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206-142
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD4-321 COLVILLE RIV UNIT CD4-321 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 CD4-321 50-103-20536-00-00 206-142-0 W SPT 7180 2061420 4000 2286 2290 2286 2285 0 0 0 0 REQVAR P Josh Hunt 6/17/2025 2-year MIT required by AIO 18C.002, tested to maximum anticipated injection pressure. 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 CD4-321 Inspection Date: Tubing OA Packer Depth 675 4200 4150 4140IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250618073358 BBL Pumped:6.4 BBL Returned:6.4 Thursday, July 24, 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:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CRU CD4-321 (PTD 206-142) Date:Wednesday, March 12, 2025 1:01:48 PM Attachments:image001.png AnnComm Surveillance TIO for CD4-321.pdf From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Wednesday, March 12, 2025 10:16 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: CRU CD4-321 (PTD 206-142) Chris, As per the communication below, CRU CD4-321 (PTD 206-142) was placed on a 30-day monitoring period to watch to watch IA pressures while on gas injection. During the 30 days, the IA has not exhibited problematic behavior and has been stable on injection. Attached is the 90-day TIO plot and wellbore schematic. The plan is to stop the 30 day monitor and continue gas injection. Please let me know if you have any questions or disagree with the plan forward. Thanks, Mark Mark Shulman WNS Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 From: WNS Integrity Sent: Wednesday, February 12, 2025 2:53 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: CRU CD4-321 (PTD 206-142) Hi Chris, CRU CD4-321 (PTD 206-142) is a WAG injector currently on MI injection with amended AIO 18C.002. The IA pressure exceeded the wells maximum operating pressure of 2,000 psi on February 11, 2025 with a pressure of 2,003 psi before being bled by the operations team. The Operations team had increased the injection rate causing raising IA pressure. Following the pressure excursion, the IA was bled from 2,003 psi to 1,500 psi. The IA has stabilized at the new injection rate at 1,400 psi. The production casing is 7” 26# L80 with a burst rating of 7,240 psi (45% of burst is 3,258 psi). CPAI believes that the increased IA pressure was due to the increase in injection rate. CPAI will start a 30 day monitor this well on gas injection closely and report as required if any additional anomalies are observed. Warmest regards, Mark Mark Shulman WNS Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 CD4-321 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD4-321 2025-02-11 2002 1425 -577 IA CD4-321 2025-02-11 1437 1462 25 IA CD4-321 2025-02-16 1470 495 -975 IA CD4-321 2025-02-16 455 950 495 IA Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD4-321 5/9/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull A1, Drift, Re-set new A1 CD4-321 10/26/2024 oberr Notes: General & Safety Annotation End Date Last Mod By Note: Waivered for WAG Injection with surface casing leak 6/20/2017 pproven NOTE:5/9/2017 pproven 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 INS 34" 16 15.2537.0 114.0 114.065.00 H-40 WELDED SURFACE 9 5/8 8.83 36.6 3,504.0 2,385.2 40.00 L-80 BUTT INTERMEDIATE 7 6.28 34.4 19,323.1 7,800.2 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 30.9 Set Depth… 18,055.2 Set Depth… 7,173.2 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection Hydril 563 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) 30.9 30.9 0.06 HANGER 11.000 FMC 4-1/2" Tubing Hanger FMC TC-EMS 4.000 2,289.7 1,958.5 58.55 NIPPLE 4.500 DB-6 Landing Nipple, 4-1/2" x 3.812", L80, HYD563 BxP Camco DB-63.812 17,818.5 7,095.5 71.16 GAS LIFT 6.109 4-1/2" x 1", Camco KBMG GLM, w/ DCK-2 (2000 psi) SOV, BEK-5 Camco BEK-53.860 17,875.6 7,114.0 70.99 SEAL ASSY 4.500 Baker Seal Assy (1.89' from fully located) BakerH683-19 -4756 3.875 17,888.4 7,118.2 70.96 SBR 5.490 Baker PBR, 17.65' polish bore at 4.75" ID 4.750 17,918.8 7,128.1 70.86 PACKER 7.000 Baker Premier Production Packer Baker Premier 3.880 17,983.6 7,149.4 70.64 NIPPLE 4.500 X Landing Nipple, 3.813", L80, HYD563 BxPw/ RHC HES X 3.812 18,049.0 7,171.2 70.63 OVERSHOT 5.500 Baker, non-sealing Tbg stub overshot (2' from fully located) Baker4.750 Top (ftKB) 18,052.4 Set Depth… 18,194.2 Set Depth… 7,219.5 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM 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) 18,077.0 7,180.4 70.66 PACKER 5.970 BAKER PREMIER PACKER Baker 3.875 18,181.9 7,215.4 70.35 NIPPLE 5.000 HES NX NO GO NIPPLE 3.725 18,192.8 7,219.1 70.32 WLEG 5.000 BAKER WIRELINE FLUTED GUIDE 3.875 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) 2,289.7 1,958.5 58.55 INJ VALVE 4.5" A1 Injection Valve on 3.812" DB Lock (40" OAL) Camco A1 HYS- 0444 10/26/2024 1.250 17,981.0 7,148.6 70.65 FISH A glove was dropped down the IA while N/D the BOPE and not recovered. 4/22/2017 0.000 18,051.0 7,171.8 70.63 CHEM CUT CHEM CUT 4/16/2017 0.000 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) 17,818.5 7,095.5 71.16 1 GAS LIFT DMY BK 0.00.0 4/28/2017 Camco 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 18,434.0 18,450.0 7,299.8 7,305.3 11/20/2006 6.0 IPERF 18,450.0 18,470.0 7,305.3 7,312.3 11/20/2006 6.0 IPERF CD4-321, 10/27/2024 5:13:20 AM Vertical schematic (actual) INTERMEDIATE; 34.4-19,323.1 Float Shoe; 19,321.0-19,323.1 Float Collar; 19,233.3-19,234.5 IPERF; 18,450.0-18,470.0 IPERF; 18,434.0-18,450.0 WLEG; 18,192.8 NIPPLE; 18,181.9 PACKER; 18,077.0 OVERSHOT; 18,049.0 CHEM CUT; 18,051.0 PACKER; 17,918.8 GAS LIFT; 17,818.5 Tam Port Collar; 9,512.6-9,515.4 SURFACE; 36.6-3,504.0 Float Shoe; 3,501.7-3,504.0 Float Collar; 3,422.2-3,423.3 INJ VALVE; 2,289.7 CONDUCTOR INS 34" ; 37.0- 114.0 Casing Hanger; 36.6-38.8 Casing Hanger; 34.4-37.0 HANGER; 30.9 WNS INJ KB-Grd (ft) 43.58 RR Date 10/26/200 6 Other Elev… CD4-321 ... TD Act Btm (ftKB) 19,337.0 Well Attributes Field Name NANUQ KUPARUK Wellbore API/UWI 501032053600 Wellbore Status INJ Max Angle & MD Incl (°) 72.56 MD (ftKB) 3,218.04 WELLNAME WELLBORE Annotation Last WO: End Date 4/23/2017 H2S (ppm)DateComment SSSV: NIPPLE 1 Gluyas, Gavin R (OGC) From:Wallace, Chris D (OGC) Sent:Wednesday, February 12, 2025 4:36 PM To:AOGCC Records (CED sponsored) Subject:FW: CRU CD4-321 (PTD 206-142) Attachments:AnnComm Surveillance TIO for CD4-321.pdf From: WNS Integrity <WNSIntegrity@conocophillips.com> Sent: Wednesday, February 12, 2025 2:53 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: CRU CD4-321 (PTD 206-142) Hi Chris, CRU CD4-321 (PTD 206-142) is a WAG injector currently on MI injection with amended AIO 18C.002. The IA pressure exceeded the wells maximum operating pressure of 2,000 psi on February 11, 2025 with a pressure of 2,003 psi before being bled by the operations team. The Operations team had increased the injection rate causing raising IA pressure. Following the pressure excursion, the IA was bled from 2,003 psi to 1,500 psi. The IA has stabilized at the new injection rate at 1,400 psi. The production casing is 7” 26# L80 with a burst rating of 7,240 psi (45% of burst is 3,258 psi). CPAI believes that the increased IA pressure was due to the increase in injection rate. CPAI will start a 30 day monitor this well on gas injection closely and report as required if any additional anomalies are observed. Warmest regards, Mark Mark Shulman WNS Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com OƯice (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. CD4-321 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING CD4-321 2025-02-11 2002 1425 -577 IA CD4-321 2025-02-11 1437 1462 25 IA Last Tag Annotation Depth (ftKB)Wellbore End Date Last Mod By Last Tag:CD4-321 5/9/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull A1, Drift, Re-set new A1CD4-321 10/26/2024 oberr Notes: General & Safety Annotation End Date Last Mod By Note: Waivered for WAG Injection with surface casing leak 6/20/2017 pproven NOTE:5/9/2017 pproven 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 INS 34" 16 15.2537.0 114.0 114.065.00 H-40 WELDED SURFACE 9 5/8 8.83 36.6 3,504.0 2,385.2 40.00 L-80 BUTT INTERMEDIATE 7 6.28 34.4 19,323.1 7,800.2 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 30.9 Set Depth … 18,055.2 Set Depth … 7,173.2 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection Hydril 563 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) 30.930.90.06 HANGER 11.000 FMC 4-1/2" Tubing Hanger FMC TC-EMS 4.000 2,289.7 1,958.5 58.55 NIPPLE 4.500 DB-6 Landing Nipple, 4-1/2" x 3.812", L80, HYD563 BxP Camco DB-63.812 17,818.5 7,095.5 71.16 GAS LIFT 6.109 4-1/2" x 1", Camco KBMG GLM, w/ DCK-2 (2000 psi) SOV, BEK-5 Camco BEK-5 3.860 17,875.6 7,114.0 70.99 SEAL ASSY4.500Baker Seal Assy (1.89' from fully located) Baker H683-19 -4756 3.875 17,888.4 7,118.2 70.96 SBR 5.490 Baker PBR, 17.65' polish bore at 4.75" ID 4.750 17,918.8 7,128.1 70.86 PACKER 7.000 Baker Premier Production Packer Baker Premier 3.880 17,983.6 7,149.4 70.64 NIPPLE 4.500 X Landing Nipple, 3.813", L80, HYD563 BxPw/ RHC HES X 3.812 18,049.0 7,171.2 70.63 OVERSHOT5.500Baker, non-sealing Tbg stub overshot (2' from fully located) Baker 4.750 Top (ftKB) 18,052.4 Set Depth … 18,194.2 Set Depth … 7,219.5 String Max No… 4 1/2 Tubing Description Tubing – Production Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM 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) 18,077.0 7,180.4 70.66 PACKER 5.970 BAKER PREMIER PACKER Baker 3.875 18,181.9 7,215.4 70.35 NIPPLE 5.000 HES NX NO GO NIPPLE 3.725 18,192.8 7,219.1 70.32 WLEG 5.000 BAKER WIRELINE FLUTED GUIDE 3.875 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) 2,289.7 1,958.5 58.55 INJ VALVE 4.5" A1 Injection Valve on 3.812" DB Lock (40" OAL) Camco A1 HYS- 0444 10/26/2024 1.250 17,981.0 7,148.6 70.65 FISH A glove was dropped down the IA while N/D the BOPE and not recovered. 4/22/2017 0.000 18,051.0 7,171.8 70.63 CHEM CUT CHEM CUT 4/16/2017 0.000 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) 17,818.5 7,095.5 71.16 1 GAS LIFT DMY BK 0.00.0 4/28/2017 Camco 0.000 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 18,434.0 18,450.0 7,299.8 7,305.3 11/20/2006 6.0 IPERF 18,450.0 18,470.0 7,305.3 7,312.3 11/20/2006 6.0 IPERF CD4-321, 10/27/2024 5:13:20 AM Vertical schematic (actual) INTERMEDIATE; 34.4-19,323.1 Float Shoe; 19,321.0-19,323.1 Float Collar; 19,233.3-19,234.5 IPERF; 18,450.0-18,470.0 IPERF; 18,434.0-18,450.0 WLEG; 18,192.8 NIPPLE; 18,181.9 PACKER; 18,077.0 OVERSHOT; 18,049.0 CHEM CUT; 18,051.0 PACKER; 17,918.8 GAS LIFT; 17,818.5 Tam Port Collar; 9,512.6-9,515.4 SURFACE; 36.6-3,504.0 Float Shoe; 3,501.7-3,504.0 Float Collar; 3,422.2-3,423.3 INJ VALVE; 2,289.7 CONDUCTOR INS 34" ; 37.0- 114.0 Casing Hanger; 36.6-38.8 Casing Hanger; 34.4-37.0 HANGER; 30.9 WNS INJ KB-Grd (ft) 43.58 RR Date 10/26/200 6 Other Elev… CD4-321 ... TD Act Btm (ftKB) 19,337.0 Well Attributes Field Name NANUQ KUPARUK Wellbore API/UWI 501032053600 Wellbore Status INJ Max Angle & MD Incl (°) 72.56 MD (ftKB) 3,218.04 WELLNAME WELLBORE Annotation Last WO: End Date 4/23/2017 H2S (ppm)DateComment SSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD4-321 COLVILLE RIV UNIT CD4-321 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 CD4-321 50-103-20536-00-00 206-142-0 W SPT 7180 2061420 4000 2545 2555 2555 2555 0 0 0 0 REQVAR P Bob Noble 6/25/2023 MITIA to max anticipated inject pressure as per AIO 18C.002 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 CD4-321 Inspection Date: Tubing OA Packer Depth 640 4200 4140 4140IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN230629130939 BBL Pumped:6.5 BBL Returned:6.5 Thursday, July 27, 2023 Page 1 of 1 MEMORANDUM TO: Jim Re` gg P.I. Supervisor ti 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 -321 COLVILLE RIV C134-321 Src: Inspector Reviewed By: P.I. Supry -Isp— Comm Well Name COLVILLE RIV CD4 -321 API Well Number 50-103-20536-00-00 Inspector Name: Lou Laubenstein Permit Number: 206-142-0 Inspection Date: 6/11/2021 Insp Num: mitLOL210611145901 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4 -321 'Type Inj i W - TVD 7180 Tubing 2394 - 2394 _ 2394 _ 2394 PTD 2061420 Type Test SPT"Test psi 3900 IA 1300 _ 4200 4180 4180 - BBL Pumped: 4.9 BBL Returned: 4.9 OA 0 0 0 0 Inter—, REQvAR P/F P Notes: MIT -IA to maximum anticipated injection pressure per AIO 18C.002 Thursday, June 17, 2021 Page 1 of I ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 10, 2020 Commissioner Jesse Chmielowski Alaska Oil & Gas Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jesse Chmielowski: RECEIVED Mpl,'Y 13 2020 AOCCC Enclosed are the spreadsheets 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/sand if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement/sand was installed April 215f thru April 24`h, 2020. The corrosion inhibitor/sealant was pumped on April 22°d thru April 25`h, 2020. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerel !, � Roger Winter ConocoPhillips Well Integrity Field Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) Alpine Field Date 5/10/2020 CD2, 3, 4 & MT6 Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement/Sand top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal CD2 -02 *501032051300 2051090 30" 14 gals 9" 4/24/2020 1.5 4/25/2020 CD2 -73 *501032059000 2081960 11" 1 gal 6" 4/24/2020 0.5 4/2512020 CD2 -468 *501032058700 2081800 11" 1 gal 7" 4/24/2020 0.8 4/25/2020 CD3 -111A *501032052601 2170040 14" 4 gals V. 4/21/2020 1.3 4/22/2020 CD3 -198 *501032063700 2110240 10" 10" 3 4/22!2020 CD4 -215 *501032053900 2061570 40" 28 gals 9" 4/23/2020 1.4 4/23/2020 CD4 -291 *501032067200 2131100 2r 80 gals 6" 4/23/2020 0.5 4/23/2020 CD4 -321 *501032053600 2061420 18.5' 4 gals 6" 4/23/2020 0.5 4/23/2020 MT6-02 *501032079200 2181600 30" 14 gals 8" 4/23/2020 1 4/24/2020 MT6-03 *501032077000 2180160 49" 32 gals 10" 4/23/2020 1.7 4/24/2020 MT6-04 *501032077500 2181080 24" 17 gals 8" 4/23/2020 1 4/24/2020 MT6-05 *501032077100 2180450 30" 10 gals 7" 4/23/2020 1.3 4/24/2020 MT6-06 *501032077300 2180930 25' 7 gals 8" 4/23/2020 1 4/24/2020 MT6-08 *501032077200 2180480 12" 2.5 gals 7" 4/23/2020 1 4/24/2020 MT6-09 *501032077900 2181340 34" 15 gals 9" 4/23/2020 1.5 4/24/2020 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 7p / DATE: Tuesday, July 2, 2019 PA. SupervisorI [ � f SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CD4 -321 FROM: Adam Earl COLVILLE RIV NAN-K CD4 -321 Petroleum Inspector Src: Inspector Reviewed By: P.1.Supry .1 NON -CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-K CD4 -321 API Well Number 50-103-20536-00-00 Inspector Name: Adam Earl Permit Number: 206-142-0 Inspection Date: 6/20/2019 Insp Num: mitAGE190623113437 Rel Insp Num: Packer Depth Well C134-321 - Type Ini W- TVD %iso PTD zo61az0'Type Test SNT Test psi _100 BBL Pumped: 68 - BBL Returned: 6.S Interval' REQVAR .._IP/F i Notes: MITIA tested as per AIO 18C.002 to MAIP Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 2coi mo; 2003 2002 - IA ].0 4200 41165 - 4a6o - OA a 0 0 0 Tuesday, July 2, 2019 Page I of I cf • • c --4-'� a _I a) N M U -0 cc (V — a (v)" •, X Ql fG cO Q Q 10 CI ^1` - v a O i`� O ~ y O H > O • N 0 p ti V a Y v E o (o > _ o2(5 ail III o o o w co v n3 >- Q Q r aNz t7 a)_c v 0 Q W l.9 +.4 N ++ (n �lnm O Q a N L C C (p H r4 Y W Q Q E 4-+ (a 'C rm Q N C fu a) �' WQ U a) o ° u t .0 0- U.' J J CO (1) Ua. y_ ,•- _ _ W W pOp = co O O LL L� 'N aJ E -0 N 0 F J J Q ) 0 C a) (1') N Q Q Q .. N , N a, O 0) ° LL LLL c)u n3 L) IP E• 4; E ai a O 0 O LT rst° Z N a a) +' -a ax i" 0 c O saC a, .:. z p Q r XI.41 U n ~ C co 0 CD it < a) o > EJ b in w U U r--= d C5 _i Z w a .� U m m = CV cc I— H4 U ro w v J is (f CI m 0 1,4 a M a � r. a) Z \ Z a`( aG ro b r., w O > (0 0 m « ; G J J 1 ro M I / ii; • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 19,2017 TO: Jim Regg P.I.Supervisor � 6rZ((/? SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-321 FROM: Bob Noble COLVILLE RIV NAN-K CD4-321 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-K CD4-321 API Well Number 50-103-20536-00-00 Inspector Name: Bob Noble Permit Number: 206-142-0 Inspection Date: 6/9/2017 ✓ Insp Num: mitRCN170612073953 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4-321 Type Inj W 'TVD I 7180 - Tubing 1909 1909 - 1907 - 1904- PTD 2061420 - Type Test SPT Test psi 4080 - IA 1070 4200 - 4180 _ 4180 BBL Pumped: 5.5 -BBL Returned: 5.5 - OA 0 0 o _ o - I Interval REQVAR P/F P Notes: MITIA per AIO 18C.002 to max anticapated injection pressure of 4080. SCANNED AUG 2 2 201? Monday,June 19,2017 Page 1 of 1 • STATE OF ALASKA ` ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory❑ 206-142 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service 0 6.API Number: 99510 50-103-20536-00 7.Property Designation(Lease Number): 8.Well Name and Number: CRU CD4-321 ADL 380077,ADL 387209,ASRCNPRA02 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 19,337 feet Plugs measured NONE feet true vertical 7,810 feet Junk measured NONE feet Effective Depth measured 19,323 feet Packer measured 17919, 18077 feet true vertical 7,800 feet true vertical 7128,7180 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 feet 16 " 114' MD 114 SURFACE 3,467 feet 9 5/8" 3,504'MD 2385 INTERMEDIATE 19,289 feet 7 " 19,323'MD 7800 RECEIVED Perforation Depth Measured depth 18434-18450, 18450-18470 feet MAY 2 2 2017 True Vertical depth 7300-7305, 7305-7312 feet AOCC Tubing(size,grade,measured and true vertical depth) 4.5" L-80 18,194' MD 7,219'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER PREMIER PRODUCTION PACKER 17,919' MD 7,128'TVD PACKER-BAKER PREMIER PACKER 18,077' MD 7,180'TVD SSSV: NIPPLE 2,290' MD 1,958'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,s 25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development❑ Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ ❑ WAG 0 GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-111 Contact Name: Andrew Beat Authorized Name: Andrew Beat Authorized Title: Workover Engineer Contact Email: Andrew.T.Beat@cop.com ` SAZ `,zo 17 Contact Phone: (907)265-6341 Authorized SignatureA771740------ Ifni. Date: / Form 10-404 Revised 4/2017 PTN �� tiri W 2 rf 7t�� Submit Original Only Operations Summary (with Timelog Depths) 0; CD4-321 c `PhIIMiips Al. Rig: DOYON 19 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code. Time P-T-X Operation (ftKB) End Depth(ftKB) 4/16/2017 4/17/2017 12.00 MIRU MOVE MOB P Break down modules and split apart in 12:00 00:00 preparation for rig move. Pull Doyon 19 off of CD1 -14 and transport modules to end of Alpine Airstrip. 4/17/2017 4/17/2017 8.00 MIRU MOVE MOB P Move Doyon 19 from CD1,along run 00:00 08:00 way and to CD 4 pad. 4/17/2017 4/17/2017 14.00 MIRU MOVE OTHR P Change out cellar walls to 08:00 22:00 accommodate 20-ft well centers 4/17/2017 4/18/2017 2.00 MIRU MOVE MOB P Move sub base on to mats and center 22:00 00:00 up with the well. 4/18/2017 4/18/2017 4.75 MIRU MOVE MOB P Move in over CD4-321,Center up and 0.0 0.0 00:00 04:45 set down. Skid the sub over the well. Move in complexes and connect all interconnects. 4/18/2017 4/18/2017 1.75 MIRU MOVE MOB P Spot ballmill and pipe shed. 0.0 0.0 04:45 06:30 4/18/2017 4/18/2017 3.50 MIRU MOVE RURD P Hook up steam lines,air,and water. 0.0 0.0 06:30 10:00 Connect flow liens to sub base take RKB measurements. RKB-GL= 36.82',LLDS=34', ULDS=30.95'. 4/18/2017 4/18/2017 3.00 MIRU MOVE RURD P M/U IA valves to tree,spot squeeze 0.0 0.0 10:00 13:00 manifold and rig up to choke skid. Positioned TigerTank and spotted Pipe Shed. ACCEPTED RIG @ 13:00 4/18/2017 4/18/2017 2.00 MIRU WELCTL RURD P R/U hoses and squeeze manifold to 0.0 0.0 13:00 15:00 choke skid andTiger Tank. Thawed out frozen hard lines and checked hammer unions. SimOps,took on sea water. 4/18/2017 4/18/2017 1.00 MIRU WELCTL MPSP P Rig up lubricator and test to 3500 psi. 0.0 0.0 15:00 16:00 Pulled BPV and L/D.Tubing=300 psi, IA=200 psi. 4/18/2017 4/18/2017 1.50 MIRU WELCTL SEQP P Steam line to TigerTank. Checked 0.0 0.0 16:00 17:30 flow path and pressure tested lines to 3500 psi. 4/18/2017 4/18/2017 2.75 MIRU WELCTL CIRC P Pump seawater down IA taking 0.0 0.0 17:30 20:15 returns up tubing to clear diesel cap. Pumped 55 bbl @ 6 bpm,to the TigerTank. Shut down and lined up to pump down tubing and take returns f/ IA to TigerTank. Pumped 644 bbl at 4 -6 bpm,930-1720 psi. 4/18/2017 4/18/2017 0.75 MIRU WELCTL OWFF P OWFF. Well static within 10 min and 0.0 0.0 20:15 21:00 observed static for 30 min. 4/18/2017 4/18/2017 0.75 MIRU WHDBOP MPSP P Installed BPV and tested to 1000 psi 0.0 0.0 21:00 21:45 for 10 min. SimOps,B/D hard lines to TigerTank. 4/18/2017 4/18/2017 0.75 MIRU WHDBOP NUND P Bleed off tree/adapter void and N/D 0.0 0.0 21:45 22:30 tree. SimOps,R/D displacement lines in cellar. 4/18/2017 4/18/2017 1.00 MIRU WHDBOP MPSP P Inspected tubing hanger threads and 0.0 0.0 22:30 23:30 installed blanking plug. Measured height f/ULDS. 4/18/2017 4/19/2017 0.50 MIRU WHDBOP NUND P N/U BOPE. 0.0 0.0 23:30 00:00 4/19/2017 4/19/2017 0.50 MIRU WHDBOP NUND P N/U BOPE. 0.0 0.0 00:00 00:30 Page 1/5 Report Printed: 4/25/2017 Operations Summary (with Timelog Depths) �p ��,�, F �,` CD4-321 s,. Coo mdips Rig: DOYON 19 Job: RECOMPLETION Time Logrt Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation St(ftKB) End Depth(ftKB) 4/19/2017 4/19/2017 2.00 MIRU WHDBOP 'NUND P R/U RCD clamp,flow box,Orbit valve, 0.0 0.0 00:30 02:30 trip nipple,bleeder hose and choke lines. 4/19/2017 4/19/2017 2.00 MIRU WHDBOP RURD P R/U to test BOPE. M/U 4.5"test joint, 0.0 0.0 02:30 04:30 XO,and blanking plug. Fill stack and lines w/water and purge air. 4/19/2017 4/19/2017 7.50 MIRU WHDBOP BOPE P BOPE test witness waived by Guy 0.0 0.0 04:30 12:00 Cook. Tested annular,3.5"x6"top and bottom VBRs,valves 1-14,Auto and manual IBOP,Kill and Choke valves, needle valve,4"Demco,and 4"FOSV w/4.5"test joint to 250/3500 psi for 5 min. Observed failure on the speed head ring gasket. B/D choke lines to investigate. 4/19/2017 4/19/2017 2.00 MIRU WHDBOP NUND T Removed trip nipple,hole fill lines and 0.0 0.0 12:00 14:00 mud bucket. Released BOP stack and P/U. Removed damaged API ring,cleaned ring groves and replaced speed head API ring. 4/19/2017 4/19/2017 2.00 MIRU WHDBOP NUND T N/U BOPE stack,flow lines,trip 0.0 0.0 14:00 16:00 nipple,and flow box. 4/19/2017 4/19/2017 0.50 MIRU WHDBOP RURD T P/U 4"test joint and R/U BOP test 0.0 0.0 16:00 16:30 equipment. Fill stack with water. 4/19/2017 4/19/2017 1.75 MIRU WHDBOP BOPE P Test upper and lower 3.5"x6"rams w/ 0.0 0.0 16:30 18:15 4"joint and blind rams to 250/3500 psi for 5 min. Draw down super choke and manual. 4/19/2017 4/19/2017 0.75 MIRU WHDBOP RURD P R/D test equipment and B/D lines. 0.0 0.0 18:15 19:00 Pulled blanking plug w/test joint. 4/19/2017 4/19/2017 1.25 MIRU WHDBOP MPSP P Pull BPV w/T-Bar. SimOps,stage 0.0 0.0 19:00 20:15 tools to rig floor to pull tubing. 4/19/2017 4/19/2017 1.25 COMPZN WHDBOP PULL P M/U landing joint A and engage 4.5" 18,052.0 18,052.0 20:15 21:30 tubing hanger. Set down and BOLDS. P/U to 208k and observed tubing free. Continued up 20'. P/U=180k,S/O= 110k. 4/19/2017 4/19/2017 0.25 COMPZN WHDBOP OWFF P OWFF,Well Static. 18,052.0 18,052.0 21:30 21:45 4/19/2017 4/20/2017 2.25 COMPZN WHDBOP RURD P Re-land hanger and R/U casing test 18,052.0 18,052.0 21:45 00:00 equipment,test manifold,and space out pup. Test surface lines to 4200 psi. 4/20/2017 4/20/2017 0.50 COMPZN RPCOMP PRTS P Pressure tested 7"casing to 4200 psi 18,052.0 18,052.0 00:00 00:30 for 30 min. Test held. 4/20/2017 4/20/2017 1.00 COMPZN RPCOMP CIRC P Circulated BU at 8 bpm w/1540 psi. 18,052.0 18,052.0 00:30 01:30 4/20/2017 4/20/2017 1.75 COMPZN RPCOMP RURD P B/D kill lines and L/D testing manifold. 18,052.0 18,052.0 01:30 03:15 Changed out elevators and installed bell guide. 4/20/2017 4/21/2017 20.75 COMPZN RPCOMP PULL P Pull 4.5"tubing to surface f/18,052'to 18,052.0 1,686.0 03:15 00:00 1,686'MD. Recovering I-Wire on spool.Control line was parted at 3 points,jnts#221,227,and 336 out of hole. Page 2/5 Report Printed: 4/25/2017 i A$F1m o Operations Summary (with Timelog Depths) f rw a c CD4-321 Conoc itiips Rig: DOYON 19 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(MB) 4/21/2017 4/21/2017 2.75 COMPZN RPCOMP PULL P Pull 4.5"tubing to surface f/1,686' 1,686.0 0.0 00:00 02:45 MD. Recovering I-Wire on spool.Cut joint was 15.28'long. NORM all equipment removed from well. 4/21/2017 4/21/2017 0.75 COMPZN RPCOMP WWWH P M/U and set 9"ID wear ring as per 0.0 0.0 02:45 03:30 FMC and LID tool. 4/21/2017 4/21/2017 1.00 COMPZN RPCOMP PULD P Clean and clear rig floor. L/D Cannon 0.0 0.0 03:30 04:30 clamps, I-Wire spools,and job box. 4/21/2017 4/21/2017 1.00 COMPZN RPCOMP SLPC P Slip and cut 78'of DL. SimOps,prep 0.0 0.0 04:30 05:30 4 1/2"tubing in pipe shed. 4/21/2017 4/21/2017 0.75 COMPZN RPCOMP SVRG P Service TD,inspect crown,and 0.0 0.0 05:30 06:15 brakes. 4/21/2017 4/21/2017 0.75 COMPZN RPCOMP RURD P R/U 4 1/2"tubing equipment. P/U 0.0 0.0 06:15 07:00 hanger assy,and C/O elevators. 4/21/2017 4/22/2017 17.00 COMPZN RPCOMP PUTB P Run 4 1/2"Hyd563 tubing f/surface to 0.0 17,305.0 07:00 00:00 17,305'MD as per tally. 4/22/2017 4/22/2017 0.75 COMPZN RPCOMP PUTB P Run 4 1/2"Hyd563 tubing f/17,305'to 17,305.0 18,019.0 00:00 00:45 18,019'MD as per tally. P/U=190, S/O=105 4/22/2017 4/22/2017 1.00 COMPZN RPCOMP PUTB P R/U head pin and circulation 18,019.0 18,057.0 00:45 01:45 equipment. S/O and tagged up at 18,052'MD w/20k. P/U and rotated 1/2 turn and tagged up at same spot. P/U a 3rd time swallowed tubing stump. S/O to 18,053'MD and sheared pins w/7k. Continued down to 18,057'MD and tagged NoGo. S/O 20k to confirm. 4/22/2017 4/22/2017 0.25 COMPZN RPCOMP CIRC P P/U and washed down over stump w/2 18,057.0 18,050.0 01:45 02:00 bpm, 120 psi and observed pressure increase to 200 psi,confirming stump in overshot. P/U above tubing stump. 4/22/2017 4/22/2017 1.75 COMPZN RPCOMP CIRC P Spotted 20 bbl of CI brine w/264 bbl 18,050.0 18,050.0 02:00 03:45 of sea water at 3 bpm,270 psi. 10 bbl in ann.and 10 bbl in tubing. 4/22/2017 4/22/2017 0.25 COMPZN RPCOMP HOSO P Dropped 1.88"ball&rod,and spaced 18,050.0 18,055.0 03:45 04:00 out 2'above top go at 18,055'MD. 4/22/2017 4/22/2017 0.25 COMPZN RPCOMP PACK P Pumped 6.5 bbl of sea water to seat 18,055.0 18,055.0 04:00 04:15 ball and pressured up to 3500 psi and held for 10 min while S/O as per baker to set packer. 4/22/2017 4/22/2017 0.25 COMPZN RPCOMP PRTS P Bleed of tubing to 2000 psi and 18,055.0 18,055.0 04:15 04:30 pressure tested IA to 1500 psi for 10 min. Packer held. 4/22/2017 4/22/2017 0.50 COMPZN RPCOMP HOSO P Bleed off and P/U 215k to release 18,055.0 18,055.0 04:30 05:00 SBR as per Baker. S/O and confirmed NoGo. Calculated needed space out to be 2'above NoGo. 4/22/2017 4/22/2017 0.75 COMPZN RPCOMP RURD P R/D circulating equipment and LID 2 18,055.0 18,055.0 05:00 05:45 space out joints. 4/22/2017 4/22/2017 0.75 COMPZN RPCOMP WWWH P M/U landing joint B and retrieve 9" 18,055.0 18,055.0 05:45 06:30 wear ring. 4/22/2017 4/22/2017 0.75 COMPZN RPCOMP HOSO P M/U 9.54'space out pup,tubing 18,055.0 18,055.0 06:30 07:15 hanger and landing joint. 4/22/2017 4/22/2017 2.25 COMPZN RPCOMP CIRC P Spot 341 bbl of CI brine in the annulus 18,055.0 18,055.0 07:15 09:30 w/599 bbl of sea water at 5.5 bpm, 700 psi. Page 3/5 Report Printed: 4/25/2017 J Operations Summary (with Timelog Depths) CD4-321 Whillipes ,' Rig: DOYON 19 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (5KB) End Depth(ftKB)' 4/22/2017 4/22/2017 0.50 COMPZN RPCOMP CIRC P Wash down at 1 bpm,30 psi and 18,055.0 18,055.0 09:30 10:00 locate seal assy w/160 psi build. 4/22/2017 4/22/2017 1.50 COMPZN RPCOMP HOSO P Drain stack and B/D lines. S/O and 18,055.0 18,055.0 10:00 11:30 land 4 1/2"tubing hanger at 18,055.23'MD. Ran in lockdown screw. 4/22/2017 4/22/2017 0.75 COMPZN RPCOMP PRTS P Pressure test hanger seals to 18,055.0 18,055.0 11:30 12:15 250/5000 psi for 5/10 min. 4/22/2017 4/22/2017 4.00 COMPZN .RPCOMP PRTS P R/U and test tubing to 4200 psi for 30 18,055.0 18,055.0 12:15 16:15 min. Bleed down to 3200 psi and test IA to 4200 psi for 30 min. Bleed off and pressure up IA to 2180 psi to shear GLM valve and pumped at 2 bpm,980 psi. R/D test equipment. State Witness waived by AOGCC, Ade Earl. 4/22/2017 4/22/2017 0.75 COMPZN WHDBOP MPSP P L/D landing joint and set BPV. Tested 18,055.0 0.0 16:15 17:00 BPV from IA to 1000 psi for 10 min. 4/22/2017 4/22/2017 0.75 COMPZN WHDBOP MPDA P N/D MPD equipment. 0.0 0.0 17:00 17:45 4/22/2017 4/22/2017 2.25 COMPZN WHDBOP NUND P Break ram doors for BWM,and 0.0 0.0 17:45 20:00 service break DSM. N/D BOP stack and set back on pedestal. 4/22/2017 4/22/2017 1.25 COMPZN WHDBOP NUND P Install SBSM,BPV,and N/U tree and 0.0 0.0 20:00 21:15 adapter. 4/22/2017 4/22/2017 1.50 COMPZN WHDBOP PRTS P Test adapter flange to 5000 psi. Fill 0.0 0.0 21:15 22:45 tree and test same to 250/5000 psi for 10 min. 4/22/2017 4/22/2017 0.75 COMPZN WHDBOP MPSP P Pull test dart and install BPV. 0.0 0.0 22:45 23:30 4/22/2017 4/23/2017 0.50 COMPZN WHDBOP RURD P R/U to freeze protect from the ball mill 0.0 0.0 23:30 00:00 and U-tube. 4/23/2017 4/23/2017 0.50 COMPZN WHDBOP RURD P R/U to freeze protect from the ball mill 0.0 0.0 00:00 00:30 and U-tube. 4/23/2017 4/23/2017 2.25 COMPZN WHDBOP FRZP P Pressure test lines 2800 psi and pump 0.0 0.0 00:30 02:45 80 bbl of 6.7#diesel freeze protect down the IA @ 2 bpm, 110 psi. SimOps,prep MP#1 for rig move and cellar for pad move. 4/23/2017 4/23/2017 0.50 COMPZN WHDBOP FRZP P Allowed the diesel to U-Tube for 30 0.0 0.0 02:45 03:15 min. Tub=220 psi, IA=220 psi,OA= 0 psi. 4/23/2017 4/23/2017 0.75 COMPZN WHDBOP MPSP P B/D and R/D lines. Set BPV as per 0.0 0.0 03:15 04:00 FMC w/lubricator. SimOps,Prep MP#2 for move. 4/23/2017 4/23/2017 1.00 COMPZN WHDBOP PRTS P Pressure test BPV to 2500 psi for 15 0.0 0.0 04:00 05:00 min on chart and bleed off IA to 320 psi. SimOps,R/D choke and flare lines outside for rig move. 4/23/2017 4/23/2017 1.00 COMPZN WHDBOP RURD P R/D squeeze manifold and B/D lines. 0.0 0.0 05:00 06:00 Function rig move systems,warm up generators,and hydraulics. "Rig Off High Line @ 6:00" 4/23/2017 4/23/2017 1.00 COMPZN WHDBOP RURD P Secure Well.R/D annulus valve and 0.0 0.0 06:00 07:00 working platform. Install flanges and gauges. SimOps,install 5"DP elevators on TD,De-energize TD and DW. Sub on gen power at 6:30. Page 4/5 Report Printed: 4/25/2017 Operations Summary (with Timelog Depths) CD4-321 ConocoPhalli ps Rig: DOYON 19 Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(5KB}_. 4/23/2017 4/23/2017 1.00 COMPZN MOVE MOB P Suck fluids.Disconnected service 0.0 0.0 07:00 08:00 lines in pits/sub. Work on Rig Move check list. "Rig Released @ 8:00" Page 5/5 Report Printed: 4/25/2017 WNS INJ CD4-321 'ConocoPhillips Well Attributes Max Angle&MD TD Alaska.InL;, Wellbore APUUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Cokoc4hiHips 501032053600 NANUO KUPARUK INJ 72.56 3,218.04 19,337.0 ... Ate. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD4-321,5/22/2017927:00 AM SSSV:NIPPLE Last WO: 4/232017 43.58 10/26/2006 Vertical schematic(actual) Annotation Depth IRKS) End Date Annotation Last Mod By End Date Last Tag: 5/9/2017 Rev Reason:RECOMPLETION,GLV C/O,PULL pproven 5/9/2017 PLUG 8 CATCHER,SET INJ VALVE Casing Strings HANGER,30.9 'o,"�t ,-: ' 1I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR INS 34" 16 15.250 37.0 114.0 114.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)...Wt/Len(I...Grade Top Thread I / SURFACE 95/8 8.835 36.6 3,504.0 2,385.2 40.00 L-80 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread , INTERMEDIATE 7 6.276 344 19,323.1 7,800.2 26.00 L-80 BTCM iii' Tubing Strings Ilk r.". Tubing DescriptionString Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(TVD((...Wt(lb/ft) Grade Top Connection TUBING RWO 2017 I 41/21 3.9581 30.9) 18,055.2 7,173.21 12.601 L-80 I Hydril 563 ,,,...,,...,,,,.......................,,..w„T^ Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl r) Item Des Com (in) 30.9 30.9 0.06 HANGER FMC 4-1/2"Tubing Hanger 4.000 CONDUCTOR INS 34•;'4o-0 2,289.7' 1,958.5 58.55 NIPPLE DB-6 Landing Nipple,4-1/2"X 3.812",L80,HYD563 BxP 3.813 ili17,875.6 7,114.0 70.99 SEAL ASSY Baker Seal Assy(1.89'from fully located) 3.875 17,888.4 7,118.2 70.96 SBR Baker PBR,17.65'polish bore at 4.75"ID 4.750 ���� 17,918.8 7,128.1 70.86 PACKER Baker Premier Production Packer 3.880 VALVE;2,290.01.; 17,983.6 7,149.4 70.64 NIPPLE X Landing Nipple,3.813",L80,HYD563 BxPw/RHC 3.812 18,049.0 7,171.2 70.63 OVERSHOT Baker,non-sealing Tbg stub overshot(2 from fully 4.750 located) Tubing Description Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth)TVD)(...Wt lb/R) Grade Top Connection TUBING ORIGINAL 'String 41/21 3.9581 18,052.4 18, 194.21 7,219.51 12.601 L-80 'Top 1 Completion Details Nominal ID Top(1KB) Top(TVD)(ftKB) Top Incl rt Item Des Com (In) 18,077.0 7,180.4 70.66 PACKER BAKER PREMIER PACKER 3.875 SURFACE;3863,504.0 18,181.9• 7,215.4 70.35 NIPPLE 'HES NX NO GO NIPPLE 3.125 • 18,192.8 7,219.1 70.32 WLEG BAKER WIRELINE FLUTED GUIDE 3.875 • Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (") Des Corn Run Date ID(In) 2,290.0 1,958.6 58.56 VALVE 4 1/2"MCX INJ VALVE(SER#SER#C3776581-3, 5/6/2017 1.500 34"GAL,1 5"ID) 17,981.0 7,148.6 70.65 FISH A glove was dropped down the IA while N/D the 4/22/2017 0.000 BOPE and not recovered. GAS LIFT,170105 18,051.0 7,171.8 70.63 CHEM CUT CHEM CUT 4/16/2017 0.000 Perforations&Slots Shot Dens Top(TVD) Btm)TVD) (shots/ Top(ftKB) star(MB) (MB) (MB) Zone Date ft) Type Com 18,434.0• 18,450.0 7,299.8 7,305.3 11/20/2006 6.0 (PERF lir flames- 18,450.0 18,470.0 7,305.3 7,312.3 11/20/2006 6.0 (PERF PACKER;17,918.8 lb. Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn ' 1 17,818.5 7,095.5 Camco BEK-5 0.0 GAS LIFT DMY BK 0.000 0.0 4/28/2017 Notes:General&Safety End Date Annotation 5/9/2017 NOTE: CHEM CUT;18,051.0 1 ` / \ OVERSHOT;18,049.0 I I PACKER;18,077.0 1 I NIPPLE;18,181.9 I WLEG;18,192.8 IPERF;18,434.0-18,450.0-- . (PERF;18,450.0-18,470.0-- . INTERMEDIATE,34.4-19,323.1- it • • .Zd C 14-zo Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, May 2, 2017 8:23 AM To: NSK Well Integrity Supv CPF3 and WNS Cc: Senden, R.Tyler Subject: RE: CRU CD4-321 (Sundry#317-111) Travis, Plan below to recommence injection–including the potential delay in witnessed testing to coincide with CPAI scheduled pad testing-is acceptable to AOGCC. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone), (907)276-7542(fax),chris.wallace@alaska.gov 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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.aov. From: NSK Well Integrity Supv CPF3 and WNS [mailto:n2549@conocophillips.com] Sent:Tuesday, May 2, 2017 7:46 AM To:Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject:CRU CD4-321(Sundry#317-111) SCANNED (Vii. 0 320- . [ Chris— CRU injection well CD4-321(PTD#206-142) recently had a rig workover completed under sundry number 317-111. In the approval,the AOGCC specifies a witnessed MIT-IA after the well is returned to stabilized injection. Because multiple State-witnessed MIT-IA's for CD4 drilisite are due by June 30, 2017 (and tentatively scheduled for around June 15, 2017), we request that the witnessed MIT-IA for CD4-321 be conducted at the same time. The well passed an MIT-IA to 4200 psi at the conclusion of the workover—the charted test is attached to this email. Post-rig wellwork has not been completed yet, but when it is,we would like to bring the well on water injection service and complete the required witnessed MIT-IA in June 2017. As noted in the 10-403 approval,we will submit a request for a reissued Administrative Approval for MWAG service. Please advise if this plan is acceptable. Thank you very much, Travis Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Wednesday,April 5, 2017 2:38 PM To: Wallace, Chris D (DOA) Subject: FW:CD4-321 (PTD#206-142) Hello Chris— Just to update this item,CD4-321 now has a pending workover under Sundry Approval 317-111. As per the Sundry, when the workover is complete we will renew the AA and perform a witnessed MITIA to return the well to MWAG service. Thank you very much, Travis SCANNED APP,P From: NSK Well Integrity Supv CPF3 and WNS p .l? , Sent:Saturday,January 28, 2017 5:01 PM To: 'chris.wallace@alaska.gov'<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject:CD4-321(PTD#206-142) Chris, Alpine injector CD4-321 (PTD#206-142,AIO 18C.002) had recently failed an MITIA on 1/18/2017. During the course of the diagnostic work, slickline exercised the CMD sliding sleeve open and closed. The sliding sleeve is believed to have been the source of communication,as subsequent testing yesterday(1/27/2017) passed an MITIA. The results of the MITIA are attached here. The well remains shut-in awaiting the approval of the 10-403 for surface casing repair. Upon completion of the surface casing repair, CPAI intends to return the well to water injection for a 30-day monitoring period to demonstrate the T x IA communication has been eliminated. Please let me know if you have questions or disagree with this plan. Regards, Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 • OF TFJ //j,-w THE STATE Alaska Oil and Gas tti , o f LAS <:A Conservation Commission A 333 West Seventh Avenue wo- GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS�P Fax: 907.276.7542 www.aogcc.alaska.gov Andr w eat WorkeoveBr Engineer c( � +' �k i' 4 ,10 1, ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field,Alpine Oil Pool, CD4-321 Permit to Drill Number: 206-142 Sundry Number: 317-111 Dear Mr. Beat: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, p90.44.4 7lL` Cathy P Foerster Chair h4 - DATED this 2day of March,2017. RBD MS Uv 1,;;,„; 2 3 2017 1 0 i RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 1 0 2017 APPLICATION FOR SUNDRY APPROVALS lb"7"..S 4 fl 7 !P"� 20 AAC 25.280 C 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well Q Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Conocophillips Alaska,Inc. Exploratory ❑ Development ❑ 206-142 3.Address: III Service Q , 6.API Number: Stratigraphic PO Box 100360,Anchorage,Alaska 99510 50-103-20536-00 " 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/Af CD4-321 ' Will planned perforations require a spacing exception? Yes El No E 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL0380077, ADL0387209,ASRCNPRA02 ' Colville River Field/Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 19323 7800 19323 7800 2993 Casing Length Size MD TVD Burst Collapse Structural Conductor 77 16 114 114 Surface 3467 9.625 3504 2384 Intermediate 19289 7 19323 7800 Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 18434'-18470' ' 7300'-7312' 4-1/2" L-80 18193 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Premier Packer, DB Nipple w/A-1 injection valve - Packer-18077', DB Nipple-2290' 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 ' 14.Estimated Date for 15.Well Status after proposed work: 3/8/2016 111 WINJ El WDSPL El Suspended ElCommencing Operations: OIL 16.Verbal Approval: Date: GAS ❑ WAG ❑., . GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Andrew Beat @ 265-6341 Email Andrew.T.Beatcop.com Printed Name Andrew Beat @ 265-6341 Title Workover Engineer 3/1o/zo t SignatureA—r72---- eLPhone Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3k1 _ tkk Plug Integrity ❑ BOP Test [ M-ec-haanical Integrity Test Location Clearance Elc- '1 � t1 Other: -I1 3500 e�4.. 6'©{n /zf-- i' "i' Rt._ i55,..„... viAA- -..r Mt4JA CZ CX r_///( t ..'r .re . U /ww] �'/ 26-?-11 /7 ` I Post Initial Injection MIT Req'd? Yes El/No ❑ C0 L� /d _ �11- Spacing Exception Required? Yes ❑ No Subsequent Form Required: �y ti l RDDNIS Vt' r A'1, 2 3 2017 V APPROVED BY Approved by: :54-••••—___ COMMISSIONER THE COMMISSION Date: 3 _az,-/7 R4G lNaA Submit Form and orm 10ved 11/2015 LaIis7m the date of approval. t,� attachments in Duplicate • 0 i pvRECEIVED ConocoPhillips MAR 1 0 2017 Alaska P.O. BOX 100360 j ANCHORAGE,ALASKA 99510-0360 March 10th,2017 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to work over Alpine CD4 Kuparuk Injector CD4-321 (PTD#206-142). An application was submitted and approved in 2016(316-060),however,scheduling difficulties did not allow the execution of this workover during the 2016 ice road season. CD4-321 was originally drilled and completed in 2006 as,a Kuparuk C sand MWAG injector in Alpine.In 2013, communication was found between the outer annulus and the conductor through a suspected surface casing leak at 54',detected by fluid level. At this point,ConocoPhillips applied for an AA waiver for water only injection(Sundry #313-181)and the well has been on water only injection since.Further diagnostics were completed in 2016-2017 that indicated the leak was shallower than 22' below surface and within the limitations of an external repair. In February 2017,a surface excavation was conducted to identify and repair the surface casing.A leak was identified 58"below the OA valve and a weld repair was performed,however,the subsequent MIT-IA failed 7 indicating there was another leak present in the surface casing. No further efforts to repair the surface casing externally are planned and this well will now require a workover. he proposed workover scope for CD4-321 is to pull the existing 4-1/2"tubing down to the permanent packer.A new 4-1/2"tubing string with gas tight connections and a stacked packer will then be run into place.An MIT-IA will ,)€*-- be conducted to confirm tubing and production casing integrity.Pending a passing test,CPAI will notify the state to amend the AA waiver for MWAG injection. A variance from 20 AAC 25.412 to allow the stacked packer to be set approximately 500' MD above the top of the perforations is also requested. t) If you have any questions or require any further information,please contact me at 265-6341. 