E E ° 3 ° C H H H a�i `) aai '� d d o , E c E �° N m c m J a) a .c ,—) ,—) a 7 -0 n a a) Zr) m ° — 2 0 0 7 2 2 2 m -o m a = 0 O s 0 °- m a) m 'm m 0 ❑ U @ a J D cn 0 0 a a U ¢ a z U cn U U U U Q .- c ' o m m U N 2 a ❑ co U) U I ° O `- N M V Cn (0 N CO 0) O N M V LO (O I- Co O) O N M d LO CO N- Co 6) I N M V L!7 co N Co m �- .- N N N N N N N N N N M M M M M M M M M M U I- 0 0 0 o o d o d o c 2 O c (p N U) N CO N ° O W O (6 h C N N 0' O. r �, 0 0 0 - E C O ` O w 0- E a ❑ c a 0 0 a- � 0 a Q a w Q 0 Q 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 Sep 14 17:02 :22 2010 Reel Header Service name LISTPE Date 10/09/14 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 10/09/14 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 Colville River MWD/MAD LOGS WELL NAME: CD4-12 API NUMBER: 501032041401 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 13-SEP-10 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: MW-000726443 MW-000726443 MW-000726443 LOGGING ENGINEER: JESSE BOBBIT JESSE BOBBIT PAUL ORTH OPERATOR WITNESS: FRED HERBERT SCOTT HEIM DAVE BURLEY MWD RUN 5 JOB NUMBER: MW-000726443 LOGGING ENGINEER: PAUL ORTH OPERATOR WITNESS: FRED HERBERT SURFACE LOCATION SECTION: 24 TOWNSHIP: 11N RANGE: 4E FNL: 2937 FSL: FEL: 283 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 55.68 GROUND LEVEL: 19.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 2914.0 2ND STRING 6.750 7.000 11497.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2 . ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3 . THIS WELLBORE EXITED FROM CD4-12PB1 FROM AN OPENHOLE SIDE TRACK AT 15481' MD, 7410' TVD. 4. MWD RUN 1 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY- PHASE 4 (EWR-P4) , PRESSURE WHILE DRILLING AND DRILLSTRING DYNAMICS SENSOR (DDSr) BEHIND A PEFORMANCE DRILL MOTOR (PDM) . 5. MWD RUN 2-3,5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY- PHASE 4 (EWR-P4) , PRESSURE WHILE DRILLING AND DRILLSTRING DYNAMICS SENSOR (DDSr) BEHIND A ROTARY STEERABLE SYSTEM (RSS) . 6. MWD RUN 3 ALSO INCLUDED A BI-MODAL ACOUSTIC TOOL (BAT) UTILIZED FOR CEMENT EVALUATION ONLY, NO OPENHOLE DATA PRESENTED. 7. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILL SITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 8. MWD RUNS 1-3,5 REPRESENT WELL CD4-12 WITH API# 50-103-20414-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 16,004 'MD, 7,448'TVD. SROP = RATE OF PENETRATION WHILE DRILLING SGRC = DUAL GAMMA RAY COMBINED 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 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 10/09/14 Maximum Physical Record65535 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 GR 2859.0 15955.0 RPD 2904.0 15962 .0 RPS 2904.0 15962.0 RPM 2904.0 15962.0 FET 2904.0 15962.0 RPX 2904.0 15962.0 ROP 2920.0 16005.0 BASELINE CURVE FOR SHIFTS: 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 2859.0 5287.0 MWD 2 5287.5 11507.0 MWD 3 11507.5 15480.5 MWD 5 15481.0 16005.0 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 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2859 16005 9432 26293 2859 16005 RPD MWD OHMM 0.38 2000 22.4586 26083 2904 15962 RPM MWD OHMM 0.4 2000 14.6136 26083 2904 15962 RPS MWD OHMM 0.4 1469.18 11.4991 26083 2904 15962 RPX MWD OHMM 0.33 643.33 10.3296 26083 2904 15962 FET MWD HR 0.2 155.42 1.04176 26083 2904 15962 GR MWD API 28.16 377.26 97.8598 26193 2859 15955 ROP MWD FPH 0.08 270.25 123.14 26161 2920 16005 First Reading For Entire File 2859 Last Reading For Entire File 16005 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/09/14 Maximum Physical Record65535 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 10/09/14 Maximum Physical Record65535 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 SGRC 2859.0 5227.0 SEDP 2904.0 5236.5 SEMP 2904.0 5236.5 SEXP 2904.0 5236.5 SESP 2904.0 5236.5 SFXE 2904.0 5236.5 SROP 2920.0 5287.0 # LOG HEADER DATA DATE LOGGED: 17-AUG-10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 5287.0 TOP LOG INTERVAL (FT) : 2920.0 BOTTOM LOG INTERVAL (FT) : 5287.