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Home My WebLink About204-062CAUTION: 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: 2N-306 (PTD 204-062) IA Pressure Exceeded OPL Date:Tuesday, March 18, 2025 8:27:49 AM Attachments:2N-306 Bleed Log.csv AnnComm Surveillance TIO for 2N-306.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Monday, March 17, 2025 4:28 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: 2N-306 (PTD 204-062) IA Pressure Exceeded OPL Hi Chris, 2N-306 (PTD 204-062) is a WAG injector with a waiver (AA# AIO 16.006 AMD) to operate with TxIA on gas, WAG allowed. On March 13th, 2025, the IA pressure exceeded its Operating Pressure Limit of 2000 psi. The pressure increased to 2042 psi before the drill site operator responded and bleed the pressure to 1100 psi. The tubing head pressure increased due to pigging operations and the IA pressure had a thermal reaction that was not caught in time. CPAI does not suspect any integrity issues beyond those in the waiver and does not intend to conduct any diagnostics. The TIO plot, bleed log, and schematic are attached. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 17-MAR-25 16:15 Well Annulus Test Report DS WL TIME DURATION STR-PRES END-PRES DIF-PRES CASING SERVICE MATERIAL 2N 306 ########+000:04 1290 840 450 INNER PWI DIESEL 2N 306 ########+000:05 2042 1100 942 INNER PWI METH 2N 306 ########+000:05 905 30 875 OUTER PWI DIESEL 2N 306 ########+000:05 1850 1150 700 INNER PWI PW COMMENTS tbg x IA < 500 diff. H Bleed IA down to get u Bleed IA to prevent DN 2N-306 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2N-306 2025-03-06 1850.0 1150 -700.0 IA 2N-306 2025-03-12 905.0 30 -875.0 OA Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 29.8 Set Depth (ftKB) 139.0 Set Depth (TVD) … 139.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.875 Top (ftKB) 29.8 Set Depth (ftKB) 2,794.0 Set Depth (TVD) … 2,438.8 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description PRODUCTION 5.5"x3.5" @ 6964' OD (in) 5 1/2 ID (in) 4.950 Top (ftKB) 28.3 Set Depth (ftKB) 7,594.7 Set Depth (TVD) … 5,602.4 Wt/Len (l… 15.50 Grade L-80 Top Thread BTCMOD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 25.4 Set Depth (ft… 6,961.4 Set Depth (TVD) (… 5,186.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 25.4 25.4 0.00 HANGER FMC TUBING HANGER 3.500 493.9 493.7 3.17 NIPPLE CAMCO DS LANDING NIPPLE 2.875 6,882.1 5,133.3 48.75 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 6,898.2 5,144.0 48.62 NIPPLE CAMCO D NIPPLE 2.750 6,942.6 5,173.6 47.61 LOCATOR G-22 LOCATOR SUB 3.000 6,943.5 5,174.2 47.58 SEAL ASSY BAKER GBH 80-40 SEAL ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 7,504.0 5,546.2 51.56 FISH Plug off Gauge LOST BULL PLUG OFF PANEX GAUGES IN RATHOLE - 6/27/2007 6/27/2007 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 7,258.0 7,266.0 5,387.7 5,393.1 S-3, S-5, 2N- 306 6/26/2004 6.0 IPERF 2.5" HSD PJ 2506, EHD 0.31" 7,270.0 7,286.0 5,395.7 5,406.4 S3, 2N-306 6/26/2004 6.0 IPERF 2.5" HSD PJ 2506, EHD 0.31" 7,292.0 7,310.0 5,410.3 5,422.2 S3, 2N-306 6/26/2004 6.0 IPERF 2.5" HSD PJ 2506, EHD 0.31" 7,364.0 7,382.0 5,457.5 5,469.2 Top Purple, 2N-306 4/30/2008 6.0 APERF 7,394.0 7,440.0 5,476.9 5,506.1 Top/Base Purple, 2N- 306 4/29/2008 6.0 APERF Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 6,833.7 5,101.5 CAMCO KBG-2- 9 1 GAS LIFT SOV BTM 0.000 0.0 5/23/2004 Notes: General & Safety End Date Annotation 11/19/2010 NOTE: View Schematic w/ Alaska Schematic9.0 6/27/2016 NOTE: Waivered Well TxIA communication on gas. Water injection only allowed. Comment SSSV: NIPPLE2N-306, 3/11/2017 11:25:06 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6964'; 28.3-7,594.7 FISH; 7,504.0 APERF; 7,394.0-7,440.0 APERF; 7,364.0-7,382.0 IPERF; 7,292.0-7,310.0 IPERF; 7,270.0-7,286.0 IPERF; 7,258.0-7,266.0 SEAL ASSY; 6,943.5 LOCATOR; 6,942.6 NIPPLE; 6,898.2 SLEEVE; 6,882.1 GAS LIFT; 6,833.7 SURFACE; 29.8-2,794.0 NIPPLE; 493.9 CONDUCTOR; 29.8-139.0 HANGER; 25.4 Annotation Last Tag: SLM Depth (ftKB) 7,569.0 End Date 3/10/2017 Annotation Rev Reason: TAG Last Mod By pproven End Date 3/11/2017 KUP INJ KB-Grd (ft) 36.51 Rig Release Date 6/2/2004 Annotation Last WO: End Date 2N-306 H2S (ppm) Date ... TD Act Btm (ftKB) 7,605.0 Well Attributes Wellbore API/UWI 501032049000 Field Name TARN PARTICIPATING AREA Wellbore Status INJ Max Angle & MD Incl (°) 52.43 MD (ftKB) 3,116.17 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, October 14, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2N-306 KUPARUK RIV U TARN 2N-306 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/14/2024 2N-306 50-103-20490-00-00 204-062-0 G SPT 5174 2040620 3900 3350 3350 3350 3350 81 460 460 460 REQVAR P Josh Hunt 8/6/2024 2-year MIT-IA Required by AIO 16.006. Required test pressure to pass is the max anticipated injection pressure of 3900 psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U TARN 2N-306 Inspection Date: Tubing OA Packer Depth 590 4210 4110 4095IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240806161105 BBL Pumped:1.7 BBL Returned:1.7 Monday, October 14, 2024 Page 1 of 1 9 9 9 9 9 999 99 99 9 9 9 9 2-year MIT-IA AIO 16.006 James B. Regg Digitally signed by James B. Regg Date: 2024.10.14 16:13:57 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supervisor To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:Well Integrity Specialist CPF2 Subject:2L-319 and 2N-306 Surface casing leak detects 10-426 forms from 8-15-24 Date:Sunday, August 18, 2024 11:42:48 AM Attachments:image001.png SCLD KRU 2L-319 08-15-24.xlsx SCLD KRU 2N-306 08-15-24.xlsx Please see the attached 10-426 form from the surface casing leak detects at 2L-319 and 2N- 306 from 8-15-24. If you have any questions or concerns, please let me know. Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .581 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2040620 Type Inj N Tubing 3260 3260 3260 3260 Type Test P Packer TVD 5174 BBL Pump IA 792 792 792 792 Interval O Test psi 1200 BBL Return OA 816 1250 1246 1243 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 2N Pad Waived Weimer / Casey 08/15/24 Notes:Surface casing leak detect per AIO 16.006. Witnessed Waived by Adam Earl Notes: 2N-306 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2024-0815_MIT_KRU_2N-306 9999 9 9 9 9 9 -5HJJ Surface casing leak detect per AIO 16.006. 1 Regg, James B (OGC) From:Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent:Tuesday, August 30, 2022 11:12 AM To:Regg, James B (OGC); Brooks, Phoebe L (OGC); Wallace, Chris D (OGC); DOA AOGCC Prudhoe Bay Cc:Earhart, Will C Subject:Emailing: SCLD KRU 2N-306 8-28-22.xlsx, SCLD KRU 2L-310 08-25-22.xlsx, SCLD KRU 2L-305 08-26-22.xlsx, SCLD KRU 2L-319 08-27-22.xlsx, SCLD KRU 2N-337C 08-29-22.xlsx Attachments:SCLD KRU 2N-306 8-28-22.xlsx; SCLD KRU 2L-310 08-25-22.xlsx; SCLD KRU 2L-305 08-26-22.xlsx; SCLD KRU 2L-319 08-27-22.xlsx; SCLD KRU 2N-337C 08-29-22.xlsx CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. All Attached are the 10 426 forms for the SCLD that are required for each wells associated administrative approval. Due to the fact that the surface casing leak detects are performed with a gas media there are no "bbls pumped" nor "bbls returned". CPAI's surface casing leak detects have two passing criteria; pass according to the MIT OA criteria to 1200 psi or if the OA fluid level depresses below 1000' without maintain MIT criteria. The wells that passed with MIT criteria will have the numbers input into the "Pressures" boxes as a UIC compliance MIT would. If the OA fluid level depressed below 1000' without meeting the MIT criteria the notation of a passing test is placed in the "Notes" portion of the 10 426. Since this is the first submittal of these types of tests if there is additional information in which you believe to be beneficial or you would rather have these test reported in a different manner please feel free to reach out to discuss. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 265 6218 Cell phone: (907) 830 9777 Submit to: OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2040620 Type Inj G Tubing 3254 3254 3254 3254 Type Test P Packer TVD 5174 BBL Pump IA 2040 2108 2108 2108 Interval O Test psi 1200 BBL Return OA 618 1350 1325 1325 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mec han ical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Surface casing leak detect per AIO 06.006. Witness waived by Lou Laubenstein. Notes: 2N-306 Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 2N Pad Waived Caudle / Galle 08/28/22 Form 10-426 (Revised 01/2017)2022-0828_MIT_KRU_2N-306_OA AIO 06.006. 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: CPAI 2L-305 (PTD #198-240), 2L-319 (PTD #207-112), 2N-306 (PTD #204-062) & 2N-337C (PTD #214- 121) 30 day monitor period for diagnostic testing. Date:Wednesday, August 3, 2022 11:10:18 AM Attachments:image001.png AnnComm Surveillance TIO for 2N-306.pdf AnnComm Surveillance TIO for 2L-319.pdf AnnComm Surveillance TIO for 2L-305.pdf AnnComm Surveillance TIO for 2N-337C.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Friday, May 27, 2022 7:50 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2L-305 (PTD #198-240), 2L-319 (PTD #207-112), 2N-306 (PTD #204-062) & 2N-337C (PTD #214-121) 30 day monitor period for diagnostic testing. Chris- CPAI has identified four Tarn injectors 2L-305 (PTD #198-240), 2L-319 (PTD #207-112), 2N-306 (PTD #204-062) & 2N-337C (PTD #214-121) that were previously waivered for water injection only due to known TxIA while on gas injection. During a recent reservoir evaluation, these 4 wells were identified to have a significant production benefit from the ability to inject MI. CPAI has developed criteria under which it believes a gas injection well may operate safely with TxIA communication. That criterion includes the well having casing rated high enough to support maximum anticipated injection pressure of gas injection should a barrier fail, passing a MITIA to maximum anticipated injection pressure of gas injection, passing a MITOA or SCLD, and passing an IA DDT on water or gas injection and during gas injection service the IA pressure must sustain below the “do not exceed” of 2400 psi. These wells meet the above criteria and CPAI has conducted diagnostic MIT-IAs and SCLDs all with passing results. The remaining criteria yet to be met is the ability to maintain IA pressure under DNE of 2400 psi while on gas injection. Therefore, CPAI intends to place 2L-305, 2L-319, 2N- 306 & 2N-337C into gas injection service for a 30 day monitor period. If the 30 day monitor period displays the ability of the IAs to sustain a pressure below the DNE, CPAI intends to apply for administrative approval for continued WAG injection with known TxIA communication while on gas injection. Attached are the current 90 day TIO plots and wellbore schematics. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 29.8 Set Depth (ftKB) 139.0 Set Depth (TVD) … 139.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.875 Top (ftKB) 29.8 Set Depth (ftKB) 2,794.0 Set Depth (TVD) … 2,438.8 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description PRODUCTION 5.5"x3.5" @ 6964' OD (in) 5 1/2 ID (in) 4.950 Top (ftKB) 28.3 Set Depth (ftKB) 7,594.7 Set Depth (TVD) … 5,602.4 Wt/Len (l… 15.50 Grade L-80 Top Thread BTCMOD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 25.4 Set Depth (ft… 6,961.4 Set Depth (TVD) (… 5,186.3 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 25.4 25.4 0.00 HANGER FMC TUBING HANGER 3.500 493.9 493.7 3.17 NIPPLE CAMCO DS LANDING NIPPLE 2.875 6,882.1 5,133.3 48.75 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 6,898.2 5,144.0 48.62 NIPPLE CAMCO D NIPPLE 2.750 6,942.6 5,173.6 47.61 LOCATOR G-22 LOCATOR SUB 3.000 6,943.5 5,174.2 47.58 SEAL ASSY BAKER GBH 80-40 SEAL ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 7,504.0 5,546.2 51.56 FISH Plug off Gauge LOST BULL PLUG OFF PANEX GAUGES IN RATHOLE - 6/27/2007 6/27/2007 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 7,258.0 7,266.0 5,387.7 5,393.1 S-3, S-5, 2N- 306 6/26/2004 6.0 IPERF 2.5" HSD PJ 2506, EHD 0.31" 7,270.0 7,286.0 5,395.7 5,406.4 S3, 2N-306 6/26/2004 6.0 IPERF 2.5" HSD PJ 2506, EHD 0.31" 7,292.0 7,310.0 5,410.3 5,422.2 S3, 2N-306 6/26/2004 6.0 IPERF 2.5" HSD PJ 2506, EHD 0.31" 7,364.0 7,382.0 5,457.5 5,469.2 Top Purple, 2N-306 4/30/2008 6.0 APERF 7,394.0 7,440.0 5,476.9 5,506.1 Top/Base Purple, 2N- 306 4/29/2008 6.0 APERF Mandrel Inserts St ati on N o/ Top (ftKB) Top (TVD) (ftKB) Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 6,833.7 5,101.5 CAMCO KBG-2- 9 1 GAS LIFT SOV BTM 0.000 0.0 5/23/2004 Notes: General & Safety End Date Annotation 11/19/2010 NOTE: View Schematic w/ Alaska Schematic9.0 6/27/2016 NOTE: Waivered Well TxIA communication on gas. Water injection only allowed. Comment SSSV: NIPPLE2N-306, 3/11/2017 11:25:06 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6964'; 28.3-7,594.7 FISH; 7,504.0 APERF; 7,394.0-7,440.0 APERF; 7,364.0-7,382.0 IPERF; 7,292.0-7,310.0 IPERF; 7,270.0-7,286.0 IPERF; 7,258.0-7,266.0 SEAL ASSY; 6,943.5 LOCATOR; 6,942.6 NIPPLE; 6,898.2 SLEEVE; 6,882.1 GAS LIFT; 6,833.7 SURFACE; 29.8-2,794.0 NIPPLE; 493.9 CONDUCTOR; 29.8-139.0 HANGER; 25.4 Annotation Last Tag: SLM Depth (ftKB) 7,569.0 End Date 3/10/2017 Annotation Rev Reason: TAG Last Mod By pproven End Date 3/11/2017 KUP INJ KB-Grd (ft) 36.51 Rig Release Date 6/2/2004 Annotation Last WO: End Date 2N-306 H2S (ppm) Date ... TD Act Btm (ftKB) 7,605.0 Well Attributes Wellbore API/UWI 501032049000 Field Name TARN PARTICIPATING AREA Wellbore Status INJ Max Angle & MD Incl (°) 52.43 MD (ftKB) 3,116.17 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 9, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2N-306 KUPARUK RIV U TARN 2N-306 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/09/2022 2N-306 50-103-20490-00-00 204-062-0 G SPT 5174 2040620 3900 3460 3460 3460 3460 30 104 104 104 REQVAR P Adam Earl 8/1/2022 MIT-IA tested as per AIO 16.006 to max ant. Inj. Psi. Amended waiver test to 4200psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U TARN 2N-306 Inspection Date: Tubing OA Packer Depth 260 4210 4135 4130IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220803204041 BBL Pumped:1.8 BBL Returned:1.8 Friday, September 9, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 99 9 $,2UHYLVHGMEU 5(9,6(' AIO 16.006 James B. Regg Digitally signed by James B. Regg Date: 2022.09.09 13:23:00 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 29, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2N-306 KUPARUK RIV U TARN 2N-306 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2022 2N-306 50-103-20490-00-00 204-062-0 G SPT 5174 2040620 3900 3460 3460 3460 3460 30 104 104 104 REQVAR P Adam Earl 8/1/2022 MIT-IA tested as per AIO 16.066 to max ant. Inj. Psi. Amended waiver test to 4200psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U TARN 2N-306 Inspection Date: Tubing OA Packer Depth 260 4210 4135 4130IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220803204041 BBL Pumped:1.8 BBL Returned:1.8 Monday, August 29, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 AIO 16.066 to max ant. Inj. Psi. James B. Regg Digitally signed by James B. Regg Date: 2022.08.29 15:40:54 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CPAI 2L-319 (PTD #207-112) & 2N-306 (PTD #204-062) 30 day monitor period for diagnostic testing. Date:Tuesday, July 12, 2022 11:49:18 AM Attachments:image001.png AnnComm Surveillance TIO for 2L-319.pdf AnnComm Surveillance TIO for 2N-306.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, July 7, 2022 2:53 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2L-319 (PTD #207-112) & 2N-306 (PTD #204-062) 30 day monitor period for diagnostic testing. Chris- Kuparuk Tarn injectors 2L-319 (PTD #207-112) and 2N-306 (PTD #204-062) have completed their 30 day monitor periods. Both IAs have shown stabilization below the DNE of 2400 psi while on gas injection and have now met all of the criteria in which CPAI requires to continue WAG injection with known tubing by inner annulus communication. It is CPAI’s intention to submit an application for continued WAG injection with known tubing by inner annulus communication. While the AAs are in process the well will be left in gas injection service. Attached are the current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 Sent: Friday, May 27, 2022 7:50 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2L-305 (PTD #198-240), 2L-319 (PTD #207-112), 2N-306 (PTD #204-062) & 2N-337C (PTD #214-121) 30 day monitor period for diagnostic testing. Chris- CPAI has identified four Tarn injectors 2L-305 (PTD #198-240), 2L-319 (PTD #207-112), 2N-306 (PTD #204-062) & 2N-337C (PTD #214-121) that were previously waivered for water injection only due to known TxIA while on gas injection. During a recent reservoir evaluation, these 4 wells were identified to have a significant production benefit from the ability to inject MI. CPAI has developed criteria under which it believes a gas injection well may operate safely with TxIA communication. That criterion includes the well having casing rated high enough to support maximum anticipated injection pressure of gas injection should a barrier fail, passing a MITIA to maximum anticipated injection pressure of gas injection, passing a MITOA or SCLD, and passing an IA DDT on water or gas injection and during gas injection service the IA pressure must sustain below the “do not exceed” of 2400 psi. These wells meet the above criteria and CPAI has conducted diagnostic MIT-IAs and SCLDs all with passing results. The remaining criteria yet to be met is the ability to maintain IA pressure under DNE of 2400 psi while on gas injection. Therefore, CPAI intends to place 2L-305, 2L-319, 2N- 306 & 2N-337C into gas injection service for a 30 day monitor period. If the 30 day monitor period displays the ability of the IAs to sustain a pressure below the DNE, CPAI intends to apply for administrative approval for continued WAG injection with known TxIA communication while on gas injection. Attached are the current 90 day TIO plots and wellbore schematics. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Casing StringsCasing DescriptionCONDUCTOR OD (in)16 ID (in)15.062 Top (ftKB)29.8 Set Depth (ftKB)139.0 Set Depth (TVD) …139.0 Wt/Len (l…62.50 GradeH-40 Top ThreadWELDEDCasing DescriptionSURFACE OD (in)7 5/8 ID (in)6.875 Top (ftKB)29.8 Set Depth (ftKB)2,794.0 Set Depth (TVD) …2,438.8 Wt/Len (l…29.70 GradeL-80 Top ThreadBTCMCasing DescriptionPRODUCTION 5.5"x3.5" @ 6964'OD (in)5 1/2 ID (in)4.950 Top (ftKB)28.3 Set Depth (ftKB)7,594.7 Set Depth (TVD) …5,602.4 Wt/Len (l…15.50 GradeL-80 Top ThreadBTCMODTubing StringsTubing DescriptionTUBING String Ma…3 1/2 ID (in)2.992 Top (ftKB)25.4 Set Depth (ft…6,961.4 Set Depth (TVD) (…5,186.3 Wt (lb/ft)9.30 GradeL-80 Top ConnectionEUE8RDMODCompletion DetailsTop (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 25.4 25.4 0.00 HANGER FMC TUBING HANGER 3.500 493.9 493.7 3.17 NIPPLE CAMCO DS LANDING NIPPLE 2.875 6,882.1 5,133.3 48.75 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 6,898.2 5,144.0 48.62 NIPPLE CAMCO D NIPPLE 2.750 6,942.6 5,173.6 47.61 LOCATOR G-22 LOCATOR SUB 3.000 6,943.5 5,174.2 47.58 SEAL ASSY BAKER GBH 80-40 SEAL ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 7,504.0 5,546.2 51.56 FISH Plug off Gauge LOST BULL PLUG OFF PANEX GAUGES IN RATHOLE - 6/27/2007 6/27/2007 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Date Shot Dens (shots/f t)Type Com 7,258.0 7,266.0 5,387.7 5,393.1 S-3, S-5, 2N- 306 6/26/2004 6.0 IPERF 2.5" HSD PJ 2506, EHD 0.31" 7,270.0 7,286.0 5,395.7 5,406.4 S3, 2N-306 6/26/2004 6.0 IPERF 2.5" HSD PJ 2506, EHD 0.31" 7,292.0 7,310.0 5,410.3 5,422.2 S3, 2N-306 6/26/2004 6.0 IPERF 2.5" HSD PJ 2506, EHD 0.31" 7,364.0 7,382.0 5,457.5 5,469.2 Top Purple, 2N-306 4/30/2008 6.0 APERF 7,394.0 7,440.0 5,476.9 5,506.1 Top/Base Purple, 2N- 306 4/29/2008 6.0 APERF Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 6,833.7 5,101.5 CAMCO KBG-2- 9 1 GAS LIFT SOV BTM 0.000 0.0 5/23/2004 Notes: General & Safety End Date Annotation 11/19/2010 NOTE: View Schematic w/ Alaska Schematic9.0 6/27/2016 NOTE: Waivered Well TxIA communication on gas. Water injection only allowed. CommentSSSV: NIPPLE2N-306, 3/11/2017 11:25:06 AMVertical schematic (actual) PRODUCTION 5.5"x3.5" @ 6964'; 28.3-7,594.7 FISH; 7,504.0 APERF; 7,394.0-7,440.0 APERF; 7,364.0-7,382.0 IPERF; 7,292.0-7,310.0 IPERF; 7,270.0-7,286.0 IPERF; 7,258.0-7,266.0 SEAL ASSY; 6,943.5 LOCATOR; 6,942.6 NIPPLE; 6,898.2 SLEEVE; 6,882.1 GAS LIFT; 6,833.7 SURFACE; 29.8-2,794.0 NIPPLE; 493.9 CONDUCTOR; 29.8-139.0 HANGER; 25.4 AnnotationLast Tag: SLM Depth (ftKB)7,569.0 End Date3/10/2017 AnnotationRev Reason: TAG Last Mod Bypproven End Date3/11/2017KUP INJ KB-Grd (ft)36.51 Rig Release Date6/2/2004AnnotationLast WO:End Date 2N-306H2S (ppm) Date...TDAct Btm (ftKB)7,605.0Well AttributesWellbore API/UWI501032049000 Field NameTARN PARTICIPATING AREA Wellbore StatusINJ Max Angle & MDIncl (°)52.43 MD (ftKB)3,116.17 MEMORANDUM TO: Jim Regg,p�`q pl(q mz) P.I. Supervisor `` �` `I FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 12, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2N-306 KUPARUK RIV U TARN 2N-306 Src: Inspector Reviewed By: P.I. Supry yl� Comm Well Name KUPARUK RIV U TARN 2N-306 API Well Number 50-103-20490-00-00 Inspector Name: Lou Laubenstein Permit Number: 204-062-0 Inspection Date: 8/3/2020 - Insp Num: mitLOL200804122711 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2N-306 Type Inj W 'TVD 5174 Tubing 2520 - 2520 2520 - 2520 PTD 2040620 Type Test SPT.ITest psi 3000 - IA 520 3310. 3220 3220 - BBL Pumped: r 1.4 'OL Returned: 1.4 OA — 35 270 - 270 - 242 Intervale REQVAR /P F P Notes: MIT -IA to Maximum anticipated injection pressure per AIO 16.006 Wednesday, August 12, 2020 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,August 25,2016 TO: Jim ReggZS1tL P.I.Supervisor �Z SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2N-306 FROM: Brian Bixby KUPARUK RIV U TARN 2N-306 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry --3/3"---- NON-CONFIDENTIAL 3/3"-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 2N-306API Well Number 50-103-20490-00-00 Inspector Name: Brian Bixby Permit Number: 204-062-0 Inspection Date: 8/20/2016 Insp Num: mitBDB160821045340 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2N-306 Type Inj W'TVD 5174 . Tubing 1790 - 1790 - 1790 _ 1790 - PTD 2040620 - Type Test SPT Test psi 3000 - IA 470 3310- 3230_ 3230 Interval REQVAR P/F P ,/ OA 176 500 • 478 469 - Notes: AIO-16.006 - SCANNED KAY :' 9201? Thursday,August 25,2016 Page 1 of 1 • I Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Tuesday, May 17, 2016 8:16 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: RE: Report of IA pressure anomaly 2N-306 (PTD 204-062) Update 5-17-16 Attachments: 2N-306 90 day TIO 5-17-16.PNG Chris, Tarn WAG injector 2N-306 (PTD 204-062) is completing the 30 day monitor on gas injection and the IA pressure has continued to increase subsequent pressure bleeds. The plan is for DHD to perform initial diagnostics including an MIT- IA and packoff testing. The well will be WAG'd to water injection and the IA pressure bled down for the 30 day monitor on water injection. At the end of the diagnostic and monitor period an update with the plan forward and any required paperwork will be submitted. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions with the plan. Regards, Jan Byrne/ Dusty Freeborn Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7126 Pager(907) 659-7000 pgr. 123 WELLS TEAM co,«oPhabbps WOOD D MAY 8205 rom: NSK Problem Well Supv Se . ► onday, April 18, 2016 12:35 PM To:Wallac-, ris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Ty e '.Tyler.Senden@conocophillips.com>° Subject: Report of IA pres . - anomaly 2N-306 (PTD 204-062)4-18-16 Chris, Tarn WAG injector 2N-306 (PTD 204-062) is expe ' cing IA pressure swings while the well is on gas injection. The well has been on gas injection since September 2015. The I s needed to be bled a couple of times in the last two weeks when reaching its DNE pressure. While at this point we bell vie pressure swings are thermally related,there is also a longer term slow upward trend of the IA which may be indicative o IA communication issue. At this point, we plan to monitor this well with higher scrutiny for the next 30 days. No diagnost are planned yet, but if pressure observations become more suspicious we will follow-up with an email and begin t*D diagnostics(MIT, packoff and drawdown testing). Please let me know if you disagree with the plan forward. Attached are the schematic and 90 day TIO plot. Kelly Lyons/ Brent Rogers Problem Wells Supervisor 1 S • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, April 18, 2016 12:35 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Report of IA pressure anomaly 2N-306 (PTD 204-062) 4-18-16 Attachments: 2N-306 schematic.pdf; 2N-306 90 day TIO 4-18-16.PNG Chris, Tarn WAG injector 2N-306 (PTD 204-062) is experiencing IA pressure swings while the well is on gas injection. The well has been on gas injection since September 2015. The IA has needed to be bled a couple of times in the last two weeks when reaching its DNE pressure. While at this point we believe the pressure swings are thermally related,there is also a longer term slow upward trend of the IA which may be indicative of a TxIA communication issue. At this point, we plan to monitor this well with higher scrutiny for the next 30 days. No diagnostics are planned yet, but if pressure observations become more suspicious we will follow-up with an email and begin DHD diagnostics (MIT, packoff and drawdown testing). Please let me know if you disagree with the plan forward. Attached are the schematic and 90 day TIO plot. Kelly Lyons/ Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 goo uN 1 5 2016 W 0 s N 2 ix ix ix ix a w w w V _ N 20 -- a uo o d N W Obi o W a o O N , O O N .a 3 CO ss d2 y W m ' lin K CO Co d H M Of • Q N N F H w 14, w W o a a 2 NN fv X n O 4 `o ° N y N !V N f4 dBapp N± co . 40 to t0 Q 'Q tl� ID .c Q to CD 16 d i 2 V C M to fD 3 W t0 Ve O 3 q p E O t0 .0 o N la O Ct0 t0 Q r V i......: LLLL to {o ' el M N p N a 4. IIII I to a> "Q § Q c .c G .. ° o § c�aii R § ?.. ea a 51 z O p v to n ra r/ .- - Galli G:106 gi. a a c S. ISd inOw -2-5s121 WELL LOG TRANSMITTAL DATA LOGGED G i t/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. May 7, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 u RE: Injection Profile : 2N-306 Run Date: 5/7/2015 f V.401' The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-306 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20490-00 Injection Profile 1 Color Log 50-103-20490-00 SCANNED JUN 12 2015 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MA412-0.4sek..4) o_e4t.eat MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggDATE: Friday,January 09,2015 ) P.I.Supervisor 1\el 1104!5 SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2N-306 FROM: John Crisp KUPARUK RIV U TARN 2N-306 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 2N-306 API Well Number 50-103-20490-00-00 Inspector Name: John Crisp Permit Number: 204-062-0 Inspection Date: 12/26/2014 Insp Num: mitJCr141231121119 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2N-306 'Type Inj W TVD 5174 Tubing 1700 1700 1700- 1700 PTD 2040620 Type Test SPT Test psi i 1500 - IA 859 2542 2493 —r- 2486 — Interval 4YRTST P/F P ' OA 417 607 - 586 - 756 Notes: 75 bbl pumped for test Friday,January 09,2015 Page 1 of 1 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c2 Q [} - ofo:J... Well History File Identifier Organizing (done) o Two-sided ""111111111I" III o Rescan Needed 1111111111111 111111 R,CAN \Ø' Color Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) o Maps: D Other Items Scannable by a Large Scanner o Diskettes, No. D Other, NofType: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Dale 7 /:J$/O~ D Other:: BY: ~ Isl MP Dale 7/:L'?i / Óh I ~ + ~ = TOTAL PAGES~ (Count does not include cover sheet) Isl 111111111111111111I Project Proofing BY: ~ Isl n1f Scanning Preparation BY: Date: Production Scanning Stage 1 Page Count from Scanned File: 4 (Counl does include cove' sheel) Page Count Matches Number in Scanning Preparation: V YES BY ~ Da,e7/á8/0~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES "'11111111111" III NO Isl YV1 P NO BY: Maria Date: Isl 11111111111I111111I Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111" III BY: Maria Date: Isl Comments about this file: Quality Checked "1111111111 111111I 10/6/2005 Well History File Cover Page.doc • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 16, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 2N -306 Run Date: 5/11/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2N -306 Digital Data in LAS format, Digital Log Image file Sk D 1 CD Rom 50- 103 - 20490 -00 14 Bottom Hole Pressure Survey Log / 1 Color Log 50- 103 - 20490 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. h ", �{ =� Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: f L ( Signed: 1 ;0 ( r 4 0-1 � — 6 • • Nor' . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 April 13, 2011 o - Commissioner Dan Seamount ar N _., 3b Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 la it ) APR 1 9 201 Commissioner Dan Seamount: 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 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 cement was pumped November 11, 2001. The corrosion inhibitor /sealant was pumped February 17 and 18, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 4113/11 2M & 2N PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls _ ft gal 2M -05 50103201680000 1920470 Surface NA 16" NA 2.5 2/17/2011 2M -06 50103201760000 1920770 Surface NA 19" NA 2.5 2/18/2011 2M -30 50103201800000 1920840 Surface NA 16" NA 4.25 2/17/2011 2N -303 50103203520000 2001690 26' 5.00 20" 11/8/2001 4.4 2/17/2011 2N-306 50103204900000 2040620 SF NA 241 . ; NA 2 2/17/2011 2 N -310 50103205490000 2070900 SF NA 28" NA 5.1 2/17/2011 2N -342 50103205470000 2070680 24" NA 24" NA 7 2/17/2011 • • Page 1 of 1 Regg, James B (DOA) From: Phillips, Jim (ASRC Energy Services) [Jim.Phillips@contractor.conocophillips.com] Sent: Wednesday, August 25, 2010 3:57 PM To: Regg, James B (DOA) ~ ~~'" ~6 ~ Subject: RE: State MITIA test results for 2N pad on 8/24/10 ~<jL~,t ~ ' ~~ Follow Up Flag: Follow up Flag Status: Red Attachments: MIT KRU 2N Pad DRAFT.xIs Jim, I apologize for the mix up I am filling in for Brent this week and by mistake I did not double check the form before sending it off. Therefore I did not notice that it was showing 12 water injectors SI. I have attached the correct copy and again I am sorry about this mistake on my part. If you have any more questions please feel free to contact me. Jim Phillips Acting Problem Well Supervisor Email: N1617 @conocophillips.com Office: 659-7224 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, August 25, 2010 2:36 PM To: Phillips, Jim (ASRC Energy Services) Subject: RE: State MITIA test results for 2N pad on 8/24/10 Why were all the wells SI except the gas injector? Jim Regg ~ ~. z t ~ ~ tr' AOGCC ,~,,~,~.., ~~. ~iU4,. ~ ~•- , 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Phillips, Jim (ASRC Energy Services) [mailto:Jim.Phillips@contractor.conocophillips.com] Sent: Wednesday, August 25, 2010 8:57 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: State MITIA test results for 2N pad on 8/24/10 All, Attached is the MITIA tests for 2N pad that were waived by Chuck Shieve on 08/24/10. Jim Phillips Acting Problem Well Supervisor Email: N1617 @conocophillips.com Office: 659-7224 8/26/2010 Email to:jim.regg c~alaska.gov; phoebe.brooks~alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD /UNIT /PAD: Kuparuk /KRU / 2N DATE: 08/24/10 OPERATOR REP: Ives/MouserAES AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Packer De th Pretest Initial 15 Min. 30 Min. Well 2N-302 T e In'. W ND 5,185' Tubin 1,860 1,860 1,860 1,860 Interval 4 P.T.D. 2011150 T etest P Test si 1500 Casin 1,210 2,540 2,520 2,520 P/F P Notes: OA 235 265 260 260 Well 2N-306 T e In'. W ND 5,174' Tubin 2,150 2,150 2,150 2,150 Interval 4 P.T.D. 2040620 ~ T e test P Test si 1500 ~ Casin 1,245 2,820 2,760 2,760 P/F P Notes: OA 375 550 520 520 Well 2N-307 T e In'. W TVD 5,141' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 1990170 T etest P Test si 1500 Casin 810 2,180 2,150 2,150 P/F P Notes: OA 250 350 300 300 Well 2N-309 T e In'. W ND 5,042' Tubin 1,600 1,600 1,600 1,600 Interval 4 P.T.D. 1990210 T etest P Test si 1500 Casin 775 2,225 2,100 2,080 P/F P Notes: OA 300 365 340 340 Well 2N-310 T e In'. W ND 5,004' Tubin 1,550 1,550 1,550 1,550 Interval 4 P.T.D. 2070900 T e test P Test si 1500 Casin 440 2,300 2,250 2,250 P/F P Notes: OA 270 390 350 350 Well 2N-314 T e In'. W ND 5,046' Tubin 1,600 1,600 1,600 1,600 Interval 4 P.T.D. 2001930 T e test P Test si 1500 Casin 600 2,300 2,270 2,270 P/F P Notes: OA 225 240 240 240 Well 2N-321A T e In'. W ND 4,915' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 1981730 T e test P Test si 1500 Casin 575 2,280 2,250 2,250 P/F P Notes: OA 250 450 450 450 Well 2N-326 T e In'. W ND 4,821' Tubin 1,860 1,860 1,860 1,860 Interval 4 P.T.D. 2001550 T etest P Test si 1500 Casin 1,150 2,760 2,720 2,710 P/F P Notes: OA 360 460 460 460 Well 2N-331 T e In'. W ND 4,770' Tubin 1,460 1,460 1,460 1,460 Interval 4 P.T.D. 1981170 T etest P Test si 1500 Casin 460 2,200 2,150 2,150 P/F P Notes: OA 300 480 480 480 Well 2N-335 T eln. W TVD 4,966' Tubin 1,950 1,950 1,950 1,950 Interval 4 P.T.D. 1982040 T e test P Test si 1500 Casin 560 2,800 2,600 2,590 P/F P Notes: OA 200 430 430 430 Well 2N-343 T e In'. G ND 4,937' Tubin 3,350 3,350 3,350 3,350 Interval 4 P.T.D. 1980920 T e test P Test si 1500 Casin 850 2,780 2,630 2,620 P/F P Notes: OA 400 420 420 420 Well 2N-348 T e In'. W ND 4,374' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 2011420 T e test P Test si 1500 Casin 630 2,280 2,240 2,240 P/F P Notes: OA 190 320 320 320 Well 2N-349A T e In'. G ND 5,078' Tubin 1,625 1,625 1,625 1,625 Interval 4 P.T.D. 2001390 T e test P Test si 1500 Casin 280 2,320 2,250 2,250 P/F P Notes: OA 150 250 250 250 Well 2N-325 T e In'. W ND 5015' Tubin 1,975 1,975 1,975 1,975 Interval 4 P.T.D. 1981630 T e test P Test si 1500 Casin 750 2,675 2,630 2,630 P/F P Notes: OA 220 250 240 240 TYPE INJ Codes D =Drilling Waste G =Gas 1 =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Interval Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 2N Pad 08-24-10 Revisedl.xis ~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~N~~9 JUN ~. 2~1~8 Log Description 05/30/08 ~ ~~` NO. 4732. , Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1 F-04 11964615 INJECTION PROFILE +Cr I ~ ( 05/26/08 1 1 3F-10 11964609 PRODUCTION PROFILE - ~ ~ 05/23/08 1 1 1J-101 11970685 GLS - C C 05!23/08 1 1 iJ-166 11970681 GLS / 05/20/08 1 1 2N-306 11964608 INJECTION PROFILE - xf V (~ 05/22/08 1 1 3K-13 11970688 INJECTION PROFILE ~ 05/26/08 1 1 1 B-08A 11970686 INJECTION PROFILE e i ~~ j ( 05/24/08 1 1 1Y-11 11964613 INJECTION PROFILE I$ - /(e~~ 05/25/08 1 1 3K-19 11964616 INJECTION PROFILE U~ - p ~ 05/27/08 1 1 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. RECElV'E~ • STATE OF ALASKA MAY 3 ®2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA'~~9'~& Gas Cons. Commission ~nrhnrana 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate Q Re-enter Suspended Well ^ Z. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 204-062 / 3. Address: Stratigraphic ^ Service ^/ - 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20490-00 7. KB Elevation (tt): 9. Well Name and Number: RKB 30', 149' AMSL + 2N-306 ' 8. Property Designation: 10. Field/Pool(s): ADL 375074 % 380054 / 380053 ~ Kuparuk River Field / Tarn Oil Pool - 11. Present Well Condition Summary: Total Depth measured 7605' ' feet true vertical 5609' • feet Plugs (measured) 7504' Effective Depth measured 7504' feet Junk (measured) true vertical 5546' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 107' 16" 137' 137' SURFACE 2764' 7-5/8" 2794' 2438' PRODUCTION 6934' S-1/2" 6964' 5188' LINER 631' 3-1/2" 7595' 5603' > s Perforation depth: Measured depth: 7258'-7266', 7270'-7286', 7292'-7310', 7364'-7382', 7394'-7440' true vertical depth: 5388'-5393', 5396'-5406', 5410'-5422', 5458'-5469', 5477'-5506' ~~~ ~u~ ~ 2aa~ Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6961' MD. Packers & SSSV (type & measured depth) no packer Camco DS landing nipple @ 494' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not appl-Cable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 4928 -- Subsequent to operation 4151 - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 ' Daily Report of Well Operations _X 16. Well Status after work: Oit^ Gas^ WAG^ GINJ^ WINJ ® WDSPL^ 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: none Contact John Peirce Printed Name John Peirce Title Wells Group Engineer / r Signature .! r'` (~ J Phone: 265-6845 ~ 2Q a Date .~f ! f do ~~1' 3 , Pre red Karon Allsu Oreke 263-4612 ~'~^^-_ Form 10-404 Revised 04/2006 ORIGINAL _ S ~i ~it~~ a) ~oo~ ,~ S'~o,oa Submi inal~nl~ • 2N-306 Well Events Summary DATE SUMMARY 3/4/08 TAGGED @ 7540' SLM. DRIFTED TBG WITH 10' x 2.65" DUMMY TO 7450' RKB. READY FOR E/L. 4/29/08 PERFORATED 7394' TO 7440', 6 SPF WITH 2 1/2" HSD POWERJET REMAINING 18' ZONE TO BE PERFED TOMORROW MORNING, 4/30 4/30/08 PERFORATED 7364' - 7382', 6 SPF, 2-1/2" HSD PowerJet. • • _ -~,._ ;-~. -.