92 Sincerely, t ` jj Andrew Bea Nibc` ,0 Senior RWO Engineer �is e." , CPAI Drilling and Wells * �/ y \(:) I\NI � � ,,- �1 i CD4-321 Rig Workover Swap 4-1/2"Tubing with Stacked Packer (PTD#:206-142) Current Status: This well is an active water injector into the Kuparuk C-sand at CD4 supporting CD5 and currently has a surface casing leak at an unknown depth. Scope of Work: Cut and pull the existing 4-1/2"tubing and run new 4-1/2"HYD563 gas tight tubing with a stacked packer.Work to be completed by Doyon 19. General Well info: Well Type: Injector MPSP: 2,993 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 3,708 psi/7,152' TVD(10.0 ppg EMW)measured on 7/11/2015 Wellhead type/pressure rating: FMC Gen V, 11"5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MIT-IA Passed— 1/27/17 Earliest Estimated Start Date: April 11,2017 Production Engineer: Anu Sood Workover Engineer: Andrew Beat(265-6341 /Andrew.T.Beat@cop.com) Pre-Rig Work 1. RU Slickline: Pull A-1 Injection Valve. Set plug in nipple @18,182', set catcher sub on top of plug. PT plug to 3,000 psi, perform NFT on plug. 2. Cut tubing in first full joint above packer 3. PT tbg &csg packoffs, FT LDS's. 4. Set BPV w/i 24 hrs of rig arrival. Workover Procedure 1. MIRU. 2. Pull BPV. Reverse circulate KWF. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF and repeat circulation as necessary. Verify well is dead. 3. Set BPV& blanking plug or two-way check, PT to 1,000 psi from below if possible, ND tree, NU BOPE &test to 3,500 psi high/250 psi low. 4. Pull blanking plug & BPV or two-way check. 5. RU to pull tubing, MU landing joint, BOLDS's, POOH laying down tubing. 6. RIH w/new 4-1/2" HYD563 gas tight tubing, stacked packer and seal assembly to just above the cut. Engage overshot over the tubing stub and set the premier packer. PT the IA to confirm packer is set. Shear the PBR. 7. Space out, mark the pipe, and pull out of PBR. , 8. Install space out pups below the hanger, MU hanger and land. RILDS. i0s/° 9. Load the well with corrosion inhibited brine. pct' , 4J' 10. PT the tubing for 10 min. Reduce the tubing pressure and PT h� e IA and chart for 30 min. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 11. Pull the landing joint, install BPV or two-way check. PT BPV or two-way check to 1,000 psi from below. 12. ND BOPE. NU tree. If BPV is installed, pull BPV& install tree test plug. Test tree. Pull test plug/two-way check. 13. Freeze protect well w/diesel. Install BPV. 14. RDMO. Post-Rig Work 1. Pull BPV. 2. RU Slickline: Change SOV for DV, Pull catcher, Pull plug. 3. Turn well over to operations. j "fi c>+-, 1 • n.-. WNS INJ CD4-321 ConocoPhillips w Well Attributes Max Angle&MD TD Alaska,Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) rmr,,_ p� 501032053600 NANUQ KUPARUK INJ 72.56 3,218.04 19,337.0 •°° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date CD4-321.4/19/201612.26.00 PM SSSV:WRDP Last W0: 43.58 10/26/2006 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:SET Al INJ VALVE pproven 4/19/2016 Casing Strings HANGER;31.5- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 11.-.111 -CONDUCTOR Insulated 34" 16 15.250 37.0 114.0 114.0 65.00 H-40 WELDED , L� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread �j SURFACE 95/8 8.835 36.6 3,504.0 2,385.2 40.00 L-80 BUTT 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread INTERMEDIATE 7 6.276 34.4 19,323.1 7,800.2 26.00 L-80 BTCM Ill 1}g Tubing Strings Tubing Description String Ma...�ID(in) Top(ftKB) Set Depth(ft..1 Set Depth(ND)(...Wt(IWft) Grade I Top Connection 1. Injection TUBING 41/2 3.9581 31.51 18,194.21 7219.51 12.60 L-80 IIBTM Gas �� Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) CONDUCTOR loculated 34`, 37.0-114.0 31.5 31.5 0.06 HANGER FMC TUBING HANGER 4.500 2,290.2 1,958.7 58.57 NIPPLE CAMCO DB NIPPLE 3.812 vs , 17,907.9 7,124.5 70.90 SLEEVE BAKER PREMIER SLIDING SLEEVE CMD 3.810 ■�■��//IIII��1f1f 17,993.5 7,152.7 70.61 GAUGE WEATHERFORD POD2 GAUGE CARRIER 3.958 VALVE;2,290.0 ZT'" 18,077.0 7,180.4 70.66 PACKER BAKER PREMIER PACKER 3.875 NIPPLE;2,290.2 rs 18,181.9 7,215.4 70.35 NIPPLE HES NX NO GO NIPPLE 3.725 18,192.8 7,219.1 70.32 WLEG BAKER WIRELINE FLUTED GUIDE 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (3 Des Com Run Date ID(in) s 2,290.0 1,958.6 58.56 VALVE A-1 INJ VLV(S/N:HLS-766/1.25"ORIFICE)ON DB- 4/17/2016 1.250 LOCK Perforations&Slots Shot SURFACE;36.6-3,504.0 w Dens Top(ND) Btm(ND) (shots// Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 18,434.0 18,450.0 7,299.8 7,305.3 11/20/2006 6.0 IPERF 18,450.0 18,470.0 7,305.3 7,312.3 11/20/2006 6.0 IPERF SLEEVE;17,907.9 > GAUGE;17,993.5 ling +mss - sS) 17 0 „,lf. ".. PACKER;18,077.0 + 1 V ill NIPPLE;18,181.9 111 WLEG;18,192.8 Sr --r IPERF,18.434.0-18,450 0-.4...4 est-- 4... i IP- I PERF;18,4500-18,470.0-2 INTERMEDIATE;344-1/3211-w w • • _ _ _ _ onocoPhillip CD4-321 MWAG Injector Surface Casing Leak Unknown Depth PROPOSED COMPLETION Well Details: API: 50-103-20536-00 ® c) Nipple w/ Injection Valve PTD: 206-142 Wellhead: FMC Alpine 5M Casing/Tubing Details: 16"65#H-40 Conductor to 114' MD 9-5/8"40#L-80 Surface to 3,504' MD 7"26#L-80 Production to 19,323'MD 2nd Stage Cement Top 4-1/2" 12.6#L-80 Tubing to 18,194' MD Calculated at 8,272' MD s Cement Stage Tool 9,512' MD ( 7: Cr NA Circulation GLM II 1St Stage Cement Top Sr PBR and Seal Assembly Calculated at 17,850' MD . � Permanent Packer ,4' /?, vcx- ,-v r-s Pre-Rig Tubing Cut = Non-sealing Tubing Overshot Existing Permanent Packer ISP 77 4 yi-t3L1 __ 11 i-- Existing XN Nipple v Kuparuk C Sand Perfs 18,434'-18,470' - Date: March 10,2017 I Drawn By: Andrew Beat • i Schwartz, Guy L (DOA) From: Beat,Andrew T <Andrew.T.Beat@conocophillips.com> Sent: Tuesday, March 21, 2017 11:54 AM To: Schwartz, Guy L(DOA) Subject: Re: [EXTERNAL]CD4-321 (PTD 206-142) RWO for WMAG service Guy, That's correct. I believe the current packer is even over 200'above the perfs. We plan to set the new packer —100' above the existing packer. Enough room to cut tubing and stack with an overshot and other packer setting tools. Thanks, Andrew From:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Sent:Tuesday, March 21,2017 11:43:29 AM To: Beat,Andrew T Subject: [EXTERNAL]CD4-321(PTD 206-142) RWO for WMAG service Andrew, Since the packer will be moved up hole you will need to request a variance to"packer placement>200 ft above perfs(20 MC 25.412 Also, in the sundry there is no depth given for the new packer... assume it will be approx. 18000ft depending on where the tubing is cut.Can you provide your best guess for this depth? As we discussed the AA will need to be reissued with the understanding that if the gastight tubing leaks with Ml gas then you will be back to water only again. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 Re: THE APPLICATION OF ) Area Injection Order No. 18C.002 CONOCOPHILLIPS ALASKA, ) INC.for Administrative Approval ) Colville River Unit allowing well CD4-321 (PTD ) Colville River Field 2061420)to be online in water only ) Nanuq Oil Pool injection service with outer annulus x ) outer outer annulus pressure ) April 25,2013 communication. ) By letter dated April 13, 2013, ConocoPhillips Alaska, Inc. (CPAI) requested administrative approval to continue water only injection in the subject well. In accordance with Rule 11 of Area Injection Order (AIO) 18C.000, the Alaska Oil and Gas Conservation Commission (AOGCC) hereby GRANTS ConocoPhillips Alaska Inc. (CPAI)'s request for administrative approval to continue water only injection in the subject well. CPAI reported to AOGCC on March 18, 2013 that well CD4-321 showed signs of a surface casing leak to atmosphere via the surface casing by conductor annulus. A surface casing leak detect log (SCLD) was performed on March 17, 2013 indicating a suspected leak at 54 ft. The AOGCC finds that CPAI does not intend to perform repairs at this time. A passing non-witnessed mechanical integrity test of the Inner Annulus (MITIA) on March 17, 2013 indicates that CRU CD4-321 exhibits at least two competent barriers to the release of well pressure. Accordingly, the AOGCC believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's approval to continue water injection only in CRU CD4-321 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report; 3. CPAI shall perform a mechanical integrity test of the inner annulus (MITIA) every 2 years to the maximum anticipated injection pressure; 4. CPAI shall limit the well's IA operating pressure to 2000 psi and the OA operating pressure to as low as reasonably possible not to exceed 100 psi; 5. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and Y S Ill AIO 18C.002 April 25,2013 Page 2 of 2 7. The MIT anniversary date will be set as the date of the AOGCC witnessed MITIA that is to be completed once the well is returned to injection and stabilization is achieved. The Commission must be provided the opportunity to witness the MIT for the test that will establish the new MIT Anniversary date. DONE at Anchorage,Alaska and dated April 25, 2013. / 4,.d. • : �, thy P .- ster Daniel T. eamount,Jr. hair, Commissioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or decision,or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become fmal. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. As provided in AS 31.05.080(b),"[tJhe questions reviewed on appeal are limited to the questions presented to the AOGCC by the application for reconsideration." In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period ruts until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. itAtil f.) It '1/9 17 .- . , STATE OF ALASKA ALISA OIL AND GAS CONSERVATION COMISISION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend E PerforateAlter Casing r Other Stimulate� E Change Approved Program I- Plug for Redrill r Perforate New Pool E Repair Well r Re-enter Susp Well E Other:SC repair F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Developmen r Exploratory r206-1420 • 3.Address: 6.API Number: Stratigraphi r Service F P. O. Box 100360, Anchorage, Alaska 99510 - 50-103-20536-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380077, ADL0387209 CRU CD4-321 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 19337 feet Plugs(measured) None true vertical 7810 feet Junk(measured) None Effective Depth measured 18125 feet Packer(measured) 17908, 18077 true vertical 7196 feet (true vertical) 7125, 7180 Casing Length Size MD ND Burst Collapse CONDUCTOR 77' 16 114' 114' SURFACE 3467' 9 5/8 3504' 2385' INTERMEDIATE 19289' 7 19323' 7800' �'® �� ! ,P L X" Perforation depth: Measured depth: 18434-18470 '," I V►Y True Vertical Depth: 7300-7312 �/ MAR 2 1 2017 Tubing(size,grade,MD,and TVD) 4 1/2 ,L-80, 18193 MD, 7219 TVD CC Packers&SSSV(type,MD,and TVD) Jdsl SLEEVE=BAKER PREMIER SLIDING SLEEVE CMD @ 17908 MD and 7125 TVD PACKER=BAKER PREMIER PACKER @ 18077 MD and 7180 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory E Development r Service F Stratigraphic r Copies of Logs and Surveys j"-- 16.Well Status after work: Oil r Gas E WDSPL r Printed and Electronic Fracture Stimulation j"" GSTOR r WINJ r WAG F GINJ r SUSP r SPLUG E ^17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-010 Contact Roper Winter/Roger Mouser Email: nI927(p�conocophillips.com Printed c N Ro er Winter Title: WI Field Supervisor Signature Phone:659-7506 Date 3/15/17 Form 10-41/4 Revised 5/2015 Q-0AE—_W t*IT vQ- Submit Original Only ,t Mb `rt.. 3/2 5'///- RBDMS U\, MAR 2 '? 2017 • • 111.V ConocoPhillips Alaska !,4, P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 March 15, 2017 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well CRU CD4-321, PTD 206-142, Sundry Number 317-010, surface casing inspection and repair. Please contact me at 659-7506 if you have any questions. Sincerely, 61Roger Winter ConocoPhillips Well Integrity Field Supervisor • CD4-321 S DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/17/17 Cut and remove conductor to expose surface casing. 02/18/17 Clean surface casing and found hole at 58" below OA valve. 03/02/17 Complete welding sleeve over exposed surface casing. 03/04/17 Surface casing leak detect FAILED with N2, bubbling coming from conductor during test. 03/13/17 Normal up conductor and back fill excavation. 4 4,4 a t 64,4' & ' lk..... 4! '' .4 4r nt ..° t *- 1. ".,) ► "; ** ;_ ,t ''); V ,. ti 6.. } z •Ja f s. . - i , s . 4Fc� ,1 g• N � ' f;` • 1. ! • ° 0fir"< t z *`n ? A Li Y' 4.�5t t • 1 'Sat ` / vet£ I Y ... t .-4.,-. F ; 'i • Ili 4 I I "Copyright 2017. Alf rights serve photograph is provided to th AC permission to copy for its°\'''' Esc any other pur s or by any other p,, 44 prohibited irithout the express con ConocoPhillips Alaska, Inc." , v RECEIVED — � 2 • z<g"0%5 MAR 0 7 2017 WELL LOG TRANSMITTAL#903745528 AOGCC To: Alaska Oil and Gas Conservation Comm. February 2, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 DATA LOGGED / 1/201 !d BENDER RE: Leak Detect Log with ACX: CD4-321 Run Date: 12/24/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD4-321 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20536-00 Leak Detect Log with ACX 1 Color Log 50-103-20536-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. l 0 Anchorage, Alaska 99518 SSCANNED APR 0 a LU1t. w Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ��.-1�_ „4- /� � ,/, • • e4•1"��\� Tit THE STATE Alaska Oil and Gas -g' ?���' 7Conservation Commission'- 4 of\T A 'fTt_- • • STATE OF ALASKA JAN /9J1 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon PlugPerforations Fracture Stimulate r Repair Well �' r p F Operations shutdown Suspend fl Perforate r Other Stimulate r Pull Tubing F Change Approved Program F Plug for Redrill F Perforate New Pool F Re-enter Susp Well F Alter Casing F Other:SC repair F+ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory F Developmen F 206-1420 3.Address: 6.API Number: Stratigraphi F Service F, P. O. Box 100360,Anchorage,Alaska 99510 50-103-20536-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes 1 No F/ CRU CD4-321 + 9.Property Designation(Lease Number): � f8173 10.Field/Pool(s): F r ADL0380077,ADL0387209 , Colville River Field/Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 19337 r 7810 * i 18125' # 7196' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77' 16 114' 114' SURFACE 3467' 9 5/8 3504' 2385' INTERMEDIATE 19289' 7 19323' 7800' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 18434-18470 + 7300-7312 4 1/2 L-80 18193 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SLEEVE=BAKER PREMIER SLIDING SLEEVE CMD MD=17908 TVD=7125 PACKER=BAKER PREMIER PACKER ' MD=18077 TVD=7180 12.Attachments: proposal summary F WellBore Schematic F 13. Well Class after proposed work: Detailed Operations Program F BOP Sketch F Exploratory F Stratigraphic F Development F Service F., 14.Estimated Date for 15. Well Status after proposed work: 2/20/2017 Commencing Operations: OIL F WINJ F WDSPL F Suspended F 16.Verbal Approval: Date: GAS F WAG Ft GSTOR F SPLUG F Commission Representative: GINJ F Op Shutdown F Abandoned F 17.I hereby certify that the foregoing is true Contact: Roger Winter/Roger Mouser Printed Name Roper Winter Phone:659-7506 Email: n1927(cr�conocophillips.com c 41-41 Title: WI Field Supervisor Signature Date:1/10/17 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: PlugIntegrity (r BOP Test F Mechanical Integrity TestNS *z-441,1.1.3 g y g y F Location Clearance 1-1, lig Other: / �i hr-to eloevmzvti� w ,�4Ce Ca d r-e p m.1 t' t� q Post Initial Injection MIT Req'd? Yes F No RBDMS 1,vFE3 - 3 2017 Spacing Exception Required? Yes F No j/ Subsequent Form Required: /0 -- 4 (J d APPROVED BY Approved by:raja9f?!...#4.-.._ COMMISSIONER THE COMMISSION Date:2-1-17 Q a 444 ,PG 52';47ORIGIN rate of Form 10-403 Revised 11/2015 A roved a licationv approval. Attachments in Duplicate r ! January 10, 2017 RECEIVED Commissioner Cathy Foerster JAN 1 1 2017 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 AOGCC Anchorage, AK 99501 Dear Commissioner Cathy Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well CD4-321, PTD 206-142 for repairing surface casing leak. I Please contact me at 907-659-7506 if you have any questions. Sincerely, t All Roger Winter ConocoPhillips Well Integrity Field Supervisor Enclosures: Description Summary of Proposal 10-403 Application for Sundry Approvals CD4-321 Wellbore Schematic • • ConocoPhillips Alaska,Inc. Alpine Well CD4-321 (PTD 206-142) SUNDRY NOTICE 10-403 APPROVAL REQUEST January, 2017 This application for Sundry approval for Alpine well CD4-321 is for the inspection and repair of surface casing with a suspected surface casing leak. Subsequent diagnostics indicate that the leak is relatively shallow. ConocoPhillips requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will require the following general steps: 1. Secure the well as needed with mechanical plug in tubing 2. Remove the floor grate,well house, flow lines, and other equipment as necessary from around the wellhead. 3. Remove gravel around well head and excavate to—20'. 4. Install nitrogen purge equipment for the conductor and OA(if needed)so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary.Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check. 8. Perform a low-pressure test(Open OA shoe)to confirm no fluid to surface. 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. 10. Replace the conductor and fill the void with cement and top off with sealant. 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s) and return the well to injection. 13. File 10-404 with the AOGCC post repair. WNS INJ • CD4-321 A CanacoPhiIIips ( iptgio,"7.1s, Well Attributes Max Angle&MD TD Wellbore APIIUWI Field Name Wellbore Status Inc!(°) MD(ftKB) Act m(ftKB) f cd'hlhps 41861 a,Inc. 501032053600 NANUQ KUPARUK INJ Bt 72.56 3,218.04 19,337.0 .•- .. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date CD4-321,4119201612:26:00 PM SSSV:WRDP Last WO: 43.58 10/26/2006 Vertical schemata:(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:SET Al INJ VALVE pproven 4/19/2016 Casing Strings HANGER 31 5 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread 'J CONDUCTOR 16 15.250 37.0 114.0 114.0 65.00 H-40 WELDED 4Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 36.6 3,504.0 2,3852 40.00 L-80 BUTT Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I. Grade Top Thread INTERMEDIATE 7 6.276 34.4 19,323.1 7,800.2 26 00 L-80 BTCM ii i It l TubingStrings T Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Iblft) Grade Top Connection ir. ETUBING 1 4 1/21 3.9581 31.51 18,194.21 7,219.51 12.601 L-80 1 IBTM Gas Injection I Completion Details r Nominal lD Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in CONDUCTOR Insulated 34•; 31.5 31.5 0.06 HANGER FMC TUBING HANGER 4.500 37.0-114.0 2,290.2 1,958.7 58.57 NIPPLE CAMCO DB NIPPLE 3.812 17,907.9 7,124.5 70.90 SLEEVE BAKER PREMIER SLIDING SLEEVE CMD 3.810 N .g f 17,993.5 7,152.7 70.61 GAUGE WEATHERFORD POD2 GAUGE CARRIER 3.958 VIPLE;ALPVE;2,2 90 90 i.0 7[ 18,077.0 7,180.4 70.66 PACKER BAKER PREMIER PACKER 3.875 2,2 .2 18,181.9 7,215.4 70.35 NIPPLE HES NX NO GO NIPPLE 3.725 s§ 18,192.8 7,219.1 70.32 WLEG BAKER WIRELINE FLUTED GUIDE 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(AKB) (ftKB) (°) Des Com Run Date ID(in) 2,290.0 1,958.6 58.56 VALVE A-1 INJ VLV(S/N:HLS-766/1.25"ORIFICE)ON DB- 4/17/2016 1.250 LOCK I Perforations&Slots Shot SURFACE;36 6.3,504.0 � a• Dens TopftKB Btm ftKB Top(.TVD) Btm(TVD) (sht) (ftKB) l ) (ftKB) (ftKB) Zone Date t) Type Corn 18,434.0 18,450.0 7,299.8 7,305.3 11/20/2006 6.0 (PERF 18,450.0 18,470.0 7,305.3 7,312.3 11/20/2006 6.0 (PERF SLEEVE;17,907.9 1. 5 f GAUGE;17,993.5 ( �) Vic: k r r PACKER;18,077.0 r E 4 NIPPLE;18,181.9 j I WLEG.18,192.8 '. (PERF;18,434.0-18,450.0-----.... ..,.. (PERF;18,450.0-18,470.0 INTERMEDIATE;34.4-19,323.1--e „, • • Loepp, Victoria T (DOA) From: Sylte, Hanna <Hanna.Sylte@conocophillips.com> Sent: Wednesday,January 25,2017 11:01 AM To: Loepp,Victoria T(DOA) Subject: Fwd:Alpine injector CD4-321 (PTD#206-142,NO 18C.002)failed MITIA Attachments: CD4-321 schematic.pdf;CD4-321 90-day110 plot.docx Follow Up Flag: Follow up Flag Status: Flagged Victoria, Below is the notification made to the AOGCC to report the failed MIT-IA on CD4-321. Please let me know if I can help with anything else. Thank you, Hanna SCANNED M, 2!1 Get Outlook for iOS From: NSK Well Integrity Supv CPF3 and WNS<n2549@conocophillips.com> Sent:Wednesday,January 25, 2017 10:43 AM Subject: FW:Alpine injector CD4-321(PTD#206-142,AI0 18C.002)failed MITIA To:Sylte, Hanna<hanna.sylte@conocophillips.com> Hanna, Here is the email I sent to Chris Wallace last week to report the failed MIT on CD4-321. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 From: NSK Problem Well Supv Sent:Wednesday,January 18,2017 7:53 PM To:Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject:Alpine injector CD4-321(PTD#206-142,A10 18C.002)failed MITIA Chris, Alpine injector CD4-321(PTD#206-142,AIO 18C.002)failed an MITIA today during routine diagnostics prior to wellwork. The well will be SI and secured by slickline as soon as possible. Following the secure,we will do diagnostics to 1 assess the well's condition. Based on the results of the diagnostics,we will deve p and update you with a plan forward. Please let me know if you have any questions or disagree with this plan. Attached is a 90-day TIO plot and a schematic. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 2 E WNS INJ • CD4-321 ConocoPhillips h� Well Attributes Max Angle&MD TD We(More APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Cannrunela(n 501032053600 NANUQ KUPARUK INJ 72.56 3,218.04 19,337.0 .-- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Rebase bate CD4-321,4/19/20161226:00 PM SSSV:WRDP Last WO: 43.58 10/26/2006 Verfical scFremahc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:SET Al(NJ VALVE pproven 4/19/2016 Casing Strings HANGER;31.5---• Casing Dexription OD(in) ID On) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread WI CONDUCTOR 16 15.250 37.0 114.D 114.0 65.00 H-40 WELDED Insulated 34" Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WBLen(I...Grade Top Thread LII SURFACE95/8 8.835 36.6 3,504.0 2,385.2 40.00 L$0 BUTT Casing DescriptionOD(in) ID(in) Top mica) Set Depth(MB) Set Depth(TVD).. WI/Len(I...Grade 'Top Thread INTERMEDIATE 7 6.276 344 19,323.1 7,800.2 26.00 L-80 BTCM II' Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection li TUBING 41/2 3.958 31.5 18,194.2 7,219.5 12.60 L-80 IBTM Gas Infection 1e _r�� Completion Details Nominal ID Top(ftKB) Top(1VD)(11KB) Top Incl(°) Item Des Corn (in) CONDUCTOR Insulated 34.; , 31.5 31.5 0.06 HANGER FMC TUBING HANGER 4.500 37.0-114.0 2,290.2 1,958.7 58.57 NIPPLE CAMCO DB NIPPLE 3.812 oori' 17,907.9 7,124.5 70.90 SLEEVE BAKER PREMIER SLIDING SLEEVE CMD 3.810 I VAI 17,993.5 7,152.7 70.61 GAUGE WEATHERFORD POD2 GAUGE CARRIER 3.958 VALVE;2,290.0 18,077.0 7,180.4 70.66 PACKER BAKER PREMIER PACKER 3.875' NIPPLE;2,293.2 IN a;. 18,181.9 7,215.4 70.35 NIPPLE HES NX NO GO NIPPLE 3.725 18,192.8 7,219.1 70.32 WLEG BAKER WIRELINE FLUTED GUIDE 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) CI Des Corn Run Date ID(in) I 2,290.0 1,958.6 58.56 VALVE A-1 INJ VLV(S/N:HLS-766/(.25"ORIFICE)ON DB- 4/17/20(6 1.250 LOCK 1 Perforations&Slots I Shot SURFACE;38.6-1504.0 \ Dens Top(TVD) Btm(TVD) (shoN/f Top(ftKB) Btm(ftKB) (ftKB) (ORB) Zone Date t) Type Com 18,434.0 18,450.0 7,299.8 7,305"3 11/20/2006 6.0 IPERF 18,450.0 18,470.0 7,305"3 7,312.3 11/20/2006 6.0 IPERF SLEEVE:17.907.9 { GAUGE;17993.5 PACKER;18,077 r If.0 ® r NIPPLE;18,181.9 WLEG;18,192.8 (PERF;18,434.0-18,4500- I a► ItmaI (PERF;18,450.0-18,470.0- I I INTERMEDIATE;34.4-19,323.1-- • I m p co s (]SI Q-c m rn Per, cm a - 0 Y, t. Y. Y. t Y. % wa P. `, A e.°1 m m 2p . N % H H H % H H % _ _ _ _ A ry 3 Vt 1 1 1 1 1 to .. ., n n ., .. ., I 11 N O Y• .1 v r^ D C 44 ... 0 Z1 z O 0q. fD C p I 1 _3 n O 3 In LI 1 t7 G 9 • 4 • 7 ,- :( 0 N E 7--.4 m i. 1 I I 1 I 1 1 1 1 1 degF... 6 U 6 0 V V V 0 U O !!!!!!P B @hhh ; a T T T a V co -4 S jay to A ....au, m CO z a d x A N WW m G O O-NOD. N r 1C T 11 {{,�}} ppA m O O+N O N N 1111111 t'' Iti VA n m a • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, January 18, 2017 7:53 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Alpine injector CD4-321 (PTD# 206-142, AIO 18C.002) failed MITIA Attachments: CD4-321 schematic.pdf; CD4-321 90-day TIO plot.docx Chris, Alpine injector CD4-321 (PTD#206-142, AIO 18C.002)failed an MITIA today during routine diagnostics prior to wellwork. The well will be SI and secured by slickline as soon as possible. Following the secure, we will do diagnostics to assess the well's condition. Based on the results of the diagnostics, we will develop and update you with a plan forward. Please let me know if you have any questions or disagree with this plan. Attached is a 90-day TIO plot and a schematic. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED MAR 0 2017 1 0 W U s N U1N(1NN 2 , wrc R'C11Ru' w W F- 1-1- h- U --0 0 0 0 0 0 0((V N00 ul .i CC I 1 O. U. O Onn�N 00 0 W N_ 9 m2 GI W 0 0 0 0 0 L ul or ,— ID , W ID(D CD CD — a 0 fV 0'�)oS r5 r+s t+S C'f W .i UV� 8f1 ISS r I:'44 g - 1 1 I 1 1 1 1 I rr 4 ar , d V d 'o L oz $ H .... C O ro v o 'c E z V 48. C 1 es .A o S Q • I L. ? I'' I - - r.r rrN 1 I 1 1I 1 r; to ao 0 ii. v �r u:J �'y _ H }{ H H H Y. II H H ur — , o — _ ,- ,..-0. H Yr I' ii LI :1 Ii 4: h O �n In�.,n z N C !S I s r%1 O W e-).-DG-t, -;,2_. Et • v\-1 Q. G? IIII NOV 22 2013 Memory Multi-Finger Caliper 1111. ii, AOGCC Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: CD4-321 Log Date: November 5, 2016 Field: Alpine Log No.: 12416 State: Alaska Run No.: 1 API No. 50-103-20536-00 Pipe Description: 4.5 inch 12.6 lb. L-80 IBTM Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 18,109 Ft.(MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : This caliper data is tied into the Sliding Sleeve at 17,908 feet(Driller's Depth). This log was run to assess the condition of tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 4.5 inch tubing logged appears to be in good condition, with an exception of 20%wall penetrations in joint 446 (17,758 ft),joint 442 (17,614 ft), and joint 409 (16,315 ft). Recorded damage appears as isolated pitting and a line of pits. No other significant wall penetrations, areas of cross- sectional wall loss or I.D. restrictions are recorded throughout the tubing logged. MAXIMUM RECORDED WALL PENETRATIONS : Jescripilon Perten,n,OJAI P=.r etf aucx J)iEit L,pitt Line of Pits 20 447 17,758 Ft. (MD) Isolated Pitting 20 443 17,614 Ft. (MD) Isolated Pitting 20 410 16,315 Ft. (MD) No other significant areas of wall penetrations(> 18%)are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (>4%)are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the tubing logged. scANNED APR 2 4 2 :7, D. Sparks C. Waldrop B. Boehme Ali'd -:f 1(jltic:e3'{s .A.iX'y S1;S) ln.IEti7 i355;f',S ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford,TX 77497 Phone: (281)431-7100 or(888) 565-9085 Fax: (281)431-7125 E-mail: PDSAnalysis(@memorvlog.com Prudhoe Bay Field Office Phone: (907)659-2307 Fax: (907) 659-2314 • • Correlation of Recorded Damage to Borehole Profile • Pipe 1 4.5 in (-2.5'- 18,108.9') Well: CD4-321 Field: Alpine Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: November 5, 2016 ■ Approx.Tool Deviation ■ Approx.Borehole Profile 1 1 50 1,941 100 3,926 150 — 5,901 200 7,904 5 250 9,889 C o I 300 11,874 350 13,862 400 15,861 450 17,858 455 18,094 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=455 • • PDS Report Overview tit Body Region Analysis Well: CD4-321 Survey Date: November 5,2016 Field: Alpine Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 4.5 in. 12.6 ppf L-80 IBTM Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBTM 3.958 in. -2 ft. 18,109 ft. Penetration(°/0 wall) Damage Profile(%wall) 500 Penetration body An Metal loss body 0 50 100 0.1 400 300 50 200 100 100 0 150 - 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analyzed(total=462) 459 3 0 0 200 Damage Configuration(body) 250 10 8 300 6 4 350 2 400 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole 450 Number of joints damaged(total= 10) 9 0 1 0 0 Bottom of Survey=455 0 0 PI 4J4 wit PDS Report Joint Tabulation Sheet Well: CD4-321 Survey Date: November 5, 2016 Field: Alpine Analyst: C.Waldrop Company: ConocoP hillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 I BTM Tubing 3.958 in. 0.271 in. -2 ft. 18,109 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 0.1 -2 0 0.03 11 3 3.92 Pup 1 1 0 0.05 19 2 3.90 Shallow Pitting. ill 2 43 0 0.03 12 2 3.92 3 81 0 0.02 9 3 3.92 4 122 0 0.03 10 2 3.89 Lt.Deposits. C 5 163 0 0.03 10 2 3.93 C 6 203 0 0.02 7 2 3.93 7 243 0 0.02 8 2 3.94 • 8 283 0 0.04 15 3 3.93 Shallow Pitting. • 9 323 0 0.03 10 3 3.89 Lt.Deposits. • 10 361 0 0.04 14 2 3.93 • 11 399 0 0.03 12 2 3.93 ■ 12 439 0 0.03 13 2 3.92 r• 13 478 0 0.03 12 2 3.94 • 14 519 0 0.04 14 2 3.94 • 15 558 0 0.03 9 2 3.93 II 16 598 0 0.02 7 2 3.89 Lt.Deposits. C 17 638 0 0.02 8 1 3.93 18 678 0 0.02 7 2 3.87 Lt.Deposits. i 19 717 0 0.02 8 2 3,92 • 20 758 0 0.03 11 3 3.94 11 21 797 0 0.02 6 1 3.94 22 837 0 0.02 6 2 3.85 Lt.Deposits. 1 23 878 0 0.02 6 3 3.84 Lt.Deposits. 24 916 0 0.02 6 3 3.88 Lt.Deposits. 25 955 0 0.02 7 3 3.87 Lt.Deposits. 26 993 0 0.02 7 3 3.93 27 1033 0 0.01 5 1 3.94 28 1073 0 0.02 6 1 3.94 i 29 1113 0 0.01 5 2 3.93 i 30 1153 0 0.02 7 2 3.86 Lt.Deposits. II 31 1192 0 0.02 6 1 3.93 32 1232 0 0.02 7 2 3.93 • 33 1272 0 0.02 9 2 3.93 • 34 1310 0 0.03 12 2 3.94 • 35 1350 0 0.02 8 1 3.94 • 36 1389 0 0,02 7 2 3.92 C 37 1429 0 0.01 5 1 3.90 38 1468 0 0.02 6 1 3.93 1 39 1507 0 0.02 8 1 3.94 • 40 1546 0 0.02 7 2 3.93 i 41 1586 0 0.02 9 2 3.92 C 42 1625 0 0.02 7 1 3.94 43 1665 0 0.02 7 2 3.93 •• 44 1705 0 0.02 6 1 3.93 1 45 1745 0 0.02 8 1 3.92 46 1784 0 0.02 6 2 3.88 Lt.Deposits. i 47 1824 0 0.02 8 2 3.94 • 48 1864 0 0.02 7 1 3.93 i 49 1903 0 0.02 8 2 3.93 • IPenetration Body Metal Loss Body Page 1 • • illi tie PDS Report Joint Tabulation Sheet Well: CD4-321 Survey Date: November 5, 2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBTM Tubing 3.958 in. 0.271 in. -2 ft. 18,109 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 50 1941 0 0.02 6 2 3.87 Lt.Deposits. • 51 1980 0 0.02 7 1 3.93 1 52 2020 0 0.02 6 3 3.94 53 2060 0 0.02 6 2 3.88 Lt.Deposits. 54 2101 0 0.02 7 2 3.93 55 2141 0 0.03 10 2 3.89 Lt.Deposits. r 56 2180 0 0.02 8 2 3.87 Lt.Deposits. F 57 2220 0 0.03 10 2 3.88 Lt.Deposits. 57.1 2259 0 0 0 0 3.77 4.5"CAMCO DB NIPPLE 58 2261 0 0.02 7 2 3.94 • 59 2301 0 0.02 8 3 3.93 60 2341 0 0.03 10 2 3.93 61 2380 0 0.02 6 1 3.94 r 62 2417 0 0.02 6 1 3.86 Lt.Deposits. 63 2457 0 0.03 10 3 3.94 64 2497 0 0.01 5 1 3.88 Lt.Deposits. 65 2536 0 0.02 7 3 3.94 C 66 2576 0 0.02 6 2 3.89 Lt.Deposits. 67 2616 0 0.02 6 1 3.93 68 2654 0 0.02 8 2 3.89 Lt.Deposits. 69 2694 0 0.02 6 2 3.88 Lt.Deposits. 70 2733 0 0.02 9 2 3.94 71 2773 0 0.01 5 1 3.94 r 72 2813 0 0.02 6 2 3.93 C 73 2853 0 0.02 7 2 3.94 74 2892 0 0.02 7 2 3.93 75 2932 0 0.03 10 2 3.93 76 2972 0 0.02 6 2 3.92 77 3012 0 0.02 8 2 3.92 78 3050 0 0.02 6 3 3.87 Lt.Deposits. 79 3090 0 0.02 6 1 3.90 80 3128 0 0.02 6 2 3.90 • 81 3168 0 0.02 6 1 3.93 82 3209 0 0.02 7 2 3.94 • 83 3249 0 0.02 6 2 3.93 84 3289 0 0.02 7 2 3.92 • 85 3329 0 0.03 10 3 3.94 86 3369 0 0.02 8 2 3.93 C 87 3409 0 0.03 10 2 3.94 88 3450 0 0.02 6 2 3.94 • 89 3490 0 0.02 6 3 3.92 C 90 3530 0 0.02 8 2 3.93 91 3570 0 0.03 11 2 3.93 • 92 3610 0 0.02 6 2 3.88 Lt.Deposits. i 93 3650 0 0.02 7 2 3.92 94 3690 0 0.02 7 3 3.93 95 3730 0 0.02 8 2 3.92 96 3770 0 0.02 8 2 3.88 Lt.Deposits. • 97 3808 0 0.02 6 2 3.92 C 98 3847 0 0.02 6 2 3.90 IPenetration Body Metal Loss Body Page 2 • • PDS Report Joint Tabulation Sheet Well: CD4-321 Survey Date: November 5, 2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBTM Tubing 3.958 in. 0.271 in. -2 ft. 18,109 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 99 3886 0 0.02 6 2 3.94 100 3926 0 0.02 6 2 3.93 101 3965 0 0.02 6 3 3.87 Lt.Deposits. 102 4002 0 0.01 5 1 3.93 103 4043 0 0.02 7 1 3.92 104 4080 0 0.02 6 2 3.93 105 4120 0 0.02 6 2 3.93 106 4161 0 0.02 6 2 3.88 Lt.Deposits. 107 4199 0 0.02 6 2 3.93 108 4239 0 0,02 9 3 3.92 109 4278 0 0.02 6 2 3.93 110 4317 0 0.02 6 1 3.94 111 4357 0 0.02 6 3 3.88 . Lt.Deposits. 112 4397 0 0.01 5 1 3.89 Lt.Deposits. 113 4435 0 0.02 7 1 3.93 114 4474 0 0.02 6 3 3.94 115 4513 0 0.02 6 2 3.93 116 4553 0 0.02 6 2 3.94 117 4594 0 0.02 6 1 3.94 118 4634 0 0.03 11 2 3.93 119 4674 0 0.01 4 1 3.93 120 4714 0 0.02 7 2 3.89 Lt.Deposits. 121 4754 0 0.02 7 2 3.89 Lt.Deposits. 122 4794 0 0.02 6 2 3.92 123 4833 0 0.02 6 1 3.94 124 4873 0 0.02 7 3 3.89 Lt.Deposits. 125 4912 0 0.02 6 2 3.86 Lt.Deposits. 126 4951 0 0.02 7 2 3.90 127 4990 0 0.02 7 2 3.93 • 128 5030 0 0.01 5 3 3.89 Lt.Deposits. 129 5068 0 0.02 6 2 3.92 130 5108 0 0.01 4 1 3.92 131 5149 0 0.02 6 1 3.86 Lt.Deposits. 132 5189 0 0.02 6 3 3.93 133 5229 0 0.02 9 2 3.94 134 5269 0 0.03 11 1 3.89 Lt.Deposits. 135 5309 0 0.02 6 2 3.93 136 5349 0 0.01 5 1 3.88 Lt.Deposits. 137 5389 0 0.02 6 2 3.94 138 5428 0 0.01 5 2 3.89 Lt.Deposits. 139 5465 0 0.02 6 2 3.89 Lt.Deposits. 140 5506 0 0.02 6 1 3.92 141 5545 0 0.02 6 2 3.92 142 5585 0 0.02 7 2 3.85 Lt.Deposits. 143 5624 0 0.01 5 2 3.94 144 5664 0 0.03 12 2 3.93 145 5704 0 0.02 6 2 3.94 146 5 744 0 0.04 13 1 3.93 147 5782 0 0.02 7 2 3.85 Lt.Deposits. 148 5822 0 0.01 4 2 3.92 IPenetration Body Metal Loss Body Page 3 • • ll-r..4SPDS Report Joint Tabulation Sheet a Well: CD4-321 Survey Date: November 5, 2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBTM Tubing 3.958 in. 0.271 in. -2 ft. 18,109 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 149 5862 0 0.02 7 3 3.89 Lt.Deposits. C 150 5901 0 0.02 6 1 3.92 151 5941 0 0.03 11 2 3.94 152 5981 0 0.02 7 2 3.93 • 111153 6021 0 0.03 10 2 3.93 154 6061 0 0.02 6 2 3.89 Lt.Deposits. 111155 6099 0 0.03 11 1 3.93 156 6140 0 0.03 10 2 3.93 •C 157 6180 0 0.02 7 4 3.89 Lt.Deposits. 158 6221 0 0.02 6 1 3.94 ••159 6262 0 0.03 12 3 3.92 • 160 6302 0 0.02 7 1 3.92 • 161 6342 0 0.03 11 3 3.93 162 6382 0 0.02 6 2 3.88 Lt.Deposits. 1 163 6422 0 0.02 7 2 3.93 • 164 6463 0 0.01 5 1 3.94 1 165 6503 0 0.02 7 2 3.85 Lt.Deposits. • 166 6541 0 0.02 6 2 3.92 1 167 6581 0 0.02 6 2 3.93 1 168 6621 0 0.02 7 1 3.92 • 169 6660 0 0.02 6 1 3.92 1 170 6701 0 0.02 8 2 3.94 • 171 6741 0 0.02 6 3 3.87 Lt.Deposits. • 172 6779 0 0.03 11 3 3.93 173 6818 0 0.01 5 1 3.89 Lt.Deposits. 174 6858 0 0.02 6 1 3.93 II 175 6899 0 0.01 4 1 3.93 176 6954 0 0.02 6 2 3.93 1 177 6994 0 0.02 6 1 3.92 i 178 7034 0 0.02 7 1 3.88 Lt.Deposits. U 179 7074 0 0.01 5 1 3.91 1 180 7114 0 0.02 6 1 3.93 • 181 7153 0 0.03 11 3 3.93 • 182 7193 0 0.04 14 2 3.94 r 183 7233 0 0.02 6 1 3.94 184 7273 0 0.02 8 3 3.94 • 185 7313 0 0.02 6 1 3.94 r 186 7353 0 0.02 6 2 3.88 Lt.Deposits. 1 187 7393 0 0.02 7 2 3.93 188 7431 0 0.03 11 2 3.91 • 189 7471 0 0.02 6 1 3.93 1 190 7512 0 0.02 8 2 3.94 • 191 7551 0 0.02 6 1 3.86 Lt.Deposits. • 192 7590 0 0.02 6 1 3.92 i 193 7630 0 0.02 7 2 3.92 • 194 7668 0 0.02 7 2 3.92 U 195 7707 0 0.03 11 3 3.94 • 196 7747 0 0.02 7 2 3.94 1 197 7788 0 0.02 7 3 3.94 II 198 7826 0 0.01 4 1 3.94 i IPenetration Body Metal Loss Body Page 4 0 • (itP_____ PDS Report Joint Tabulation Sheet k Well: CD4-321 Survey Date: November 5, 2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 I BTM Tubing 3.958 in. 0.271 in. -2 ft. 18,109 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 199 7865 0 0.02 6 1 3.93 i 200 7904 0 0.01 5 2 3.94 201 7945 0 0.02 6 3 3.88 Lt.Deposits. C 202 7983 0 0.02 7 1 3.94 203 8022 0 0.02 6 2 3.90 1 204 8062 0 0.04 13 4 3.94 r 205 8100 0 0.01 5 1 3.93 206 8139 0 0.03 11 3 3.93 207 8179 0 0.02 9 3 3.94 208 8219 0 0.02 8 2 3.92 209 8258 0 0.02 7 1 3.92 210 8298 0 0.02 7 2 3.93 i 211 8337 0 0.02 6 1 3.93 1 212 8377 0 0.01 4 1 3.92 213 8418 0 0.02 9 3 3.93 214 8458 0 0.03 10 2 3.92 215 8496 0 0.01 5 1 3.88 Lt.Deposits. 216 8535 0 0.02 6 2 3.90L 217 8574 0 0.03 12 2 3.94 218 8614 0 0.03 12 3 3.93 C 219 8654 0 0.02 7 2 3.89 Lt.Deposits. 220 8694 0 0.03 11 2 3.92 • 221 8735 0 0.03 10 4 3.88 Lt.Deposits. 222 8773 0 0.02 6 1 3.94 223 8812 0 0.02 6 2 3.94 224 8851 0 0.03 10 2 3.93 225 8891 0 0.03 11 2 3.94 226 8932 0 0.04 14 3 3.87 Lt.Deposits. 227 8971 0 0.02 7 3 3.94 228 9011 0 0.02 8 3 3.92 229 9051 0 0.02 6 1 3.85 Lt.Deposits. 230 9091 0 0.02 6 1 3.92 231 9131 0 0.02 8 2 3.91 II 232 9171 0 0.02 7 1 3.92 1 233 9211 0 0.03 10 2 3.92 • 234 9252 0 0.02 6 1 3.93 1 235 9292 0 0.02 7 2 3.90 236 9333 0 0.02 6 2 3.93 237 9373 0 0.02 6 3 3.93 ` 238 9412 0 0.02 6 1 3.91 239 9451 0 0.03 11 2 3.94 240 9491 0 0.02 6 1 3.89 Lt.Deposits. 241 9531 0 0.02 7 3 3.94 242 9571 0 0.02 6 1 3.93 243 9611 0 0.02 7 2 3.87 Lt.Deposits. 244 9650 0 0.02 7 2 3.92 245 9690 0 0,02 7 3 3.86 Lt.Deposits. 246 9730 0 0.02 6 1 3.93 247 9770 0 0.02 6 1 3.94 i 248 9811 0 0.02 7 1 3.94 U IPenetration Body Metal Loss Body Page 5 • 111111 PDS Report Joint Tabulation Sheet Well: CD4-321 Survey Date: November 5, 2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBTM Tubing 3.958 in. 0.271 in. -2 ft. 18,109 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100. 249 9851 0 0.01 5 2 3.88 Lt.Deposits. 250 9889 0 0.02 7 2 3.94 251 9929 0 0.01 5 2 3.90 Lt.Deposits. 252 9969 0 0.02 7 1 3.92 253 10009 0 0.02 6 1 3.94 1 254 10049 0 0.02 6 2 3.86 Lt.Deposits. 255 10089 0 0.02 7 1 3.93 256 10129 0 0.01 5 2 3.92 257 10169 0 0.02 6 2 3.93 258 10209 0 0.03 12 3 3.90 Lt.Deposits. 259 10248 0 0.02 6 1 3.90 260 10288 0 0.01 5 1 3.93 261 10328 0 0.02 7 2 3.89 Lt.Deposits. 262 10366 0 0.02 6 3 3.93 263 10405 0 0.02 6 2 3.91 264 10445 0 0.02 8 2 3.92 265 10485 0 0.02 6 1 3.92 266 1052 5 0 0.03 10 2 3.92 • 267 10565 0 0.03 13 2 3.93 • 268 10606 0 0.02 7 2 3.91 269 10645 0 0.02 6 2 3.92 270 10685 0 0.01 5 1 3.92 271 10725 0 0.02 6 1 3.93 272 10766 0 0.02 7 3 3.92 273 10805 0 0.02 6 2 3.92 274 10846 0 0.02 6 2 3.94 275 10885 0 0.02 6 2 3.92 276 10924 0 0.02 9 3 3.94 277 10964 0 0.02 6 2 3.89 Lt.Deposits. 278 11003 0 0.02 6 2 3.93 279 11042 0 0.01 5 1 3.92 1 280 11082 0 0.03 11 2 3.92 • 281 11122 0 0.02 7 2 3.94 282 11162 0 0.02 6 3 3.88 Lt.Deposits. 283 11200 0 0.02 6 1 3.89 Lt.Deposits. 284 11241 0 0.04 14 3 3.88 Lt.Deposits. 285 11281 0 0.02 6 1 3.92 286 11319 0 0.02 6 2 3.93 287 11359 0 0.02 7 2 3.89 Lt.Deposits. 288 11399 0 0.02 6 2 3.86 Lt.Deposits. 289 11438 0 0.02 6 2 3.94 1 290 11478 0 0.02 8 1 3.89 Lt.Deposits. _ • 291 11518 0 0.02 6 2 3.88 Lt.Deposits. 292 1155 7 0 0.02 7 2 3.92 293 11597 0 0.02 7 2 3.93 294 1163 7 0 0.02 8 2 3.92 295 11677 0 0.02 6 2 3.93 296 11716 0 0.02 6 2 3.87 Lt.Deposits. 297 11753 0 0.03 9 2 3.89 Lt.Deposits. 298 11793 0 0.01 5 2 3.93 IPenetration Body Metal Loss Body Page 6 • • PDS Report Joint Tabulation Sheet Well: CD4-321 Survey Date: November 5, 2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBTM Tubing 3.958 in. 0.271 in. -2 ft. 18,109 ft. Joint it.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 299 11833 0 0.02 6 2 3.94 300 11874 0 0.02 7 1 3.93 301 11913 0 0.02 8 1 3.92 U 302 11953 0 0.02 6 1 3.93 303 11993 0 0.02 7 2 3.92 V 304 12033 0 0.02 7 2 3.92 305 12073 0 0.02 8 2 3.87 Lt.Deposits. 306 12111 0 0.02 6 1 3.93 307 12149 0 0.02 7 1 3.95 308 12189 0 0.02 8 1 3.92 309 12229 0 0.02 6 2 3.94 310 12269 0 0.02 6 2 3.90 311 12307 0 0.02 6 2 3.89 Lt.Deposits. 312 12348 0 0.01 5 2 3.94 1 313 12387 0 0.02 8 2 3.88 Lt.Deposits. • 314 12428 0 0.02 6 1 3.87 Lt.Deposits. I 315 12468 0 0.02 6 1 3.94 I 316 12508 0 0.02 7 2 3.94 • 317 12548 0 0.02 7 2 3.94 318 12588 0 0.02 9 1 3.93 • 319 12628 0 0.02 8 2 3.93 • 320 12668 0 0.03 11 2 3.94 321 12708 0 0.01 5 2 3.95 322 12748 0 0.01 4 1 3.89 Lt.Deposits. 323 12788 0 0.03 10 2 3.94 • 324 12828 0 0.02 6 2 3.94 I 325 12868 0 0.01 5 1 3.87 Lt.Deposits. 326 12907 0 0.01 5 1 3.92 327 12945 0 0.02 6 1 3.93 328 12985 0 0.03 12 3 3.92 M 329 13025 0 0.02 8 3 3.92 r 330 13065 0 0.02 7 2 3.93 331 13105 0 0.02 7 2 3.92 1 332 13145 0 0.02 7 2 3.92 333 13186 0 0.02 6 2 3.94 334 13226 0 0.02 8 3 3.87 Lt.Deposits. 335 13263 0 0.02 7 2 3.93 336 13303 0 0.02 6 2 3.94 337 13343 0 0.02 6 1 3.88 Lt.Deposits. 338 13384 0 0.03 11 3 3.92 339 13424 0 0.02 6 2 3.92 340 13465 0 0.02 6 2 3.93 341 13505 0 0.03 10 4 3.88 Lt.Deposits. 342 13544 0 0.01 4 1 3.91 343 13584 0 0.03 10 1 3.94 • 344 13624 0 0.03 10 2 3.95 • 345 13664 0 0.02 6 3 3.90 346 13703 0 0.02 6 2 3.85 Lt.Deposits. 347 13744 0 0.02 7 1 3.94 U 348 13783 0 0.02 6 2 3.87 Lt.Deposits. IPenetration Body Metal Loss Body Page 7 • • VO PDS Report Joint Tabulation Sheet Well: CD4-321 Survey Date: November 5, 2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBTM Tubing 3.958 in. 0.271 in. -2 ft. 18,109 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 349 13822 0 0.01 4 2 3.90 350 13862 0 0.02 7 3 3.88 Lt.Deposits. 351 13903 0 0.02 8 2 3.93 352 13943 0 0.02 7 3 3.93 353 13983 0 0.02 7 3 3.93 354 14023 0 0.02 6 2 3.93 355 14063 0 0.02 6 3 3.93 356 14103 0 0.02 9 2 3.88 Lt.Deposits. 357 14144 0 0.03 12 2 3.93 358 14183 0 0,02 7 2 3.94 359 14223 0 0.02 7 2 3.92 360 14264 0 0.02 8 2 3.83 Lt.Deposits. 361 14303 0 0.02 8 1 3.93 362 14341 0 0.03 10 1 3.91 363 14381 0 0.02 7 3 3.93 364 14421 0 0.02 8 1 3.93 365 14462 0 0.02 8 2 3.92 • 366 14502 0 0.02 7 1 3.87 Lt.Deposits. U 367 14541 0 0.02 7 1 3.93 368 14581 0 0.01 4 2 3.93 I 369 14621 0 0.02 7 2 3.93 M 370 14662 0 0.01 5 2 3.93 M 371 14701 0 0.02 7 1 3.93 1 372 14741 0 0.02 6 2 3.92 373 14781 0 0.01 5 1 3.92 374 14821 0 0.02 7 1 3.92 • 375 14862 0 0.02 6 2 3.89 Lt.Deposits. 376 14902 0 0.02 7 2 3.92 377 14942 0 0.02 8 1 3.89 Lt.Deposits. • 378 14982 0 0.02 9 1 3.93 379 15023 0 0.01 5 1 3.93 380 15062 0 0.02 6 2 3.91 381 15103 0 0.02 6 2 3.92 - 382 15143 0 0.04 16 2 3.92 Shallow Pitting. 383 15182 0 0.02 6 1 3.93 1 384 15221 0 0.02 8 2 3.93 • 385 15261 0 0.02 8 2 3.87 Lt.Deposits. • 386 15301 0 0.02 7 2 3.92 387 15341 0 0.02 6 1 3.90 388 15382 0 0.02 6 2 3.92 C 389 15422 0 0.03 10 2 3.91 390 15462 0 0.02 6 1 3.93 391 15501 0 0.01 5 1 3.88 Lt.Deposits. • 392 15541 0 0.02 6 2 3.89 Lt.Deposits. 393 15580 0 0.02 6 2 3.92 394 15620 0 0.02 7 2 3.93 395 15660 0 0.02 7 2 3.89 Lt.Deposits. 396 15700 0 0.02 7 1 3.91 • 397 15741 0 0.02 6 1 3.92 398 15781 0 0.02 6 2 3.89 Lt.Deposits. IPenetration Body Metal Loss Body Page 8 • - • 111.-4 PDS Report joint Tabulation Sheet Well: CD4-321 Survey Date: November 5, 2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 IBTM Tubing 3.958 in. 0.271 in. -2 ft. 18,109 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 399 15821 0 0.02 6 1 3.92 400 15861 0 0.02 7 1 3.92 401 15915 0 0.03 12 2 3.86 Lt.Deposits. 