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 44.5 MAXIMUM ANGLE: 56.5 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 163685 EWR4 EWR Phase-4 231951 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.750 DRILLER'S CASING DEPTH (FT) : 2914.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.60 MUD VISCOSITY (S) : 36.0 MUD PH: 10.0 MUD CHLORIDES (PPM) : 700 FLUID LOSS (C3) : .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.550 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.767 109.6 MUD FILTRATE AT MT: 2.900 70.0 MUD CAKE AT MT: 2.350 70.0 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 .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 RPD MWD010 OHMM 4 1 68 4 2 RPM MWD010 OHMM 4 1 68 8 3 RPS MWD010 OHMM 4 1 68 12 4 RPX MWD010 OHMM 4 1 68 16 5 FET MWD010 HR 4 1 68 20 6 GR MWD010 API 4 1 68 24 7 ROP MWD010 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2859 5287 4073 4857 2859 5287 RPD MWD010 OHMM 0.38 2000 14.2674 4666 2904 5236.5 RPM MWD010 OHMM 0.4 2000 6.6176 4666 2904 5236.5 RPS MWD010 OHMM 0.42 1469.18 4.8607 4666 2904 5236.5 RPX MWD010 OHMM 0.42 15.06 4.35995 4666 2904 5236.5 FET MWD010 HR 0.23 7.48 0.802267 4666 2904 5236.5 GR MWD010 API 57.88 192.05 125.791 4737 2859 5227 ROP MWD010 FPH 0.11 270.25 158.73 4735 2920 5287 First Reading For Entire File 2859 Last Reading For Entire File 5287 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/09/14 Maximum Physical Record65535 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 10/09/14 Maximum Physical Record65535 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 5227.5 11460.5 SEXP 5237.0 11469.5 SFXE 5237.0 11469.5 SEMP 5237.0 11469.5 SEDP 5237.0 11469.5 SESP 5237.0 11469.5 SROP 5287.5 11507.0 LOG HEADER DATA DATE LOGGED: 21-AUG-10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 11507.0 TOP LOG INTERVAL (FT) : 5287.0 BOTTOM LOG INTERVAL (FT) : 11507.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 44.1 MAXIMUM ANGLE: 87.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 132482 EWR4 EWR Phase-4 96540 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.750 DRILLER'S CASING DEPTH (FT) : 2914.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.70 MUD VISCOSITY (S) : 40.0 MUD PH: 9.1 MUD CHLORIDES (PPM) : 400 FLUID LOSS (C3) : 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 4.000 77.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.034 162 .6 MUD FILTRATE AT MT: 4.250 76.0 MUD CAKE AT MT: 3.100 78.0 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 5227.5 11507 8367.25 12560 5227.5 11507 RPD MWD020 OHMM 2 .55 45.98 7.27557 12466 5237 11469.5 RPM MWD020 OHMM 2.72 34.75 7.00236 12466 5237 11469.5 RPS MWD020 OHMM 2.64 40.94 6.47876 12466 5237 11469.5 RPX MWD020 OHMM 2.58 49.23 6.29845 12466 5237 11469.5 FET MWD020 HR 0.2 28.2 0.651704 12466 5237 11469.5 GR MWD020 API 40.59 377.26 117.647 12467 5227.5 11460.5 ROP MWD020 FPH 15.86 248.04 137.921 12440 5287.5 11507 First Reading For Entire File 5227.5 Last Reading For Entire File 11507 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/09/14 