~ MICROFILMED 03/01/2008 DO NOT PLACE _. ~;: ., ~" ~~ -._ ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\C~rPgs_Inserts~Mitcrofilm Marker.doc ...-;-.~ sCANNED JUN 2 1 2007 06/14/07 Schlumberger U.I. C- 9å4 -Ó<Od- NO. 4300 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ;f; 0 iOOl Company: Alaska Oil & Gas Cons C()mm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Color CD Log Description Date BL 2M-16 11629024 SBHP SURVEY 06/06/07 1 2N-306 11629025 SBHP SURVEY 06/06/07 1 2H-07 11638870 PRODUCTION PROFILE 06/07/07 1 2N-323 11629027 SBHP SURVEY 06/08/07 1 2N-313 11629027 SBHP SURVEY 06/08/07 1 2M-29 11638871 SBHP SURVEY 06/08/07 1 1C-104 11638872 LDL 06/08/07 1 1 G-08A 11629026 PRODUCTION PROFILE 06/09/07 1 2N-308 11638874 SBHP SURVEY 06/09/07 1 2M-10 11629031 SBHP SURVEY 06/10/07 1 1A-27 11638876 PRODUCTION PROFILE 06/10/07 1 2M-12 11629030 SBHP SURVEY 06/10/07 1 2L-311 11638881 SBHP SURVEY 06/11/07 1 2N-317 11638878 SBHP SURVEY 06/11/07 1 2B-08 11629032 INJECTION PROFILE 06/11/07 1 1 H-OS 11638882 INJECTION PROFILE 06/12/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor k?/. çq ¡~\ci.p ! r-ti &f v' I L " DATE: Wednesday, August 09,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHJLLIPS ALASKA INC 2N-306 KUPARUK RIV U TARN 2N-306 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: ~2-- P.I. Suprv, \ \/1 Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U TARN 2N-306 API Well Number 50- I 03-20490-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060808 I 85049 Permit Number: 204-062-0 Inspection Date: 8/812006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -, ¡Type Inj. I G I TVD ! 1860- -L-- Well I 2N-306 ! IA ! 5174 ! 20 1890 ! -~ i ~-+ ! I I I ----"---. P.T. I 2040620 ITypeTest : SPT i Test psi 1500 OA 260 ! 420 400 I 400 I I I I i Tubing I i ! Interval 4YRTST P/F P /' 3090 3090 ! 3090 3090 , , I I Notes Pretest pressures were observed and found stable. WelJ demonstrated good mechanical integrity. SCANNED f~UG 2 Ü 2D05 Wednesday, August 09, 2006 Page 1 of 1 Permit to Drill 2040620 MD 7605 / ~6 ~~~ DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 SP"tJ. ^'~ M~ ~ Ý API No. 50-103-20490-00-00 Well Name/No. KUPARUK RIV U TARN 2N-306 Operator CONOCOPHILLlPS ALASKA INC TVD 5609 / Completion Date 6/26/2004 ~ Completion Status WAGIN Current Status WAGIN REQUIRED INFORMATION DATA INFORMATION Mud Log No Samples No Directional Survey ...§ (data taken from Logs Portion of Master Well Data Maint . Interval OH/ Start Stop CH Received Comments 0 7605 6/25/2004 ---, 150 7290 Case 10/17/2005 Injection Profile SPIN/GRADIOITEMP/PRE SS/GRlCCL 19 Sep 2005 2803 7605 Open 8/20/2004 MPR, GRAPHIC IMAGES, LIS TIF, LDWG, RWD, MPRlCCN/ORD/GR 2803 7605 Open 8/20/2004 MPR, PRESSURE, MWD, GR, CCN 2803 7605 Open 8/20/2004 MPR, PRESSURE, MWD, GR, CCN 2803 7605 Open 8/20/2004 MPR, PRESSURE, MWD, GR, CCN 2803 7605 Open 8/20/2004 MPR, PRESSURE, MWD, . GR, CCN 2803 7605 8/20/2004 MPR, PRESSURE, MWD, GR, CCN, DSN 12626 6780 7356 Case 7/21/2004 PERFORATING RECORD & SBHP 6775 7367 Case 7/21/2004 CEMENT BOND LOG, SCMT-CAlPRESSITEMP Types Electric or Other Logs Run: Well Log Information: Electr Digital Dataset Med/Frmt Number 12626 Induction/Resistivity ~ J..e9 Well Cores/Samples Information: Name Name Directional Survey Injection Profile Log Log Run Scale Media No 5 Blu 2 25 Blu 2 25 Blu 2 25 Blu 2 25 Blu 2 25 2 5 Blu 5 Blu Density 1"'-9 "'Vi) Density Induction/Resistivity ~ ~ Induction/Resistivity tV j) LIS Verification Perforation Cement Evaluation Interval Start Stop Sample Set Number Comments Sent Received Permit to Drill 2040620 MD 7605 TVD 5609 ADDITIONAL INFORMATION Well Cored? è Chips Received? ~ Analysis Received? ~ DATA SUBMITTAL COMPLIANCE REPORT 6/26/2006 Well Name/No. KUPARUK RIV U TARN 2N-306 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20490-00-00 UIC Y Comments: Compliance Reviewed By: Completion Date 6/26/2004 Completion Status WAGIN Current Status WAGIN Daily History Received? 'bs/N ~ Formation Tops ~ Date: rJ",S ~ 6 . . 10/07/05 Scblumbepgep NO. 3492 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Log Description Date BL Color CD . 3M-07 11015737 INJECTION PROFILE 09/26/05 1 1E-18 11015745 GLS SURVEY 10/02/05 1 1 Q-22 11015744 PRODUCTION PROFILE 10/01/05 1 1 G-08A 11072911 PRODUCTION PROFILE 10/01/05 1 1G-10A 11072910 PRODUCTION PROFILE 09/30/05 1 2C-04 11072907 INJECTION PROFILE 09/27/05 1 2D-05 11072909 INJECTION PROFILE 09/29/05 1 2P-429 11056695 INJECTION PROFILE 09/18/05 1 2N-306 11056696 INJECTION PROFILE 09/19/05 1 10-122 11015730 INJECTION PROFILE 09/06/05 1 1 C-111 11015732 INJECTION PROFILE 09/22/05 1 1 D-114 11015728 INJECTION PROFILE 09/04/05 1 2V-08A 11072913 INJECTION PROFILE 10/03/05 1 3M-01 (REDO) 11015736 INJECTION PROFILE 09/25/05 1 31-04 10092325 PRODUCTION PROFILE 10102/05 1 1E-105 11015726 TEMPERATURE SURVEY 09/02/05 1 SIGNED: 11. rD/i _ DATE: /7 ()11-Jvtt r . Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~ ~ v{ -~~ ~ ~:l<t · STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test J,blf- ú 0'" Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Tarn/ KRU/2N 05/19/05 Arend/Sauvageau - AES o P Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover o = other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 2N-306 05-19-05.xls 5/24/2005 · e ~~.!I~'- L Transmittal Form r'__ BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: '-p9lJin Ð~iI~UII -/.Iei~ .:r lJø.,~ Reference: 2N-306 Contains the following: ~)¡to 1 LDWG Compact Disc Jt ) ì-- (Includes Graphic Image files) - ~ 1 LDWG lister summary 1 blue line - GRlMPR Measured Depth Log 1 blue line - GRlMPR TVD Log 1 blueline - CCN/ORD Measured Depth Log 1 blueline - CCN/ORD TVD Log LAC Job#: 683652 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ----------.--------.--------------------- I:;:~~~~~~;~'--l,:¡ ,.. .;;;;;;:-~'<~;:;;¡;.;,~;;;- -- . !.....,.".,.. i -'" - .... .., --~ .. "_'-_'_'_"_'__'_' """,_ _(,~, H_"'M_'_'~ -"" _ ... .-, -~' ,'''' ...... ~. "',':'':'''"', ' _'" _II .... '" _.~, ,,"~~""'L _,,,.. ..,_ -.", """_:e<' , s=-~~r ! :-~'-~;:-..-:-i;;:.;~----1 ~~i:~~'1:¿~~~~:i~~' ,.~:;. j "';' ,~'/"- -'.', : --", - ........ -~:: -------------------------------:.---....-: MEMORANDUM State of Alaska . e Alaska Oil and Gas Conservation Commission TO: Jim Regg ?~ 3124-104~ P.I. Supervisor ( I DATE: Thursday, August 19, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2N-306 KUPARUK RIV U TARN 2N-306 ~(Jtf-t7 ".~ FROM: JeffJones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :)J!fl- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U TARN 2N-306 API Well Number: 50-103-20490-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ040818094753 Permit Number: 204-062-0 Inspection Date: 81l5/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2N-306 Type Inj. G TVD 5609 IA 1500 2160 2140 2140 P.T. 2040620 TypeTest SPT Test psi 1500 OA 250 290 265 255 Interval INITAL P/F P Tubing 2950 2950 2950 2950 Notes: .6 BBLS diesel pumped Thursday, August 19,2004 Page I of I . Conoc;r;hillips . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage. AK 99510-0360 Phone: 907-265-6830 July 21, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2N-306 (APD # 204-062) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 2N-306. If you have any questions regarding this matter, please contact me at 265-6830 or Philip Hayden at 265-6481. Sincerely, .~, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT /skad OR'G\~JfJ\ 1a. Well Status: Oil 0 Gas U Plugged 0 Abandoned 0 Suspended D MWAG 0 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WINJ 0 WDSPL 0 No. 01 Completions _ Other - Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp., Susp., ~~ ~f1.~·~t 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: June,Z,' 2004 204-062 / 3. Address: 6. Date Spudded: 13. API Number: P. o. Box 100360, Anchorage, AK 99510-0360 . 50-103-20490-00 May 20, 2004 4a. Location 01 Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: . Surface: 9' FNL, 544' FEL, Sec. 3, T9N, R7E, UM .- May 29,2004 2N-306 At Top Productive 8. KB Elevation (It): 15. Field/Pool(s): Horizon: 2564' FSL, 2354' FEL, Sec. 35, T10N, R7E, UM 30' RKB /149' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): Tarn Oil Pool 2531' FNL, 2078' FEL, Sec. 35, T10N, R7E, UM 7409' MD / 5487' TVD 4b. Location 01 Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 461049 . y- 5911997 ,. Zone- 4 7605' MD / 5609' TVD ADL 375074/380054/380053 TPI: x- 464528 y- 5914553 Zone- 4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 464805 . y- 5914737 Zone-4 Landing Nipple @ 494' ALK 31961/32027/32026 18. Directional Survey: Yes 0 NoU 19. Water Depth, ilOffshore: 20. Thickness 01 N/A feet MSL Pennalrost: 1213' MD 21. Logs Run: GR/Res/Dens/Neu, SCMT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE CEMENTING RECORD WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# B 30' 137' 30' 137' driven 166 sx AS I (surface liII-up) 7.625" 29.7# L-80 30' 2794' 30' 2438' 9.875" 203 sx AS Lite, 196 sx LiteCrete 5.5" 15.5# L-80 30' 6964' 30' 5188' 6.75" 231 sx GasBlok 3.5" 9.3# L-80 6964' 7595' 5188' 5603' 6.75" included above 23. Perforations open to Production (MD + TVD 01 Top and Bottom 24. TUBING RECORD Interval, Size and Number; il none, state "none"): SIZE DEPTH SET (MD) PACKER SET 3.5" 6961' none 7258' - 7266' MD 5388' - 5393' TVD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7270' - 7286' MD 5396' - 5406' TVD 6 spf DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7292' - 7310' MD 5410' - 5422' TVD 6 spf n/a 26. PRODUCTION TEST Date First Injection Method 01 Operation (Flowing, gas lift, etc.) June 19, 2004 Injector Date 01 Test Hours Tested Production lor OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO n/a Test Period --> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. psi 24-Hour Rate -> not available 27. CORE DATA Briel description 01 lithology, porosity, Iractures, apparent dips and presence 01 oil, gas or water (attach separate sheet, il necessary). Submit core chips; il none, state "none". T^':''t~=~~, ;j:'/; :.-. ,-':" '-;'''''"} I Yo'(}!¡'-i_,.r!'-II ~ \ >~ NONE I~~;J -M'c..c .t - ------.-.-..- ; '.---."..--....-."".,',....,..."-."....."...:: . STATE OF ALASKA . ALASKA Oil AND GAS CONSERVATION COMM ION WELL COMPLETION OR RECOMPLETION REPORT AND lOG Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ORIGINAL R8UMS 8ft JUt a 6 1.ftft' G 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". 2N-306 T3 7170' 5329' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Philip Hayden @ 265-6481 printedNa~. ThO~ Signature \ \ Title: .....;/.hone KUDaruk Drillina Team Leader ~¿~ç- G""i )(;) Date 7/2.< (t:.'-( Prepared by Sharon AI/sup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Altemating-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 1 0-407 Revised 2/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-306 2N-306 ROT - DRILLING n1433@ppco.com Nordic 3 Start: 5/18/2004 Rig Release: 6/2/2004 Rig Number: Spud Date: 5/19/2004 End: Group: 15:30 - 21 :00 SURFAC 21 :00 - 21 :30 SURFAC 21 :30 - 23:30 SURFAC 23:30 - 00:00 SURFAC 5/20/2004 00:00 - 02:30 2.50 WELCT SURFAC 02:30 - 03:00 0.50 WELCT SURFAC 03:00 - 06:00 3.00 DRILL SURFAC 06:00 - 07:00 1.00 DRILL SURFAC 07:00 - 08:30 1.50 DRILL OTHR SURFAC 08:30 - 10:00 1.50 DRILL OTHR SURFAC 10:00 - 11 :00 1.00 DRILL PULD SURFAC 11 :00 - 12:00 1.00 DRILL SFTY SURFAC 12:00 - 13:00 1.00 DRILL SFTY SURFAC 13:00 - 13:15 0.25 DRILL OTHR SURFAC 13:15 - 15:15 2.00 DRILL DRLG SURFAC 15:15 - 15:30 0.25 DRILL TRIP SURFAC 15:30 - 16:00 0.50 RIGMNT RGRP SURFAC 16:00 - 18:00 2.00 DRILL OTHR SURFAC 18:00 - 20:00 2.00 DRILL OTHR SURFAC 20:00 - 20:30 0.50 DRILL DRLG SURFAC 20:30 - 21 :30 1.00 DRILL OBSV SURFAC 21 :30 - 00:00 2.50 DRILL CIRC SURFAC 5/21/2004 00:00 - 03:45 3.75 DRILL DRLG SURFAC 03:45 - 04:00 04:00 - 04:30 04:30 - 04:45 04:45 - 12:00 0.25 DRILL 0.50 DRILL 0.25 DRILL 7.25 DRILL TRIP SURFAC CIRC SURFAC TRIP SURFAC DRLG SURFAC 12:00 - 00:00 12.00 DRILL DRLG SURFAC 5/22/2004 00:00 - 11 :00 11.00 DRILL DRLG SURFAC PJSM on rig move. Move rig off well. Move f/ 2N-345A to well 2N-306. (450'). Spot and level rig. RU diverter system and 16" diverter line. Rig accepted @ 1530 hrs 5/19/2004. Function knife valve. Fill water above bag to function test. Bottom seal on quick connect leaking water. Steam heat seal, still leaking. N/D riser, Pull diverter off well. Check seal inside of FMC Oick connect 16". Seal appears to be good. Change out seal w/ new seal. NU Diverter system. Attatch 16" diverter line. Test diverter system, accumulator test. Load 72 joints 4" dp in pipe shed. PU and stand back 4" dp in derrick. PU 234" HWDP, 34" spiral weight dp, stand back in derrick. Test gas alarms, check Totco rig monitorsing system alarms(visual and audible) f/ flow, PVT and trip tank. MU stand of 4" HWDPw/ stack washing tool. RIH, tag @ 66'. Circ well w/ mud to displace water f/ hole. Blow down top drive. Load Drilling tools in shed. MU bit, mtr and 1 stand HWDP. Pre spud safety meeting. Hold accumulator drill, diverting shallow gas drill. Cleanout inside of conductor f/66' to 139'. Drill 9 7/8" hole f/ bottom of conductor to 304'. Lost 5-10 bbls while drilling @ 210'. then ok. Blow down top drive, POOH to inside of conductor. MU headpin. Pump @ 10 bpm to calibrate Totco flow sensor. Sensor not reading flow out. RID circ equipment. MU BHA #1, Orient UBHO, motor and MWD, MU RIH w/ flex DC's. Shallow pulse test MWD. RU HOWCo slickline. Run gyro survey. RIH, Drill f/304' to 334'. Lost circ. POOH to 280, monitor well. RIH to 334, pump 30 bbls LCM pill w/20 ppb medium material. PU wt 37K, SO wt 37k, rot wt 37k. Total hours today on bit = 2.3 rotating. Drill f/ 334' to 506', ART = .75 hrs, AST = 1.2 hrs, WOB 5/10K, RPM 80, 463 GPM @ 2050 psi, UP 50K, ON 50K, ROT 50K, TO 3200 on /2500 off. Note; Lost circ @ 506'. POOH to 280'. Circ & regain circulation. RIH to 506'. Drill f/506' to 980', ART= 1.45 hrs, AST= 2.2 hrs, WOB 5/10K, RPM 80, 463 GPM @ 2050 psi, UP 50K, DN 50K, ROT 50K, TO 3200 on /2500 off, (Losing 30 bph). Drill f/ 980' to 1930', ART = 2.6 hrs, AST = 4.5 hrs, WOB 5/15K, RPM 80, 520 GPM @ 2900 psi, UP 65K, DN 58K, ROT 60K, TO 2800 on /2310 off (Presently losing +/- 5 bph)- (Had Gas Hydrates at base of Premafrost, Controled drilled 100/120 ftIhr). Note; Have lost 134 bbls last 24 hrs. Have lost total of 378 bbls total up to date. Drill f/1930' to 2803' (2445' TVD), ART = 4.9 hrs, AST = 2.6 hrs, WOB 10-20K, RPM 80, 514 GPM @ 3000 psi, UP 70K, ON 60K, ROT 65K, Printed: 7/13/2004 9:53:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-306 2N-306 ROT - DRILLING n1433@ppco.com Nordic 3 Start: 5/18/2004 Rig Release: 6/2/2004 Rig Number: Spud Date: 5/19/2004 End: Group: 5/22/2004 00:00 - 11 :00 11.00 DRILL DRLG SURFAC TQ 4800 on /2800 off (Presently losing less than 5 bph) Controled drilled 100/120 ftIhr). Check flow on connections. Pump hi vis weighted sweep @ 2000' MD, pump 30 bbl hi vis sweep @ 2750' MD 11 :00 - 15:00 4.00 DRILL CIRC SURFAC Circ BU, pump 30 bbl weighted sweep, follow w/ 4 BU total. Monitor well. Circ @ 480 gpm w/ 2800 psi. Pull a stand after each bottoms up (Pull to 2,543'). 15:00 - 17:00 2.00 DRILL REAM SURFAC Back ream out f/ 2,543' to 1,691' at 480 gpm @ 2800 psi. 17:00 - 18:30 1.50 DRILL CIRC SURFAC Circ btm's up 3 times & hole clean while POOH very slow to 1,407', Blow down top drive. 18:30 - 19:30 1.00 DRILL TRIP SURFAC Pump out of hole to DC's due to swabbing, Monitor well at HWDP & BHA -Static. 19:30 - 22:30 3.00 DRILL PULD SURFAC PJSM, Lay down BHA. 22:30 - 00:00 1.50 CASE RURD SURFAC Rig to run 7-5/8" casing. 5/23/2004 00:00 - 00:15 0.25 CASE SFTY SURFAC PJSM on running 7-5/8" casing. 00:15 - 02:15 2.00 CASE RUNC SURFAC Pick up run 7-518" Weatherford Float Shoe, 2 jts 7-5/8",29.7#, L-80, BTCM, 7-5/8" Weatherford Float collar, 17 more joints 7-5/8" casing to 847' at a rate of 30/40 ftImin- w/ good displacement, Install total of 22 Bowspring centralizers as per detail. 02:15 - 02:45 0.50 CASE CIRC SURFAC Circ btm's up at rate of 2 bpm @ 250 psi, Lost total of 10 bbls mud while circ, Losses subsided after btm's up, UP 40K, ON 37K. 02:45 - 03:15 0.50 CASE RUNC SURFAC Run 10 joints 7-5/8" casing to 1,274' at rate of 20/30 ftImin.- w/ good displacement. 03:15 - 03:30 0.25 CASE CIRC SURFAC Break circ & circ at 2 bpm @ 275 psi, Lost 7 bbls mud then losses subsided, UP 55K, ON 50K. 03:30 - 04:00 0.50 CASE RUNC SURFAC Run 10 joints 7-5/8" casing to 1,702' at rate of 20/30 ftImin.- w/ good displacement. 04:00 - 05:00 1.00 CASE CIRC SURFAC Circ btm's up at rate of 2 bpm @ 300 psi, Lost total of 15 bbls mud while circ, Losses subsided after btm's up, UP 70K, ON 60K. 05:00 - 05:30 0.50 CASE RUNC SURFAC Run 10 joints 7-5/8" casing to 2,123' at rate of 20/30 ftImin.- w/ good displacement. 05:30 - 06:00 0.50 CASE CIRC SURFAC Break circ & circ at 2 bpm @ 325 psi, Lost 11 bbls mud then losses subsided, UP 75K, ON 65K. 06:00 - 06:30 0.50 CASE RUNC SURFAC Run 12 joints 7-5/8" casing to 2,633' at rate of 20/30 ftImin.- w/ good displacement. 06:30 - 07:30 1.00 CASE CIRC SURFAC Circ btm's up at rate of 2 bpm @ 325 psi, Lost 5 bbls mud then losses subsided, UP 85K, ON 70K. 07:30 - 08:00 0.50 CASE RUNC SURFAC Run 3 joints (Total of 65 in hole) 7-5/8" casing to 2,761' at rate of 20/30 ftImin.- w/ good displacement. Note: Lost total of 48 bbls running 7-5/8" casing. 08:00 - 09:00 1.00 CASE RURD SURFAC Make up FMC Gen 5 casing hanger, Land casing on hanger, Make up Dowell cement head. 09:00 - 13:30 4.50 CEMEN CIRC SURFAC Circ & condo mud, Stage rate up from 2 bpm @ 200 psi to 6 bpm @ 370 psi, No losses - Full returns, UP 95K, ON 75K, Held PJSM for cmt job. 13:30 - 15:30 2.00 CEMEN PUMP SURFAC Rig Dowell, Mix & pump 5 bbls CW100 at 8.3 ppg at rate of 5.8 bpm @ 400 psi, Shut down, Test lines to 3500 psi, Continue pumping CW100 to total of 40 bbls, Mix & pump 40 bbls MudPUSH II with red dye added mixed at 10.5 ppg at rate of 6.2 bpm @ 400 psi, Shut down and drop btm plug, Mix & pump 203 sxs (161.1 bbls) Lead ArcticSet III cmt mixed at 10.7 ppg w/ additives at rate of 6.0 bpm @ 325 psi, Followed by 196 sxs (89.5 bbls) Tail LiteCRETE cmt mixed at 12.0 ppg w/ additives at Printed: 7/13/2004 9:53:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-306 2N-306 ROT - DRILLING n1433@ppco.com Nordic 3 Start: 5/18/2004 Rig Release: 6/2/2004 Rig Number: Spud Date: 5/19/2004 End: Group: 2.00 CEMEN PUMP SURFAC rate of 5.4 bpm @ 550 psi, Shut down and drop top plug, Displace cmt w/ 20 bbls fresh water, Shut down and turn over to ri9 pumps and continue to displace w/106.2 bbls 10.0 ppg mud (total of 126.2 bbls to bump plug) at rate of 6.0 bpm @ 360 to 600 psi, Slowed rate to 3.0 bpm @ 430 psi for last 15 bbls of displacement, Bump plug w/1030 psi, Floats held- OK, CIP @ 15:30 hrs 5/23/04, Had good returns thru out job, Reciprocate csg. 15' until cement rounded shoe, Had 34.3 bbls good cmt returns to surface. Blow down pump line & rig down same, Rig down Dowell cement head, Lay down all cement & casing tools, Flush out Diverter system, Lay down langin9 joint. Nipple down Diverter system. Nipple up FMC Gen 5 Well head & test same to 1000 psi for 10 min.