402 1595 5 0 0.02 8 1 3.95 403 15996 0 0.01 5 1 3.93 404 1603 6 0 0.02 7 1 3.92 405 16076 0 0.02 6 1 3.93 406 16117 0 0.02 7 2 3.88 Lt.Deposits. 407 1615 7 0 0.02 7 1 3.92 408 1619 7 0 0.02 6 1 3.94 409 1623 7 0 0.04 13 2 3.92 • 410 16277 0 0.05 20 3 3.90 Isolated Pitting. Lt.Deposits. 411 16316 0 0.02 6 1 3.92 412 16356 0 0.02 6 2 3.93 413 1639 7 0 0.02 8 2 3.94 414 1643 6 0 0.03 10 2 3.93 • 415 16475 0 0.02 6 2 3.92 416 16514 0 0.03 9 2 3.92 417 16554 0 0.02 8 1 3.92 418 16594 0 0.02 6 1 3.93 • 419 16634 0 0.02 7 3 3.88 Lt.Deposits. 420 16673 0 0.02 6 2 3.89 Lt.Deposits. 421 16713 0 0.01 5 1 3.89 Lt.Deposits. 422 16752 0 0.02 6 2 3.93 423 16792 0 0.02 6 2 3.89 Lt.Deposits. 424 16831 0 0.02 6 1 3.91 425 16870 0 0.03 11 2 3.93 • 426 16910 0 0.02 8 2 3.92 U 427 16950 0 0.02 6 2 3.89 Lt.Deposits. 428 16990 0 0.02 7 2 3.91 429 17030 0 0.02 6 1 3.93 430 17070 0 0.03 10 2 3.87 Lt.Deposits. • 431 17110 0 0.02 7 2 3.90 432 17148 0 0.03 12 2 3.92 433 17188 0 0.04 15 1 3.95 Shallow Pitting. 434 17228 0 0.03 10 2 3.86 Lt.Deposits. 435 17267 0 0.01 5 1 3.89 Lt.Deposits. 436 17305 0 0.02 6 2 3.91 437 17344 0 0.05 18 1 3.92 Shallow Pitting. 438 17384 0 0.02 7 2 3.90 Lt.Deposits. 439 17423 0 0.03 11 3 3.88 Lt.Deposits. 440 17463 0 0.01 5 2 3.89 Lt.Deposits. 441 17502 0 0.03 12 2 3.91 442 17542 0 0.03 11 1 3.90 •• 443 17582 0 0.05 20 3 3.88 Isolated Pitting. Lt.Deposits. 444 1762 2 0 0.03 11 2 3.93 - 445 17662 0 0.04 13 2 3.93 446 17702 0 0.03 13 3 3.93 447 17742 0 0.05 20 2 3.93 Line of Pits. 448 17781 0 0.02 6 1 3.90 IPenetration Body Metal Loss Body Page 9 • • 11111 PDS Report Joint Tabulation Sheet 111. Well: CD4-321 Survey Date: November 5, 2016 Field: Alpine Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L-80 I BTM Tubing 3.958 in. 0.271 in. -2 ft. 18,109 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 449 17819 0 0.03 10 1 3.93 • 450 17858 _ 0 0.05 17 2 3.93 Shallow Pitting. 450.1 17898 0 0.02 7 1 3.90 Pup 450.2 17908 0 0 0 0 3.77 BAKER PREMIER SLIDING SLEEVE 450.3 17914 0 0.03 12 1 3.91 Pup 451 1792 3 0 0.02 9 3 3.93 452 1795 5 0 0.03 10 3 3.92 452.1 17986 0 0.02 6 1 3.92 Pup 452.2 17994 0 0 0 0 3.90 WEATHERFORD POD2 GAUGE CARRIER 452.3 17998 0 0.02 7 1 3.94 Pup 453 18005 0 0.04 16 2 3.92 Shallow Pitting. 454 1803 7 _ 0 0.02 9 4 3.89 Lt.Deposits. 454.1 18068 0 0.02 6 1 3.90 Pup 454.2 18077 0 0 0 0 3.83 BAKER PREMIER PACKER 454.3 18085 0 0.02 6 1 3.89 Pup Lt. Deposits. 455 18094 0 0.03 12 2 3.91I Penetration Body Metal Loss Body Page 10 • • 1111 PDS Report Cross Sections 1_i Well: CD4-321 Survey Date: November 5,2016 Field: Alpine Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 4.5 in. 12.6 ppf L-80 IBTM Analyst: C.Waldrop Cross Section for Joint 447 at depth 17,757.926 ft. Tool speed=52 Nominal ID=3.958 Nominal OD=4.5 4n Remaining wall area=99% \ Tool deviation=71° 1 Finger= 12 Penetration=0.054 in. Line of Pits 0.05 in.=20%Wall Penetration HIGH SIDE=UP • . CES. PDS Report Cross Sections Well: CD4-321 Survey Date: November 5,2016 Field: Alpine Tool Type: UW MFC 24 No.214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 4.5 in. 12.6 ppf L-80 IBTM Analyst: C.Waldrop Cross Section for Joint 443 at depth 17,613.914 ft. Tool speed= 52 Nominal ID=3.958 Nominal OD=4.5 Remaining wall area=97% Tool deviation= 71° • i 1 / Finger= 12 Penetration=0.054 in. Isolated Pitting 0.05 in.=20%Wall Penetration HIGH SIDE= UP • • WNS INJ CD4-321 ConocOi'1iIIips 04 Well Attributes Max Angle&MD TD Alaska.Inc Wellbore APINWI Field Name Wellhete Slates Incl('j MD(1180) Act Ptm(It(8) Co oc<imilips 501032053600 NANUU KUPARUK 1114 77.5(1 3.218-04 19,337.0 Comment 1120(ppm) Date Annotation End Dale KBGni(ft) Rig Release Date 004321,4/19/20181126 00 PM SSSV:WRDP Last WO: .48.58 10/26/2006 Varbcal scne,461(actual) Annotation Depth(IIKB) End Date Annotation I.tot Mod By End Date Last Tag: Rev Reason:SET Al INJ VALVE poroven 4/192010 '. gr Casing Strings HANGER,31 5 I.-_ _ Casing Description 00(in) ID(in) Top(01(13) Set Depth(OK• Set Depth _7 t}.. WN.en(I...Grade fop Thread _ CONDUCTOR 16 15.250 37.0 114.3 114.0 65.00 1+40 WELDED ' Insulated 34' Casing Description 013(Int ID(in) Top fell)) Set Depth(BNB) Set Depth(TVD)... Wt/Len(L..Grade Top thread " I- SURFACE 9 5'8 8.835 36.5 3,504.0 2,385.2 40.00 L-80 BUTT s Casiny Description 00(ln) 'ID(in) Top(ftl(B) Set Depth(0136) Set Depth(TVD)... WVLen(1...Grade Top Thread I IN-ERNIEDIAE 7 6.2713 3,1.4 19,323.1 7800.2 26.00 L-80 B-rom �1 ill Tubing Stnngs Tubing Des caption IStriny Ma..�10(In) I Top(1I(0) I Set Depth(tt..1 Set Depth(TVO)(...I Wt(Ib/N) I Grade I Top Connection TUBING 4 1/2 3.958 31.5 18,194.21 7,219.5 12.60 L-80 IBTM Gas Injection I Completion Details 1•• r Nominal N CONDUCTOR InsUlYted 34 1 lop(111)() Top(TW)(0089) Top Incl I) Item Dns Coto (ht) 37.0-11413 31.5 31.5 0.36 HANGER FMC.TUBING HANGER 4.500 2,290.2 1,958.7 58.57 NIPPLE CAMCO DB NIPPLE 3.812 17,907.9 7,124.5 70.90 SLEEVE BAKER PREMIER SLIDING SLEEVE CMD 3.810 i, [,i 17,993.5 7,152.7 70.61 GAUGE WEATHERFORD POD2 GAUGE CARRIER 3.958 da VALVE2,290.0 1 18,077.0 7,180.4 70.66 PACKER BAKER PREMIER PACKER 3.875 N9'PLE,2,290.2 :�.� 18,181.9 7,215.4 70.35 NIPPLE HES NX NO GO NIPPLE 3.725 18,192.8 7,219.1 70.32 WLEG BAKER WIRELINE FLUTED GUIDE 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(MB) (MB) (1 Des Com Run Date ID(in) 2,290.0 1,958.6 58.56 VALVE A-1 INJ VLV(S/N:HLS-7881 1.25'ORIFICE)ON DB- 4/17'2416 1.75:) LOCK Perforations&Slots Shot SURFACE,36.63.504,0 A Dens T op(TVD) Btm(TVD) (shots/f Top(1186) Bun((DWI (IOW) (MD) Zone Date 0) Type Cum 18,434.0 18,450.0 7.299.8 7,305.3 11/20/2006 6.0 IPERF 1 18.450.0 18,470.0 7,305.3 7,312.3 11202006 6.0 IPERF SLEEVE;17,907.9 OAU0E;17,993.5 L PACKER,16,071.0 NIPPLE;18.181,9 1111 WLEO;18.192.8 (PERF;18,434.0-18,050.0 IPERF;18,450.0.18,470.0.+ I INTERMEDIATE;34.4-19.3231..... . 2aG- \-4 2- • • -tc.0 WELL LOG TRANSMITTAL -111W1r3g11° S DATA LOGGED PROACTIVE DIAGNOSTIC SERVICES, INC. 30/201Cs RECEIVEDvI K BENDER NOV 222016 To: AOGCC AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 pa 1) Caliper Report 05-Nov-16 CD4-321 1 Report /CD 50-103-20536-00 2) Signed : �/ '�� a'h'0v t,k Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-8952 E-MAIL: PDSANCHORAGE(t MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\AchivesWasterTemplateFi les\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx • OF 7 • • rp- 2, ., \ 11/" THE STATE Alaska Oil and Gas o I1j\ Commission f ConservationCommission _,rte•.:=-°_-__--___ o �:__�= 333 West Seventh Avenue �T,�,,, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 11 ALASY'P- fr4 Main: 907.279.1433 sEc F _ GUI Fax: 907.276.7542 �,� www.aogcc.alaska.gov Drew Huck I Drilling Engineer b ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD4-321 Permit to Drill Number: 206-142 Sundry Number: 316-060 Dear Mr. Huck: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval oval se tout in p the enclosed form. p As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, �i / ,) Cathy '. Foerster Chair DATED this ,D day of February, 2016. RBDMS L'. FEB 0 4 2016 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well L, Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q . Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing Q , Other: ❑ 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Conocophillips Alaska, Inc. Exploratory ❑ Development ❑ 206-142 • 3.Address: Stratigraphic ❑ Service ❑f 6.API Number: PO Box 100360,Anchorage,Alaska 99510 50-103-20536-00 • 7. If perforating: 8.Well Name and Number: Glu- RECEIVED What Re ulation or Conservation Order governs well spacing in thispool? N/A CD4-321 . Will planned perforations require a spacing exception? Yes ❑ No 0 / JAN 2 9 2 16 9.Property Designation(Lease Number): 10.Field/Pool(s): ` 3 8 ADL0380077,ADL0387209, ASRCNPRA02 - Colville River Field/Alpine Oil Pool , AO? 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 19323 . 7800 -19323 - 7800 2993 f'.jb?JE NanlZ Casing Length Size MD TVD Burst Collapse Structural Conductor 77 16 114 114 Surface 3467 9.625 3504 2384 Intermediate 19289 7 19323 7800 Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 18434'-18470' , 7300'-7312' 4-1/2" L-80 18193 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Premier Packer, DB Nipple w/A-1 injection valve . Packer-18077', DB Nipple-2290' 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑✓ 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: 3/8/2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑✓ • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Drew Huck @ 265-6828 Email Andrew.Huck@cop.com Printed Name Drew Huck @ 265-6828 Title Drilling Engineer Signature Phone Date Cer..----"---- 2/1 1/Z-VI 6 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test M Mechanical Integrity Test 15 Location Clearance ❑ Other: /3 p n fi«-t to 3 5 c o p 'a (iv,p 5P i5 2, 411,3• p s r ..vr,,,,Oar pre✓« trY t-e15-1-- to ZSvci p ' r SJ-a 6_,-/ ,,,5_, 0 ,1 ,J cctr � - f-H r55T d M Cr-IA rrt t../ -f el k 0"�u re 1^-'1 Post Initial Injection MIT Req'd? Yes Er No ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: / — 4 D APPROVED BY Approved by:( 96,12.4,......., COM ISSIONER THE COMMISSION Date: Z_ 3 ../4 Submit Form and Form 10-403 Revised 11/2015 03RvEldGAW ' for 12 months from the date of approval. Attachments in Duplicate ?1I2.1I�r UT L 2/3/u, I � RBDMS L, FEB 0 4 2016 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 28th,2016 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to work over Alpine CD4 Kuparuk Injector CD4-321 (PTD#206-142). CD4-321 was originally drilled and completed in 2006 as a Kuparuk C sand MWAG injector in Alpine. In 2013, communication was found between the outer annulus and the conductor through a suspected surface casing leak at 54',detected by fluid level. At this point,ConocoPhillips applied for an AA waiver for water only injection(Sundry #313-181)and the well has been on water only injection since. The proposed workover scope for CD4-321 is to pull the existing 4-1/2"completion,pull the 7"production casing near surface,and repair the surface casing leak with an expandable patch. The 7"and 4-1/2"tubing string will then be rerun and MWAG injection resumed. If you have any questions or require any further information,please contact me at 265-6828,or Brett Packer at 265- 6845. Sincerely, '21,/ Drew Huck Drilling Engineer CPAI Drilling and Wells • CD4-321 Rig Workover • Surface Casing Repair—4-1/2"tubing with surface casing repair (PTD#:206-142) Current Status: This well is an active water injector into the Kuparuk C-sand at CD4 supporting CD5 and currently has a surface casing leak at an estimated depth of 54'. Scope of Work: Cut and pull the existing 4-1/2"tubing, cut and pull the 7"casing to+/-300',Run an expandable patch over the 9-5/8" surface casing,rerun 7"and run 4-1/2"tubing with a stacked packer. General Well info: Well Type: Injector MPSP: 2,993 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 3,708 psi/7,152' TVD(10.0 ppg EMW)measured on 7/11/2015 Wellhead type/pressure rating: FMC Gen V, 11"5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MITIA passed— 11/11/15, suspected surface casing leak @ 54'. Earliest Estimated Start Date: March 8th,2016 Production Engineer: Garett McKee Workover Engineer: Drew Huck(265-6828/Andrew.Huck@cop.com) Pre-Rig Work 1. RU Slickline: Pull A-1 Injection Valve. Set plug in nipple @18,182', set catcher sub on top of plug. PT plug to 3,000 psi, perform NFT on plug. 2. Cut tubing in first full joint above packer 3. PT tbg &csg packoffs, FT LDS's. 4. Set BPV w/i 24 hrs of rig arrival. Workover Procedure 5. MIRU. 6. Pull BPV. Reverse circulate KWF. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF and repeat circulation as necessary. Verify well is dead. 7. Set BPV& blanking plug or two-way check, PT to 1,000 psi from below if possible, ND tree, NU BOPE &test to 3,500 psi high/250 psi low. 8. Pull blanking plug & BPV or two-way check. 9. RU to pull tubing, MU landing joint, BOLDS's, POOH laying down tubing. 10. RIH &set an RBP at 1000 ft below surface. PT to 3000_p_siand drawdown test to 0 psi. 11. RIH open-ended and dump 50'-100' of sand on top of plug. POOH standing back drillpipe. 12. Cut 7" casing at+/-300' in mid joint. 13. Spear the casing &circulate out the Arctic Pack from the OA w/ heated diesel & seawater. 14. POOH laying down 7" casing. 15. RU E-line, RIH with CCL, MTT and caliper. Log from casing stub to surface. 16. RIH w/the backoff tool to the top of the 7" casing stub, engage stub and backoff. POOH standing back drillpipe. 17. RIH w/7" casing spear, retrieve 7"casing stub. POOH standing back drillpipe. 18. RU Weatherford Hydro Skin patch system. RIH with patch (+1-4 joints, pending MTT/caliper results). Circulate CI fluid around patch, ensuring outer surface is covered. Set patch with top as close as practical to surface. 19. RIH w/7-7/8" mill tooth bit to patch shoe, pressure test patch, drill up shoe, POOH standing back drillpipe. 20. RIH with inflatable test packer, set just below patch. PT above packer to 1,800 psi, POOH with test packer. 21. RIH w/wash string assembly and wash out top of 7" connection. POOH standing back drillpipe. 22. RU casing crew& RIH w/ new 7" casing, screw into top of 7" casing, PT casing to 3000 psi. 1 • • CD4-321 Rig Workover Surface Casing Repair—4-1/2"tubing with surface casing repair (PTD#:206-142) 23. ND BOPE and tubing head (break stack between tubing head and casing head), pull 7" casing in tension and land in the slips. Cut excess 7" casing w/Wachs cutter. NU tubing head and BOPE and test break. 24. RIH w/wash string assembly and circulate out sand on top of the RBP/IBP. POOH standing back drillpipe. (Repeat cleanout runs if necessary until boot baskets come back empty.) 25. RIH w/IBP/RBP retrieving head to top of plug, swap well back to KWF, engage RBP and pull to release. POOH standing back drillpipe. 26. RIH w/new tubing, packer and seal assembly to just above the cut. Engage overshot over the tubing stub and set the premier packer. PT the IA to confirm packer is set. Shear the PBR. 27. Space out, mark the pipe, and pull out of PBR. 28. Install space out pups below the hanger, MU hanger, MU control line(s)to hanger(if present). 29. Load the well with corrosion inhibited brine. 30. PT the tubing for 10 min. Reduce the tubing pressure and PT the IA and chart for 30 min. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 31. Pull the landing joint, install BPV or two-way check. PT BPV or two-way check to 1,000 psi from below. 32. ND BOPE. NU tree. If BPV is installed, pull BPV& install tree test plug. Test tree. Pull test plug/two-way check. 33. Freeze protect well w/diesel. Install BPV. 34. RDMO. Post-Rig Work 35. Pull BPV. 36. RU Slickline: Change SOV for DV, Pull catcher, Pull plug. 37. Turn well over to operations. WNS INJ • CD4-321 ConocoPhillips & Well Attributes Max Angle&MD TD Alaska,Inc, Wellbore API/UWI Field Name Wellbore Statue Incl(°) MD(lKB) Act Blm(ftKB) [cr+rrYPlaMlls 501032053600 NANUO KUPARUK INJ 72.56 3,218.04 19.337,0 - ••; Comment 625(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date CD4-22110/39201510:50:1/AM SSSV:WRDP Last WO: 43.58 10/26/2006 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation `Last Mod By End Date Last Tag: Rev Reason:RESET INJ VALVE pproven 10/25/2015 i �n Casing Strings HANGER;31.5— I B Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Tap Thread •----••----•••-••--••---•--- '; CONDUCTOR 16 15.250 37.0 114.0 114.0 65.00 H-40 WELDED Insulated 34" Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) -Set Depth(IVO)...WULen(I...Grade Top Thread SURFACE 95/8 8.835 36.6 3.504.0 2,385.2 40.00 L-80 BUTT 1 Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1...Grade Top Thread • INTERMEDIATE 7 6.276 34.4 19,323.1 7,800.2 26.00 L-80 BTCM Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection , _ Gas 412 3.958 31.5 18,194.2 7,219.5 12.60 L-80 IBTM Gas Injection I Completion Details -_ Nominal ID Top(ftKB) Top(TVD)(ftKB) Top mel(°) Item Des Corn (In) CONDUCTOR Insulated 34., 0. 31.5 31.5 0.06 HANGER FMC TUBING HANGER 4.500 37.0.114.0 2,290.2 1,958.7 58.57 NIPPLE CAMCO DB NIPPLE 3.812 e 17,907.9 7,124.5 70.90 SLEEVE BAKER PREMIER SLIDING SLEEVE 3.810 NIPPLE;2,290.2 VALVE;2,290.2 17,993.5 7,152.7 70.61 GAUGE WEATHERFORD P002 GAUGE CARRIER 3.958 •' 18,077.0 7,180.4 70.66 PACKER BAKER PREMIER PACKER 3.875 18,181.9 7,215.4 70.35 NIPPLE HES NX NO GO NIPPLE 3.725 18,192.8 7,219.1 70.32 WLEG BAKER WIRELINE FLUTED GUIDE 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top(Incl Top(11K8) (ftKB) (°J Des Com Run Date ID(in) 2.290,2 1,958.7 58.57 VALVE A-1 INJECTION VALVE ISM:HSS-169) 10/25/2015 1.250 Perforations&Slots SURFACE;36.6-3,504.0 Shot Dens Top)TVD) Bim(TVD) (shotslf Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date i) Type Com l 18,434.0 18,450.0• 7,299.8 7,305.3 11/2012006 6.0 IPERF ) 18,450.0 18,470.0 7,305.3 7,312.3 11/20/2006 6.0 IPERF SLEEVE:17,807.9 --_--j _ll. GAUGE',17,0935 r----41— __,i; 1 Ler, PACKER las-,.0 ai NIPPLE,10,181.9 y., ( II WLEG-18,192.8 IPERF;18,434.0-19,450.0-- IPERF;18,450.0.18.470.0 - fl INTERMEDIATE,34.4-19,323.1— • • CD4-321 Huck 1-28-2016 MWAG Injection Well -77-7,777:77-7 Proposed Schematic Conductor(Drivenl: 16",65#,H-40 Welded Set @+/-114'RKB 9-5/8 Expandable Casing Patch,Surface to+/-200 MD,7"Casing replaced to+/-300'MD Surface Casing: 0 9-5/8",40#,L-80,BTC J Camco 3.812"DB Nipple+/-@2,300° Set @+/-3,504'MD/2,385'TVD With Injection valve l J { f — GLM/SS @+1-18,000' J =--= PBR Baker Premier Packer @+1-18,030' i Production Tubing; Poor Boy Overshot @+/-18,040'MD over cut tubing joint 4 Ys",12.6#L-80,Hydril 563 Baker Premier Packer @ 18,077'MD T XN Nipple w/3.725"No-go f J r 0111110__ Kuoaruk C Perforations 18,434'-18,470' r 111111m--- 1 1 I production Casing; 7",26#,L-80,BTC-Mod Set @ +/-19,323'MD/7,800'TVD • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday,November 19,2015 Jim RZ_a 11/21(I SUBJECT: Mechanical Integrity Tests P.I.Supervisor ( CONOCOPHILLIPS ALASKA INC CD4-321 FROM: Guy Cook COLVILLE RIV NAN-K CD4-321 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J -- NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-K CD4-321API Well Number 50-103-20536-00-00 Inspector Name: Guy Cook Permit Number: 206-142-0 Inspection Date: 11/11/2015 Insp Num: mitGDCl51112140508 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4-321 ' Type Inj W`FTVD 7180 ' Tubing 2492 2494 - 2490 - 2505 -1 PTD 2061420 ' Type Test SPT Test psi 2916 - IA 1300 3300 - 3270 - 3270 - Interval REQVAR PAF P OA 0 2 . 2 2 Notes: AIO 18C.002 MITIA to Max Anticipated Injection Pressure. Max since August of 2015 is 2916 psi. , SCANNED SEP 1 6 2016 Thursday,November 19,2015 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 16,2015 TO: Jim Regg / P.I.Supervisor q b'I 1 f c SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-321 FROM: Johnnie Hill COLVILLE RIV NAN-K CD4-321 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J,6(2— NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-K CD4-321API Well Number 50-103-20536-00-00 Inspector Name: Johnnie Hill Permit Number: 206-142-0 Inspection Date: 6/12/2015 Insp Num: mitJWH150613214430 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well CD4-321 - Type Inj N -TVD 7180 ' Tubing 100 - 100 • loo loo PTD 2061420 - Type Test SPT Test psi 3000 . IA 159 3310 - 3276 3267 Interval REQVAR P/F P OA 0 2 1 1 Notes: MITIA to max anticipated injection psi MO I8C.002 Tuesday,June 16,2015 Page 1 of 1 • • Ir~~~~~ Project W~U hiistof!~ File CoV~r ~°~~e Xi-IVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q~,©~ - ~ ~ ~ Well History File Identifier Organizing (done> Two-sided III IIIIII II III II III ^ Rescan Needed III (I'lll II II III III RE CAN DIGI AL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other.: BY: Maria Date: /s/ ProjectProofing III IIIIIIIIIII IIIII BY: _ aria Date: ~ `~. ~ ~1~D ~_ lsl Scanning Preparation ~ x 30 = ~ + C>C.~ =TOTAL PAGES~~ (Count does not include cover sheet) BY: Maria Date: `(~, ~' lOg /s/ Production Scanning Stage 1 Page Count from Scanned Fife: _~~ (Count does include cove sheet) Page Count Matches Number in Scannin Preparation: __~,~YES NO BY: Maria Date: ~ /s/ ~-.~~ l a-~ 3 I ©~ ~ ~I Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. N I II II II I (I II I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III II'I III 10/6/2005 Well History File Cover Page.doc Fisher, Samantha J (DOA) cvLO- From: Wallace, Chris D (DOA) Sent: Monday,June 17, 2013 12:33 PM To: Fisher, Samantha J (DOA); NSK Well Integrity Proj Subject: FW: ConocoPhillips Cancel 10-403 Question? Attachments: CD1-28 Approved Sundry 313-178.pdf; CD4-321 Approved Sundry 313-181.pdf Follow Up Flag: Follow up Flag Status: Flagged Martin, By copy of this email we will cancel approved Sundry 313-178 for well CD1-28 (PTD 2001990) and approved Sundry 313- 181 for well CD4-321 (PTD 2061420) as per the CPAI email request. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer SCANNED FEB 2 0 2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov From: NSK Well Integrity Proj [mailto:N1878 @conocophillips.com] Sent: Sunday, June 16, 2013 3:57 PM To: Wallace, Chris D (DOA) Cc: NSK Well Integrity Proj Subject: ConocoPhillips Cancel 10-403 Question? Chris, ConocoPhillips submitted 10-403s and received approval to pump outer annulus cement shoes in CD1-28 (313-178) and CD4-321 (313-181). As a part of the procedure, we determined that there was not enough injectivity into the OA to support pumping the shoes. As a result of cancelling the job, we also need to cancel the 10-403. We have not done this in quite a while so can you give me some guidance on what I need to do take care of this? Please contact me at your convenience if you have questions or comments. Martin Martin Walters/MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office: 907-659-7043 Cell: 907-943-1720 Pager: 907-659-7000#937 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg e ; - ('74:i i 3 DATE: Tuesday,May 14,2013 P.I.Supervisor 11 11 ) ( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-321 FROM: Lou Grimaldi COLVILLE RIV NAN-K CD4-321 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry `Try NON-CONFIDENTIAL Comm Well Name COLVILLE RIV NAN-K CD4-321 API Well Number 50-103-20536-00-00 Inspector Name: Lou Grimaldi Permit Number: 206-142-0 Inspection Date: 5/10/2013 Insp Num: mitLG130510181648 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well; CD4-321 Type Inj , W•'TVD 7181 IA 640 3010 .- 3000 3000 SPT psi 3010 PTD 2061420 Type Test [ 3010 1 OA 3 �� 1 I YP Test si 1270 �z�o iz7o IntervalIREQVAR P/F P Tubing 1270 Notes: Initial test for AIO 18C.002 compliance(OAxOOA comm.).3.25 bbls pumped,3.22 returned.Water header pressure entering pad was 2470 psi today.Good solid test.Miller/Byrne well prepared today which made for a enjoyable test. SCANNED FEB 2 o 204 Tuesday,May 14,2013 Page 1 of 1 4.) . ‘ 5 ,-,- - 6 vl - dwei/elogo `\- - o o o ■:./,' __1 0 in o o Lo o ---- --E- cv -t- - • • • . . . co --- ,...,,...). - - • • . • . . - --=---.-------•-..- ..- _ --3 ,.,4'• . . . . -5, • . • , _ 'a. A . . • • • - • • • . • . . . - • . • . . . • . . - . . • . . • . . . • _ . . . • • . . . - . • . • - • . • - . • . . . . . . . • • • N • . • . • • - "? — • • Tt . - 7-----7.................:•::• iii..........,„:: ,,.',,,-,,,:.:....:.......-.. .,,,,,' ___ (1,_,y),...:\ic6<6.,:a., . : • . • . o. . . . 0 - • • • - •. . ..... li . . . . , • • • co ca : . . . -4-, - • • • • , 7- T"'" C) 0 • • • • ;• , 1 • - • • ,. Ca LI. - . • . • . . . . cs 0 - : • . • . . . -_, i........ . . . . • . . . . . . i . . • • • . : . . :1 • i co .. . . . . . ., , • • - . • . . 1 . H . . . . . .-, 1 .. 1,...\„\• • • :. .. , . - \i':•-•\ : ._;----. I/.: , : 0 • ..„---- - .‹ . • r- • • . . . „ Is. --, - ',,, • . \_::_____ . • 1: a) i- ci c\I . i ---- / ce) : • . . .. a) u_ = F- < 0 0 c•■ 0 0 0 co 0 • 1 1 ISd 1 14--T+r.`C,'l W.."- fttr cC- T^ t#�..-' t vv1 It LC1 I C610l l L-4'&W • 1.-- W NS C D4-321 ConocoPhillips WON ,MO akilitIMOD : - Alasiia Inc Waleson APWWI I Field Name Well Statue Incl('I MD MKS)) Aol Bon(t1K8) 501032053600 NANUQ KUPARUK INJ ; 7256 3,218. 04 19,337.0 'Comment flit(ppm) !Date 'Annotation lEnd Date KB.Grd(R) Rig Release Date SSSV:WRDP Last 0/0: 43.58 10/26/2006 .•• well Conn:-GOe•321,.JW401s 4:34:00 PM �.— -_e _...__ - _� &abnyBC.Atluel... - Annotation DNRII KB) End Date !Annotation Last Mod By End Date lest Tag: I I Rev Reason:WELL REVIEW cabal 11/30/2012 Casing Description String 0... String ID...Top(MKB) Set Depth(f...Set Depth(TVD).-Seine WI...String...Siring Top Thrd CONDUCTOR 16 15.250 37.0 114.0 114.0 65.00 H.40 WELDED ,-- —— - Insulated 34' / , Casing Description 'String 0... String ID..rtop(MKS) 'Set Depth(I...Set Depth(ND). String WL..String ..String Top Thrd HANGER,33-- ! SURFACE 95/8 8.835 36.6 3,504.0 2,384.1 40.00 1-80 BUTT __.S Casing Description tieing 0... String ID..Top MKS) Set Depth If...Set Depth(TVD)...Saing Wt...Smng...String Top Tied INTERMEDIATE 7 I 6.276 34.4 19,323.1 7,800.2 26.00 L-80 BTCM - .. - Tubing Description String 0... String ID_.Top(81(8) Set Depth(1...;Set Depth(TVD)...'String WI...String...Stang Top Thrd TUBING 4 1/2 3.958 31.5 18,194.2 i 7,220.4 12.60 L-80 IBTM Gas Injection - Top Depth (ND) Top trrcl Top(MKB) 01K8) r) Item OnscriptIon Comment 0(In) CONDUCTOR 31.5 31.5 0.12 HANGER FMC TUBING HANGER I I 4.500 Insulated 34^, 37414 -- ----- - , 3 2,290.2 1,958.6 58.57 NIPPLE CAMCO DB NIPPLE 3.812 17,907.8 7,124.5 70.90 SLEEVE )BAKER PREMIER SLIDING SLEEVE 3.810 NIPPLE,2$90- -7 VALVE,2,290 �• 17,993.5 ,152. 70.61`GAUGE — WEATHERFORD POD2 GAUGE CARRIER 3.958 I 18,077.0 7,180,5 70.78 PACKER BAKER PREMIER PACKER a -18,181.9 7,215.4 70.35 NIPPLE HES NX NO G0 NIPPLE 3.725 18,192.8 7,220.0 71.16 WLEG BAKER WIRELINE FLUTED GUIDE . 3.875 1 - . .. - Top DePlh ......., , (TVD) Top Intl Top MKS) (RKB) ('I Description Comment '• Run Date ID(In) 2,290.21 1,958.6 58.57 VALVE - A-1 INJECTION VALVE(S/N:HSS•163) /70/2212012 1.250 SURFACE._� • J 37-3,504 .,... ..�..... .�..a. .. - - .. Shot Top(TVD) Elm(ND) Den. • Top(RKB)Sim(MKB) MKS) MKS) zorM Date (■h•.. Comment— 18,434.0. 18,450.0 7,300.3 7,305.5 11/20/2006 6.0 IPERF 18.45O.Oi 18,470.0 7,3055 7,312.3 11/20/2006 6.0 IPERF a I SLEEVE, 17,909 I I I ant GAUGE,17,993 air I I I PACKER. 'v - 18,077 I I NIPPLE,18,182 " I MEG,16,103 I r I IPERF, 18,434-10,450 ° IPEetf. 18,450-16,470 _ NTERMEDIATE, 34-19,323�4 ' TD,10,337 • • O��%%� THE STATE T Alaska Oil and Gas s - �� °f A LASJ�� 1 1 Conservation Commission OF h , GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1 433 Fax: 907.276.7542 sCOMEQ APR 12 ZO13 Jerry Dethlefs Well Integrity Director ConocoPhillips Alaska, Inc. 6-00' P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD4 -321 Sundry Number: 313 -181 Dear Mr. Dethlefs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / Cathy P Foerster Chair DATED this 1� day of April, 2013. Encl. STATE OF ALASKA RECEIVED A<A OIL AND GAS CONSERVATION COMM JN 1-7/j`7_3 APPLICATION FOR SUNDRY APPROVALS APR 1 0 2013 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell r ChanCm r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other: SC Cement Shoe • r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 206 - 142' 3. Address: Stratigraphic r Service r� • 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20536 - 00 • 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r CD4 - 321 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0380077IADL0387209IFEE -ASRC 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): •19337 7810 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 3467 10 3504' 2384' INTERMEDIATE 19289 9 19323' 7800' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): • 18434' - 18470' 7300' - 7312' 4.5 L - 18193 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) HANGER - FMC TUBING HANGER MD= 32 TVD= 32 VALVE - A -1 INJECTION VALVE (S /N: HSS -163) • MD= 2290 TVD= 1959 SLEEVE - BAKER PREMIER SLIDING SLEEVE ' MD= 17908 TVD= 7125 GAUGE - WEATHERFORD POD2 GAUGE CARRIER • MD= 17993 TVD= 7153 PACKER - BAKER PREMIER PACKER ■ MD= 18077 TVD= 7180 I NIPPLE - HES NX NO GO NIPPLE • MD= 18182 TVD= 7215 WLEG - BAKER WIRELINE FLUTED GUIDE • MD= 18193 TVD= 7219 12. Attachments: Description Summary of R oposal • r- 13. Well Class after proposed work: • Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r:% 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/13/2013 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG Pl 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: Jerry Dethlefs Email: jerry.c.dethlefs@conocophillips.com Printed Name Dethlefs Title: Well Integrity Director Signature Phone: 265 -1464 Date ����� Com ssion Use Only Sundry Number: 3 al Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r FIRDMS APR 12 2t1. ■ Other: Spacing Exception Required? Yes ❑ No [il Subsequent Form Required: / 9 — 401-f APPROVED BY T Approved by: T"""' COMMISSIONER THE COMMISSION Date: ` // /.... Approved application is valid for 12 months from the date of approval. O /1?))41 A L �,/Z4% 4.1/` / Submit Form and Attachments in Duplicate A`o\ • • Jerry Dethlefs Well Integrity Director ConocoPhillips Alaska, Inc. )110V 700 700 G Street t '` t `` y Conoco Anchorage, AK 99510 Phone 907 - 265 -1464 April 10, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well CD4 -321, PTD 206 -142 for pumping a surface casing cement shoe. Please contact me at 907 265 -1464 if you have any questions. Sincerely, C e- Jerry Dethlefs ConocoPhillips Well Integrity Director Enclosures: Description Summary of Proposal 10 -403 Application for Sundry Approvals CD4 -321 Wellbore Schematic • • ConocoPhillips Alaska, Inc. Kuparuk Well CD4 -321 (PTD 206 -142) SUNDRY NOTICE 10 -403 REQUEST 4/10/13 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to pump a cement shoe in the surface casing of Alpine CRU service well CD4 -321. A surface casing cement shoe was not pumped at the time of original completion in 2006. The cement shoe is required in order to pressure test the surface casing and to locate and verify the size of a suspected surface casing corrosion penetration. With approval, the OA cement shoe will require the following general steps: 1. Pump cement designed for a 1000' linear shoe in the OA. 2. Displace cement with freeze protection fluids 3. Wait 48 hrs on cement 4. MITOA to 1800 psi and / or establish LLR. 5. If MITOA fails establish circulation to conductor and locate leak 6. Submit 10 -404 to AOGCC. I I NSK Problem Well Supervisor 4/10/2013 • r WNS CD4 -321 r ConocoPhillips Well Attributes 0 Max Angle & MD TD {11e153 IIH: Wellborn API/UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) 501032053600 NANUO KUPARUK INJ 72.56 3,218.04 19,337.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (R) Rig Release Date • °• Well Conk - CD4 -321, 11/30/101212:43:20 PM SSSV: WRDP Last WO: 43.58 10/26/2006 Schematic • Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: WELL REVIEW osborl 11/30/2012 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (9... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.250 37.0 114.0 114.0 65.00 H-40 WELDED — — Insulated 34" HANGER, 32 d. r Casing Description String 0... String ID ... Top (ftKB) Set Depth (f.., Set Depth (TVD) ... String Wt... String ... String Top Thrd — SURFACE 9 5/8 8.835 36.6 3,504.0 2,384.1 40.00 L BUTT — - — - — 1 ° s 9i• Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd k INTE RMEDIATE 7 6.276 34.4 19,323.1 7,800.2 26.00 L-80 BTCM � Tubing Strings '' Tubing Description String 0.. String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 4 1/2 3.958 31.5 18,194.2 7,220.4 12.60 L -80 IBTM r Gas Injection I Completion Details Top Depth (TVD) Top Inc' Noml... Top (ftKB) (ftKB) (°) Item Description Comment ID (In) CONDUCTOR 31.5 31.5 0.12 HANGER FMC TUBING HANGER 4.500 Insulated 1 3d - 3414 4 2,290.2 1,958.6 58.57 NIPPLE CAMCO DB NIPPLE 3.812 17,907.9 7,124.5 70.90 SLEEVE BAKER PREMIER SLIDING SLEEVE 3.810 NIPPLE, 2,290 17,993.5 7,152.7 70.61 GAUGE WEATHERFORD POD2 GAUGE CARRIER 3.958 VALVE. 2290 ® ;- 18,077.0 7,180.5 70.78 PACKER BAKER PREMIER PACKER 3.875 18,181.9 7,215.4 70.35 NIPPLE HES NX NO GO NIPPLE 3.725 18,192.8 7,220.0 71.16 WLEG BAKER WIRELINE FLUTED GUIDE 3.875 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (ftKB) (ftKB) (°) Description Comment Run Date ID (In) 2,290.2 1,958.6 58.57 VALVE A - 1 INJECTION VALVE (S/N: HSS - 163) 10/22/2012 1.250 SURFACE, • 37 -3504 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top(ftKB) B1m(ftKB) (ftKB) (ftKB) Zone Date ( Type Comment 18,434.0 18,450.0 7,300.3 7,305.5 11/20/2006 6.0 IPERF 18,450.0 18,470.0 7,305.5 7,312.3 11/20/2006 6.0 IPERF , c i n SLEEVE 1' , 1 17.908 17: 1 GAUGE. 17,993 -I C PAC KER, 1 8,077 ''`- NIPPLE, 18,182 - 1 WLEG, 18,193 IPERF, 18,43418,450 i IPERF, 18,450-18.470 NTERMEDIATE, 3419,323 N ' TO 19,337 ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service IO 6. Permit to Drill Number: 206 -142 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD4 -321 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG 0 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20536 -00 - - 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation El or Final ❑ 310 -320 & 311 -271 9/8/2011 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement - contaminated domestic waste water descriptions in block 12) disposal K, 9 �Ua°2 1 drilling mud, completion occurred Est E g y . �I a fluids, formation fluids and any necessary water added Previous 34332 300 522 35154 7 totals (bbls): 2011 / 3rd 0 0 0 0 0 2011 /4th 11856 100 0 11956 14 10/1/2011 12/19/2011 CD4 -321, CD4 -03, CD4 -27 2012 / 1st 910 100 0 1010 3 1/12/2012 1/14/2012 CD4 -27 2012 / 2nd 18780 100 0 18880 20 5/3/2012 6/11/2012 CD4-213B IP Total Ending Report is due on the 20th Volume 65878 600 522 67000 44 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeze protect volumes only I hereby certify that the foregoing is true and correct the best of my knowledge. / Date: 7 ( b 4O(Z Signature: Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate RECEIVED STATE OF ALASKA APR 1 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL AOGCC 1. Operator: 4a. Well Class: Stratigraphic ❑ Service 0 6. Permit to Drill Number: 206 -142 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD4 -321 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG In 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20536 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation 0 or Final ❑ 310 -320 / 311 -271 9/8/2011 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement- contaminated domestic waste water descriptions in block 12) disposal • drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 34332 300 522 35154 7 totals (bbls): 2011 / 3rd 0 0 0 0 0 2011 /4th 11856 100 0 11956 14 10/1/2011 12/19/2011 CD4 -321, CD4 -03, CD4 -27 2012 / 1st 910 100 0 1010 3 1/12/2012 1/14/2012 CD4 -27 2012 / 2nd IP Total Ending Report is due on the 20th Volume 47098 500 522 48120 24 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeze protect volumes only SC ifiNNEO APR 1 2012 I hereby certify that the foregoing is rue and correct to the best of my knowledge. Signature: `�-� Date: 4 eL Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, April 03, 2012 2:34 PM To: 'Brunswick, Scott A' Cc: Regg, James B (DOA) Subject: RE: CD4 -321 AD (PTD 206 -142) Scott, Regulations require that the source wells be listed on the 10 -403AD sundry (per 20AAC 25.080 (b)(14)). That said, we have also allowed additional wells to be added after the fact if there is still additional injection volume available and there is no other reason to deny the request. You have approval to add CD4 -213A and CD4-213B to the source well list for Annular Disposal in CD4-32 (per Sundry 311 -271). Guy Schwartz Senior Petroleum Engineer AOGCC EnZ 793 -1226 (office) 444 -3433 (cell) From: Brunswick, Scott A [mailto: Scott. A.Brunswick @conocophillips.com] Sent: Tuesday, April 03, 2012 1:53 PM To: Schwartz, Guy L (DOA) Subject: CD4 Pad Annular Disposal Guy Do we submit a new application for annular disposal for each well we are going to drill? For example, CD4 -321 was permitted for annular disposal in Sept 2011, Approval number 311 -271. To date is has a total of 48,120 bbls into it. The limit looks to be 70000 bbls. May I use the CD4 -321 well for injection for fluids /cuttings generated next month while drilling CD4 -213A & CD4 -213B under the current approved permits 311 -271, PTD 212 -003 & PTD 212 -005? Thanks Scott Brunswick Drilling Engineer Alpine Drilling Team Office: (907) - 263 -4249 Cell: (907)- 227 -8499 4/3/2012 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service 0 6. Permit to Drill Number: 206-142 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD4 -321 2. Address: 4b. Well Status: Oil ❑ Gas WAG E 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20536 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation 0 or Final ❑ 310 -320 / 311 -271 9/8/2011 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: 1 cement- contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred r:a c' L 71,112 fluids, formation fluids and _ Y any necessary water added Previous 30632 100 385* 31117 totals (bbls): 2010 /3rd 0 0 0 0 0 2010 / 4th 178 100 137 415 2 12/19/2010 12/20/2010 CD4 -298 2011 / 1st 0 0 0 0 0 2011 / 2nd 3522 100 0 3622 5 6/5/2011 6/14/2011 CD -208A Total Ending Report is due on the 20th • Volume 34332 300 522 35154 7 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeze protect volumes only I hereby certify that the foregoing is true a correct to the best of my knowledge. Signature: C_ / Date: �I (20(2_ Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 IIBDMS JAN 0 9 2012 4S,-7 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service El 6. Permit to Drill Number: 206 -142 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD4 -321 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG 0 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20536 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation El or Final ❑ 310 -320 / 311 -271 9/8/2011 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement- contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurrede l� • fluids, formation fluids and � � F any necessary water added Previous 34332 300 522 35154 7 totals (bbls): 2011 / 3rd 0 0 0 0 0 2011 /4th 11856 100 0 11956 14 10/1/2011 12/19/2011 CD4 -321, CD4 -03, CD4 -27 2012 /1st 2012 / 2nd Total Ending Report is due on the 20th • Volume 46188 400 522 47110 21 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeze protect volumes only I hereby certify that the foregoing is ue and � correct to the best of my knowledge. Signature: '6 •�\ Date: t (4 1Z0/ L Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 RBDMS JAN 0 9 20 Form 10 -423 Rev. 2/2004 \. INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate 1r i - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service 0 6. Permit to Drill Number: 206 -142 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD4 -321 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG 0 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20536 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation 0 or Final ❑ 310 -320 / 311 -271 9/8/2011 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement- contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added II 34332 300 522 35154 7 totals (bbls): 2011 / 3rd 0 0 0 0 0 2011 / 4th 2012 / 1st 2012 / 2nd Total Ending Report is due on the 20th Volume 34332 300 522 35154 7 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter,. 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances -- % (` i't LO\ Description(s): 'freeze protect volumes only "' I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: • L 6,... Date: (L; (C: (Z,; [ ` Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10 -423 Rev. 2/2004 RB[JMS OCT 14 2011 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service 0 6. Permit to Drill Number: 206 -142 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD4 -321 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG 0 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20536 -00 3. (Check one box only) 5a. Sundry number: 5b. ij val date: 9. Field: Initial Disposal ❑ or Continuation '1 or Final 310 -320 _ 1.109( ss-9 /$ 9i.1 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement- contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added . Previous totals (bbls): 30632 100 385 31117 2010 / 3rd 0 0 0 0 0 2010 / 4th 178 100 137 415 2 12/19/2010 12/20/2010 CD4 -298 2011 /1st 0 0 0 0 0 2011 / 2nd 3522 100 0 3622 5 6/5/2011 6/14/2011 CD -208A Total Ending Report is due on the 20th Volume 34332 300 522 35154 7 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter,. 