Maximum Physical Record65535 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 10/09/14 Maximum Physical Record65535 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 SGRC 11461.0 15480.5 SESP 11487.0 15480.5 SFXE 11487.0 15480.5 SEMP 11487.0 15480.5 SEXP 11487.0 15480.5 SEDP 11487.0 15480.5 SROP 11507.5 15480.5 LOG HEADER DATA DATE LOGGED: 01-SEP-10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 5.55 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 15481.0 TOP LOG INTERVAL (FT) : 15481.0 BOTTOM LOG INTERVAL (FT) : 15481.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 87.8 MAXIMUM ANGLE: 91.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 203301 EWR4 EWR Phase-4 67978 $ ## BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6.750 DRILLER'S CASING DEPTH (FT) : 11497.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.00 MUD VISCOSITY (S) : 44.0 MUD PH: 9.6 MUD CHLORIDES (PPM) : 21000 FLUID LOSS (C3) : 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .230 76.0 MUD AT MAX CIRCULATING TERMPERATURE: .112 162 .6 MUD FILTRATE AT MT: .220 76.0 MUD CAKE AT MT: .180 73.0 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 MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11461 15480.5 13470.8 8040 11461 15480.5 RPD MWD030 OHMM 2.98 2000 50.2595 7988 11487 15480.5 RPM MWD030 OHMM 0.67 1703.84 30.1832 7988 11487 15480.5 RPS MWD030 OHMM 0.4 662.28 21.9129 7988 11487 15480.5 RPX MWD030 OHMM 0.33 643.33 19.1211 7988 11487 15480.5 FET MWD030 HR 0.35 155.42 1.65957 7988 11487 15480.5 GR MWD030 API 28.16 108.48 56.3111 8040 11461 15480.5 ROP MWD030 FPH 0.69 139.58 87.1908 7947 11507.5 15480.5 First Reading For Entire File 11461 Last Reading For Entire File 15480.5 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/09/14 Maximum Physical Record65535 File Type LO Next File Name STSLIB.005 Physical EOF File Header Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/09/14 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SEMP 15481.0 15962 .0 SEXP 15481.0 15962 .0 SESP 15481.0 15962 .0 SEDP 15481.0 15962 .0 SGRC 15481.0 15955.0 SFXE 15481.0 15962 .0 SROP 15481.5 16005.0 LOG HEADER DATA DATE LOGGED: 04-SEP-10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 5.55 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 16004.0 TOP LOG INTERVAL (FT) : 15481.0 BOTTOM LOG INTERVAL (FT) : 16004.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 82 .1 MAXIMUM ANGLE: 89.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 94063 EWR4 EWR Phase-4 173235 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6.125 DRILLER'S CASING DEPTH (FT) : 11497.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.00 MUD VISCOSITY (S) : 45.0 MUD PH: 9.6 MUD CHLORIDES (PPM) : 23500 FLUID LOSS (C3) : 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .230 76.0 MUD AT MAX CIRCULATING TERMPERATURE: .116 162.6 MUD FILTRATE AT MT: .220 76.0 MUD CAKE AT MT: .180 76.0 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 MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 15481 16005 15743 1049 15481 16005 RPD MWD050 OHMM 6.19 45.86 28.0846 963 15481 15962 RPM MWD050 OHMM 5.08 38.98 22.7344 963 15481 15962 RPS MWD050 OHMM 4 .97 42.81 22 .2718 963 15481 15962 RPX MWD050 OHMM 4.25 38.45 18.5128 963 15481 15962 FET MWD050 HR 0.55 96.77 2.12676 963 15481 15962 GR MWD050 API 31.58 101.6 50.4996 949 15481 15955 ROP MWD050 FPH 0.08 117.86 59.0058 1038 15481.5 16005 First Reading For Entire File 15481 Last Reading For Entire File 16005 File