- OK., Begin Nipple up BOPE. Nipple up 11" BOP stack. Change out ram on OS extend f/ top drive. Load 147 joints 4" dp in shed. Middle boot on riser leaking. N/D riser and change out boot. Continue to load 4" DP in pipe shed. Remove burr from inside of boot housing. Set FMC test plug. Test BOPE. Witness of test waived by AOGCC inspector Jeff Jones. Test annular to 250 psi low and 5000 psi high. Test top and bottom rams and blinds and allvalves and choke manifold to 250 psi low and 5000 psi high. Test accumulator. Pull test plug. Set wear ring, problems setting. Wear bushing egged, not big enough(6 11/16",65/8", wrong wear bushing, (short wear bushing). Set correct FMC wear bushing w/9" 10. PJSM. PU 4" DP, RIH 54 jts, stand back, PUlRIH 45 jts, POOH stand back. Install flange w/2" 1502 thread union, then double valve lower annulus valve. PU tools f/ BHA #2. PU BHA #2. Upload Baker MWD. PJSM. Load nuke sources PU/MU NMDC's. Change out jars Test MWD. 100 spm & 120 spm. Pre Drill out meeting w/ rig team. Pre job safety meeting on stripping drill. RIH w/4" HWDP f/ derrick. PU 37 jts 4" weatherford DP f/ Pipe shed, RIH to 2192'. All DP was drifted to 2.25" BOP drill while tripping in hole. Break circ. perform well kill drill. Circ. RU to test 7 5/8" casing. Test casing to 3500 psi. Chart test. Lost 60 psi. OK. Stripping Drill. Install full open valve, shut annular, install inside BOP, MU single, apply 200 psi to well, run pipe till 300 psi buildup, bleed volume of pipe, continue w/ stand. Blled off well, POOH, remove safety valve and inside BOP Continue PU 4" DP f/ pipe shed to 2540'. RIH w/ stands f/ derrick to tag stringers @ 2650' MU top drive. Circ and condition mud. Blow down top drive. Stand back a stand. RU to test casing again. Test casin9 to 3500 psi f/30 min. Chart test. 5/23/2004 13:30 - 15:30 15:30 - 17:00 1.50 CEMEN PULD SURFAC 17:00-21:00 4.00 WELCT SURFAC 21 :00 - 00:00 3.00 WELCT SURFAC 5/24/2004 00:00 - 03:00 3.00 WELCT SURFAC 03:00 - 05:30 SURFAC 05:30 - 09:30 SURFAC 09:30 - 11 :00 1.50 WELCT EQRP SURFAC 11 :00 - 16:30 5.50 DRILL SURFAC 16:30 - 17:00 0.50 WELCT SURFAC 17:00 - 19:30 2.50 DRILL PULD SURFAC 19:30 - 21 :00 1.50 DRILL OTHR SURFAC 21 :00 - 21 :45 0.75 DRILL OTHR SURFAC 21 :45 - 22:45 1.00 DRILL PULD SURFAC 22:45 - 23:30 0.75 DRILL DEQT SURFAC 23:30 - 00:00 0.50 DRILL SFTY SURFAC 5/25/2004 00:00 - 00:45 0.75 DRILL TRIP SURFAC 00:45 - 02:30 1.75 DRILL TRIP SURFAC 02:30 - 02:45 0.25 DRILL SFTY SURFAC 02:45 - 03:15 0.50 DRILL CIRC SURFAC 03:15 - 03:45 0.50 DRILL CIRC SURFAC 03:45 - 04:45 1.00 CASE MIT SURFAC 04:45 - 06:45 2.00 DRILL SFTY SURFAC 06:45 . 07:30 0.75 DRILL TRIP SURFAC 07:30 - 08:30 1.00 DRILL CIRC SURFAC 08:30 - 09:30 1.00 CASE MIT SURFAC Printed: 7/13/2004 9:53:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-306 2N-306 ROT - DRILLING n1433@ppco.com Nordic 3 Start: 5/18/2004 Rig Release: 6/2/2004 Rig Number: Spud Date: 5/19/2004 End: Group: 5/25/2004 08:30 - 09:30 1.00 CASE MIT SURFAC Lost 55 psi. OK. RID test equipment. 09:30 - 10:00 0.50 DRILL SFTY SURFAC Pre drill out safety meeting. 10:00 - 11 :00 1.00 CEMEN DSHO SURFAC RIH, wash to top of FC @ 2703'. Drill top and bottom plugs, FC, cement, and FS @ 2793', drill rat hole to 2803; and 20' new hole (6 3/4") to 2823'. Drill w/3/5k WOB, 60 RPM, 280 mtr rpm, 270 gpm, 1800 psi, 75 k PU wt, 55 k SO wt, 65 k Rot wt, 2800 Torque on bottom, 2200 torque off bttm. 11 :00 - 12:00 1.00 DRILL CIRC SURFAC Change out mud to new LSND mud 10 ppg. Used new spud mud not used in surface hole to build LSND system. 12:00 - 13:00 1.00 DRILL FIT SURFAC Blow down top drive, stand back a stand of drill pipe, RU f/ LOT. Perform FIT to 18.5 ppg w/1 Oppg mud and shoe @ 2438' TVD with 1075 psi. Chart test. R/D test equipment. 13:00 - 15:30 2.50 DRILL DRLG PROD Drill 6 3/4" hole f/ 2823' to 3010'. ART = 1.4 hrs Drill w/ 5/12 k WOB, 80 RPM, 305 mtr rpm, 294 gpm, 2400 psi, 68 k PU wt, 63 k SO wt, 65 k Rot wt, 3400 Torque on bottom, 3000 torque off bttm. 15:30 - 16:00 0.50 DRILL CIRC PROD Circ hole clean. Perform PWD baseline w/1 0 ppg mud. Baseline 10.86 ppg. pumping @ 300 gpm, rotating @ 80 rpm, w/1400-1450 psi. 16:00 - 19:00 3.00 DRILL DRLG PROD Drill 6 3/4" hole f/ 3010' to 3200'. ART = .6 hrs AST = 1.0 hrs Drill w/ 8/15 k WOB, 80 RPM, 305 mtr rpm, 294 gpm, 2500 psi, 65 k PU wt, 63 k SO wt, 65 k Rot wt, 3600 Torque on bottom, 2900 torque off bttm. ECD's 10.86 ppg 19:00 - 19:15 0.25 DRILL OTHR PROD Change shaker screens. Change # 1 shaker f/250's to 21 O's. Change # 2 shaker f/250's to 210 & 250 . Leave # 3 @ 250's. 19:15-20:45 1.50 DRILL DRLG PROD Drill 63/4" hole f/32oo' to 3311 '. ART = 0.0 hrs AST = 1.0 hrs Drill w/ 6-8 k WOB, 0.0 RPM, 305 mtr rpm, 294 gpm, 2200 psi, 65 k PU wt, 65 k SO wt, 66 k Rot wt. ECD's 10.86 ppg 20:45 - 21 :00 0.25 DRILL OBSV PROD Flow check well @ 3311'. OK. 21 :00 - 00:00 3.00 DRILL DRLG PROD Drill 6 3/4" hole f/3311' to 3550'. ART = .8 hrs AST = 1.3 hrs Drill w/6-8 k WOB, 90 RPM, 305 mtr rpm, 294 gpm, 2500 psi, 70 k PU wt, 68 k SO wt, 68 k Rot wt, 4200 Torque on bottom, 3400 torque off bttm. ECD's 10.99 ppg. Pump 15 bbs hi vis sweep while drilling @ 3440'. 5/26/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Drill 6 3/4" hole f/3550' to 4159'. ART = 4.6 hrs AST = 3.6 hrs Drill w/ 4-15 k WOB, 80 RPM, 305 mtr rpm, 294 gpm, 2200-2850 psi, 70-82 k PU wt, 66-70 k SO wt, 67-75 k Rot wt, 3950-5500 Torque on bottom, 3500-5300 torque off bttm. ECD's 11.1 ppg. Pump 15 bbs hi vis sweep while drilling @ 3768',3910' and hi vis weighted sweep @ 4440'. 12:00 - 00:00 12.00 DRILL DRLG PROD Drill 63/4" hole f/4159' to 4809'. ART = 4.3 hrs AST = 3.8 hrs Drill w/ 4-15 k WOB, 80 RPM, 305 mtr rpm, 294 gpm, 2100-2500 psi, 78-80 k PU wt, 68-72 k SO wt, 74-78 k Rot wt, 4500 - 5700 Torque on bottom, 4200-5600 torque off bttm. ECD's 11.3- 10.6 ppg. Pump 15 bbs hi vis weighted sweep @ 4440' and hi vis sweep @ 4720',saw 5-10% increase in cuttings w/4720' sweep. 5/27/2004 00:00 - 13:30 13.50 DRILL DRLG PROD Drill 63/4" hole f/4809' to 5472'. (4194' TVD)ART = 8.0 hrs AST = 2.3 hrs Drill w/4-15 k WOB, 80 RPM, 280 mtr rpm, 270 gpm, 2250-2700 psi, 85-90 k PU wt, 79-85k SO wt, 79-85 k Rot wt, 5250-6200 Torque on bottom, 45300-6000 torque off bttm. ECD's 107-11.2 ppg. Pump 15 bbs hi vis weighted sweep @ 5000' and hi vis wt'd 12 ppg sweep @ 5472'. 13:30 - 15:30 2.00 DRILL CIRC PROD Survey, pump hi vis 12ppg weighted sweep prior to wiper trip to 7 5/8" shoe. Circ 3x BU. Rotate and recip pipe. Pull a stand every 1/2 hr while circ.while circ pull f/5472' to 5187'. 15:30 - 17:15 1.75 DRILL WIPR PROD Observ well. POOH f/5187' to 2726' wet. No problems. Hole fill good. Check f/ flow @ 2800'. Printed: 7/13/2004 9:53:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-306 2N-306 ROT - DRILLING n1433@ppco.com Nordic 3 Start: 5/18/2004 Rig Release: 6/2/2004 Rig Number: Spud Date: 5/19/2004 End: Group: 5/27/2004 17:15 - 18:00 0.75 RIGMNT RSRV PROD Service rig and clean rig floor. 18:00 - 19:00 1.00 DRILL WIPR PROD RIH f/2726' to 4146'. 19:00 - 19:15 0.25 DRILL CIRC PROD Fill pipe @ 4146'. 19:15 - 20:00 0.75 DRILL WIPR PROD RIH f/4146' to 5377'. Fill pipe, break circ. 20:00 - 20:15 0.25 DRILL REAM PROD Precautionary ream f/5377' to 5472'. 20:15 - 00:00 3.75 DRILL DRLG PROD Drill 6 3/4" hole f/5472' to 5683'. (TVD = 4336') ART = .8.0 hrs AST = 1.9 hrs Drill w/ 6-8 k WOB, 85 RPM, 280 mtr rpm, 270 gpm, 2300 psi, 95 k PU wt, 85k SO wt, 88 k Rot wt, 6000 Torque on bottom, 5800 torque off bttm. ECD's 10.8 ppg. 5/28/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Drill 6 3/4" hole f/ 5683' to 6358'. (TVD = 4788') ART = 4.1 hrs AST = 4.1 hrs Drill w/ 2-9 k WOB, 85 RPM, 270 mtr rpm, 270 gpm, 2700 psi, 99 k PU wt, 85k SO wt, 94 k Rot wt, 6400-7400 Torque on bottom, 5200-6400 torque off bttm. ECD's 10.7-11.2 ppg. 12:00 - 00:00 12.00 DRILL DRLG PROD Drill 6 3/4" hole f/6358' to 6855'. (TVD = 5116') ART = 4.9 hrs AST = 3.5 hrs Drill w/7-12 k WOB, 85 RPM, 305 mtr rpm, 293 gpm, 2700 psi, 145 k PU wt, 93k SO wt, 95 k Rot wt, 7200-7600 Torque on bottom, 6100-7400 torque off bttm. ECD's 10.9-11.3 ppg. 5/29/2004 00:00 - 06:00 6.00 DRILL DRLG PROD Drill 63/4" hole f/6855' to 7053'. (TVD = 5247') ART = .75 hrs AST = 4.0 hrs. Drill w/4-10 k WOB, 85 RPM, 305 mtr rpm, 293 gpm, 2700 psi, 110-140 k PU wt, 95k SO wt, 100 k Rot wt, 7200-7600 Torque on bottom, 6100-7400 torque off bttm. ECD's 10.9-11.3 ppg. Pump 12ppg HI VIS sweep @ 7040'. 06:00 - 12:00 6.00 DRILL DRLG PROD Drill 6 3/4" hole f/7053'(5247' TVD) to 7460'. (TVD = 5521') ART = 2.75 hrs AST = 1.0 hrs. Drill w/5-12 k WOB, 85 RPM, 293 mtr rpm, 282 gpm, 2800 psi, 1112 k PU wt, 91k SO wt, 101 k Rot wt, 8100-8900 Torque on bottom, 7400-8400 torque off bttm. ECD's 10.9-11.2 ppg. 12:00 - 13:45 1.75 DRILL DRLG PROD Drill 6 3/4" hole f/7460' (5521' TVD) to 7588'. (TVD = 5597') ART = 1.3 hrs AST = 0.0 hrs. Drill w/4-10 k WOB, 85 RPM, 293 mtr rpm, 282 gpm, 2800 psi, 115 k PU wt, 95k SO wt, 103 k Rot wt, 9200-9500 Torque on bottom, 8100-8200 torque off bttm. ECD's 10.9-11.0 ppg. 13:45 - 14:45 1.00 DRILL CIRC PROD Circ@ 7588', pump 12 ppg hi vis sweep, follow w/290 gpm & 2700 psi. Recip and rotate @ 85 rpm. 14:45 - 15:15 0.50 DRILL DRLG PROD Drill 63/4" hole f/7588' (5597' TVD) to 7605'. (TVD = 5609') ART = .1 hrs AST = 0.0 hrs. Drill w/5-10 k WOB, 85 RPM, 293 mtr rpm, 282 gpm, 2750 psi, 115 k PU wt, 95k SO wt, 105 k Rot wt, 9400-9900 Torque on bottom, 8300-8600 torque off bttm. ECD's 11.0 ppg. 15:15 - 17:45 2.50 DRILL CIRC PROD Circ and condition mud and hole. Recip and rotate @ 85 rpm, pull a stand every 1/2 hr. Pump total of 1053 bbls. Circ @ 290 gpm w/26oo psi. 17:45 - 18:15 0.50 DRILL REAM PROD Backream f/ 7176' to 6986' w/ 290 gpm w/2400 psi, 85 rpm. Monitor well. 18:15 - 19:15 1.00 DRILL WIPR PROD POOH wet w/ elevators to 6043'. Hole in good shape, good hole fill. PU wt 155k. 19:15 - 20:15 1.00 DRILL WIPR PROD RIH f/6043' to 7557'. 20:15 - 23:15 3.00 DRILL CIRC PROD Break circ, wash 7557' to 7605' w/122 gpm & 650 psi. Circ and condition mud and hole. Pump 20 bbl hi vis, 12 ppg weighted sweep w/ rotating and recip. 23:15 - 00:00 0.75 DRILL REAM PROD Backream out of hole f/ w/290 gpm & 2350 psi. Pull a stand every 1/2 hr. 5/30/2004 00:00 - 01 :45 1.75 DRILL CIRC PROD Circ & Backream out of hole f/ 7559' to 7179' w/ 290 gpm & 2350 psi. Pull a stand every 1/2 hr. 01 :45 - 02:45 1.00 DRILL REAM PROD Backream out of hole f/ 7179 to 6705' w/ 290 gpm & 2350 psi. 02:45 - 03:00 0.25 DRILL OBSV PROD Monitor well. OK. Blow down top drive. Fill trip tank. Printed: 7/1312004 9:53:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-306 2N-306 ROT - DRILLING n1433@ppco.com Nordic 3 Spud Date: 5/19/2004 End: Group: Start: 5/18/2004 Rig Release: 6/2/2004 Rig Number: 03:00 - 06:00 DRILL PROD POOH w/ BHA # 2 to run 3 1/2" x 51/2" csg. Tight spot @ 5545'- 5516'. 06:00 - 06:15 DRILL PROD Monitor well @ 7 5/8" casing shoe. 06:15 - 08:00 DRILL PROD Continue POOH w/4" DP. 08:00 - 10:30 2.50 DRILL PROD PJSM on Baker nuke tools/sources. UD BHA. 10:30 - 11 :00 0.50 WELCT PROD Pull wear FMC bushing. 11 :00 - 11 :45 0.75 WELCT PROD Set FMC test plug, RU to test. 11 :45 - 12:30 0.75 WELCT PROD Change lower pipe rams f/4" to 51/2". 12:30 - 12:45 0.25 WELCT PROD Test lower pipe rams to 250 psi low and 5000 psi high. Chart test. 12:45 - 13:30 0.75 WELCT PROD RID test equipment. Pump water thru kill and choke lines. Cleaned pump manifold, suction screens and discharge screens on mud pumps. 13:30 - 14:00 0.50 CASE RURD PROD RU floor to run 3 1/2" x 5 1/2" casing. 14:00 - 14:30 0.50 CASE SFTY PROD PJSM on running casing. 14:30 - 16:30 2.00 CASE RUNC PROD Run 3 1/2" x 5 1/2" casing. Weatherford FS, bakerlock jts # 1 & #2, run-n-seal dope box of #3, bakerlock box of # 4& #5, weatherford FC,dope box of jt #6 and install weatherford plug catcher in box #6. Dope the rest of casing w/ Jet Lube Run-N-Seal. Circ 18 bbls @ 3bpm w/110 psi after MU jt # 7. Continue running total of 20 jts of 31/2". Installed centralizers every 20'. Centralizer pattern of every 20'. Casing in hole to 620'. Torque 31/2" EUE mod to 1800 ftllb 16:30 - 17:30 1.00 CASE OTHR PROD RU long bales, 5 1/2" elevators and Frank's fillup tool. 17:30 - 18:00 0.50 CASE RUNC PROD MU 3 1/2" pup, crossover, Baker 5" SBE w/5 1/2" pup on top. MU jt # 1 of 51/2". 18:00 - 18:15 0.25 CASE CIRC PROD Circ @ 704', (25 spm) 1.45 bpm w/300-330 psi w/ Frank's fillup tool. Circ @ (60 spm) 3.5bpm w/240 psi. Final circ @ (86 spm) 5 bpm w/ 440 psi. Circ total of 74 bbls. 18:15 - 20:15 2.00 CASE RUNC PROD Run jt # 2 thru jt # 1551/2" casing installing centralizers every 30'. Centralizer pattern of 3/2 jt. Had to circ a little to get last 9 joints in hole. All string down weight supported by centralizers. Casing in hole to 1285'. 20: 15 - 20:30 0.25 CASE CIRC PROD Circ 1200 strokes (70 bbls) @ 80 spm w/435-450 psi. Clear all air out of casing and casing annulus. 20:30 - 22:00 1.50 CASE RUNC PROD Run joints # 16 thru joints # 50 of 5 1/2" casing in hole to 2759'. Total of 70 total joints in hole. 22:00 - 00:00 2.00 CASE CIRC PROD Circ and condition mud @ 2759'. 3 bpm w/350 psi. 4bpm w/430 psi. Circ total of 6500 strokes (379 bbls). Add water @ 9-11 bph to get weight to 9.8 ppg. 5/31/2004 00:00 - 02:00 2.00 CASE RUNC PROD Run joints # 50 thru joints # 100 of 51/2" casing in hole to 4873'. Total of 120 total joints in hole. Torque 51/2" to 3600 ftIIb. 02:00 - 03:30 1.50 CASE CIRC PROD Circ @ 3bpm w/600 psi @ 4873'. 03:30 - 06:00 2.50 CASE RUNC PROD RIH w/3 1/2" x 51/2" casing. Run joints #101 thru joint # 164 of 51/2" (total 184 joints in hole). 06:00 - 06:15 0.25 CASE OTHR PROD PU/MU FMC hanger w/landing joint. 06:15 - 07:30 1.25 CASE CIRC PROD Circ and condition mud and hole @ 1.5 bpm w/1 000 psi. Circ 70 bbls total. Land on hanger @ 0715 hrs, 5/31/2004. PU wt 135k, SO wt 55k 07:30 - 07:45 0.25 CEMEN PULD PROD UD Frank's fillup tool. MU Dowell cement head and hoses to circ. 07:45 - 11 :45 4.00 CEMEN CIRC PROD Recip 20' w/ Circ and condition mud and hole f/ cement. Initial 1.2 bpm w/600 psi (41 bbls). Stage up to 2 bpm w/600 psi (117 bbls), returns 10.6 ppg+. Stage to 2.5 bpm w/450 psi (41 bbls), returns 9.6-9.8 ppg. Stage up to 3 bpm w/480-500 psi (50 bbls), returns 9.8 ppg. Stage to 3.5 bpm w/535 psi (50 bbls). Stage to 4 bpm w/580 psi (112 bbls), stage up to 4.5 bpm @ 1030 hrs w/630 psi (240 bbls), returns 9.6 ppg. 11 :45 - 12:00 0.25 CEMEN CIRC PROD Continue to recip & circ @ 4.5 bpm w/ holding PJSM on cementing. (67 Printed: 7/13/2004 9:53:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-306 2N-306 ROT - DRILLING n1433@ppco.com Nordic 3 Start: 5/18/2004 Rig Release: 6/2/2004 Rig Number: Spud Date: 5/19/2004 End: Group: 5/31/2004 11 :45 - 12:00 0.25 CEMEN CIRC PROD bbls) 12:00 - 12:30 0.50 CEMEN CIRC PROD Continue to circ @ 4.5 bpm w/ 630 psi while Dowell batches up cement. (135 bbls) 12:30 - 13:00 0.50 CEMEN OTHR PROD Flush rig pumps w/ water, follow w/ seawater to cuttings tank. 13:00 - 13:45 0.75 CEMEN PUMP PROD Dowell pump 10 bbl CW100 8.3 ppg, pressure test lines to 4000 psi, pump 20 more bbls CW 100,pump 30.3 bbls 12.27 ppg mud push, follow w/48.26 bbls 15.8 ppg GasBLOK "G" cement. Shut down. Shut in cement head. Flush to cuttings tank 1 0 bbls water. Break cap on cement head. Load Weatherford wiper dart. Open head. 13:45 - 14:30 0.75 CEMEN DISP PROD Rig displace cement @ 4.5 bpm w/ 8.5 ppg seawater while recip casing. Continue recip till 5 bbls before and 5 bbls after CW 100 @ shoe, Mud push @ shoe, and cement @ shoe. Land on hanger when slow pumps to 2 bpm @ 155 bbls displaced. Saw a 300 psi pressure increase when dart went through x-o @ 2793 strokes, followed w/ bumping plug @ calculated 67 additional strokes. Plug bumped earfy @ 2860 strokes (166.74 bbls). Calculated strokes was 2913 strokes x .0583 bps= 169.8 bbls. Final weight 50K down & 115 K PU wt. Circ pressure prior to bumping plug @ 2 bpm was 1300 psi, bumped to 2300 psi, floats held. CIP @ 1422 hrs. 14:30 - 15:15 0.75 CASE OTHR PROD Flush out mud lines w/ seawater thru kill line & choke line into BOP stack. 15:15 - 17:30 2.25 CASE RURD PROD Drain stack. R/D casing and cement equipment. Clear pipe shed of extra 16 jts of 5 1/2" casing. Clear BHA # 2 f/ pipe shed. 17:30 - 18:45 1.25 WELCT OTHR PROD RU to install 5 1/2" FMC packoff. RILDS, torque to 450 ftllb. Test packoff to 5000 psi f/1 0 min. ok. Rig down test pump. 18:45 - 20:30 1.75 CMPL TN RURD PROD Change bales on top drive to drilling bales. RU to run 3 1/2" completion. 20:30 - 20:45 0.25 CMPL TN SFTY PROD PJSM on running 3 1/2" completion. 20:45 - 00:00 3.25 CMPL TN RUNT PROD Run 3 1/2" 9.3 # EUE 8rd mod tubing completion. Little Red did injectivity test on 7 5/8" x 5 1/2" annulus, w/9.6 ppg mud in hole, pumping .5 bpm,pressure broke @ 850-875 psi, injected 3 bbls @ 600 psi., 10 min bled to 470 psi. Bleed back .5 bbls. Follow w/ total of 281 bbls water (pumped @ 3 bpm w/ avg 1000 psi), follow w/32 bbls diesel to 2000' (1808' TVD). Final pressure 800 psi. 6/1/2004 00:00 - 01:15 1.25 CMPL TN RUNT PROD Run 3 1/2" 9.3 # EUE 8rd mod tubing completion. Run jt # 41 thru #60 01:15 - 01:45 0.50 RIGMNT RSRV PROD Service rig. 01 :45 - 08:30 6.75 CMPLTN RUNT PROD Run 3 1/2" 9.3 # EUE 8rd mod tubing completion. Run jt # 61 thru #220 08:30 - 09:30 1.00 CMPL TN SOHO PROD Break circulation. While pumping slow, stung into SBE and shut down pumps. RIH to space out 09:30 - 10:30 1.00 CMPL TN CIRC PROD Pump 200 bbl sea water and 3.5 bpm @ 790 psi 10:30 - 11 :45 1.25 CMPL TN SOHO PROD UD 3 jts and P/U space ouut jt., hanger and landing jt. Pump slow and sting into SBE to verify space out. Pull out of SBE 11:45 - 13:00 1.25 CMPLTN CIRC PROD Pump 143 bbls of inhibited sea water. followed by 50 bbl seawater @ 3.5 bpm, 730 psi. P/U=80K, S/O=50k. 13:00 - 14:00 1.00 CMPL TN SOHO PROD Drain stack. Land tubing and run in LOS's 14:00 - 15:15 1.25 CMPL TN SEQT PROD Test tubing to 3500 psi for 30 minutes. Bled tubing pressure to 1500 psi. Test annulus to 3500 psi for 30 minutes. Bleed off tubing. Shear valve did not open. Bled off annulus pressure and repressured annulus to 3250 psi to open shear valve. 