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances _ f) t Description(s): *freeze protect volumes only I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: d ' , I° Date: ,� ( , '" Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 ri8 &M OCT 14 201 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • • U SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMIIHSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 n b 6 " t (-J' Anchorage, AK 99510 -0360 Re: Colville River Field, Alpine Oil Pool, CD4 -321 Sundry Number: 311 -271 Dear Mr. Alvord: �;s r) s ' Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above - referenced well. Please note that any disposal into the surface /production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless r= caring has been requested. i ; o,r . . - an om . issi , tie DATED this 4 day of September, 2011 Encl. ConocoPhillips Alaska, Inc. • • Post Office Box 100360 Anchorage, Alaska 99510 -0360 ConocoPh i l h ps Telephone 907 - 263 -1215 August 30th, 2011 RECEIVED Alaska Oil and Gas Conservation Commission 'SEP 01 2M11 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 -3539 Malkn Oil & Gas Can. G'®nwnission Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD4 - F" 9 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that the annular disposal permit for CD4 -321 (sundry permit # 206- 142) be re- permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. The current Annular Disposal Permit on CD4 -321 expires on September 23r 2011. The total injection volume is 35,154 bbl so far and total approved injection volume is 70,000 bbl. It is requested that the Annular Disposal Permit described in 20 -ACC 25.080 d. 1. could be extended. The other wells not yet permitted for annular disposal are either in too close a proximity to explorations wells or are not good annular disposal candidates. This leaves us with the choice of re- permitting a previously used annular disposal well to increase the allowable injection volume. Of the wells on the CD4 pad previously used for annular disposal, CD4 -321 is the strongest candidate for extending permit term. Although it is possible to haul the drilling wastes to the Alpine disposal well, no environmental benefit would be realized and additional risks of spillage and vehicular accidents are possible. Injection pressure has typically been significantly below our original surface casing shoe test pressure. CD4 -321 was last used for annular disposal on August 1 e 2011 after injecting 35,154 bbls. Extend the disposal term for CD4 -321 will allow for time to drill more wells and potentially other candidates for annular disposal. For further details please reference the original annular disposal permit for CD4 -321, approved on October 25th, 2007. If you have any questions or require further information, please contact Weifeng Dai at 263 -4324; Chip Alvord can also be reached by calling 265 -6120. v ✓�) R io Sincerely, 3ry ° 3 0 11 4 ( - 1- �:i 1 1- 5 k Weifeng Dai �r, ; P Drilling Engineer , 1 �" 111 1 �'` r Vv IP 10 8/ 1 ? t( cc: CD4 -321 Well File Chip Alvord ATO -1570 Sharon Allsup -Drake ATO -1530 • 0 6 Id i'REcEivEV STATE OF ALASKA SEP 0 1 2011 ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION Msks OH & Gat Cam. GerilfiliS 20 AAC 25.080 Anc her 1. Operator 3. Permit to Drill Name: Number: 206 -142 ConocoPhillips Alaska 4. API Number: 50- 103- 20536 -00 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD4 -321 - 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one - quarter mile: a) Interval exposed to open annulus: CD4 322, CD4-16, Nanuq 3, CD4 -17, CD4 -214, CD4-215, 0D4. Torok and Seabee formation, shale, siltstone and sandstone 26 and CD4 -318 " b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation . None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1650' MD / 1600' TVD None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: 35,154 bbl - 08.30.11 densities range from diesel to 12# /gal ' 2232 • 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 70,000 bbls. 4 ` 4 ."'"• 1° i 4 ` ` Vo c v Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement - contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 16. Estimated start date: act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any 15- Sep -11 • added water needed to facilitate pumping of drilling mud or drilling cuttings, and other substances that the commissioner determines on application are wastes associated with the act of drilling a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) El Cement Bond Log (if required) ❑ FIT Records w /LOT Graph 111 Surf. Casing Cementing Data ❑ Other ❑ previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the 11 is true and correct to the best of my knowledge. /// \ Signature: 4 f A.A. Title: k () - X t+'7 �e , ._- Printed Phone j Name: Chip Alvord Number: 265 -6120 Date: 8/30/11 Commission Use Only Conditions of approval: LOT review and approval: 7 // Subsequent form re. ' ed: ® O' Approval number: 3t t `191' APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 9..8.-# R8DMs3. 0 ;. 1 re: 1e ° j.7. i STRUCTIONS ON REVERSE 0R1G1NAS i t in licate ).r // SURFACE CASING SHOE SEPARATION FROM CD4 -321 a s CD4 -321 x Y Surface Casing Shoe ASP 4 Coordinates NAD 27. 375795.28 5956945.38 uistance Ann. from Surface csg. Surface csg. Surface Details @ Disp. Ann. Object Shoe X Shoe Y Surf LOT casing TVD Annular Wells AOGCC ** Permit # Permit Date Source well Vol. Start Date End Date well* Coord. Coord. (ppg) (ft) LOT (ppg) Comments CD4 -07 n 1430 376700.4 5958052 5 16.7 2396 15.4 CD4 -16 We°i 954 376571.7 5957499.3 18.1 2388.5 17.90 Not for annular disposal, due to proximity to Nanuq 3 CD4 -17 y 679 376416 3 5957221.0 18.1 2386.93 16 2 Not for annular disposal, due to proximity to Nanuq 3 D4 -318a, D4 -320, D4 -214, CD4 -208 y 306 -183 5/30/2006 CD4- 321,CD4 -211 61839 7/3/2006 1/4/2007 2344 378134.12 5956792.58 16.3 2440.26 14.4 volume extension to 70000 bbl, permit #306 -266 CD4 -209 ©M%11 Milliiiill 2175 377935.02 5957333.89 14.7 2376.79 17.5 Not for annular disposal CD4 -210 ©PI �_ 1752 377547.47 5956963.14 18.0 2385.97 17.3 CD4 -211 y 306 -392 12/29/2006 D4 -302, CD4 -16 31937 6/20/2007 7/11/2007 1652 377354 32 5957492.92 18.1 2400.1 15.0 2nd annular LOT, 1st ann test @18.4 ppg Not for annular disposal. High Ann test Probably ice plug, CD4 -213 y 1687 377441.38 5956577.89 18.1 2400.5 21 40 will retest if needed 04 CD4 -214 y 1221 377016.49 5956949.56 17.3 2400.8 17.6 Not for annular disposal CD4 -215 y WINii11 _, . --"" 967 376762.06 5956914.11 17.6 2400.4 17.50 Not for annular disposal 307 -257 / 9/6/2007 Extended volume to 70,000 (64,000 bbls) 5/20/2009, CD4 -302 y 309 -167 5/20/2009 CD4 -304, CD4 -05 32006 10/21/2007 12/6/2007 3481 379247.67 5957393.4 18.1 2390 43 17.10 second ALOT was 15.5ppg 5/27/2009 CD4 -304 n -r 1772 377304.4 5957874 3 16.6 2391 17 8 Not for Annular Disposal • CD4 -306 y 307 -258 9/6/2007 CD4 -304, C04 -07 28330 9/11/2007 10/21/2007 1863 377262.19 595809322 18.0 2376.29 1490 CD4 -318 y 306 -181 5/26/2006 CD4 -209, CD4 -320 942 5/31/2006 8/2/2006 724 376138.31 5956308.17 18.2 2375.32 17.1 Unable to pump- SD pumping CD4 -208, CD4 -318, CD4 -209, CD4 -319 y 305 -373 12/9/2005 CD4 -320 32010 12/14/2005 7/2/2006 1799 377174.72 5955790.44 18.4 2396.47 161 CD4 -320 y -- ■- 2418 377915.36 5958108.91 17.1 2387.33 17 8 Not for annular disposal CD4 -321 y 306 -393 9/23/2010 CD4 -306, C04 -322 31117 7/14/2007 8/20/2007 0 375795.28 5956945 38 18.0 2385.47 16.3 Extension permit filed for 70,000 BBLS CD4 -322 y 307 -293 10/25/2007 CD4 -301, CD4 -05 30832 12/8/2007 1/10/2008 795 375674.64 5957731 19 18.0 2385.44 16.8 Nanuk 1 n ,- j_-"" ��' Exploration P &A'd Nanuk 2 n / �ipillIll■ ,�." Exploration P &A'd -�'►" the su rf a ce, X-Y location calculated at 2400' TVD, NOT Nanuq 3 y 1299 377015.63 5957391 42 11.8 1774.97 the surface shoe de th Nanu. 3 2400" TVD 111 M1111111111111111111111.."-- 828 376499.3 5957380 8 To show .roximit to Nanu. 3 at 2400' TVD Nanu. 5 �' WaI1 1 - 2627 378326.61 5956241.68 14.9 2393.75 15.1 Not for annular disposal CD4 -301 3747 379541 0 5957028.4 14 8 2387 13.5 CD4 -05 �_. 1493 377233.4 5957348.0 18 2 2388 16 5 Not for AD (too close to Nanuq 3) CD4 -25 1371 376993.5 5956278.8 17.8 2393 15 9 CD4 -26 n ® 376757.1 59567651 18.0 2389 17.2 CD4 -24 377321.7 5956140.6 16.2 2389 15.1 Planned CD4 -298 NMI �-- 3908 379658.20 5957535.10 2390 13.9 CD4- 03wp04 - 2587 378180 32 5955942.15 Not for annular disposal CD4- 27wp07 1492 ' 376803.42 5955845.33 Not for annular disposal * Lateral distance in feet, between surface casing shoes, in the X -Y plane **As of April 21, 2008 Note that this sheet is not the definitive record for annular disposal volumes • - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ❑ Service 11111 6. Permit to Drill Number: 206 -142 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD4 -321 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG 0 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20536 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ❑ or Continuation El or Final ❑ 310 -320 9/23/2010 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement - contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous totals (bbls): 30632 100 385* 31117 2010/3rd 0 0 0 0 0 2010 / 4th 178 100 137 415 2 12/19/2010 12/20/2010 CD4 -298 2011 / 1st 0 0 0 0 0 2011 / 2nd 3522 100 0 3622 5 6/5/2011 6/14/2011 CD -208A Total Ending Report is due on the 20th Volume 34332 300 522 35154 7 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ fourth quarter. 12. Remarks and Approved Substances Description(s): * r freeze protect volumes only, JO ��� I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: A-6- iO( Date: - g6 f 2.o U Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 Form 10 -423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 07, 2011 TO: Jim Regg e , Y// u P.I. Supervisor ( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4 -321 FROM: Matt Herrera COLVILLE RIV NAN -K CD4 -321 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry C - NON- CONFIDENTIAL Comm Well Name: COLVILLE RIV NAN -K CD4 -321 API Well Number: 50- 103 - 20536 -00 -00 Inspector Name: Matt Herrera Insp Num: mitMFHI 10701085800 Permit Number: 206 -142 -0 Inspection Date: 6/30/2011 Rel Insp Num: Packer Depth Pretest i Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD4 -321 'Typelnj, i G ' TVD G 7180 - IA 1030 2575 ' 2558 2554 '! P.T.D 2061420 ' TypeTest SPT Test psi I 1795 , OA 750 860 840 820 Interval 4YRTST _ - P/F P - Tubing 3881 3889 3906 I 3909 Notes: IA tested to 2550 psi 2.4 BBL's ' ; . w „ 4 � I JUL - ')(11 ;d :d'Ssi.S Thursday, July 07, 2011 Page 1 of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1, Operator: 4a. Well Class: Stratigraphic ❑ Service © 6. Permit to Drill Number: 206 -142 ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 7. Well Name: CD4 -321 2. Address: 4b. Well Status: Oil ❑ Gas ❑ WAG 0 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ❑ WINJ ❑ WDSPL ❑ 50 -103- 20536 -00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9, Field: Initial Disposal ❑ or Continuation B or Final ❑ 310 -320 9/23/2010 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement- contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and • any necessary water added totals Previ(bbls): 30632 100 385* 31117 2010 / 3rd 0 0 0 0 0 2010 / 4th 178 100 137 415 2 12/19/2010 12/20/2010 CD4 -298 2011 / 1st 0 0 0 0 0 2011 / 2nd Total Ending Report is due on the 20th • volume 30810 200 522 31532 2 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ❑ Step Rate Test ❑ October 20 for the third quarter, and January 20 for the Other (Explain) ❑ r fourth quarter. 12. Remarks and Approved Substances a f Description(s): *freeze protect volumes only I hereby certify that the foregoing is tr and correct to the best of my knowledge. t Signature: 4 Date: 4( ti- (24) U Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265 -6120 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate W ecurity Level: AK Development j "a m Daily Drilling Report CD4 -26 Report Number: 19 Rig: DOYON 19 Report Date: 5/15/2009 AFE Type. NetworkllD # Total AFE +Sup " .�, „ _ 10252964 12,430 000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD4 - 26 Development ALPINE 16.88 19.0 0.00 16,581.0 16,581.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 2,000.00 553,508.65 1,090,046.00 1 5,422,726.65 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 4/27/2009 4/29/2009 36.91 34.49 2.42 5/31/2009 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 2,802.OftKB Ops and Depth @ Morning Report 24hr Forecast Cementing 7 5/8" csg Finish cementing csg - Test BOPE - LD 5" DP Last 24hr Summary Cont. Running 7 5/8" csg f/ 1701' to 16,088' ( 380 its of 390 its to run) Circ & conditon @ 2821'- 6770'- 10,765'& 14,370'- SO wt. down to 90 k @ 15442'- worked casing down f/ 15,442' to 16,088'- SO wt. 125 to 90 k General Remarks Weather Head Count No Accidents - No spills 19/8 we /E @10 mph/ Vis 10 mi 50.0 °= Supervisor' Fred Herbert, Rig Supervisor Rig Supervisor ~ }-- Don Mickey, Rig Supervisor Rig Supervisor Dave Egedahl, Rig Engineer Rig Engineer Start End 1P iu" p ' Time Time (hits) , .Y Phase 4p Code Aetiviy Cade R -T X fm }e trbl Code: Trbl Class € 8} (ftKB) < < ppeFaiion 00:00 00:45 0.75 INTRM1 CASING RNCS P 1 2,821.0 Continue RIH w/ 7 5/8" 29.7# L -80 MBTC casing f/ 1,701' to 2,821' ( 66 its total in hole) PU =140K. SO =130K. 0045 01:15 0.50 INTRM1 CASING CIRC P 2,821.0 2,821.0 Circ casing volume - Stage pumps up to 6 bbl /min @ 350 psi - PU wt 140 So wt 130 01:15 05:15 4.00 INTRM1 CASING RNCS P 2,821.0 6,770.0 Cont. RIH 7 5/8" 29.7# L -80 MBTC csg f/ 2,821' to 6,770' ( 160 its. total in hole) PU wt. 215 SO wt. 140 Installed 1 tandem rise centralizer per it f/ it # 83 to it # 106 (arcoss Albian 96 - Nanuq) 05:15 06:15 1.00 INTRMI CASING CIRC P 6,770.0 6,770.0 Circ btms up + @ 6770'- stage pump up to 6.5 bbl /min @ 580 psi - PU wt. 210 SO wt 140 06:15 10:45 4.50 INTRMI CASING RNCS P 6,770.0 10,348.0 Continue RIH w/ 7 5/8'29.7# L -80 BMTC casing f/ 6770' to 10,765' (255 its total in hole) Installed Hallibutron stage collar top of it # 208 - Ran 1 Straight blade rigid centralizer on its # 208 to # 234 10:45 12:30 1.75 INTRM1 CASING CIRC P 10,348.0 10,348.0 Circ btms up + Stage pump up to 6 bbls /min @ 570 psi - PU wt. 285 Sowt. 145 12:30 17:00 4.50 INTRM1 CASING RNCS P 10,438.0 14,370.0 Cont. RIH w/ 7 5/8" 29.7# L -80 MBTC casing f/ 10,765 to 14,370' ( 340 its total in hole) PU wt. 400 SO wt. 155 Installed Straight blade centralizers on its #'s 326,327,328, then every other it f/ 330 to 340 17:00 19:30 2.50 INTRM1 CASING CIRC P 14,370.0 14,370.0 Circ btms up + @ 14,370'- Stage pump up f/ 3.5 bbls /min @ 580 psi to 6 bbls /min @ 650 psi - PU wt 345 SO wt 160 Latest BOP Test Data e Comment 5/2/2009 ITWst BOPS as Follows: Annular Preventer U 250/2500 Psi; Upper, Lower and Blind Rams t/ 250/3500 Psi; Tested Dart, TIW Choke Page 1/2 Report Printed: 9120/2010 IM Security Level: AK Development f" �o'lh�l�'I� illliih , fir w . _ Daily Drilling Report CD4 -26 HI Report Number: 19 Rig: DOYON 19 Report Date: 5/15/2009 Tinri Start End Dur. Time Depth Start Depth End Time Time _ (hr$Y- , Phase Op Code Activity Code P -T -X Trbl Code Trbl Class. (ftKB) (ftKB) 0i 19:30 00:00 4.50 INTRMI CASING RNCS P 14,370.0 16,088.0 Cont. RIH w/ 7 5/8'29.7# L -80 MBTC casing f/ 14370' to 15,442'- SO wt down to 100 k - Worked casing down f/ 15,442' to 16,088'- SO wt. 90 to 125 k ( 380 jts of 390 jts to run in hole) installing straight blade centralizers every otherjt 342 to 380 Mud Check Data YP Cate Get (10s) Gel (10m) Gel (30m) HTNP Fitt - Density Temp R Solids, Corr - Type Depth (ftK ns B) "De (tb /gat V9s (s/qt) PV Calc (cp) (Ibf 11001ft -) (Ibf /100R') (Ibft100tt') (lbf /100fF) MBT (Ibrobl) (MU30miny pl{ LSND w/ 16,581.0 10.00 39 11.0 17.0 7.0 8.0 9.000 20.0 9.1 11.0 Inhibycol In ection Fluid Fkutd Source I From Lease ,(bbl) I Destination Vendor Manifest Number Note Drilling Mud WBM CD4-26 560.0 CD1 -19 JASRC 1324372,324373 We[lbores Wellbore Name Wellbore API /UWI CD4 -26 501032060000 Section Size (in) Act Top (ftKB) Act Sim (ftKB} Start Date End Data' COND1 24 37.0 114.0 4/29/2009 4/29/2009 SURFAC 131/2 114.0 2,812.0 4/29/2009 4/30/2009 INTRM1 97/8 2,812.0 16,581.0 5/3/2009 5/13/2009 PROD1 63/4 16,581.01 24,749.0 5/20/2009 5/25/2009 Page 2/2 Report Printed: 9/20/2010 ~ ~ ,~ : ~: ~ ,~ ~, - ,~, ~'`~r ~ _. ~ .~ ~. ,t~~ ~ ~~ MICROFLLMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS .PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~ • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, July 29, 2009 Jim Regg ~ P.I. Supervisor ~~ -Z j~'b~ SUBJECT: Mechanical Integriry Tests 1 CONOCOPHILLIPS ALASKA INC CD4-321 FROM: Bob Noble COLVILLE RIV NAN-K CD4-321 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~,~-- Comm Well Name: COLVII.LE RN NAN-K CD4-321 Insp Num: mitRCN090729094629 Rel Insp Num: API Well Number: so-io3-2o535-00-0o Permit Number: 206-142-0 ~ Inspector Name: Bob Noble Inspection Date: ~~3/2009 Packer Depth Pretest Initial 1S Min. 30 Min. 45 Min. 60 Min. Well cDa-32~ Type Inj. G TVD 7180 IA 1695 z~zo 2~~0 2~~0 P.T.D zo6iazo TypeTest SPT Test psi z72o OA ~oo ~30 ~zs ~zo Interval 4YRTST P~' P ~ Tubing 3495 3495 3500 3500 Notes: d°~I\~ ~- `~ ~~ ,~~`,~LU'~ ~ L l S~Si , .,.~~~ ,' ..o.~ :a~ _ . ~~~~,~~ Wednesday, July 29, 2009 Page 1 of 1 ConocoPhillips ~~~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 19, 2008 ;; ,_ ~~ MAC ~. ~ 2.U~ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: C~ ~~~~ ~~! Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped March 18~', 2009. 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. Sinc Perry nicui ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Alpine Field Date 3/19/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al CD4-301 B 207-180 SF NA 7" NA 2.55 3/18/2009 CD4-302 207-056 28" NA 28" NA 22.95 3/18/2009 CD4-304 207-132 8" NA 8" NA 1.70 3/18/2009 CD4-05 207-155 SF NA 7" NA 1.70 3/18/2009 CD4-306 207-094 SF NA 5" NA 1.70 3/18/2009 CD4-07 207-118 SF NA 6" NA 0.42 3/18/2009 CD4-208 205-162 SF NA 7" NA 1.27 3/18/2009 CD4-209 206-065 SF NA 6" NA 0.85 3/18/2009 CD4-210 206-077 SF NA 7" NA 1.27 3/18/2009 ` CD4-211 ' 206-153 9" NA 9" NA 3.82 3/18/2009 CD4-214' 206-145 7" NA 7" NA 2.12 3/18/2009 CD4-215 ~ 206-157 5" NA 5" NA 2.55 3/18/2009 CD4-16 206-131 SF NA 5" NA 2.55 3/18/2009 4-17 206-118 SF NA 11" NA 1.27 3/18/2009 CD4-318A 206-113 7" NA 7" NA 1.70 3/18/2009 CD4-319 205-148 SF NA 7" NA 1.27 3/18/2009 CD4-320 206-055 6" NA 6" NA 0.85 3/18/2009 CD4-321• 206-142 SF NA 8" NA 1.70 3/18/2009 CD4-322 207-101 SF NA 5" NA 1.27 3/18/2009 z6 ~~1r DATA SUBMITTAL COMPLIANCE REPORT 9/17/2008 Permit to Drill 2061420 Well Name/No. COLVILLE RIV NAN-K CD4-321 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20536-00-00 MD 19337 TVD 7811 Completion Date 10/26/2006 Completion Status WAGIN Current Status WAGIN C Y REQUIRED INFORMATION Mud Log No Samples No Directional Surv Yes DATA INFORMATION Types Electric or Other Logs Run: GR / RES /DENS /NEUTRON, CBL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / type n-rmt rvumoer Name Scale Media No Stan. Stop CH Received Comments C Lis 14221~tion/Resistivity 3476 19337 Open 11/9/2006 LIS Verification GR, FET, NPHI, NCNT, RHOB, / DRHO, FCNT, ROP D Asc"' Directional Survey 0 19337 Open 11/9/2006 14221 LIS Verification 3476 19337 Open 11/9/2006 GR, FET, NPHI, NCNT, RHOB, DRHO, FCNT, ROP g Cement Evaluation 5 Col 1 18150 18535 Case 12/21/2006 SCMT 21-Nov-2006 JVell Cores/Samples Information: Name ADDITIONAL INFORMN Well Cored? Y N Chips Received? '47~N-- Analysis ~~ Received? Comments: Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~:.JN Formation Tops Compliance Reviewed By: Date: `I '~ u STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: 206-142 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-321 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG Q 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20536-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^ or Final Q 306-393 1/2/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 385"' 385 totals (bbls): 2007 / 1st 0 0 0 0 0 2007 / 2nd 0 0 0 0 0 2007 / 3rd 30632 100 0 30732 32 7/1/2007 8/19/2007 CD4-306, CD4-322 2007 / 4th 0 0 0 0 0 Total Ending Report is due on the 20th volume 30632 100 385 31117 32 (bbis>: of the month following the final month of the quarter. Ex: Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Descriptions>: *annular flush and freeze rotect volumes f my knowledge. best I hereby certify that the foregoing is true and correct to the o ~ . ~ ~~ ~ ~`-1°- - D t ~ ~~ ~~ ~ i e: gnature: a S Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: 206-142 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-321 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG Q 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20536-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ~ or Final ^ 306-393 1/2/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 385* 385 totals (bbls): 2007 / 1st 0 0 0 0 0 2007 / 2nd 0 0 0 0 0 2007 / 3rd 30632 100 0 30732 32 7/1/2007 8/19/2007 CD4-306, CD4-322 2007 / 4th 0 0 0 0 0 Total Enai"g Report is due on the 20th volume 30632 100 385 31117 32 (bbls>: of the month following the final month of the quarter. Ex: April 20 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Descriptions>: *annular flush and freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. ~""'1 // Signature: 1 r".s-----~--------.. Date: ~ (°t ~o~ Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: ~ ~~ " ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4'-321 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ~ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20536-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g, Field: Initial Disposal ^ or Continuation ^Q or Final ^ 306-393 1/2/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 385* 385 totals (bbls): 2007 / 1st 0 0 0 0 0 2007 / 2nd 0 0 0 0 0 2007 / 3rd 30632 100 0 30732 32 7/1/2007 8/19/2007 CD4-306, CD4-322 2007 / 4th Total Ending Report is due on the 20th volume 30632 100 385 31117 32 (bbls): of the month following the final month of the quarter. Ex: Apri120 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): "annular flush and freeze rotect volumes I hereby certify that the foregoing is tru e and correct to the best of my knowledge. l Signature: \ ~ Date: ~~~~ Co 7 Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service 0 6. Permit to Drill Number: 2(16-142 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-321 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG Q 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20536-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ~ or Continuation ^ or Final ^ 306-393 1/2/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 385* 385 totals (bbls): 2007 / 1st 0 0 0 0 0 2007 / 2nd 0 0 0 0 0 2007 / 3rd 2007 / 4th Total Ending Report is due on the 20th volume 0 0 385 385 0 (obis): of the month following the final month of the quarter. Ex: Apri120 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Descriptions>: '`annular flush and freeze protect volumes I hereby certify that the foregoin ~ true and correct to the best of my knowledge. f ~ ~5 / O ~ ~ Signature: Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL I~ 1. Operator: 4a. Well Class: Stratigraphic ^ Service O 6. Permit to Drill Number: 2-142 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD4-321 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG Q 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20536-00 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal Q or Continuation ^ or Final ^ 306-393 1/2/2007 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 385'` 385 totals (bbls): 2007 / 1st 0 0 0 0 0 2007 / 2nd 2007 / 3rd 2007 / 4th Total Ending Report is due on the 20th volume (bbls): 0 0 385 385 0 of the month following the final month of the quarter. Ex: July 20 for the second quarter Apri120 for the first quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Descriptions>: *annular flush and freeze protect volumes is t r and correct to the best of my knowledge. I hereby certify that the foregoing u e , ~' ' ~ ~ ~ `r ~' ~o Signature: l ~~^-~--~ Date: ~ Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate MEMORANDUM TO: Jim Reg; P.I. Supervisor ~ ~~''~e~ + ~ ~~~~ ~ FROlVt: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January I7, 2007 SIIBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD4-32 i COLVILLE RIV N,~V-K CD4-3zl Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: COLVILLE RIV NAN-K CD4-321 API Well Number 50-I03-20536-00-00 Inspector Name: Joh^ Crisp Insp Num: mitJCr070117054529 Permit Number: 206-142-0 Inspection Date: Lill/2007 Rel Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~~ Well c~a''-I Type Inj. w ~~', TVD ~ ISO ~ IA us '~ z3zz z3oo ~ z3oo P.T. zo6lazo ''~TypeTest I sPT ' Test psi I~9s ! OA ', 3so s~z sss j ss6 ~ -T-- Interval INIrAL p~ P J~ Tubing' Iro -- nso I?~o I%so -- NOtes ~ bbl's pumped for test. No problems. Wednesday, January 17. ?007 Page 1 of l Emailing: MIT CRU CD3 01-12-07.x1s, MIT CRU CD4 01-12-07.x1s Subject: Emailing: MIT CRU CD3 01-12-07.x1s, MIT CRU CD4 01-12-07.x1s From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Sun, 14 Tan 2007 10:30:08 -0900 `to: h~>h llechenst~in~cra~lmin.statc.ak.us, jim re~~~<<i.~idiT~in.statc.al~.us, Thomas C ~'Iaunder =toi1~ i~iaun~ler<<r'acfi7~in.st<~te.ak.us= «MIT CRU CD3 O1-12-07.x1s» Ge « MIT CRU CD4 01-12-07.x1s» ntlemen, Enclosed are the initial MITIA results for CD3-110, CD4-319, and CD4-321. Regarding the T X IA communication in CD4-321 PTD # 206-142, reported 12/23/06, the CMD was found to be in the open position. Slick Line closed the sleeve. After passing the witnessed initial MITIA I removed CD4-321 from the monthly failed MITIA report. Let me know if you have any questions. Sincerely, Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n:I.67..7 ~~?c:nnccophi.ll ips . cozr€ Content-Description: MIT CRU CD3 01-12-07.x1s MIT CRU CD3 O1-12-07.x1s Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT CRU CD4 01-12-07.x1s '',MIT CRU CD4 O1-12-07.x1s Content-Type: application/vnd.ms-excel ', Content-Encoding: base64 1 of 1 ]/16/2007 4:03 PM f 1 ~J } a ~~~ ~i iii '-,~I7'.rf 1 AI,~SSA OIL A1QD ~5 C011TSERQ~Z`I011T COrII~II5SIOIQ Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska PO Box 100360 Anchorage, AK SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ' FAX (907) 276-7542 Re: Colville River Field, Nanuq-Kuparuk Oil Pool, CD4-321 Sundry Number: 306-393 Dear Mr. Alvord: Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please °b note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not. appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of January, 2006 Encl. ~, ~,2,0~ ~ ~~ RE~~I~~D ~ ~/ ~ STATE OF ALASKA ~ DEC 1 4 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION Alaska Dil & Gas Cans. Commission 20 AAC 25.080 Anchoraae 1. Operator 3. Permit to Drill Name: Number: 206-142 ConocoPhillips Alaska 4. API Number: 50-103-20536-00 , 2. Address: 5. Well P.O. Box 100360, Anchorage, Alaska CD4-321 6. Field: Colville River Field , 7. Publicly recorded wells 8. Stratigraphic description: a) All wells within one-quarter mile: a) Interval exposed to open annulus: Nanuk 3, CD4-318, CD4-17, CD4-214 Torok and Seabee formation, shale, siltstone and sandstone b) Waste receiving zone: b) water wells within one mile: Sand layers below the C30 marker in the Seabee formation None c) Confinement: The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1720' MD / 1 600' ND ~ None 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2232 psi 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- contaminated drilling mud, completion fluids, diesel, formation fluids associated with the 1~~ stip~ated start date: ~ act of drilling a well, drill rig wash fluids, domestic waste water, any added water 1.8'Dec -06 needed to facilitate pumping of drilling mud or drilling cuttings, new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations and any other fluids associated with drilling a well. 17. Attachments: Well Schematic (Include MD and TVD)^ Cement Bond Log (if required) ^ FIT Records w/LOT Graph Q Surf. Casing Cementing Data ^~ Other ~ previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ ~ ~~" /~ Title: /~ ~#~w' (~."~ ~~~~y-. ~.~~,c~" Printed Phone t f Name: Chip Alvord Lx ~ Z ~~ ~. Number: 265-6120 Date: ~ Commission Use Onl Conditions of approval LOT review and approval ~r.~ ~~' ~©!~~ ` ~~ Subsequent form required: Approval number: ~( ),S,Q ~ . 1 Approved by: APPROVED BY COMM{SSIONER THE COMMISSION Date: j•a -D ~-~ ~ ~~ ~ / ~ 1-7 ""ZJ L Form 10-403RD Rev. 6!2004 1 ~ ~ I (~ I n ! ~ ~RUCTIONS ON REVERE Submit in Duplicate i~~ ConocoPhillips Alaska, Inc. Post Office Box 100360 ~ A ~ Anchorage, Alaska 99510-0360 ~0~~~©~~' I'' ~~ Telephone 907-276-1215 ~~~~~~~ November 20, 2006 D ~ ~ ~ ~ 2006 Alaska Oil and Gas Conservation Commission Alaska Oi! & Gas Cons. Commissian 333 West 7~' Avenue, Suite 100 Anchorage Anchorage, Alaska 99501-3539 _. Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD4-321 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD4-321 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD4-321 approximately December 25, 2006 or whenever a permit is available. Please find attached form 10-403RD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD4 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within % mile radius at AOGCC: no new wells 12. Copy of previous authorization (CD1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial annular LOT (16.3 ppg) occurred at a lower equivalent mud weight than the casing shoe test (18.0 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. If you have any questions or require further information, please contact Vern Johnson at 265-6081; Chip Alvord can also be reached by calling 265-6120. Sin y, l~~ 0%6 v U Vern Johnson Drilling Engineer cc: CD4-321 Well File Chip Alvord ATO-1700 Anadarko Sharon Allsup-Drake ATO-1530 • • Annulus Disposal Transmittal Form -Well CD4-321 AOGCC ReQUlations, 20 AAC 25.080 (b) 1 Desi nation of the well or wells to receive drillin wastes: CD4-321 2 The depth to the base of freshwater aquifers and permafrost, i There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = +/-1600' TVD RKB 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission fording that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/1. (Ref. AOGCC Conservation Order No. 443, 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within 1/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin waste. 5 Identify the types and maximum volume of waste to be Types of waste maybe drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipement after producing drilling/completion fluid (see included note from CD 1 &2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2232 psi. See attached calculation calculations showin how this value was determined. a e. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT /FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N/A de th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N/A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD4-211, CD4-16, CD4-215, CD4-207, CD4-205, CD4-213, will be enerated. CD4-212 CD4-203 CD4-204 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why com liance would be im rodent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. Pressure Calculations for Annular Disposal (for submital with Annular Disposal Application) v~~°~t.o-i~a~os Well CD4-321 Assumptions Date 11/20/2006 Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure (for wells on gas lift) 1,000 psi on •H Maximum Fluid Density to avoid Burst of Surface Casing U Pburst85% - PHydrostatic +PApplied - PFormation 4,888 = ( 2,385 * 0.052 * MW~ ) + 1500 - (0.4337 * 2,385 ) N a MWmax = 35.7 PPg 2,385 TVD Surface Casing String Size 9.625 in ~ ~ Weight 40 ppf Grade L 80 on ~ ~ ~ rburst100% 5,750 Pst .~ TOC Est. 2 8,272' M Pburst85% 4,888 psi U 3,959' TV Depth of Shoe 2,385 ft FIT/LOT @ Shoe 18 ppg or 2,232 psi FIT/LOT for Annulus 16.3 ppg c Max Surf. Pressure 1,500 psi Maximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% - PHydrostatic +PApplied - PGasGradient - PHeader 4,599 = ( 3,959 * 0.052 * MW~ ) + 1,500 - (0.0700 * 3,959) - 1,000 MWmax = 21.3 PPg a.s "Tubing 2nd Casing String Size 7 in 7,810 TVD Weight 26 ppf Grade L 80 rcollapsel00% 5,410 psi Pcollapse85% 4,599 pSi Top of Cement 3,959 ft Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable =Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable - ( 2,385 * .052 * 18 ) Pmax allowable - 2,232 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". ConocoPhilli s p Casing Detail 9 5/8" Surface Casing • Well: CD4321 Date: 10/8/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.65 FMC Gen V Hanger 2.19 36.65 Jts 3 to 90 88 Jts 9-5/8" 40# L-80 BTC Csg 3383.38 38.84 Halliburton Float Collar 1.12 3422.22 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 78.41 3423.34 Ray Oil Tools "Silver Bullet" Float Shoe 2.26 3501.75 3504.01 TD 12 1/4" Surface Hole 3514.00 12 1/4" hole 3514' MD - 2389' TVD 9 5/8" csg shoe 3504.01' MD - 2385' TVD TOTAL BOWSPRING CENTRALIZERS - 51 1 per jt on Jt #1 - #13 (stop ring on Jt #1 8~ 3 ) and over collars on jts# 15, 17, 19, 21, 23, 25, 27, 29, 31, 33, 35, 37, 39, 41, 43, 45, 47, 49, 51, 53, 55, 57, 59, 61, 63 65, 67, 69,71,73,75,77,79,81,83,85,87,89 98 joints in the pipe shed. 90 jts to run -Last 8 jts out Use Best-o-Life 2000 pipe dope All joints drifted - 8.781" MU torque ~ 8600 ft/Ibs Remarks: Up Wt -195 k Dn Wt - 127 k Block Wt - 75k Supervisor: Lutrick /Hill r-~ ~ Cement Detail Report CD4-321 Surface Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10146270 10/4/2006 10/5/2006 - - --_ _ - - - -- Cement`Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 10/8/2006 21:30 10/7/2006 23:50 CD4-321 Comment Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/ nut plug as marker w/ rig pumps -Line up Dowell & pump 10 bbls CW-100 -Test lines to 2500 psi -Pumped 30 bbls CW-100. Mix & pump 50 bbls MudPush @ 10.5 ppg @ 5 bbl/min @ 210 psi -Mix & pump Lead slurry (ASL) @ 10.7 ppg @ 7.5 bbls/min @ 230 psi -Observed nut plug marker @ shakers w/ 381 bbls lead slurry pumped -pumped down surge can - 391 bbls lead slurry pumped - Switched to tail slurry (G w/ 1 % -S002, .20% D046, .30% D065) Mixed & pumped 48 bbls @ 15.8 ppg @ 5.4 bbls/min @ 250 psi -dropped top plug & chased w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced w/ 9.8 ppg mud @ 7 bbls/ min for 220 bbls (400 to 700 psi) slowed pump to 4 bbls/min for last 19.7 bbls of displacement (500 to 600 psi) 240 bbls total displacment -Bumped plug w/ 1100 psi -Checked floats OK -CIP @ 2350 hrs. -Full circulation throughout job w/ 160 bbls 10.7 ppg cmt to surface - -- - Cement Stages - - -- - -- ---- - Stage # 1 - - -- - -' Description ©b)ective Top (ftK6) Bottom (ftK6) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement Cement to Surface. 0.0 3,504.0 No 160.0. Yes Yes Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 7 570.0 1,100.0 Yes 20.00 N o Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) Comment Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/ nut plug as marker w/ rig pumps -Line up Dowell & pump 10 bbls CW-100 -Test lines to 2500 psi -Pumped 30 bbls CW-100. Mix & pump 50 bbls MudPush @ 10.5 ppg @ 5 bbl/min @ 210 psi -Mix & pump Lead slurry (ASL) @ 10.7 ppg @ 7.5 bblslmin @ 230 psi -Observed nut plug marker @ shakers w/ 381 bbls lead slurry pumped -pumped down surge can - 391 bbls lead slurry pumped - Switched to tail slurry (G w/ 1 % -S002, .20% D046, .30% D065) Mixed & pumped 48 bbls @ 15.8 ppg @ 5.4 bbls/min @ 250 psi -dropped top plug & chased w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced w/ 9.8 ppg mud @ 7 bbls/ min for 220 bbis (400 to 700 psi) slowed pump to 4 bbls/min for last 19.7 bbls of displacement (500 to 600 psi) 240 bbls total displacment -Bumped plug w/ 1100 psi -Checked floats OK -CIP @ 2350 hrs. -Full circulation throughout job w/ 160 bbls 10.7 ppg cmt to surface -_ -- --- Cement Fluids & Additives --- _ - T _ - - ---- Fluid; Fluid Type Fluid Description Estimated Top (ftK6) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 36.6 2,980.0 493 G 391.0 Yield (ft"ISack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.45 20.77 10.70 Additives Additive Type Concentration Conc Unit label 'Fluid -- - - - _- - - Fluid Type Fluid Description Estimated lop (ftK6) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,980.0 3,504.0 48 G 48.0 Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label Page 1/2 Report Printed: 11/20/2006 r~ ~ Cement Detail Report CD4-321 Surface Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date Drilling Support -Capital Well Intervention 10146271 11/17/2006 11/18/2006 Page 2/2 Report Printed: 11/20/2006 ~~ Daily Drilling Report CD4-321 ~. ,.,, Report Date: 1018/2006 Report Number Days From Spud (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 5 3.29 3,514.0 3,514.0 0.00 CD4-321 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftKB) 10/5/2006 DOYON 19 NANUQ KUPARUK Development 19,604.0 AFE / RFE I Maint.# Total AFE Amount Average ROP (ft/hr) 10146270 6,964,464.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 3,504.OftK6 Ops and Depth @ Morning Report Daily Cost Total Cummulative Cost Nippling up BOP. 319,501.28 1,055,169.35 24hr Forecast Daily Mud Cost Cummulative Mud Cost NU and test BOP. LD 4" DP & PU 5" DP. 6,151.28 57,347.35 Last 24hr Summary Finished wiper trip. Circ hole clean. POOH and laid down BHA. RU and ran 90 Jts 9 5/8" casing and cemented same. General Remarks Weather Head Count 28 NE 38-57 mph 46.0 _ Superv!sor..__ - Donnie Lutrick Larry Hill !Time Loa --, Cle 'Rig Supervisor Rig Supervisor `-Start End p.-!~ -.. __-I Time- ------- _... - li ~•h Stmt Del;ih-~ Er~.J '. Tome Time (?'ors) F!-ase Op r;ade OpSuk-Co 'RN TI Trbl Code T.bi lass nKB:~ !fiF:H! C _ rJOperfio~. 00:00 00:30 0.50 SURFAC DRILL WPRT P 2,895:0 3,452.0 RIH from 2895' to 345`L'. 00:30 01:30 1.00 SURFAC DRILL CIRC P 3,452.0 3,514.0 Break circulation. Wash to 3514'. Circulate hole clean at 650 gpm and 40 rpms. 01:30 08:00 6.50 SURFAC DRILL TRIP P 3,514.0 250.0 POH on trip tank to 850'. Slight swabbing. RIH w! 3 stds. Pump out 7stds at 3 bpm to 474'. Stand back HWDP. No hole problems. 08:00 10:00 2.00 SURFAC DRILL PULD P 250.0 0.0 Std back NMFC and jars. Download MWD. LD BHA #1 10:00 12:00 2.00 SURFAC CASING RURD P 0.0 0.0 RD DP equipment. RU csg equipment. 12:00 15:30 3.50 SURFAC CASING RNCS P 0.0 1,924.0 PJSM. Ran 50 jts 9 5/8" 40# L-80 BTCM casing 1,924'. 15:30 16:30 1.00 SURFAC CASING CIRC P 1,924.0 1,924.0 Circulated Casing working up to 4.5 BPM 1CP 400 psi FCP 330 psi. 16:30 19:30 3.00 SURFAC CASING RNCS P 1,924.0 3,504.0 PJSM. Ran 40 jts 9 5/8" 40# L-80 BTCM casing 3,465'. Made up landing jt and landed casing @ 3,504'. Laid down Franks tool and made up cement head. 19:30 21:30 2.00 SURFAC CEMENT CIRC P 3,504.0 3,504.0 Circulated Casing working up to 7 BPM ICP 570 psi FCP 340 psi. 21:30 00:00 2.50 SURFAC CEMENT DISP P 3,504.0 0.0 Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/ nut plug as marker w/ rig pumps -Line up Dowell & pump 10 bbls CW-100 -Test lines to 2500 psi -Pumped 30 bbls CW-100. Mix & pump 50 bbls MudPush @ 10.5 ppg @ 5 bbl/min @ 210 psi -Mix & pump Lead slurry (ASL) @ 10.7 ppg @ 7.5 bbls/min @ 230 psi -Observed nut plug marker @ shakers w/ 381 bbls lead slurry pumped -pumped down surge can - 391 bbls lead slurry pumped -Switched to tail slurry {G w! 1 -S002, .20% D046, .30% D065) Mixed & pumped 48 bbls @ 15.8 ppg @ 5.4 bbls/min @ 250 psi -dropped top plug & chased w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced w/ 9.8 ppg mud @ 7 bbls/ min for 220 bbls (400 to 700 psi) slowed pump to 4 bbls/min for last 19.7 bbls of displacement (500 to 600 psi) 240 bbls total displacment -Bumped plug w/ 1100 psi - Checked floats OK - CIP @ 2350 hrs. -Full circulation throughout job w/ 160 bbls 10.7 ppg cmt to surface Latest BDP Test Data --- -- -- --_ - _ --- r, ~r,.r.~,.t ~,~~c Page 1/2 Report Printed: 11/20/2006 i Daily Drilling Report CD4-321 Report Date: 10/8/2006 Mud Check Data --- -- T;;~r U.-. th (11 kt Deii.'b a~I~ Spud Mud 3.514 0 9 85 fP Ca ~ gel 1Js) ~ 1 im) ",!mii ~ ~~ HTHP Fdt Density Tem .Vi~~~t '. PJ l;alc (c,i 'S81U?tt7 bil U':rft') k r.ft=1 ilt ~~Ot1'1 MBt (i~m~l ~ i~L m;n; ;~H Ft 73 28.0 22.000 13.000 36 000 54.000 325 2-8 I ~ ~ a Sotids, Corr_ _ `%) 10.0 - -- In ectton Fluid _ _ F!cid -- DIBSeI ~ ~ -- - _ _ --~~ u~~e - - - _- ~ ( I Fr,rnLease bbl 1 U Destinatio- T Note -~--- ~(.D4 z08 __ (From CD4-321 __ _ - 'Dri11 Strin s: $HA No. 1 -Surface / Bit Run No. i - - 12 114in, Hu hes Christensen, MXL-1, 6044769 _ Depth In (ftK6) Depth Out (ftK6) TFA (incl Noz) (in') Nozzles (/32") IADC Bit Dutl String Wt (10001bf) WOB (max) (100... WOB (min) (1000... 114.0 3,514.0 0.75 12/16/18/16 2-4-WT-G-E-1-NO-TD 44 0 0 Drill Strin Components _ dts Stem Descripfion _ T ~ OD (in) ID (in) Top Conn Sz (in) Top Thread _ ~- _ - Cun~ Le^ (ft) - -.. Motor with Stabilizer 8 4.947 6 5/8 H 90 30.03 Float Sub 7 7/8 3.000 6 5/8 H 90 32.24 Stabilizer 8 2.875 6 5/8 H 90 37.83 MWD (DM) 7.99 3.000 6 5/8 Reg 48.71 MWD (HCIM) 7.98 1.920 6 5!8 Reg 57.35 MWD (TM) 8.02 3.250 6 5/8 H 90 67.17 UBHO 8 3.500 6 5/8 H 90 69.67 NMDC 7 1/2 2.813 6 5/8 H 90 100.27 NMDC 7 3/4 2.813 6 5/8 H 90 128.90 Drilling Jars -Mechanical 7 3/4 2.750 4 1/2 IF 163.18 HWDP 5 3.000 41/21F 886.39 _ - tDrillin Parameters - _ -- - - ~nw q Start (ft KB) Enj fIKB) hrs 1 ime Sliding Hrs i t {miNFt) f;urr Dri Cur DPr~ih tft li~nc; ~~ =~ I~t Dep[h eft ~Fm) 'JU8 ~.It~'I RPM (rpm) SPF it sit Drll Ta 3,514.0 8 514.01 3,40QOU 31 83 0 00 600 30.0 60 _ _L - 8 500.0 -- - Wellbores -- - - - - Wellbore Name Wellbore API/UWI CD4-321 501032053600 ;action S¢e [nl Act Top (RKB~ ~ Act Btm (ftK6; Stan Date End Dafe PROD1 6 1/8 COND1 16 0.0 114.0 10/4/2006 10/4/2006 SURFAC 12 114 114.0 3,514.0 10/5/2006 10/7/2006 INTRM1 8 3/4 3,514.0 19,337.0 10/11/2006 10/17/2006 __ 'Cement ---__ _ - _ __ ____ Surtace Casin Cement -Started 10/8/2006 Type Wellbore String Cement Evaluation Results casing CD4-321 Surface, 3,504.OftKB 160 Bbis to surface. Stg No. Description Top (ftK6) Bottom (ftK6) Q (end) (bbl/... P (final) (psi) 1 Surface Casing Cement 0.0 3,504.0 4 570.0 ___ - - Flwd Class __ - Arrwunt{saris) V robl) Den:.itc ht~ all , ~ F:1--- -- Esf r r:e ~_ Est Btm Y.e.d rYt r ! (ftKB1 ~, Lead Cement G _ 493 391.0 10.70 _ 4.45 36.6 2,580.0 Tail Cement G 48 48.0 15.80 1.17 2,980.0 3,504.0 Page 2/2 Report Printed: 11/20/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-321 Rig: Doyon 19 Date: 10/11/2006 Volume Input Volume/Stroke Pum ~ Rate: Drilling Supervisor: Lutrick/Mickey Pump used: ~ #z Mud Pump. ~ strokes I - 0.1000 Bbls/strk I ~ 8.00 strk/min ~ Type of Test: openholeTest LOT/Frr I ~ Pumping down ~~ drillpipe. ~ Casin Test Pressure Inte rit Test Hole Size: $-3/4" ' ~ Casin Shoe De th Hole De th Pum in Shut-in Pum in Shut-in RKB-CHF: 36.7 Ft 3504.0 Ft-MD 2385_.0 Ft-TVD 353.4_ .0 Ft-MD 2395.0 Ft-TVD Strks psi Min psi Strks si Min psi Casing Size and Description: ' 9-5/8" 40#/Ft L-80 13TC ~ ~ 0 0 2500 0 20 0.00 1020 Casin Test Pressure Int e rit Test 2 50 1 2500 1 30 0.25 960 Mud Weight: 9.8 ppg Mud Weight: 9.6 ppg 4 110 2 2500 2 55 0.50 910 Mud 10 min Gel: 21.0 Lb/100 Ft2 Mud 10 min Gel: 23.0 Lb/100 Ft2 6 240 3 2500 3 140 1.00 850 Test Pressure: 2500.0 psi Rotating Weight: ####### Lbs 8 460 4 2500 4 240 1.50 8" Rotating Weight: ###### Lbs Blocks/Top Drive Weight: 74000.0 Lbs 10 650 5 2500 5 340 2.00 7 Blocks/Top Drive Weight 74000.0 Lbs Desired PIT EMW: 18.0 ppg 12 800 6 2500 6 .440 2.50 780 _ Estimates for Test: 2.3 bbls _ Estimates for Test: 1042 psi 1 bbls 14 975 7 2500 7 _ 525 3.00 765 ~ ~ ~ 16 1100 8 2500 8 630 3.50 750 _ EMW =Leak-off Pressure + Mud Weight = 1045 + 9 6 PIT 15 Second 18 1250 9 2500 9 700 4.00 745 . 