Trailer Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/09/14 Maximum Physical Record65535 File Type LO Next File Name STSLIB.006 Physical EOF Tape Trailer Service name LISTPE Date 10/09/14 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 10/09/14 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 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Sep 10 11:09:55 2010 Reel Header Service name LISTPE Date 10/09/10 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 10/09/10 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 Colville River MWD/MAD LOGS WELL NAME: CD4-12 PB1 API NUMBER: 501032041470 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 10-SEP-10 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: MW-000726443 MW-000726443 MW-000726443 LOGGING ENGINEER: JESSE BOBBIT JESSE BOBBIT PAUL ORTH OPERATOR WITNESS: FRED HERBERT SCOTT HEIM DAVE BURLEY MWD RUN 4 JOB NUMBER: MW-000726443 LOGGING ENGINEER: PAUL ORTH OPERATOR WITNESS: FRED HERBERT SURFACE LOCATION SECTION: 24 TOWNSHIP: 11N RANGE: 4E FNL: FSL: 2937 ei v 00 c34.f FEL: FWL: 283 ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 55.68 GROUND LEVEL: 19.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 2914.0 2ND STRING 6.750 7.000 11497.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2 . ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. MWD RUN 1 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY- PHASE 4 (EWR-P4) , PRESSURE WHILE DRILLING AND DRILLSTRING DYNAMICS SENSOR (DDSr) BEHIND A PEFORMANCE DRILL MOTOR (PDM) . 4. MWD RUN 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY- PHASE 4 (EWR-P4) , PRESSURE WHILE DRILLING AND DRILLSTRING DYNAMICS SENSOR (DDSr) BEHIND A ROTARY STEERABLE SYSTEM (RSS) . 5. MWD RUN 3 ALSO INCLUDED A BI-MODAL ACOUSTIC TOOL (BAT) UTILIZED FOR CEMENT EVALUATION ONLY, NO OPENHOLE DATA PRESENTED. 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR THE DRILL SITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 7. MWD RUNS 1-4 REPRESENT WELL CD4-12PB1 WITH API# 50-103-20414-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11,497'MD, 7383 'TVD. SROP = RATE OF PENETRATION WHILE DRILLING SGRC = DUAL GAMMA RAY COMBINED 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 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 10/09/10 Maximum Physical Record65535 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 GR 2859.0 15780.0 RPD 2904 .0 15787.0 RPS 2904.0 15787.0 RPM 2904.0 15787.0 FET 2904.0 15787.0 RPX 2904.0 15787.0 ROP 2920.0 15829.0 $ BASELINE CURVE FOR SHIFTS: 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 2920.0 5287.0 MWD 2 5287.5 11507.0 MWD 3 11507.5 15813.0 MWD 4 15813 .5 15829.0 $ 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 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2859 15829 9344 25941 2859 15829 RPD MWD OHMM 0.38 2000 22 .111 25733 2904 15787 RPM MWD OHMM 0.4 2000 14.3163 25733 2904 15787 RPS MWD OHMM 0.4 1469.18 11.1229 25733 2904 15787 RPX MWD OHMM 0.33 643 .33 10.036 25733 2904 15787 FET MWD HR 0.2 155.42 1.10137 25733 2904 15787 GR MWD API 28.16 377.26 98.9285 25843 2859 15780 ROP MWD FPH 0.02 270.25 123 .778 25819 2920 15829 First Reading For Entire File 2859 Last Reading For Entire File 15829 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/09/10 Maximum Physical Record65535 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 10/09/10 Maximum Physical Record65535 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 SGRC 2859.0 5227.0 SEDP 2904.0 5236.5 SEMP 2904.0 5236.5 SEXP 2904.0 5236.5 SESP 2904.0 5236.5 SFXE 2904.0 5236.5 SROP 2920.0 5287.0 $ # LOG HEADER DATA DATE LOGGED: 17-AUG-10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 5287.0 TOP LOG INTERVAL (FT) : 2920.0 BOTTOM LOG INTERVAL (FT) : 5287.