15:15 - 15:45 0.50 CMPL TN OTHR PROD Pull landing jt. and install BPV. 15:45 - 16:45 1.00 CMPL TN NUND PROD Change bottom pipe rams to 4" 16:45 - 20:00 3.25 CMPL TN NUND PROD N/D BOPE 20:00 - 21 :30 1.50 CMPL TN NUND PROD N/U tree and adapter spool. Printed: 7/13/2004 9:53:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-306 2N-306 ROT - DRILLING n1433@ppco.com Nordic 3 Start: 5/18/2004 Rig Release: 6/2/2004 Rig Number: Spud Date: 5/19/2004 End: Group: 6/1/2004 21 :30 - 22:30 22:30 - 23:45 23:45 - 00:00 00:00 - 00:45 00:45 - 01:15 01 :15 - 02:00 1.00 CMPL TN SEQT PROD 1.25 CMPL TN FRZP PROD 0.25 CMPL TN FRZP PROD 0.75 CMPL TN FRZP CMPL TN 0.50 CMPL TN OTHR CMPL TN 0.75 CMPL TN OTHR CMPL TN Test packott and tree to 5000 psi. Pump 60 bbl diesel down 5-1/2" x 3-1/2" annulus Allow diesel to U-tube between tubing and annulus Allow diesel to U-tube into tubing Flush pumps and kill/choke lines w/ water and blow down Rig down freeze protect equipment and set BPV-secure well. Release rig @ 02:00 hrs 6-2-2004 6/212004 Printed: 7/13/2004 9:53:42 AM . 2N-306 Well Events Summary . Date Summary 06/17/04 DRIFTED TBG WI 2.78 TO D-NIPPLE @ 6898' RKB, TAGGED FILL @ 7384' RKB. DRIFTED TBG TO 7384' RKB WI 23' OF 2.5" DUMMY GUN'S, REPLACED SHEARED SOV WI DV @ 6834' RKB. [Tag] 06/25/04 LOGGED SCMT FROM 7367' TO 6775' -- CEMENT QUALITY WAS GOOD EXCEPT IN AREA 7250' TO 7308' WHERE IT WAS FAIR -- TAGGED BOTTOM AT 7380' 06/26/04 PERFORATED: 7258-7266 + 7270-7286 + 7292-7310,6 SPF POWERJET -- MEAS SBHP AT 7280'= 2575.0 PSIA, TEMP= 146.7 DEGF AND AT 7145'= 2530.2 PSIA, TEMP= 139.8 DEGF [Perf, Pressure Data] .... ConocJ'Phillips ConocoPhillips Alai, Inc.,slot #306 Pad 2N, Tarn ,North Slope, Alaska ;if)~. - tJ(p 2- well.: 306 Wellpath: GSS<0-542'>MWDw/Sag<676-7605'> Date Printed: 21-Jun-2004 rli. 8AlŒR HUGHES INTEQ Field Name Tarn 461651.5943 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic III 149.6ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 53.64 degrees Bottom hole distance is 4649.45 Feet on azimuth 53.60 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~~¡\~ 11~-\ \\~\ ~ ~SJ~ Conoc6Phillips ConocoPhillips Alai, Inc.,slot #306 Pad 2N, Tarn ,North Slope, Alaska well.: 306 Wellpath: GSS<0-S42'>MWDw/Sag<676-760S'> Date Printed: 21-Jun-2004 Jli. 8fIII.s INTEQ WellDath lGrid) ReDort MD[ft] Inc[deg] Azi[deg] TVD[ft] Station Station Dogleg Severit) Vertical Easting Northing PositionlY) PositionlX) Sectionrftl 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 461049.37 5911997.31 139.00 0.00 0.00 i 139.00 O.OON O.OOE 0.00 0.00 461049.37 5911997.31 171.00 0.70 118.00 171.00 0.09S 0.17E 2.19 0.08 461049.54 5911997.22 264.00 0.75 105.00 263.99 0.52S 1.26E 0.18 0.71 461050.63 5911996.79 356.00 1.00 60.00 355.98 0.27S 2.54E 0.77 ! 1.88 461051.91 5911997.03 i 450.00 2.60 23.00 449.94 2.10N 4.08E 2.02 I 4.53 461053.46 5911999.39 I I 542.00 I 3.80 12.00 541.79 I 7.01N 5.53E 1.46 8.61 461054.94 5912004.29 676.52 4.71 15.24 675.94 16.70N 7.91E 0.70 16.27 461057.37 5912013.96 769.41 7.25 14.62 768.32 26.05N 10.39E 2.74 23.81 461059.90 5912023.30 862.10 7.89 14.72 860.20 37.86N 13.49E 0.69 33.31 461063.05 ! 5912035.10 954.17 8.93 16.53 951.28 50.82N 17.12E 1.17 43.92 461066.75 5912048.04 I 1053.15 11.06 21.67 1048.75 67.01N 22.82E 2.33 58.10 461072.53 5912064.20 I 1148.44 12.88 27.01 1141.97 84.97N 31.02E 2.23 I 75.35 461080.82 5912082.11 1243.18 18.25 33.13 1233.21 106.82N 43.93E 5.92 98.70 461093.84 5912103.89 1336.71 21.46 32.70 1321.16 133.49N 61.18E 3.44 128.41 461111.23 5912130.47 1432.35 24.76 37.63 1409.13 164.08N 82.87E 4.00 164.01 461133.07 5912160.95 1527.77 29.82 42.56 1493.91 I 197.41N 111.14E 5.80 206.54 461161.51 5912194.12 1622.90 33.28 42.28 1574.96 234.15N 144.71E 3.64 255.35 461195.26 5912230.69 1718.18 33.84 41.50 1654.36 273.36N 179.87E 0.74 306.92 461230.63 5912269.72 1812..18 34.44 45.11 1732.17 311.73N 216.05E 2.25 358.80 461267.00 5912307.89 1905.35 36.70 48.98 1807.96 348.61 N 255.73E 3.42 412.61 461306.86 5912344.56 2000.56 39.47 47.83 1882.89 387.60N 299.63E 3.00 471.09 461350.96 5912383.32 2094.56 41.97 49.11 1954.13 428.24N 345.54E 2.80 532.15 461397.08 5912423.72 2189.49 45.35 51.19 2022.80 470.20N 395.87E 3.87 597.56 461447.61 5912465.42 2283.30 46.38 50.21 2088.13 512.84N 447.96E 1.33 664.79 461499.92 5912507.79 2378.08 45.93 53.15 2153.79 555.22N 501.58E 2.29 733.09 461553.75 5912549.89 2472.77 45.96 56.19 2219.64 I 594.57N 557.09E 2.31 801.12 461609.45 5912588.94 2567.82 46.57 54.90 2285.35 633.42N 613.71E 1.17 869.76 461666.27 5912627.50 2662.80 47.12 55.18 2350.32 673.13N 670.50E 0.62 939.02 461723.25 5912666.91 2736.13 47.64 55.36 2399.97 703.87N 714.84E 0.73 992.96 461767.75 5912697.42 2834.00 48.40 56.04 I 2465.43 744.86N 774.95E 0.93 1065.67 461828.06 5912738.10 2926.84 50.23 55.78 2525.95 784.32N 833.25E 1.98 1136.01 461886.56 5912777.26 3020.75 51.91 55.67 2584.96 825.46N 893.61E 1.79 I 1209.01 461947.13 5912818.08 3116.17 52.43 56.39 2643.48 867.57N 956.11E 0.81 1284.31 462009.84 5912859.86 3210.67 51.59 56.18 2701.65 908.91N 1018.07E 0.91 1358.71 462072.00 5912900.88 3305.79 50.09 55.45 2761.72 950.35N 1079.08E 1.69 1432.41 462133.22 5912941.99 3400.10 47.98 55.48 2823.54 990.72N 1137.74E 2.24 1503.58 462192.08 5912982.06 3493.72 48.62 54.91 2885.82 1030.61N 1195.13E 0.82 1573.46 462249.67 5913021.66 3589.61 49.22 56.22 2948.83 I 1071.48N 1254.75E 1.20 1645.69 462309.49 5913062.21 I 3684.99 48.13 58.02 3011.82 1110.37N 1314.89E 1.82 1717.18 462369.82 5913100.79 3778.94 48.80 58.03 3074.11 1147.61N 1374.55E 0.71 1787.30 462429.67 5913137.72 I 3873.43 48.14 58.42 3136.76 1184.86N 1434.68E 0.76 1857.81 462489.98 5913174.65 3968.31 47.70 57.85 I 3200.35 1222.04N 1494.49E 0.64 1928.02 462549.98 5913211.52 4062.86 48.20 57.70 3263.67 1259.48N 1553.88E 0.54 1998.04 462609.56 5913248.65 4157.55 49.03 58.47 3326.27 1297.03N 1614.19E 1.07 2068.87 462670.05 5913285.89 4252.01 49.33 58.32 3388.02 1334.49N 1675.07E 0.34 2140.11 462731.11 5913323.03 4346.83 48.03 56.10 3450.63 1373.04N 1734.93E 2.23 2211.17 462791.17 5913361.27 4440.67 46.64 55.05 3514.23 1412.04N 1791.85E I 1.69 I 2280.13 462848.29 5913399.97 I 4536.38 47.87 56.21 3579.19 1451.72N 1849.87E 1.56 2350.37 462906.50 5913439.34 4631.27 48.17 55.79 3642.66 1491.16N 1908.35E i 0.46 2420.85 462965.18 5913478.48 4725.74 47.83 56.77 3705.87 i 1530.14N 1966.74E I 0.85 2490.98 463023.76 5913517.15 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic III 149.6ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 53.64 degrees Bottom hole distance is 4649.45 Feet on azimuth 53.60 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated eonocJPmllips ConocoPhillips AlaI. Inc.,slot #306 Pad 2N, Tarn ,North Slope, Alaska well.: 306 Wellpath: GSS<0-542'>MWDw/Sag<676-760S'> Date Printed: 21-Jun-2004 .i. ___cI.s INTEQ Well[)ath (Grid} Report MD[ft] Inc{deg] Azi[deg] TVD[ft] Station Station Dogleg Sevent) Vertical Easting Northing Position(Y) PositiOn(Xl Sectionlft1 4820.62 46.92 55.12 3770.13 1569.22N 2024.58E 1.60 2560.73 463081.79 i 5913555.93 4916.16 48.39 54.52 3834.48 1609.91N 2082.29E 1.61 2631.33 463139.71 5913596.32 5009.85 47.96 54.91 3896.96 1650.24N 2139.28E 0.55 2701.13 463196.90 5913636.35 5104.59 48.68 53.52 3959.96 I 1691.61 N 2196.68E 1.33 2771.88 463254.50 5913677.43 5197.98 49.57 55.24 4021.07 1732.73N 2254.08E 1.69 I 2842.49 463312.11 5913718.24 5292.56 50.51 56.18 4081.82 1773.57N 2313.97E 1.25 2914.93 463372.21 5913758.77 2989.11 463433.52 , 5913800.56 5388.78 50.43 54.68 4143.06 1815.68N 2375.08E 1.21 i 5483.18 50.06 55.97 4203.43 1856.96N 2434.76E 1.12 3061.65 463493.41 5913841.53 5577. 79 47.57 58.10 I 4265.73 1895.72N 2494.47E 3.13 3132.71 463553.32 5913879.98 5672.73 48.02 57.71 4329.51 1933.09N 2554.05E 0.56 3202.84 463613.08 5913917.04 5767.00 48.87 54.13 4392.06 1972.62N 2612.45E 2.98 3273.31 463671.68 5913956.26 5861.53 I 47.13 53.48 4455.31 2014.10N 2669.15E 1.91 3343.56 463728.58 5913997.44 5955.87 46.54 53.67 4519.85 2054.95N 2724.51E 0.64 3412.37 463784.15 5914038.01 6051.42 48.14 55.31 4584.60 2095.75N 2781.71E 2.10 3482.62 463841.55 5914078.51 6145.61 47.57 52.11 4647.81 2137.07N 2837.99E 2.59 I 3552.44 463898.04 I 5914119.53 6240.51 48.59 53.07 4711.21 2179.96N 2894.08E 1.31 3623.03 463954.34 5914162.13 6334.30 48.88 55.24 4773.07 2221.24N 2951.23E 1.77 3693.52 464011.69 5914203.11 6429.29 48.14 54.69 4836.00 2262.09N 3009.49E 0.89 3764.66 464070.16 5914243.65 6523.79 48.77 55.99 4898.67 2302.30N 3067.66E 1.23 3835.35 464128.53 5914283.57 6618.39 49.32 56.63 4960.68 2341.93N 3127.11E 0.77 3906.72 464188.18 5914322.88 6710.32 48.93 54.70 5020.85 2381.13N 3184.51E 1.64 3976.18 464245.77 5914361.78 6808.09 49.32 54.82 5084.83 2423.79N 3244.89E I 0.41 4050.09 464306.36 5914404.12 6902.63 48.59 54.62 5146.91 2464.97N 3303.09E 0.79 4121.38 464364.77 5914445.00 6998.10 46.24 57.84 5211.51 I 2504.06N 3361.48E 3.50 4191.58 464423.36 5914483.79 7092.49 47.16 55.68 5276.25 2541.72N 3418.93E 1.93 4260.16 464480.99 5914521.14 7186.79 47.72 55.01 5340.03 2581.22N 3476.06E 0.79 4329.59 464538.32 5914560.34 7281.71 48.34 57.70 5403.52 2620.30N 3534.80E 2.21 4400.07 464597.26 5914599.12 7376.11 49.80 55.71 5465.36 2659.46N 3594.40E 2.22 4471.28 464657.05 5914637.97 7470.43 51.36 57.35 5525.26 2699.63N 3655.18E 2.13 4544.04 464718.03 5914677.82 7521.28 51.67 55.20 5556.90 2721.73N 3688.29E 3.37 4583.80 464751.24 5914699.75 7605.00 51.67 55.20 5608.82 2759.21N 3742.21E 0.00 4649.45 464805.36 5914736.95 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic III 149.6ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 53.64 degrees Bottom hole distance is 4649.45 Feet on azimuth 53.60 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocJfhillips ConocoPhillips Ala! Inc.,slot #306 Pad 2N, Tarn ,North Slope, Alaska Well a: 306 Wellpath: GSS<0-542'>MWDw/Sag<676-760S'> Date Printed: 21-Jun-2004 .i. 'WJI. INTEQ Hole Sections Diameter Start In MD ft 97/8 139.00 6 3/4 2803.00 Wellbore 306 306 .CåsinQs .. . Name Top Top Top Top Shoê S/)pe Shoe Shoe Wellbore MDfftl TVDfftl . Northfftl Eastfftt MDfftl . T\lDfftl Northfftl Eastlftl 16" Conductor 0.00 0.00 O.OON O.OOE 139.00 139.00 O.OON O.OOE 306 7 5/8" Casino 0.00 0.00 O.OON O.OOE 2793.00 2438.13 727.72N 749.62E 306 51/2" x 31/2" XO 0.00 0.00 O.OON O.OOE 6964.00 5188.11 2490.64N 3340.63E 306 31/2" Casino 6964.00 5188.11 2490.64N 3340.63E 7595.00 5602.62 2754.73N 3735.77E 306 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic III 149.6ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 53.64 degrees Bottom hole distance is 4649.45 Feet on azimuth 53.60 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk 2N-306 ConocoPhillips Alaska, Inc. Permit No: 204-062 Surface Location: 9' FNL, 544' FEL, SEC. 3, T9N, R7E, UM Bottomhole Location: 2516' FNL, 2024' FEL, SEC. 35, TlON, R7E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you ITom obtaining additional permits or approvals 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector 59-3607 (pager). BY ORDER OF THE COMMISSION DATED this3/'day of April, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation w/o encl. ConocJP'hillips e Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com April 14, 2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill Tarn injector 2N-306 and Tarn producer 2N-311 Dear Sir / Madam I ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill onshore injection well 2N-306 and production well 2N-311 in the Bermuda sands of the Tarn oil pool. Please find attached for the review of the Commission Form 10-401 and the information required by 20 ACC 25.005 for this well. The planned spud date for 2N-306 is 04/27/2004 and for 2N-311 is 05/11/2004. If you have any questions or require any further information, please contact Philip Hayden at 265-6481. Sincerely, ~~ Randy Thomas Greater Kuparuk Area Drilling Team Leader RECEIVED APR 1 4 2004 Alaska Oil & Gas Cons Carom' . . ISSlOn Anchorage ORfGINAiL STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL - 1a. Type of Work: Drill 0 Re-entry 0 1 b. Current Well Class: Stratigraphic Test 0 RedrillU 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 9' FNL, 544' FEL, Sec. 3, T9N, R7E, UM ¡/ Top of Productive Horizon: 2570' FSL, 2314' FEL, Sec. 35, T10N, R7E, UM Total Depth: ./ 2516' FNL, 2024' FEL, Sec. 35, T10N, R7E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 461049./ y- /' Zone- 5911997 16. Deviated wells: Kickoff depth: 400 18. Casing Program Size ,/ ft. Maximum Hole Angle: 48.81° Specifications Weight Grade Coupling Length 62.5# H-40 Weld 120 29.7# L-80 BTC 2731 15.5# L-80 BTCM 6988 9.3# L-80 EUE8RD 664 Hole 42" Casing 16" 97/8" 63/4" 63/4" 7 5/8" 5.5" 3.5" 19 Total Depth MD (It): PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) Casing Structural Conductor Detailed Operations Intermediate Production Liner Perforation Depth MD (ft): Length Size 20. Attachments: Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling Program0 Seabed Report 0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature R. Thomas ~~~ e Á 1\\ RE.CE:.í'V ¿D APR 1 4 2004 ExploratoryU Development OilD MultiPle,;lone 0 Service 0 D~..r,aeGib&~s Cons. CO~~~I~bne0 5. Bond: ~ Blanket U Single Well An~rq& and Number: Bond No. 59-52-180 2N-306 6. Propos;d Depth: I 12. Field/Pool(s): MD: 7682' TVD: 5655' Kuparuk River Field 20 AAC 25.005 7. Property D;signation~. .I ADL 375074/380054/380053 8. Land Use Permit: Tarn Oil Pool 13. Approximate Spud Date: 4/27/2004 L31961/32027/32026 9. Acres in Property: ;' 2560 14. Distance to Nearest Property: 9' @ Surface 10. KB Elevation 15. Distance to Nearest 4 Ii 150' AMSL feet Well within Pool: 2N-304 , 1348 17. Anticipated Pressure (see 20 AAC 25.035) ./ Max. Downhole Pressure: 2700 psig / Max. Surface Pressure: 2212 psig Setting Depth Quantity of Cement Bottom c. f. or sacks TVD (including stage data) 150' Artie Set I 2415 204 sx ASL & 199 sx LiteCRETE 5218 243 sx GasBLOK 5655 Included above Top MD 30.3' 30.3' 30.3' 7018 TVD 30.3' 30.3' 30.3' 5218 MD 150' 2761 7018 7682 (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Cement Volume MD rvD Perforation Depth TVD (ft): Timev. Depth Plot 0 Drilling Fluid Program 0 Date: Shallow Hazard Analysis Q 20 AAC 25.050 requirements 0 Contact Philip Hayden 265-6481 Title Kuparuk Drilling Team Leader Phone Us- -6ó)ö Date i'lft.{fo'f p .. n Commission Use Only Permit to Drill .. / '_ I API Number: I ~ Permit AP~rorl / Number: 2D-r--L)6Z-1 50-/()~ -267/U"C() Date: 1/-'/;:;-/ ¿)(/ Conditions of approval: Samples required Q<es g-NO Mud log require£¡ I Hydrogen sulfide measures )Al Yes 0 No Directional survey required See cover letter for other requirements Wes g No ~ Yes -eJ No Othsc \,\-51' fí/;t" \-'\,Y <\. (,\'"1 \,~. ~C\>.;. ov.:¡ ,,\ "''' '"'- \')Ö I? ~,.\,. ~ ,{ I J:1~ BY ORDER OF I.. ~/L~ Approved b)!of-- /\V I'¡ If ~I.A./ COMMISSION!;R THE COMMISSION Date: 'r 'Zf 4'(" L/ V .. '---""" UUlr":l NI ^L / f f Form 10-401 Revised 3/2003 . I \ U ' n Submit in duplicate e Ap.ion for Permit to Drill, Well 2N-306 _ Revision No.O Saved: 14-Apr-04 Permit It - Tarn Well #2N-306 Application for Permit to Drill Document Moximize We-II I/alue Table of Contents 1. Well Name... ...... ........... ..... ......... ... .... ..... ......... ...... ........................ ..... ...... ...... ..... ...... 2 Requirements of 20 AAC 25.005 (f)............................. ............ ..................... ....................... ...................2 2. Location Sum mary .... ... ........... ... ...... ......... ....... .......... ....... .... ......... ...... ...... ..... ...... ... 2 Requirements of 20 AAC 25.005(c)(2) ...................................................................................................2 Requirements of 20 AAC 25. 050(b ).......... ................................... ... ........................................ ..... ........... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ...................................................................................................3 4. Dri II i ng Hazards Information ... .......... ..... .......... ........ .............. ........ ...... .......... ......... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing .Program............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ...................................................................................................4 7. Diverter System Information ...................................................................................4 Requirements of 20 AAC 25.005(c)(7) .......... ..... ......................... ....... .............. .......... ........................ ....4 8. Dri II i ng FI uid Prog ram ............. ............ ........... ................ ..... ......... ...... ....... ..... ......... 4 Requirements of 20 AAC 25.005(c)(B) ........ ....................... ..................... ................... ...................... ...... 4 Surface Hole Mud Program (extended bentonite) .................................................................................. 4 Production Hole Mud Program (LSND) ..................................................................................................5 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis... ....... ..... ................................. .......................... ..... ....... ..... ........... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ...............................................................................................5 2N-306 PERMIT IT. doc Page 1 of 7 Printed: 14-Apr-04 ORIGINAL e AP.tion for Permit to Drill, Well 2N-306 Revision No.O Saved: 14-Apr-04 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................6 15. Attachments ...... ......... ...... .................... ............ ..... ....... ........ ............. .... ........ .... ....... 7 Attachment 1 Directional Plan (18 pages) .............................................................................................. 7 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................. 7 Attachment 3 Cement Loads and CemCADE Summary (2 page) ......................................................... 7 Attachment 4 Well Schematics (1 page) ................................................................................................ 7 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25.040{b). For a well with multiple well branche!>~ each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 2N-306. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a PermIt to Drill must be accompanied by each of the following itemSr except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the propertys owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation; and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface I NGS Coordinates Northings: 5,911,997 Eastings: 461,049 ,¡-' 9' FNL 544' FEL Section 3, T9N, R7E, UM - I RKB Elevation I 150' AMSL I Pad Elevation I 120' AMSL Location at Top of Productive Interval Bermuda Sand NGS Coordinates Northings: 5,914,560 2570' FSL, 2314' FEL, Section 35, nON, R7E, UM 7218 Eastings: 464,568 5350 5200 Location at Total De NGS Coordinates Northings: 5,914,752 2516' FNL 2024' FEL Section 35 nON Measured De th RKB: Eastings: 464,859 Total Vertical De th RKB: Total Vertical De th 55: R7E UM 7682 5655 5505 and ORIGINAL 2N-306 PERMIT IT.doc Page 2 of 7 Printed: 14-Apr-04 e AP.ion for Permit to Drill, Well 2N-306 Revision No.O Saved: 14-Apr-Q4 (D) other information required by 20 MC 25.050(b),· Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviateeí the application for a Permit to Drill (Form 10-401) must (1) include a plat drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well/ Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those well~ to the extent that those names are known or discoverable in public record~ and show that each named operator has been furnished a copy of the application by certified mai¿· or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to 01711 must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (3) a diagram and description ofthe blowout prevention equipment (BOPE) as required by 20 MC 25.03~ 20 MC 25.036, or 20 MC 25.03~ as applicable/ An API 11" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 2N-306. Please see information on the Nordic Rig 3 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (4) information on drilling hazard~ including (A) the maximum downhole pressure that may be encountered, CrIteria us-ed to determine it and maximum potential surface pressure based on a methane gradient· The expected reservoir pressures in the Bermuda sands in the 2N-306 area vary from 0.35 to 0.51 psijft, .j or 6.8 to 9.7 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from existing wells on the field together with reservoir model forecasts. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the Bermuda sand formation is 2212 psi, calculated as follows: MPSP =(5530 ft)(O.51 - 0.11 psijft) =2212 psi / (B) data on potential gas zones/ No potential gas zones are expected. and (C) data concerning potential causes of hole problems SUcll as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking/ Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 MC 25.005 (c)(5) An applicatIon for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity test~ as required under 20 MC 25.030(f),- ORIGINAL 2N-306 PERMIT IT. doc Page 3 of 7 Printed: 14-Apr-04 e AP.ion for Permit to Drill, Well 2N-306 Revision No.O Saved: 14-Apr-04 2N-306 will be completed with 7 5/8" surface casing landed above the C-80 mudstone interval. The casing shoe will be drilled out and a leak off test will be performed in accordance with the "Leak Off Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25. 03~ and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program I See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (fb/ft) Grade Connection (ft) (ft) (ft) Cement Proaram 16 42 62.5 H-40 Welded 120 30.3 I 30.3 150 I 150 Cement to surface ArticSet I 7 5/8 97/8 29.7 L-80 BTC 2731 30.3 I 30.3 2761 I 2415 Cement to Surface with 204 sx ASLite Lead, 199 sx LiteCRETE Tail 51/2 81/2 15.5 L-80 BTCM 6988 30.3 I 30.3 7018 I 5218 Cement Top planned @ 31/2 8'/2 9.3 L-80 EUE8RD 664 7018 I 5218 7682 I 5655 6574' MDI Mod 4926'1VD. Cemented wI 243 sx GasBLOK 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applícation for a Permit to Drill must be accompanied by each of the following item~ except for an Item already on file with the commission and identified in the application: (7) a diagram and description of the dive/ter system as required by 20 MC 25.030 unless this requirement is waived by the commission under 20 AAC 25.035(II}(2); A 21 %", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 2N-306. Please see diagrams of the Nordic 3 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill ml/st be accompanied by each of the following item~ except for an item already on file with the commission and Identified in the application: (8) a drilling flUId program, including a diagram and description of the drilling fluid system, as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to 75/8" Casin Point Initial Value Final Value Initial Value Final Value Density (ppg) 8.6 <9.2 <9.2* 9.6 Funnel Viscosity 250 250 150-200 55-65 /" ORIGINAL 2N-306 PERMIT IT. doc Page 4 of 7 Printed: 14-Apr-04 e AP.ion for Permit to Drill, Well 2N-306 Revision No.O Saved: 14-Apr-04 (seconds) Yield Point 35-45 35-45 30-35 12-15 (eP) pH 9-9.5 9-9.5 9-9.5 9-9.5 API Filtrate 6 6 4-6 4-6 (ee /30 min)) Chlorides (mgll) <600 <600 <600 <600 *9.6 PPQ if hydrates are encountered Production Hole Mud Program (LSND) 75/8" Casin '1 Shoe to TD Initial Value Final Value Density (ppg) 9.8 9.8 Yield Point 22-28 10-15 (eP) pH 9-9.5 9-9.5 API Filtrate 4-6 4-5 (ee /30 min)) HTHP @ 1S{f (ee)) <12 <12 ,/ Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Nordic Rig 3. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file wIth the commission and identified in the application: (9) for an exploratory or stratigraphic test we/~ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(1O) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the applicatíon: (10) for an exploratOlY or stratigraphic test we/~ a seismic refraction or refiection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following Items, except for an Item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platfoml, mobile bottom-founded structure, jack-up rig, or fioatlìlg drilf¡ìlg vesse~ an analysis of seabed conditions as required by 20 MC 25. 061 (b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following Items, except for an item already on file with the commission and identified in the application: (12) evidence showlì/g that the requirements of 20 MC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. ORIGINAL 2N-306 PERMIT IT. doc Page 5 of 7 Printed: 14-Apr-04 e APWion for Permit to Drill, Well 2N-306 Revision No.O Saved: 14-Apr-Q4 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the fo/lowing items; except for an item already on file with the commission and Identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematics. 1. Move in / rig up Nordic Rig 3. Install 21 %" Annular with 16" diverter line and function test (conductor will have been installed and cemented). 2. Spud and directionally drill 9 7/8" hole to casing point at 2761' MD / 2415'1VD as per directional plan. Run MWD tools as required for directional monitoring. 3. Run and cement 7 5/8", 29.7# L-80, BTC casing to surface. Displace cement with mud. Perform top job if required. 4. Remove diverter system and install wellhead and test. Install and test 11" x 5,000 psi BOP's and test to 5000 psi (annular preventer to 3500 psi). Notify AOGCC 24 hrs before test. / 5. PU 6 314" bit and 4 3/4" drilling assembly, with MWD and LWD (GR, resistivity & neutron density). RIH, clean out cement to top of float equipment. Pressure test casing to 3500 psi for 30 minutes and record results. 6. Drill out cement and 20' of new hole. Perform LOT or FIT to 18.0 ppg EMW, recording results. 7. Directionally drill to 5 V2" X 3 V2" casing point at 7682' MD / 5655'1VD. 8. Run 5 V2", 15.5# L-80, BTC Mod x 3 V2", 9.3# L-80, EUE8RD Mod casing to TD. Pump cement and displace with water. 9. Make up completion string as required and RIH to depth. Locate seal bore extension, space out and land completion. Pressure test completion and production casing to 3500 psi for 30 minutes and record results. Shear RP shear valve in gas lift mandrel. 10. Install BPV, nipple down stack, nipple up and test tree to 5,000 psi. Pull BPV 11. Freeze protect well with diesel by pumping into the annulus, taking returns from tubing and allowing to equalize. Carry out LOT and injection test on the outer annulus. Sweep the annulus with water and freeze protect. 12. Set BPV and move rig off. 13. Rig up wire line unit. Pull BPV. Set dummy valve in place of RP shear valve in gas lift mandrel. Perform MIT pressure tests of tubing and annulus (Tubing and annulus to 3500 psi). Perforate well and rig down wire line unit. 14. Freeze protect well and turn well over to production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following Items; except for an Item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator Intends to request authorization under 20 MC 25.080 for an annular disposal operation in the we//./ Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids v into a permitted annulus on 2N Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 2N Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on the pad in accordance with a permit from the State of Alaska. ORIGINAL 2N-306 PERMIT IT. doc Page 6 of 7 Printed: 14-Apr-04 e AP.ion for Permit to Drill, Well 2N-306 Revision No.O Saved: 14-Apr-04 At the end of drilling operations, an application may be submitted to permit 2N-306 for annular disposal of fluids occurring as a result of future drilling operations on 2N pad. 15. Attachments Attachment 1 Directional Plan (18 pages) Attachment 2 Drilling Hazards Summary (1 page) Attachment 3 Cement Loads and CemCADE Summary (2 page) Attachment 4 Well Schematics (1 page) ORIGINAL 2N-306 PERMIT IT. doc Page 70(7 Printed: 14-Apr-04 e e .. BAKER - INTEQ ConocoPhillips Alaska, Inc. lot: slot #306 Well: 306 Wellbore: 306 Location: North Slope, Alaska Field: Tarn Conoc~illips Installation: Pad 2N Created by : Planner Date lotted: 31-Mar-2004 Plot reference is 306. Ref well path is 2N-306 Ver#1.B. Coordinates are in feet reference slot #306. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Planned Datum Rig Datum to mean sea level: 150.00 ft. Plot North is aligned to TRUE North. ./ ¢:' o o -400 C'\I II E o WELL PROFILE DATA ./ Point MD Inc Azi TVD North 0.00 0.00 0.00 0.00 0.00 400.00 0.00 0.00 400.00 0.00 900.00 10.00 15.00 897.47 42.04 East deg/100ft V. Sect 0 Estimated RKB: 150' (]) ro 0 (f) 400 KOP 4.00 800 8.00 BldfTrn 3/100 15.94 1200 Base Permafrost Top West Sak 25.60 1600 30.49 - DLS: 3.00 deg/100ft - Base West Sak () () 2000 43.85 - EOC - .r: ã. 2400 () C CO 2800 (,) :e () > 3200 () j ... ~ 3600 . V 4000 4400 4800 5200 5600 6000 Tie on 0.00 0.00 0.00 0.00 0.00 2.00 33.99 3.00 104.76 3.00 715.27 0.00 4353.46 0.00 4701.76 End of Hold 0.00 End of BuildfTurn 11.26 KOP 1235.81 20.00 20.00 1221.43 124.38 38.52 End of BuildITurn 2378.50 48.81 56.29 2162.83 559.69 476.16 Target 2N-306 Top Berm 7218.21 48.81 56.29 5350.00 2580.97 3505.87 TD.&EndofHold 7681.54 48.81 56.29 5655.12 2774.48 3795.92 5 1/2in Casing ~~ T3 (Top Bermuda Target) 2N-306 Top Bermuda Tgt 17 Feb 04 ,~,.}h5 (K3) 3 1/2in Casing I> TO -400 -0 400 Scale 1 em = 200 ft 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 Vertical Section (feet) -> Azimuth 53.64 with reference 0.00 N, 0.00 E from slot #306 5200 4400 4000 3600 3200 2800 ^ 2400 I - - ~ 2000 - - J: ~ 1600 Z 1200 800 400 "" 0 0 N II 0 E () Q) -400 ro () (/) iii. IIIAKIR HUGIIES ¡N'TF:,Q~~- SURFACE LOCATION: 9' FNL, 544' FEL SEC, 3, T9N, R7E e e ConocoPhillips Alaska, Inc. lot: Well: Wellbore: slot #306 306 306 Conoc~illips Location: North Slope, Alaska Field: Tarn Installation: Pad 2N Created by: Planner Date lotted: 31-Mar~2004 Plot reference is 306. Ref wellpath is 2N-306 Ver#1.B. Coordinates are in feet reference slot #306. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Planned Datum Rig Datum to mean sea level: 150.00 ft, /' Plot North is aligned to TRUE North. or TO LOCATION: 2516' FNL, 2024' FEL ,,/ SEC. 35, T10N, R7E TARGET LOCATION: 2570' FSL, 2314' FEL SEC, 35, T10N, R7E ~ lÌ~ ~ -Ò ~%i1Q ~. /4. ~5?" f?-<;ò ~.~ ~6'~ ~ , -i-" ~-Iö' , / C80 (K10) ~ 7 5/8in Casing ~oc -400 0 400 Scale 1 em = 200 ft °0 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 East (feet) -> ConoeoPhiHips Alaska, Ine.. North Slope, Alaska Field: Tarn Installation: Pad 2N slot #306 Well: 306 Wellbore: 306 Canoe illips TRUE NORTH 10 2100 20 330 30 320 40 310 50 60 70 80 90 100 110 240 120 1300 230 130 "00 220 140 210 1700 150 200 160 1000 190 180 170 "17ûú 1700 f!!3 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ConocoPhillips Alaska, Inc. Location: North Slope, Alaska lot: slot #306 ï-~i:jÚ)~ Field: Tarn Well: 306 Installation: Pad 2N Wellbore: 306 Scaie 1 em = 5 ft East ~eet) -> -70 60 -50 -40 -30 -20 -10 o 0 20 30 40 50 60 70 80 90 180 fJ 180 I I I 170 I 170 I I I I 160 1100 I 160 I I I 150 150 140 140 130 I 130 I I I 120 , 120 I 1000 1JO I 110 I 110 I I I 1100 I 100 I 100 I ^ I I ^ . 1300/ . - .... 90 I 90 (,) (,) 1400 I - T --- I .c: 80 I 800 .... I 80 .... 900 I 0 I Z I I 70 I 70 I 6 I 60 200 $1000 I 60 I I I I 50 800 I 50 I 900 I I 1200 I 40 I 40 1100 I I 600 I I 30 I 30 I 800 t I 20 6 I 500 20 6 I 700 10 I 10 ~ 6 (J) '+- l{) I 600 400 (') t Q) II I 300 (¡) E 0 ø 500 0 300 ü (') :3 <D -10 ~ <D -10 ü (J) ;::Þ T- -70 -60 -50 -40 -30 -20 -10 0 10 20 30 40 50 60 70 80 90 SealG 1 em = 5 ft East (feet) ~> i} 320 - ..... (!) ~300 J:: ..... ... o 280 z ~ 4- o : 140 E ü ~ 120 () ro ü (f) 1 00 ConocoPhillips Alaska, Inc. location: North Slope, Alaska lot: slot #306 Field: Tarn Well: 306 Installation: Pad 2N Well bore: 306 -> 100 120 140 200 220 240 260 280 300 320 340 500 480 1800~ 460 , , , , 440 , , , , 420 400 380 360 340 320 ^ . Z 0 300 ;t ::r - - ø 280A 260 240 220 !NTE() 480 Scale 1 em = 10 ft 20 40 60 80 500 __,L 460 440 420 , , , 190~'" , , , , , , , , , , , , , , , , / 1800 , , , , , , ... , , , , " " " / 1700 , .. " .. .. , 1500 400 380 360 340 1400 260 .. .. .. , /1 .. .. .. .. .. , , , 1600 " , / 1500 , .. , , .. .. .. I .. / 1400 I ¡I¡ 00 I .. I I I I 1300 240 220 200 180 160 20 40 60 80 100 120 140 Scale 1 em = 10 ft 160 180 200 220 240 260 280 East (feet) -> 300 200 180 160 (f) () OJ 140 ro () :3 120 II 320 o 100 ;:::þ 340 ConocoPhillips Alaska, Inc. ocatlon: North Siope, Alaska Ot: siot #306 ·".w?' Field: Tarn Well: 306 ConocoPhiUips . _~__~·,____~,...M__ Installation: Pad 2N Wellbore: 306 INHQ Scale -1 ern = 100 ft East (feet) -> 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 3200 3200 3000 3000 30£200 2800 e 2800 ./ 5600 , " 2600 2~0 ..' 5400 2600 " " 5200 2400 2400 2200 tJ 2200 ^ 2000 4400/. 2000 ^ . " , - 4200 ",,' Z .... Q> 1800 ,,' 1800 g. .! - 4000 ",' ::r .r::. " - " - 1:::: 1600 3800 ¿¡I,.' 1600 ~ 0 " z - 360~" - 1400 " 1400 3400 ",,,,' '" ",,' 1200 3200"," 1200 ,.... 3000...."" 1000 .. ",' 1000 '" ",,,,'" 2800 " 800 ,.. 2600 800 " ¢: '" (f) 0 .",'" 2400 () 0 OJ ~ ,'" ëD II 600 " 600 E ,.. 2200 () 0 ,'" 3 '" 2000 II ill 400 400 ãj 0 0 0 (f) ;;:P 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 Seale 1 em = 100 ft East (feet) -> e Conoc6'Phillips ConocoPhillips Alaska, Inc.,slot #306 Pad 2N, Tarn ,North Slope, Alaska e PROPOSAL LISTING Page 1 Wellbore: 306 Wellpath: 2N-306 Ver#1.B Date Printed: 1-Apr-2004 R¡. BAKER HUGHES INTEQ N 306 r 10-Mar-2004 IWell ~~~ I Government 10 I ~~~~:~~i~~~ in m AK-4 on NORTH AMERICAN DATUM 1927 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 53.64 degrees Bottom hole distance is 4701.78 Feet on azimuth 53.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL e ConocJ'Phillips ConocoPhillips Alaska, Inc.,slot #306 Pad 2N, Tarn ,North Slope, Alaska e PROPOSAL LISTING Page 2 Wellbore: 306 Wellpath: 2N-306 Ver#1.B Date Printed: 1-Apr-2004 .i. BAKER HUGHES INTEQ Wellpath {Grid & LatlLon~I)Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Northing Easting Latitude Longitude Vertical Sectionfftl 000 000 000 000 591199736 N70 10 n RROO W1"O 1R ,1e <;'>.A<; 000 10000 0.00 0.00 100.00 "011 007.~R 4R1040.24 N70 10 13.8R90 W1<;0 18 48.<;34<; 0.00 200.00 0.00 0.00 200.00 5911997.36 461049.24 N70 10 13.8690 W150 18 48.5345 0.00 ~oooo 0.00 000 300.00 5911997.36 461049.24 N70 10 13.8R90 W1<;O 1 8 48.<;~4<; 000 40000 000 000 40000 <;911997 ~R N70 10 13 8R90 W1<;0 18 4R "'>.4<; 000 500.00 2.00 15.00 499.98 5911999.04 461049.70 N70 10 13.8856 W150 18 48.5214 1.36 600.00 4.00 1 <;.00 <;99.R4 <;91 ?004 00 4R10<;1.08 N70 1 0 13.9~<;3 W1<;O 18 484822 <;45 700.00 6.00 15.00 699.45 591 :::>012.<;0 4610<;3.38 N70 10 14.0181 W150 18 48.4168 12.26 800.00 8.00 15.00 798.70 5912024.25 461056.60 N70 10 14.1339 W150 18 48.3254 21.78 900.00 10.00 15.00 897.47 <;91::>03934 4610RO.72 N70 10 14.2825 W150 18 48.2081 33.99 1000.00 12.07 17.28 99545 5912058.41 461066.40 N70 10 14.4704 W1"O 18 4804R" 49.81 1100.00 15.94 18.72 1092.28 5912082.10 461074.26 N70 10 14.7037 W150 18 47.8222 70.12 1 ?OO 00 18.93 1971 1187 R7 <;91:::>1103::\ 4R10R4 ?Q N70 10 149819 W150 1R 47 "'>."0 Q4 84 1 :::>::\<;.81 20.nO ?n.oo 1221.43 "01 ?1?1 ,,~ 4R108R.4n N70 10 1<;.00:::>::\ W1<;O 18 47418<; 104 7R 1300.00 21.23 24.21 1281.52 5912142.40 461097.03 N70 10 15.2980 W150 18 47.1716 124.02 14no.nn ?::\.3~ 29.87 1374.06 5912176.00 461114.49 N70 10 1".R?94 W1<;n 18 4R R707 1 <;7.9? 1 <;0000 ?<; RO 34 R? 14R<; 08 <;Q1 ??1 (\ R,1 4R11~R 81 N70 10 1<;9731 W1<;0 18 41': n?Q? 19R48 1600.00 28.00 38.62 1554.34 5912246.82 461163.92 N70 10 16.3284 W150 18 45.2491 239.58 170000 :'\0.49 4?03 1R41.RO <;91 ??8~.84 4R119".7<; N70 10 1R R942 W1<;0 18 44.3323 ?87.11 1800.00 33.07 44.9R 17?R.RO <;91 :::>::\?1.81 4R1232.?1 N70 10 17.0R95 W150 18 43.2815 338.94 1900.00 35.70 47.51 1809.13 5912360.62 461273.21 N70 10 17.4533 W150 18 42.0995 394.93 2000.00 38.:'\8 49.7<; 1888 9<; <;912400.1 R 4R1318.R2 N70 10 17.8445 W150 18 40.7894 454.92 ?100.00 41.10 51.73 1965.84 5912440.32 4 N70 10 18.2420 W150 1 8 ~9.~""1 <;187R 2200.00 43.85 53.52 2039.60 5912481.00 461422.20 N70 10 18.6448 W150 18 37.8002 586.26 ?300 00 46.62 55.13 2110.02 5912522.08 4R148008 N70 10 19.0518 W150 18 36.1292 R"7.24 :::>::\78 <;0 48..8.1 <;R.29 2162.83 5912554.54 461528.23 N70 1 0 19.37~4 W1<;O 18 ~4.7390 71 <;.27 2400.00 48.81 56.29 2176.99 5912563.45 461541.73 N70 10 19.4617 W150 18 34.3490 731.43 ?<;Oo 00 48. 8.1 "R ?9 2242.84 "91?R04 RR ,1"'1"'''. <;,1 N70 10 10 R7?" W150 18 '>') <;'>.<;') 80R R1 ?ROO 00 48. 8.1 <;R ?9 ?~O8. 70 e"."C>AC> ~? .~ N70 10 ?O ?8.~? W1<;O 18 '>.(\ 7?14 88178 2700.00 48.81 56.29 2374.55 5912687.76 461730.16 N70 10 20.6939 W150 18 28.9076 956.95 ?800.00 48.8.1 <;R.20 2440.41 5912729.20 461792.97 N70 10 21.104R W1<;O 18 27.0937 103?13 2900.00 48.8.1 <;R.29 2<;OR.?R <;012770.R~ 4R18<;".78 N70 10 21.<;1<;3 W1<;0 18 ?<;.2798 1107.30 3000.00 48.81 56.29 2572.12 5912812.07 461918.59 N70 10 21.9260 W150 18 23.4659 1182.47 3100.00 48.8.1 <;R.29 2R37.97 <;9128<;3.<;1 4R198.1.39 N70 10 22.33RR W1<;0 18 21R<;20 12<;7.R<; 3200.00 48.81 5R.29 2703.83 <;912894.9<; 4R2044.?0 N70 10 227473 W150 18 19.8381 1332.82 3300.00 48.81 56.29 2769.68 5912936.38 462107.01 N70 10 23.1580 W150 18 18.0241 1407.99 3400.00 48.81 5R.29 283<;.<;3 <;912977.82 4R21R9.82 N70 10 23.<;R87 W150 18 1R.2101 1483.17 3<;00.00 48..8.1 56.29 2901.39 5913019.2R 462232.63 N70 10 23.9793 W150 18 14.