0.052 x TVD 0.052 x 2385 Shut-in Pressure, psi 20 1400 10 2500 10 765 4.50 745 EMW at 3504 Ft-MD (2385 Ft-ND) = 18.0 960 22 1570 15 2500 11 820 5.00 740 3000 -Lost 0 psi during test, held 100% 24 1750 20 2.500 12 860 5.50 740 --_-- of test pressure. 26 1900 25 2500 13 890 6 00 735 . - 28 2150 30 2500 14 930 6.50 735 z5oo -- - - 30 2300 15 960 7.00 735 _ 32 ?510 16 . 990 7.50 730 17 1020 8 00 72 zooo - - -- . 5 18 1045 8 50 725 w . ~ - - 9.00 725 ~ X500 9.50 725 w - --- ~~ -- _ _ 7 ~ = - a 0 ~=~ 'S ~~ --- iooo -- ~ - ; --- - --- - - -_ _~ _ _` _'" - - ` ~ - - - -- - 500 - - - -- - 0 o , z s a o s ,o ,s zo zs so Barrels Shut-In time, Minutes 'CASING TEST tLEAK-OFF TEST O PIT Point Vol PUm ume ed Vol Bled ume Back Vol PU ume m ed Vol Bled ume Back s s s s Comments: Tested 9 5/8" csg after bumping plug on cmt. Job w i lJU4-3Ll SUrraCe Summary • • 7" Csg Detail ConocoPhillips Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM Company Well: CD4-321 Date: 10/19/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 34.40 FMC Gen V Hanger 2.65 34.40 Jts 230 to 454 225 Jts 7" 26# L-80 BTCM Csg 9475.54 37.05 Tam Port collar 2.80 9512.59 Jts 3 to 229 227 Jts 7" 26# L-80 BTCM Csg 9717.89 9515.39 Weatherford Float Collar 1.25 19233.28 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 86.49 19234.53 Ray Oil Tools "Sliver Bullet" Float Shoe 2.11 19321.02 7" Shoe @ 19323.13 8 3/4" hole TD @ 19337.00 8 3/4" hole TD @ 19,337' MD / 7810.53' TVD 7" Shoe @ 19323.13' MD / 7800' TVD Total Centralizers: 82 Straight blade centralizers one perjt. on jts. # 1-27 Straight blade cent. one per jt. on jts. # 228,229,230,231 Straight blade cent. one per jt. on jts. # 245, 246, 247, 248, 249, 250, 251, 252 Straight blade cent. one per jt. on jts. # 370,371,372 Straight blade cent. One every other jt. # 374 to 452 475 jts in shed - 454 total jts. to run Last 21 jts. Out Used Jet Lube Run-N-Seal i e do e Remarks: Up wt - Pulled to 400k unable to move pipe Dn wt - 150k Blocks - 70k Make up torque - -7800 fUlbs SupervisorD. Burley/D. Mickey r~ ~ Cement Detail Report CD4-321 Intermediate Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10146270 10/4/2006 10/5/2006 Cement Details _ Description __ _ Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 10/21/2006 05:30 10/21/2006 08:40 CD4-321 Comment Cement Stages _- -- - -- _ - _ I Sta e # T Description Objective Top (ftK6) Bottom (ftKB) Full Retum? Cmnt Rtm (... Top Plug? Btm Plug? Intermediate Casing Primary 17,850.0 19,323.0 Yes 0.0 Yes Yes Cement O (start) (bbl/min) O (end) (bbl/min) O (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 5 6 940.0 1,500.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment - - - ,Cement Fluids & Additives - -_ - - - -- - Fluid -- - Fiuitl Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Glass Volume Pumped (bbl) Tail Cement 17,850.0 19,323.0 292 G 62.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.08 15.80 Additives Additive Type Concentration Conc Unit label Sta e # 2 - ---- -- - Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtm (... Top Piug? Btm Plug? Intermediate Casing Primary 8,272.0 9,512.0 Yes 0.0 No No O (start) (bbllmin) Q (end) (bbl/min) O (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 5 5 1,000.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftK6) Amount (sacks) Class Volume Pumped (bbl) CW-100 6,269.0 7,015.0 20.0 Yield (fP/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 7 (psi) 8.30 Additives Additive Type Concentration Conc Unit label - - - - - --- Fluid __ --- -- -- - - - Fluid Type Fluid Description -_ Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push 7,015.0 7,761.0 20.0 Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid --- --- - Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftK6) Amount (sacks). Class Volume Pumped (bbl) Tail Cement 7,761.0 9,515.0 223 G 47.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label Page 1/2 Report Printed: 11/20/2006 ~1 ~ Cement Detail Report CD4-321 Intermediate Casing Cement Primary Job Type Job Category AFE / RFE Start Date Spud Date End Date Drilling Support-Capital Welllntervention 10146271 11/17/2006 11/18/2006 Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top tftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Water/Brine 0.0 9,515.0 0.3 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 2/2 Report Printed: 11/20/2006 r 1 -- ~ ~ Daily Drilling Re port CD4-321 Report Date: 10/20/2006 Report Number Days From Spud (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 17 15.29 19,337.0 19,337.0 0.00 CD4-321 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftKB) 10/5/2006 DOYON 19 NANUO KUPARUK Development 19,604.0 AFE / RFE / Maint.# Total AFE Amount Average ROP (ft/hr) 10146270 6,964,464.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 19,323.1ftK6 Ops and Depth @ Morning Report Daily Cost Total Cummulative Cost Cement 7" casing 606,095.71 4,360,771.81 24hr Forecast Daily Mud Cost Cummulative Mud Cost Finish cmt job -Set pack off - perform 2nd stage cmt job 28,584.71 661,943.81 Last 24hr Summary Run 7" csg f/ 3513' to 19,323' - Circ @ 9636' - 13,610' & 17,425' - RD csg tools RU Cmt equip. General Remarks Weather Head Count 24116 we / NE@7 mph 52.0 f?ave Burley Rig Supervisor Don Mickey Rig Supervisor Time Lo _ __ _ _ _ _ I Start End Dur Time _ _- Drrrr Stai7 _ _ _ D~F~thE J~ ~,. ~ Time (tus) I-Ids=~ Ur~C~ie u.~~,~~:;., ~~ P-NT, Trolr_ ae TrblGa~_. h~~C- ;flKPi r,-rmlOperatlon 00:00 02:UU 2.00 INTRM1 CASING RNCS P 3,513.0 5,573.0 Run 7" 26# L-80 BCTM casing f/ 3,513' to 5,573' (130 jts total) 02:00 02:45 0.75 INTRM1 CASING CIRC P 5,573.0 5,573.0 Establish circulation 3.5 bpm / 530 psi - CBU -FCP 6 bpm / 540 psi 02:45 07:00 4.25 INTRM1 CASING RNCS P 5,573.0 9,636.0 Run 7" 26# L-80 BCTM casing f/ 5,573' to 9,636' (225 jts total) 07:00 08:30 1.50 INTRMI CASING CIRC P 9,636.0 9,636.0 Establish circulation 3.7 bpm / 680 psi -circulate and condition mud - FCP 6.1 bpm / 680 psi PUW 205K SOW 120K 08:30 13:00 4.50 INTRMI CASING RNCS P 9,636.0 13,610.0 Run 7" 26# L-80 BCTM casing f/ 9,636' to 13,610' (320 jts total of 454 to run)) 13:00 15:00 2.00 INTRMI CASING CIRC P 13,610.0 13,610.0 Establish circulation 3.6 bpm / 630 psi -circulate and condition mud - FCP 6.1 bpm / 800 psi PUW 265K SOW 130K 15:00 19:30 4.50 INTRM1 CASING RNCS P 13,610.0 17,425.0 Run 7" 26# L-80 BCTM casing f/ 13,610' to 17425' (410 jts total of 454 to run) 19:30 21:15 1.75 INTRMI CASING CIRC P 17,425.0 17,425.0 Establish Circ @ 2,4 bbls/min -Circulate & condition mud - ICR 3.4 bbls/min @ 750 psi FCR - 6 bbls/min @ 960 psi - PU 310 SO 140 21:15 23:30 2.25 INTRMI CASING RNCS P 17,425.0 19,323.0 Run 7" 26# L-80 BTCM f/ 17;425' to 18,286' (454 jts total ran) MU FMC fluted hanger & landing jt. -Land 7" casing in wellhead w/ FS @ 19,323' - FC @ 19,233' - Tam Port collar @9512' -Hole in good condition for casing f/ 17,425' to TD - SO wt. 150 to 135 K 23:30 00:00 0.50 INTRMI CASING RURD P 19,323.0 19,323.0 RD fill up tool - RU cmt head i3< lines Mud Check Data '~ ~ IPA ale ~ ~~PI ~; V 1Jm; ~ ' fr ~ ~ '3i Ti H1Hr Filt 'D=n d, Temp S 7s Corr. l ~ p ( ~ i l ~ TyF~e De ttt Y E Dent i LSND 19,337.0 ~ ~ Vis 51 4 f'V C,an.1~, IL z of 10.40 50 15.0' ,.b: ~irtt) Itfll ~ft j i I~.,yL> 20.000 9 OOO i~ 10.000 ~ *Lni pH I i 1u fl i MBT ~ti19) m 12.000 22.0. 6.9 9 7 ~ ln'ection Fluid _ -- - - J - -_ - -- Fria s:.~~~ i room wa~F ~e6r~ ~ - ~ c_ t~na.~ n ~ Nose - -- ~__ - Wellbores - - _ ---- Wellbore Name i Wellbore AP I/UWI CD4-321 , 50703"?053600 -- Section Size din ~ _ - Acf Top (ftKB) A~a B _ - eni {ftKB) '~ Sra~~t Dafe Bid Date PROD1 6 1 /8 Latest BOP Test Data _ _ ---. - __. _. - _ Date - Comment 10/9/2006 250/5000 si Page 1/2 Report Printed: 11/20/2006 i Daily Drilling Report CD4-321 . ..,_- , Report Date: 10/20/2006 5c ;~ it,r~. ~. Sr- . c,; Ac: Top (ft K6) ---- - -- ~ Act Btm (ftKB; Siart Date - - --- End Date GOND1 16 0.0 114.0 10/4/2006 10/4/2006 SURFAC 12 1 /4 114.0 3,514.0 10/5/2006 10/7/2006 INTRM1 8 3/4 3,514.0 19,337.0 10/11/2006 10/17/2006 Page 2/2 Report Printed: 11/20/2006 . -_- Daily Drilling Report CD4-321 ... . Report Date: 10/21/2006 Report Number Days From Spud (days) Depth Start (ftK6) Depth End (ftK6) Depth Progress (ft) Wellbore 18 16.29 19,337.0 19,337.0 0.00 CD4-321 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftK6) 10/5/2006 DOYON 19 NANUQ KUPARUK Development 19,604.0 AFE / RFE / Maint.# Total AFE Amount Average ROP (ft/hr) 10146270 6,964,464.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 19,323.1ftKB Ops and Depth @ Morning Report Daily Cost Total Cummulative Cost LD swivel f/ 2nd stage cmt job 154,262.95 4,515,034.76 24hr Forecast Daily Mud Cost Cummulative Mud Cost Cut & slip DL - LD DP 5,659.95 667,603.76 Last 24hr Summary Circ & condition mud -Cmt 7" csg -Set pack-off & test - MU tam comb tool &RIH w/ 4" DP General Remarks Weather Head Count 49.0 Su ~is~r Trtle Dave burley Rig Supervisor Don Mickey Rig Supervisor Time L o _ _ _ Sta.; i End Dur ~ Time ~ I iieD h 3'.arr ~ D th End Tim= ~ Time (hrs) ',: Phase 0 Cone 'O Sub-Co_. P-NT Trb'~COde TrbiCla<s irihBi tR3 ~ _ p ~ p ) rrm~0_~ ~; ,n - 00:00 05:30 5.50 INTRM1 CASING CIRC P 19,323.0 19,323.0 Establish circulation / 3 bpm @ 670 psi staged pumps up to 6 bpm @ 820 psi -circulate and condition mud for cementing -reduced mud wt. to 10.0 ppg 05:30 05:45 0.25 INTRM1 CEMENT SFTY P 19,323.0 19,323.0 PJSM -flush pumps with fresh water 05:45 09:00 3.25 INTRM1 CEMENT DISP P 19,323.0 19,323.0 Cemented 7" csg as follows: Pumped 5 bbls CW100 - Tested lines to 3100 psi -pumped 35 bbls oc CW100 - Mixed & pumped 40 bbls MudPush @ 10.5 ppg - 4.5 BPM @ 520 psi -Dropped btm plug -Mixed and pumped 62 bbls of tail slurry (292 sxs Class G w/additives) - 15.8 ppg @ 5.3 BPM @ 459 psi -Flushed cement line to floor Dropped top plug displaced w/ rig pumps with 9.6 ppg kcl brine @ 6.5 BPM for 607 bbls - 7 bpm for 89 bbls and 5 bpm last 29 bbls pumped - 725 bbls total displacement -Bumped plug w/ 1500 psi - Check floats OK CIP @ 0840 hrs.- Full returns throughout - No pipe movement -Pressure test casing to 3500 psi for 10 minutes. 09:00 10:00 1.00 INTRMI CEMENT RURD P 19,323.0 0.0 Rig down cement head ,elevators, LJ and bails 10:00 11:00 1.00 INTRM1 CASING DHEO P 0.0 0.0 Pull wear ring -set and test packoff to 5000 psi for 10 minutes 11:00 14:45 3.75 INTRM1 WELCTL OTHR P 0.0 0.0 Change top pipe rams to 31/2" x 6" VBR's -test rams 250/5000 psi -pull test plug and set wear bushing 14:45 15:00 0.25 INTRMI CEMENT PULD P 0.0 0.0 Mu Tam Combo tool 15:00 00:00 9.00 INTRM1 CEMENT TRIP P 0.0 9,471.0 RIH w/ Combo tool picking up 4" drill pipe to 9471' (298 jts 4" DP) !Mud Check Data 1PCal V iyaL PVC''{;o) il~f~l~Ofi ~ De [Y~iftFE. Den il ~ ~J ~ Ge~~1 cj gel JmJ Gel (3{m) ~ H1HP Pdt jDenc t~T~mp~. I^ JOrr JL~f,1 itC) ILf~ Mfr°j Qbf/16Grff1 ~ MBT IbrtiJ ~ Sri 1n~n1 nH I F) "^I - - -- k 6~ KCLBfllle - - - - _._ In'ection Fluid - _ - - _- 1laid i Source - - - FrOrn Le~~ ibbij C ~natie~n Nose _ Diesel 45.0 CD4-208 freeze protect Other 500.0 CD4-208 tank rinse Water 150.0 CD4-208 Annular flush Water Based Mud 2560.0 CD4-208 f/ CD4-321 Latest BOP Test Data Dale --- _ __ Comment _ _ 10/9/2006 250/5000 si -- _ __ _ Page 1/2 Report Printed: 11/20/2006 r~ ~ • Daily Drilling Report CD4-321 Report Date: 10/21/2006 ~ Wellbores Wellbore Name Wellbore API/UWI CD4-321 501032053600 Section Si e (in) Act Top tttY.6'~ - - Aft Btm (ftKB. Start D~+:e End Date PROD1 6 1/8 COND1 16 0.0 114.0 10/4/2006 10/4/2006 SURFAC 12 1 /4 114.0 3,514.0 10/5/2006 10/7/2006 INTRMI 8 3/4 3,514.0 19,337.0 10/11/2006 10/17/2006 -- _ Cement - -- -- _ ~- Intermediate Casin Cement -Started 10/21/2006 Type Wellbore String Cement Evaluation Results casing CD4-321 Intermediate, 19,323.1ftK6 Bond log planned p ost rig work Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Intermediate Casing Cement 17,850.0 19,323.0 5 940.0 - Fluid Class Amoon- l~a;.ksi --- - -- - V {bbl) Densely pb ;aU ~ Yield {ft'isacki ', -- Est Top (ftKB) ~ Est Gtm (ftKB) Tail Cement G 292 - - 62.0 15.80 1.16 - - 17,850.0 19,323.0 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 2 Intermediate Casing 8,272.0 9,512.0 5 1,000.0 - - Fluid Class Pr ur rs~-rs; ~ - -- V (bbl) Density (tblgai) Yield (ft'Isacki --- EstTop.~ftKH) Es; Btm {ftKB) _ CW-100 20.0 8.30 - 6,269.0 7,015.0 Mud Push 20.0 10.50 7,015.0 7,761.0 Tail Cement G 223 47.0 15.80 1.17 7,761.0 9,515.0 Water/Brine 0.3 0.0 9,515.0 Page 2/2 Report Printed: 11/20/2006 O M ~ 0 ~ 1~ O 1~ ~t CO 0 Q 0 ll~ 0 t() ~ lf~ ~ Ln ~ tn ~ lf) 0 ~ 0 ~ 0 ~ 0 ~ 0 ~ 0 ~ d' ' tf7 'd' ~ tt ~ ~ ~ ~t ~ ~ ~ ~ ~ ~ ~ ~ ~ ~' d' a d1 R N N C ~ m r F ? 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O ~ M I p Q. O_ O ~ m U p _ N ~ 0 0 ~~ ~ ap p ~ ~ ~ O .C ~ U N 'y +' 0 t N d _ ~ ~ t0 07 C1 ~ m ~ II H ~ C U U 'd r R H _ l C 3 p ~ . ~ J LL v L Q L ~ ~ M + ~ N ~ o U I ~ r.- .: ~ ~ ~ ~ ~ ~ L f+ ~ ~ ~ a ~ c ~ ' O 7 7 Q~ ~ Z ~ Q c ? ~ ~ ~ O O 0) fn ~ ~ to U Q ~ ~ ~ Q r, ~ o om ' a ~W _ ~n C N H ~ n i a~c m ~ ~ _ ~ ~ O ~ 0 ~ H w LL N y d 0) to 0~ ~ O O d ~ d ~ 0 a = V ,C ~ ~ t O (~ ~ •L ~ c~ C~ O ~ ~ ~ R J p °° °o ° fA N ~, N m V V c 'N:~ NH ~ o 'n ... ~ ~ Z C1 ~ ~ N ~ Y ~ U .~- Y 'O ~ L y .~ ~ ~ I ~~ ~ abnss3bd uJ ~ D 2 ~ ~ .N •~ W U ConocoPhillips Alaska MALLIBURTON .....,, e..~.....~.. WELLPATH DETAILS CD4-321 501032051600 Rig: Doron 19 Rcf Datum. CD4-32 L 55 90R V Scction Origin Origin Starting Anglc +N/-S +E/-W From TVD 25S.Sg° 0.00 000 36.90 Quarter Mile (1320 feet) radius plot t 7O C t 7 O -1 -4217 -3690 -3163 -2636 -2109 -1581 -1054 -527 0 West(-)/East(+) [ft] SURFACE CASING SHOE SEPARATION FROM CD4-321 CD4-321 x Y Surface Casing Shoe ASP 4 Coordinates NAD 27: 375795.55 5956945.42 ells Nanuk 1 Nanuk 2 Details @ AOGCC** n n Ann. Disp. Permit # ermit Date ource well Ann. Vol. tart Date nd Date is ante from Object well* Surface csg. Shoe X Coord. Surface csg. Shoe Y Coord. Surf LOT (ppg) Surface casing TVD (ft) Annular LOT (ppg) omments Exploration P&A'd Exploration P&A'd Nanu 3 ~~ 828 376499.54 5957381.96 11.8 1781 Exploration, X-Y location calculated at 2400' TVD, NOT the surface shoe depth Nanu 5 2627 378326.61 5956241.68 14.9 2393 15.1 Not for annular dis osal CD2-319 305-373 12/9/2005 CD4-208, CD4-318, CD4-209, CD4-320 32000 12/14/2005 7/212006 1799 377174.72 5955790.42 18.4 2400 16.1 CD4-208 306-183 5/30/2006 CD4-318a, CD4-320, CD4-214, CD4-321 58495 7/3/2006 10/31/2006 2344 378134.16 5956792.74 16.3 2439 14.4 volume extension to 70000 bbl, permit #306- 266 CD4-318 306-181 5/26/2006 CD4-209, CD4-320 457 5/31/2006 712/2006 •--~ 724 376138.41 5956308.25 18.2 2375 17.1 Unable to pum SD um in CD4-209 2174 377934.93 5957333.86 14.7 2377 17.5 Not for annular dis osal CD4-210 1752 377547.4212 5956963.174 18.0 2386 17.3 CD4-320 2415 377914.23 5958105.03 17.1 2378 17.8 Not for annular dis sal CD4-17 "'~ 679 376416.34 5957221.03 18.1 2387 16.2 Not for annular disposal, due to proximity to Nanuq 3 CD4-321 0 375795.55 5956945.42 18.0 2385 16.3 CD4-214 1245 377040.88 5956962.79 18.2 2365 17.6 Not for annular disposal * Lateral distance in feet, between surface casing shoes, in the X-Y plane ** As of Nov. 14, 2006 Note that this sheet is not the definitive record for annular disposal volumes • • • ~a~n ar.~i ~hai~nor, , `tau i~ati~ r~c~ested to dispose ref "cze=~~r-prt+~uct" a? ~~n ~:p fl~zids from the ~'C~L't 1 P t. mixiY~,3 of m~.d and. cement at hlpir:t' as T,m11 d the trle~i up fluid s res~:l tinq gram gleaning taut the ta~°iie~ at the muci plant in prer~aratio:~ far t~a,ing,©i1 kaase mud. T~'~ (:asni~sic~n }~aci pre:~i.~;asz~ app*~avcd disposi-tq a£ t}>e °r~e~~ prveiuct'" clean up El~.a~s via ~r~nut~r tai..>gosal at C~L~ 1 padx I~ue to the cxec~lc~~[icdl settincs ~t alpine, ~ ass } and ~las:~ 2 di:~gosai c~pt~ions are 1ir~:.itsd. t?}~zllips' px•rritrcesSar, ~?C'f?, h_ad ~.t~x}fished the i.imit~~tacn r~E Disposal c?ptivns i:o the Ca~;~rtii~~iort`s s{'~ri,sar..t~o1~ anti anr_~~lar cli~art~sal +rtas appr`oveci as tt~e :~z.zcr~c'e3l anti c~nvire~runental alternative. Ir. these requesL-s the yluste fluids are nc~ diaf~:rcrt t}-:an previously aplart7vecl ciL~C'i ~~ra -ham rasult o the an3aing develr~rxc~en`: act iva. Yi.es at r'11pir:c~ _ The cvam~t~isszaners have s-~uthc~rt led me r_a^>c?nC} yc~;~ th_s m::suat~e. IIy copy of ~;~,s e~r:Qil, Fhiili:3~ i~ ~eutl~orized tc~ cZ.~~rz~e c~~ clean up fluids as descr~c~ i~,. your i~a i 1 - Plea~e call wii:X~ any ~Iaes ~iorzs 'T'rrr ~l~unrics, PE ;~r. Petrolewn Enga.~.ep;. .'.t?~CG ~~l' Env ~a7ord grate. :~ lea r ~r . t~aur~c~er~ , ~ ~~ *~ated i_r the attar~aec~ etna,i.l, `}'C7tri `?d~ai7sotl l~r~vi~asly re~tze~ted ~ aut~rar.a.~atic~n to dispose of nev:-graduct clean a>.~ fesiid~ SuC}2 as cemer~t~ > rin~ate, and ~rrud dnd i7x'irz~ pil r.t:iseS [rani mixing operatiflns via annular in~c.t;Cion ir. }~ermfttP~i ~f~c~lls at Ghe Alpinr_ C1?2 twill mite. A~ noted. 1:seiQl~t, ~ kC~Gf;C approvod such disposal at the Cn1 iii All ~iGe y.n 149 ~ ~as~c3 ran tlxe t integral reiations}aip of he mt~d myxi~nex facility and the an-site drilling oner~a~: aQn- r Pi~ill:.p~ would ia.ke to rc~i~ti.nuing laursuanu t'iis rec~,~est. Signl.fiaant clean cut of tanks at tl;e mud mixing foci? ity m;~st ~sccu~ zn prep~tx~~tiQn for i-h~ tc~:npt3~ary use o£ oil ba~€:d rnud proauits at Alixine sn the comang months. ~• ^he availability oL anz~Ula.~ disptisz-~ ~-~s on e~}a an far tank rinse fluids and ~ si.:zilar urastes *,~~c~tilc~ gr~<~tly faczlitare t:~is process. ~`E'ypically, routine ~ r`i.rs~s ara bcne£icially re*.iseci, i-igwe+~er, t2:ere i~ a conce~-r. about thc~ > potential cuantit,y of fluid t1~at~ coul~3 be t~en8x'Fat~?d during thi:~ large scale } alear~ up ~ar~acess. ) > 'r':~rks ati the m~sd r4ixizig facility Wray cor3tai;z either n~~a and used mud ~- products. ihoU(~.'I rimes in ro<2~~CU triCh used pwoducts may be in~ccted in ~ the permitted class Il di:~pcrsal Yte? 1 ~~b19i~1 r rinses c~£ rzew produ~Ca~ +,.*C~~alt3 ~ r.~overiti€illy be xoxae~ to thc~ class I ~iisp~sal ~~~-11 tbr~-Q2} , ;here there is' ~ ~ ~3a f fictzlty xz~raging ~plids content- The c1a:~s I ~Xell is a critical ~ lifrl.i~ie €or £acili.ty infrastructure, ~inc~ the di~~osa~. locara.c~n for all' :~ dantastie e££luent, and i~ i~ a pric+rity L°a prevent any c+amprQmis~ to this > disposal facility. annular di5pc~sal presents ~ pxeferre~d waste management :~ alterndtiv~ in tai case. _ •- • > 'Tktan.~c ~~zzu u~_y ,aucYz fc~r ~~ou> cc~t~it?eratir~n c~k rh~~ ~Fgttc~4t~ ~l~as~ dc~ r~c~t } ht=sitet~ tc~ tvrsn~C!~ me Ur tai alternates -,°a ~m~il r~r phca:t~ at t~ti7) €'10-~2n~ > if y~~~t h~~te c~t~~St.~r~ or ri°ftCi edt35,vc~na1 inft~r-rnatir~n. s hanr~n D~rnn~lly > ~.lpine ~i~lcl E;riuirvrttnezit~l t:c~orairiatt~t' > ~~'J r } ~`~~-~~~}{a ~ ---~-°~°- E'~~.:Farden ~~ ALP zt~~ et3~irdrPF~D oa lll~i2f~?1 i2:~D ~~~f ~_~_~_ liLP En~~{ Courc~ r Cr~~31~Ct1 l~: ~~ FN } ~`v: to~^ ~cttxur:t~er~?a~~min. st ate. a'~:. u > rc: f Sut~ject: I~~{uesL. ts3 Ttjiec-~ C~tner:t :zt..aa%c. at c~z 7 ~ Dear iii . I~`~aur~d~.~' < > Inje<~tian ~f cemcr:t t'w;~~t!? end ~:1c:an-u~ fluids frvzn'm~zr~ urt~i t>x~i.ne t~t:ixizic~ } c~prrataans ,mot tn~ ralpine mud plant ~~tci1..Cy iz:ta ._~r~~'?r©~~d annule-tr- elis}~asal ~~ vperat i«rYS t;~~s c~.r<-tttteci k~~r ~~~ .=~1 ~s~.a tai l find Ga:, Cczn:~_vativu Cr~anzn~.ssic~zt ~ f~iCtGC~~~n the htar~h 1~, 1.~~9 1~tter from ~t~G~C tt7 ~~uc~ wS~ester t~f ~~~D > Alaska, irtc. , Y:zz,~ L*hillip~ Alaska, Inc. {~:~I) fi~~ ag~aro~aal ~;~~ ~_anted to ~ P~,:~ s~e~l~icall~ ~~r Aldine I~xill :~ir.~ CISi arcl attL~t~rizeCl ~«lumes up t~ > :~a, ~~7~ 2~arrels thr~udl`i t~'i~ ~nr_-alai sg~ce. PAS request that this approval be extenciec` tc~ dj-.7,1 inq circ._~~tic~xt a~ ~lgine .. Drill Site ~~~. ~errter.t ttlixii7C.t c~pera;:wnrs fnr sitting surface conc_luctvr:~ r ~,: l l 2're t>~king p1.3cc~ cat thc~ grind ..and Ir~~ct facility sv;ti{;;'t l ~ rtt~retltly > a~tacl:e~ to the !3rilling rca at CD2, r~parz t:orn~~r-:t,~~z: ~f t:ham ccros~ntnt~ in of the c~r.,~~:ur^tc?r.s, r}~,e l.:tc~~ anti mM.xnq tank ~•;ill ita~.~e tc~ lie rirtsec? anti r Fick ~- rin.a`e disp~;~eti of . PAI r~qu~:st apgrr~va ° to i.:aj ect r.~aas r. a r.~~t~, end ~~ a~her c:lean-ug <voM the rnuu <txtd l~r ne mixing o;~~_ration~, i:zt~ tr:e antu~l -r sp3cc af` apprr~v~d Dells located at Drib Site X172.. > IL you ~tatrc~ anv questions r~tea~~ contact m~ Gt ~7C?-~~QCt. y ~ 3C~ifY I~c'~xYSUn ~- Alprt~ Field Ertvirc~nm~ntal Ca^glianee torn~n~under:vC Note to File CD4-321 (206-142...306-393) Colville River Unit (Nanuq-Kuparuk) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips' request. --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Approximately 160 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 42% XS of the calculated hole volume. --On the initial leak off test, the pressure slope rises steadily to 15.2 EMW and continues rising at a decreasing rate to 18.0 EMW. Minimal fluid was pumped into the formations. During the observation period, the pressure declined to about 15.4 EMW, in good agreement with the pressure slope change. The initial leak off indicates that the surface casing shoe is well cemented. --No problems are reported drilling the intermediate hole. The 7" casing was run and successfully cemented. Full returns were noted, but the casing was not reciprocated. --An infectivity test down 9-5/8" x 7" annulus was conducted. Pressure steadily increases until the break at 16.3 EMW. The pressure declined with additional pumping to 14.3 EMW. During the observation period, the pressure declined to 13.4 EMW. The lower EMWs of the pump in tests indicate that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA provided a listing of all surface casing shoes within '/4 mile radius of CD4-321. The nearest well is 680' distant. 2 other wells are 725' and 1245' distant and Nanuq 3 is 830' distant at 10 o'clock from the surface shoe. An examination of the cementing information for all wells did not reveal any problem that would preclude granting CPA's request for CD4-321. Nanuq 3 is sufficiently distant that its uncemented annulus should not be of concern Based on examination of the submitted information, I recommend approval of ConocoPhillips' request for the subject well. ~~~~ Tom Maunder, PE Sr. Petroleum Engineer December 29, 2006 G:\common\tommaunder\Well Information\By Subject\Annular Disposal\061228--CD4-321.doc • • Note to File CRU CD4-321 (PTD 2061420) December 27, 2006 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD4-321 Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annulus of CD4-321. Recommendation Approve ConocoPhillips' request. Discussion CPAI's application was reviewed along with records from nearby wells Nanuk No. 1 ("Nanuk 1"}, Nanuq No. 3 ("Nanuq 3"- the spelling of Nanuq is indeed different), and Nanuq No. 5 ("Nanuq 5"). The proposed injection interval in CRU CD4-321 lies in the Seabee formation approximately 3,500' from the north line and 2,450' from the east line of Section 24, T11N, R4E, UM and about 2 miles from the current boundary of the Colville River Unit. The surface casing shoe of CD4-321 lies at the base of a siltstone and claystone interval that is about 350' thick and appears to be corninuous throughout this area (see attached schematic cross- section). This interval will provide upper confinement. The annulus proposed for disposal of drilling wastes extends downward from the 9-5/8" surface casing shoe at about 2,330' true vertical feet subsea ("TVDSS") to the top of cement for the 7" casing string, which is estimated to be at about 3,905' TVDSS. The disposal injection zone in CD4-321 consists of a 700-foot thick sequence of siltstone, silty sandstone and sandstone with scattered interbeds of claystone. Beneath the injection zone are several layers of clay, claystone and shale will provide lower confinement. These layers range in thickness from 10' to 30', appear to be continuous throughout the area, and have an aggregate thickness of more than 100'. The operator's application reports the base of permafrost occurs at about 1,550' TVDSS in this area. My inspection of the well logs from Nanuk 1, Nanuq 3 and Nanuq 5 indicates that precise determination of the base of permafrost is difficult here. The geologic section is frozen through about 1,050' TVDSS, and possibly as deep as 1,300' TVDSS. Depending on the correlation used, the base of permafrost lies between approximately 800' and 1,300' above the top of the proposed injection interval. The shallow geologic section in the area surrounding CD4-321 commonly contains methane gas. Records from Nanuk 1, Nanuq 3 and Nanuq 5 indicate that surface hole was drilled in each of these wells using about the same weight of drilling mud (between 9.5 and 10 pounds per gallon}. Traces of methane were first measured in Nanuk 1, Nanuq 3 and Nanuq 5 at 460', 380' and 50', respectively. The shallowest occurrence of more significant amounts of methane encountered in • CRU CD4-321 • ~ December 27, 2006 Note to File Page 2 of 2 these three wells (arbitrarily placed at 20 units of gas on the mudlog) were 1,$90', 1,700' and 2,235' TVDSS, respectively. So, the entire proposed disposal zone currently contains methane gas. Supporting documentation to ConocoPhillips' annular disposal application states "...There are no USDW aquifers in the Colville River Unit." This is correct. Area Injection Orders No. 18, 18A, and 18B all conclude that there are no USDWs beneath the permafrost in the Colville River Unit area. Shallow aquifers within the area affected by this proposed disposal injection program occur in an area of abundant surface water, contain methane gas, and are situated beneath about 1,000' of permafrost. Even if the shallow aquifers contained freshwater, these characteristics combine to ensure that it would never be economically possible to develop them as sources of drinking water. The shallowest oil shows in Nanuq 3 and Nanuq 5 occur at 3,940' and 3,770' TVDSS. Correlative intervals within CD4-321 are separated from the disposal intervals by several layers of clay, claystone and shale, and should be sealed with cement placed around the 7-inch casing. This cement extends upward to about 3,905' TVDSS. The shallowest oil show in Nanuk 1 lies at 6,110' TVDSS, well below the disposal and lower confinin~ intervals. Conclusions The 9-518" surface casing shoe is set near the base of a 350-foot thick claystone and shale interval that persists throughout the area and will prpvide upper confinement to prevent migration of injected waste into freshwater or to the suri`ace. 2. There appears to be a sufficient volume of siltstone, silty sandstone and sandstone open to the annulus of CRU CD4-321 to accept the proposed injected fluids. 3. The lower confining layers are sufficiently thick (over 100' aggregate thickness) and laterally persistent to ensure injected materials remain within the target disposal intervals. 4. There are no potential USDWs in this area. 5. The disposal injection operations will not affect potential oil reservoirs. 6. Correlative rights will be protected. I recommend approval of the proposed program to inject drilling waste into the annulus of CRU CD4-321. -'_'~ Steve Davies Senior Petroleum Geologist a CRU CD4-321 Annular Disposal Intervals e A' EAST NANUQ 3 NANUQ 5 NANUK 1 _.~ ~.~~..~ o .~ i A Nanuq 3 - 'Nanuk 1 n r. __.. } _~ I ..A~ ~. ~ / - II -zooo,. I r pn _ ' ~~) / CD4-321 I ~, First occurrence of X l ~ _ i r ,~ ~`~, Nanuq c 20 units gas in mud - ~- _ ~ N _~~. ' ;C, uaao '~ 7 _ %~ ~ 9-5/8" Casing ~f ~ ~ i ~ ~ ~~,~ - id ~) ,~ Shoe at 2,330' TVDSS , ~ /` / ,~ ,./ i - 7 ~ _ it //// /q~ ! y Pper Coofimr{~~ -~ .wno -uwo ~ zouu o zaa wnu uooo eooo / / .. //d'7 p n~~.'.. lntet'VeIS ~I xm~ ~tasn •uzmon:m~ ~ d~~ ~l lf~r ~ J Ili 1 ~ ~t ~~ I 2500' TVDSS I 3000' 3500' Top of at -3,90: Fitst oil show First oil show ~-~~~'~ _ ~~! ~ 1 l ~~ _ -~~ i4~S Nanuk I: First oil show @ n +~~/, 6,150' MD, 6,110' TVDSS 4000' r~ vrj Vertical Exaggeration = 3X SFD 12/27/06 CONFIDENTIAL UNTIL RELEASE OF CRU CD4-321 Re: T X IA communication • i Subject: Re: T X IA communication From: Thomas E Maunder <tom_maunder a,admin.state.ak.us> Date: Sat. 23 Dec 2006 07:47:24 -0900 To: NSK i'ri~blci7~ 1~1'~:II Sups n1617(ciconocophillip~.com=- CC: jim rcc~,:~r~admin.statc.ak.l~s Perry, Your plan is appropriate. Hope it is the sliding sleeve. Too new a well to have a failure this soon. Tom Maunder, PE AOGCC ----- Original Message----- From: NSK Problem Well Supv <n1617;2cor~ocopi~xillips.ccm> Date: Saturday, December 23, 2006 5:15 am Subject: T X IA communication To: Thomas Maunder <tom maundercx•admir_.state.ak.us>, ~ .i.r:.t .r.•eggc?adrrtix~.. state . ak . us Tom & Jim, CD4-321 PTD ## 206-142, new sea water injector, is showing signs of t X IA communication while on injection. T/I/O = 1832/1777/466 psi A passing MITT and MITIA to 3500 psi was performed on 10/27/06. We suspect the sliding sleeve and plan to investigate it with slickline. I have placed the well on the monthly Failed MIT list. Our plans are to find and fix the leak then schedule an initial witnessed MITIA with the slope inspectors. Please call or write with any questions. Sincerely, Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 __, n1617~?conocophi_!ips.com «CD4-321.pdf» 1 of 1 12/26/2006 8:26 AM Schlumberger-DCS 2525 Gambell Street, Suite 400 q -~I ^ ~ ~ _,~~ ~„ ~:~s~gw~9s~4~ Anchorage, AK 99503-2838 r,,,>;~~,,,-,,,,,, Attn: Beth Well Job # Log Description N0.4081 Company: Field: Color Date BL Prints Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alpine CD 12/19/06 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 581-8367. Thank you. RE: FW: CD4-321 cement bond log • • Subject: RE: F~V: CD4-32I cement bond tog From: "Schwartz, Guy L" <Guy.L.Schwartz@conocophillips.com> Date: Fri, 15'~Dec 2006 18:08:44 -0600 "t~o: Thomas f~laur~d~:r .:~-lom ~»aui~der("~i'acir~~in.state.ak.us -, ".fohnson, Vern" ~~ Vern.Johnson«<conocophillips.com, . CC: "Walker, Jack A" °~~Jack.:~.1~Valkcrrci'~conocophillips.cum Torn, Right you are ... that is the Kuparuk C sand interval and as usual the cement quality is degraded due to the high permeability of the zone. All in all though a good cement job and excellent zone isolation. Guy Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy.I.schwartz@conocophillips.com -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, December 15, 2006 2:55 PM To: Johnson, Vern Cc: Walker, Jack A; Schwartz, Guy L Subject: Re: FW: CD4-321 cement bond log Vern, Jack and Guy, All in all the log looks pretty good. Any explanations as to the "poor" interval. Looks like the GR makes a change there indicating some sort of formation change, but those lines are kind of faint. Is that the Kuparuk? With the rock quality I've heard of, it might not be unusual to see "poor" cement there. Thanks in advance for your reply. Tom Maunder, PE AOGCC Johnson, Vern wrote, On 12/15/2006 2:00 PM: Tom, Please see the attached cement bond log. Let me know if there is anything else you need. Vern -----Original Message----- 1 of 2 12/15/2006 3:18 PM TUBING - (0.18194, OD:4.500, ID 3.958) PRODUCTION (0-19323, OD:7.000, w1 zs oo) SLEEVE (1790& 17909. O D:5.600) Gauge Carrier (1799317994, O D:6.000) PACKER (18077-18078. it OD:5.970) NIP (18182-18183, OD:5.000) WLEG (1819318194, OD:5.000) TTL (1819418195, OD 4.500) ~ ~ ALPINE CD4-321 • ConocoPhillips December 5, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for CD4-321 (#206-142) Dear Commissioner: G. C. Alvord Alpine Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 I~® CIF ~.~ ~ 2006 Alas~a ~:~il ~ Cap i',on~. Commission Anchorage ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Alpine well CD4-321. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, _~ G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad I~.ECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 0 6 2006 WELL COMPLETION OR RECOMPLETION REPOR~e~fi~Lt~~s• Cofnmission 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned Suspended WAG Q - 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other_ 1b. Well Class: Development ^ Exploratory ^ Service ^~ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: October 26, 2006 12. Permit to Drill Number: 206-142 / - 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: October 5, 2006 ~ 13. API Number: 50-103-20536-00 - 4a. Location of Well (Governmental Section): Surface: 2982' FNL, 458' FEL, Sec. 24, T11 N, R4E, UM ~ 7. Date TD Reached: October 17, 2006 ~ 14. Well Name and Number: CD4-321 - At Top Productive Horizon: 1747' FNL, 250' FEL, Sec. 28, T11 N, R4E, UM 8. KB Elevation (ft): 37' RKB - GL 15. Field/Pool(s): Colville River Field Total Depth: 1923' FNL, 962' FEL, Sec. 28, T11 N, R4E, UM 9. Plug Back Depth (MD + ND): 19233' MD / 7734' ND Nanuq Kuparuk Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377786 ~ y- 5957433 Zone- 4 10. Total Depth (MD + ND): ^19337' MD / 7811' ND ' 16. Property Designation: ~ ADL 380077, 387209, ASRCNPRA02 TPI: x- 362091 y- 5953659 Zone- 4 Total Depth: x- 361376 ~ - 5953496 ~ Zone- 4 11. Depth where SSSV set: no SSSV 17. Land Use Permit: ALK 380077 18. Directional Survey: Yes Q No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 1720' MD 21. Logs Run: GR/Res/Dens/Neutron, CBL 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE CEM G CO D AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE ENTIN RE R PULLED 16" 65# H-40 37' 114' 37' 114' 24" Portland Type III 9.625" 40# L-80 37' 3504' 37' 2385' 12.25" 493 sx AS Lite, 48 sx Class G 7" 26# L-80 37' 19323' 37' 7800' 8.75" 292 sx Class G(1 st stage) & 223 sx Class G (2nd stage) 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 18194' 18077' 18434'-18470' MD 7300'-7312' ND ~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Injector -waiting for facility hook-up Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". , _ ,~-d~...»,.,. ~.... .~-,, tepp~',~ a- d1l-~ ff 4 n_ 1 NONE ~ ~F~3 ; Y ' b......-.-._....._...-............... ~/D f~ -~~.~.~ r ~C Form 10-407 Revised 12/2003 C(~1TINU ~D~~l REVERSE ,,,~ C~/q`~~ <~ ~~.~./~ ~ early G~IGI~IAL ~ 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CD4-321 Nanuq sand 14963' 6159' Kuparuk 'C' 18433' 7300' Alpine 'C' 18933' 7534' Alpine 'A' 1911 T 7653' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, MIT 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Vern Johnson @ 265-6081 Printed Name ,~ C. Ivord Title: Aloine Drillino Team Leader ,; r .-- ~~ Phone Date (~ ~ ~2,0``' Si nature ~~- . g : _, Z.G~S - C.c% (~. ~ INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 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 elevation in feet abour mean low low water. 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: True vertical thickness. 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 i Time Lo s ~--- -- - Date From To Dur _S. Depth E. Depth Phase Code.- Subcode T COM ___ __ 10/07/2006 00:00 12:00 12.00 2,530 3,137 SURFA DRILL DDRL P Drilled 12 1/4" hole from 2,530' to 3,137'. ND 2,269'. ADT 9.96 hrs ART 8.98 hrs AST .98 hrs. WOB 20/35 K, RPM 0/60, GPM 600 PP 2150 psi. PU Wt 133. SO 115. ROT 126 K Tor ON 9000 Off 7500 Ft Lbs. 12:00 16:30 4.50 3,137 3,514 SURFA DRILL DDRL P Drilled 12 1/4" hole from 3,137' to 3,514'. TVD 2,388'. ADT 3.76 hrs ART 3.07 hrs AST .67 hrs. WOB 25/30 K, RPM 0/60, GPM 600 PP 2180 psi. PU Wt 130. SO 115. ROT 125 K Tor ON 8500 Off 7500 Ft Lbs. 16:30 18:00 1.50 3,514 3,514 SURFA DRILL CIRC P Circulate and condition mud 650 GPM 2180 si 60 RPM. 18:00 22:30 4.50 3,514 887 SURFA DRILL WPRT P POOH from 3,514' to 887' Backreaming with 550 GPM 60 RPM. Reduced GPM to 400 in the Permafrost. 22:30 00:00 1.50 887 2,895 SURFA DRILL WPRT P RIH to 2,895'. 10/08/2006 00:00 00:30 0.50 2,895 3,452 SURFA DRILL WPRT P RIH from 2895' to 3452'. 00:30 01:30 1.00 3,452 3,514 SURFA DRILL CIRC P Break circulation. Wash to 3514'. Circulate hole clean at 650 gpm and 40 r ms. 01:30 08:00 6.50 3,514 250 SURFA DRILL TRIP P POH on trip tank to 850'. Slight swabbing. RIH w/ 3 stds. Pump out 7stds at 3 bpm to 474'. Stand back HWDP. No hole roblems. 08:00 10:00 2.00 250 0 SURFA DRILL PULD P Std back NMFC and jars. Download MWD. LD BHA #1 10:00 12:00 2.00 0 0 SURFA CASIN( RURD P RD DP equipment. RU csg equipment. 12:00 15:30 3.50 0 1,924 SURFA CASIN( RNCS P PJSM. Ran 50 jts 9 5/8" 40# L-80 BTCM casin 1,924'. 15:30 16:30 1.00 1,924 1,924 SURFA CASIN< CIRC P Circulated Casing working up to 4.5 BPM ICP 400 si FCP 330 si. 16:30 19:30 3.00 1,924 3,504 SURFA CASIN( RNCS P PJSM. Ran 40 jts 9 5/8" 40# L-80 BTCM casing 3,465'. Made up landing jt and landed casing @ 3,504'. Laid down Franks tool and made up cement head. 19:30 21:30 2.00 3,504 3,504 SURFA CEME~ CIRC P Circulated Casing working up to 7 BPM ICP 570 si FCP 340 si. ___ __e _ e _ Page cf 11 r -- _ _ -- Time Logs Date From To Dur 5 De th E. De th Phase Code Subcode T COM 10/08/2006 21:30 00:00 2.50 3,504 0 SURFA CEME~ DISP P Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/ nut plug as marker w! rig pumps -Line up Dowell & pump 10 bbls CW-100 -Test lines to 2500 psi -Pumped 30 bbls CW-100. Mix & pump 50 bbls MudPush @ 10.5 ppg @ 5 bbllmin @ 210 psi -Mix & pump Lead slurry (ASL) @ 10.7 ppg @ 7.5 bbls/min @ 230 psi -Observed nut plug marker @ shakers w/ 381 bbls lead slurry pumped -pumped down surge can - 391 bbls lead slurry pumped - Switched to tail slurry (G w/ 1 -SOO2, .20% DO46, .30% DO65) Mixed & pumped 48 bbls @ 15.8 ppg @ 5.4 bbls/min @ 250 psi -dropped top plug & chased w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced w/ 9.8 ppg mud @ 7 bbls/ min for 220 bbls (400 to 700 psi) slowed pump to 4 bbls/min for last 19.7 bbls of displacement (500 to 600 psi) 240 bbls total displaement - Bumped plug w/ 1100 psi -Checked floats OK - CIP @ 2350 hrs. -Full circulation throughout job w/ 160 bbls 10.7 cmt to surface 10/09/2006 00:00 01:00 1.00 0 0 SURFA CASINC DHEO P Pressure test 9 5/8" csg to 2500 psi for 30 min. 01:00 02:00 1.00 0 0 SURFA CASIN( RURD P RD cement head and csg handling e ui ment. Clear floor. 02:00 04:30 2.50 0 0 SURFA CASIN( NUND P ND riser. NU well head. Test MTM seals to 1000 si. 04:30 06:30 2.00 0 0 SURFA WELCT NUND P NU ROPE. 06:30 12:00 5.50 0 0 SURFA DRILL PULD P Change inserts in iron roughneck. PJSM. LD 49 stds 4" DP from derrick. 12:00 17:30 5.50 0 0 SURFA WELCT BOPE P BOP test. Tested Annulur to 250/3500. Tested rams, choke manifold and floor valves to 250/5000. Tested Closing unit: Witiness of test waived b Chuck Shieve AOGCC. 17:30 18:30 1.00 0 0 SURFA DRILL RURD P Installed wear bushing and rigged up GeoS an. 18:30 00:00 5.50 0 0 SURFA DRILL PULD P Picking up 5" drill pipe and standing back. 10/10/2006 00:00 15:30 15.50 0 0 SURFA DRILL PULD P PU and stand back 5" DP. Total - 435 'ts. 15:30 20:00 4.50 0 320 SURFA DRILL PULD P MU BHA #2 - GeoPilot - MWD - Up load MDW -Shallow test tools -Load RA sources for to in tools 20:00 23:30 3.50 320 3,227 SURFA DRILL PULD P RIH w/ BHA - finishpicking up 5" DP f/ shed f/ 320' to 3227' 23:30 00:00 0.50 3,227 3,227 SURFA RIGMN SVRG P PJSM -Cut & slip drill line ___.__ _ --~--~ ~ Page 3 oaf 11 3 1 -- --- _. _ Time Logs --- Date From To Dur S Dep_t_h E. Depth Phase_ Code Subcode T___ COM _ 10/11/2006 00:00 01:00 1.00 3,227 3,227 SURFA RIGMN SVRG P PJSM. Slip and cut drilling line. 01:00 01:30 0.50 3,227 3,227 SURFA RIGMN SVRG P Performed thorough derrick and cable ins ection after 2 da s of hi h wind. 01:30 03:00 1.50 3,227 3,421 SURFA CEME~ COCF P Wash and ream from 3227' to 3400' (top of cmt) Clean out cmt & wiper lu s to 3422' to of FC 03:00 08:15 5.25 3,421 3,534 SURFA CEME~ DRLG P Drill out float equipment, cement and 20' new formation to 3534'. 08:15 08:30 0.25 3,534 3,534 SURFA CEMEP CIRC P CBU 08:30 08:45 0.25 3,534 3,418 SURFA CEME~ TRIP P Set back 2 stds to 3418'. 08:45 09:45 1.00 3,418 3,418 SURFA CEMEI~ FIT P Perform FIT with 9.6 ppg mud - 2385' TVD - 1045 psi surface pressure for 18.0 EMW. 09:45 10:00 0.25 3,418 3,534 INTRM1 DRILL TRIP P RIH w/ 2 stds DP to 3534'. 10:00 10:45 0.75 3,534 3,534 INTRM1 DRILL CIRC P Displace mud to 9.6 ppg LSND. Obtain ECD base lines. 10:45 12:00 1.25 3,534 3,608 INTRM1 DRILL DDRL P Drill 8 3/4" hole with GeoPilot from 3534' to 3608'. MD - 2419' TVD ADT - .42 hrs ECD - 10.5 ppg WOB 10/15 k RPM 110 GPM 650 @ 1700 psi String wt. PU - 145k So - 100k -Rot -125k Tor ue on/off btm. - 9500/9000 ft lbs. 12:00 00:00 12.00 3,608 5,525 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GeoPilot f/ 3608' to 5225' MD 2948' TVD ADT - 7.92 hrs EDC - 11.68 ppg WOB - 8/13 k RPM 130 GPM 650 @ 2250 psi String wt. PU 152 So 108 Rot. 130 Torque on/off btm. - 10,500/9,500 ft/Ibs. 10/12/2006 00:00 12:00 12.00 5,525 6,341 INTRM1 DRILL DDRL P Dril18 3/4" hole w/ GeoPilot f/ 5225' to 6341' MD 3316' TVD ADT - 7.75 hrs EDC - 11.5 ppg WOB - 10/15 k RPM 110 GPM 650 @ 4250 psi String wt. PU 170 So 113 Rot. 136 Torque on/off btm. - 12,500/11,500 ft/Ibs. 12:00 00:00 12.00 6,341 7,517 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GeoPilot f/ 6341' to 7517' MD 3706' TVD ADT - 8.35 hrs. ECD - 11.28 ppg WOB - 13/16 k RPM 110 GPM 650 @ 2650 psi String wt. PU 170 SO 123 Rot 143 Torque on/off btm. - 12,000/11,000 ft/Ibs. ~ F~~ 4 t~f 13 _ _ _--- - _- - --- - - - --- - i Time Logs ' Date.. __ From To______ Dur S. !?e th E._Depth Phase Code Subcode 7 COM - -- 10/13/2006 00:00 12:00 12.00 7,517 8,650 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GeoPilot f! 7517' to 8650' MD 4081' TVD ADT - 8.39 hrs. ECD - 11.32 ppg WOB - 12/17 k RPM 120 GPM 650 @ 2960 psi String wt. PU 170 SO 132 Rot 150 Torque on/off btm. - 13,000/11,000 fUlbs. 