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 44.5 MAXIMUM ANGLE: 56.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 163685 EWR4 EWR Phase-4 231951 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.750 DRILLER'S CASING DEPTH (FT) : 2914.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.60 MUD VISCOSITY (S) : 36.0 MUD PH: 10.0 MUD CHLORIDES (PPM) : 700 FLUID LOSS (C3) : .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.550 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.767 109.6 MUD FILTRATE AT MT: 2 .900 70.0 MUD CAKE AT MT: 2 .350 70.0 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 MWD010 OHMM 4 1 68 4 2 RPM MWD010 OHMM 4 1 68 8 3 RPS MWD010 OHMM 4 1 68 12 4 RPX MWD010 OHMM 4 1 68 16 5 FET MWD010 HR 4 1 68 20 6 GR MWD010 API 4 1 68 24 7 ROP MWD010 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2859 5287 4073 4857 2859 5287 RPD MWD010 OHMM 0.38 2000 14.2674 4666 2904 5236.5 RPM MWD010 OHMM 0.4 2000 6.6176 4666 2904 5236.5 RPS MWD010 OHMM 0.42 1469.18 4.8607 4666 2904 5236.5 RPX MWD010 OHMM 0.42 15.06 4.35995 4666 2904 5236.5 FET MWD010 HR 0.23 7.48 0.802267 4666 2904 5236.5 GR MWD010 API 57.88 192.05 125.791 4737 2859 5227 ROP MWD010 FPH 0.11 270.25 158.727 4735 2920 5287 First Reading For Entire File 2859 Last Reading For Entire File 5287 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/09/10 Maximum Physical Record65535 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 10/09/10 Maximum Physical Record65535 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 5227.5 11460.5 SEXP 5237.0 11469.5 SFXE 5237.0 11469.5 SEMP 5237.0 11469.5 SEDP 5237.0 11469.5 SESP 5237.0 11469.5 SROP 5287.5 11507.0 $ LOG HEADER DATA DATE LOGGED: 21-AUG-10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.2 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 11507.0 TOP LOG INTERVAL (FT) : 5287.0 BOTTOM LOG INTERVAL (FT) : 11507.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 44.1 MAXIMUM ANGLE: 87.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 132482 EWR4 EWR Phase-4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.750 DRILLER'S CASING DEPTH (FT) : 2914.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.70 MUD VISCOSITY (S) : 40.0 MUD PH: 9.1 MUD CHLORIDES (PPM) : 400 FLUID LOSS (C3) : 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 4.000 77.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.034 162 .6 MUD FILTRATE AT MT: 4.250 76.0 MUD CAKE AT MT: 3.100 78.0 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 5227.5 11507 8367.25 12560 5227.5 11507 RPD MWD020 OHMM 2.55 45.98 7.27557 12466 5237 11469.5 RPM MWD020 OHMM 2 .72 34.75 7.00236 12466 5237 11469.5 RPS MWD020 OHMM 2.64 40.94 6.47876 12466 5237 11469.5 RPX MWD020 OHMM 2.58 49.23 6.29845 12466 5237 11469.5 FET MWD020 HR 0.2 28.2 0.651704 12466 5237 11469.5 GR MWD020 API 40.59 377.26 117.647 12467 5227.5 11460.5 ROP MWD020 FPH 15.86 248.04 137.921 12440 5287.5 11507 First Reading For Entire File 5227.5 Last Reading For Entire File 11507 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/09/10 Maximum Physical Record65535 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 10/09/10 Maximum Physical Record65535 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 SGRC 11461.0 15763.5 SESP 11487.0 15770.5 SFXE 11487.0 15770.5 SEMP 11487.0 15770.5 SEXP 11487.0 15770.5 SEDP 11487.0 15770.5 SROP 11507.5 15813.0 # I LOG HEADER DATA DATE LOGGED: 01-SEP-10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 5.55 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 15813.0 TOP LOG INTERVAL (FT) : 11507.0 BOTTOM LOG INTERVAL (FT) : 15813.