~OR1 1""8.34 3600.00 48.81 56.29 2967.24 5913060.70 462295.44 N70 10 24.3900 W150 18 12.5821 1633.52 370000 48.81 5R29 3033 10 ~".~.,"" 14 N70 10 '). 0""'" W150 18 107RR1 1708.69 3800.00 48.8.1 <;R.29 3098.95 5913143.57 462421 .06 N70 10 25.2113 W1"o 18. 8 9!')40 178.3.8R 3900.00 48.81 56.29 3164.81 5913185.01 462483.87 N70 10 25.6219 W150 18 7.1399 1859.04 4000.00 48.81 56.29 3230.R6 591 ::\22R.4<; 4R2!'i4R.R7 N70 10 26.0326 W150 18 5.3258 1934.21 410000 48. 8.1 <;R ?9 ~?OR ,,? "'". ""C>7 00 N70 10 ?R 44~? W1"O 18. ::\<;117 ?009 ::\8. 4200.00 48.81 56.29 3362.37 5913309.32 462672 .29 N70 10 26.8538 W150 18 1.6976 2084.56 4300.00 48..8.1 56.29 3428.23 5913350.76 462735.10 N70 10 27.2645 W1"O 17 "9 8.8.~4 21<;9.7::\ 4400.00 48.81 <;R.29 3494.08 <;913::\92 20 4R?797.91 N70 10 27.R7<;1 W1<;0 17 <;R ORQ'>. 22::\4.90 4500.00 48.81 56.29 3559.93 5913433.64 462860.72 N70 10 28.0857 W150 17 56.2551 2310.08 460000 48.81 <;R.29 ::\R2<;.79 <;91 ::\47<;.07 4R292::\.<;::\ N70 10 ?8.49R::\ W1<;0 17 <;4 4408 2::\8<;.25 470000 48.81 56.29 3691.R4 5913<;16.<;1 46298R.34 N70 10 W150 17 526266 2460.43 4800.00 48.81 56.29 3757.50 5913557.95 463049.15 N70 10 29.3175 W150 17 50.8123 2535.60 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 53.64 degrees Bottom hole distance is 4701.78 Feet on azimuth 53.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL e ConocJPt,illips ConocoPhillips Alaska, Inc.,slot #306 Pad 2N, Tarn ,North Slope, Alaska e PROPOSAL LISTING Page 3 Wellbore: 306 Wellpath: 2N-306 Ver#1.B Date Printed: 1-Apr-2004 .i. BAKER HUGHES INTEQ WelløathlGrid & tat/Lone I) Report MD[ft] Inc[deg] Azi[deg] TVD[ft) Northing Easting Latitude Longitude Vertical Sectionrftl 4AOO 00 4881 !'iR ?A ~R?~ ~!'i <::n< ')::nn -:¡Q 4R~111 AR N70 10 ?A7?R1 W1!'i0 17 4R QQR1 2R10.77 'iOOOOO 48.81 56.2A 388A.21 !'iA13R40.82 4R3174.76 N70 10 30.1387 W150 17 47.1838 2RR!'i.A!'i 5100.00 48.81 56.29 3955.06 5913682.26 463237.57 N70 10 30.5493 W150 17 45.3694 2761.12 5200.00 48.81 !'iR.?A 4020.A? !'iA1 ~72~70 4 N70 10 W150 17 43.!'i551 2836.29 'i~OO 00 4R R1 'iR ?Q 40RR 77 <::n<"7"'''.14 N70 1 0 ~1.'>.704 W1'iO 17 111 7MH ?A11 47 5400.00 48.81 56.29 4152.63 5913806.58 463426.00 N70 10 31.7810 W150 17 39.9264 2986.64 'i'iOO.OO 48.81 56.29 4218.48 5A1384801 4R3488.81 N70 10 32.1915 W1'iO 17 ~R.1120 ~OR1 R1 !'iROO.OO 48.R1 !'iR.29 4284.33 'iA1 ~RRQ.4'i 463551.62 N70 1 0 ~2.RO?1 W1!'iO 17 ~R ?A7R ~nR.AA 5700.00 48.81 56.29 4350.19 5913930.89 463614.43 N70 10 33.0126 W150 17 34.4831 3212.16 !'iROO.OO 4R.R1 !'iR.2Q 4416.04 'iA1 ~Q72.33 463677.24 N70 1 0 ~~.4?~2 W1!'iO 17 ~?RRR7 ~2R7.~~ 5AOO.00 4f!.R1 !'iR.2A 44R1.AO !'iA140n.7R 4R~740.0!'i N70 1 0 ~~.R337 W1!'i0 17 ~08542 33R2.51 6000.00 48.81 56.29 4547.75 5914055.20 463802.85 N70 10 34.2443 W150 17 29.0397 3437.68 R10000 4R 81 !'iR ?Q 4Rn R1 ~~ ,~. "'II N70 10 '> "<::'0 W1!'i0 17?7 ??<;? 3!'i1?8R 6200.00 48.81 56.2A 4R7A.4R !'iA1413R.08 4R3A2R.47 N70 10 '>.<; OR'i'>. W1!'i0 17 25.4106 3588.03 6300.00 48.81 56.29 4745.32 5914179.51 463991 .28 N70 10 35.4759 W150 17 23.5961 3663.20 6400.00 4RR1 5R.2A 4R11 17 !'iA14220.A!'i 4R4054.0A N70 10 3!'i.R8R4 W1!'i0 17 21.7815 373R.38 R'iOO 00 4R R1 56.29 487702 '>.Q N70 10 W1'iO 171AQRRQ '>.R1'>. 'i!'i 6600.00 48.81 56.29 4942.88 5914303.83 464179.71 N70 10 36.7074 W150 17 18.1523 3888.72 6700.00 48.81 56.2A !'i008 73 !'iA14~4!'i.27 4R424?!'i2 N70 10 37.1179 W150 17 16.3376 '>.QR'>..QO RROO 00 4R.R1 56.29 5074.59 5914386.70 464305.33 N70 10 37.5284 W1'iO 17 14.'i?30 403A.07 6900.00 48.81 56.29 5140.44 5914428.14 464368.13 N70 10 37.9389 W150 17 12.7083 4114.24 ?OOO 00 4R.81 56.29 5206.30 5914469.58 464430.94 N70 10 38.3494 W1'iO 17 1 0 RA~R 41RA.4? 710000 4R.81 !'iR.2Q !'i272 1!'i 'iQ14!'i11.02 4R44Q~.7!'i N70 1 0 ~R.7!'iQ8 W1!'i0 17 A.078A 42R4.!'iA 7200.00 48.81 56.29 5338.01 5914552.45 464556.56 N70 10 39.1703 W150 17 7.2641 4339.77 7218.21 4R.81 !'iR.2A !'i~!'iO 00 'iQ14'iRO 00 4R4!'iRR 00 N70 10 ~A.24!'i1 W1!'i0 17 R A33R 43!'i~.4R 7300.00 48.81 5R.2A !'i4m8R !'iA14!'iQ~ RA 4R4R1 A.~7 N70 10 W1!'i0 17 !'i.4494 4414.94 7400.00 48.81 56.29 5469.72 5914635.33 464682.18 N70 10 39.9913 W150 17 3.6346 4490.11 7!'i0000 48R1 !'iR ?A !'i!'i~!'i !'i7 ~~ ,~~~ 77 '''''7'. nn N70 10 W1!'i0 17 1 R1A8 4!'iR!'i?A 7ROO 00 48.81 5R?A !'iR01 43 ~~ ,~, ~ ~~ 4"'4Rn7 Rn N70 10 W1!'i0 17 00050 4640.46 7681.54 48.81 56.29 5655.12 5914751.99 464859.01 N70 10 41.1468 W150 16 58.5252 4701.76 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 53.64 degrees Bottom hole distance is 4701.78 Feet on azimuth 53.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL · ConocJ'Phillips ConocoPhillips Alaska, Inc.,slot #306 Pad 2N, Tarn ,North Slope, Alaska e PROPOSAL LISTING Page 4 Wellbore: 306 Wellpath: 2N-306 Ver#1.B Date Printed: 1-Apr-2004 .¡. BAKER HUGHES INTEQ / Casin s Name Top Top Shoe Well bore Taroèts Name Northrftl Eastrft 1 worftl Latitudé Lonoitude Eastino NorthinQ Last Revised 2N-306 Top 2580.97N 3505.87E 5350.00 N70 1 0 39.2~ W150 176.9 464568.00 5914560.00 30-Jan-2004 Bermuda Tgt 17 Feb 04 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 53.64 degrees Bottom hole distance is 4701.78 Feet on azimuth 53.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIG'~J e Conoc6Phillips ConocoPhillips Alaska, Inc.,slot #306 Pad 2N, Tarn ,North Slope, Alaska e PROPOSAL LISTING Page 1 Wellbore: 306 Wellpath: 2N-306 Ver#1.B Date Printed: 1-Apr-2004 ,&¡. BAKER HUGHES INTEQ Wellbore N 306 IW~11 ~~~ I Government 10 I ;~~~:~~~~: r AK-4 on NORTH AMERICAN DATUM 1927 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 53.64 degrees Bottom hole distance is 4701.78 Feet on azimuth 53.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL e e PROPOSAL LISTING Page 2 Wellbore: 306 Wellpath: 2N-306 Ver#1.B Date Printed: 1-Apr-2004 .¡. BAKER HUGHES INTEQ ,-,/ ConocoPhillips ConocoPhillips Alaska, Inc.,slot #306 Pad 2N, Tarn ,North Slope, Alaska Welløath Reøort MD[ft] Inc[deg] Azi[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical Station Comment deol100ftl Sectionfftl 0.00 000 000 000 OOON OOOF 0.00 000 Tie on 100.00 0.00 000 100.00 O.OON O.OOE 0.00 0.00 200.00 0.00 0.00 200.00 O.OON O.OOE 0.00 0.00 <\00.00 0.00 0.00 300.00 O.OON O.OOE 0.00 0.00 40000 000 000 400 00 o OON o OOF 000 000 I<'r\D ¡:::n"¡ nfHnlrl 500.00 2.00 15.00 499.98 1.69N OA5E 2.00 1.36 ROO 00 4.00 15.00 5qq 84 R.74N 1.81E ?OO 545 70000 6.00 15.00 RQq45 15.1RN 4.0RE ?OO 1??6 800.00 8.00 15.00 798.70 26.93N 7.22E 2.00 21.78 QOOOO 10.00 15.00 8q747 4? 04N 11.2RF ?OO ::I::I.QQ RlrlfTrn ::1/100. End of BuildfTurn 1000.00 12.97 17.28 QQ5A5 61 14N 1 ñ.84E ::1.00 49.81 1100.00 15.94 18.72 1092.28 84.87N 24.59E 3.00 70.12 1200.00 18.93 1971 1187ñ7 1 n 1 ñN ::I447F ::100 Q484 121::\.05 1Q ::12 19.82 1200.00 117 18N 35.91E 3.00 q8<\q B""" P"rm"frn"t 1235.81 20.00 20.00 1221A3 124.38N 38.52E 3.00 104.76 3DJ Kick off Point 1266.27 20.57 22.06 1250.00 134.23N 4?31E 3.00 113.65 Tnn W",,¡ C:::"k 1 ::100 00 ? 1 ?::\ ?4 ?1 1 ?81 !'i? 14!'i<\ON 4704F <\ 00 1?40? 1400.00 23.33 29.87 1374.06 178.99N 64.33E 3.00 157.92 1!'i00.00 ?5.RO <\LI.R? 1465.08 213.94N 86A7E 3.00 1qñ 48 1 ñOOOO ?8.00 ::IR.ñ2 1!'i!'i4.::I4 2!'i0.07N 11::\.40E 3.00 2::19.!'i8 1700.00 30A9 42.03 1641.60 287.26N 145.04E 3.00 287.11 1800 00 33.07 44.Qñ 17?R.ñO ::I?!'i.42N 181.::I?E ::1.00 ::1::18.94 1900.00 ::15.70 47.51 1809.13 3ñ4.44N 222.11 E ::1.00 ::I94.Q3 2000.00 38.38 49.75 1888.95 404.22N 267.33E 3.00 454.92 2050.29 39.74 50.77 19?8.00 424.47N 291.70E ::100 48ñ.56 S;:¡~e We~t Sak 2100.00 41.10 51.73 1965.84 444.ñ4N 316.84E ::1.00 518.76 2200.00 43.85 53.52 2039.60 485.60N 370.50E 3.00 586.26 ?<\oo 00 4ññ? 55.13 2110.02 5?ñ 98N 4?818F 300 ñ57?4 ?::I78 !'i0 4881 !'iñ ?q ?1ñ? 8<\ !'i!'iqñQN 476.16E 3.00 71!'i ?7 Fnr. Fnrl 2400.00 48.81 56.29 2176.99 568.67N 489.62E 0.00 731A3 2500.00 48.81 56.29 2242.84 610A3N 552.22E 0.00 806.61 2ROO.00 48.81 !'iñ.29 2<\08 70 652.20N 614.82E 0.00 881.78 2700.00 48.81 56.29 2374.55 693.96N 677A2E 0.00 956.95 ?7R1 A? 48.81 !'iñ.2Q 241500 719.61 N 715.87E 0.00 1 003.12 7 !'i/8 r.c:::r; 280000 48.81 !'iR.?Q 244041 7::1!'i.7::1N 740.O?E 0.00 10::\2.13 2875.31 48.81 56.29 2490.00 767.18N 787.16E 0.00 1088.74 C80 (K101 290000 48.81 !'iR.29 2!'iOR.2R 777A9N 802.R2E 0.00 1107 ::10 <\000 00 48.81 5R.29 257?12 819.2RN 8R5.2::1E 0.00 118247 3100.00 48.81 56.29 2637.97 861.02N 927.83E 0.00 1257.65 3200.00 48.81 5R?Q ?70::\ 8::1 90? 78N QQO 4::1F 000 1::1::1? 8? ::1<\00.00 48.81 56.29 2769.68 944.55N 1053.O::\E 0.00 1407.99 3400.00 48.81 56.29 2835.53 986.31 N 1115.63E 0.00 1483.17 3500.00 48.81 5R.29 2901.3Q 1028.08N 117R.2::1E 0.00 1558.::14 ::IñOO 00 4881 !'iñ ?Q ?Qñ7 ?4 A^,'" n.'.' 1?40 A<\¡::: 000 1ñ<\<\ !'i? 3700.00 48.81 56.29 3033.10 1111 .61 N 1303A3E 0.00 1708.69 <\800.00 48.81 56.29 30Q8.95 115337N 13Rñ.O::\F 0.00 1783.86 3900.00 48.81 !'iñ.2Q ::11 ñ4.81 1195.14N 1428.64E 0.00 1 85Q 04 4000.00 48.81 56.29 3230.66 1236.90N 1491.24E 0.00 1934.21 4100.00 48.81 !'iñ ?Q ::I2Qñ.52 1278.ñ7N 1553.84E 0.00 200Q.<\8 4200.00 48.81 5R.2Q 3::1R?::I7 1::\20 4::1N 1 R1 RA4F 0.00 ?OM.!'iR 4300.00 48.81 56.29 3428.23 1362.19N 1679.04E 0.00 2159.73 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 53.64 degrees Bottom hole distance is 4701.78 Feet on azimuth 53.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Saker Hughes Incorporated ORIGINAL e Conoc~illips ConocoPhillips Alaska, Inc.,slot #306 Pad 2N, Tarn ,North Slope, Alaska e PROPOSAL LISTING Page 3 Well bore: 306 Wellpath: 2N-306 Ver#1.B Date Printed: 1-Apr-2004 _i. BAKER HUGHES INTEQ We II cath ReDort . MD[ft] Inc[deg] Azi[deg] WD[ft] North[ft] East[ft] Dogleg Vertical Station Comment dea/100ftl Sectionfftl 4400 00 41'1 I'll "ñ ?q ~q4 OR 1M\'>. Q"'" 1741 ñ4F 000 ??~ qO 4500.00 48B 1 !16.29 ~!159.q~ 144!1.72N 1 R04.?4E 0.00 2~10.08 4600.00 48.81 56.29 3625.79 1487.49N 1866.84E 0.00 2385.25 4700.00 41'1 I'll "6.29 ~ñq1 .ñ4 1"2q 2"N 1 q?q 44E 0.00 2460.4~ 41'100 00 48.81 !16.29 ~7!17!10 1 !1710?N 1 QQ? n<;F 000 2!135.60 4894.91 48.81 56.29 3820.00 1610.66N 2051.46E 0.00 2606.95 C50 4900.00 48.81 !16.29 ~82~.~!1 1612.78N 20M.6!1F 0.00 2610.77 "000.00 41'1 I'll 56.29 388921 1654.55N 2117.25E 0.00 2685.95 5100.00 48.81 56.29 3955.06 1696.31N 2179.85E 0.00 2761.12 !1200.00 4R.A1 56.29 4020.92 1738.08N 2242.45E 0.00 2836.29 !1~00.00 4R.A1 "ñ.2q 40Rñ.77 1779.84N 2?'0!1.0'1F 0.00 2q11.47 5358.05 48.81 56.29 4125.00 1804.09N 2341.39E 0.00 2955.11 C40 (K5) !'i400 00 41'1 A1 "ñ ?q 41'1? ñ?, 1A?1 1)1 N ??'ñ7 ñ"F onn ?qAñ ñ4 5500.00 48.81 "ñ.?9 421 AAA 1 Añ::U7N ?4?'0.2!1F 0.00 ~Oñ1.81 5600.00 48.81 56.29 4284.33 1905.14N 2492.86E 0.00 3136.99 !1ñ4ñ.!17 4R.A1 "ñ.?q 4?'1'1.00 1q?4.'1AN 2"?2.01 F 0.00 ?'171.qq ('.?'7 "7nn on 48.81 !1ñ.29 4~!10 1 q 1MñQn'" ?<;<;<; llñF 000 ~?12.16 5800.00 48.81 56.29 4416.04 1988.66N 2618.06E 0.00 3287.33 5900.00 48.81 !1ñ.29 44R1 .90 20~0.4~N 2ñRO.6ñE 000 ~~ñ2.!11 ñOOO.OO 4R.A1 56.29 4547.75 2072.19N 2743.26E 0.00 3437.68 6100.00 48.81 56.29 4613.61 2113.96N 2805.86E 0.00 3512.86 ñ?OO.OO 48.A1 56.29 4679.46 215572N 2Rñ8.46E 000 3588.03 ñ~OO.OO 48.R1 "ñ.?q 474".?'2 2197.49N 2931.06E 0.00 ?'ññ?'.20 6400.00 48.81 56.29 4811.17 2239.25N 2993.66E 0.00 3738.38 ñ!100.00 4RR1 '1ñ.2q 4877.02 2281.02N 3056.26E 0.00 ?'An."!1 659!1.63 41'1.81 "ñ.29 4940.00 2?'?0.q"N ?,11ñ1?,F 0.00 ?'RR!1.44 T7 6600.00 48.81 56.29 4942.88 2322.78N 3118.87E 0.00 3888.72 ñ700 00 41'1 R1 '1ñ ?q "OOA 7?, ')'>."A 0:;0:;", '>.1 Ai 47F 000 ?,qñ?,qO ñAnn nn 4R.81 "ñ.?9 !1074"q ?40ñ?,1 N '>.?All n7F 000 4o::¡q 07 6900.00 48,81 56.29 5140.44 2448.07N 3306.67E 0.00 4114.24 7000.00 41'1.81 "ñ.2Q !120ñ ?,o 24Rq.R4N ?'?'ñq.27E 0.00 41 R9.42 701 A.?1 48.81 !1ñ.29 5218.?9 ?4Q7.44N ?'~RO.ñ7F 0.00 4203.11 !1 1/2 x 31/2 XO. 5 1/2in Casino 7073.95 48.81 56.29 5255.00 2520.72N 3415.57E 0.00 4245.01 T4.1 7100.00 48.81 !1ñ.29 5272.1!1 ?!131.ñON ~~1.87E 0.00 4?ñ459 nOO 00 4R.R1 56.29 5338.01 2573.37N 3494.47E 0.00 4339.77 7218.21 48.81 56.29 5350.00 2580.97N 3505.87E 0.00 4353.46 T3 (Top Bermuda Target), 2N-306 Top Bermuda Tgt 17 Fet 04 Enrl of Holrl 7300.00 48.81 56.29 5403.86 2615.13N 3557.07E 0.00 4414.94 7400 00 41'1 R1 '1ñ ?q "4ñQ 7? ?ñ"ñ QnN '>."1Q "At: nnn llllQO 11 7491M 48.81 !1ñ.29 !1!1~0.00 ?ñQ".1 ::IN ::Iñ7ñ.QRE 000 4""R.93 12 7500.00 48.81 56.29 5535.57 2698.66N 3682.28E 0.00 4565.29 7!17!1.0ñ 48.R1 '1ñ.2Q !1"A".OO 2730.01 N 3729.26E o.on 4ñ21.71 7ñnn no 48.81 !1ñ.?9 !1ñ014::1 n~ ,n ,n, '>.7All AAF 000 4ñ40 4ñ 7681 .54 48.81 56.29 5655.12 2774.48N 3795.92E 0.00 4701.76 TD 3 1/2in Casino. End of Hold All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Planned Datum 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 53.64 degrees Bottom hole distance is 4701.78 Feet on azimuth 53.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGl~~/\ e ConocJ'Pt,illips ConocoPhillips Alaska, Inc.,slot #306 Pad 2N, Tarn ,North Slope, Alaska e PROPOSAL LISTING Page 4 Well bore: 306 Well path: 2N-306 Ver#1.B Date Printed: 1-Apr-2004 _i. BAKER HUGHES INTEQ Hole Sèctions Start Casin s Name Top Shoe Shoe Shoe Well bore Taraets Name . Nörthfftl Eastfft 1 TVDfftJ Latitude Lonaitude Eastina Northing Last Revised 2N-306 Top 2580.97N 3505.87E 5350.00 N70 10 39.245 W150 176.93 464568.00 5914560.00 30-Jan-2004 Bermuda Tgt 17 Feb 04 7681.54 M All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVD's are from Rig (Planned Datum 150.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 53.64 degrees Bottom hole distance is 4701.78 Feet on azimuth 53.84 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated OR1Gjt'~ .ker Hughes IncorporateÞ Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.00 ft Depth Range: 0.00 to 7681.54 ft Maximum Radius: 5280.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse Survey Program for Definitive Wellpath Date: 311012004 Validated: No Planned From To Survey ft ft . 0.00 7681.54 Planned: 2N-306 Ver#1 V7 Version: 0 Toolcode Tool Name MWD+SAG MWD + Sag correction ---~~~-- Summary Tarn #2 Tarn#2 Tarn#2 VO Out of range Tarn #3 Tarn#3 Tarn#3 V1 3211.97 2800.00 3912.60 98.86 3813.74 Pass: Major Risk Tarn #3 Tarn#3 Tarn#3A VO 2903.63 2350.00 3913.88 84.67 3829.21 Pass: Major Risk Tarn #4 Tarn#4 Tarn#4 VO 7678.15 5675.00 4652.64 245.01 4407.63 Pass: Major Risk Tarn Drillsite 2N 302 2N-302 V1 374.92 375.00 56.06 5.19 50.87 Pass: Major Risk Tarn Drillsite 2N 303 2N-303 V1 374.96 375.00 46.09 4.16 41.93 Pass: Major Risk Tarn Drillsite 2N 304 2N-304 V1 324.94 325.00 28.83 4.08 24.75 Pass: Major Risk Tarn Drillsite 2N 304 2N-304PB1 V1 324.94 325.00 28.83 4.08 24.75 Pass: Major Risk Tarn Drillsite 2N 305 2N-305 V1 324.98 325.00 17.36 3.39 13.98 Pass: Major Risk Tarn Drillsite 2N 307 2N-307 V1 449.76 450.00 17.72 5.63 12.10 Pass: Major Risk Tarn Drillsite 2N 308 2N-308 V1 699.51 700.00 27.26 11.70 15.56 Pass: Major Risk Tarn Drillsite 2N 309 2N-309 V1 499.12 500.00 47.07 7.11 39.96 Pass: Major Risk Tarn Drillsite 2N 310 2N-310 VO Plan: 2N-310 572.20 575.00 58.92 8.76 50.15 Pass: Major Risk Tarn Drillsite 2N 311 2N-311 V1 Plan: 2N-311 1018.52 1025.00 76.35 20.61 55.74 Pass: Major Risk Tarn Drillsite 2N 312 2N-312 VO Plan: 2N-312 634.56 625.00 544.90 9.63 535.27 Pass: Major Risk Tarn Drillsite 2N 313 2N-313 V1 324.98 325.00 106.28 3.31 102.97 Pass: Major Risk Tarn Drillsite 2N 314 2N-314 V1 125.00 125.00 120.14 0.04 120.10 Pass: Major Risk Tarn Drillsite 2N 315 2N-315 V1 324.98 325.00 136.50 3.51 132.99 Pass: Major Risk Tarn Drillsite 2N 316 2N-316 V1 374.97 375.00 150.51 4.33 146.18 Pass: Major Risk Tarn Drillsite 2N 317 2N-317 V1 497.14 500.00 166.13 6.80 159.33 Pass: Major Risk Tarn Drillsite 2N 318 2N-318 V1 275.00 275.00 179.79 2.25 177. 54 Pass: Major Risk Tarn Drillsite 2N 319 2N-319 V1 472.56 475.00 196.91 5.99 190.92 Pass: Major Risk Tarn Drillsite 2N 320 2N-320 V1 448.36 450.00 207.41 6.70 200.72 Pass: Major Risk Tarn Drillsite 2N 321 2N-321 V2 299.94 300.00 227.89 2.72 225.17 Pass: Major Risk Tarn Drillsite 2N 321 2N-321A V1 299.94 300.00 227.89 2.72 225.17 Pass: Major Risk Tarn Drillsite 2N 323 2N-323 VO 299.95 300.00 257.21 3.02 254.20 Pass: Major Risk Tarn Drillsite 2N 325 2N-325 VO 1.00 1.00 284.95 0.00 284.95 Pass: Major Risk Tarn Drillsite 2N 326 2N-326 VO 324.99 325.00 301.86 4.10 297.76 Pass: Major Risk Tarn Drillsite 2N 329 2N-329 VO 447.30 450.00 344.58 5.47 339.11 Pass: Major Risk Tarn Drillsite 2N 331 2N-331 VO 299.99 300.00 376.53 2.71 373.81 Pass: Major Risk Tarn Drillsite 2N 332 2N-332 VO 0.00 0.00 390.04 0.00 390.04 Pass: Major Risk Tarn Drillsite 2N 332 2N-332PB1 VO 0.00 0.00 390.04 0.00 390.04 Pass: Major Risk Tarn Drillsite 2N 335 2N-335 VO 539.46 550.00 434.26 7.77 426.49 Pass: Major Risk Tarn Drillsite 2N 337 2N-337 V1 374.95 375.00 465.08 4.43 460.65 Pass: Major Risk Tarn Drillsite 2N 337 2N-337PB1 V1 374.95 375.00 465.08 4.43 460.65 Pass: Major Risk Tarn Drillsite 2N 339 2N-339 V1 399.94 400.00 492.17 4.57 487.59 Pass: Major Risk Tarn Drillsite 2N 341 2N-341 VO 374.96 375.00 527.00 4.39 522.61 Pass: Major Risk Tarn Drillsite 2N 343 2N-343 V1 349.99 350.00 554.67 3.64 551.02 Pass: Major Risk Tarn Drillsite 2N 345 2N-345 VO 445.60 450.00 586.19 5.89 580.30 Pass: Major Risk Tarn Drillsite 2N 345 2N-345A VO Plan: 2N-34 445.60 450.00 586.19 5.89 580.30 Pass: Major Risk Tarn Drillsite 2N 347 2N-347 VO 349.99 350.00 615.67 3.84 611.83 Pass: Major Risk Tarn Drillsite 2N 348 2N-348 VO 399.98 400.00 631.46 5.67 625.79 Pass: Major Risk Tarn Drillsite 2N 349 2N-349 VO 349.99 350.00 645.71 3.80 641.91 Pass: Major Risk Tarn Drillsite 2N 349 2N-349A V2 0.00 0.00 645.04 0.00 645.04 Pass: Major Risk Tarn Drillsite 2N 350 2N-350 VO 349.97 350.00 656.79 4.61 652.17 Pass: Major Risk OR'G'~~A e e CLEARANCE LISTING Page 1 Date Printed: 1-Apr-2004 Tarn, North Slope, Alaska Bi. BAKER HUGHES INTEQ conocJ'Phillips ConocoPhillips Alaska, Inc. 2N-306 Ver#1.B, 306 slot #306, Pad 2N Ellipse separations are reported ONLY if BOTH wells have uncertaintv data Only Depth and Maqnetic Reference Field error terms are correlated across tie points Cutoff is calculated on CENTRE to CENTRE distance Summary data uses Closest Approach clearance calculation for all minima Cone of Safety applied (Ref: 0.0%, Offset: 0.0%) from Slot Permanent Datum Hole size/Casinqs are NOT included Hole size/Casinqs are NOT subtracted from Centre-Centre distance Ellipses scaled to 2.58standard deviations. Closinq Factor Confidence limit of 99.80% Errors on Ref start at Slot Permanent Datum (0.00) Report uses Revised: (D-C)/E Factor Calculation f~"bofe I~I I ~b~~t:~2004 I ~~~~:~~~~~ Slot Name I I Government 10 I Last Revised 10-Mar-2004 T N 5927841.632 AK-4 on NORTH AMERICAN DATUM 1927 datum True Cléarance·..Sommarv .,. ,. . Offset Offset Offset Offsét Minimum MD[ft] DiVérging Ellipse Ellipse Clearance I v'v"" e,,, ,''v WeUNamé WeUbore Slot Structure Distancé From[ft] MD[ft] Factor IMD[ft] Iftl Iftl 304 304 slot #304 Pad 2N 1348.2C 7218.0 7218.0 <\().