12:00 00:00 12.00 8,650 10,280 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GeoPilot f/ 8650' to 10280' MD 4616' TVD ADT - 8.23 hrs ECD - 11.15 ppg WOB 15/18 k RPM 130 GPM 650 @ 2560 psi String wt. - PU 185 So 137 Rot 160 Torque on/off btm. - 14,500/12,500 ft/Ibs. 10/14/2006 00:00 12:00 12.00 10,280 11,710 INTRM1 DRILL DDRL P Drill 8 3!4" hole w/ GeoPilot f! 10280' to 11710' MD 5089' TVD ADT - 8.03 hrs ECD - 10.89 ppg WOB 15/18 k RPM 130 GPM 650 @ 2430 psi String wt. - PU 195 So 145 Rot 165 Torque on/off btm. - 15,500/14,000 ft/Ibs. 12:00 00:00 12.00 11,710 13,395 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GeoPilot f/ 11,710' to 13,395' MD 5645' TVD ADT - 8.49 hrs ECD - 11.19 ppg WOB 19/22 k RPM 130 GPM 650 @ 2720 psi String wt. PU 212 SO 148 Rot 176 Torque on/off btm. - 16,500/14,500 ft/Ibs. 10/15/2006 00:00 12:00 12.00 13,395 14,750 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GeoPilot f/ 13,395' to 14,750' MD 6088' TVD ADT - 8.07 hrs ECD - 10.87 ppg WOB 18/21 k RPM 130 GPM 650 @ 2510 psi String wt. PU 220 SO 150 Rot 170 Torque oNoff btm. - 16,500/14,500 ft/Ibs. 12:00 00:00 12.00 14,750 16,172 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GeoPilot f/ 14,750' to 16,172' MD 6555' TVD ADT - 8.74 hrs. ECD - 10.9 ppg WOB - 18/22 k RPM 130 GPM 650 @ 2800 psi String wt. - PU 245 SO 154 Rot 195 Torque on/off btm - 20,000/17,500 ft/Ibs 10/16/2006 00:00 12:00 12.00 16,172 17,420 INTRMI DRILL DDRL P Drill 8 3/4" hole w/ GeoPilot f/ 16,172' to 17,420' MD 6966' TVD ADT - 8.25 hrs. ECD - 10.98 ppg WOB - 18/22 k RPM 130 GPM 600 @ 2800 psi String wt. - PU 280 SO 150 Rot 200 Torque on/off btm - 25,000/24,000 ft/Ibs _ e. ~qe 5 ref 1 ~ Time Logs Date __ From To_ Dur____ S. De th E. De th Phase Code Subcode T GOM ____.__ _ -- - 10/16/2006 12:00 00:00 12.00 17,420 18,378 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GeoPilot f/ 17,420' to 18,378' MD 7280' TVD ADT - 8.14 hrs. ECD - 10.85 ppg WOB 15/23 k RPM 130 GPM 600 @ 2990 psi String wt. PU 285 SO 150 Rot 205 Torque on/off btm. - 23,000/21,000 ft/Ibs. 10/17/2006 00:00 12:00 12.00 18,378 18,893 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GeoPilot f/ 18,378' to 18,893' MD 7511' TVD ADT - 9.93 hrs. ECD - 10.9 ppg WOB 15/20 k RPM 130 GPM 600 @ 3060 psi String wt. PU 305 SO 155 Rot 215 Torque on/off btm. - 24,000/23,000 ft/Ibs. 12:00 18:00 6.00 18,893 19,337 INTRM1 DRILL DDRL P Drill 8 3/4" hole w/ GeoPilot f/ 18,893' to 19,337 MD 7811' TVD ~ ADT - 5.24 hrs. ECD - 11.0 ppg WOB 15/21 k RPM 130 GPM 584 @ 3370 psi String wt. PU 315 SO 165 Rot 220 Torque on/off btm. - 25,000/22,000 ft/Ibs. 18:00 22:00 4.00 19,337 18,872 INTRM1 DRILL CIRC P Pump hi-vis sweep & circulate 3 X btms up @ 584 gpm @ 3340 psi w/ 130 rpm -Standing back 5 stds f/ 19,337' to 18,872' 22:00 00:00 2.00 18,872 18,128 INTRM1 DRILL WPRT P Wiper trip f/ 18,872' to 18,128' -Back reaming w/ 100 rpm 584 gpm @ 3340 psi - PU 290 SO 150 Rot 213 -torque off btm 20,500 ft/Ibs 18,128' 10/18/2006 00:00 01:30 1.50 18,128 17,478 INTRM1 DRILL TRIP P Wiper trip f/ 18,128 to 17,478' -Back reaming w/ 100 rpm 500 gpm @ 2650 psi -torque off btm 22,000 ft/Ibs 17,478' 01:30 02:45 1.25 17,478 19,245 INTRM1 DRILL TRIP P Flow check well, static - RIH from 17,478' to 19,245' - no robfems 02:45 08:00 5.25 19,245 19,245 INTRM1 DRILL CIRC P Stage pumps up to 550 gpm / 3200 psi - precautionary ream from 19,245' to 19,337' - 120 rpm / 22K torque - Circ and condition mud -increase weight from 9.8 to 10.2 ppg -spot WSP and casing tube pills to bit (10.4 ppg)-set back first stand 08:00 11:00 3.00 19,245 17,386 INTRM1 DRILL TRIP P POOH from 19,245' to 17,386' spotting pills - 130 gpm / 570 psi -flow check well, static 11:00 13:45 2.75 17,386 16,642 INTRM1 DRILL CIRC P Backream from 17,386' to 16,642' - 500 gpm / 2830 psi / 100 rpm 20K torque / 200-205 K rot up wt. - increase mud wt. from 10.2 to 10.4 ppg -set back one stand every 20 minutes - 13:45 14:00 0.25 16,642 16,642 INTRM1 DRILL OWFF P Flow check well, static -attempt to ull i e - swabbin ~~_ - ~.~ ~ __ ___~__ _ _____ P~c~~ cif 11 Time Logs _ Date From To Dur S. De th E. De th Phase Code Subcode T CDM 10/18/2006 14:00 20:30 6.50 16,642 11,314 INTRM1 DRILL TRIP P POOH w/ pump 3 bpm / 600 psi from 16,642' to 11,314' 20:30 00:00 3.50 11,314 9,221 INTRM1 DRILL TRIP P POOH on TT f/ 11,314' to 9221' -Ream thru ti ht hole 9300' 10/19/2006 00:00 07:45 7.75 9,221 3,133 INTRMI DRILL TRIP P POOH from 9,221' to 3133' -wiped clean several ti ht s ots 07:45 08:15 0.50 3,133 3,133 INTRM1 DRILL OWFF P Flow check well, static -pump dry job -blow down to drive 08:15 10:15 Z.00 3,133 800 INTRMI DRILL TRIP P POOH from 3133' to 800' -flow check well, static 10:15 11:30 1.25 800 106 INTRM1 DRILL TRIP P POOH stand back hwdp -laid down 'ars, nm flex collars and float sub 11:30 13:30 2.00 106 106 INTRM1 DRILL PULD P PJSM -Remove source -Plug in and download LWD 13:30 15:30 2.00 106 0 INTRM1 DRILL PULD P Lay down BHA components -clear tools from floor 15:30 16:00 0.50 0 0 INTRM1 CASIN< OTHR P Pull wear bushing 16:00 18:00 2.00 0 0 INTRM1 CASIN( OTHR P Change top pipe rams to 7" & test to 250/5000 psi -Change TD savwer sub to 4" XT-39 18:00 19:30 1.50 0 0 INTRM1 CASINC RURD P Install thin wall wear bushing - RU to run 7" casin 19:30 20:00 0.50 0 0 INTRMI CASINC SFTY P Held pre job safety meeting with crew 20:00 00:00 4.00 0 3,513 INTRM1 CASINC RNCS P Run 7" 26# L-80 BCTM casing as follows: FS (Ray Oil Tools silver bullet) 2 jts csg - FC (Weatherford) 2 jts csg (first 4 jts made up w/ Baker Loc -filled pipe & checked floats) 78 jts csg to 3513' (total 82 jts. of 454 'ts. to run 10/20/2006 00:00 02:00 2.00 3,513 5,573 INTRMI CASINC RNCS P Run 7" 26# L-80 BCTM casing f/ 3,513' to 5,573' 130 'ts total 02:00 02:45 0.75 5,573 5,573 INTRM1 CASINC CIRC P Establish circulation 3.5 bpm / 530 psi -CBU-FCP6b m/540 si 02:45 07:00 4.25 5,573 9,636 INTRM1 CASINC RNCS P Run 7" 26# L-80 BCTM casing f/ 5,573' to 9,636' 225 'ts total 07:00 08:30 1.50 9,636 9,636 INTRM1 CASINC CIRC P Establish circulation 3.7 bpm / 680 psi - circulate and condition mud - FCP 6.1 bpm / 680 psi PUW 205K SOW 120K 08:30 13:00 4.50 9,636 13,610 INTRM1 CASINC RNCS P Run 7" 26# L-80 BCTM casing f/ 9,636' to 13,610' 320 'ts total of 454 to run 13:00 15:00 2.00 13,610 13,610 INTRM1 CASIN( CIRC P Establish circulation 3.6 bpm / 630 psi - circulate and condition mud - FCP 6.1 bpm / 800 psi PUW 265K SOW 130K 15:00 19:30 4.50 13,610 17,425 INTRMI CASINC RNCS P Run 7" 26# L-80 BCTM casing f/ 13,610' to 17425' (410 jts total of 454 to run 19:30 21:15 1.75 17,425 17,425 INTRM1 CASINC CIRC P Establish circ @ 2,4 bbls/min - Circulate & condition mud - ICR 3.4 bbls/min @ 750 psi FCR - 6 bbls/min 960 si - PU 310 SO 140 ~ ® ~ Page 7 cif 1! ~ _ _--- _ _ Time Logs .gate From To Dur S: De th E. Depth Phase Code Subcade T CDM __ 10/20/2006 21:15 23:30 2.25 17,425 19,323 INTRM1 CASIN( RNCS P Run 7" 26# L-80 BTCM f/ 17,425' to 19,286' (454 jts total ran) MU FMC fluted hanger & landing jt. -Land 7" casing in wellhead w/ FS @ 19,323' - FC @ 19,233' -Tam Port collar @ 9512' -Hole in good condition for casing f/ 17,425' to TD - SO wt. 150 to 135 K 23:30 00:00 0.50 19,323 19,323 INTRM1 CASINC RURD P RD fill up tool - RU cmt head & lines 10/21/2006 00:00 05:30 5.50 19,323 19,323 INTRM1 CASIN( CIRC P Establish circulation / 3 bpm @ 670 psi staged pumps up to 6 bpm @ 820 psi -circulate and condition mud for cementing -reduced mud wt. to 10.0 05:30 05:45 0.25 19,323 19,323 INTRM1 CEME~ SFTY P PJSM -flush pumps with fresh water 05:45 09:00 3.25 19,323 19,323 INTRM1 CEME~ DISP P Cemented 7" csg as follows: Pumped 5 bbls CW100 -Tested lines to 3100 psi -pumped 35 bbls oc CW100 - Mixed & pumped 40 bbls MudPush @ 10.5 ppg - 4.5 BPM @ 520 psi - Dropped btm plug -Mixed and pumped 62 bbls of tail slurry (292 sxs Class G w/additives) - 15.8 ppg @ 5.3 BPM @ 459 psi -Flushed cement line to floor Dropped top plug displaced w/ rig pumps with 9.6 ppg kcl brine @ 6.5 BPM for 607 bbls - 7 bpm for 89 bbls and 5 bpm last 29 bbls pumped - 725 bbls total displacement -Bumped plug w/ 1500 psi -Check floats OK CIP @ 0840 hrs.- Full returns throughout - No pipe movement -Pressure test casing to 3500 si for 10 minutes. 09:00 10:00 1.00 19,323 0 INTRM1 CEME~ RURD P Rig down cement head ,elevators, LJ and bails 10:00 11:00 1.00 0 0 INTRM1 CASINC DHEQ P Pull wear ring -set and test packoff to 5000 si for 10 minutes 11:00 14:45 3.75 0 0 INTRM1 WELCT OTHR P Change top pipe rams to 31/2" x 6" VBR's -test rams 250/5000 psi -pull test lu and set wear bushin 14:45 15:00 0.25 0 0 INTRM1 CEME~ PULD P Mu Tam Combo tool 15:00 00:00 9.00 0 9,471 INTRM1 CEME~ TRIP P RIH w/Combo tool picking up 4" drill i e to 9471' 298 'ts 4" DP 10/22/2006 00:00 01:15 1.25 9,471 9,471 INTRMI CEME~ RURD P PU and MU top Drive side entry swivel assembl 01:15 01:30 0.25 9,471 9,471 INTRM1 CEME~ SFTY P PJSM -port collar and cementing opts 01:30 02:45 1.25 9,471 9,514 INTRM1 CEMEI~ CIRC P Displace drill string with 9.8 ppg mud while pumping down ball to choke seat - locate port collar -blank test tool to 1000 psi -open port collar with 10k SOW _._ ~ _ ~ E~~~~ ~ rsf 11 ~ i Time Logs Date From___ To Qur S. De th E. Depth _Phase Code Subcode T COM ___ 10/23/2006 08:15 12:00 3.75 0 _ 0 INTRM1 DRILL PULD P Lay down 108 joints of 5"drill pipe from derrick 12:00 12:30 0.50 0 0 INTRM1 CEME~ OTHR T Change elevators and iron roughneck dies to 4" 12:30 13:30 1.00 0 104 INTRM1 CEME~ OTHR T PU three 4 3/4" dc's - mu string mill, bs and bit 13:30 15:00 1.50 104 2,961 INTRM1 CEME~ TRIP T RIH from 104' to 2961' -fill pipe 15:00 16:30 1.50 2,961 4,486 INTRM1 CEME~ TRIP T RIH from 2961' to 4486' -picked up 48 ~oints from i e shed 16:30 19:00 2.50 4,486 9,441 INTRM1 CEME~ TRIP T RIH w/ DP f/derrick f/ 4486' to 9441' 19:00 20:00 1.00 9,441 9,823 INTRM1 CEME~ OTHR T Wash & ream f/ 9441' to 9536' - Observed no obstruction going through Tam port collar @ 9514' down to 9536' - Wash down f/ 9536' to 9823' (no obstruction 20:00 21:00 1.00 9,823 9,823 INTRM1 CEME~ CIRC T Pump Hi-vis sweep around @ 6 BPM @ 950 psi -Observed no signs of cement 21:00 21:30 0.50 9,823 9,441 INTRMI CEME~ TRIP T POOH f/ 9823' to 9441' -Observed no increase in up wt coming through Tam PC 21:30 22:00 0.50 9,441 9,441 INTRM1 CEME~ OTHR T Test 7" casing to 3500 psi for 10 mins. OK 22:00 00:00 2.00 9,441 6,010 INTRM1 CEME~ TRIP T Blow down TD & kill line -POOH f/ 9441' to 6010' 10/24/2006 00:00 01:30 1.50 6,010 104 COMPZ RPCOA TRIP P POOH on Trip tank F/ 6000' to 104'. 01:30 02:00 0.50 104 0 COMPZ RPCOh PULD P POOH LD BHA. 02:00 04:00 2.00 0 0 COMPZ RPCOh RURD P Pull wear ring PU tool and RU to run 4-1/2" tubin . 04:00 04:15 0.25 0 0 COMPZ RPCOh SFTY P PJSM 04:15 05:00 0.75 0 200 COMPZ RPCOA RCST P RIH w/ 4-1/2" 12.6# IBT Mod f/ 0' to 200'. 05:00 09:00 4.00 200 200 COMPZ RPCOti RCST T Troubleshoot cable connecting gauge carrier. 09:00 12:00 3.00 200 1,243 COMPZ RPC06 RCST P RIH w/ 4-1/2" 12.6# IBT Mod f/ 200' to 1243'. 12:00 00:00 12.00 1,243 9,443 COMPZ RPCOh RCST P RIH w/ 4-1/2" 12.6# IBT Mod f/ 1243' to 9443'. 10/25/2006 00:00 13:00 13.00 9,443 18,159 COMPZ RPCOh RCST P RIH w/ 4-1/2" 12.6# IBT Mod f/ 9443' to 18,159' 456' 'oints total 13:00 13:45 0.75 18,159 18,194 COMPZ RPCOh OTHR P MU FMC tubing hanger and LJa -strip Weatherford power line through hanger and test connection to 5000 psi. Land hanger in wellhead Top of WLEG @ 18,192', XN nipple 18,182', Packer 18,077', POD2 17,993', Baker SS 17,908', DB ni le 2290' 13:45 15:00 1.25 18,194 18,194 COMPZ RPCOh OTHR P RILDS - LD LJa - MU LJ b -test casing to 3500 si for 10 minutes. - LD LJb __ ~~ _ ~ P~~'it~ csf 1'! r Time Logs - -_- -- _ , Date_From To Dur S. De th E De th Phase Gode Subcode T GOM _ i 10/25/2006 15:00 16:00 1.00 18,194 18,194 COMPZ RPCOh OTHR P Install TWC - MU LJb -attempted to test M/M hanger seals, Top seal leakin 16:00 17:00 1.00 18,194 18,159 COMPZ RPCOA OTHR T LD LJb -Pull TWC - MU LJb and pull han er to ri floor - la down han er 17:00 19:00 2.00 18,159 18,194 COMPZ RPCOR T MU emergency tubing hanger, RIH and retest to 5000 si. OK. 19:00 19:30 0.50 18,194 18,194 COMPZ RPCOh OTHR P RD Landing joint-B. Clear floor. 19:30 21:00 1.50 18,194 18,194 COMPZ RPCOh NUND P ND BOP. Change out saver sub to 5". 21:00 00:00 3.00 18,194 18,194 COMPZ RPCOh NUND P NU Tree, manifold and hardlines. Test tree to 5000 si. OK. Pull TWC. 10/26/2006 00:00 00:30 0.50 18,194 18,194 COMPZ RPCOh RURD P Continue RU displacement manifold and lines. 00:30 00:45 0.25 18,194 18,194 COMPZ RPCOA SFTY P PJSM displace with inhibited brine and diesel. 00:45 04:15 3.50 18,194 18,194 COMPZ RPCOh FRZP P Fill and test lines. Displace with 260 bbls inhibited brine and 321 bbls diesel. Pum 3 bbl/min. 04:15 05:00 0.75 18,194 0 COMPZ RPCOh PACK P RU lubricator, drop ball and rod, set acker 4400 si. 05:00 06:30 1.50 0 0 COMPZ RPCOh DHEO P Test tubing to 3500 psi for 0.5 hours. Test annulus to 3500 si for 0.5 hours. 06:30 08:30 2.00 0 0 COMPZ RPCOA RURD P Flush and blow down lines, RD manifold. Set BPV, dress and secure tree. 08:30 09:30 1.00 0 0 PROD1 DRILL PULD P PJSM LD 4" DP from derrick to pipe shed 09:30 14:00 4.50 0 0 PROD1 DRILL PULD P Change over elevator and dies to 5". LD 5" DP from derrick to i e shed. 14:00 15:00 1.00 0 PROD1 DRILL RURD P Clear floor. Prep rig to move to CD4-214. Ri release at 15:00 hrs. ~_ ~ ~ P~~a~ 11 ~f 11 • Halhburton Company Survey Report Company: COnoOOPhillips Alaska InC. __ _ Date: 11/6/2006 ____ Time: 14:20:44 Fage: I Field: Colville River Unit Co-ordinate(NE) Reference: Well: CD4-321, Tru e North .~ Site: Alpine CD4 Vertical (TVD) Referenceed CD4-321: 55.9 Well: CD4-321 Section (VS} Reference: W ell (O.OON,O.OOE,255.58Azi) Wellpath: Cbd-321 Survey Calculation Method: Mi nimum Curvature - Db: OraCle Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: CD4-321 Slot Name: Alpine CD4 Well Position: +N/-S -99.32 ft Northing: 5957433. 08 ft - Latitude: 70 17 31.989 N j +E/-W -387.42 ft Easting : 377785. 75 ft ~ Longitude: 150 59 22.054 W Position Uncertainty: 0.00 ft Wellpatb: CD4-321 Drilled From: Well Ref. Point 501032053600 Tie-on Depth: 36.90 ft Current Datum: CD4-321: Height 55. 90 ft Above System Datum: Mean Sea Level Magnetic Data: 10/3/2006 Declination: 23.03 deg Field Strength: 57549 nT Mag Dip Angle: 80.66 deg Vertical Section: Depth From (TVD) +N/-S +FJ-W Direction ft ft ft deg 36.90 0.00 0.00 255.58 Survey Program for Definitlve Wellpath Date: 11/6/2006 Validated: No Version: 16 Actual From To Survey Toolcode Tool Name ft ft 78.00 620.00 CD4-321 Gyro (78.00-620.00) CB-GYRO-SS Camera based gyro single shot ~ 657.46 19273.00 CD4-321 (657.46-19273. 00) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC Survey ~iD ind Azim TVD Svs TVD ~ N/S FJ~i' ~1apN MapE Tool ft deg deg ft ft ft ft ff ft 36.90 0.00 .0.00 36.90 -19.00 0.00 0.00 5957433.08 377785.75 TIE LINE 78.00 0.15 220.00 78.00 22.10 -0.04 -0.03 5957433.04 377785.71 CB-GYRO-SS 161.00 0.20 223.00 161.00 105.10 -0.23 -0.20 5957432.85 377785.54 CB-GYRO-SS 256.00 0.35 184.00 256.00 200.10 -0.64 -0.34 5957432.44 377785.40 CB-GYRO-SS i 347.00 2.00 231.00 346.98 291.08 -1.92 -1.59 5957431.19 377784.13 CB-GYRO-SS 438.00 3.90 245.00 437.85 381.95 -4.23 -5.63 5957428.95 377780.05 CB-GYRO-SS 529.00 5.20 252.00 528.57 472.67 -6.81 -12.36 5957426.47 377773.29 CB-GYRO-SS 620.00 6.40 256.00 619.10 563.20 -9.31 -21.20 5957424.12 377764.40 CB-GYRO-SS ~ 657.46 6.35 255.21 656.33 600.43 -10.34 -25.23 5957423.15 377760.36 MWD+IFR-AK-CAZ-SC 747.76 8.85 256.12 745.83 689.93 -13.28 -36.80 5957420.40 377748.74 MWD+IFR-AK-CAZ-SC 837.20 13.32 257.05 833.58 777.68 -17.25 -53.53 5957416.71 377731.95 MWD+IFR-AK-CAZ-SC 931.54 17.32 259.89 924.55 868.65 -22.15 -77.96 5957412.20 377707.45 MWD+IFR-AK-CAZ-SC 1028.54 21.36 260.61 1016.05 960.15 -27.57 -109.61 5957407.30 377675.71 MWD+IFR-AK-CAZ-SC 1120.09 22.48 258.93 1100.98 1045.08 -33.65 -143.24 5957401.77 377641.99 MWD+IFR-AK-CAZ-SC 1218.86 26.74 256.33 1190.76 1134.86 -42.53 -183.38 5957393.54 377601.72 MWD+IFR-AK-CAZ-SC 1313.76 29.60 257.23 1274.42 1218.52 -52.76 -226.99 5957384.02 377557.95 MWD+IFR-AK-CAZ-SC 1409.33 33.78 254.91 1355.72 1299.82 -64.90 -275.69 5957372.68 377509.06 MWD+IFR-AK-CAZ-SC 1504.43 36.16 254.21 1433.65 1377.75 -79.42 -328.22 5957359.02 377456.31 MWD+IFR-AK-CAZ-SC 1599.55 39.29 252.91 1508.87 1452.97 -95.91 -384.03 5957343.44 377400.25 MWD+IFR-AK-CAZ-SC 1694.86 42.02 253.71 1581.17 1525.27 -113.73 -443.50 5957326.59 377340.49 MWD+IFR-AK-CAZ-SC 1789.73 44.81 254.92 1650.08 1594.18 -131.34 -506.27 5957310.00 377277.45 MWD+IFR-AK-CAZ-SC 1885.08 47.95 255.31 1715.85 1659.95 -149.06 -572.98 5957293.37 377210.47 MWD+IFR-AK-CAZ-SC , 1980.15 50.03 254.99 2075.56 52.75 255.01 1778.23 1837.76 1722.33 1781.86 -167.45 -642.32 -186.74 -714.32 5957276.11 5957257.99 377140.85 377068.55 MWD+IFR-AK-CAZ-SC ' MWD+IFR-AK-CAZ-SC i i 2170.76 55.44 255.50 1893.59 1837.69 -206.36 -788.89 5957239.59 376993.68 MWD+IFR-AK-CAZ-SC 2265.85 57.80 255.15 1945.90 1890.00 -226.48 -865.70 5957220.72 376916.56 MWD+IFR-AK-CAZ-SC 2361.13 60.80 255.18 1994.54 1938.64 -247.45 -944.88 5957201.04 376837.05 MWD+IFR-AK-CAZ-SC 2456.49 63.65 255.58 2038.98 1983.08 -268.74 -1026.52 5957181.08 376755.09 MWD+IFR-AK-CAZ-SC 2551.49 66.84 256.93 2078.75 2022.85 -289.22 -1110.31 5957161.97 376670.98 MWD+IFR-AK-CAZ-SC ~Halli r n m n bu to Co pa y Survey Report Company: ConoCOPhiilips Alaska Inc. Date: 11/6/2006 Time: 14:20:44 Page: 2 Field: Co lville River Unit Co-ord inate(NE) Reference: Well: Cp4-321, True North Site: Alpine CD4 Vertical (TVD) Reference: CD4-32'1: 55.9 Well: CD4-321 Section (VS) Reference: Well (0':OON,O.OOE.255.58Azi) Wellpath: Cb4-321 Survey Calculation bfethodc'' Minimum Gurvatura Db: Oraele Survey MD Intl Azim TVU SysTVD ti/S FJW ~7apN MapE Tool ft deg deg ft ft ft ft ft ft 2646.63 69.89 256.30 2113.83 ___ 2057.93 -309.70 -1196.33 5957142.90 376584.64 MWD+IFR-AK-CAZ-SC 2742.40 71.98 255.59 2145.11 2089.21 -331.68 -1284.13 5957122.34 376496.51 MWD+IFR-AK-CAZ-SC 2837.61 71.24 255.77 2175.14 2119.24 -354.03 -1371.67 5957101.42 376408.62 MWD+IFR-AK-CAZ-SC 2932.57 71.63 254.90 2205.38 2149.48 -376.82 -1458.75 5957080.06 376321.18 MWD+IFR-AK-CAZ-SC 3027.89 71.94 255.31 2235.17 2179.27 -400.09 -1546.25 5957058.21 376233.32 MWD+IFR-AK-CAZ-SC 3122.48 71.92 254.67 2264.51 2208.61 -423.38 -1633.11 5957036.34 376146.11 MWD+IFR-AK-CAZ-SC 3218.04 72.56 253.98 2293.66 2237.76 -447.97 -1720.73 5957013.18 376058.11 MWD+IFR-AK-CAZ-SC 3312.95 71.03 254.50 2323.31 2267.41 -472.46 -1807.50 5956990.10 375970.96 MWD+IFR-AK-CAZ-SC 3408.16 71.10 255.06 2354.21 2298.31 -496.10 -1894.40 5956967.88 375883.70 MWD+IFR-AK-CAZ-SC ~ 3467.15 71,04 254.71 2373.35 2317.45 -510.65 -1948.27 5956954.21 375829.60 MWD+IFR-AK-CAZ-SC I j 3483.19 71.15 254.63 2378.54 2322.64 -514.66 -1962.90 5956950.44 375814.91 MWD+IFR-AK-CAZ-SC 3577.78 71.09 254.47 2409.15 2353.25 -538.51 -2049.17 5956928.00 375728.27 MWD+IFR-AK-CAZ-SC 3672.25 72.21 254.71 2438.89 2382.99 -562.33 -2135.61 5956905.58 375641.46 MWD+IFR-AK-CAZ-SC 3766.98 72.00 255.88 2468.00 2412.10 -585.22 -2222.80 5956884.12 375553.91 MWD+IFR-AK-CAZ-SC 3861.86 71.66 256.01 2497.59 2441.69 -607.11 -2310.25 5956863.66 375466.13 MWD+IFR-AK-CAZ-SC 3957.68 71.41 256.47 2527.94 2472.04 -628.73 -2398.53 5956843.48 375377.52 MWD+IFR-AK-CAZ-SC 4052.40 70.85 256.49 2558.57 2502.67 -649.68 -2485.67 5956823.95 375290.05 MWD+IFR-AK-CAZ-SC 4147.68 70.51 256.87 2590.09 2534.19 -670.40 -2573.17 5956804.66 375202.24 MWD+IFR-AK-CAZ-SC 4243.03 70.05 257.51 2622.27 2566.37 -690.30 -2660.69 5956786.18 375114.41 MWD+IFR-AK-CAZ-SC ; 4337.71 70.98 258.03 2653.85 2597.95 -709.20 -2747.92 5956768.70 375026.89 MWD+IFR-AK-CAZ-SC j 4433.06 71.10 257.60 2684.83 2628.93 -728.24 -2836.07 5956751.10 374938.45 MWD+IFR-AK-CAZ-SC 4528.39 71.47 257.48 2715.42 2659.52 -747.72 -2924.23 5956733.06 374849.99 MWD+IFR-AK-CAZ-SC 4623.81 71.67 256.99 2745.58 2689.68 -767.72 -3012.52 5956714.50 374761.40 MWD+IFR-AK-CAZ-SC 4718.97 70.10 255.39 2776.75 2720.85 -789.18 -3099.83 5956694.46 374673.76 MWD+IFR-AK-CAZ-SC 4814.12 69.25 255.94 2809.80 2753.90 -811.27 -3186.27 5956673.78 374586.97 MWD+IFR-AK-CAZ-SC ~ 4909.16 69.45 256.00 2843.31 2787.41 -832.83 -3272.55 5956653.63 374500.36 MWD+IFR-AK-CAZ-SC 5004.23 70.91 256.09 2875.55 2819.65 -854.40 -3359.35 5956633.48 374413.23 MWD+IFR-AK-CAZ-SC 5099.59 70.87 255.79 2906.77 2850.87 -876.29 -3446.76 5956613.01 374325.49 MWD+IFR-AK-CAZ-SC 5194.49 71.15 255.26 2937.65 2881.75 -898.72 -3533.64 5956592.00 374238.26 MWD+IFR-AK-CAZ-SC 5289.69 70.23 255.29 2969.13 2913.23 -921.55 -3620.53 5956570.58 374151.01 MWD+IFR-AK-CAZ-SC 5384.57 70.63 255.83 3000.91 2945.01 -943.85 -3707.11 5956549.70 374064.10 MWD+IFR-AK-CAZ-SC 5479.23 70.68 254.92 3032.26 2976.36 -966.40 -3793.53 5956528.56 373977.33 MWD+IFR-AK-CAZ-SC 5576.16 71.01 255.58 3064.07 3008.17 -989.71 -3882.08 5956506.69 373888.42 MWD+IFR-AK-CAZ-SC 5669.98 70.63 256.61 3094.89 3038.99 -1011.00 -3968.09 5956486.80 373802.08 MWD+IFR-AK-CAZ-SC 5765.13 70.97 254.79 3126.19 3070.29 -1033.20 -4055.16 5956466.02 373714.67 MWD+IFR-AK-CAZ-SC 5860.39 70.96 253.81 3157.26 3101.36 -1057.57 -4141.85 5956443.07 373627.60 MWD+IFR-AK-CAZ-SC 5955.30 70.43 254.82 3188.63 3132.73 -1081.78 -4228.08 5956420.26 373540.99 MWD+IFR-AK-CAZ-SC 6050.53 70.76 254.85 3220.27 3164.37 -1105.28 -4314.78 5956398.18 373453.94 MWD+IFR-AK-CAZ-SC 6145.73 71.22 255.02 3251.28 3195.38 -1128.67 -4401.69 5956376.20 373366.66 MWD+IFR-AK-CAZ-SC 6240.85 70.71 255.09 3282.31 3226.41 -1151.86 -4488.57 5956354.43 373279.42 MWD+IFR-AK-CAZ-SC 6335.92 70.63 255.81 3313.78 3257.88 -1174.40 -4575.40 5956333.31 373192.24 MWD+IFR-AK-CAZ-SC 6431.12 6526.27 70.68 70.50 255.18 255.53 3345.31 3376.93 3289.41 3321.03 -1196.90 -1219.59 -4662.36 -4749.19 5956312.23 5956290.96 373104.94 373017.76 MWD+IFR-AK-CAZ-SC I MWD+IFR-AK-CAZ-SC 6621.40 70.31 255.32 3408.84 3352.94 -1242.14 -4835.92 5956269.82 372930.67 MWD+IFR-AK-CAZ-SC 6717.96 70.83 255.43 3440.96 3385.06 -1265.13 -4924.03 5956248.27 372842.21 MWD+IFR-AK-CAZ-SC 6813.51 69.92 256.00 3473.05 3417.15 -1287.34 -5011.25 5956227.48 372754.65 MWD+IFR-AK-CAZ-SC 6908.71 70.71 256.70 3505.12 3449.22 -1308.49 -5098.35 5956207.75 372667.22 MWD+IFR-AK-CAZ-SC 7003.55 71.16 256.27 3536.10 3480.20 -1329.44 -5185.51 5956188.22 372579.75 MWD+IFR-AK-CAZ-SC 7098.79 71.63 255.53 3566.48 3510.58 -1351.43 -5273.05 5956167.66 372491.87 MWD+IFR-AK-CAZ-SC 7193.91 71.15 254.83 3596.84 3540.94 -1374.49 -5360.20 5956146.02 372404.36 MWD+IFR-AK-CAZ-SC 7288.79 70.88 254.95 3627.70 3571.80 -1397.88 -5446.81 5956124.05 372317.38 MWD+IFR-AK-CAZ-SC 7384.02 70.03 253.97 3659.56 3603.66 -1421.92 -5533.27 5956101.42 372230.55 MWD+IFR-AK-CAZ-SC I H llibur n om an a to C p y Survey Report Company: ConocoPhillips Alaska Inc. - _ Date: --_ 11/6J2006 Timc: 14:20:44 Page: 3 Field: Co lville River Unit Co-ordinate(NE)'Reference: W ell: CD4-321, True North Site: Alpine CD4 Vertical (TVD) Refe rence: C D4-321: 55.9 Well: CD4-321 Section (VS) R@feren ce: W ell (O.OON,O.OOE,255.5$Azi) Wellpath: CD4-321 SurveyCalculatiuaMeihod: Mi nimum Curvature Db: Oracle Survey - __ __ MD Intl Azim T•"D tit's TVD N/S E/R' 1iapN MapE Tuul ft deg deg ft ft ft ft ft ft 7485.15 70.84 253.66 3693.43 3637.53 -1448.48 -5624.79 5956076.35 372138.63 - - MWD+IFR-AK-CAZ-SC 7573.60 70.69 253.82 3722.57 3666.67 -1471.86 -5704.96 5956054.28 372058.09 MWD+IFR-AK-CAZ-SC 7667.62 70.56 254.78 3753.76 3697.86 -1495.86 -5790.34 5956031.67 371972.33 MWD+IFR-AK-CAZ-SC 7764.32 70.70 254.96 3785.83 3729.93 -1519.67 -5878.41 5956009.29 371883.90 MWD+IFR-AK-CAZ-SC ~ 7859.30 70.30 254.93 3817.54 3761.64 -1542.93 -5964.87 5955987.45 371797.08 MWD+IFR-AK-CAZ-SC j 7954.89 70.44 255.87 3849.65 3793.75 -1565.62 -6051.99 5955966.18 371709.61 MWD+IFR-AK-CAZ-SC ~ 8049.77 70.34 255.76 3881.49 3825.59 -1587.52 -6138.65 5955945.69 371622.62 MWD+IFR-AK-CAZ-SC 8144.95 70.71 256.74 3913.23 3857.33 -1608.85 -6225.81 5955925.78 371535.13 MWD+IFR-AK-CAZ-SC 8239.50 70.55 256.12 3944.59 3888.69 -1629.78 -6312.51 5955906.27 371448.10 MWD+IFR-AK-CAZ-SC 8335.16 71.33 256.04 3975.82 3919.92 -1651.53 -6400.27 5955885.95 371360.01 MWD+IFR-AK-CAZ-SC 8430.01 70.56 256.03 4006.79 3950.89 -1673.17 -6487.28 5955865.73 371272.67 MWD+IFR-AK-CAZ-SC 8524.90 70.17 256.55 4038.68 3982.78 -1694.35 -6574.10 5955845.96 371185.52 MWD+IFR-AK-CAZ-SC 8620.60 70.30 256.31 4071.04 4015.14 -1715.48 -6661.65 5955826.26 371097.65 MWD+IFR-AK-CAZ-SC 8715.79 70.24 256.74 4103.17 4047.27 -1736.36 -6748.78 5955806.80 371010.19 MWD+IFR-AK-CAZ-SC 8811.31 70.23 256.31 4135.48 4079.58 -1757.31 -6836.20 5955787.28 370922.45 MWD+IFR-AK-CAZ-SC 8906.66 70.76 256.16 4167.31 4111.41 -1778.69 -6923.50 5955767.32 370834.83 MWD+IFR-AK-CAZ-SC I 9001.46 70.68 255.34 4198.61 4142.71 -1800.72 -7010.23 5955746.71 370747.76 MWD+IFR-AK-CAZ-SC 9096.62 70.95 254.92 4229.89 4173.99 -1823.78 -7097.09 5955725.06 370660.54 MWD+IFR-AK-CAZ-SC 9191.75 71.15 254.01 4260.78 4204.88 -1847.88 -7183.78 5955702.38 370573.48 MWD+IFR-AK-CAZ-SC 9286.87 70.96 253.67 4291.66 4235.76 -1872.92 -7270.19 5955678.75 370486.68 MWD+IFR-AK-CAZ-SC 9382.19 70.82 252.36 4322.87 4266.97 -1899.23 -7356.33 5955653.84 370400.13 MWD+IFR-AK-CAZ-SC 9476.99 70.16 254.85 4354.53 4298.63 -1924.45 -7442.04 5955630.02 370314.03 MWD+IFR-AK-CAZ-SC 9572.35 70.10 256.10 4386.95 4331.05 -1946.95 -7528.86 5955608.94 370226.87 MWD+IFR-AK-CAZ-SC 9667.64 71.29 257.53 4418.45 4362.55 -1967.45 -7616.41 5955589.86 370138.99 MWD+IFR-AK-CAZ-SC 9762.95 70.61 256.45 4449.56 4393.66 -1987.73 -7704.19 5955571.02 370050.91 MWD+IFR-AK-CAZ-SC 9858.14 71.50 255.72 4480.46 4424.56 -2009.39 -7791.58 5955550.79 369963.18 MWD+IFR-AK-CAZ-SC 9953.58 71.01 254.57 4511.13 4455.23 -2032.55 -7878.93 5955529.04 369875.47 MWD+IFR-AK-CAZ-SC 10048.76 71.48 255.44 4541.74 4485.84 -2055.87 -7965.99 5955507.15 369788.05 MWD+IFR-AK-CAZ-SC 10144.05 71.72 255.22 4571.81 4515.91 -2078.77 -8053.46 5955485.68 369700.23 MWD+IFR-AK-CAZ-SC 10239.40 71.22 254.83 4602.12 4546.22 -2102.13 -8140.80 5955463.74 369612.53 MWD+IFR-AK-CAZ-SC ~ 10334.17 71.34 255.54 4632.53 4576.63 -2125.08 -8227.57 5955442.21 369525.41 MWD+IFR-AK-CAZ-SC 10429.49 70.97 257.68 4663.33 4607.43 -2145.97 -8315.32 5955422.75 369437.33 MWD+IFR-AK-CAZ-SC 10524.69 70.36 257.19 4694.85 4638.95 -2165.51 -8403.00 5955404.63 369349.36 MWD+IFR-AK-CAZ-SC 10619.86 70.57 258.23 4726.67 4670.77 -2184.60 -8490.63 5955386.97 369261.43 MWD+IFR-AK-CAZ-SC 10714.58 71.03 257.60 4757.82 4701.92 -2203.33 -8578.10 5955369.67 369173.68 MWD+IFR-AK-CAZ-SC 10809.70 71.22 257.65 4788.59 4732.69 -2222.62 -8666.02 5955351.81 369085.47 MWD+IFR-AK-CAZ-SC 10905.02 71.22 256.96 4819.28 4763.38 -2242.45 -8754.05 5955333.42 368997.13 MWD+IFR-AK-CAZ-SC 11000.11 71.01 255.36 4850.06 4794.16 -2263.97 -8841.41 5955313.32 368909.44 MWD+IFR-AK-CAZ-SC 11094.78 70.58 256.09 4881.20 4825.30 -2286.02 -8928.05 5955292.69 368822.46 MWD+IFR-AK-CAZ-SC 11189.86 70.50 255.35 4912.88 4856.98 -2308.13 -9014.93 5955271.99 368735.24 MWD+IFR-AK-CAZ-SC 11284.80 -70.89 255.68 4944.26 4888.36 -2330.54 -9101.68 5955251.00 368648.14 MWD+IFR-AK-CAZ-SC 11380.05 70.89 255.76 4975.45 4919.55 -2352.74 -9188.90 5955230.22 368560.58 MWD+IFR-AK-CAZ-SC 11474.69 70.76 255.46 5006.53 4950.63 -2374.96 -9275.49 5955209.42 368473.65 MWD+IFR-AK-CAZ-SC I 11570.28 70.64 255.86 5038.13 4982.23 -2397.30 -9362.89 5955188.50 368385.90 MWD+IFR-AK-CAZ-SC ~ 11665.15 70.83 255.68 5069.43 5013.53 -2419.32 -9449.70 5955167.90 368298.75 MWD+iFR-AK-CAZ-SC 11759.79 71.28 255.01 5100.15 5044.25 -2441.96 -9536.30 5955146.67 368211.80 MWD+IFR-AK-CAZ-SC '. 11854.74 70.83 253.98 5130.98 5075.08 -2465.97 -9622.84 5955124.07 368124.89 MWD+IFR-AK-CAZ-SC 11949.89 70.49 254.17 5162.49 5106.59 -2490.60 -9709.17 5955100.85 368038.18 MWD+IFR-AK-CAZ-SC I 12045.25 70.37 254.54 5194.43 5138.53 -2514.83 -9795.70 5955078.03 367951.28 MWD+IFR-AK-CAZ-SC 12140.36 70.64 254.84 5226.17 5170.27 -2538.51 -9882.17 5955055.76 367864.44 MWD+IFR-AK-CAZ-SC 12235.95 70.43 255.12 5258.03 5202.13 -2561.86 -9969.22 5955033.83 367777.03 MWD+IFR-AK-CAZ-SC 12331.20 70.68 255.28 5289.74 5233.84 -2584.81 -10056.06 5955012.30 367689.84 MWD+IFR-AK-CAZ-SC 12426.51 70.29 255.87 5321.57 5265.67 -2607.19 -10143.06 5954991.34 367602.49 MWD+IFR-AK-CAZ-SC I •Halli r n m n bu to Co pa y Survey Report Company: ConocoPhillips Alaska Inc. Date: t 1 /6/2006 'fimr. 14:20:44 Fa~,c 4 Field:. Colv ille River Unit Co-ordinate(NE}Reference: '''Well: CD4-321, True North Site: Alpin e CD4 ~ eriical (T~-D) Reference: CD4-321: 55.9 Well: CD4 -321 Section (VS) Reference: Well (O.OON,O.OOE,255.58Azi} Wellpatb: CD4-321 Survey Calculation MetLod: Mi nimum Curvature Db: Oracle Survey ~~ ~ D7•I1 loci Azim TVD Sys TVD V1S FIrV MapN MapE Tool ft deg deg ft fi t[ ft ft ft 12521.59 70.18 255.65 5353.73 5297.83 -2629.20 -10229.79 5954970.75 367515.42 MWD+IFR-AK-CAZ-SC 12616.10 70.51 255.63 5385.52 5329.62 -2651.27 -10316.01 5954950.08 367428.86 MWD+IFR-AK-CAZ-SC 12710.99 70.31 255.18 5417.33 5361.43 -2673.80 -10402.52 5954928.96 367342.00 MWD+IFR-AK-CAZ-SC 12806.19 70.31 255.98 5449.41 5393.51 -2696.12 -10489.33 5954908.06 367254.85 MWD+IFR-AK-CAZ-SC 12901.56 70.30 256.02 5481.55 5425.65 -2717.84 -10576.45 5954887.76 367167.39 MWD+IFR-AK-CAZ-SC 12996.66 70.75 256.64 5513.25 5457.35 -2739.03 -10663.57 5954867.99 367079.94 MWD+IFR-AK-CAZ-SC 13091.75 70.96 256.49 5544.44 5488.54 -2759.90 -10750.95 5954848.54 366992.25 MWD+IFR-AK-CAZ-SC 13187.42 70.62 255.68 5575.92 5520.02 -2781.63 -10838.64 5954828.25 366904.23 MWD+IFR-AK-CAZ-SC 13282.93 70.69 255.01 5607.56 5551.66 -2804.43 -10925.82 5954806.87 366816.69 MWD+IFR-AK-CAZ-SC I 13378.10 71.40 254.67 5638.47 5582.57 -2827.96 -11012.70 5954784.75 366729.45 MWD+IFR-AK-CAZ-SC j 13473.45 71.67 255.19 5668.67 5612.77 -2851.48 -11100.03 5954762.66 366641.76 MWD+IFR-AK-CAZ-SC 13568.52 71.48 256.02 5698.72 5642.82 -2873.90 -11187.39 5954741.66 366554.05 MWD+IFR-AK-CAZ-SC 13663.83 71.68 255.38 5728.84 5672.94 -2896.24 -11275.02 5954720.75 366466.08 MWD+IFR-AK-CAZ-SC 13759.27 71.01 255.14 5759.36 5703.46 -2919.24 -11362.47 5954699.17 366378.27 MWD+IFR-AK-CAZ-SC 13854.76 70.56 255.35 5790.79 5734.89 -2942.21 -11449.66 5954677.63 366290.72 MWD+IFR-AK-CAZ-SC 13950.16 70.49 255.81 5822.60 5766.70 -2964.61 -11536.77 5954656.65 366203.27 MWD+IFR-AK-CAZ-SC 14043.62 70.76 256.18 5853.60 5797.70 -2985.94 -11622.32 5954636.71 366117.39 MWD+IFR-AK-CAZ-SC 14139.40 70.17 256.09 5885.63 5829.73 -3007.58 -11709.95 5954616.51 366029.43 MWD+IFR-AK-CAZ-SC 14234.55 70.22 255.46 5917.87 5861.97 -3029.57 -11796.73 5954595.93 365942.31 MWD+IFR-AK-CAZ-SC 14329.96 70.17 255.82 5950.20 5894.30 -3051.84 -11883.69 5954575.08 365855.00 MWD+IFR-AK-CAZ-SC 14424.87 70.84 256.48 5981.87 5925.97 -3073.25 -11970.56 5954555.08 365767.81 MWD+IFR-AK-CAZ-SC 14519.98 70.71 256.31 6013.19 5957.29 -3094.38 -12057.84 5954535.38 365680.20 MWD+IFR-AK-CAZ-SC 14615.09 70.83 255.76 6044.51 5988.61 -3116.05 -12144.99 5954515.13 365592.72 MWD+IFR-AK-CAZ-SC 14709.76 70.70 253.90 6075.70 6019.80 -3139.44 -12231.26 5954493.15 365506.09 MWD+IFR-AK-CAZ-SC 14805.15 71.03 254.57 6106.97 6051.07 -3163.92 -12317.99 5954470.08 365418.98 MWD+IFR-AK-CAZ-SC 14899.46 70.69 254.45 6137.89 6081.99 -3187.72 -12403.85 5954447.69 365332.75 MWD+IFR-AK-CAZ-SC 14994.59 70.89 254.67 6169.20 6113.30 -3211.63 -12490.44 5954425.18 365245.79 MWD+IFR-AK-CAZ-SC 15089.89 71.42 255.11 6199.98 6144.08 -3235.14 -12577.51 5954403.09 365158.35 MWD+IFR-AK-CAZ-SC 15184.76 70.96 255.06 6230.57 6174.67 -3258.26 -12664.29 5954381.40 365071.22 MWD+IFR-AK-CAZ-SC 15280.23 70.38 255.43 6262.17 6206.27 -3281.20 -12751.41 5954359.87 364983.75 MWD+IFR-AK-CAZ-SC 15375.24 70.38 256.36 6294.07 6238,17 -3303.01 -12838.20 5954339.48 364896.62 MWD+IFR-AK-CAZ-SC 15469.83 70.50 256.74 6325.74 6269.84 -3323.74 -12924.89 5954320.16 364809.61 MWD+IFR-AK-CAZ-SC 15565.24 70.76 256.26 6357.38 6301.48 -3344.76 -13012.41 5954300.58 364721.77 MWD+IFR-AK-CAZ-SC 15660.31 70.56 254.81 6388.87 6332.97 -3367.16 -13099.27 5954279.59 364634.56 MWD+IFR-AK-CAZ-SC 15755.88 71.15 255.29 6420.21 6364.31 -3390.45 -13186.50 5954257.72 364546.98 MWD+IFR-AK-CAZ-SC 15851.07 70.97 255.98 6451.11 6395.21 -3412.79 -13273.72 5954236.80 364459.41 MWD+IFR-AK-CAZ-SC 15946.42 70.83 255.79 6482.31 6426.41 -3434.76 -13361.10 5954216.26 364371.69 MWD+IFR-AK-CAZ-SC 16041.74 71.95 255.80 6512.73 6456.83 -3456.93 -13448.67 5954195.52 364283.78 MWD+IFR-AK-CAZ-SC 16137.04 70.88 254.63 6543.10 6487.20 -3479.98 -13536.01 5954173.89 364196.09 MWD+IFR-AK-CAZ-SC 16232.16 70.76 254.91 6574.35 6518.45 -3503.58 -13622.69 5954151.71 364109.04 MWD+IFR-AK-CAZ-SC 16327.76 70.43 256.09 6606.12 6550.22 -3526.16 -13709.99 5954130.56 364021.39 MWD+IFR-AK-CAZ-SC 16422.94 70.56 255.54 6637.90 6582.00 -3548.14 -13796.97 5954109.99 363934.07 MWD+IFR-AK-CAZ-SC 16518.44 70.96 255.80 6669.37 6613.47 -3570.46 -13884.33 5954089.10 363846.37 MWD+IFR-AK-CAZ-SC 16613.67 70.56 256.30 6700.75 6644.85 -3592.13 -13971.59 5954068.84 363758.78 MWD+IFR-AK-CAZ-SC 16707.68 70.91 255.97 6731.77 6675.87 -3613.40 -14057.75 5954048.98 363672.29 MWD+IFR-AK-CAZ-SC 16800.27 70.57 255.66 6762.31 6706.41 -3634.82 -14142.49 5954028.95 363587.22 MWD+IFR-AK-CAZ-SC i 16891.51 70.17 256.11 6792.96 6737.06 -3655.78 -14225.83 5954009.35 363503.55 MWD+IFR-AK-CAZ-SC 16982.11 70.50 256.03 6823.45 6767.55 -3676.32 -14308.64 5953990.16 363420.43 MWD+IFR-AK-CAZ-SC 17075.16 70.83 256.53 6854.25 6798.35 -3697.14 -14393.93 5953970.73 363334.81 MWD+IFR-AK-CAZ-SC 17168.43 71.09 256.44 6884.68 6828.78 -3717.74 -14479.66 5953951.52 363248.77 MWD+IFR-AK-CAZ-SC 17260.53 70.64 255.33 6914.87 6858.97 -3738.96 -14564.04 5953931.68 363164.06 MWD+IFR-AK-CAZ-SC 17355.87 71.10 255.16 6946.12 6890.22 -3761.90 -14651.15 5953910.16 363076.60 MWD+IFR-AK-CAZ-SC ~H lli r n man • a bu to Co p y Survey Report Company: ConocoPhillips Alaska Inc. Date: 11/6'2006 Time: 14:2(1:44 Fapc: ti Field: Co lville River Unit Co-ordinate(NE) Reference: WeII: CD4-32i, True North Site: Atpine CD4 Vertical (TVD) Reference: CD 4-321: 55.9 Well: CD4-321 tiection (VS) Reference: WeII (O.OON,0.00!E.255.58Azi) Wellpath: CD4-321 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Intl Azim 'TVD Svs'I'VD ~ N/S 'FJW 1iapN ~iapF, Tool ft deg deg ft ft ft ft ft ft j ___ 17448.33 _ _.._ 71.34 252.81 6975.89 6919.99 -3786.05 -14735.28 5953887.38 362992.10 MWD+IFR-AK-CAZ-SC 17540.91 71.10 253.30 7005.69 6949.79 -3811.60 -14819.12 5953863.20 362907.85 MWD+IFR-AK-CAZ-SC 17634.12 71.08 253.10 7035.90 6980.00 -3837.09 -14903.54 5953839.09 362823.04 MWD+IFR-AK-CAZ-SC 17726.95 71.09 253.23 7065.99 7010.09 -3862.52 -14987.59 5953815.03 362738.59 MWD+IFR-AK-CAZ-SC 17819.66 71.16 254.56 7095.98 7040.08 -3886.85 -15071.87 5953792.07 362653.93 MWD+IFR-AK-CAZ-SC 17911.06 70.89 254.81 7125.70 7069.80 -3909.68 -15155.24 5953770.60 362570.22 MWD+IFR-AK-CAZ-SC 18004.49 70.57 255.35 7156.54 7100.64 -3932.39 -15240.46 5953749.29 362484.65 MWD+IFR-AK-CAZ-SC 18098.15 70.69 255.75 7187.60 7131.70 -3954.44 -15326.02 5953728.63 362398.74 MWD+IFR-AK-CAZ-SC 18191.54 70.31 256.15 7218.78 7162.88 -3975.81 -15411.42 5953708.66 362313.01 MWD+IFR-AK-CAZ-SC 18284.48 70.76 256.03 7249.75 7193.85 -3996.88 -15496.48 5953688.98 362227.63 MWD+IFR-AK-CAZ-SC 18376.06 70.36 256.65 7280.23 7224.33 -4017.27 -15580.39 5953669.95 362143.40 MWD+IFR-AK-CAZ-SC -18467.15 69.53 257.64 7311.46 7255.56 -4036.31 -15663.81 5953652.27 362059.69 MWD+IFR-AK-CAZ-SC 18560.94 66.65 257.48 7346.46 7290.56 -4055.05 -15748.78 5953634.92 361974.44 MWD+IFR-AK-CAZ-SC 18656.37 63.08 256.53 7386.99 7331.09 -4074.47 -15832.95 5953616.87 361889.98 MWD+IFR-AK-CAZ-SC 18749.34 59.48 256.62 7431.65 7375.75 -4093.39 -15912.24 5953599.24 361810.39 MWD+IFR-AK-CAZ-SC 18840.69 55.94 256.55 7480.45 7424.55 -4111.30 -15987.34 5953582.55 361735.01 MWD+IFR-AK-CAZ-SC 18935.67 52.63 256.27 7535.88 7479.98 -4129.42 -16062.29 5953565.66 361659.79 MWD+IFR-AK-CAZ-SC 19029.39 49.97 255.58 7594.48 7538.58 -4147.20 -16133.23 5953549.04 361588.57 MWD+IFR-AK-CAZ-SC 19122.76 46.67 254.83 7656.56 7600.66 -4164.99 -16200.65 5953532.35 361520.88 MWD+IFR-AK-CAZ-SC 19215.60 44.03 255.01 7721.80 7665.90 -4182.17 -16264.41 5953516.20 361456.85 MWD+IFR-AK-CAZ-SC 19273.00 42.73 255.01 7763.51 7707.61 -4192.37 -16302.50 5953506.63 361418.61 MWD+IFR-AK-CAZ-SC - 19337.00 42.73 255.01 7810.53 7754.63 -4203.60 -16344.45 5953496.08 - 361376.49 ~ PROJECTED to TD • ~ ConocoPhilli 5 Casing Detail 9 5/8"Surface Casin_g Well: CD4-321 Date: 10/8/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.65 FMC Gen V Hanger 2.19 36.65 Jts 3 to 90 88 Jts 9-5/8" 40# L-80 BTC Csg 3383.38 38.84 Halliburton Float Collar 1.12 3422.22 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 78.41 3423.34 Ray Oil Tools "Silver Bullet" Float Shoe 2.26 3501.75 3504.01 TD 12 1/4" Surface Hole 3514.00 12 114" hole 3514' MD - 2389' TVD 9 5/8" csg shoe 3504.01' MD - 2385' TVD TOTAL BOWSPRING CENTRALIZERS - 51 1 per jt on Jt #1 - #13 (stop ring on Jt #1 & 3 ) and over collars on jts# 15, 17, 19, 21, 23, 25, 27, 29, 31, 33, 35, 37, 39, 41, 43, 45, 47, 49, 51, 53, 55, 57, 59, 61, 63 65, 67, 69,71,73,75,77,79,81,83,85,87,89 98 joints in the pipe shed. 90 jts to run -Last 8 jts out ~. Q o~~ - C ~ -\ ~o Use Best-o-Life 2000 pipe dope All joints drifted - 8.781" MU torque - 8600 ft/Ibs Remarks: Up Wt r 195" k t?n 1Nt - 127' k Block Wt`- 7~ _ _ -. Supervisor: Lutrick /Hill r~ ~ Cement Detail Report CD4-321 Surface Casing Cement Primary Job Type Job Category AFE I RFE Start Date Spud Date End Date DRILLING ORIGINAL DRILLING 10146270 10/4/2006 10/5/2006 Cement Details Description Cementing Start Date Cementing End Date Weiibore Name Surface Casing Cement 10/8/2006 21:30 10/7/2006 23:50 CD4-321 Comment Cement 9 5!8" casing as follows: Pumped 40 bbls Biozan water w/ nut plug as marker w/ rig pumps -Line up Dowell & pump 10 bbls CW-100 -Test lines to 2500 psi -Pumped 30 bbls CW-100. Mix & pump 50 bbls MudPush @ 10.5 ppg @ 5 bbl/min @ 210 psi -Mix & pump Lead slurry (ASL) @ 10.7 ppg @ 7.5 bbls/min @ 230 psi -Observed nut plug marker @ shakers w/ 381 bbls lead slurry pumped -pumped down surge can - 391 bbls lead slurry pumped - Switched to tail slurry (G w! 1 % -S002, .20% D046, .30% D065) Mixed & pumped 48 bbls @ 15.8 ppg @ 5.4 bbls/min @ 250 psi -dropped top plug & chased w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced w/ 9.8 ppg mud @ 7 bbls/ min for 220 bbls (400 to 700 psi) slowed pump to 4 bbls/min for last 19.7 bbls of displacement (500 to 600 psi) 240 bbls total displacment -Bumped plug w/ 1100 psi -Checked floats OK -CIP @ 2350 hrs. -Full circulation throughout job w/ 160 bbls 10.7 ppg cmt to surface --- Cement Stages. - - - - 1 S~ _ Description Objective Top (ftke) Bottom (ftKB) Full Retum? Cmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement Cement to surface. 0.0 3,504.0 No 160.0 Yes Yes Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 7 4 7 570.0 1,100.0 Yes 20.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/ nut plug as marker w/ rig pumps -Line up Dowell & pump 10 bbls CW-100 -Test lines to 2500 psi -Pumped 30 bbls CW-100. Mix & pump 50 bbls MudPush @ 10.5 ppg @ 5 bbl/min @ 210 psi -Mix & pump Lead slurry (ASL) @ 10.7 ppg @ 7.5 bbls/min @ 230 psi -Observed nut plug marker @ shakers w! 381 bbls lead slurry pumped -pumped down surge can - 391 bbls lead slurry pumped - Switched to tail slurry (G w/ 1 % -S002, .20% D046, .30% D065) Mixed & pumped 48 bbls @ 15.8 ppg @ 5.4 bbls/min @ 250 psi -dropped top plug & chased w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced w/ 9.8 ppg mud @ 7 bbls/min for 220 bbls (400 to 700 psi) slowed pump to 4 bbls/min for last 19.7 bbls of displacement (500 to 600 psi) 240 bbls total displacment -Bumped plug w/ 1100 psi -Checked floats OK -CIP @ 2350 hrs. -Full circulation throughout job w/ 160 bbls 10.7 ppg cmt to surface Cement Fluids & Additives Fluid Flwd Type Lead Cement Fluid Description Estimated Top (ftKB) 36.6 Est Btm (ftK8) 2,980.0 Amount (sacks) 493 Class G Volume Pumped (bbl) 391.0 Yield (ft'Isack) 4.45 Mix H2O Ratio (gal/sa... 20.77 Free Water (%) Density (Iblgal) 10.70 Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Fluid Fluid Type Tail Cement luid Description Type - _ Estimated Top (ftKB) 2,980.0 _ Est Btm (ftKB) 3,504.0 ____ Amount (sacks) 48 Concentration Class G Conc Unit label Volume Pumped (bbl) 48.0 Yield (ft'/sack) 1.17 Mix H2O Ratio (gal/sa... 5.10 Free Water (%) Density (Ib/gal) 15.80 Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 7 (psi) Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 11/14/2006 r Daily Drilling Report CD4-321 }~ Report Date: 10/8/2006 Report Number Days From Spud (days) Depth Start (ftK6) Depth End (ftK6) Depth Progress (ft) Wellbore 5 3.29 3,514.0 3,514.0 0.00 CD4-321 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftK6) 10/5/2006 DOYON 19 NANUO KUPARUK Development 19,604.0 AFE / RFE / Maint.# Total AFE Amount Average ROP (ftlhr) 10146270 6,964,464.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6) Surface, 3,504.OftKB Ops and Depth ~ Morning Report Daily Cost Total Cummulative Cost Nippling up BOP. 319,501.28 1,055,169.35 24hr Forecast Daily Mud Cost Cummulative Mud Cost NU and test BOP. LD 4" DP & PU 5" DP. 6,151.28 57,347.35 Last 24hr Summary Finished wiper trip. Circ hole clean. POOH and laid down BHA. RU and ran 90 Jts 9 5/8" casing and cemented same. General Remarks Weather Head Count 28 NE 38-57 mph 46.0 ~ s .~;~~ _ i ~~E - - _ - _ _-- ' Donnie Lutrick Rig Supervisor Larry Hill IRig Supervisor Time Lo Stat2 End Dur 'i 1 T}me bepth Start Depfh Bid Time Time (hrs) Ft as~~ Op Code OpSub-Co_. P-N-T Trbl ~;odc '~ Trbl Class. IftKRj (ftK.B~~ CommfOperation 00:00 00:30 0.50 SURFAC DRILL WPRT P 2,855.0 3,452.0 RIH from 2895' to 3452'. 00:30 01:30 1.00 SURFAC DRILL CIRC P 3,452.0 3,514.0 Break circulation. Wash to 3514'. Circulate hole clean at 650 gpm and 40 rpms. 01:30 08:00 6.50 SURFAC DRILL TRIP P 3,514.0 250.0 POH on trip tank to 850'. Slight swabbing. RIH w/ 3 stds. Pump out 7stds at 3 bpm to 474'. Stand back HWDP. No hole problems. 08:00 10:00 2.00 SURFAC DRILL PULD P 250.0 0.0 Std back NMFC and jars. Download MWD. LD BHA #1 10:00 12:00 2.00 SURFAC CASING RURD P 0.0 0.0 RD DP equipment. RU csg equipment. 12:00 15:30 3.50 SURFAC CASING RNCS P 0.0 1,924.0 PJSM. Ran 50 jts 9 5/8" 40# L-80 BTCM casing 1,924'. 15:30 16:30 1.00 SURFAC CASING CIRC P 1,924.0 1,924.0 Circulated Casing working up to 4.5 BPM ICP 400 psi FCP 330 psi. 16:30 19:30 3.00 SURFAC CASING RNCS P 1,924.0 3,504.0 PJSM. Ran 40 jts 9 5/8" 40# L-80 BTCM casing 3,465'. Made up landing jt and landed casing @ 3,504'. Laid down Franks tool and made up cement head. 19:30 21:30 2.00 SURFAC CEMENT CIRC P 3,504.0 3,504.0 Circulated Casing working up to 7 BPM ICP 570 psi FCP 340 psi. 21:30 00:00 2.50 SURFAC CEMENT DISP P 3,504.0 0.0 Cement 9 5/8" casing as follows: Pumped 40 bbls Biozan water w/ nut plug as marker w/ rig pumps -Line up Dowell & pump 10 bbls CW-100 -Test lines to 2500 psi -Pumped 30 bbls CW-100. Mix & pump 50 bbls MudPush @ 10.5 ppg @ 5 bbl/min @ 210 psi -Mix & pump Lead slurry (ASL) @ 10.7 ppg @ 7.5 bbls/min @ 230 psi -Observed nut plug marker @ shakers w/ 381 bbls lead slurry pumped -pumped down surge can - 391 bbls lead slurry pumped -Switched to tail slurry (G w/ 1 -S002, .20% D046, .30% D065) Mixed & pumped 48 bbls @ 15.8 ppg @ 5.4 bbls/min @ 250 psi -dropped top plug & chased w/ 20 bbls water f/ Dowell -Switched to rig pumps & displaced w/ 9.8 ppg mud @ 7 bbls/ min for 220 bbls (400 to 700 psi) slowed pump to 4 bbls/min for last 19.7 bbls of displacement (500 to 600 psi) 240 bbls total displacment -Bumped plug w/ 1100 psi - Checked floats OK - CIP @ 2350 hrs. -Full circulation throughout job w/ 160 bbls 10.7 ppg cmt to surface Latest BOP Test Data - -- - -- - - Date ---- _ Comment ~ Page 1/2 Report Printed: 11/14/2006 Daily Drilling Report CD4-321 Report Date: 10/8/2006 Mud Check Data ~} - ~ -- - e - - :Ibtn Mme,. 1 ppftn ` m} F1l HF' F iC oc~srt, I emp ~ he :'o~r. : ` r, ~sxr fF C __ _~ ) ~) MF3r t htl` nL ~Jmini ~ hl ~~ rv T.. ..p_ Deph ifih6) G_n_ h a.y ~ ! Jia (a/y(j F'v C.aiciWj v~;~J;.l ~,~ 1ds ,,,,, l0m ~ I'3J, p S ud Mud 28.0 22.000 1 ~ 000 36.000 54.000 3~ 5 3 ~' p _ _ - 3.514.0 9 3~ 73 ~- J -- - - -- ~ -- - - ~ i QO r ,Injection Fluid (Drill J. Drilli _~ -- - -- FIuId S uii ~' From Lea: tbi;- L ti ~abon N e ~ 10.01CD4-208 ..From CD4-321 r - - - - -- >trings: BHA No. 1 -Surface / Bit Run_No. 1 - 12 1/4in, Hughes';`.Christensen, MXL-1, 6044769 In (ftK6) Depth Out (ftK6) TFA (incl Noz) (in') Nozzles (/32") (ADC Bit Dull String Wt (10001bf) WOB (max) (100... WOB (mm) (1000... 114.0 ~ 3,514.0 0.75 I 12/16/18/16 2-4-WT-G-E-1-NO-TD 44 ~ 0 0 >tring Components Item De .iq~llon - GD (in) IG [r-,i Top (,u i S, I~~n1 ~ Top~?hread Motor with Stabilizer 8 4.947 6 5/8 H 90 Float Sub 7 7/8 3.000 6 5/8 H 90 Stabilizer 8 2.875 6 5/8 H 90 MWD (DM) 7.99 3.000 6 5/8 Reg MWD (HCIM) 7.98 1.920 6 518 Reg MWD (TM) 8.02 3.250 6 5/8 H 90 UBHO 8 3.500 6 5/8 H 90 NMDC 7 1/2 2.813 6 5/8 H 90 NMDC 7 3/4 2.813 6 5/8 H 90 Drilling Jars -Mechanical 7 3/4 2.750 4 1/2 IF HWDP 5 3.000 41/2 1F -:ari iftKB) 3,51 4 m - -- - - ---- -- --- - Lin iiq Time Slidin Hrs T Cvrn U ill n rflpwi End 3 O 14.6 rrsi (mir ~ G ~ ~ 3 ~~~h ~ Time iF~ra3 Ir 1 Uepth (~ ~~ i aP~T) L'VG8 ilbY RPM (rr 1 i ~PF iF,-i) _~.. - _. _ --~- - F - } - - - - -. _. 600 30 0 60 30.03 32.24 37.83 48.71 57.35 67.17 69.67 100.27 128.90 163.18 886.39 Ur IIT 3.500.01 Wellbores - - Wellbore Na me - Wellbore APIIUWI CD4-321 , 501032053600 '~ion Size (in} Ret Top {ftKB} Act Btrn (ftK6 i cart Date End Date PROD1 6 1/8 COND1 16 0.0 114.0 10/4!2006 10/4/2006 SURFAC 12 1/4 114.0 3,514.0 10/5!2006 10/7/2006 INTRMI 8 3/4 3.514.0 1 - - - --- 9,337.0 10/11/2006 -- 10/17/2006 -- -- _ 'Cement -_ __ Surface Casin Cement -Started 10/8/2006 Type Wellbore String Cement Evaluation Results casing CD4-321 Surface, 3,504.OftK6 160 Bbls to surface. Stg No. Description Top (ftK6) Bottom (ftK6) Q (end) (bbl/... P (final) (psi) 1 Surface Casing Ceme nt 0.0 3,504.0 4 570.0 Fluid .Class Amour i 's-rk-1 V bbl Densrt Ib`~al) field t2'Isack Est To ftKB E,t 6tm i~,YP'~ Lead Cement G 493 391.0 10.70 * 4.45 36.6 2,980.0 Tail Cement G 48 48.0 15.80 1.17 2,980.0 3,504.0 Page 2/2 Report Printed: 11/14/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-321 Rig: Doyon 19 Date: 10/11/2006 Volume Input Volume/Stroke _ Pum Rate: Drilling Supervisor: Lutrick/Mickey Pump used: ~i #2 Mud Pump _ ~ P Strokes ~ 0.1000 Bbls/Strk'I ~ 8.OO ~~ Strk/min ~ Type of Test: openholeTest LOT/Fir ~ umping down driupipe• ~ Casin Test Pressure In te rit Test Hole Size: 8-3/4" ~ Casin Shoe De th Hole De th Pum in Shut-in Pum in Shut-in RKB-CHF: 36.7 Ft 3504.0 Ft-MD 2385.0 Ft-TVD 3534.0 Ft-MD 2395.0 Ft-TVD Strks psi Min si Strks si Min si Casing Size and Description: ~ 9-5/8" 40#/Ft L-so BTC ~ 0 0 2500 0 20 0.00 1020 Casin Test Pressure Int e rit Test 2 50 1 2500 1 30 0.25 960 Mud Weight: 9.8 ppg Mud Weight: 9.6 ppg 4 110 2 2500 2 55 0.50 910 Mud 10 min Gel: 21.0 Lb/100 Ft2 Mud 10 min Gel: 23.0 Lb/100 Ft2 6 240 3 2500 3 140 1.00 850 Test Pressure: 2500.0 psi Rotating Weight: ####### Lbs 8 460 4 2500 4 , 240 1.50 82 Rotating Weight: ###### Lbs Blocks/Top Drive Weight: 74000.0 Lbs 10 650 5 2500 5 ~ 340 2.00 7 Blocks/Top Drive Weight 74000.0 Lbs Desired PIT EMW: 18.0 ppg 12 800 6 2500 6 , 440 2.50 7 Estimates for Test: 2.3 bbls Estimates for Test: 1042 psi 1 bbls 14 975 7 2500 7 525 3.00 765 _ ~~ ~ ~I 16 1100 8 2500 8 630 3.50 750 __ _ EMW =Leak-off Pressure + Mud Weight = 1045 PIT 15 Second 18 1250 9 2500 9 700 4.00 745 + 9 6 0.052 x TVD 0.052 x 2385 Shut-in Pressure, si 20 1400 10 2500 10 765 4.50 745 EMW at 3504 Ft-MD (2385 Ft-ND) = 18.0 960 22 1570 15 2500 11 820 5.00 740 sooo - - Lost 0 psi during test, held 100% 24 1750 20 2500 12 860 5.50 740 - ___ _ of test pressure. 26 1900 25 2500 13 890 6 00 735 . - ~ 28 2150 30 2500 14 930 6.50 735 2500 - 30 2300 15 960 7.00 735 -- __ _ 32 2510 16 990 7.50 730 17 1020 8 00 725 ~ . 2000 18 1045 8 50 725 w . _ _ 9.00 725 N 1500 _ 9.50 725 . w 10.00 72 ~ a - looo --- - -- - - _ - -_ __ ~j - 500 - - - ~ -- t 0 0 1 2 3 4 0 5 10 15 20 25 ~ Barrels Shut-In time, Minutes ~~CASING TEST (LEAK-OFF TEST O PIT Point Vol Pum ume ed Vol Bled ume Back Vol Pu ume m ed Vol Bled ume Back s s s s Comments: Tested 9 5/8" csg after bumping plug on cmt. Job LV I 1..U4-JL I SUIIdI:C Summary C 7" Csg Detail ConocoPhillips Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM Company • Well: CD4-321. Date: 10/19/2006 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 34.40 FMC Gen V Hanger 2.65 34.40 Jts 230 to 454 225 Jts 7" 26# L-80 BTCM Csg 9475.54 37.05 Tam Port collar 2.80 9512.59 Jts 3 to 229 227 Jts 7" 26# L-80 BTCM Csg 9717.89 9515.39 Weatherford Float Collar 1.25 19233.28 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 86.49 19234.53 Ray Oil Tools "Sliver Bullet" Float Shoe 2.11 19321.02 7"Shoe @ 19323.13 8 3/4" hole TD @ 19337.00 8 3/4" hole TD @ 19,337' MD / 7810.53' TVD 7" Shoe @ 19323.13' MD / 7800' TVD Total Centralizers: 82 Straight blade centralizers one per jt. on jts. # 1-27 Straight blade cent. one per jt. on jts. # 228,229,230,231 Straight blade cent. one per jt. on jts. # 245, 246, 247, 248, 249, 250, 251, 252 Straight blade cent. one per jt. on jts. # 370,371,372 Straight blade cent. One every other jt. # 374 to 452 475 jts in shed - 454 total jts. to run Last 21 jts. Out Used Jet Lube Run-N-Seal i e do e Remarks: Up wt - Pulled to 400k unable to move pipe Dn wt - 150k Blocks - 70k Make up torque - -7800 ft/Ibs Supervisor.D. Burley/D. Mickey Cement Detail Report CD4-321 Intermediate Casing Cement DRILLING ORIGINAL (DRILLING 10146270 10/4/2006 10/5/2006 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 10/21/2006 05:30 10/21/2006 08:40 CD4-321 Comment - Dement Stages _ __ - - --- - -- --- - Sta e # 1 -- Descri lion P Objective J p ( ) -- To ftKB - __ - ( ) Bottom ftKB Full Return? - Cmnt Rtrn (... Top Plug? Btm Pfug? Intermediate Casing Primary 17,850.0 19,323.0 Yes 0.0 Yes Yes Cement O (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbllmin) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 5 6 940.0 1,500.0 No No Depth tagged (ftKB) lag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids S Additives - - - - Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est elm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 17,850.0 19,323.0 292 G 62.0 Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.16 5.08 15.80 Additives Additive Type Concentration Conc Unit label - -- - Sta e # 2 - - - - -- _ - - -- -J Description Objective Top (ftKB) Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Intermediate Casing Primary 8,272.0 9,512.0 Yes 0.0 No No O (start) (bbl/min) Q (end) (bbl/min) (l (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 5 5 1,000.0 No No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids 8 Additives _- _ - Fluid Fluid Type TFluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbQ CW-100 6,269.0 7,015.0 20.0 Yield (ft /sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 8.30 Additives Additive Type Concentration Conc Unit label Fluid - - --- _ _ - - - - - - - - - --- - ---- Fluid Type `Fluid Description ~ Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Mud Push 7,015.0 7,761.0 20.0 Yield (ft /sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbq Tail Cement 7,761.0 9,515.0 223 G 47.0 Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label Page 1/2 Report Printed: 11/14/2006 Cement Fluids & Additives Cement Detail Report CD4-321 Intermediate Casing Cement iriu~u Fluid Type Water/Brine Fluid Description Estimated Top (ftK8) 0.0 Est Btm (ftKB) 9,515.0 Amount (sacks) Class Volume Pumped (bbl) 0.3 Yield (ft (sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Page 2/2 Report Printed: 11/14/2006 Daily Drilling Report CD4-321 Report Date: 10/21/2006 Report Number Days From Spud (days) Depth Start (ftKB) Depth End (ftKB) Depth Progress (ft) Wellbore 18 16.29 19,337.0 19,337.0 0.00 CD4-321 Spud Date Contractor Rig Name/No Field Name Well Type Target Depth (ftKB) 10/5/2006 DOYON 19 NANUQ KUPARUK Development 19,604.0 AFE / RFE / Maint.# Total AFE Amount Average ROP (ftlhr) 10146270 6,964,464.00 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 19,323.1ffK6 Ops and Depth @ Morning Report Daily Cost Total Cummulative Cost LD swivel f/ 2nd stage cmt job 154,262.95 4,515,034.76 24hr Forecast Daily Mud Cost Cummulative Mud Cost Cut & slip DL - LD DP 5,659.95 667,603.76 Last 24hr Summary Ciro & condition mud -Cmt 7" csg -Set pack-off & test - MU tam comb tool & R1H w/ 4" DP General Remarks Weather Head Count 49.0 - -- Supervisor - -- - Title Dave burley Rig Supervisor Don Mickey Rig Supervisor Time Lo -Start End Dur Time Time (hrs) Ph,;._ np ~-oi U;~Sur ~ , _ _ pih Erxi P N T Trbl t- rir T I Ala-- t~P dart 3e KB r ,r mloperatfcn ~ ~~ ~~ ~ 00:00 05:30 5.50 INTRMI CASING ~CIRC pm @ 670 psi staged pumps 19,323.0 19,323.0 Establish circulation / 3 b P up to 6 bpm @ 820 psi -circulate and condition mud for cementing -reduced mud wt. to 10.0 ppg 05:30 05:45 0.25 INTRMI CEMENT SFTY P 19,323.0 19,323.0 PJSM -flush pumps with fresh water 05:45 09:00 3.25 INTRM1 CEMENT DISP P 19,323.0 19,323.0 Cemented 7" csg as follows: Pumped 5 bbls CW100 - Tested lines to 3100 psi -pumped 35 bbls oc CW100 - Mixed & pumped 40 bbls MudPush @ 10.5 ppg - 4.5 BPM @ 520 psi -Dropped btm plug -Mixed and pumped 62 bbls of tail slurry (292 sxs Class G w/additives) - 15.8 ppg @ 5.3 BPM @ 459 psi -Flushed cement line to floor Dropped top plug displaced w/ rig pumps with 9.6 ppg kcl brine @ 6.5 BPM for 607 bbls - 7 bpm for 89 bbls and 5 bpm last 29 bbls pumped - 725 bbls total displacement -Bumped plug w/ 1500 psi - Check floats OK CIP @ 0840 hrs.- Full returns throughout - No pipe movement -Pressure test casing to 3500 psi for 10 minutes. 09:00 10:00 1.00 INTRMI CEMENT RURD P 19,323.0 0.0 Rig down cement head ,elevators, LJ and bails 10:00 11:00 1.00 INTRM1 CASING DHEQ P 0.0 0.0 Pull wear ring -set and test packoff to 5000 psi for 10 minutes 11:00 14:45 3.75 INTRM1 WELCTL OTHR P 0.0 0.0 Change top pipe rams to 31/2" x 6" VBR's -test rams 250/5000 psi -pull test plug and set wear bushing 14:45 15:00 0.25 INTRMI CEMENT PULD P 0.0 0.0 Mu Tam Combo tool 15:00 00:00 9.00 INTRM1 CEMENT TRIP P 0.0 9,471.0 RIH w/ Combo tool picking up 4" drill pipe to 9471' (298 - jts 4" DP) -- - - -- - - -- Mud Check Data ~ V ~ ~ oh F~ r 3 ~~~pth iftK6) Derr t X ~ _ - d Cori ( ) ilf ~~n d. T~~np i i~,p ~If f 1 1Cd['1 (bf1100ft } (bf/1 r, _Ft') lio ,~~ i ~MBT ibr<,n~; ~r i~~ ~ ran i p f r ~ I i - C Br ne KCL 60 ---_L __- fnlectiore Fluid _ - - -- Fiuid Source C .t~na~on Nc~e Rom Lea iUd) : Diesel --- - _ . ~ -._.- ---- - -- --- 45.0 CD4-208 freeze protect Other 500.0 CD4-208 tank rinse Water 150.0 CD4-208 Annular flush Water Based Mud 2560.0 CD4-208 f/ CD4-321 Latest BOP Test Data _ _ Date ~ ~ CoTrn~nt 10/9/2006 250/5000 si Page 1/2 Report Printed: 11/14/2006 Daily Drilling Report CD4-321 Report Date: 10/21/2006 - - - - -- - Wellbores - __ _ -- - _ -- Wellbore Name Wellbore API/UWI GD4-~21 Section S~-- ,~~~) PROD1 6 1 /8 Act Top (#Kt3) Act Btm (ftKB 50103105:1600 I Start Date End Date COND1 16 0.0 114.0 10/4/2006 10/4/2006 SURFAC 12 1 /4 114.0 3 ,514.0 10/5/2006 10/7/2006 INTRMI 8 3/4 3,514.0 19 ,337.0 10/11/2006 10/17/2006 ;Cement - - - -- Intermediate Casin Cement -Started 10/21/2006 Type Wellbore String Cement Evaluation Results casing CD4-321 Intermediate, 19,323.1ftK6 Bond log planned post rig work Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (final) (psi) 1 Intermediate Casing Cement 17,850.0 19,323.0 5 940.0 Flwd - Class Mwunt lsa_r,~ V ~bta1 Derv ~t~ ,Ib~oa~, ', -r'ield (ft%sac- ~, Est l:.p iith:D~ Es Gtm (ftKB) i -Tail Cement G 292 62.0 15.80 1.16 17,850.0 19,323A Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl(... P (final) (psi) 2 Intermediate Casing 8,272.0 9,512.0 5 1,000.0 Fluid Class Amamt (sacks) V {bbl) i Dens6ty (dWgal) Yield (ft'/sacF,j J Est Top (ftK6) .Est Btm {ftKB) CW-100 20.0 8.30 _ _ __._ 6,269.0 7,015.0 Mud Push 20.0 10.50 7,015.0 7,761.0 Tail Cement G 223 47.0 15.80 1.17 7,761.0 9,515.0 Water/Brine 0.3 0.0 9,515.0 Page 2/2 Report Printed: 11/14/2006 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD4-321 Rig: Doyon 19 Date: 10/22/2006 Volume Input Pump Rate: Drilling Supervisor: D. Burley / D. Mickey Pump used: Cement unit ~ -- - - T f T t ~ P i d ~ Barrels ~~ ~ ~ Bbls/Strk ~ ~ 0.8 Bbl/min ~ ype O es : Annulus Leak Off Test for Disposal Adequacy - ump ng own annulus. Casin Test Pressure In te rit Test Hole Size: $-3/4" ~ ~ Casin Shoe De th Hole Depth Pumpin Shut-in Pum in Shut-in RKB-CHF: 34.4 Ft 3,504 Ft-MD 2,385 Ft-TVD _ 8,272 Ft-MD 3,9_59 Ft-TVD Bbls psi Min si Bbls si Min psi Casing Size and Description: ~" 26#/Ft L-80 BTC-MOD ~ 0 0 0 0 530 Chan es for Annula r Ade ua c Test Pressure Int e rit Test 1 1 101 0.25 495 uter casing shoe test results in comments Mud Weight: 9.8 ppg 2 2 177 0.5 475 Description references outer casing string. Inner casing OD: 7.0 In. 3 3 258 1 470 ize is that drilled below outer casing. 4 4 333 1.5 ' "'4 timated TOC for Hole Depth. 5 5 399 2 Enter inner casing OD at right Desired PIT EMW: 16.0 ppg 6 6 464 2.5 Estimates for Test: 769 psi 0.3 bbls 7 7 530 3 459 ~ ~ 8 8 586 3.5 459 ____ ___ EMW =Leak-off Pressure + Mud Weight = 803 + 9 8 PIT 15 Second 9 9 646 4 459 0.052 x TVD 0.052 x 2385 Shut-in Pressure, si 10 10 702 4.5 454 EMW at 3504 Ft-MD (2385 Ft-ND) = 16.3 495 15 11 757 5 454 loo0 20 12 803 5.5 454 25 12.5 757 6 454 30 13 620 6.5 449 -- __ - -__ --_ _ 13.5 581 7 449 14 570 7.5 449 - - -- - 14.5 565 8 449 W ~ ,! 15 560 8.5 449 ~ - - - - - 15.5 560 9 449 to soo -- - -_ - - -- ' - -- - ___ ~ 9.5 444 w 10 44 - -- a y ~c~~ - 0 0 2 4 6 8 10 12 14 16 18 0 5 10 15 20 25 30 Barrels Shut-In time, Minutes ~~CASING TEST tLEAK-OFF TEST O PIT Point Vol PUm ume ed Vol Bled ume Back Vol Pu ume m ed Vol Bled ume Back s s s s Comments: 9 5/8" casing shoe PIT = 18.0 ppg • • 07-Nov-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD4-321 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 36.90' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 19,337.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date /~- ~/~ Si ned ~ 9 Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ao~-- lY~. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD4-321, November 8, 2006 AK-MW-4668208 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20536-00. L.~(.~l- _, ~_~_ ,~ :. ~~ -~~/~ ~ 1L~aa~ • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein~admin.state.ak.us; Jim Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: ConocoPhillips Alaska, Inc FIELD /UNIT /PAD: Colville River Field /Alpine /CD4 DATE: 10/26/06 OPERATOR REP: Larry Hill AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well CD4-321 Type Inj. N ND 7,180' Tubing 700 950 950 950 Interval I P.T.D. 206-142 T e test P Test psi 3500 Casin 1,550 3,550 3,525 3,525 P/F P Notes: OA 350 350 350 350 Well Type Inj. ND Tubing Interval P.T.D. T pe test Test si Casing P/F Notes: ~ OA Well Type Inj. ND Tubin Interval P.T.D. T e test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well T Inj. ND Tubin Interval P.T.D. Ty test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waist G=Gas I =Industrial Waistewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D = D'rfferential Temperature Test INTERVAL Codes i =Initial Test 4 =Four Year Cycte V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT ReportForm BFL 9/1/05 MIT Form CD4-321 MEC:iANICAL ZIITEGRITY REPORT ~ • [C~'„ _ :_ °UD ~~ ".:.: ~ ~'U ~ OPER ~ FZELD ~~- __-C C. .... ...~:.. r_., .. ~LJI~~....-.f~ ( _ }~L1.L 1~VL11~~Lt ~~ `-~~~..~` N ~ LL DAT ~_ TD : ~C'y.~~~,1 ?~.. ~~~ ~ 'L'VD ; P BTD : ~ ~1~ ~ j ?-ID ~1~~'rVD C a s i^ g '~ ~ Shoe . ~Gl~~ ~ 2•ID °l~~C TVD ; liV . ~1~ 1 ~ '-'~ TG"')i -=:,e.. 1:~p1 Shoe. '~ '?'`TD • _Cr . ?~ID _'.J _ ~~'_- V y~~ ~ PaCKer ~ C e t c t ~~` ole S=ee t~~j~ and Perfs to ~,~ ~-~ ~~~ \~s ~~ ~ '' ~Cc..t~?Z=C~.T, ZNTEGR ~ TY - PA..RT # ~ ~n::ulus Press Test: :? Comments: CsQ ~~t~„~ DV ~-~~ a~- Cement Volt~es :~ A.mt. Liner C.~t -ro1 to cover oers t-1~ 4,h\S~c,~~ ~.~v-~n~~ S~~t~~~+e~~ 6 ,~ ~ `~ ~ - =eoretical TOC ~ ~0~~ ~S ~d~ '~c. ~~ ~~~ 1~la~l a ~ ~,~ Cement Bond Log (Yes or No) ~C:S In AOGCC File ~ ~ CBL Evaluation, gone above peril E~ ~ ~ ~ ~ Production Log: Type CONCL'JS ~ Ot1S : Part 11 j Part r2: i r r _ _ _ _ '~'CH.~NZCri, INTEGRITY - PART #2 ~"S'~~L,t,~ ~~1~~~~5 15 nin ~0 min Evaluation Re: Doyon 19 BOP test 10-23-06 • • Subject: Re: Doyon 19BOPtest 10-23-0(~ From: Thomas Maunder <tom_maunder(a7admin.state.ak.us> Date: Mon, 23 Oct 2006 13:11:30 -0800 ''o: ",fohl~son, `ern" <Vern.Johnson(uconocophillips.com=> CX': ":~l~~ord_ Chip" <Chip..'11tio«~ u~conocohhillips.eon~=>. llovon t9 Con~p~n~~ ~1an -do~~or~ l (uconocophillips.corn =~~, ,~~000C North Slope Office ao~~cc~~rudhoe_ba~'<<i':admin.state.ak.us> Vern, et al, Since there is no open hole open to the wellbore, waiving the BOP test is approved for this event. It is requested that the rig keep the Inspector notified when the next BOP test is expected. Due to weather and personnel availability, it has not been possible to witness a test at Doyon 19 and a witnessed test is desired. Call or message with any questions. Tom Maunder, PE AOGCC Johnson, Vern wrote, On 10/23/2006 11:27 AM: Tom, Per my message this morning, we would like to get a waiver for the BOP test which is due today. We are currently preparing to make a cleanout run with a bit and string mill prior to running our completion string, so we will probably start picking up the completion assembly Tuesday morning. The well has 7" casing set and cemented (19323' MD), and we have indications of good casing integrity and a good cement job. There is kill weight fluid in the cased hole and there are no perforations or open hole sections. Running the cleanout assembly is a change from the plan discussed with the slope inspectors over the weekend, this put our operations over the two week BOP test window. Let me know if you need further information. Vern Johnson 1 of 1 10/24/2006 8:32 AM RE: FW: PPT for AOGCC • • Subject: RE. FW: PPT for AOGCC From: "Wiens, JORDAN F" <JORDAN.F.Wiess cr;conocophillips.com> Date: Thu, I9 Oct ?006 16:1'.0:33 -0800 To: tong i~~aunder~a:;admin.slatc.ak.us CC: ".fohnson, Vern" ~~Vern.Johnson(ci::conocophillips.com==~, "11~razer, Lamont C^~ <Lamont.C.F~a~cr~<<-conocophillips.com== "Crumrinc. Tim 1~%illiam" ~~=Tim.~~~'.Crniz~rine~a`conocophillips.com=> ~ ~o - ~ `-~ ~-- Tom, I agree we want to make the record complete on this decision. But I would prefer not to include the parameters used wi#h these tools for this quick analysis we attempted. In the case of this well we performed a nodal analysis using two tools SNAP and PRC75PER. When the tools are used to analysis flow results on a full well scale production test such as the CD2-444, which is completed in the K-2 formation, both models provide similar results. But when these models were scaled down to the conditions discussed this week, and for the wellbore characteristics and K-~ thickness ~~~ in the CD~'--321 well the results were 2 orders of magnitude differential between the two tools, In the view of ConocoPhillips neither answer was correct right as the tools were being asked to perform in a range for which they have not been designed. Therefore ConocoPhillips has not been able to provide an analysis to meet the request of the AO~CC., and as a result ConocoPhillips has agreed to cement off the K-2 in this ellbore. ~~ ConocoPhiiiips sill wishes to pursue a means to provide a quantitative analysis for the AOGCC which ~~Il aid in the discussion and decisions to isolate the K-2. ConocoPhillips would like to consult with the A®GCC staff regarding the path forward for an appropriate analysis to meet the requirements and basis for cementing the K-2 in other well bores. Jordan F. Wiens Nanuq -Fiord Development Coordinator WNS Satellites ConocoPhillips Alaska Inc. 700 G Street Anchorage, Alaska 99501 907 263-4370 (Office) 907 351-4734 (Cell) 907 265-1515 (Fax) 1 of 3 10/24/2006 8:36 AM RE: FW: PPT for AOGCC r ~ L J -----Original Message----- From: Thomas Maunder [mailio:tom mauncler(a~.admin.state.ak.us] Sent: Thursday, October 19, 2006 7:47 AM To: Johnson, Vern Cc: Steve Davies; dave roby Subject: Re: FW; PPT for AOGCC Vern, Since this message was sent, a meeting was held during the afternoon of 10/17 to discuss the K-2 zone in CD4-321 and there were a number of phone conversations yesterday. The outcome was that the stage job will still be performed to cover the sand interval in CD4-321. In order to make the record complete on this matter, would you or one of your colleagues provide information regarding the nodal analyses. This information will provide a basis as discussions go forward regarding the K-2 in other wellbores. Thanks, Tom Maunder, PE AOGCC Thomas Maunder wrote, On 10/17/2006 1:20 PM: > Vern, > Thanks for the information regarding the K-2 as penetrated by > CD4-321. The West Team (myself, Dave Roby and Steve Davies) have > examined the information you submitted. The information submitted > shows the K-2 interval penetrated by CD4-321 to be of reservoir > quality. While the vertical thickness is only about 4', due to the > angle ~l l' of sand is open to the wellbore. We disagree with CPAI's > contention that this interval is not significant. It is appropriate > to perform the planned stage cement job to isolate this hydrocarbon > interval. > Call or message with any questions. > Tom Maunder, PE > AOGCC > Johnson, Vern wrote, On 10/17/2006 9:18 AM: » Tom, » Here are the logs I mentioned this morning. This is the basis for » our evaluation that the K2/Qannik is not significant and does not » warrant isolation. » If needed, we can set up a conference call or take a walk over to » your office to discuss. Let me know what you think. » Vern » -----Original Message----- » *From: * Yeaton, Jeffrey William *Sent: * Tuesday, October 17, 2006 » 9:02 AM » *To: * Johnson, Vern » *Cc: * Hannon, Renee; Wiess, JORDAN F » *Subject: *PPT for DNR • 2 of 3 10/24/2006 8:36 AM CD4-17 K-2 Log Analysis (Klein Model, real time logs) Net Oil Pay: 12.3ft Avg Por (pay): 23.5% Avg Avg n u n u CD4- 17_PRELIM 3175ft .] Gfi i 2N 271e ~D 1 56 CD4-321_PRELIM f s, RD 20 120 ~ __, 20 1?0 rm~ • • a ~ x. ~ a ~ W ~ - C7 ~ ~ r ~ z~m~ ~ ~ N N ~ ~ ~ n ~ -• O _+: ~ ~ 00 ~ N (n "'~• y, ~- ~~~..rJ' ~j}Z~~p1"QL - ^Yc~ l~ ~ I .~ ,1 ,~ ~ _ - ~ i~ :' ~ (-}~ ~~~ ~ ~'? _ i- t .~.~ -~~s -._. l .may _ ~ J 6J r__- ' I~-+ `'~'' ,GJ~ _ _ _ _ ~ __j _ o ~ ~-- - ~'-~ --_ - (_ --' CD4-321 Preliminary Log Analysis K-2 Upper Lobe Net Oil Pay: 3.9ft 0 ft Net Oil Avg Por (pay): 24.5% (cemented; Avg Perm (pay)_35md I I I _ I K-2 Lower I she ' ~ STATE OF ALASKA ~ 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: dim ~~e~g :n)~adn:i:~.stute.ak.u~ uG`~~: ~`I_E~i1b8 pf:~~.ad¢~~n.s~tate.uk.us br_:Iv :~eckenJte~n~:~3aor~:t:~.stute.a~c.~~~' Contractor: Doyon Rig No.: 19 DATE: 10/9/2006 Rig Rep.: Krupa / Grazulis Rig Phone: 670-4302 Rig Fax: 670-4303 Operator: Conoco Phillips Alaska Op. Phone: 670-4300 Op. Fax: 670-4301 Rep.: Lutrick /Hill Field/Unit & Well No.: Colville Rv CD4-321 PTD # 206-142 Operation: Drlg: x Test: Initial: x Test Pressure: Rams: 250/5000 MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 13-5/8 P Pipe Rams 1 3-1/2x 6 P Lower Pipe Rams 1 3-1/2x 6 P Blind Rams 1 blinds P Choke Ln. Valves 1 3-1/8 P HCR Valves 2 3-1/8 P Kill Line Valves 1 3-1/8 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Workover: Weekly: Annular: 250/3500 Explor.: Bi-Weekly Valves: 250/5000 TEST DATA FLOOR SAFETY VALVES: Test Result Quantity Test Resu P Upper Kelly 1 P P Lower Kelly 1 P P Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Resu No. Valves 16 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Resu System Pressure 3200 P Pressure After Closure 1525 P 200 psi Attained 31 P Full Pressure Attained 2 min 50 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ 1900 psi Test Results Number of Failures: 0 Test Time: 4-1/4 Hours Components tested 28 Repair or replacement of equipment will be made within n/a days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervises at: dim re~~~asrrr:i:~_state.ak.u~ Remarks: Good test. 24 HOUR NOTICE GIVEN YES X NO Date 10/08/06 Time 7:OOam Test start Waived By Chuck Scheve Witness Krupa /Lutrick Finish BOP Test (for rigs) BFL 11/09/04 Doyon19 10-9-06 CD4-321.x1s CD4-321 Permit to drill application • • Subject: CD4-321 Permit to drill application From: "Johnson, Vern" <Vern.Johnson@conocophillips.com> Date: Tue, 03 Oct 2006 09:50: ,6 -0800 To: Thomas Mau~ider ="tommaunder(ciadmi~~.state.ak.us-= ('C: ",Al~~or~l, Chip" ~~_Chip.Al~~oi~l(ciconoeophillips.com>, "Galiunas, Elizabeth C" -E ~ _abet .C.Galiunas(u%,conocophillips.com.:,, "Noel, F31~ian" <Bi-i~~n.'~loeliu conocophillips.com.- As iscussed this morning, our plans for Doyon 19 have changed in the last 24 hrs. Due to unexpected g results on CD4-17, we have decided to not continue drilling CD4-17 and move to drill CD4-321 p~Sct. CD4-16 was going to be the next well in the program, however due to the results from CD4-17 we have deferred drilling CD4-16, pending further evaluation. I delivered a copy of the permit to drill application for CD4-321 this morning. Wee ect Doyon 19 will be ~ available to spud CD4-321 as early as Thursday morning. I realize this is a mu shorter time for permit approvals than normal, but given the c rcumstances it was difficult to av id. Let me know if there is anything I can do to help expedite the process. Regards Vern Johnson 265-6081 w 748-3906 c 1 of 1 10/3/2006 10:18 AM FRANK H. MURKOWSKI, GOVERNOR 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 C. Alvord WNS Drilling Team Lead ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Nanuq-Kuparuk Oil Pool, CD4-321 ConocoPhillips Alaska, Inc. Permit No: 206-142 Surface Location: 2982' FNL, 458' FEL, SEC. 24, T11N, R4E Bottomhole Location: 1997' FNL, 1252' FEL, SEC. 28, Tl 1N, R4E Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this day of October, 2006 cc: Department of Fish 8s Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIO ~~ PERMIT TO DRILL 20 AAC 25.005 ~~~ p 3 2006 Alaska 0-~ ~ Gas Cons. Commission 1 a. Type of Work: Drill /^ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service^ Development Gas ^ Multiple Zone^ Single Zone d ~~~ 1 c. Specify if well is proposed C b Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: CD4-321 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: ~ MD: 19604' TVD: 7855` 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): Surface: 29$2° FNL, 458' FEL,. Sec 24 T11 N R4E 7. Property Designation: ADL ADL 380077, 387209, ASRCNPRA02 Nanuq Kuparuk Oil Pool Top of Productive Horizon: 1732` FNL 227° FEL. Sec. 28 T11 N R4E 8. Land Use Permit: ALK 380077 13. Approximate Spud Date: 10/5/2006 Total Depth: 1997' FNL 1252' FEL, etJG'C. 2$ T11 N R4E 9. Acres in Property: 2560 14. Distance to Nearest Property:4028 FEL ASRCNPRA02 4b. Location of Well (State Base Plane Coordinates): Surface: x- 377786 y- 5957433 ~ Zone- 4 10. KB Elevation (Height above GL): 56' RKB feet 15. Distance to Nearest Well within Pool: CD4-318 , 4748 ' 16. Deviated wells: Kickoff depth: 336 ft. Maximum Hole Angle: 71 ° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3554 psig - Surface: 2841 psig ' 18. Casing Program if ti S Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24'° 16" 62.5 H-40 ~~leided 77 37 37 114 114' pre-installed 12.25" 9-5,`8" 40~ L-8? BTC 3452 37 37 3489 2400 693 sx AS Lite3, 230 sx 15.8 G 8.75" 7" 26# L-80 BTCM 19557 37 37 19594 7850 77sx Litecee#e lead/106sx 15.8G tail 2nd stage 51 sx ASL3 4.5" 12.6 L-80 IBT-M 18168 32 32 18200 7224 tubing 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee /^ BOP Sketch^ Drilling Program^/ Time v. Depth Plot ^ Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ~/ 20 AAC 25.050 requirements ^~ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact V. JOhnso7l Printed Name C. Alvord Title WNS Drilling Team Lead Signature / /'1/.~ Phone Z(~~ ,~ ~,~ Date (9~~ ~ Z oo (, "(,~, ('~+' ~ Commission Use Only ' Permit to Drill / ~7 Number: 2~(Q ~ ~~G-- API Number: 50-~~~ ?Q~~v/p " ~ Permit Approval Date: . See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: ~rs~ ~~,,~~--CL~\~~a~ `~ p Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No [,]~ Other: ~ H2S measures: Yes ^ No [/]~ Directi svy req'd: Yes [~ No ^ 35~~ ~` >I-•~i~~~or~~®T' e~-k-, 9t~~c~z wci~~~~ ~O A ~ •c7 SCinIC~~ ~~c-o.~o.-~`«`. ~c~c c~ `~' ~ ADO ~ `Z . ~csCC~~ `1 ~~t~ o c ~ \ i~, c~~ .~-k~50 ~.G ~ -D ~ APPROVED BY THE COMMISSION COMMISSIONER Form 10-401 Revised 12/2005 /.~ n Duplicate ~ ;~~~ • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 2, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD4-321 Dear Sir or Madam: ConocoPhi~li s ~p y 0 = o n _~ ~. H O c ~ a~i ca N n ~ o °' • ~ N_ O m (Tl C m ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore injector well from the Nanuq CD4 drilling pad. The intended spud date for this well is 10/5/2006. It is intended that ~ Doyon Rig 19 be used to drill the well. r CD4-321 will be drilled through the primary target Kuparuk interval then through the Alpine reservoir for evaluation purposes. After setting 7" intermediate casing, the horizontal section will be drilled and the well completed as a perforated injector. At the end of the rig work program, the Kuparuk interval will be perforated then flowed back to mitigate reservoir damage. The well will then be closed in awaiting completion of well work and facilities connection that will allow the well to begin injection. It is expected that the K2 (Qannik) sand could be considered a significant hydrocarbon bearing / zone. Hydraulic modeling indicates that it is not technically feasible to place cement from the 7" casing shoe up to 500' above the K2, due to the distance between the two points, so a variance under 20 AAC 25.030 (g) is necessary. It is planned to pump lead and tail cement, then open a stage tool and pump a second cement job to isolate the K2 with 500' of cement above and ~ below the interval. This will leave a mud gap between the two stages. It is requested that a waiver of the diverter requirement under 20 AAC 25.035 (h)(2) be granted. There have been 7 surface holes drilled at CD4 and there has not been a significant show of / shallow gas or gas hydrates. It is also requested that the packer placement requirement be relaxed to place the completion packer +/-315 ft MD above the Kuparuk reservoir. This will allow sufficient measured depth (200 ft) between the tubing completion and the reservoir to allow wireline tools to evaluate cement quality. 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. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program 4. A drilling fluids program summary. 5. Pressure information as required by 20 ACC 25.035 (d)(2). 6. 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 diverter set up. If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. Sinc y, ~~/~~6 Vern Johnson Drilling Engineer Attachments cc: CD4-321 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1700 Liz Galiunas ATO 1704 Jack Walker ATO 1740 Lanston Chin Kuukpik Corporation • CD4-321 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) 12-1/4" Hole / 9-5/8" Casing Interval Event Risk Level Miti ation Strate Conductor Broach Low Monitor cellar continuous) Burin interval. Well Collision Low G ro sin le shots, travelin c tinder dia rams Gas Hydrates Low Monitor well at base of permafrost, increased mud ' weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud tem eratures Running Sands and Gravel Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Abnormal Pressure in Low Increased mud weight Surface Formations >2000' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of low densi cement slurries 8-3/4" Hole / 7" Casing Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned well bore. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well ' control ractices, mud scaven ers • ~ Fiord : CD4-321 Procedure 1. Move on Doyon 19. 2. Drill 12?/" hole to the surface casing point as per the directional plan. (Directional/MWD). 3. Run and cement 9-5/8" surface casing. 4. Install and test BOPE to 5000 psi. 5. Pressure test casing to 2500 psi. 6. Drill out 20' of new hole. Perform leak off test. 7. Pick up and run in hole with 8-3/4" drilling BHA. 8. Drill 8-3/4" hole to casing point in the through the Kuparuk sand then Alpine A sand (for evaluation). (LWD Program: GR/RES/DENS/POROSITY/PWD) , 9. Run and cement 7" casing as per program. Carry out a 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. 10. Run 4-%2, 12.6#, L-80 tubing with DB profile, tubing conveyed pressure gauges, packer, sliding sleeve, XN profile and wireline entry guide. Land hanger. 11. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 12. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 13. Circulate tubing to diesel and install freeze protection in the annulus. 14. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 15. Set BPV and secure well. Move rig off. Post rig well work will include pulling the ball and rod assembly, running cement evaluation logs below the tubing tail, perforating the Kuparuk interval and setting an injection valve. • ~ Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD4-320 is the closest well. Well separation is 20' @ 375' MD. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Kuparuk 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. DRILLING FLUID PROGRAM SPUD to 9-5/8"surface casing oint -12'/" Intermediate hole to 7" casing point - 8 %" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg PV 10 - 25 YP 20 - 60 15 - 25 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 minute gels <18 API Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 PH 8.5-9.0 9.0-10.0 KCL Surface Hole: A standard high viscosity fresh water /gel spud mud is recommended for the surface interval. Keep flow line viscosity at ± 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel /polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. • CD4-321 Nanuq Kuparuk Injector Completion 16" Insulated Conductor to Uodated 10-2-06 VTJ -114' 4-''/z" 12.6 ppf L-80 IBT Mod. Tubing 3.81" DB Landing Nipple 9-5/8" 40 ppf L-80 BTCM Surface Casing 3489' MD / 2400' TVD TOC Stage ''' +/- 8297' MD / 3977 TVD cementing tool +/- 9357 MD / 4325' TVD ' K2/Qannik sand n (~ ~n I +/_ 8797' MD / 4141' TVD Upper Completion: Top MD TVD Angle 1) Tubing Hanger 32' 32' 0 2) 4-1/2", 12.6#/ft, IBT-Mod Tubing 3) Camco DB nipple 3.81" 2300' 1972' S9 4) 4-1/2", 12.6#/ft, IBT-Mod Tubing 5) Baker CMD Sliding Sleeve w/ X 3.81" Profile 17888' 7122' 71 6) 4-1/2", 12.6#/ft, IBT-Mod Tubing w/ special Clearance couplings (2) 7) Weatherford 7500 psi mPOD2 Gauge and Gauge Carrier ID=3.958", OD=6.145" 17988' 7155' 71 8) 4-1/2", 12.6#/ft, IBT-Mod Tubing w/ special Clearance couplings (2) 9) Baker Premier Packer 18088' 7187' 71 10) 4-1/2", 12.6#/ft, IBT-Mod Tubing (2) 11) HES "XN" (3.725") 18188' 7220' 71 12) 4-1/2", 12.6#/ft, IBT-Mod Tubing (1) 13) Wireline entry guide 18200' 7224' 71 Top of cement 500' above top of Kuparuk / 200' MD above packer 17888' MD / 7122' TVD ~,,` +/- 20' perforations Kuparuk C 18401' MD / 7290' TVD Alpine A 19053' MD / 7555' TVD 7" 26 ppf L-80 BTC Mod Production Casing @ +/-53° 19604' MD, 7855' TVD (TD will likely be closer to the bottom of the Alpine A formation) • • CD4-321 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 Size in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 3489 / 2400 14.5 1087 1571 7" 19604 / 7855 16.0 3555 2842 • NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASPS 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 Ib/gal 0.052 =Conversion from Ib./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 ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1]x114=53 psi OR ASP =FPP - (0.1 x D) = 1087 - (0.1 x 2400') = 846.7 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1 ] D _ [(14.5 x 0.052) - 0.1 ] x 2400 = 1571 psi OR ASP =FPP - (0.1 x D) = 3555 - (0.1 x 7132') = 2842 psi • • Cementing Program: 9 5/8" Surface Casing run to 3489' MD / 2400' TVD. Cement from 3489' MD to 2989' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2989' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost (1850' MD). Lead slurry: (3489'-1850') X 0.3132 ft3/ft X 1.5 (50% excess) = 770 ft3 below permafrost 1850' X 0.3132 ft3/ft X 4 (300% excess) = 2317.7 ft3 above permafrost Total volume = 770 + 2317.7 =3087 ft3 => 693 Sx @ 4.45 ft /sk System: 693 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% 5001 accelerator, 50% D124 extender and 9% BWOWI D044 freeze suppressant Tail slurry: 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 19604' MD / 7855' TVD Cemented in two stages First Stage: Cement from 19604' MD to 19104' MD with Class G + adds @ 15.8 PPG, and from 19104' MD to 17888' MD (200' above packer depth, and 500' above Kuparuk C sand) with LiteCRETE @ 11.0 ppg. Assume 40% excess annular volume Lead: (19104'-17888') X 0.1503 ft3/ft X 1.4 (40% excess) = 255.9 ft3 annular vol. Total Volume = 255.9 ft3 => 77 Sk @ 3.35 ft3/sk System: 77 Sx LiteCrete with 0.4% D046 antifoamer, 1.0 % D065 dispersant, 0.010% B155 retarder, 0.25% D167 fluid loss @ 11.0 PPG yielding 3.35 ft3/sk Tail: (19604' -19104') X 0.1503 ft3/ft X 1.4 (40% excess) =105.2 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume = 105.2 + 17.2 = 122.4 ft3 => 106 Sx @ 1.16 ft3/sk System: 106 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 ' By Weight Of mix Water, all other additives are BWOCement • Second Stage: Cement from ports in a stage tool set 500' below the K2 interval to +/- 500' above the K2 interval with ArcticSet Lite 3 @ 10.7 ppg. Assume 40% excess annular volume Lead: (9357'-8297') X 0.1503 ft3/ft X 1.4 (40% excess) = 223.0 ft3 annular vol. Total Volume = 223 ft3 => 51 Sk @ 4.45 ft3/sk System: 51 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.45 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW1 D044 freeze suppressant ~ By Weight Of mix Water, all other additives are BWOCement ~ i ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Ina Date: 9/21/2006 Timer 13:33:32 Page: 1 Field: Colville River Unit Co-ordinate(NE) Reference: WeIL• Plan: CD4-321', True North ' Site: Alpine CD4 Vertical (TVD) Reference: Plan: CD4-321 55.3 Well: Plan: CD4-321 Section (VS) Reference: Well. (O.OON,O.OOE,255.58Azi)' Wellpath: Plan: CD4-321 Survey Calculation Method: Minimum Curvature Db: Oracle Plan: CD4-321wp04 Date Composed: 7/27/2006 Version: 10 Principal: Yes Tied-to: From Well Ref. Point Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) . Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: Alpine CD4 Site Position: Northing: 5957526.10 ft Latitude: 70 17 32.966 N From: Map Easting: 378174.70 ft Longitude: 150 59 10.763 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.93 deg Well: Plan: CD4-321 Slot Name: Alpine CD4 Well Position: +N/-S -99.32 ft Northing: 5957433.08 ft Latitude: 70 17 31.989 N +E/-W -387.42 ft Easting : 377785.75 ft Longitude: 150 59 22.054 W Position Uncertainty: 0.00 ft Wellpath: Plan: CD4-321 Drilled From: Well Ref. Point Tie-on Depth: 36.30 ft Current Datum: Plan: CD4-321 Height 55.30 ft Above System Datum: Mean Sea Level Magnetic Data: 9/20/2006 Declination: 23.05 deg Field Strength: 57548 nT Mag Dip Angle: 80.66 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 255.58 Survey Program for Definitive Wellpath Date: 12/1/2004 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 36.30 0.00 0.00 36.30 0.00 0.00 0.00 0.00 0.00 0.00 336.30 0.00 0.00 336.30 0.00 0.00 0.00 0.00 0.00 0.00 2698.00 70.85 255.58 2140.48 -319.60 -1242.94 3.00 3.00 0.00 255.58 18403.40 70.86 255.58 7291.00 -4014.33 -15612.38 0.00 0.00 0.00 2.59 CD4-321wp04 T1 19604.53 52.84 255.58 7855.30 -4276.97 -16633.88 1.50 -1.50 0.00 180.00 Survey MD Incl Azim TVD Sys TVD N/S E1W MapN MapE DLS VS Comme t ft deg deg ft ft ft ft ft ft deg/100ft ft 36.30 0.00 0.00 36.30 -19.00 0.00 0.00 5957433.08 377785.75 - 0.00 0.00 Surface location 100.00 0.00 0.00 100.00 44.70 0.00 0.00 5957433.08 377785.75 0.00 0.00 200.00 0.00 0.00 200.00 144.70 0.00 0.00 5957433.08 377785.75 0.00 0.00 300.00 0.00 0.00 300.00 244.70 0.00 0.00 5957433.08 377785.75 0.00 0.00 336.30 0.00 0.00 336.30 281.00 0.00 0.00 5957433.08 377785.75 0.00 0.00 KOP; 336' MD, 3 400.00 1.91 255.58 399.99 344.69 -0.26 -1.03 5957432.83 377784.72 3.00 1.06 500.00 4.91 255.58 499.80 444.50 -1.75 -6.79 5957431.44 377778.93 3.00 7.01 600.00 7.91 255.58 599.16 543.86 -4.53 -17.60 5957428.84 377768.08 3.00 18.18 700.00 10.91 255.58 697.81 642,51 -8.60 -33.44 5957425.03 377752.18 3.00 34.53 784.09 13.43 255.58 780.00 724.70 -13.01 -50.61 5957420.89 377734.94 3.00 52.26 Base Permafrost 800.00 13.91 255.58 795.46 740.16 -13.95 -54.25 5957420.02 377731.28 3.00 56.02 'T WELL DETAILS Name +N/-S +E/-W Northing Easting Latitude Longitude Slot Plan: CD4-321 -99.32 -387.42 5957433.08 377785.75 70°l7'31.989N 150°59'22.054W N/A WELLPATH DETAILS Plan: CD4-321 Rig: Doyon 19 Ref. Datum: Plan: CD4-321 55.30ft V.Section Origin Origin Starting Angle +N/-S +E/-W From TVD 255.58° 0.00 0.00 36.30 T ~ ~ M Azimuths to True North Magnetic North: 23.05° Magnetic Field Strength: 57548nT Dip Angle: 80.66° Date: 9/20/2006 Model: bggm2006 SURVEY PROGRAM Depth Fm Depth To Survey/Plan Tool 36.30 1000.00 Planned: CD4-321wp04 V10 CB-GYRO-SS 1000.00 19604.53 Planned: CD4-321wp04 V10 MWD+IFR-AK-CAZ-SC a 2 [-- 5000 KOP; 336' MD, 336' TVD, 3° DLS Start sail; 70.9° Inc for 15705' 9 5/8" cs x 12 1/4' ; 3489' MD, 2400' TVD - - __ --.__ - ~. 5 _ - T1; 18403' MD, 7291' TVD _ -- ' rT''c~ ° `.' o o0 o n _ ? °0 0 i ~ o o o ~, ~ o o 0 ' -500 CD4-321w 04 Toe; 19604' MD, 7855' TVD, 17175' A HD ConocoPhillips i Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 9/21/2006 Time: 13 :33:32 Page: 2 Field: Colville River Un it Co-ordinate(NE) Reference: Well: Plan: CD4-321, True North Site: Al pine CD4 Vertical (TVI)) Reference: Pl an:. CD4-321 55.3 Well: Plan: C D4-321 Section (VS) Reference: Well ( O.OON,O.OOE,25558Azi) Wellpath: Plan: C D4-321 Survey Calculation Method: M inimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE DLS VS' : Comm t ft deg deg ft ft ft ft ft ft deg/100ft ft 900 .00 16. 91 255 .58 891 .85 836. 55 -20 .57 -79 .98 5957413. 82 377705. 45 3.00 82 .59 1000 .00 19. 91 255 .58 986 .72 931. 42 -28 .43 -110 .57 5957406. 45 377674. 74 3.00 114 .17 1100 .00 22. 91 255 .58 1079. 81 1024. 51 -37 .52 -145 .92 5957397. 94 377639. 25 3.00 150 .67 1200 .00 25. 91 255 .58 1170. 86 1115. 56 -47 .81 -185. 94 5957388. 30 377599. 07 3.00 191 .99 1300 .00 28. 91 255 .58 1259. 62 1204. 32 -59 .27 -230. 52 5957377. 57 377554. 31 3.00 238. 02 1400 .00 31. 91 255 .58 1345. 85 1290. 55 -71 .88 -279. 54 5957365. 76 377505. 10 3.00 288. 64 1500 .00 34. 91 255 .58 1429. 32 1374. 02 -85 .59 -332. 87 5957352. 92 377451. 56 3.00 343. 69 1600 .00 37. 91 255 .58 1509. 79 1454. 49 -100 .37 -390. 35 5957339. 08 377393. 85 3.00 403. 04 1700 .00 40. 91 255 .58 1587. 04 1531. 74 -116 .18 -451. 83 5957324. 27 377332. 13 3.00 466 .53 1800 .00 43. 91 255 .58 1660. 86 1605. 56 -132 .97 -517. 14 5957308. 54 377266. 56 3.00 533 .96 1900 .00 46. 91 255 .58 1731. 06 1675. 76 -150 .70 -586. 11 5957291. 94 377197. 32 3.00 605 .17 2000 .00 49. 91 255 .58 1797. 43 1742. 13 -169 .33 -658. 53 5957274. 49 377124. 61 3.00 679 .95 2100 .00 52. 91 255 .58 1859. 79 1804. 49 -188 .79 -734. 23 5957256. 27 377048. 61 3.00 758 .11 2200 .00 55. 91 255 .58 1917. 98 1862. 68 -209 .04 -812. 98 5957237. 30 376969. 55 3.00 839 .42 2300 .00 58. 91 255 .58 1971. 84 1916. 54 -230 .02 -894. 57 5957217. 65 376887. 63 3.00 923 .67 2400 .00 61. 91 255 .58 2021. 21 1965. 91 -251 .67 -978. 78 5957197. 37 376803. 09 3.00 1010 .62 2500 .00 64. 91 255 .58 2065. 96 2010. 66 -273 .94 -1065. 38 5957176. 52 376716. 15 3.00 1100 .03 2600 .00 67, 91 255 .58 2105. 98 2050. 68 -296 .76 -1154. 12 5957155. 15 376627. 05 3.00 1191 .66 2698 .00 70. 85 255 .58 2140. 48 2085. 18 -319 .60 -1242. 94 5957133. 76 376537. 88 3.00 1283 .38 Start sail; 70.9° I 2700 .00 70. 85 255 .58 2141 .14 2085. 84 -320 .07 -1244. 77 5957133. 32 376536. 04 0.00 1285 .27 2800 .00 70. 85 255 .58 2173 .94 2118. 64 -343 .59 -1336. 27 5957111. 28 376444. 19 0.00 1379 .73 2900 .00 70. 85 255 .58 2206 .75 2151. 45 -367 .12 -1427 .76 5957089. 25 376352. 33 0.00 1474 .20 2925 .16 70. 85 255 .58 2215 .00 2159. 70 -373 .04 -1450. 78 5957083. 71 376329. 22 0.00 1497 .97 C-40 3000 .00 70. 85 255 .58 2239 .55 2184. 25 -390 .64 -1519. 25 5957067. 22 376260. 48 0.00 1568 .67 3100 .00 70. 85 255 .58 2272 .35 2217. 05 -414 .17 -1610 .74 5957045. 19 376168. 63 0.00 1663 .13 3200 .00 70. 85 255 .58 2305 .15 2249. 85 -437 .69 -1702 .23 5957023. 15 376076. 77 0.00 1757 .60 3300 .00 70. 85 255 .58 2337 .95 2282. 65 -461 .22 -1793 .72 5957001. 12 375984. 92 0.00 1852 .07 3400 .00 70. 85 255 .58 2370 .76 2315. 46 -484 .74 -1885 .21 5956979. 09 375893. 06 0.00 1946 .53 3489 .15 70. 85 255 .58 2400 .00 2344. 70 -505 .71 -1966 .78 5956959. 45 375811. 17 0.00 2030 .76 9 5/8" 3500 .00 70. 85 255 .58 2403 .56 2348. 26 -508 .27 -1976 .70 5956957. 06 375801. 21 0.00 2041 .00 3571 .47 70. 85 255 .58 2427 .00 2371. 70 -525 .08 -2042 .09 5956941. 31 375735. 57 0.00 2108 .51 C-30 3600 .00 70. 85 255 .58 2436 .36 2381. 06 -531 .79 -2068 .19 5956935. 02 375709. 36 0.00 2135 .47 3700 .00 70. 85 255 .58 2469 .16 2413. 86 -555 .32 -2159 .68 5956912. 99 375617. 50 0.00 2229 .94 3800 .00 70. 85 255 .58 2501 .96 2446. 66 -578 .84 -2251 .18 5956890. 96 375525. 65 0.00 2324 .40 3900 .00 70. 85 255 .58 2534 .76 2479. 46 -602 .37 -2342 .67 5956868. 93 375433. 79 0.00 2418 .87 4000 .00 70. 85 255 .58 2567 .57 2512. 27 -625 .89 -2434 .16 5956846. 89 375341. 94 0.00 2513 .34 4100 .00 70. 85 255 .58 2600 .37 2545. 07 -649 .42 -2525 .65 5956824. 86 375250. 09 0.00 2607 .81 4200 .00 70. 85 255 .58 2633 .17 2577. 87 -672 .94 -2617 .14 5956802. 83 375158. 23 0.00 2702 .27 4300 .00 70. 85 255 .58 2665. 97 2610. 67 -696 .47 -2708 .63 5956780. 80 375066. 38 0.00 2796 .74 4400 .00 70. 85 255 .58 2698. 77 2643. 47 -719 .99 -2800. 12 5956758. 76 374974. 52 0.00 2891 .21 4500 .00 70. 85 255 .58 2731 .57 2676. 27 -743 .52 -2891 .62 5956736. 73 374882. 67 0.00 2985 .67 4600 .00 70. 85 255 .58 2764 .37 2709. 07 -767 .04 -2983. 11 5956714. 70 374790. 82 0.00 3080 .14 4700 .00 70. 85 255 .58 2797 .17 2741. 87 -790 .57 -3074. 60 5956692. 67 374698. 96 0.00 3174 .61 4708 .62 70. 85 255 .58 2800 .00 2744. 70 -792 .59 -3082. 49 5956690. 77 374691. 04 0.00 3182 .76 C-20 4800 .00 70. 85 255 .58 2829 .97 2774. 67 -814 .09 -3166. 09 5956670. 63 374607. 11 0.00 3269 .08 4900 .00 70. 85 255 .58 2862 .77 2807. 47 -837 .62 -3257 .58 5956648. 60 374515. 25 0.00 3363 .55 5000 .00 70. 85 255 .58 2895 .57 2840. 27 -861 .14 -3349 .07 5956626. 57 374423. 40 0.00 3458 .01 5100 .00 70. 85 255 .58 2928 .37 2873. 07 -884 .67 -3440 .56 5956604. 54 374331. 54 0.00 3552 ,48 5200 .00 70. 85 255 .58 2961 .17 2905. 87 -908 .19 -3532 .06 5956582. 50 374239. 69 0.00 3646 .95 5300 .00 70. 85 255 .58 2993 .97 2938. 67 -931 .72 -3623 .55 5956560. 47 374147. 84 0.00 3741 .42 5400 .00 70. 85 255 .58 3026 .77 2971. 47 -955 .24 -3715 .04 5956538. 44 374055. 98 0.00 3835 .88 5500 .00 70. 85 255 .58 3059 .57 3004. 27 -978 .77 -3806 .53 5956516. 40 373964. 13 0.00 3930 .35 5600 .00 70. 85 255 .58 3092 .37 3037. 07 -1002 .29 -3898 .02 5956494. 37 373872. 27 0.00 4024 .82 ConocoPhillips r- Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 9/21/2006 Time: 13:33:32 Page: 3 Field: Colville River Un it Co-ordinate(NE) Reference: Well: Plan: CD4-321, True North Site: Al pine CD4 Vertical (TVD) Reference: Pl an: CD4-321 55.3 Well: Plan: C D4-321 Section (VS) Reference: Well (O.OON,O.OOE,255 :58Azi) Wellpath: Plan: C D4-321 Survey Calculation Method: M inimum Curvature Db: Oracle Survey MD Incl Azin- TVD Sys TVD N/S E/W MapN MapE DLS VS Comme t ft deg deg ft ft ft ft ft ft deg/100ft ft 5700. 00 70. 85 255 .58 3125 .17 3069. 87 -1025 .82 -3989 .52 5956472. 34 373780. 42 0.00 4119 .29 5800. 00 70. 85 255 .58 3157 .97 3102. 67 -1049 .34 -4081 .01 5956450. 31 373688. 56 0.00 4213 .76 5900. 00 70. 85 255 .58 3190 .77 3135. 47 -1072 .87 -4172 .50 5956428. 27 373596. 71 0.00 4308 .22 6000. 00 70. 85 255 .58 3223 .57 3168. 27 -1096 .39 -4263 .99 5956406. 24 373504. 85 0.00 4402 .69 6100. 00 70. 85 255 .58 3256 .37 3201. 07 -1119 .92 -4355 .48 5956384. 21 373413. 00 0.00 4497 .16 6200. 00 70. 85 255 .58 3289 .17 3233. 87 -1143 .44 -4446 .98 5956362. 18 373321. 14 0.00 4591 .63 6300. 00 70. 85 255 .58 3321 .97 3266. 67 -1166 .97 -4538 .47 5956340. 14 373229. 29 0.00 4686 .10 6400. 00 70. 85 255 .58 3354. 77 3299. 47 -1190 .49 -4629. 96 5956318. 11 373137. 43 0.00 4780 .56 6500. 00 70. 85 255 .58 3387. 56 3332. 26 -1214 .02 -4721. 45 5956296. 08 373045. 58 0.00 4875. 03 6600. 00 70. 85 255 .58 3420. 36 3365. 06 -1237 .54 -4812. 94 5956274. 05 372953. 72 0.00 4969 .50 6700. 00 70. 85 255 .58 3453. 16 3397. 86 -1261 .07 -4904. 44 5956252. 01 372861. 87 0.00 5063. 97 6800. 00 70. 85 255 .58 3485. 96 3430. 66 -1284 .59 -4995. 93 5956229. 98 372770. 01 0.00 5158 .44 6900. 00 70. 85 255 .58 3518. 76 3463. 46 -1308 .12 -5087. 42 5956207. 95 372678. 16 0.00 5252. 91 7000. 00 70. 85 255 .58 3551. 56 3496. 26 -1331 .64 -5178. 91 5956185. 91 372586. 30 0.00 5347 .37 7100. 00 70. 85 255 .58 3584. 36 3529. 06 -1355 .17 -5270. 41 5956163. 88 372494. 45 0.00 5441 .84 7200. 00 70. 85 255 .58 3617 .15 3561. 85 -1378 .69 -5361. 90 5956141. 85 372402. 59 0.00 5536 .31 7300. 00 70. 85 255 .58 3649 .95 3594. 65 -1402 .22 -5453 .39 5956119. 82 372310. 74 0.00 5630 .78 7400. 00 70. 85 255 .58 3682 .75 3627. 45 -1425 .74 -5544 .88 5956097. 78 372218. 88 0.00 5725 .25 7500. 00 70. 85 255 .58 3715 .55 3660. 25 -1449 .27 -5636 .37 5956075. 75 372127. 03 0.00 5819 .72 7600. 00 70. 85 255 .58 3748 .34 3693. 04 -1472 .79 -5727 .87 5956053. 72 372035. 17 0.00 5914 .18 7700. 00 70. 85 255 .58 3781 .14 3725. 84 -1496 .32 -5819 .36 5956031. 69 371943. 32 0.00 6008 .65 7800. 00 70. 85 255 .58 3813 .94 3758. 64 -1519 .84 -5910 .85 5956009. 65 371851. 46 0.00 6103 .12 7900. 00 70. 85 255 .58 3846 .74 3791. 44 -1543 .37 -6002 .35 5955987. 62 371759. 61 0.00 6197 .59 7970. 93 70. 85 255 .58 3870 .00 3814. 70 -1560 .05 -6067 .24 5955971. 99 371694. 45 0.00 6264 .60 K-3 8000. 00 70. 85 255 .58 3879 .53 3824. 23 -1566 .89 -6093 .84 5955965. 59 371667. 75 0.00 6292 .06 8100. 00 70. 85 255 .58 3912 .33 3857. 03 -1590 .42 -6185 .33 5955943. 55 371575. 90 0.00 6386 .53 8200. 00 70. 85 255 .58 3945 .13 3889. 83 -1613 .94 -6276 .82 5955921. 52 371484. 04 0.00 6481 .00 8300. 00 70. 85 255 .58 3977 .92 3922. 62 -1637 .47 -6368 .32 5955899. 49 371392. 19 0.00 6575 .47 8400. 00 70. 85 255 .58 4010 .72 3955. 42 -1660 .99 -6459 .81 5955877. 46 371300. 33 0.00 6669 .93 8500. 00 70. 85 255 .58 4043 .52 3988. 22 -1684 .52 -6551 .30 5955855. 42 371208. 47 0.00 6764 .40 8600. 00 70. 85 255 .58 4076 .32 4021. 02 -1708 .04 -6642 .79 5955833. 39 371116. 62 0.00 6858 .87 8672. 22 70. 85 255 .58 4100 .00 4044. 70 -1725 .03 -6708 .87 5955817. 48 371050. 28 0.00 6927 .10 Basal K-3 8700. 00 70. 85 255 .58 4109 .11 4053. 81 -1731 .57 -6734. 29 5955811. 36 371024. 76 0.00 6953 .34 8794. 18 70. 85 255 .58 4140. 00 4084. 70 -1753 .72 -6820. 46 5955790. 61 370938. 25 0.00 7042 .32 K-2 8800. 00 70. 85 255 .58 4141 .91 4086. 61 -1755 .09 -6825. 78 5955789. 33 370932. 91 0.00 7047 .81 8900. 00 70. 85 255 .58 4174 .70 4119. 40 -1778 .62 -6917. 27 5955767. 29 370841. 05 0.00 7142 .28 9000. 00 70. 85 255 .58 4207 .50 4152. 20 -1802 .14 -7008 .77 5955745. 26 370749. 20 0.00 7236 .75 9099. 10 70. 85 255 .58 4240 .00 4184. 70 -1825 .46 -7099 .43 5955723. 43 370658. 17 0.00 7330 .36 Base K-2 9100. 00 70. 85 255 .58 4240 .30 4185. 00 -1825 .67 -7100 .26 5955723. 23 370657. 34 0.01 7331 .22 9200. 00 70. 86 255 .58 4273 .09 4217. 79 -1849 .19 -7191 .75 5955701. 19 370565. 48 0.00 7425 .69 9300. 00 70. 86 255 .58 4305 .89 4250. 59 -1872 .72 -7283 .25 5955679. 16 370473. 63 0.00 7520 .16 9400. 00 70. 86 255 .58 4338 .68 4283. 38 -1896 .24 -7374 .74 5955657. 13 370381. 77 0.00 7614 .63 9500. 00 70. 86 255 .58 4371 .48 4316. 18 -1919 .77 -7466 .23 ,5955635. 10 370289. 92 0.00 7709 .09 9600. 00 70. 86 255 .58 4404 .28 4348. 98 -1943 .29 -7557 .73 555613. 06 370198. 06 0.00 7803 .56 9700. 00 70. 86 255 .58 4437 .07 4381. 77 -1966 .82 -7649 .22 5955591. 03 370106. 20 0.00 7898 .03 9800. 00 70. 86 255 .58 4469 .87 4414. 57 -1990 .35 -7740 .71 5955569. 00 370014. 35 0.00 7992 .50 9900. 00 70. 86 255 .58 4502 .66 4447. 36 -2013 .87 -7832 .21 5955546. 96 369922. 49 0.00 8086 .97 10000. 00 70. 86 255 .58 4535 .46 4480 .16 -2037 .40 -7923 .70 5955524. 93 369830. 64 0.00 8181 .44 10100. 00 70. 86 255 .58 4568 .25 4512 .95 -2060 .92 -8015 .19 5955502. 90 369738. 78 0.00 8275 .91 10200. 00 70. 86 255 .58 4601 .05 4545 .75 -2084 .45 -8106 .69 5955480. 87 369646. 92 0.00 8370 .38 10300. 00 70. 86 255 .58 4633 .84 4578 .54 -2107 .97 -8198 .18 5955458. 83 369555. 07 0.00 8464 .85 10400. 00 70. 86 255 .58 4666 .64 4611 .34 -2131 .50 -8289 .67 5955436. 80 369463 .21 0.00 8559 .32 ConocoPhilhps Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 9/2112006 . Time: 13:33:32. Page:. 4 Field: Colville River Unit Co-ordinate(NE) Reference; Well: Plan: CD4-321; True North Site: Alpine CD4 Vertical (TVD) Reference; Plani GD4-321 55.3 Well: Plan: CD4-321 Section (VS) Reference: Well (O.OON,O.OOE,255.58Azi) Wellpath: Plan: CD4-321 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD ft 10500.00 10600.00 10700.00 10800.00 10900.00 11000.00 11100.00 11200.00 11300.00 11400.00 11500.00 11600.00 11700.00 11800.00 11900.00 12000.00 12100.00 12200.00 12300.00 12400.00 12500.00 12600.00 12700.00 12800.00 12900.00 13000.00 13100.00 13200.00 13300.00 13400.00 13500.00 13600.00 13700.00 13800.00 13810.38 13900.00 14000.00 14100.00 14200.00 14300.00 14400.00 14500.00 14600.00 14700.00 14786.26 14800.00 14900.00 15000.00 15100.00 15200.00 15300.00 15400.00 15500.00 Incl Azim TVD Sys TVD N/S E/W deg deg ft ft ft ft 70.86 255.58 4699.43 4644.13 -2155.02 -8381.17 70.86 255.58 4732.23 4676.93 -2178.55 -8472.66 70.86 255.58 4765.02 4709.72 -2202.07 -8564.15 70.86 255.58 4797.81 4742.51 -2225.60 -8655.65 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 4830.61 4863.40 4896.20 4928.99 4961.78 4994.58 5027.37 5060.17 5092.96 5125.75 4775.31 4808.10 4840.90 4873.69 4906.48 4939.28 4972.07 5004.87 5037.66 5070.45 -2249.12 -8747.14 -2272.65 -8838.64 -2296.17 -8930.13 -2319.70 -9021.62 -2343.22 -9113.12 -2366.75 -9204.61 -2390.27 -9296.10 -2413.80 -9387.60 -2437.32 -9479.09 -2460.85 -9570.59 70.86 255.58 5158.55 5103.25 -2484.37 -9662.08 70.86 255.58 5191.34 5136.04 -2507.90 -9753.57 70.86 255.58 5224.13 5168.83 -2531.43 -9845.07 70.86 255.58 5256.92 5201.62 -2554.95 -9936.56 70.86 255.58 5289.72 5234.42 -2578.48 -1.Oe04 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 5322.51 5355.30 5388.10 5420.89 5453.68 5486.47 5519.26 5552.06 5584.85 5617.64 5267.21 5300.00 5332.80 5365.59 5398.38 5431.17 5463.96 5496.76 5529.55 5562.34 -2602.00 -1.Oe04 -2625.53 -1.Oe04 -2649.05 -1.Oe04 -2672.58 -1.Oe04 -2696.10 -1.Oe04 -2719.63 -1.Oe04 -2743.15 -1.Oe04 -2766.68 -1.Oe04 -2790.20 -1.Oe04 -2813.73 -1.Oe04 70.86 255.58 5650.43 5595.13 -2837.25 -1.1e04 70.86 255.58 5683.22 5627.92 -2860.78 -1.1e04 70.86 255.58 5716.01 5660.71 -2884.31 -1.1e04 70.86 255.58 5748.81 5693.51 -2907.83 -1.1e04 70.86 255.58 5781.60 5726.30 -2931.36 -1.1e04 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 70.86 255.58 5785.00 5814.39 5847.18 5879.97 5912.76 5945.55 5978.34 6011.13 6043.92 6076.71 6105.00 6109.50 6142.29 6175.08 6207.87 5729.70 5759.09 5791.88 5824.67 5857.46 5890.25 5923.04 5955.83 5988.62 6021.41 6049.70 6054.20 6086.99 6119.78 6152.57 -2933.80 -1.1e04 -2954.88 -1.1e04 -2978.41 -1.1e04 -3001.93 -1.1e04 -3025.46 -1.1e04 -3048.98 -1.1e04 -3072.51 -1.1e04 -3096.03 -1.2e04 -3119.56 -1.2e04 -3143.08 -1.2e04 -3163.38 -1.2e04 -3166.61 -1.2e04 -3190.14 -1.2e04 -3213.66 -1.2e04 -3237.19 -1.2e04 70.86 255.58 6240.66 6185.36 -3260.71 -1.2e04 70.86 255.58 6273.45 6218.15 -3284.24 -1.2e04 70.86 255.58 6306.24 6250.94 -3307.76 -1.2e04 70.86 255.58 6339.03 6283.73 -3331.29 -1.2e04 MapN MapE DLS VS ft ft deg/100ft ft 5955414.77 369371.35 0.00 8653.79 5955392.74 369279.50 0.00 8748.26 5955370.70 369187.64 0.00 8842.73 5955348.67 369095.79 0.00 8937.20 5955326.64 369003.93 0.00 9031.67 5955304.60 368912.07 0.00 9126.14 5955282.57 368820.22 0.00 9220.61 5955260.54 368728.36 0.00 9315.08 5955238.51 368636.50 0.00 9409.55 5955216.47 368544.65 0.00 9504.02 5955194.44 368452.79 0.00 9598.49 5955172.41 368360.93 0.00 9692.96 5955150.37 368269.08 0.00 9787.43 5955128.34 368177.22 0.00 9881.90 5955106.31 368085.36 0.00 9976.37 5955084.28 367993.51 0.00 10070.84 5955062.24 367901.65 0.00 10165.31 5955040.21 367809.79 0.00 10259.78 5955018.18 367717.93 0.00 10354.25 5954996.14 367626.08 0.00 10448.72 5954974.11 367534.22 0.00 10543.19 5954952.08 367442.36 0.00 10637.66 5954930.05 367350.51 0.00 10732.13 5954908.01 367258.65 0.00 10826.60 5954885.98 367166.79 0.00 10921.07 5954863.95 367074.93 0.00 11015.54 5954841.91 366983.08 0.00 11110.01 5954819.88 366891.22 0.00 11204.48 5954797.85 366799.36 0.00 11298.95 5954775.81 366707.51 0.00 11393.42 5954753.78 366615.65 0.00 11487.89 5954731.75 366523.79 0.00 11582.37 5954709.72 366431.93 0.00 11676.84 5954687.68 366340.08 0.00 11771.31 5954685.40 366330.54 0.00 11781.11 Albian 97 5954665.65 366248.22 0.00 11865.78 5954643.62 366156.36 0.00 11960.25 5954621.58 366064.50 0.00 12054.72 5954599.55 365972.65 0.00 12149.19 5954577.52 365880.79 0.00 12243.66 5954555.49 365788.93 0.00 12338.13 5954533.45 365697.07 0.00 12432.60 5954511.42 365605.21 0.00 12527.07 5954489.39 365513.36 0.00 12621.55 5954470.38 365434.12 0.00 12703.04 Albian 96 5954467.35 365421.50 0.00 12716.02 5954445.32 365329.64 0.00 12810.49 5954423.29 365237.78 0.00 12904.96 5954401.25 365145.93 0.00 12999.43 5954379.22 365054.07 0.00 13093.90 5954357.19 364962.21 0.00 13188.37 5954335.16 364870.35 0.00 13282.84 5954313.12 364778.49 0.00 13377.32 ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaska Inc. Date: 9/21/2006 Times 13:33:32 Page: 5 Field: Colville River Un it Co-ordinate(NE) Reference: Well: Plan: CD4-321; True North Site: Alpine CD4 Vertical (TVD) Reference: P lan: GD4-321 55.3 Well: Plan: C D4-321 Section (VS) Reference: Well (O.OON,O. OOE,255.58Azi) Wellpath: Plan: C D4-321 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Intl Azim TVD Sys TVD N/S E/W MapN MapE DLS VS Comore t ft deg deg ft ft ft ft ft ft deg/100ft ft 15600. 00 70. 86 255 .58 6371 .82 6316. 52 -3354 .81 -1.3e04 5954291. 09 364686 .63 0.00 13471 .79 15700. 00 70. 86 255 .58 6404 .61 6349 .31 -3378 .34 -1.3e04 5954269. 06 364594. 78 0.00 13566 .26 15800. 00 70. 86 255 .58 6437 .40 6382 .10 -3401 .86 -1.3e04 5954247. 02 364502. 92 0.00 13660 .73 15900. 00 70. 86 255 .58 6470 .19 6414 .89 -3425 .39 -1.3e04 5954224. 99 364411 .06 0.00 13755 .20 16000. 00 70. 86 255 .58 6502 .98 6447 .68 -3448 .91 -1.3e04 5954202. 96 364319 .20 0.00 13849 .67 16100. 00 70. 86 255 .58 6535 .77 6480 .47 -3472 .44 -1.3e04 5954180. 92 364227 .34 0.00 13944 .15 16200. 00 70. 86 255 .58 6568 .56 6513 .26 -3495 .97 -1.3e04 5954158. 89 364135 .49 0.00 14038 .62 16300. 00 70. 86 255 .58 6601 .35 6546 .05 -3519 .49 -1.3e04 5954136. 86 364043 .63 0.00 14133 .09 16400. 00 70. 86 255 .58 6634 .13 6578 .83 -3543 .02 -1.3e04 5954114. 83 363951 .77 0.00 14227 .56 16500. 00 70. 86 255 .58 6666 .92 6611 .62 -3566 .54 -1.3e04 5954092. 79 363859 .91 0.00 14322 .03 16600. 00 70. 86 255 .58 6699 .71 6644. 41 -3590 .07 -1.3e04 5954070. 76 363768. 05 0.00 14416 .50 16700. 00 70. 86 255 .58 6732 .50 6677. 20 -3613 .59 -1.4e04 5954048. 73 363676. 19 0.00 14510 .98 16800. 00 70. 86 255 .58 6765 .29 6709. 99 -3637 .12 -1.4e04 5954026. 69 363584. 33 0.00 14605 .45 16900. 00 70. 86 255 .58 6798 .08 6742. 78 -3660 .64 -1.4e04 5954004. 66 363492. 48 0.00 14699 .92 17000. 00 70. 86 255 .58 6830 .86 6775 .56 -3684 .17 -1.4e04 5953982. 63 363400. 62 0.00 14794 .39 17100. 00 70. 86 255 .58 6863 .65 6808. 35 -3707 .69 -1.4e04 5953960. 59 363308. 76 0.00 14888 .86 17200. 00 70. 86 255 .58 6896 .44 6841 .14 -3731 .22 -1.4e04 5953938. 56 363216. 90 0.00 14983 .34 17300. 00 70. 86 255 .58 6929 .23 6873 .93 -3754 .75 -1.4e04 5953916. 53 363125. 04 0.00 15077 .81 17400. 00 70. 86 255 .58 6962 .02 6906 .72 -3778 .27 -1.4e04 5953894. 50 363033. 18 0.00 15172 .28 17500. 00 70. 86 255 .58 6994 .80 6939 .50 -3801 .80 -1.4e04 5953872. 46 362941. 32 0.00 15266 .75 17531. 10 70. 86 255 .58 7005 .00 6949 .70 -3809 .11 -1.4e04 5953865. 61 362912. 75 0.00 15296 .13 Top HRZ 17600. 00 70. 86 255 .58 7027 .59 6972 .29 -3825 .32 -1.4e04 5953850. 43 362849. 46 0.00 15361 .22 17700. 00 70. 86 255 .58 7060 .38 7005 .08 -3848 .85 -1.4e04 5953828. 40 362757 .61 0.00 15455 .70 17800. 00 70. 86 255 .58 7093 .16 7037 .86 -3872 .37 -1.5e04 5953806. 36 362665. 75 0.00 15550 .17 17900. 00 70. 86 255 .58 7125 .95 7070 .65 -3895 .90 -1.5e04 5953784. 33 362573 .89 0.00 15644 .64 18000. 00 70. 86 255 .58 7158 .74 7103 .44 -3919 .42 -1.5e04 5953762. 30 362482 .03 0.00 15739 .11 18031. 30 70. 86 255 .58 7169 .00 7113 .70 -3926 .79 -1.5e04 5953755. 40 362453 .28 0.00 15768 .68 Base HRZ 18100. 00 70 .86 255 .58 7191 .53 7136 .23 -3942 .95 -1.5e04 5953740. 26 362390 .17 0.00 15833 .59 18174. 65 70 .86 255 .58 7216 .00 7160 .70 -3960 .51 -1.5e04 5953723. 82 362321 .60 0.00 15904 .11 K-1 18200. 00 70 .86 255 .58 7224 .31 7169 .01 -3966 .48 -1.5e04 5953718. 23 362298 .31 0.00 15928 .06 18300. 00 70. 86 255 .58 7257 .10 7201 .80 -3990 .00 -1.5e04 5953696. 20 362206 .45 0.00 16022 .53 18302. 75 70. 86 255 .58 7258 .00 7202 .70 -3990 .65 -1.5e04 5953695. 59 362203. 93 0.00 16025 .13 Kuparuk D 18400. 00 70. 86 255 .58 7289 .89 7234. 59 -4013 .53 -1.5e04 5953674. 16 362114. 59 0.00 16117 .00 18400. 35 70. 86 255 .58 7290 .00 7234 .70 -4013 .61 -1.5e04 5953674. 09 362114. 27 0.00 16117 .33 Kuparuk C 18403. 40 70. 86 255 .58 7291 .00 7235 .70 -4014 .33 -1.5e04 5953673. 42 362111. 47 0.00 16120 .21 CD4-321wp04 T 18418. 56 70. 63 255 .58 7296 .00 7240 .70 -4017 .89 -1.5e04 5953670. 08 362097. 55 1.50 16134 .53 LCU 18500. 00 69. 41 255 .58 7323 .82 7268 .52 -4036 .95 -1.5e04 5953652. 23 362023. 13 1.50 16211 .06 18600. 00 67. 91 255 .58 7360 .21 7304 .91 -4060 .14 -1.5e04 5953630. 50 361932. 57 1.50 16304 .21 18700. 00 66. 41 255 .58 7399 .02 7343 .72 -4083 .09 -1.5e04 5953609. 01 361842, 96 1.50 16396 .36 18800. 00 64. 91 255 .58 7440 .23 7384 .93 -4105 .78 -1.5e04 5953587. 76 361754, 37 1.50 16487 .47 18900. 00 63. 41 255 .58 7483 .81 7428 .51 -4128 .19 -1.6e04 5953566. 77 361666. 86 1.50 16577 .48 19000. 00 61. 91 255 .58 7529 .74 7474 .44 -4150 .31 -1.6e04 5953546. 05 361580 .49 1.50 16666 .30 19052. 97 61. 12 255 .58 7555 .00 7499 .70 -4161 .91 -1.6e04 5953535. 20 361535 .22 1.50 16712 .86 Alpine A 19100. 00 60. 41 255 .58 7577 .97 7522 .67 -4172 .13 -1.6e04 5953525. 63 361495 .31 1.50 16753 .90 19200. 00 58 .91 255 .58 7628 .48 7573 .18 -4193 .62 -1.6e04 5953505. 50 361411 .40 1.50 16840 .20 19300. 00 57 .41 255 .58 7681 .23 7625 .93 -4214 .77 -1.6e04 5953485. 69 361328 .80 1.50 16925 .15 19400. 00 55 .91 255 .58 7736 .19 7680 .89 -4235 .58 -1.6e04 5953466. 20 361247 .56 1.50 17008 .70 19500. 00 54 .41 255 .58 7793 .31 7738 .01 -4256 .01 -1.6e04 5953447. 06 361167 .76 1.50 17090 .77 19600. 00 52 .91 255 .58 7852 .56 7797 .26 -4276 .07 -1.6e04 5953428. 27 361089 .44 1.50 17171 .32 • 19604. 53 52 .84 255 .58 7855 .30 .7800 .00 -4276 .97 -1.6e04 5953427. 43 361085 .92 1.50 17174 .94 7" ConocoPhillips Alaska, Inc. CPAI Report Company: ConocoPhillips Alaskalnc. Date: 9/21/2006 Time: 13:33:32 Page: 6 Field: Colville River Unit Co-ordinate(NE) Reference: Well: Plan: CD4-324; True North Site: Alpine CD4 Vertical (TVD) Reference: Plan: CD4-321 55.3 Well: Plan: CD4-321 Section (VS) Reference: Well (O.OON,O.OOE,255. 58Azi) Wellpath: Plan: CD4-321 Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <- Latitude --> <-- Longitade --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft CD4-321wp04 T1 7291.00 -4014.33 -1561 2.38 5953673.42 362111.47 70 16 52.349 N 151 6 56.784 W -Plan hit target Annotation MD TVD ft ft 36.30 0.00 Surface location 336.30 336.30 KOP; 336' MD, 336' TVD, 3° DLS 3489.15 2400.00 9 5/8" csg x 12 1/4"; 3489' MD, 2400' TVD 2698.00 2140.48 Start sail; 70.9° Inc for 15705' 18403.40 7291.00 T1; 18403' MD, 7291' TVD 19604.53 7855.30 Toe; 19604' MD, 7855' TVD, 17175' AHD Casing Points MD TVD Diameter Hole Size Name ft ft in in 3489.15 2400.00 9.625 12.250 9 5/8" 19604.53 7855.30 7.000 8.750 7" Formations MD TVD Formations Lithology Dip Angle. Dip Direction ft ft deg deg 784.09 780.00 Base Permafrost 0.00 0.00 2925.16 2215.00 C-40 0.00 0.00 3571.47 2427.00 C-30 0.00 0.00 4708.62 2800.00 C-20 0.00 0.00 7970.93 3870.00 K-3 0.00 0.00 8672.22 4100.00 Basal K-3 0.00 0.00 8794.18 4140.00 K-2 0.00 0.00 9099.10 4240.00 Base K-2 0.00 0.00 13810.38 5785.00 Albian 97 0.00 0.00 14786.26 6105.00 Albian 96 0.00 0.00 17531.10 7005.00 Top HRZ 0.00 0.00 18031.30 7169.00 Base HRZ 0.00 0.00 18174.65 7216.00 K-1 0.00 0.00 18302.75 7258.00 Kuparuk D 0.00 0.00 18400.35 7290.00 Kuparuk C 0.00 0.00 18418.56 7296.00 LCU 0.00 0.00 19052.97 7555.00 Alpine A 0.00 0.00 ConocoPhillips Alaska, Inc. Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 9/21/2006 Time: 13:28:00 Page: 1 Field: Colville River Unit Reference Site: Alpine CD4 Co-ordinate (NE) Reference: Well: Pla n: CD4-321, True North Reference Well: Plan:. CD4-321 Vertical (TVD) Reference: Plan: CD4-321 55.3 Reference Wellpath: Plan: CD4-321 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: CD4-321wp04 & NOT PLANNED P Interpolation Method: MD Interval: 25.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 36.30 to 19604.53 ft Scan Method: Trav Cylinder North Maximum Radius: 2156.82 ft Erro r Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 3489.15 2400.0 0 9.625 12.250 9 5/8" 19604.53 7855.3 0 7.000 8.750 7" Plan: CD4-321wp04 Date Composed: 7/27/2006 Version : 10 Principal: Yes Tied-to: From Well Ref. Point Summary <------ Offset Wellpatit --- ---a Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Alpine CD4 CD4-209 CD4-209 V4 391.98 400.00 236.36 7.45 228.91 Pass: Major Risk Alpine CD4 CD4-210 CD4-210 V3 364.81 350.00 219.89 6.59 213.30 Pass: Major Risk Alpine CD4 CD4-318 CD4-318 V6 1430.20 1475.00 60.35 24.66 35.69 Pass: Major Risk Alpine CD4 CD4-318 CD4-318A V5 1429.21 1475.00 60.30 24.63 35.67 Pass: Major Risk Alpine CD4 CD4-318 CD4-318PB1 V3 1430.20 1475.00 60.35 24.66 35.69 Pass: Major Risk Alpine CD4 CD4-319 CD4-319 V5 422.95 425.00 36.98 8.14 28.84 Pass: Major Risk Alpine CD4 CD4-320 CD4-320 V7 373.00 375.00 20.01 6.45 13.56 Pass: Major Risk Alpine CD4 CD4-320 CD4-320PB1 V4 373.00 375.00 20.01 6.45 13.56 Pass: Major Risk Alpine CD4 Nanuq 3 Nanuq 3 V1 1052.44 1000.00 95.62 16.63 78.99 Pass: Major Risk Alpine CD4 Nanuq 5 Nanuq 5 V1 252.59 250.00 181.58 4.56 177.03 Pass: Major Risk Alpine CD4 Nanuq 5 Plan: CD4-212 VO Plan: 252.59 250.00 181.58 4.58 177.01 Pass: Major Risk Alpine CD4 Plan: CD4-16 Plan: CD4-16 V1 Plan: 420.10 425.00 100.04 8.50 .91.54 Pass: Major Risk Alpine CD4 Plan: CD4-211 Plan: CD4-211wp05 VO P 370.42 375.00 200.30 7.81 192.50 Pass: Major Risk Alpine CD4 Plan: CD4-211 Prelim: CD4-211wp04 V3 37.30 35.10 199.97 No Offset Stations Alpine CD4 Plan: CD4-213 Plan: CD4-213 V1 Plan: 441.35 450.00 159.23 7.87 151.36 Pass: Major Risk Alpine CD4 Plan: CD4-214 Plan: CD4-214wp04 V2 P 371.61 375.00 140.37 7.82 132.55 Pass: Major Risk Alpine CD4 Plan: CD4-214 Prelim: CD4-214wp03 V2 37.10 35.30 140.02 No Offset Stations Alpine CD4 Plan: CD4-215 Plan: CD4-215 V1 Plan: 819.66 850.00 116.68 14.06 102.62 Pass: Major Risk Alpine CD4 Plan: CD4-222 Plan: CD4-222 VO Plan: 930.95 925.00 28.93 16.94 11.99 Pass: Major Risk Alpine CD4 Rig: CD4-17 Plan: CD4-17 V1 Plan: 372.96 375.00 80.40 7.77 72.63 Pass: Major Risk Alpine CD4 Rig: CD4-17 Rig: CD4-17 V7 517.17 525.00 76.00 9.88 66.12 Pass: Major Risk Alpine Nanuq EIS Pa~lan: Nanuq 4 Prelim: Nanuq 4 Lat A 55.30 0.00 30.06 No Offset Stations Alpine Nanuq EIS Pa~lan: Nanuq 4 Prelim: Nanuq 4 Lat B 55.30 0.00 30.06 No Offset Stations )GRAM WELL DETABS +N/-S +F/-W Northivg Lasting I.Itinde Wrlgintde Slot -9932 -387.42 5957433.08 377185.75 70°17?I 969N 150°5922.054W WA ANTI-COI. LISI(7N SETTINGS COMPANY DF,"rAdS Interpolation MethodMU Interval: '_S.OU C'.ovow~~ps Alaska lrc. Duplh Range From: 36.30 To: 19604.53 e 01'~ Macimum Range: 21 Sfi.82 Reference: Plan: CD4-3-1 u'pU4 Calculaliun Melhad: MiNmum Curvature Emir System: ISC WSA Scan Metlad: Trav Cylirder NoM Error Surtia: Elligical ~ C'esivg Warttin6 MetM~d: Rulev dew.d 75 From Colour To MD 36 250 250 500 500 750 750 1000 1000 1250 1250 1500 1500 1750 1750 2000 2000 2250 2250 2500 2500 2750 2750 3000 3000 3250 (CD4-320pB~~00 3750 :CD4-16 (PI~~iStfip~ 4000 4000 4250 n.Pw Pn, oepr. r° s n,o1 1W].ro 1964.53 PImJ.CUf-~:I~vlol vl0 NWn~nlt nK-c'gL.51 weurnnt odr,~ls Plug ('D4J11 R6 Oewm' PIm CID4l31 5530fl or~a~ a+am srwoa .snople ws Fl-W Fmo TVn From Colour To MD 36 250 250 500 500 750 750 1000 -`~. A;~ 1500 1750 ' ;<~ 750 2000 E5 ~ 00 ~~ ~ ~~ 2250 ~ ' ~ 22 2500 250 2750 30 17 17 ~ 0 / 9 ~ ~ ~ ~ ~ 1. 3 0 4500 4750 50 75 ®(i0D4-214wp03) 8250 8500 ,4 (Plan: CD4-214v 9250 94fID13 (Plan: CD4213) 9750 10000 10250 10500 10750 11000 I1~5 ~~~ lan: CD4-222) +,a'__-_l\\ ,'1®\\ ~` 11750 12000 0 12250 ~~~~~ a r'~' ~ I ~jp 12500 G/ y ` ~ ~ ~ IS 12750 1Z ~. ~; ~~`~~, ~ r 1t2307~5p0, ,I1,3~00500, 13500 13750 \ 13750 14000 D4-319 (CD~~~ 14250 14500 ---__ _ ---r 14500 14750 21 50 14750 15000 15000 15250 -318 (CD4-31811$1) 15250 ~°--- 15500 15500 15750 180 15750 16000 16000 16250 CD0.209 (CIN-309).M jor Risk CD4-?IO (CIkF?19),M jor Risk ('D4-il8 (CD¢31R), Major Risk CIW-318 (CU431RA), Mejor Risk CD4318 (CU431RPd I), M jor Risk ('D4319 (CIkL319),M jor kirk CD4-3211 (('U4320), Me,jor Riak ^~~' CU4-3^_0 (CD4320PB 1), Major Risk Nanuq 3 (Nanuq i), Mjia kisk Nanuy S (Nanuq 5), D1jor Risk NavuyS (Plan: CD4-312), Majnr kisk PWn:CD4-16 (Plan: ClN-I6),Mjor kisk Plan:CD4-?II (Plan:CD4-'_I l..~p(IS), Major Risk 16250 16500 16500 16750 16750 17000 17000 -- °-- 17250 17250 17500 17500 17750 17750 18000 18000 18250 18250 18500 18500 18750 18750 19000 19000 19250 !9250 19500 0 27 ~= z' ~ 5000 I ~ ~ p - ~ 5250 rt f __~ , / 5 5500 "` ~ /// 55 5750 -$ . ~ ~ ~ ~ 5'7 - - 6000 - ` 500 / 6250 1 ~ 5 ~ ~ b2 6500 / ' ' ~ " ~ 6SOO - 6750 17 ~ :~ ~ I~ ,, ~ e 13 j 69950 7000 14) ~4b J~~~i "- 8 - ;700 f26 7250 `s\ ~ , 9 -_ .~_-~-~ - _ 7_S 7500 25 ~ - _ ~ 7- 0 7750 - SO 8000 Z<, .; 8000 8250 r` ~~`. 8250 8500 33 21 ~ 1 i" ;~'1j AA~ 50 8500 8750 i It ~~ 8750 9000 38 Plan: CD4-222 (Plan: CD4-222) 0 9 18 9 2 0 9500 9500 - 9750 9750 10000 10000 - 10250 10250 10500 10500 10750 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre $Q~atron ft~l'44go 11250 11500 11500 11750 11750 - 12000 12000 -- -- 12250 sec MD me na 3w +N/-s +Er-w DLe6 n~a~ vse~ Target I 3630 0.00 0.00 3630 0.00 0-00 0.00 0)lu tl t1U 336.30 0.00 0.00 336.30 0.00 0.00 0.00 U n11 O.On 3 2696.00 70.88 35.58 2140.48 -319.60 -1242.94 3.00 255.5x 12x 3.:x 4 18403.40 70.86 55.58 729100 -4014.33 -15612.38 0.00 ..59 It~l?U.?1 CI}t-321wp04 T1 5 19604.53 5'_.84 3558 7855.70 -427fi.97 -16633.68 1.5(1 I81I 011 1'174.94 Nanuq 4 Lat t 19500 19750 19750 20000 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [75ft/in] 20000 20250 20250 20500 20500 20750 N O O ~ oo ~ °o a V1 N ~ V1 N O N N h O O ~ O ~ O Q M N a1 v ~, o N v 3 Q U U N O -- 00 U ~ 1 ~ ~ N Q N ~ N O . _ ~ ~ O O Q 0. Q M 7 0.. O N O N U N ~ Q z ~ Q ~ N o U ~ A z o '~ ~ p ~ N ~ O N ' ~ F. ~ p Q U N A ~ M N z a Q a U ~ ~ r 0. M o O O ~ ~ O O N M N Q 00 ~} V ~ U ~ O_ N n M N ~ Q U- ~ G A U o `o o ° O .M. N Q ~ M M O O O - - O N U ~ ~ O ~ ° z '-' U ~ ~i A ~ `^ \ ,.~ ~ M ,~. Q O N N O ~ o O O U O N u ~ a ~_ ~ ~ A N ~ \~ a O V ° J~ `o U Q o 0 A ~ w U °' x ~ O R O ~ _ °. A O ~ U p C/1 a ~ U ~' ~ ~--1 I Q a ~ ~ U ~ ~ .--~ M M O o Q ~ O " O U .~ 00 ~ 'n v A U O O O .--1 1 0 3 N M p O C q p U O .-~ O O O O O O O O 'mot N N ~ `O o0 ~ ~ ~ ~ Lug/~~OOOZ~ ~+)u~~I~I/~-)u~nos Op.Mm CeiwcePNWW AIa~ka lnc. GxIA Cwrocxen0.93 lab Ne: NN/A NNd: CNVNI. dvx UnB MaprrXC De<Endion: 33.05 APE No: IN/A W.E: C04~321wp04 dp: A%Ne: IN/A 118: NN/A Ooghq px 100 It SYel.x /rVD) Ealxsn<e: a~ 5..+ l<.el su,saa. leaanan Original VS Plane: 255.58 Px.m wNI: nan: ca-3n x: 3mes.9s n Vlew VS Plane: 255.58 Ilse xNOlrt ss.3D n Y: 595)433.08 It unN Sydem: ea / f PS Sacllen (V S) 9Nx.ncr. W Ell Comments o' `o z S@CtIOI'1 VI@W - y -CD4-321wp04 Plan -+-CD4-318 L_ Q 0 U_ L 01 1 0) 7 U) T n Plan Viee~w~ 3 8 S 8 8 8 8 8 8 8 8 8 8 -- - 596 595 -- 595 - 595 _L_ __ _ _ ___ J 595 595 - - - -- 595 - _-_-_ ~ 1- 595 595 595 59 59 4 59 4 59 4 594 0619 i 9619 8619 7619 6619 5619 4619 3619 2619 1619 50619 9619 8619 7619 6619 • 4000 5000 6000 7000 0 0 80 9000 0 0 th M vY v3 ~n 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 (7 M n n ^ ^ ^ n ~n ~n v v v v v e v ^ v v v v v ~ d) P ' 0 0 0 0 0 0 0 0 0 ~ n n n n v v v v v v v v v h ~ ~ CO P O 0 v V C3 N ~ N ( ~ V h O N Vertical Section along "View VS Plane' M V ry ~ Combo Preview Page 1 of 1 (CD4321wp04 Toolbox.xls) 9/21/2006 2:45 PM Closest in POOL Closest Approac h: Reference Well: CD4-321wp04 Plan Offset Well: CD4 -318 Coords. - Coords. - ASP ASP 3-D ctr-ctr ' Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS Min. Dist. Depth Angle TRUE Azi. TVD E(+)/W(-) (255.58°) Comments Depth Angle TRUE Azi. TVD E(+)/W(-) (255.58°) Comments POOL Min Distance POOL Min Distance (4748.35 ft) in POOL (4748.35 ft) in POOL (7195 - 7240 TVDss) (7195 - 7240 TVDss) to CD4-318 (15436 - to CD4-321wp04 Plan 4748.35 18286 70.86 255.5 7197.028 5953677 362223.2 16009.47 20612 MD) 17911 91.08 350.2 7168.095 5954448 366908.4 11273.62 (15436 - 20612 MD) • CD4-321wp04 POOL Summary.xls 9/21/2006 2:47 PM s~ - --. k~ DELfA BROWN ~ ~~~ 1061 ,~: CONOCOPHILLIPS ATO 1534 /• ~ / ` 700 G ST. DA7E `' ~ 56-1551/441 ~' ANCHORAGE AK 99501 // Q~ //~~ ~' ORDER.OFE ~~ /! ~~ ~ ~ VO ~ ~~ ~ ~ r ~ V DOLLARS. L'1 ~ e~ x - g JPMorganChase ~ j valid up ro 5000 0ouars f JPMorgan Chase Bank, N.A: Columbus, OH ~ n_ ' MEMO `.'~ W ~~ ~~ W CiG~, ~j~Jyy ~~ - --- ------ '. +~:044iL55iL~:52874389$86L91i'L06~ ` ~.: ;. i • TRANSMITTAL LET'~T1'ER CI3ECKLIST WELL NAME ~~~ ~-~/~~~ Z. PTD# .zUtO - /~~ Development Service Exploratory Strati ra hic Test g P Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-ONS WHAT ~ (OPTIONS) APPLIES 1 TEXT FOR APPROV:4L LETTER ~ ~ MULTI LATERAL ~ The permit is for a new wellbore segment of existing well I (If last two digits in ~ ' ~ i Permit No. , API No. ~0- - _ i 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 ~r ~~0- -_) from records, data and logs I I ,acquired for well _ ~ SPAC[NG EXCEPTION ' I j The permit is approved subject to full compliance with 20 AAC ~ 2~.05~. Approval to perforate and produce /inject is contingent ~ I upon issuance of a conservation order approving a spacing I exception. assumes the j liability of any protest to the spactng exception that may occur. DRY DITCH j A11 dry ditch sample sets submitted to the Commission must be in ; ~ I SAMPLE I no greater than 30' sample intervals from below the permafrost or from where samples are first caught and f 0' sample intervals j I i ~ through target zones. Non-Conventional ~ Please note the following special condition of this permit: i i production or production testing of coal bed methane is not allowed Well ~ for (name of well) until after (Com~anv 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 Rev: t I2~106 C:ljodyitransmittal checklist i t ^^ ~ ~; : : : m a~ o a a ~ U, : : ° ~' m. 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U; V V Q; = ¢, ~ D; m; m; U; ~; y' ~; a ~' in; in; U; W fl. ~O V ~ r N M~~ CO f~ 00 O O N M I `_ t!') t0 I~ O O O N N N N M d' N N l(') (O f~ 00 N N N N O O N M M N M V M M M ~ CO I~ O M M M M O M '~~ V _ - __- w N C C C ++ O r N U O LLJ N O ~ 0 M o I I~ ~ _M o~ ~ M ~ O N v-~ O o E J ~ N N c ~ ~ C7 E O J Q E a~ a W p a~ U W a ¢ Q U ~ W ¢ ~- ~ QU ~ c • • Well History File APPENDIX Information of detailed nature that is not parliculariy germane to the Well Pennitling Process but is part of the history file. To improve the readability of the Well History file and to simpl'rfy finding intonliation, infom~ation of this nature is accumulated at the end of the file under APPENDIX. IJo special effort has been made to chronologically organize this category of information. Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Nov 08 07:23:40 2006 Reel Header Service name .............LISTPE Date .....................06/11/08 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/11/08 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Colville River Nanuq-Kuparuk MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW0004668208 LOGGING ENGINEER: E. QUAM OPERATOR WITNESS: D. LUTRICK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING Scientific Technical Services Scientific Technical Services CD4-321 501032053600 ConocoPhillips Alaska Inc Sperry Drilling Services 07-NOV-06 24 11N 4E 2298 458 55.90 19.00 OPEN HOLE CASING BIT SIZE (IN) SIZE (IN) 12.250 16.000 8.750 9.625 DRILLERS DEPTH (FT) 114.0 3504. 0 c70~o-~~l °~ ~yaa ~ REMARKS: • • 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUN 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), GEOPILOT ROTARY-STEERABLE BHA (GP), AND ACOUSTIC CALIPER (ACAL). 5. 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 DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 6. MWD RUNS 1,2 REPRESENT WELL CD4-321 WITH API#: 50-103-20536-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 19337'MD/7810'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: ACAL-DERIVED (8.75" BIT) MUD WEIGHT: 9.45 - 10.05 PPG MUD SALINITY: 250 - 2000 PPM CHLORIDES FORMATION WATER SALINITY: 25,000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header • Service name............~SLIB.001 Service Sub Level Name... Version Number.... .....1.0.0 Date of Generation.......06/11/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3476.5 19299.5 FET 3490.0 19291.5 NPHI 3490.0 19245.5 NCNT 3490.0 19245.5 PEF 3490.0 19259.0 RPS 3490.0 19291.5 RHOB 3490.0 19259.0 RPD 3490.0 19291.5 RPX 3490.0 19291.5 DRHO 3490.0 19259.0 FCNT 3490.0 19245.5 RPM 3490.0 19291.5 ROP 3514.5 19337.5 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 2 3476.5 19337.5 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 .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 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 ~ • FET MWD HOUR 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3476.5 19337.5 11407 31723 3476.5 19337.5 FCNT MWD CNTS 622.24 2758.1 1187.63 31512 3490 19245.5 NCNT MWD CNTS 115015 192841 146466 31512 3490 19245.5 RHOB MWD G/CM 0.83 3.291 2.43031 31539 3490 19259 DRHO MWD G/CM -2.379 0.247 0.0388438 31539 3490 19259 RPD MWD OHMM 0.73 2000 10.3201 31604 3490 19291.5 RPM MWD OHMM 0.81 1743.45 7.67823 31604 3490 19291.5 RPS MWD OHMM 1.42 2000 6.97441 31604 3490 19291.5 RPX MWD OHMM 1.25 1591.92 6.61375 31604 3490 19291.5 FET MWD HOUR 0.18 90.9 0.589186 31604 3490 19291.5 GR MWD API 38.76 422.03 115.974 31647 3476.5 19299.5 PEF MWD BARN 1.94 15.77 3.09068 31539 3490 19259 ROP MWD FT/H 0.25 270.36 170.582 31647 3514.5 19337.5 NPHI MWD PU-S 10.52 54.81 30.1183 31512 3490 19245.5 First Reading For Entire File..........3476.5 Last Reading For Entire File...........19337.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/08 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY' VENDOR TOOL CODE GR RPM PEF FET RPX NPHI header data for each bit run in separate files. 2 .5000 START DEPTH 3476.5 3490.0 3490.0 3490.0 3490.0 3490.0 STOP DEPTH 19299.5 19291.5 19259.0 19291.5 19291.5 19245.5 . • RPS 3490 19291.5 RPD 3490.0 19291.5 FCNT 3490.0 19245.5 DRHO 3490.0 19259.0 RHOB 3490.0 19259.0 NCNT 3490.0 19245.5 ROP 3514.5 19337.5 LOG HEADER DATA DATE LOGGED: 17-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 19337.0 TOP LOG INTERVAL (FT) 3514.0 BOTTOM LOG INTERVAL (FT) 19337.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 42.7 MAXIMUM ANGLE: 72.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 157645 CTN COMP THERMAL NEUTRON 1844674407370955 ALD Azimuth. Litho-Den 188935 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 114.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S) 36.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3) 7.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.300 68.0 MUD AT MAX CIRCULATING TERMPERATURE: .560 167.0 MUD FILTRATE AT MT: 1.300 68.0 MUD CAKE AT MT: 1.800 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units..... ....Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .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 FONT MWD020 CNTS 4 1 68 4 2 NCNT MWD020 CNTS 4 1 68 8 3 RHOB MWD020 G/CM 4 1 68 12 4 DRHO MWD020 G/CM 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 RPM MWD020 OHMM 4 1 68 24 7 RPS MWD020 OHMM 4 1 68 28 8 RPX MWD020 OHMM 4 1 68 32 9 FET MWD020 HOUR 4 1 68 36 10 GR MWD020 API 4 1 68 40 11 PEF MWD020 BARN 4 1 68 44 12 ROP MWD020 FT/H 4 1 68 48 13 NPHI MWD020 PU-S 4 1 68 52 14 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 3476.5 19337.5 11407 31723 3476.5 FONT MWD020 CNTS 622.24 2758.1 1187.63 31512 3490 NCNT MWD020 CNTS 115015 192841 146466 31512 3490 RHOB MWD020 G/CM 0.83 3.291 2.43031 31539 3490 DRHO MWD020 G/CM -2.379 0.247 0.0388438 31539 3490 RPD MWD020 OHMM 0.73 2000 10.3201 31604 3490 RPM MWD020 OHMM 0.81 1743.45 7.67823 31604 3490 RPS MWD020 OHMM 1.42 2000 6.97441 31604 3490 RPX MWD020 OHMM 1.25 1591.92 6.61375 31604 3490 FET MWD020 HOUR 0.18 90.9 0.589186 31604 3490 GR MWD020 API 38.76 422.03 115.974 31647 3476.5 PEF MWD020 BARN 1.94 15.77 3.09068 31539 3490 ROP MWD020 FT/H 0.25 270.36 170.582 31647 3514.5 NPHI MWD020 PU-S 10.52 54.81 30.1183 31512 3490 First Reading For Entire File..........3476.5 Last Reading For Entire File...........19337.5 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/08 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/11/08 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Last Reading 19337.5 19245.5 19245.5 19259 19259 19291.5 19291.5 19291.5 19291.5 19291.5 19299.5 19259 19337.5 19245.5 Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/11/08 Origin ..................~S 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