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 87.8 MAXIMUM ANGLE: 91.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 203301 EWR4 EWR Phase-4 67978 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6.750 DRILLER'S CASING DEPTH (FT) : 11497.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.00 MUD VISCOSITY (S) : 44 .0 MUD PH: 9.6 MUD CHLORIDES (PPM) : 21000 FLUID LOSS (C3) : 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .230 76.0 MUD AT MAX CIRCULATING TERMPERATURE: .112 162.6 MUD FILTRATE AT MT: .220 76.0 MUD CAKE AT MT: .180 73.0 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 MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11461 15813 13637 8705 11461 15813 RPD MWD030 OHMM 2 .98 2000 48.0303 8568 11487 15770.5 RPM MWD030 OHMM 0.67 1703.84 29.1901 8568 11487 15770.5 RPS MWD030 OHMM 0.4 662.28 21.3206 8568 11487 15770.5 RPX MWD030 OHMM 0.33 643 .33 18.5935 8568 11487 15770.5 FET MWD030 HR 0.35 155.42 1.72095 8568 11487 15770.5 GR MWD030 API 28.16 108.48 56.989 8606 11461 15763.5 ROP MWD030 FPH 0.02 139.58 84.5805 8612 11507.5 15813 First Reading For Entire File 11461 Last Reading For Entire File 15813 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/09/10 Maximum Physical Record65535 File Type LO Next File Name STSLIB.005 Physical EOF File Header Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/09/10 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 15764.0 15780.0 SEMP 15771.0 15787.0 SEXP 15771.0 15787.0 SESP 15771.0 15787.0 SEDP 15771.0 15787.0 SFXE 15771.0 15787.0 SROP 15813.5 15829.0 LOG HEADER DATA DATE LOGGED: 03-SEP-10 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 5.55 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 15829.0 TOP LOG INTERVAL (FT) : 15813 .0 BOTTOM LOG INTERVAL (FT) : 15829.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 90.9 MAXIMUM ANGLE: 90.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR Dual Gamma Ray 94063 EWR4 EWR Phase-4 173235 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6.130 DRILLER'S CASING DEPTH (FT) : 11497.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9.00 MUD VISCOSITY (S) : 45.0 MUD PH: 9.6 MUD CHLORIDES (PPM) : 23500 FLUID LOSS (C3) : 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .230 76.0 MUD AT MAX CIRCULATING TERMPERATURE: .112 162 .6 MUD FILTRATE AT MT: .220 76.0 MUD CAKE AT MT: .180 76.0 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 MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 15764 15829 15796.5 131 15764 15829 RPD MWD040 OHMM 4.44 6.99 5.76333 33 15771 15787 RPM MWD040 OHMM 3 .02 4.84 3.99545 33 15771 15787 RPS MWD040 OHMM 2 .52 3.81 3.20121 33 15771 15787 RPX MWD040 OHMM 2 .23 3 .1 2.67212 33 15771 15787 FET MWD040 HR 51.83 53.26 52.39 33 15771 15787 1 GR MWD040 API 101.21 115.44 108.648 33 15764 15780 ROP MWD040 FPH 0.2 8.7 3 .33781 32 15813.5 15829 First Reading For Entire File 15764 Last Reading For Entire File 15829 File Trailer Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 10/09/10 Maximum Physical Record65535 File Type LO Next File Name STSLIB.006 I Physical EOF Tape Trailer Service name LISTPE Date 10/09/10 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 10/09/10 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