ð. PR1 I<\MPR1 P;:,rl?N 1.1R? 4 7218.01 7218.01 <\()<\ hm 'P;:,rl2N ?.1172Ç 7?1 ROI 7?1 R 01 302 302 slot #302 Pad 2N 2579.3 7218.0 7218.0 <\()<; 1305 I P;:,rI?N <\7RR.n: 7218.01 7218.01 :107 h()7 1 "'In' it<\()7 Pad 2N 4410.2: 721R.01 721R.01 Tarn #4 Tarn #4 slot #1 TARN #4 4661.9 7234.2 7234.2 :lOR I:I()R I Pad 2N 4Mn.21 7:;>1 R.OI 721 R.OI 30A hOA I Pad 2N 4967.1, 721A.01 7218.01 Tarn#3 T arn#3 slot #1 TARN #3 4991.6 7218.0 7218.0 31:\ ¡:l1~ I"'ln'it:l1:\ Pad 2N 5551.2E 7218.0( 7218.01 319 '31ÇJ ¡",Io, #31A P;:,rl?N <;<;<;2.:I~ 7218.0( 7218.01 Tarn#3 Tarn#3A slot #1 TARN #3 5630.8 7218.0 7218.0 317 1317 I",'n' #:~1 P;:,rl?N .'iR<;() :I, 7218.01 7218.01 :114 1~14 Islol #314 Parl2N S724.n: 721R 01 721 R.Or 318 318 slot#318 Pad 2N 5793.0 7218.0 7218.0 MQ 134Ç 1"'lol#34A P;:,rI?N <;R1R.0: 7218.0( 7218.01 All data is in Feet unless otherwise stated Coordinates are from Slot and NO's are from Rig (Planned Datum 150.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) ôeRell3ll~uÄscorporated e e CLEARANCE LISTING Page 2 Date Printed: 1-Apr-2004 Tarn, North Slope, Alaska IIi. BAKER HUGHU INTEQ Conoc<>Phillips ConocoPhillips Alaska, Inc. 2N-306 Ver#1.B, 306 slot #306, Pad 2N Clearance.Summar\i Offset Offset Offset Offset Minimum MD[ft] Divergíng ~lIipsé EllipSe 1'-""""""'"'' Wel/Narœ Wellbore Slot Structure Distance F rom[ft] MD[ft] [Façtor :MD[ft] rfl1 rft] ~1!ï 1~1!'ï 1"'lnl#~1!ï P~rl2N !ïA?4.4~ 7?1 A 01 721 A.OI 316 316 slot #316 Pad 2N 5853.5C 7218.0 7218.0 ~4Ç I <\4qA ",lnl#<\4Q P~rl2N "iA7"i.4 7218.01 7218.01 ~2!ï I~?!ï "'lnl#~2!ï P~rl2N !ïÇ10.ñ: 7?1 ROI 171 A.OI 335 335 slot #335 Pad 2N 5936.1C 7218.0 7218.0 ~20 I~?o P~rl2N ñ01ñ.01 7?1A 01 721 RO( 321 1~21 1",lnl #~21 Pad 2N ñO!ï!ï.3t 7218.01 721 A.OI 321 321A slot #321 Pad 2N 6055.3t 7218.0 7218.0 323 1~2~ I "'Int #~2~ Pad 2N ñ2!ïO.!ï1 721A.01 721 A.Ûi <\?Ç h2Q ''''lnl#<\2Q Pad 2N 6292.4: 7218.01 7218D 337PS1 337 PSi slot #337 Pad 2N 6332.1 7218.0 7218.0 <\<\7 h<\7 Ip",rl?N ñ~~2.1 72180i 721 A.O ~?ñ 1<\2ñ ""lnl#<\2ñ P~rl ?N ñ<\ñA.Ç, 7218.01 7?1 Rn 332 332 slot #332 Pad 2N 6410.6 7218.0 7218.0 <\<\?PR1 h<\2 PS 1 ''''lnl#<\<\2 P~rl?N 6410.6' 7218.01 7218.0 ~~1 h~1 I P~d ?N ñ4?Ç4 7?1A 01 7?1RO 345 345 slot #345 Pad 2N 6461.2 7218.0 7218.0 ~~9 h~ç I P~rl ?N ñ!ï<\1.2 721A 01 7?1 R.O <\48 1348 1",lnl #~48 P~d 2N ñ!ï44.31 721 A.OI 171 R.Ûi 341 341 slot #341 Pad 2N 6603.3 7218.0 7218.0 347 1~47 1 ",Inl #~47 P~d ?N ññ10.4 171 A.OI 721AOi <\4<\ h41 "'lnl#<\4<\ Pad 2N 6614.2 7218.01 7218D 350 350 slot #350 Pad 2N 6620.4 7218.0 7218.0 T"'rn#? T"'rn:/t2 '''lnl#1 TARN #2 953ñ.61 7234.2 7234.2 Reference Well bore Surve H PI All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Planned Datum i50.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) PcrRbJ 13e\ rJ:t\ntorated p~ ~or~~$ "'t~ oc-d 1900 2000 2100 t ¡ I ConocoPhHUps Alaska, Inc. '¡w/ ConocoPhillips location: Field: installation: North Slope, Alaska Tarn Pad 2N Slot: slot #306 Well: 306 Well bore: 306 Datum East (feet) -> noD 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 j ,~..i._L.~~ 4000 EndofHotù·S655.12Tvd,2714.4IJN:ì795.92E ""~J--'~~ 3900 3800 3700 3600 3500 3400 3300 3200 3100 3000 2900 2800 {' 2700 Z o ;:¡, :r 2600 ~ .; 2500 2400 2300 2200 2100 2000 1900 1800 1700 1600 e e 2N-306 - DRILLING HAZARDS SUMMARY 9 7/8" Open Hole & 7 5/8" Surface Casin2 Interval Event Broach of conductor Gas Hydrates at base of Permafrost Gas at base of West Sak Running sands & gravel Hole swabbinglTight hole on trips Stuck surface casing Stuck pipe Risk Level Low Moderate Moderate Moderate Moderate Low Low Miti ation Strate I Contin enc Monitor cellar continuousl durin interval Minimum mud weight of 9.6 ppg, control drill, reduce pump rates, reduce drilling fluid tem eratures, retreat mud for h drates Minimum mud weight of 9.6 ppg before reaching base of West Sak, reduce mud viscosity after drilling out of the Permafrost, control drill Maintain planned mud parameters, Increase mud weight/viscosity, Use weighted sweeps, monitor fill on connections Circulate hole clean prior to trip, proper hole filling (use of trip sheets), pumping out of hole as needed Clean the hole before running casing, pump hi h dens it hi h viscosit swee s, wi er tri Keep hole clean, use high density high viscosity sweeps, keep pipe moving/rotating with pumps on whenever ossible 6 %" Open Hole & 5 l/i' x 3 Vi' Production Casin2 Interval Event Swabbing Campaignian sands (50 ft TVD below C- 80 Insufficient or undetermined LOT High ECD / Tight hole on trips/ Swabbing Differential sticking Barite sag Lost circulation Risk Level Moderate Moderate Moderate Moderate Low Low ORIGIN,A Importance of LOT communicated to all parties, all parties familiar with LOT procedure. Test will be carried out until leak off is observed or to an FIT of 18 MW e uivalent Condition mud & clean hole prior to trips. Monitor ECDs with PWD tool while drilling across reservoir interval. Hole cleaning best practices. Backream out on trips as a last resort, ro er hole fillin use of tri sheets Keep hole clean, periodic wiper trips, keep pipe moving/rotating with pumps on whenever ossible Good drilling practices as documented in well Ian Keep hole clean - use PWD to monitor hole cleaning. If losses occur - reduce pump rates and mud rheolo , use LCM 2N-306 Drilling Hazards Summary Prepared by Philip Hayden 4/9/2004 Rig: Doyon 141 Location: Tarn Client: CPAI Revision Date: 4/9/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 16",62.6#, H-40 grade Welded Connection at 150 ft. MD < Base of Permafrost at 1,213 ft. MD (1,200 ft. TVD) < Top of Tail at 1,261 ft. MD < 75/8",29.7#, L-80 grade BTC, AB Modified in 9 7/8" OH TO at 2,761 ft. MD (2,415 ft. TVD) Mark of Schlumberger Preliminary Job Design based on limited input data. For estimate purposes only. s Volume Calculations and Cement Systems Volumes are based on 225% excess in the permafrost and 45% excess below the permafrost. Top of tail slurry is designed to be 48' below base of permafrost. Lead Slurry (minimum pump time 164 min.) ArcticSet III Lite @ 10.7 ppg, -4.43ft3/sk 0.9513 ft31ft x (150') x 1.00 (no excess) = 0.2148 ft31ft x (1213' -150') x 3.25 (225% excess) = 0.2148 ft3/ft x (1261' - 1213') x 1.45 (45% excess) = 142.7 ft3 + 742.1 ft3+ 15 ft3 = 899.8 ft3 I 4.43 ft3/sk = Round up to 204 sks 142.7 ft3 742.1 ft3 15 ft3 899.8 ft3 203.1 sks Have 160 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry (minimum pump time 141 min.) LiteCRETE @ 12.0 ppg - 2.46 ft3/sk 0.2148 ft31ft x (2761' - 1261') x 1.45 (45% excess) = 0.2578 ft3/ft x 80' JShoe Joint} = 467.2 ft3 + 20.6 ft = 487.8 ft31 2.46 ft3/sk = Round up to 199 sks 467.2 ft3 20.6 ft3 487.8 ft3 198.3 sks BHST = 64°F, Estimated BHCT = 7rF. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (min) CW100 5 40 8.0 8.0 Drop Bottom Plug 12.0 20.0 MudPUSH II 7 40 5.7 25.7 Lead Slurry 7 161 23.0 48.7 Tail Slurry 5 87 17.4 66.1 Drop Top Plug 12.0 78.1 Displacement 7 103 14.7 92.8 Bump Plug 3 20 6.7 99.5 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv? 17-20, Ty ? 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINA Rig: Doyon 141 Location: Tarn Client: CPAI Revision Date: 4/9/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Previous Csg. < 75/8", 29.7#, L-80 grade BTC, AS Modified at 2,761 ft. MD < 51/2", 15.5#, L-80 grade BTC, AB Modified in 6 3/4" OH < Top of Tail at 6,574 ft. MD < X-over at 7,018 ft. MD < TopofT4.1. at 7,074 ft. MD < 3 1/2", 9.3#, L-80 grade in 6 3/4" OH TO at 7,682 ft. MD (5,655 ft. TVD) Mark of Schlumberger Icb berger Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 75% excess. Top of tail slurry is designed to be 644' above the Bermuda formation. Tail Slurry (minimum thickening time 133 min.) Class G wI GasBLOK additives per lab testing @ 15.8 ppg, 1.16 ft3/sk 3 0.0835 ft 1ft x 444' x 1.75 (75% excess) = 3 0.1817 ft 1ft x (7682' -7018') x 1.75 (75% excess) = 0.0488 ft3/ft x 120' (Shoe Joint) = 64.9 ft3 + 211.1 ft3 + 5.9 ft3 = 281.9 ft3/1.16 ft3/sk = Round up to 243 sks 64.9 ft3 211.1 ft3 5.9 ft3 281.9 ft3 243 sks BHST = 148°F, Estimated BHCT = 126°F. (BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (min) CW100 5 40 8.0 8.0 Drop Bottom Plug 3.0 11.0 MudPUSH II 6 40 6.7 17.7 Tail Slurry 6 50 8.3 26.0 Drop Top Plug 3.0 29.0 Displacement 6 157 26.2 55.2 Bump Plug 3 15 5.0 60.2 MUD REMOVAL Recommended Mud Properties: 10.2 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* II, Pv? 19-22, Ty ? 22-29 Centralizers: Recommend 1-% per joint across zones of interest for proper cement placement. ORIGI~J Tarn 2N-306 Injecttr Proposed Completion Schematic 3-1/2" Completion String 16" 62.6# @ +1- 150' MD Depths are based on Nordic 3 RKB Surface csg. 7 5/8" 29.7# L-80 BTC +1- 2761' MD /2415' TVD 5 %" 15.5# L-80 BTCM x 3 %" 9.3# L-80 EUE8RD Mod crossover at +1- 7018' MD I 5218' TVD Future Perforations Production csg 5 %" 15.5# L-80 BTCM x 3 %" 9.3# L-80 EUE8RD Mod +1- 7682' MD I 5655' TVD ~illipi 3 %" FMC Gen 5 Tubing Hanger, 3 %" L-80 EUE8RD Mod pin down 3 %" 9.3# L-80 EUE8RD Mod Spaceout Pups as Required 3 %" 9.3# L-80 EUE8RD Mod Tubing to Surface - Tubing & hanger TO BE DRIFTED TO 2.91" 3 %" Camco 'DS' nipple wI 2.875" No-Go Profile. 3 %" x 6' L-80 handling pups installed above and below, EUE8RD Mod, set at +1- 500' MD 3 %" 9.3# L-80 EUE8RD Mod tubing 3 %" x 1" Camco 'KBG-2-9' mandrel with shear valve, pinned for 3000 psi shear (casing to tubing differential). 3 %" x 6' L-80 handling pups installed above and below mandrel, EUE8RD Mod 3 %" Baker 'CMU' sliding sleeve wI 2.813" Cameo OS profile, EUE8RD Mod box x pin. 3 %" x 6' L-BO EUE8RD Mod handling pup installed above 3 %" Camco 'D' nipple wI 2.75" No-Go profile. 3 %" x 12' L-80 EUE8RD Mod spacaeout pup installed above, 3 %" x 6' handling pup installed below 3 %" Baker 80-40 GBH-22 casing seal assembly wI 15' stroke, 3 %" L-80 EUE8RD Mod box up, 3 %" x 6' L-80 EUE8RD Mod handling pup installed on top Baker Seal Bore Extension, 5 %" BTCM x 3 %" EUE8RD Mod SBE set at +1- 200' MD above the top of the Bermuda interval ORIGINAL 04/09/04 ~ I e e e e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER ¡¿12tl- 2~&?G WELL NAME PTD# 2D'-f-Dto2- Development c/ Service Exploration Stratigraphic CHECK WHAT ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI Tbe permit is for a new wellbore segment of LATERAL existing weD . Permit No, API No. . (If API num ber Production.sbould continue to be reported as last two (2) digits a function 'of tbe original API number. stated are between 60-69) above. PILOT HOLE In accordance witb 20 AAC 25.005(t), all (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance witb 20 AAC 25.0SS~ Approval to perforate and produce is contingent upon issuance of ;¡ conservation order approving a spacing ex ception. (Company Name) assumes tbe liability of any protest to tbe spacingeJception that may occur. DRY DITCH All dry ditcb sample sets submitted to the SAMPLE Commission must be in no greater tban 30' sample intervaJs from beJow tbe permafrost or from wbere samples are first caught and 10' sampJe hitervaJs tbrough target zones. o o Well bore seg Annular Disposal On Program SER On/Off Shore U 1fiQ Well Name: KUPARUK RI~TARN 2N-306 £ER LPEND GeoArea 890 Unit Tarn Oil PooJ,CQ 4308 Kuparuk River e 810_16_ 2N-3Q4_ y~s y~s y~s Yes y~s y~s y~s y~s y~s y~s _Yes y~s Yes y~s y~s No_ NA Initial ClasslType KUPARUK RIVER, TARN OIL - 490165 INC Pe nn it. fee attached _Leas~ _numberappropri<1te_ _U_nlque welt n_am~ _a[1d oumb_er WeU Jocat~d ina. d_efil1edpool Welllocat~d proper distance_ from driJling ul1it. Well located prpper _dista[1ce from otber wells_ _S_ufficiel1t b_oul1d_ary_ ¡ndrilJiog unjt Jtd~viated. js weJlbQre platil1cJu_ded _O-perator onl}' affected party _O-perator bas_appropriate_ b.ond inJorce Permit. p~(IlJit. co_nservaJiOI1 order admil1istratille_ apprpvaJ <:90 be iSSl.!ed without ~a[1 be issued without in_ cpmm~[1ts) (For 5-day wait Wel AJI wel!s_ within J l4Juile _area_of reyiew id~otified (Fpr servj~ )V.e!l OI1I}') Pre-produçed injector; dur<1tioRof pre-productioo I~ss_ than 3 montbs_ (For_service well only) 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Administration _acreage_aYail<1ble 10# lojectioo Ord.er # (put. Can permit be approved before Joc<1t~d within area and_strat<1authorized by Date 4/16/2004 Appr SFD from exjsting pa_d. We!! driUed 811 aquifers eJ(empt.ed.AOCFR 1<47 J02_(b)(3) 811nutar disposal "lay be propo.sed. dispos<11 I Wa_ste_to al1 approyed annulus or_Class No reseJlle_pjtplanoe_d. Rig is_equippe_dwith st~elpits. prp~imlty- an<1lysis perfprme_d. Jrayeling c}'lioder plot.PJovid.ed. MW 9.8 ppg. Max possible BHP 9.JE.MW. Planned e M8$P calcuJatedat 2212 psi. 3SQOp_si appropriate_. _CPAJ jk~1y to t.esUo SQOO psi. Mud sh_ould pœclude_ H2S_ on_rig. Rigjs equipped_ with.seos_ors_a_nd alarms, 2N-304.F'B1_and 2/11-.304 r_eviewed, _8pth_apPear adeQuatel}' cemented. y~s NA y~s No _Y_es y~s y~s _NA _Y~s Yes y~s y~s Yes y~s y~s No_ y~s CQnsi~tencyh_as beeRissued30rtbis prPiect ACMP F-:indingof _Cp[1du_ctpr _S_urfa~ ~a known. USDWs _CMT v_o, jeQuate_ to circutate o.n _cOl1d_uctor & SUJtC$g _CMT v_o' jeQuate_ to tie-in Jong .string to surf csg_ _CMT wi Jyerall stringprQv[ded _..$ingprote~t$ al knowflpro_ductiye borizon_s C, T, B&_ perroafrpst re_serve pit _ _ _ _ _ tOA03 for <1bandonment be~o approved C_asiog desigos adeQua_te fpr Adequ<1te Jankage or ItaJe-drill~ has_a. Adequ<1te )\(ellbore separatjo_n -proposed Kdiverter required, does it meet_ regulations_ _Dri!liog fJujd_ program s~hematic_& equip Jist do adequat.e ifl _comments) _they meet regulation _test to _(put _C_hoke_manifold complie$ w/APlRF'-S3 (May 84) Work will occ_ur withoutoperatjon _sbutdown 8 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 Engineering Appr Date TEM 4/19/2004 þ~ psig ra_tiog appropriate; B.oPEs, _BOPEpress wells within 80R yerified (For. s_ervice well only) H2S gas_ prob.able coodjtion pt Js presence_ of Meçhanical Offset wells _2N~303 _aod 2N-304 mea$ured 2Q and_30 ppm H2S. resp~ctively,on _ 6/251Q2, EXPected r.eSel"llojr pre_ssure range_sJrprn_6,8 tp 9,] _ppg EMW; will_be drill_ed witb 9.8 ppg mud. No y~s NA _NA NA issued w/o hydrogen s_ulfide rneas_ures P~rmit. can be D_atapreseoted on potential overpres.surezones 35 36 37 38 39 Geology Date 4/16/2004 Appr SFD _S~isrnic_aflalysjs_ of shallow gas_zpoes_ -<if off-shpre) _S.eabed .conditioo survey Contact nam_elphoneJorweekly progresueports [explQratory _only] ~:;'ineering ~f J- ~m-;; r. Date: 1-1 Geologic Commissioner fJtr e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. .. :Dso (2- ~ 2. ç, ~ðf--O(P;Z **** REEL HEADER **** LDWG 04/08/18 AWS 01 **** TAPE HEADER **** LDWG 04/08/18 01 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: LISTAPE. HED TAPE HEADER TARN UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 2N-306 501032049000 ConocoPhil1ips Alaska, Inc. BAKER HUGHES INTEQ 18-AUG-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 2 G. SUTING G. RIZEK MWD RUN MWD RUN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 3 9N 7E 149.08 119.30 # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 8.500 6.750 16.000 7.625 150.0 2793.0 7605.0 # REMARKS: PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. SURFACE LOCATION: LAT: N 70 DEG 10' 13.869" LONG: W150 DEG 18' 48.531" LOG MEASURED FROM D.F. AT 149.08 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ run 2 utilized the Slim Hole Advantage Porosity Logging Service (APLS) which includes the Optimized Rotational Density (ORD), Caliper Corrected Neutron (CCN), with Multiple Propagation Resistivity (MPR), Gamma Ray, and Annular Pressure (APII) services from 2803 - 7605 feet MD (2445-5609' TVD). REMARKS: (1) Depth of 7 5/8" Casing Shoe - Logger: 2798 feet MD (2441' TVD) Depth of 7 5/8" Casing Shoe - Driller: 2793 feet MD (2438' TVD) (2) The interval from 7560 to 7605 feet MD (5581 - 5609' TVD) was not logged due to sensor-bit offset at TD. $ Tape Subfile: 1 67 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE001.HED 1 and clipped curves; all bit runs merged. .5000 START DEPTH 2793.0 STOP DEPTH 7605.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD $ BIT RUN NO MERGE TOP 2 2793.0 MERGE BASE 7605.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT 2n-306 5.xtf 150 ConocoPhi1lips Alaska, Inc. 2N-306 Tarn North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPCLM 0.0 RPM RPM RPCSLM 0.0 RPS RPS RPCHM 0.0 RPX RPX RPCSHM 0.0 RHOB RHOB BDCM 0.0 DRHO DRHO DRHM 0.0 PEF PEF DPEM 0.0 NPHI NPHI NPCKSM 0.0 ROP ROP ROPA 0.0 FET FET RPTH 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 48 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 21 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAPI 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 RHOB MWD 68 1 G/C3 4 4 7 DRHO MWD 68 1 G/C3 4 4 8 PEF MWD 68 1 BN/E 4 4 9 NPHI MWD 68 1 PU-S 4 4 10 ROP MWD 68 1 FPHR 4 4 11 FET MWD 68 1 HR 4 4 ------- 44 Total Data Records: 459 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2793.000000 7605.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 504 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 log header data for each bit run in separate files. 2 .2500 START DEPTH 2750.0 STOP DEPTH 7605.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR CCN ORD BOTTOM) TOOL TYPE DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY 29-MAY-04 MSB 18704 4.75 TC MEMORY 7605.0 2758.0 7560.0 o 46.6 52.4 TOOL NUMBER 10103633 10093523 10093523 · c MPR GRAM $ # MULT. PROP. RESIS. GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # 106032 4209 6.750 2793.0 LSND 9.75 .0 .0 350 .0 .000 .000 .000 .000 131. 0 .0 .0 .0 SANDSTONE .00 .000 .0 o BIT RUN 2 (MWD Run 2). GR/MPR/ORD/CCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/CC) DRHM - DENSITY CORRECTION (G/CC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 2n-306.xtf LCC 150 CN ConocoPhillips Alaska, I WN 2N-306 FN Tarn COUN North Slope STAT Alaska · , *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPCLM 0.0 RPSL RPSL RPCSLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0.0 DPEM DPEM DPEM 0.0 NPCK NPCK NPCKSM 0.0 ROPA ROPA ROPA 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 64 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 15 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth 10: F 15 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 BDCM MWD 68 1 G/C3 4 4 11 DRHM MWD 68 1 G/C3 4 4 12 DPEM MWD 68 1 BN/E 4 4 13 NPCK MWD 68 1 PU-S 4 4 14 ROPA MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 ------- 60 Total Data Records: 1295 Tape File Start Depth 2750.000000 Tape File End Depth 7605.000000 · , Tape File Level Spacing Tape File Depth Units 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 1403 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 04/08/18 01 **** REEL TRAILER **** LDWG 04/08/18 AWS 01 Tape Subfile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes