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HomeMy WebLinkAbout207-112CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2L-319 (PTD 207-112) Date:Wednesday, January 22, 2025 2:28:34 PM Attachments:AnnComm Surveillance TIO for 2L-319.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, January 22, 2025 1:32 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: KRU 2L-319 (PTD 207-112) Hi Chris, CPAI has concluded our monitoring of KRU 2L-319 (PTD 207-112) which is a waivered (AIO 16.003 Amended) WAG injector with WAG allowed. After charging the IA pressure and monitoring there is no evidence of IAxOA communication. The well will continue to be operated per the AIO conditions. The well’s TIO plots, bleed log, and schematic are attached. Please let me know if you have any questions or disagree with the plan. Thanks, Jaime From: Well Integrity Specialist CPF2 Sent: Wednesday, November 20, 2024 11:58 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2L-319 (PTD 207-112) Hi Chris, KRU 2L-319 (PTD 207-112) is a waivered WAG injector with WAG allowed. On review of the monthly TIOs there is indication of IAxOA while the well is on produced water injection. CPAI will conduct diagnostics and continue to monitor the well. Please let me know if you have any questions or disagree with the plan. The schematic, TIOs, and bleed reports are attached. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2L-319 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 12,517.0 2L-319 12/30/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Update tag depth 2L-319 12/31/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: T x IA ON MI. WATER INJECTION ONLY. 11/8/2012 hipshkf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.25 30.0 110.0 110.0 65.00 H-40 WELDED SURFACE 9 5/8 8.83 30.0 4,294.8 2,385.7 40.00 L-80 BTC PRODUCTION 7"x4.5" @ 12130' 7 6.28 28.6 12,963.2 5,852.3 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 26.3 Set Depth … 12,143.4 Set Depth … 5,225.7 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.20 Grade L-80 Top Connection EUE 8rd Mod ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 26.3 26.3 0.00 HANGER 11.000 FMC HANGER 3.500 510.4 510.3 2.68 NIPPLE 4.520 CAMCO "DS" NIPPLE w/ 2.875" Profile 2.875 4,737.1 2,543.4 69.52 GAS LIFT 5.390 CAMCO KBMG 2.920 8,184.0 3,698.0 69.80 GAS LIFT 5.390 CAMCO KBMG 2.920 10,962.0 4,631.2 70.90 GAS LIFT 5.390 CAMCO KBMG 2.920 11,918.2 5,072.0 49.35 GAS LIFT 5.390 CAMCO KBMG 2.920 12,000.0 5,126.5 47.34 SLEEVE 4.500 BAKER CMU SLIDING SLEEVE w/2.813" DS Profile 2.812 12,072.8 5,176.3 46.28 NIPPLE 4.520 CAMCO 'D' NIPPLE w/ 2.75" No-Go Profile 2.750 12,141.9 5,224.6 44.95 LOCATOR 4.500 BAKER LOCATOR SUB (2' above Top PBR @ 12145' DrlD) 3.000 12,142.7 5,225.2 44.93 SEAL ASSY 3.990 BAKER 80-40 GBH-22 SEAL ASSEMBLY w/ 16' Stroke w/Baker Locator Sub 2' above No GO 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 26.3 26.3 0.00 CHEM LINE .375" Encapsulated line run from CIM to Surface. Used 5 (1/2) cannon clamps and 123 full clamps. 11/1/2007 12,190.0 5,258.9 44.21 FISH Remnant of Rubber wiper plug and cmt left after cementing. Unable to C/O when running completion. 10/27/2007 0.010 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 4,737.1 2,543.4 69.52 1 GAS LIFT DMY BK-5 1 0.0 11/1/2007 0.000 7,415.8 3,448.3 70.81 2 CHEM DMY BK-5 1 0.0 11/1/2007 Chem INJ VLV 0.000 8,184.0 3,698.0 69.80 3 GAS LIFT DMY BK-5 1 0.0 11/1/2007 0.000 10,962.0 4,631.2 70.90 4 GAS LIFT DMY BK-5 1 0.0 11/1/2007 0.000 11,918.2 5,072.0 49.35 5 GAS LIFT DMY BK 1 0.0 11/29/2009 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 12,480.0 12,500.0 5,473.3 5,488.5 T-2, 2L-319 12/31/2007 6.0 IPERF HYPERJET PERFS 2L-319, 1/1/2024 5:29:50 AM Vertical schematic (actual) PRODUCTION 7"x4.5" @ 12130'; 28.6-12,963.2 FLOAT SHOE; 12,961.6- 12,963.2 FLOAT COLLAR; 12,867.5- 12,868.8 FISH; 12,190.0 IPERF; 12,480.0-12,500.0 SEAL ASSY; 12,142.7 LOCATOR; 12,141.9 SBE; 12,132.5-12,151.8 NIPPLE; 12,072.8 SLEEVE; 12,000.0 GAS LIFT; 11,918.2 GAS LIFT; 10,962.0 GAS LIFT; 8,184.0 CHEMICAL; 7,415.8 GAS LIFT; 4,737.1 SURFACE; 30.0-4,294.8 Float Shoe; 4,293.1-4,294.8 Float Collar; 4,204.6-4,206.1 CHEM LINE; 26.3 TAM Port Collar - 9-5/8"; 1,046.9 -1,049.9 NIPPLE; 510.4 CONDUCTOR; 30.0-110.0 HANGER; 30.0-32.4 HANGER; 28.6-29.8 HANGER; 26.3 KUP INJ KB-Grd (ft) 35.63 RR Date 11/2/2007 Other Elev… 2L-319 ... TD Act Btm (ftKB) 13,010.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032055200 Wellbore Status INJ Max Angle & MD Incl (°) 73.42 MD (ftKB) 2,913.12 WELLNAME WELLBORE2L-319 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2L-319 (PTD 207-112) Date:Wednesday, November 20, 2024 1:10:11 PM Attachments:AnnComm Surveillance TIO for 2L-319.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, November 20, 2024 11:58 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2L-319 (PTD 207-112) Hi Chris, KRU 2L-319 (PTD 207-112) is a waivered WAG injector with WAG allowed. On review of the monthly TIOs there is indication of IAxOA while the well is on produced water injection. CPAI will conduct diagnostics and continue to monitor the well. Please let me know if you have any questions or disagree with the plan. The schematic, TIOs, and bleed reports are attached. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2L-319 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2L-319 2024-10-01 315 515 200 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 12,517.0 2L-319 12/30/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Update tag depth 2L-319 12/31/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: T x IA ON MI. WATER INJECTION ONLY. 11/8/2012 hipshkf Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.25 30.0 110.0 110.0 65.00 H-40 WELDED SURFACE 9 5/8 8.83 30.0 4,294.8 2,385.7 40.00 L-80 BTC PRODUCTION 7"x4.5" @ 12130' 7 6.28 28.6 12,963.2 5,852.3 26.00 L-80 BTCM Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 26.3 Set Depth … 12,143.4 Set Depth … 5,225.7 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.20 Grade L-80 Top Connection EUE 8rd Mod ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 26.3 26.3 0.00 HANGER 11.000 FMC HANGER 3.500 510.4 510.3 2.68 NIPPLE 4.520 CAMCO "DS" NIPPLE w/ 2.875" Profile 2.875 4,737.1 2,543.4 69.52 GAS LIFT 5.390 CAMCO KBMG 2.920 8,184.0 3,698.0 69.80 GAS LIFT 5.390 CAMCO KBMG 2.920 10,962.0 4,631.2 70.90 GAS LIFT 5.390 CAMCO KBMG 2.920 11,918.2 5,072.0 49.35 GAS LIFT 5.390 CAMCO KBMG 2.920 12,000.0 5,126.5 47.34 SLEEVE 4.500 BAKER CMU SLIDING SLEEVE w/2.813" DS Profile 2.812 12,072.8 5,176.3 46.28 NIPPLE 4.520 CAMCO 'D' NIPPLE w/ 2.75" No-Go Profile 2.750 12,141.9 5,224.6 44.95 LOCATOR 4.500 BAKER LOCATOR SUB (2' above Top PBR @ 12145' DrlD) 3.000 12,142.7 5,225.2 44.93 SEAL ASSY 3.990 BAKER 80-40 GBH-22 SEAL ASSEMBLY w/ 16' Stroke w/Baker Locator Sub 2' above No GO 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 26.3 26.3 0.00 CHEM LINE .375" Encapsulated line run from CIM to Surface. Used 5 (1/2) cannon clamps and 123 full clamps. 11/1/2007 12,190.0 5,258.9 44.21 FISH Remnant of Rubber wiper plug and cmt left after cementing. Unable to C/O when running completion. 10/27/2007 0.010 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 4,737.1 2,543.4 69.52 1 GAS LIFT DMY BK-5 1 0.0 11/1/2007 0.000 7,415.8 3,448.3 70.81 2 CHEM DMY BK-5 1 0.0 11/1/2007 Chem INJ VLV 0.000 8,184.0 3,698.0 69.80 3 GAS LIFT DMY BK-5 1 0.0 11/1/2007 0.000 10,962.0 4,631.2 70.90 4 GAS LIFT DMY BK-5 1 0.0 11/1/2007 0.000 11,918.2 5,072.0 49.35 5 GAS LIFT DMY BK 1 0.0 11/29/2009 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 12,480.0 12,500.0 5,473.3 5,488.5 T-2, 2L-319 12/31/2007 6.0 IPERF HYPERJET PERFS 2L-319, 1/1/2024 5:29:50 AM Vertical schematic (actual) PRODUCTION 7"x4.5" @ 12130'; 28.6-12,963.2 FLOAT SHOE; 12,961.6- 12,963.2 FLOAT COLLAR; 12,867.5- 12,868.8 FISH; 12,190.0 IPERF; 12,480.0-12,500.0 SEAL ASSY; 12,142.7 LOCATOR; 12,141.9 SBE; 12,132.5-12,151.8 NIPPLE; 12,072.8 SLEEVE; 12,000.0 GAS LIFT; 11,918.2 GAS LIFT; 10,962.0 GAS LIFT; 8,184.0 CHEMICAL; 7,415.8 GAS LIFT; 4,737.1 SURFACE; 30.0-4,294.8 Float Shoe; 4,293.1-4,294.8 Float Collar; 4,204.6-4,206.1 CHEM LINE; 26.3 TAM Port Collar - 9-5/8"; 1,046.9 -1,049.9 NIPPLE; 510.4 CONDUCTOR; 30.0-110.0 HANGER; 30.0-32.4 HANGER; 28.6-29.8 HANGER; 26.3 KUP INJ KB-Grd (ft) 35.63 RR Date 11/2/2007 Other Elev… 2L-319 ... TD Act Btm (ftKB) 13,010.0 Well Attributes Field Name TARN PARTICIPATING AREA Wellbore API/UWI 501032055200 Wellbore Status INJ Max Angle & MD Incl (°) 73.42 MD (ftKB) 2,913.12 WELLNAME WELLBORE2L-319 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, October 14, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2L-319 KUPARUK RIV U TARN 2L-319 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/14/2024 2L-319 50-103-20552-00-00 207-112-0 W SPT 5225 2071120 3900 1800 1800 1800 1800 79 349 330 314 REQVAR P Josh Hunt 8/6/2024 2-Year MIT-IA Requried by AIO 16.003 Required test pressure to pass is the max anticipated injection pressure of 3900 psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U TARN 2L-319 Inspection Date: Tubing OA Packer Depth 840 4180 4060 4025IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH240806165213 BBL Pumped:8.2 BBL Returned:7.8 Monday, October 14, 2024 Page 1 of 1 9 9 9 9 99 9 9 999 99 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.14 16:27:42 -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 .58/ 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 2071120 Type Inj N Tubing 1850 1850 1850 1850 Type Test P Packer TVD 5225 BBL Pump IA 750 764 764 764 Interval O Test psi 1200 BBL Return OA 902 1308 1304 1304 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 MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:Surface casing leak detect per AIO 16.003. Witness waived by Adam Earl Notes: 2L-319 Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 2L Pad Waived Galle / Fowler 08/15/24 Form 10-426 (Revised 01/2017)2024-0815_MIT_KRU_2L-319 999 9 99 9 9 9 - 5HJJ Surface casing leak detect per AIO 16.003 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 2071120 Type Inj N Tubing Type Test O Packer TVD 5225 BBL Pump IA Interval O Test psi 1200 BBL Return OA Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 2L Pad Waived Caudle / Galle 08/27/22 Notes:Surface casing leak detect per AIO 16.003 Witness waived by Lou Laubenstein SCLD Passed per the 1000' OA fluid level criteria Notes: 2L-319 Notes: Notes: Notes: 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 Form 10-426 (Revised 01/2017)2022-0827_MIT_KRU_2L-319_OAFL AIO 16.003 Passed per the 1000' OA fluid level criteria MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 2, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2L-319 KUPARUK RIV U TARN 2L-319 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 2L-319 50-103-20552-00-00 207-112-0 G SPT 5225 2071120 3900 3450 3450 3450 3450 43 65 66 66 REQVAR P Austin McLeod 8/3/2022 Two year MITIA to MAIP. AIO 16.003 amended allowing GINJ with TxIA. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U TARN 2L-319 Inspection Date: Tubing OA Packer Depth 1510 4210 4110 4080IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220804185312 BBL Pumped:5.8 BBL Returned:5.7 Friday, September 2, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 Two year MITIA AIO 16.003 James B. Regg Digitally signed by James B. Regg Date: 2022.09.02 13:34:04 -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-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 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod ByLast Tag: SLM 12,517.0 10/7/2019 2L-319 ferguspLast Rev Reason Annotation End Date Wellbore Last Mod ByRev Reason: Tag 10/7/2019 2L-319 ferguspCasing StringsCasing DescriptionCONDUCTOR OD (in)16 ID (in)15.25 Top (ftKB)30.0 Set Depth (ftKB)110.0 Set Depth (TVD) …110.0 Wt/Len (l…65.00 GradeH-40 Top ThreadWELDEDCasing DescriptionSURFACE OD (in)9 5/8 ID (in)8.83 Top (ftKB)30.0 Set Depth (ftKB)4,294.8 Set Depth (TVD) …2,385.7 Wt/Len (l…40.00 GradeL-80 Top ThreadBTCCasing DescriptionPRODUCTION 7"x4.5" @ 12130'OD (in)7 ID (in)6.28 Top (ftKB)28.6 Set Depth (ftKB)12,963.2 Set Depth (TVD) …5,852.3 Wt/Len (l…26.00 GradeL-80 Top ThreadBTCMTubing StringsTubing DescriptionTUBING String Ma…3 1/2 ID (in)2.99 Top (ftKB)26.3 Set Depth (ft…12,143.4 Set Depth (TVD) (…5,225.7 Wt (lb/ft)9.20 GradeL-80 Top ConnectionEUE 8rd ModCompletion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 26.3 26.3 0.00 HANGER FMC HANGER 3.500 510.4 510.3 2.68 NIPPLE CAMCO "DS" NIPPLE w/ 2.875" Profile 2.875 12,000.0 5,126.5 47.34 SLEEVE BAKER CMU SLIDING SLEEVE w/2.813" DS Profile 2.812 12,072.8 5,176.3 46.28 NIPPLE CAMCO 'D' NIPPLE w/ 2.75" No-Go Profile 2.750 12,141.9 5,224.6 44.95 LOCATOR BAKER LOCATOR SUB (2' above Top PBR @ 12145' DrlD) 3.000 12,142.7 5,225.2 44.93 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY w/ 16' Stroke w/Baker Locator Sub 2' above No GO 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) 26.3 26.3 0.00 CHEM LINE .375" Encapsulated line run from CIM to Surface. Used 5 (1/2) cannon clamps and 123 full clamps. 11/1/2007 12,190.0 5,258.9 44.21 FISH Remnant of Rubber wiper plug and cmt left after cementing. Unable to C/O when running completion. 10/27/200 7 0.010 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 12,480.0 12,500.0 5,473.3 5,488.5 T-2, 2L-319 12/31/2007 6.0 IPERF HYPERJET PERFS 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 4,737.1 2,543.4 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/1/2007 2 7,415.8 3,448.3 CAMCO KBMG- LTS- CIV 1 CHEM DMY BK-5 0.000 0.0 11/1/2007 Chem INJ VLV 3 8,184.0 3,698.0 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/1/2007 4 10,962.0 4,631.2 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/1/2007 5 11,918.2 5,072.0 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/29/2009 Notes: General & Safety End Date Annotation 7/20/2008 NOTE: VIEW SCHEMATIC w/9.0 11/8/2012 NOTE: T x IA ON MI. WATER INJECTION ONLY. 2L-319, 10/8/2019 8:16:37 AMVertical schematic (actual) PRODUCTION 7"x4.5" @ 12130'; 28.6-12,963.2 FISH; 12,190.0 IPERF; 12,480.0-12,500.0 SEAL ASSY; 12,142.7 LOCATOR; 12,141.9 NIPPLE; 12,072.8 SLEEVE; 12,000.0 GAS LIFT; 11,918.2 GAS LIFT; 10,962.0 GAS LIFT; 8,184.0 CHEMICAL; 7,415.8 GAS LIFT; 4,737.1 SURFACE; 30.0-4,294.8 CHEM LINE; 26.3 NIPPLE; 510.4 CONDUCTOR; 30.0-110.0 HANGER; 26.3 KUP INJ KB-Grd (ft)35.63 Rig Release Date11/2/20072L-319...TDAct Btm (ftKB)13,010.0Well AttributesField NameTARN PARTICIPATING AREA Wellbore API/UWI501032055200 Wellbore StatusINJ Max Angle & MDIncl (°)73.42 MD (ftKB)2,913.12WELLNAME WELLBORE2L-319 AnnotationLast WO:End DateH2S (ppm) DateCommentSSSV: NIPPLE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: 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 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod ByLast Tag: SLM 12,517.0 10/7/2019 2L-319 ferguspLast Rev Reason Annotation End Date Wellbore Last Mod ByRev Reason: Tag 10/7/2019 2L-319 ferguspCasing StringsCasing DescriptionCONDUCTOR OD (in)16 ID (in)15.25 Top (ftKB)30.0 Set Depth (ftKB)110.0 Set Depth (TVD) …110.0 Wt/Len (l…65.00 GradeH-40 Top ThreadWELDEDCasing DescriptionSURFACE OD (in)9 5/8 ID (in)8.83 Top (ftKB)30.0 Set Depth (ftKB)4,294.8 Set Depth (TVD) …2,385.7 Wt/Len (l…40.00 GradeL-80 Top ThreadBTCCasing DescriptionPRODUCTION 7"x4.5" @ 12130'OD (in)7 ID (in)6.28 Top (ftKB)28.6 Set Depth (ftKB)12,963.2 Set Depth (TVD) …5,852.3 Wt/Len (l…26.00 GradeL-80 Top ThreadBTCMTubing StringsTubing DescriptionTUBING String Ma…3 1/2 ID (in)2.99 Top (ftKB)26.3 Set Depth (ft…12,143.4 Set Depth (TVD) (…5,225.7 Wt (lb/ft)9.20 GradeL-80 Top ConnectionEUE 8rd ModCompletion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 26.3 26.3 0.00 HANGER FMC HANGER 3.500 510.4 510.3 2.68 NIPPLE CAMCO "DS" NIPPLE w/ 2.875" Profile 2.875 12,000.0 5,126.5 47.34 SLEEVE BAKER CMU SLIDING SLEEVE w/2.813" DS Profile 2.812 12,072.8 5,176.3 46.28 NIPPLE CAMCO 'D' NIPPLE w/ 2.75" No-Go Profile 2.750 12,141.9 5,224.6 44.95 LOCATOR BAKER LOCATOR SUB (2' above Top PBR @ 12145' DrlD) 3.000 12,142.7 5,225.2 44.93 SEAL ASSY BAKER 80-40 GBH-22 SEAL ASSEMBLY w/ 16' Stroke w/Baker Locator Sub 2' above No GO 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) 26.3 26.3 0.00 CHEM LINE .375" Encapsulated line run from CIM to Surface. Used 5 (1/2) cannon clamps and 123 full clamps. 11/1/2007 12,190.0 5,258.9 44.21 FISH Remnant of Rubber wiper plug and cmt left after cementing. Unable to C/O when running completion. 10/27/200 7 0.010 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 12,480.0 12,500.0 5,473.3 5,488.5 T-2, 2L-319 12/31/2007 6.0 IPERF HYPERJET PERFS 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 4,737.1 2,543.4 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/1/2007 2 7,415.8 3,448.3 CAMCO KBMG- LTS- CIV 1 CHEM DMY BK-5 0.000 0.0 11/1/2007 Chem INJ VLV 3 8,184.0 3,698.0 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/1/2007 4 10,962.0 4,631.2 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 11/1/2007 5 11,918.2 5,072.0 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/29/2009 Notes: General & Safety End Date Annotation 7/20/2008 NOTE: VIEW SCHEMATIC w/9.0 11/8/2012 NOTE: T x IA ON MI. WATER INJECTION ONLY. 2L-319, 10/8/2019 8:16:37 AMVertical schematic (actual) PRODUCTION 7"x4.5" @ 12130'; 28.6-12,963.2 FISH; 12,190.0 IPERF; 12,480.0-12,500.0 SEAL ASSY; 12,142.7 LOCATOR; 12,141.9 NIPPLE; 12,072.8 SLEEVE; 12,000.0 GAS LIFT; 11,918.2 GAS LIFT; 10,962.0 GAS LIFT; 8,184.0 CHEMICAL; 7,415.8 GAS LIFT; 4,737.1 SURFACE; 30.0-4,294.8 CHEM LINE; 26.3 NIPPLE; 510.4 CONDUCTOR; 30.0-110.0 HANGER; 26.3 KUP INJ KB-Grd (ft)35.63 Rig Release Date11/2/20072L-319...TDAct Btm (ftKB)13,010.0Well AttributesField NameTARN PARTICIPATING AREA Wellbore API/UWI501032055200 Wellbore StatusINJ Max Angle & MDIncl (°)73.42 MD (ftKB)2,913.12WELLNAME WELLBORE2L-319 AnnotationLast WO:End DateH2S (ppm) DateCommentSSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg p, �� Zj�i7ZQ DATE: Wednesday, September 2, 2020 SUBJECT: Mechanical Integrity Tests P.I. Supervisor 1 ConocoPhillips Alaska, Inc. 2L-319 FROM: Lou Laubenstem KUPARUK RIV U TARN 21--319 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry � r->_— NON -CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 2L-319 API Well Number 50-103-20552-00-00 Inspector Name: Lou Laubenstein Permit Number: 207-112-0 Inspection Date: 8/3/2020 Insp Num' mitL01-200804121649 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2L-319 Type Inj W -TVD 5225 Tubing 1810 I 1810 1810 1810 PTD 2071120 Type Test SPT ''Test psi 3000 IA 580 3320 - 3220 _ 3210 BBL Pumped: 6.4 _ BBL Returned: 6.5 OA 340 602 585 575 _ - -- - - - Interval REQVAR P/F P Notes: MIT -IA to maximum anticipated injection pressure per AIO 16.003 Wednesday, September 2, 2020 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,October 03,2016 TO: Jim Regg k� P.I.Supervisor r` id) 3+1I 1(' SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2L-319 FROM: Bob Noble KUPARUK RIV U TARN 2L-319 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry�Y- -- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U TARN 2L-319API Well Number 50-103-20552-00-00 Inspector Name: Bob Noble Permit Number: 207-112-0 Inspection Date: 9/30/2016 Insp Num: mitRCN161001071102 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 2L-319 ,T W 5225 1820 1820 - 1820 1820 - well-F Type Inj TVD � Tubing " PTD 2071120 " Type Test SPT Test psi 3000 - IA 470 3300 3245 " 3240- Interval REQVAR P/F P '/ OA 360 - 610 -1 600 - 590 - Notes: AIO 16.003.MITIA every 2 year to max anticipated injection pressure.6.3 bbls pumped. i %MOB Ail 0 '7 ?Q17, Monday,October 03,2016 Page 1 of 1 I Wallace, Chris D (DOA) From: Oksness, Jolin T [Jolin.T.Oksness @conocophillips.com] Sent: Friday, September 27, 2013 10:04 AM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; Dethlefs, Jerry C Subject: Follow up Report of possible IAxOA communication Tarn Injector 2L-319 (PTD 207-112, AIO 16.003)09-27-13 Chris— After establishing a pressure differential between the IA(800 psi)and the OA(400 psi) on 09/14/13,the OA pressure continues to remain stabilized at^'400 psi over the past two weeks with minimal change over the past week. The past two weeks of IA and OA pressure data indicates that the previously reported suspected lAxOA pressure communication is likely due to thermal effects. The well will continue to remain on the monthly report and will be monitored. Please let us know if you would like us to continue with weekly reporting on this well. Please see the 2 week and 8 week TIO plots below. Regards, Jolin Jolin Oksness Well Integrity Engineer On behalf of Problem Wells Supervisor ConocoPhillips Alaska, Inc. r Office (907) 659-7224 SCMI$E° (c) (907) 230-7493 1 0 • WELL TRENDS 2L 319 PRODUCED WATER NJ ., VA LAIE _ CURRENT VALOR CURRENT VALUE OPERATOR NOTES _ _SET CHOKE MAK RATE DO NOT VAC --- 1 I M I N RAT E i I , 7000 t 1000 . , . 1600 , . . . . . I . . . , , 1400 ,i." 1000 — - , I • •00 . , ....; . . 600 400 , I 2110 0 — I , . I . ER scA LE DESc PICK VALUE LATEs T PLOT DURAT I col 336.00 u Rs, 211411M4,34111,066 I!iii 19.7 18.7 *vs UM ' s NE 111J PRES -------1 M IIMI I NJ TEMP N NI W11 PRES I NI IOU RATE 1 PR ORI F.OF PM I A PRES • mil OA PRE 1547. 129. 1547. 1174. 10. 111,1. 120361: 845. 410. 393. 1115:2;. 111111M115 MINOR MAJOR TIME It EME wDeAYE it, ZOOM ‹. > >> 72-MEP-13 20.47 4.2 Pir rusnorr Iffir ,,SURLY 1 Pr m Mr A I I.Y _..1 2 • 110 WELL TRENDS 2L 319 PRODUCED WATER 1NJ VALUE CURRENT VALUE COMMENT %m0 OPERATOR NOTES SEI ('HON} MAX IRATE DO MOT VAG MIN RAIE 2000 1 1 i 1000 le 1600 ii 117/41 1400 ..,,, ....,,,, , ' r f 1200 , 1 , , k / 1 V ' ' 1000 1 ' goo 404 11111110111101IN my l 001/40.1%01.1A,Il i 11 it 400 vildlipil 1 200 r Iv I. vinevN.I.."I'ver.f>, ,•, a , , I : ER SCALE DKSC PICK VALDE LATEST PLOT DURATION Atitainks 12.-EEP-13 i0:01 IIII •NU 111.1 PRES 18.7 1547. 18.7 111m "62. II MINEIBIONS MINOR TIME PR > DMZ ::: TEMP 1:::: 1:::: IN WH PRES 1547. 1562. t:c, 22-SSP-I3 20.4742 IN ORIF-DP OM IA PRES • 10. .64. II. MAJOR TIME WEEK 845. ZOOM MIN Pr I NsirAhrr Flor IantLy- lor Plir NILE NE OA PRES 4111. 392. 3 Wallace, Chris D (DOA) From: Wallace, Chris D(DOA) Sent: Friday, September 13, 2013 10:09 AM To: 'NSK Problem Well Supv' Subject: RE: Report of possible IAxOA communication Tam injector 2L-319(PTD 207-112,AIO 16.003) 09-12-13 Kelly, With an AA already in place for the TxIA and now a potential IAxOA,this places this well into a potential 1 barrier position. Please continue to monitor and provide a weekly update so that we can determine a path forward as soon as possible. Thanks and Regards, SCAN MAY 1 2@15 Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent:Thursday, September 12, 2013 10:39 PM To: Wallace, Chris D (DOA) Subject: Report of possible IAxOA communication Tarn injector 2L-319 (PTD 207-112, AIO 16.003) 09-12-13 Chris Tarn injector 2L-319(PTD 207-112,AIO 16.003)is demonstrating possible IA x OA communication based on TIO trends. The well is currently waivered for TxIA communication while on gas only. It was recently returned to injection on July 24,2013 after having been offline since December 7,2012. The OA pressure rise,following several recent OA bleed events,may have been thermally induced and the IA and OA pressures may be incidental. CPAI proposes that the well remain online to be monitored and establish sufficient differential which will either refute or confirm the possible IA x OA communication. It is already on the monthly report per AIO 16.003. 1 dwa jjajoilo 0 0) 0 o N N- a ,► , I, I ,I 11 , I, .1 , I , I, I ,I H, I ,I , I , I, .1,,,I , I, (1) (1)j{ � "" r 7 T- Q o) N CO• C., I,. CD• LH4L•• co p 0 i.1 N - • __ oi _ o • . - C eL . N • - • YI, IIIiII1I , •.l , , I � Q0 0 0 0 0 0 USO o T o 4 ISd Let me know if you have any questions. Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone(907)659-7224 Pager(907)659-7000 pgr 909 3 ID • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 May 15, 2012 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 L — 3/'? Commissioner Dan Seamount: Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU), and the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped in the spring of 2012. The corrosion inhibitor /sealant was pumped in the months of April and May 2012. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 5/15/2012 1C,1D,1E,2L,3H PAD • Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API ,# PTD # cement pumped _ cement date inhibitor sealant date ft bbls ft gal - 1C-133 50029230130000 2010770 16" 3.9 12" 5/8/2012 6.8 5/14/2012 1D-116 50029229150000 1981720 10" 1.2 10" 5/8/2012 4.3 5/15/2012 1E-123 50029232080000 2040740 5" n/a 18" n/a 5.1 4/9/2012 2L -304 50103206130000 2100110 31" 0.30 20" 3/30/2012 _ 4.3 5/14/2012 2L -306 50103206300000 2101820 8" n/a 8" n/a 3.4 5/14/2012 2L -310 50103206160000 2100280 25" 0.25 12" 3/30/2012 2.6 5/14/2012 2L -312 50103206260000 2101640 13" n/a 13" n/a 2.5 5/14/2012 2L -319 50103205520000 2071120 112" 1.00 20" 3/30/2012 6 5/14/2012 2L -320 50103206270000 2101660 36' 1.00 50" 3/30/2012 3.4 5/14/2012 • 3H -17 50103200810000 1870990 19" n/a 19" n/a 3.4 4/9/2012 U MEMORANDUM TO: Jim Regg P.I. Supervisor ~ ~ ~~I 3~ j~, FROM: Bob NOble Petroleum Inspector n LJ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 10, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2L-319 KUPARUK RIV U TARN 2L-319 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~- Comm Well Name: KUPARUK RIV U TARN 2L-319 Insp Num: mitRCN100809165449 Rel Insp Num: API Well Number: 50-103-20552-00-00 Permit Number: 207-112-0 Inspector Name: Bob Noble Inspection Date: 8/8/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~'' 2L-319 ' Type Inj. ~'~' TVD 5225 jA 230 I 2150 ~ 2080 2060 P.T.Di 2071120- ITypeTest SPT Test psi ~ 2150 '' QA 361 482 458 457 . Interval4YRTST p~F, P Tubing 1300 1300 1300 1300 Notes: rn ~~~~ , ~ ~c~ -(-~ t- f~ S ~ ~~ r ~t: ~`k ~ ..._ .." ~-' .. i j ~ t ` Tuesday, August 10, 2010 Page 1 of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@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 / 2L DATE: 08/08/10 OPERATOR REP: Colee /Coleman - AES AOGCC REP: Robert Noble Packer Depth Pretest Initial 15 Min. 30 Min. Well 2L-305 Type Inj. G TVD 5,244' Tubing 3,740 3,740 3,740 3,740 Interval 4 P.T.D. 1982400 Type test P Test psi 1500 Casing 2,390 3,230 3,200 3,200 P/F P Notes: OA 325 340 330 330 Well 2L-317A Type inj. W TVD 5,350' Tubing 1,100 1,100 1,100 1,100 Interval 4 P.T.D. 2002100 Type test P Test psi 1500 Casing 850 1,830 1,780 1,770 P/F P Notes: OA 250 375 375 375 Well 2L-319 Type Inj. W TVD 5,225' Tubing 1,300 1,300 1,300 1,300 interval 4 P.T.D. 2071120 Type test P Test psi 1500 Casing 230 2,150 2,080 2,060 P/F P Notes: OA 361 482 458 457 Well 2L-323 Type Inj. W TVD 5,237' Tubing 2,100 2,100 2,100 2,100 Interval 4 P.T.D. 1982510 Type test P Test psi 1500 Casing 800 2,800 2,750 2,740 P/F P Notes: OA 400 525 500 500 Well 2L-329A Type In'. N TVD 4,899' Tubing 1,500 1,500 1,500 150 Interval 4 P.T.D. 1982250 Type test P Test psi 1500 Casing 520 2,270 2,200 2,200 P/F P Notes: OA 900 900 900 900 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA yy i ~ (('~r ~~ TYPE INJ Codes TYPE TEST Codes D =Drilling Waste M =Annulus Monitoring G =Gas P =Standard Pressure Test I =Industrial Wastewater R =Internal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D =Differential Temperature Test ~~i~ o 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 2L Pad 08-08-10.x1s • _. h :-: ;`~:~ `, _ ~ _ ; ~. ~, ~~*, ~' ~.9 ~~ ~ MICROFILMED 6/30/2010 DO NOT PLACE. ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: ~ DATE: Thursday, April O1, 2010 Jim Regg '1, P.I. Supervisor ~ ~~ `f ~ t I(ti SUBJECT: Mechanical Integrity Tests CONOCOPHII,LIPS ALASKA INC 2L-319 FROM: John Crisp KUPARUK RIV U TARN 2L-319 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: KUPARUK RIV U TARN 2L-319 Insp Num: mitJCr100227174311 Rel Insp Num: API Well Number: s0-103-205s2-00-00 Permit Number: 207-112-0 Inspector Name: John Crisp Inspection Date: 2/26/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2L-319 Type Inj. ~'~' TVD 522s IA 1500 2s00 2440 2400 y' P.T.D zo~llzo TypeTest SPT Test psi Isoo pA aso sso sso sso Interval ~IT~- p/F P .~ Tubing Izoo Izoo voo loo Notes: No problems witnessed. ~,~~` AQ It ~ ~" ~ ~ ~~ Thursday, April O1, 2010 Page 1 of 1 • Conoco~illips i Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907)659-7535 Fax: 659-7314 REC~IV~C~ February 1, 2010 Dan Seamount AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7`~ Ave. Ste. 100 Anchorage, AK 99501 FHB o ~ zo~a ,kieak~ p~ ~ bas Cons. Cottmtis>;ion An¢Merage Dear Mr. Seamount, ConocoPhillips Alaska, Inc. has converted 2L-319 a Tarn production well. Enclosed you will find 10-404 Report of Sundry Well Operation for ConocoPhillips Alaska, Inc. for Tarn we112L-319 (PTD 207-112). This report records the conversion from producer to WAG service. If you have any questions regarding this matter, please contact myself or Robert D. Christensen at 659-7535. Sincerely, Darrell R. Humphrey Attachments RECEIVED _ • • FEB 0 4 2010 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION d~Ske 0~ ~ bas Cans. Co`rsrtission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q OIL to WAG Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Conversion Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2.Operator Name: 4. Current Well Status: . Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 207-112 3. Address: Stratigraphic ^ Service ^ .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20552-00 7. KB Elevation (ft): .Well Name and Number: RKB 145' 2L-319 8. Ptoperty Designation: .Field/Pool(s): ADL 380052, 380051 Kuparuk River Field / Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured ~. 13010' feet true vertical ~ 5891' feet Plugs (measured) Effective Depth measured 12190 feet Junk (measured) true vertical 5259 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16" 110' 110' SURFACE 4265' 9-5/8" 4295 2386' PRODUCTION 12133' 7" 12163 5240' PRODUCTION 800' 4-1/2" 12963 5852' Perforation depth: Measured depth: 12480' - 12500' true vertical depth: 5474' - 5489' Tubing (size, grade, and measured depth) 3-1/2", L-80, 12159' MD. Packers &SSSV (type & measured depth) PKR =Baker 80-40 GBH-22 Seal Assy 12143' SSSV =NIP 510' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 368 509 5 544 217 Subsequent to operation 5990 840 1500 14. Attachments .Well Class after proposed work: Copies of Logs and Surveys run _ ' Exploratory ^ Development ^ Service Daily Report of Well Operations X .Well Status after proposed work: Oil^ 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 NiA if C.O. Exempt: 309-406 Contact B. Christensen/ D. Humphrey Printed Name Darrell R. Humphrey Title Production Engineering Specialist Signature Phone: 659-7535 Date 2 - /. /~ ' ~~~IVM~ tttf U 5 ZQ'~Q 'T.y.~~ Form 10-404 Revised 04/2004 ~ ~~~~ Submit Original Only ~ 1 LJ • 2L-319 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/28/09 11/29/09 11 /30/09 .01/25/10 SET 2.75" CAT SV @ 12073' RKB. PULL OV @ 11918' RKB. SET DV @ 11918' RKB. ATTEMPT TO OPEN CMU @ 12000' RKB. IN PROGRESS. PULL DV @ 11918' RKB. CIRCULATE 406 BBLS DIESEL TBG & IA. SET DV @ 11918' RKB. IN PROGRESS. CLOSE CMU @ 12000' RKB. MIT TBG **PASS**, PULL 2.75" CAT SV @ 12073' RKB. COMPLETE. TAG @ 12, 518', SET 3" INJECTION VALVE ON 2.75" C-LOCK @ 12,073' RKB. COMPLETE. .) ~-'~ r KUP ~ 2L-319 COIIOCOP~'II~~IPS ell Attributes x An le 8 MD TD ali,iin,1 li 1. Wellbore API/UWI Fieltl Name Well Statue Incl (°) MD (RNB) 501032055200 TARN PARTICIPATING AREA INJ 73.42 2,913.12 Act Btm (RKB) "' Comment H23 (ppm) Date SSSV: NIPPLE Annotation End Gale KB13r0 (R) Last WO: 35.63 Rig Release Date 11/2Y2007 Wsll Con : -2L-318 72920103'.53'. meat-ACdnl 25 PM An notatbn Depth (1tK8) End Date Annotation Last Mo d ... Entl Data Last Tag: SLM 12,518.0 1/25/2010 Rev Reason: TAG, GLV ClO, Set INJ VLV Imosbor 1/29/2010 Casio Strin s HANGER, 26 _ _. Casing Description CONDUCTOR String 0... 16 String ID ... 15.250 Top IttlcB) 0.0 Sel Depth (f... 110.0 Set Deptn (TVD) ... 110.0 String Wt... 65.00 String ... H-40 String Top Thrd Casing Daecriptlon SURFACE String 0... 95/8 String ID ... 8.835 Top (rtNa) 0.0 Set Dapln (f... 4,294.8 Sel Depth (TVD) ... 2,385.8 String Wt... 40.00 String ... L-80 String Top Thrtl BTC Casing Daecriptlon PRODUCTION String 0... 7 String ID ... 6.276 Top (Po(B) 0.0 Set Depth (/... 12,963.2 Sat Depth (TVD) ... 5,852.3 String Wt... 26.00 String ... L-80 String Top Thrd BTCM Tubin Strin s - - - - - - - - - - - Tubing Deacripnon String 0... String ID ... Top (ftKB) Set Depth (r.. Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 3 1/2 2.992 0.0 12,158.8 5,236.7 9.20 L-80 EUE 8b Mod Com le tion Details ~ . q Top (rtNB) Top Depth (TVD) (RNB) Top Intl (°) Ibm Daecriptlo n Comment Nomi... 10 (In) CONDUCTOR 26.3 26.3 -0.01 HANGER FMC HANGER , o-110 TD 110 510.4 510.3 2.30 NIPPLE CAMCO "DS" Nipple w/ 2.875" Profile 2.875 , 12,000.0 5,127.5 47.75 SLEEVE 31/2" CMU Slidirg Sleeve w/2.813" DS Profile 2.812 NIPPLE, 510 12,072.8 5,176.3 46.31 NIPPLE 3 1/2" CAMCO "D" Nipple w/ 2.75" No-Go Profile 2.750 12,141.9 5,224.8 44.95 LOCATOR Baker Locator Sub (2' above Top PBR @ 12145' D11D) 3.000 - 12,142.7 5,225.3 44.93 SEAL ASSY Baker80-40 GBH-22 Seal Assy w/ 16' Stroke w/Baker Locator Sub 2' above No GO @ 12139' 3.000 Other In Hole Wlrelirte retrievable lu a valves um fish etc. Top (fINB) rop Daptn (TVD) (RKB) lop Intl (°) Deacriptlon Comment Run Data ID (In) SURFACE, a-/ 29s 12.073 5,176.5 46.31 VALVE 3" A-1 INJECTION VALVE (1"BEAN) (HKS-239) on 2.75" CLOCK 1125/2010 1.000 12,190 5,260.2 45.31 Cement Wipe Plug 8 Cmt r Remnant of Rubber wiper plug and cmt left after cementing. Unable to GO when running completion. 10127/2007 0.010 GAS LIFT, 4,737 Pertoratlons & Slots Top (RNB) etm (RNB) Top (TVD) (RNs) arm (7VD) (RNB) Zona Deb soar Dane Ien... Type Comment 12,480 12,500 5,473.5 5,488.6 12131/2007 6.0 IPERF HYPERJET PERFS CHEMICAL, 7,1,6 Notes: General 8 Safe End Date Annotaton 11/26/2007 NOTE: 12163' Begin T' Production Casing Taper. 12183' Begin 4.5" Produc~on Casing to 12963' 7/2012008 NOTE: VIEW SCHEMATICw/9.0 GAS LIFT, 8,101 GAS LIFT, 10,962 GAS LIFT, 11,919 SLEEVE, 12,000 NIPPLE, 12,073 VALVE, 72,073 LOCATOR, 72,112 SEAL ASSY, 12,143 Mandrel Details Stn Top (RI(B) Top Oepth (TVD) (RNB) Top Intl 1°) Make Model OD lln) Serv Valve Type Latch Type Port Site tin) TRO Run (pep Run Date Com... 1 4,737.1 2,543.3 69.52 CAMCO K BMG 1 GAS LIFT DMY BKS 0.000 0.0 11/1/2007 IPERF, 12,480.12,500 Camenl Wlpar Plup 6 Cml 2 7,415.8 3,448.4 70.81 CAMCO K LT BMG- SCry 1 CHEM DMY BK-5 0.000 0.0 11/1Y2007 Chem INJ VLV , 1z,19D 4. 3 8,184.0 3,698.0 69.80 CAMCO K BMG 1 GAS LIFT DMY BKS 0.000 0.0 11/1/2007 4 10,962.0 4,631.3 70.90 CAMCO K BMG 1 GPS LIFT DMY BKS 0.000 0.0 11/1/2007 5 11,918.2 5,072.2 49.35 CAMCO K BMG 1 GAS LIFT DMY BK 0.000 0.0 11l29I2009 PRODUCTION, 0.72,903 SEAN PARNELL, GOVERNOR AIASKA OIL AND GALS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMHSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Robert D. Christensen Production Engineering Specialist ConocoPhillips Alaska, Inc. P.O. Box 100360 ® � �__� Anchorage, AK 99510 Re: Kupar-uk River Field, Tam Oil Pool, 2L-319 Sundry Number: 309-406 4tPANNED OF 2 2 2009 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 4 n Comi DATED this /—? day of December, 2009 Encl. Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit, NSK -69 PO Box 196105 ConocoMilli fib Anchorage, AK 99519 -6105 Phone: (907) 659 -7535 Fax: 659 -7314 December 3, 2009 RECEIVE Tom Maunder, P.E. DE 0 7 7 Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission ��$� ��' ; Anchorage mis io�� Anchorage 33 W. 7' Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. requests approval to convert Tarn Well 2L -319 from Oil Production service to WAG Injection service. Enclosed you will find 10 -403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. for 2L -319 (PTD 207 -112). If you have any questions regarding this matter, please contact myself or Darrell R. Humphrey at 659 -7535. Sinc A a Robert D. Christensen Attachments RECEIVED • �ti'� • DEC 0 1 2000 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska 011 & Gas C ons. C011irrlission APPLICATION FOR SUNDRY APPROVAL Anchorage 20 AAC 25.280 1. Type of Request: Abandon ❑ Suspend ❑ Operational Shutdown ❑ Perforate ❑ Waiver ❑ Other Q Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ OIL to WAG Change approved ram g ❑ Re -enter Suspended Well Conversion g pp program ❑ Pull Tubing Perforate New Pool ❑ p ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 • Exploratory ❑ 207 - 112 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20552 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and'Number: where ownership or landownership changes: Spacing Exception Required? Yes ❑ No F±1 2L -319 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 380052, 380051 RKB 145'• Kuparuk River Field / Tarn Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13010' 5891' 12190' 5259' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16" 110' 110' SURFACE 4265' 9 -5/8" 4295' 2386' PRODUCTION 12133' 7" 12163' 5240' PRODUCTION 800' 4 -1/2" 12963' 5852' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12480'- 12500' 5474'- 5489' 3 -1/2" L -80 12159' Packers and SSSV Type: Packers and SSSV MD (ft) PKR = Baker 80 -40 GBH -22 Seal Assy 12143' SSSV = NIP 510' 13. Attachments: Description Summary of Proposal P 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: Dec 18, 2009 Oil ❑ Gas ❑ Plugged ❑ Abandoned ❑ 17. Verbal Approval: Date: WAG Q GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: B. Christensen/ D. Humphrey Printed Name Robert D. ristensen Title: Production Engineering Specialist Signature Phone: 659 -7535 Date Commission Use Only Sundry Numb r: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: Wi 4_ rte � /VI / I r / /� f'�•'�, o�pe� %o7, ih c Subsequent Form Required: s ) r APPROVED BY roved by: CO NER THE COMMISSION Date: - - — �06/ - -- �� - /Z /O o°j - -- - - /z /ymitin Duplicate- 2L -319 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Tarn Well 2L -319 from Oil Production service to WAG Injection service.Well 2L -319 was completed in the Tarn Bermunda formation on November 2, 2007 as a pre - producing injector with initial production commencing on March 5 2008. Conversion to Injection service is required due to potential reservoir depletion. Well 2L -319 injection will provide pressure support to offset producer 2L -311. The 16" Conductor was cemented with 9 cu. yards High Early. The 9 -5/8" Surface casing (4295' and / 2386' tvd) was cemented with 943 sx Class "G ". The 7" x 4 -1/2" Production casing (12963' and / 5852' tvd) was cemented with 485 sx Class 'G ". The Top of the Bermuda T -3.1 was found at 12284' and / 5327' tvd. The SCMT -CB CBL performed on December 31, 2007 indicates good continuous formation quality bond from 12188' and (5258' tvd) to 12314' and (5349' tvd). The injection tubing /casing annulus is isolated via Baker 4 -1/2" x 7" 80 -40 GBH -22 Seal assembly located @ 12143' and / 5225' tvd. An MIT -IA was last performed on 11/30/09; MITIA 3000 psi, 15 minutes, Passed - An MIT -T was last performed on 12/13/07; MITT 2690 psi, 30 minutes, Passed e p 2L -319 ConocoPhillips Well Attributes Alaska, Inc. We nbore APVUwI Fleltl Name weu statue Incunanon (•) MD (RKB) Total Depth (RKB) 501032055200 TARN PARTICIPATING ARFA PROD 73.42 2,913.12 110.0 Comment 112S (ppm) Date Annotation End Data K8-Grd (R) Rig Release Data NIPPLE 0 7/1/2008 Last WO: 35.63 11/2/2007 Well C-fi : -21L319 &24200& 12:25:21 PM hamatc - Actual Annotation Depth (ttKB) End Data Annotation End Data Last Tag: 12,452.0 6/19/2008 Rev Reason: TAG TD 7/20/2008 Casing Strings _ Caning Description OD (In) ID (In) Top IRKS) Set Depth (ft.. Set Depth (N) ( DR.. Grade Top Co. neclion HANGER, 25 CONDUCTOR 16 15.250 0.0 110.0 110.0 65.00 H-40 -' Casing Descriptlon OD (in) ID (in) Top (INKS) Set Depth (ft.. Set Depth (TVD) (R... Wt libe /... Guide Top Con nectlon SURFACE 95/8 8.835 0.0 4,294.8 2,385.8 40.00 L -80 BTC °] Caeing Descript.— DO(in)ID(in) Top IRKS) Set Depth (ft.. Set Depth (TVD) pt... Wt(the /...Grade Top Connection ® PRODUCTION 7 6.276 0.0 12,963.2 5,852.3 26.00 L -80 BTCM Tubing Strings --- - - - - -- - -- Tubing Deacrlptlon OD (In) ID (In) Top (R.. Set Depth(fIK... Set Depth (TVD)(ftKB)Wt(Ibs /R) Grade Top Connection TUBING 31/2 2.992 0.0 12,158.8 5,236.7 9.20 L -80 EUE ,rd Mod Completion Details Top(RKEI)l Item Description Comment ID (In) 26.3 HANGER FMC HANGER 510.4 NIPPLE CAMCO "DS" Nipple w/ 2.875" Profile 2.875 CONDUCTOR, 12,000.0 SLEEVE 31/2" CMU Sliding Sleeve w/2.813" DS Profile 2.812 as I as asset 0 -110 12,072.8 NIPPLE 3112" CAMCO "D" Nipple w/ 2.75" No-Go Profile 2.750 12,141.9 LOCATOR Baker Locator Sub (2' above Top PBR @ 12145' DrID) 3.000 NIPPLE, 510 12,142.7 SEAL ASSY Baker 80-40 GBH -22 Seal Assy w/ 16 Stroke w /Baker Locator Sub 2' above No GO @ 3.000 12139' Other In Hole Wireline retrievable plugs, valves, pumps, fish etc. Top (ftKB) Descrlpton Comment I Run Data I ID (in) 12,190.0 Cement Wiper Remnant of Rubber wiper plug and cm! left after cementing. Unable to C/O 10/27/2007 0.010 Plug 8 Cmt when running completion. Perforations SURFACE. Top "m 0.4295 Top 131- (ND) (TVD) Dens (RKB) (RKB) (RKB) (RKB) Type Zone (aho... Data Comment 12,480.0 12,500.0 5,473.51 5,488.6 IPERF 1 1 6.0 12/31/2007 JHYPERJFTPERFS GAS LIFT. Notes: General & Safe aso 4,737 End Dats Annotation 11/26/2007 NOTE: 12163' Begin 7" Production Casing Taper. 12183' Begin 4.5" Production Casing to 12963' 7/20/2008 NOTE: VIEWSCHEMATICw/9.0 CHEMICAL, 7.416 GAS LIFT, 5.184 GAS LIF r, 10.962 GAS LIFT 11 91B SLEEVE. 12,000 NIPPLE, 12,073 LOCATOR, 12,142 Mandrel Details SEAL ASSY. Set Depth Port 12.143 T (TVD) Valve Latch Size TRO Run Stn IRKS) (RKB) Make Model OD (in) Type Typa lint (psi) Run Date Comment 1 4,737.1 5,236.7 CAMCO KBMG 1 DMY SK -5 0 0.0 11/1/2007 3 , 2 7,415.8 5,236.7 CAMCO KBMG- LTS -CIV 1 DMY BK -5 0 0.0 11/112007 Chemical � INJ VLV 3 8,184.0 5,236.7 CAMCO KBMG 1 DMY BK -5 0 0.0 11/1/2007 IPERF, 4 10,962.0 5,236.7 CAMCO KBMG 1 DMY BK -5 0 0.0 11/1/2007 12,480- 1z.5Do camentwiper 5 5,236.7 CAMCO KBMG 1 OV BK 5/16 0.011/26/200 Plug a Cmt, 12,190 PRODUCTION, 0- 12,963 I M■■I ■MI1■MMI�IG■I "1MM ».la ��� =ON WAMMMM� M■■I1•id�JiiMlll■IM■ i�•- ■■��� M■■1 ■MIl■MMIj IMM ■II MINI MMM mosemmmmmimmmmpAm mmm Alt UNNEI M■ ■1■Mll■MMIlMMi►�MM iD�!■ A M■■1■MM■MMIMI>•MMNn MMMM M■■1■MII■MMIMmMM1WA r - - IMMMi Masi ■Mll■MmMMMM►SA<> MMMM mmmm M■ ■r /MILIMM+M \MG:Q I�MMM , M■ ■I■MII ■M Mm,MlJM M■■I ■MmmwmrIM l 7M MMM ' M■■1■MIl■mmm mram MMM M■ ■1■Mn■MMimA MMt■� MMM 1� M■ ■1■Mmmwm MIsM MMM � M■ ■1■MII■M MMM '. 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Zaro7 l.•su NM9ER aLL DATA TD : 13 a! o.3M.. S8 ( TM; = BTD : Iz 14 0 ?•ID SZ TVD a'` a s ir. g : "xY yi " ' Shoe : ` ?_ & 3 MD S k- 7 — TVD ; DV: JM Shoe: MD TVD ; TOP . HD " "7 U i. ^.g: acker M TVD; Set at .ale Size and Perfs 1248 to /ZSo CN.�.N 1NTEGR3'TY - PART 11 Annulus Press Test: :.'F 5aa_; 15 min __•_ ; 30 Comments: ` �M r T I Iq r. r� / _ 36��,«;,�, •- Ell -(A 3a� p s aK. s - .�..,..,_. _. .. ..�...._._ _._. '.JECHIiC ?� 7NTEGRITT - PART 4 2 C t a s s sTI Cement Volumes r Amt. L;Lnar Gag J 86f.5 DVS. N Cmt vol to cover aer.:s _._....r ..._..._.� C 9ti -yam Z f�a� = iZ�� 3- �86r Theorecical TOC 'T'O L Q- /� 3da µD Cement Bond Log ea r No) In AOGCC File_ ^� CBL Evaluation, zone above perfs �7� �" �a� -e-• Production Log: T_ppe i Evaluation CONCLUSIONS: ? # 3 : ��`-�� e s sy.Q M (T /� -f8 k4P Or - ` f� a s w¢ 2: tea- . /Z• /d'6� WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 2L-319 May 20, 2009 AK-MW-527495 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 2L-319 2" x 5" MD TRIPLE COMBO Logs: 50-103-20552-00 2" x 5" TVD TRIPLE COMBO Logs: 50-103-20552-00 2" x 5" MD BAT Logs: 50-103-20552-00 ,~Ll?J~iS'4 X54 ~1~~.!. ~ ~' &~5,+~! 2" x 5" TVD BAT Logs: 50-103-20552-00 Digital Log Images 50-103-20552-00 1 Color Log 1 Color Log 1 Color Log 1 Color Log 2 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~ -~~~ ~ ~b4~~ DATA SUBMITTAL COMPLIANCE REPORT 11 /24/2008 Permit to Drill 2071120 Well Name/No. KUPARUK RIV U TARN 2L-319 Operator CONOCOPHILLIPS ALASKA INC APt No. 50-103-20552-00-00 MD 13010 TVD 5891 Completion Date 12/31/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint Well Log Information: ° Log/ Electr Data Digital Dataset Log Log Run Interval OH / T pe Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey 30 13010 Open 12/3/2007 Directional Survey 30 13010 Open 12/3/2007 ~ pt Report: Final Well R 0 0 Open 1/8/2008 Final Well Report, Table of Contents, Equip & ~, CrewWell Data, Geo Data, Pres/Form Data, Drilling Data, Daily Reports, Form Logs C Pdf 15832 Report: Final Well R 0 0 Open 1/8/2008 Final Well Report, Table of Contents, Equip & CrewWell Data, Geo Data, Pres/Form Data, Drilling Data, Daily Reports, Form Logs all in PDF graphics og See Notes 2 Col 403 13010 Open 1/8/2008 MD Formation Log ~ Log See Notes 2 Col 403 13010 Open 1/8/2008 TVD Formation Log ~.og See Notes 2 Col 403 13010 Open 1/8/2008 MD LWD Conbo Log ~og See Notes 2 Col 403 13010 Open 1/8/2008 MD Gas Ratio Log See Notes 2 Col 403 13010 Open 1/8/2008 TVD Gas Ratio og See Notes 2 Col 403 13010 Open 1/8/2008 MD Drilliong Dynamics ~og See Notes 2 Col 403 13010 Open 1/8/2008 TVD Drilliong Dynamics Rpt LIS Verification 175 12995 Open 1/31/2007 LIS Veri, RPM, RPD, RPS, RPX, FET, GR, ROP, ~~ NPHI, DRHO, NCNT, ~ FCNT, RHOB DATA SUBMITTAL COMPLIANCE REPORT 11 /24/2008 Pe..rmi/t to Drill 2071120 Well Name/No. KUPARUK RIV U TARN 2L-319 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20552-00-OD My~ 13010 TVD 5891 Completion Date 12/31/2007 Completion Status 1-OIL Current Status 1-OIL UIC N ~E/ _ - - _ __ -__ _ _ _ --- ---- -- _ _ ----- - D C Lis 15862 Induction/Resistivity 175 12995 Open 1/31/2007 LIS Veri, RPM, RPD, RPS, ~, RPX, FET, GR, ROP, NPHI, DRHO, NCNT, / FCNT, RHOB i~C:q~ Cement Evaluation 5 Col 1 11867 12824 Case 2/22/2008 CBL, SCMT-CB, Temp, ___ Pres 31-Dec-2007 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y 1~ Daily History Received?pr,",~, Chips Received? 1~'>tt" Formation Tops Analysis fihtJ~ Received? Comments: Compliance Reviewed By: _ Date: _ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ,t % V j~- ~„ , r ^.' 02/20/08 N0.4595 ~i~:' ~ s f Aid Company: Alaska Oil 8~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Field: Kuparuk Date BL Color CD 2L-319 11970619 SCMT _ ( 12131107 1 1A-02 11994615 INJECTION PROFILE / - 02/11/08 1 1F-10 11994616 INJECTION PROFILE - / 02112/08 1 2X-08 11996603 INJECTION PROFILE 2C ~. - ~~ 02/13/08 1 3N-11 11968841 INJECTION PROFILE T - t'J~ 02116/08 1 1J-152 11994623 PRODUCTION PROFILE (o - / 02/18/08 1 2W-17 N/A SBHP SURVEY '~ - ~'~ 02/20/08 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • WELL LOG TRANSMITTAL To: State of Alaska January 24, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~" Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 2L-319 AK-MW-5274952 1 LDWG formatted CD Rom with verification listing. API#: 5 0-103 -205 5 2-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE fiRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 9,9518 ~a ~ -; .~ ~„ ,. _- ~--:. 1;. ~;?~~ Date: ~~ Signed: ~c~-- t ~ a ~` l spa JAN-27-2008 10 40 D~ i WELLS ~ 907 265 1336 P.01 Brink, Jason A Frvm: Maunder, Thomas E (DOA) [tom.maunderQa[aska.govj Sent: Friday, January 25, 2008 8:44 AM =~~° To: Brink, Jason A Subject: RE: 2L-319 (207-112) `)~ ~'~~~ ~laxka Vii! Gas ;;~~~r.. . Jason, Thanks for the info. Gould you rescan the documents or just fax them (276-7542)? When I pr~ft~ ' ccupy several pages. Tom From: Brink, Jason A [mailto:]ason.Brink@conocophillips.GOm] Sent: Thursday, January 24, 2008 11:07 AM To: Maunder, Thomas E (pQA) Subject: FIN; 2L-319 (207-112) Tom Attached are the cement summaries from the surface and production casing. They will answer your questions. Reciprocation was maintained until the cement was in place. The cement plug was not bumped but we were able to displace half the shoe track volume. The plug hung up in the tapered string cross-over and required a dedicated cleanaut run to get the production tubing seals stung into the cross-over bare. Coiled tubing performed a cleanout inside the 4-112" liner and had no troubles getting to bottom. It appears that the cement plug hung up, lost some rubber fins, then blew on through into the liner. 3ason Brink Drilling Engineer Greater Kupartik Area ConocoPltillips Alaska, Inc. Office :907265-6419 Ce11 :907-748-4826 Fax :907-265-1535 From: Maunder, Thomas E (DOA) [mdilto:tam.maunderCa~alaska.gov] Sent: Wednesday, ]anudry 23, 2008 4:46 PM To: Brink, 3ason A Subject: 2L-319 (Z07-11Z) Jason, I am reviewing the completion report for the well. A couple of questions/requests ... 1. How much cement was circulated on the surface jab? That information is not included in the summary. 2_ Gould you provide the cementing report for the tapered production string? 3. I am curious about the comment included in the tapered cementing description. Was reciprocation stopped prior to the cement exiting the shoe? Were thEre any difficulties encountered? X /28/20Q8 JAN-27-2008 10 40 1~ i WELLS Thanks in advance. CaA or message with any questions. Tam Maunder, PE AQGCC 907 265 1336 P.02 1/28/2008 JRN-27-2008 10 40 Rig: NORDIC 3 9 1~ i WELLS Daily Drilling Report 2L-319 TARN PARTICIPATING AR(*A ~ 18.33 26.0 lulative Mud Cost Dally Cost Tbta1 346,945.91 540,801.41 AFE Dur Total (days) Projected Job Duration (days) 907 265 1336 P.03 Security L®vel: Developr 0.00 Actual start uaze 9/30/2007 ~ryrnpr apuu rraw 10/612007 30,6$ 5.01 25.67 Fast Casing string Next Casing OD On) Next Casing Set Deptk Production, 12,863.2ftK6 r„_ Ops antl DBpth ~ Morning Report ,~ 24hr Fgrecast 5" tbg. & run same. Finish tally &. drift 3 Rig up to run completion. M T Last ~ah~~ry Finish running in hole w/ 7" csg- CBU t~ Cement same, Load pips] shed w/ 3.5" tbg. While freeze protect 9 518" X 7"annulus. ~ ' ~~ General Remarks w~me Temp 18 deg. Wind E 21 CI= 1 deg. No Accidents. Na Spills. Itla' _ upervisOr David Morris, Rig Supervisor Rig Supervisor Dink Heim, Rig Supervisor Rig Supervisor Andy Anderson, Tour Pusher Tour Pusher Shane McGeehan, Tool Pusher Tool Pusher 44.0 Time 6 ~" Sta+t Entl Dur~ Titres DoP~+s~art epthEnd . Time Time (hrs) Phase 0 carte 4pSub~Code P-N-T Trbl Cede Tibl Glass. (ftK9) (nres) 0 araiion 00:00 01:00 1.00 GOMPZN CASING CIRC P _ 13,010.0 13,010.0 PJSM Circulate Casing Volume ~ 10,248' M0; 68 BPM ~ 600 PSI; PU 224K SO 65K 01:00 02:30 1.50 GOMPZN CASING ~ RNCS P ~~ ~~~ 13,010.0 13,010-0 RlH WI T' Casing f/ 10,248' - 11,726' MD; PU 250K SO 75K 02:30 04:00 1.50 COMPZN CASING CIRG P 13,010.0 13,O1p.0 Circ Casing Volume ~ 91,726' MD; 6 BPM s~ 650 PS! 04:00 05:00 1.00 COMPZN CASING RNCS P 13,010,0 73,010.0 RIH W/ 7" Gasing f/ 11,726' - 12,982' MD; PU 305K SQ 77K 05:D0 06:30 1,50 C4MPZN CASING RNCS P ~ 13,010.0 13,010.0 M/U and RIH Wl 7" Gasing Hanger; Rig Down Gasing Running Tools and R/U Circ Head. Final depths =Shoe 12,960, Float collar 12$$6 ft, S8E 12131 ft. 06:30 07:30 1.00 CCMP2N GASING CIRC P 13,010.0 13,010.0 Circ Staging Pumps Up as Follows: 2 BPM ~ 350 PSI, 3 BPM ~ 390 PSI, 4 SPM ~ 480 PSI. 5 BPM (~ 560 PSI 07:30 08:00 0.50 COMPZN CEMENT KURD P ~ ~ 13,010.0 13,010.0 RID Circ Head and Load Plug and R/U Cementing Head 08:00 10:00 2.00 COMPZN GEMENT CIRG P ~ 13,010.0 13,070,0 Reciprocate Casng and Circulate 5 BPM ~ 560 PSI & Batch Cmnt 10:00 12:00 2.00 GOMPZN CEMENT DISP P 13,010.0 13,010.0 PJSM, fast lines 3500 psi, Cement 4 112" Production String, 94 bbis, 485 sks "G", fl 12991' -11,300' MD (T4C); Displaced w/ 478 BBLS Drilling Fluid. Plug did not bump. Pump Calculated 112 shoetradc. I~eCip pipe until just before Cmt. Seat hgr, pipe sticking. ICP ~ 545 psi 15 bpm, FCP = 687 psi 15 bpm. No cmt to Surface, 12'00 12:30 O.SO COMPZN CEMENT OTHR ~P ~ L/ ' 73,010 0~ 13,u~u.u`Gnectc rtoau ~uocxi~ i ic:JV iva~ a.vu ~.vrvir civ ..+~,.,~.., .., .,.. 8r Lines and Blow Dawn ame; arrga Out Bales 15:30 18:00 2.50 GOMPZN CEMENT QTHR P ~ 13,010,0 13,010.0 PJSM-load 3.5" tbg. in pipe shed. drain & wash bop stack. Install packpff on 7" & test same to 5000 psi- dK BOP Tsst Data Report Number: 26 Report Date: 10/2512007 13,D10.0 ~ 13,010.0 re Cost 4,470,813.37 J ProjectaC Job End Datt 10/26/2007 00:00 Page 1!2 Report Printed= 9/28/2008 JAN-27-2008 10 41 'ittl@ Lo ` 6tflrt End Time Timo "HR P 93,010.0 93,010.0 Free2e protect 9 5/B X annu u5 diesel while loading pipe Shed w/ 3.5" completion string. Casng@ out upper pipe rams to 3-5"- YIUtl GI1@GIS Qe[e '" YP (raEC 110s) HTHP Fil! DOrlsity Temp Solids, Cerr. .Gel (10m G41(~m) (°F) (°+l) Depth {!!1(B) Dens Ib/ I) ~S (sl 1 PV Cfllc (Cp)' (Ibf1100R') (ID1/100ft=) mU30mkn) pH (Ibf17IXMP) (Ibf11001!') . MBT IDIbDf) ( 5 $•: 0 $ 0 Hater 13,010.0 - 9.70 41 8,0 14.000 5.0 . . 8.0 9.000 15.0 3ased Mud Nat@r 13,010.0 9.70 39 7,0 16.000 8.0 8.0 9.040 2Q.0 0.0 9.0 5•; 3ased Mud JV@Ilbores Nellbore Nasr~9 WeEldore /API-uWi 501032055200 Sect4on 2L-3t9 xe m) Act Ta fIK6 Act Bun fll tari Da(e . EM Date 0 9I4l200~ 9l2l2~7 910 ~CRQ1 16 p,0 . SURFAC 12 1/4 0.0 10/6/2007 fi@$Irl Strirt 5 Ce5at9 DflRriplrort Rwt Date (in) tiYt IDa/r!) CommfltX G~ado set Depth (ftK9) Production 10!25/2007 7 26.00 L-80 12,983.2 FINAL: 9" x 4-112" Tapered String: 7" Casing to 12130' - 4" ID Seal Bore from 12132' t0 12152' - 4-1f2" Casing to 12983'. i WELLS ~ 907 265 1336 P.04 Security Levei: Devefopmenti Daily Drilling Report 2L°'319 Report Number: 26 tig: NQRDIC 3 Report Dat@: 10/25/2007 ,m® Depth Start Depth nd re On Code 0 Sub-Code P-N 7 7r1~ Cvdb Trb1 Cl~a, (ttK$) (fIKB) Oper!#lian~„~ " 7" ( wl PBgB ~2 Report Pririt@d: i/as-xaos~ JAN-27-21708 10 41 Surface Gasieg Gement Com~rit Had approx 310 bbls Dement returns to surface. Cement Sta Sta ~ 1 Description ~ Objective ~~ Surface Gasing Cement Full cement job to surface. Q (start) (~Untin) Q (end) (bbllmin) 4 (avg) (bb' 6 q 5 rnt Ffulds ~ rYPb Cement _ tt'/sack) 4.45 i .JELLS Cement Det2fi! Report ~L-319 0.0 ial} (psi) 400.0 0.0 907 265 1336 P.05 SurFace Casing Cement enting start Gate Cementing End Gate Welrbore Name 10112/2007 08:00 10112/2007 12:15 2L-318 .,_ 1,208.0 (Iblgal) 10.70 Tail Cement 1,208.0 4,305.0 Yield (ft'/saGk) Mix H2O Ratio (gaNSa... FrA® Water (°~6) Density (Iblgaq a,47 12.00 Additives _ .~.. nn (itKB) Full Retum7 C t Rtr ... ToA Plug? Btm Plug 4,285.0 Yes 305.0 ~ Yes Yes np) (psi) Rgcip? Straka (fq Rotated Pipe RPM (rl 1,1$0.0 Yes 15.00 NO , plug Drilled Ou a KB) Drill Out Diameter (Irt) ~Amourrt jsacks) Ctass - vorume pumpetl~iC 680 G 532.0 263 ~ G ~ 74.0 JAN-27-2008 10 41 ~G i WELLS ~ 907 265 1336 P.06 Cement Detail Report 2L-319 Production Casing Cement Cement Details Description Cementing Start Dato Csn-enting Entl Date Welibore Name ProduUlon Casing Cement 10!24/2007 09:45 10125/2007 12,30 2L-319 Comment Pumped 50 BBL CW-100, Pumped 50 BBL Mud Push II, PumP~ 94 BBL 15.8 PPG Class G Cement Slurry, Displaced Cement w/ 5 66! Water Spacer and 478 BBL Drilling Mud Using 5lumberger Pumps, DID NpT Bump Plug; WOC Time 6 Hrs. Cement 5 es S B 1 ~~ Bottom {ttK8 Full Roturn7 Cmnt Rtrn (--- Top PIug7 Stm PIUg7 Dsscliptlon QbJeetWe Top (ftKB) ~ No Yes Production Casing Cement 4 112" Tubing 11,300.0 12,994.0 No 0.0 Cement and 7 "Tubing to 11,300' "~'- MD q (start) (bbllmin) (GI (end) (bbllmin) Q (avg) (bbllmin) P (floe!) (psi) P (bumph (psi) - eoip ~ trDke {tt) Rotated? Pipe RPM ppm) 3 ,~ g 5 ,^ a07.0 _ Yes 15.00 No Dept ~~~ {gKg) Tag Method Depth Plug Drill9tl t To ( Drill Out Dlam6t0r (In) ..~ -~.~- cammsnt Cemented 4 1/2" Tubing and 7 "Casing ;Cement Slurry 94 BBLS and Displaced w15 BBL F(2b Spacer and 478 BBL of Drilling Mud; Did Not Bump ug Cement Fluids ~ Additives. Fluid volume Pumpgtl (bbl Fluid Type Fluld DesCripGOn Estimated Top (ttK8) Est Btm (hKB) Amount {sacks) Class Primary Cement 11,300.0 12,994,0 485 G 94.0 Yleld (it !sack) Mix~F120 Ratio (gauss.-- Frea Water (°~) Density (Iblgaq Plastie viscosity (cp) Thickening Tlme (hra) CmprStr 1 (psq 1.17 5.20 15.80 6.D0 ,_ Dispersant Additive Gas Biock Atltli@ve Retarder cancsntratl 0.2 CpnCelitl'atf 0.4 C6nCentrat 2.0 tancentrat 0.05 %BWOC Unit label t3nlt [abet rySBWOC TOTAL P.06 ConocoPhillips January 21, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 2L-319 Dear Commissioner: Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~~~~I~' JAN 2 ~ 2,00 Ataska Oil ~ ~~ Ca~+~~ CQm~'ts~i°~ Anch~ra~ ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the Kuparuk Tarn well 2L-319. If you have any questions regarding this matter, please contact me at 265-6830 or Jason Brink at 265-6419. Sincerely, ~--___ ~ ~--~-a R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad RE~~ev~ ~~~ STATE OF ALASKA ~ ~A~I ~+ ~ ~~Q~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPO~~`~~~`~"`"~~` ~~ 1a. Well Status: Oil a Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25,110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development Q Exploratory ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~~, , ~9 ~i X47 or Aband.: 12. Permit to Drill Number: 207-112 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: /.yy•b'%" October 6, 2007 13. API Number: 50-103-20552-00 ° 4a. Location of Well (Governmental Section): Surface: 199' FNL, 777' FEL, Sec. 22, T10N, R7E, UM 7. Date TD Reached: October 21, 2007 ~ 14. Well Name and Number: 2L-319 Top of Productive Horizon: 867' FSL, 1048' FEL, Sec. 13, T10N, R7E, UM 8. KB (ft above MSL): 145' ~ Ground (ft MSL): 115' .: 15. Field/Pool(s): Kuparuk River Field Total Depth: 916' FSL, 594' FEL, Sec. 13, T10N, R7E, UM 9. Plug Back Depth (MD + TVD): 12190' MD / 5259' TVD Tarn Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 460873 - y- 5927648 Zone- 4 10. Total Depth (MD + TVD): 13010' MD / 5891' TVD 16. Property Designation: ADL 380052, 380051 TPI: x- 471166 y- 5928667 Zone- 4 Total Depth: x- 471620 - 5928714 - Zone- 4 11. SSSV Depth (MD + TVD): nipple @ 510' MD / 510' TVD 17. Land Use Permit: 4600, 4599 18. Directional Survey: Yes Q No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 1320' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/Res, SCMT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING 51ZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.6# H-40 30' 110' 30' 110' 24" 9 cu. yds High Early 9-5/8" 40# L-80 30' 4295' 30' 2386' 12.25" 68o sx Class G, 263 sx Class G 7" x 26# x L-80 30' 12163' 30' 5240' 8.75" 485 sx Class G 4.5" 12.6# L-80 12163' 12963' 5240' 5852' 8.75" included above 23. Open to production or injection? Yes No / If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 12142' none - 12480'-12500' MD 5473'-5489' TVD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 12480'-12500' 149617# of 16/20 carbolite 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) waiting on facility hook-up Date of Test Hours Tested Production for Test Period -> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (core) 27. CORE DATA Conventional Core(s) Acquired? Yes No / Sidewall Cores Acquired? Yes No / If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~_ CG~;i=~.~ t fLi DR7'E NONE ~,.•3/.~ it~i~?ED Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ~ ~-23-(~ . ~ ~t~a~ :j~,l~ :~ ~ ~OOti 28. GEOLOGIC MARKERS (List all formations and mar s encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes / No If yes, list intervals and formations tested, Permafrost -Top surface surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1400' 1320' needed, and submit detailed test information per 20 AAC 25.071. C-80 4253' 2371' C-50 8780' 3901' C-40 9930' 4284' T-7 11772' 4982' T-3.1 12284' 5327' T-3 12299' 5338' T-2 12462' 5460' C-35 12588' 5556' K-3 12610' 5573' Top Esker 12689' 5634' N/A Formation at total depth: T-3.1 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Brink @ 265-6419 Printed Na Rand @ a Title: Drillino Team Leader ~ / l 2 L d Signature ` `~6 S_ 6 ~ 3 ~ Date INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection., Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. ~' Ct~rtota-Phillips Time Log Summary WelN~ew Web Rayo~Yfnq Well Name: 2L-319 Job Type: DRILLING ORIGINAL Time Logs _ ___ _ _ _ Dale From To Dur S. Death E De th Phase Code Subcoc~e T COM 09/30/2007 08:00 00:00 16.00 0 0 DEMOB MOVE DMOB P Stand by with rig crews while waiting on rig matts to move rig from 2N pad to 2L pad. Wait on CPF 2 to stage vehicles. Rig matts are tied up moving Do on 141. 10/01/2007 00:00 00:00 24.00 0 0 DEMOB MOVE MOB P PJSM-Moving Nordic rig 3 from 2N pad to 2 L Pad 3.2 miles on Matting boards. 10/02/2007 00:00 00:00 24.00 0 0 DEMOB MOVE MOB P Moving Nordic rig 3 from 2N pad to 2L pad on matting boards. Move is 3.2 miles 10/03/2007 00:00 00:00 24.00 0 0 DEMOB MOVE MOB P Moving Nordic rig 3 from 2N pad to 2L ad on mattin boards. 10/04/2007 00:00 10:00 10.00 0 0 MIRU MOVE MOB P Moving Nordic rig 3 from 2N pad to 2L pad on matting boards. Arrive on 2L ad 10:00 hrs. 10:00 18:00 8.00 0 0 MIRU MOVE OTHR P Tubescope inspection of sub, foot beam & welds on damage thru move. Installing 4" nipples on conductor in cellar. 18:00 19:00 1.00 0 0 MIRU MOVE OTHR P PJSM-install foot beam & hang tree in cellar. 19:00 20:30 1.50 0 0 MIRU MOVE OTHR P PJSM-Move rig over well # 2L-319 Spot & level same. (RIG ACCEPTED 2030 hrs. 10-4-07 20:30 00:00 3.50 0 0 MIRU MOVE RURD P Rig up diverter & diverter line & spot service buildin s. 10/05/2007 00:00 05:00 5.00 0 0 MIRU MOVE RURD P Rig up flow line riser & continue to s of sevice a ui ment. 05:00 09:30 4.50 0 0 MIRU MOVE OTHR P Load pipe shed with 5" drill pipe. Drift & tall same. 09:30 11:00 1.50 0 0 MIRU MOVE OTHR P Pick up-make up & stand back 5"drill i e in derrick. 11:00 12:00 1.00 0 0 MIRU MOVE SFTY P Attend pre spud meeting. 12:00 17:00 5.00 0 0 MIRU MOVE OTHR P PJSM-Continue racking 5" Drill Pipe in derrick. 17:00 17:30 0.50 0 0 MIRU MOVE OTHR P Function test diverter & koomey draw down. (Witness diverter test waived by Bob Noble AOGCC 17:30 00:00 6.50 0 0 MIRU MOVE OTHR P Continue make up & stand back 5" DP. Load BHA in shed. Make up & stand back 5" HWDP. Prepare pipe shed for 9 5/8" cs . 10/06/2007 00:00 11:30 11.50 0 0 MIRU MOVE OTHR P Load 9 518" csg. in pipe shed. Drift & tall same. I~ _ Pa~{~ 1 cf 1 J Time Logs _ _ _ Date From To Dur S De th E Depth Phase_ Code Subcode T COM _ __ _ j 10/06/2007 11:30 13:00 1.50 0 0 MIRU MOVE OTHR P PJSM-Make up 12 1/4" bit to mud motor & stabilizer. Scribe & orient. Make u UBHO sub. 13:00 14:00 1.00 0 0 MIRU MOVE OTHR P PJSM-Load 9 5/8"slips & elevators on floor with crane. 14:00 16:00 2.00 0 0 MIRU MOVE OTHR P PJSM-Hang wireline sheave. Rig up gyro. Inspect all equipment prior to s ud. 16:00 18:00 2.00 0 225 SURFA DRILL DRLG P S ud well. Tag fill @ 90'. Drlg. from 0' to 225' MD. 18:00 21:00 3.00 225 225 SURFA DRILL PULD P POH. Make up MWD-orient. Make up flex collars. 21:00 00:00 3.00 225 457 SURFA DRILL DDRL P Drlg. from 225' to 457' MD. PP 880 psi 162 spm 480 gpm tq 2000 on 1800 off rpm 60 wob 10k up wt 65k do 65k rot 65k. ART 1.69 AST .55 hrs. 10/07/2007 00:00 09:30 9.50 457 974 SURFA DRILL DDRL P Drlg. 12 1/4" Directional hole from 457' M D to 974' M D. 09:30 12:00 2.50 974 925 SURFA DRILL OTHR P Work out dog leg from 818' to 925' MD 920 ND. Tq 3030 on 2420 off rpm 60 wob 10k spm 155 gpm 460 up 80k rot 80k do 80k. 12:00 00:00 12.00 925 1,606 SURFA DRILL DDRL P Drlg. 12 1/4" Directional hose from 925' to 1606' MD. PP 1300 162 spm 480 gpm up wt. 90k do 80k rot 85k tq 4000 on 3000 off rpm 60 wob 25-30k. ART 1.72 hrs. AST 6.85 hrs. MAX GAS 2735 units. 10/08/2007 00:00 05:30 5.50 1,606 2,043 SURFA DRILL DDRL P Drlg. 12 1/4"directional hole from 1606' MD to 2043' MD 1641' ND Up wt 87k do 70k rot 75k 05:30 06:30 1.00 2,043 2,043 SURFA DRILL CIRC P Pump sweep & CBU X 2 06:30 07:00 0.50 2,043 2,043 SURFA DRILL CIRC P Pump dry job-blow down top drive & fill tri tank. 07:00 09:30 2.50 2,043 84 SURFA DRILL TRIP P POH from 2043' MD to 84' MD. 09:30 11:30 2.00 84 84 SURFA DRILL OTHR P Down load MWD-upload MWD. Increase choke size. 11:30 13:00 1.50 84 0 SURFA DRILL OTHR P PJSM-Change bend in motor from 1.85 de . to 1.5 de . 13:00 15:30 2.50 0 2,043 SURFA DRILL TRIP P RIH with BHA #2 to 2043' MD. 15:30 00:00 8.50 2,043 2,795 SURFA DRILL DDRL P Drlg. 12 1/4" Directional hole from 2043' MD to 2795' MD. 1893' ND. Tq on 5800 off 3800 up 90k do 73k rot 77k PP 2100 si r m 60. 10/09/2007 00:00 12:00 12.00 2,795 3,715 SURFA DRILL DDRL P Cont Drill f/ 2795' - 3715' MD (2195' ND) ONBTorq 8010 ft-Ibs, OFBTorq 7270'. WOB 15 - 30 klbs, 90 rpm, 2100 psi, PU 95 klbs, SO 75 klbs. ROTWt 77 klbs. 12:00 19:00 7.00 3,715 4,305 SURFA DRILL DDRL P Cont drill f/ 3715' - 4305' MD (2645' ND Surf Cs TD. PU 105 klbs, SO 75 klbs, ROT Wt 85 klbs, ONB Torq 9000 ft-Ibs, OFB Tor 7500 ft-Ibs. E'age ~ taf'{3 ~~ Time Logs _ _ __ Date From To D_ur _S Depth E. Depth Pha e Code Subcode__T _ COM 10/09/2007 19:00 20:30 1.50 4,305 4,305 SURFA DRILL CIRC P Circulate and condition mud. Pump wtd sweep @648 gpm, 2100 psi. Est hole volume 15% excess. 20:30 21:00 0.50 4,305 4,305 SURFA DRILL OTHR P Blow down top-drive, monitor well, stable. Pre are for short tri . 21:00 23:00 2.00 4,305 4,305 SURFA DRILL TRIP P POOH f/ 4305' - 2043'. Hole condition ood, ro er tri volume. 23:00 00:00 1.00 4,305 4,305 SURFA DRILL TRIP P RIH f/ 2043' - 4216'. 10/10/2007 00:00 01:00 1.00 4,305 4,305 SURFA DRILL TRIP P Finish TIH after short trip. Break circulation and wash last stand. 01:00 02:00 1.00 4,305 4,305 SURFA DRILL CIRC P Circulate w/ reciprocate pipe and rotate. Large amt of clay blinded shaker and auger, causing 1 gal spill to pad. Clay plugged off flow line. Shovel spilled mud and contaminated gravel into rock washer. Work on cleanin flow line. 02:00 02:30 0.50 4,305 4,305 SURFA DRILL CIRC P Finish cleaning clay and circulate at slow rate w/ reci and rotate i e. 02:30 07:00 4.50 4,305 4,305 SURFA DRILL CIRC P Circulate and condtion mud in preparation for POOH to run 9 5/8" surface casing. Stage up pump rate to full drlg rate ,w/initial heavy clay returns. At clean-up, circ and cond mud. 07:00 09:30 2.50 4,305 4,305 SURFA DRILL CIRC P Cont. circ and cond mud @ 610 gpm / 2050 si. 09:30 11:00 1.50 4,305 4,305 SURFA DRILL TRIP P Blow down top drive, POOH f/ 4305' - 2890'. 11:00 12:00 1.00 4,305 4,305 SURFA DRILL TRIP P RIH f/ 2890' - 4305'. 12:00 13:30 1.50 4,305 4,305 SURFA DRILL CIRC P MUTD, break circulation. After est full rate, um wtd hi-vis swee . 13:30 14:00 0.50 4,305 4,305 SURFA DRILL OWFF P BDTD, monitor well. 14:00 14:30 0.50 4,305 4,305 SURFA DRILL TRIP P POOH f/ 4305' - 3836'. 14:30 15:00 0.50 4,305 4,305 SURFA DRILL CIRC P Pump dry job. 15:00 19:00 4.00 4,305 4,305 SURFA DRILL TRIP P POOH f/ 3836' - 80'. Noted tight hole conditions from 2000' -surf, able to pull on elevators. Decision made to DL MWD, RIH for final C/O run. 19:00 22:30 3.50 4,305 4,305 SURFA DRILL PULD P DL MWD. clean clay off BHA and bit, inspect bit, OK. UD float, and directional package of MWD for swap w/ new w/fresh battery. Upload MWD, finish MU BHA and RIH t/ 2040'. 22:30 23:00 0.50 4,305 4,305 SURFA DRILL CIRC P CBU, ramp up rate to 621 gpm. At bottoms up unloaded large amount of cla in returns. 23:00 00:00 1.00 4,305 4,305 SURFA DRILL TRIP P Cont TIH f/ 2040' - 4216'. l~a~e' zap ~~ i Time Logs - _ -- - --- _-- Date From To Dur S De th E. be th Phase Code Subcode T COM 10/11/2007 _ 00:00 02:00 2.00 4,305 4,305 _ SURFA DRILL CIRC P Circ /CBU, pump wtd hi-vis sweep, CBU. Noted no excess clay or other on BU. Prepare to POOH. Observe well. 02:00 02:30 0.50 4,305 4,305 SURFA DRILL CIRC P Pump dry job. BDTD. 02:30 03:00 0.50 4,305 4,305 SURFA DRILL OTHR T Lose high-line at start of trip out of hole. Start rig generators/;SCR, diagnose power issues. Determine problem w/ highline power provided to rig and camp. Decide to stay on rig ower. 03:00 08:30 5.50 4,305 4,305 SURFA DRILL TRiP P Pull 5 stands, monitor well, stable, install wiper rubber cont POOH to BHA. 08:30 10:30 2.00 4,305 4,305 SURFA DRILL PULD P DL MWD, POOH and UD BHA. Flush Mud Motor, la out. 10:30 13:30 3.00 4,305 4,305 SURFA CASIN RURD P Clear /Clean floor, RU casing crew to run 9 5/8" casin . 13:30 22:00 8.50 4,305 4,305 SURFA CASIN RNCS P Run 9 5/8" 40# L-80 BTC csg t/ 3625' w/ stops at 560', 1290', 1044' & 2830' to break circulation. 22:00 23:00 1.00 4,305 4,305 SURFA CASIN( CIRC P CBU w/ ramp rate up to 6 bpm @ 380 si. No loss / no ain. 23:00 00:00 1.00 4,305 4,305 SURFA CASIN RNCS P Conn RIH w/ 9 5/8" Csg f/ 3625' - 4250'. 10/12/2007 00:00 00:30 0.50 4,305 4,305 SURFA CASIN( RNCS P Finish RIH w/ 9 5/8" csg U 4295', wash last jt t/ bottom, hole condition good. Total csg string as follows: Flt Shoe (1.7'), 2 jts csg (87'), Flt Clr (1.5'), 79 jts csg (3154'), TAM Port Clr (2.95'), 24jts csg (1014.5'), FMC Fluted Csg Hngr (2.35'). All casing 9 5/8" 40# L-80 BTC. Centralizers installed as follows: (2) Turbolizers @ 1~t on shoe track, (11) BS Cent @ 1/conn f/ 3774' - 4161', (2) BS @ 1 ea side TAM Port Clr, (2) Turbolizers tandem @ 500', (2) BS w/ 1 @ 75', & 1 120'. 00:30 01:00 0.50 4,305 4,305 SURFA CASIN CIRC P Circulate and recip csg at reduced rate w/ RD casers, clear floor and re are to install cmt head. 01:00 02:00 1.00 4,305 4,305 SURFA CASINO RURD P Land csg, break out fill-up tool, LD. Blow down top drive, install cmt head adapter, install cmt head, line up to start circulatin . 02:00 04:00 2.00 4,305 4,305 SURFA CASIN CIRC P Circulate and treat mud properties per program in preparation for cementing operations. Slowly ramp pump rate up in 1 b m increments to 6 b m. 04:00 04:30 0.50 4,305 4,305 SURFA WELCT EQRP P SD w/ re-install riser. Hooked same w/ csg mandrel w/ reciprocating csg and disconnected same f/ diverter. 04:30 08:00 3.50 4,305 4,305 SURFA CASIN CIRC P Continue circulate @ 6 bpm w/ conditioning mud for cementing ops w! ri in u cementers ~_ _~ i~~g~ ~ rr~'13 Time Logs _ _ T COM Date From To Dur S De th E De th Phase Code Subcod e 10/12/2007 08:00 12:00 4.00 4,305 4,305 SURFA CEMEh _ _ _ DISP P _ Connect cementers, PJSM, P-test lines t/ 3500 psi. Cement 9 5/8" csg as follows: 50 bbls wash, 49 bbls 10 ppg spacer, drop bottom plug, 532 bbls, 10.75 ppg Lead, 74 bbls 12 ppg Tail, drop top plug, Displace 20 bbls water, switch to rig pumps, finish displace w/ rig pumps. Bump plug w/ 1180 psi. Hold 10 min, check floats, OK. 9 5/8" casing cemented into lace at 1200 hrs. 12:00 17:00 5.00 4,305 4,305 SURFA CEME RURD P R/D clean cement eq. RD casing equip, bails, remove cmt head, UD and landin ~t, flush stack. 17:00 21:00 4.00 4,305 4,305 SURFA WELCT NUND P N/D diverter & flow line. Note intermittent gas / cmt perk up back side of cs . 21:00 00:00 3.00 4,305 4,305 SURFA WELCT NUND P N/U starting head & spool. 10/13/2007 00:00 02:00 2.00 4,305 4,305 SURFA WELCT NUND P Finish install and test of wellhead. Orientation of same verified b/Mike Alston, Pad Operator. Note increase of ercolation and cmt flow back in Ilar. Suspend NU activities to dia nose same. 02:00 05:00 3.00 4,305 4,305 SURFA WELCT OWFF P Monitor cellar area for cmt flow back and gas w/develop strategy to mitigate. Flow back decreased. Pump out cellar and observe. 05:00 11:30 6.50 4,305 4,305 SURFA WELCT NUND P Continue NU activities w/ monitoring cellar. AOGCC Inspector notified at 0500 hrs of pending BOPE test. C/O UPR & LPR t/ 5". Prepare to test ROPE. 11:30 16:30 5.00 4,305 4,305 SURFA WELCT BOPE P Test all BOPE to 250/3500 psi. Test witnessed by John Crisp w/ AOGCC. All components w/ exception of HCR OK. HCR re aired, retested, OK. 16:30 23:30 7.00 4,305 4,305 SURFA DRILL PULD P Load, strap and tally 5" DP in pipeshed for next hole section. Install wear bushin in wellhead. 23:30 00:00 0.50 4,305 4,305 SURFA DRILL PULD P UD (2) stands HWDP from surface BHA. 10/14/2007 00:00 06:00 6.00 4,305 4,305 SURFA DRILL PULD P PU and RIH w/ 5" DP. 06:00 09:00 3.00 4,305 4,305 SURFA DRILL TRIP P POOH rack 5" DP in derrick. 09:00 10:30 1.50 4,305 4,305 SURFA DRILL PULD P PJSM, RIH w/singles t/ 1229'. 10:30 12:00 1.50 4,305 4,305 SURFA DRILL TRIP P PJSM, POOH f/ 1229' and rack in derrick. 12:00 12:30 0.50 4,305 4,305 SURFA CASIN( DHEQ P RU and perform quick pretest on casing to 2500 psi prior to RIH w/ BHA to confirm TAM closed. 12:30 14:30 2.00 4,305 4,305 SURFA DRILL PULD P PJSM, PU BHA. ~~ge ~ ~it'I3 ~ ~ Time Logs _ __ Date From To Dur S De th E. De th Phase Code Subcode T COM_ 90/17/2007 00:00 06:00 6.00 7,805 8,245 PROD1 DRILL DDRL P _ _ Drill ahead f/ 7805' - 8245' MD. Make Dir corrections and um swee s x 2. 06:00 12:00 6.00 8,350 8,685 PROD1 DRILL DDRL P Drill ahead f/ 8245' - 8685' MD (3867' TVD). PU 163 klbs, SO 83 klbs, RotWt 102 klbs. ONBTorq 14.37k ft-Ibs, OFB Torq 13.27k ft-Ibs. ECD's 11.4 ,Max Gas 69 units. 12:00 00:00 12.00 8,685 9,455 PROD1 DRILL DDRL P Drill ahead f/ 8685' - 9455' MD(4127' TVD). PU 155 klbs, SO 87 klbs, RotWt 115 klbs. ONBTorq 11 k ft-Ibs, OFBTorq 10.8k ft-Ibs. ECD's 11.78, Max Gas 75 units. 10!18/2007 00:00 03:30 3.50 9,455 9,734 PROD1 DRILL DDRL P Drlg f/ 9455' - 9734' MD. Note increase in pump pressure and ECD's, um wtd swee . 03:30 04:30 1.00 9,734 9,734 PROD1 DRILL CIRC P Circ w/ recip and rotate pipe w/ circ out swee . 04:30 05:00 0.50 9,734 9,766 PROD1 DRILL DDRL P Drill f/ 9734' - 9766' MD. Unable to achieve proper flow rate due to pump liner/ ressure restrictions. 05:00 06:30 1.50 9,766 9,766 PROD1 DRILL CIRC P Pump sweep, CBU and prepare for short trip to csg shoe. Sweep returns 2-3% increased cuttings. Fluid caliper indicates au a hole. 06:30 07:00 0.50 9,766 9,766 PROD1 WELCT OWFF P Flow check, well static. 07:00 11:00 4.00 9,766 9.,766 PROD1 DRILL WPRT P PJSM, POH wiper trip to 9-5/8 shoe at 4272 ft. Wellbore exc cond. No swab / ain /loss. Normal u dra . 11:00 14:00 3.00 9,766 9,766 PROD1 RIGMN SVRG P Flow check, PJSM, slip - cut drlg line, service top drive. C/O pump liners t/ 5". 14:00 14:30 0.50 9,766 9,766 PROD1 DRILL CIRC P CBU @540 gpm, slight clays to shaker. 14:30 18:00 3.50 9,766 9,766 PROD1 DRILL WPRT P Flow check, PJSM, RIH wiper trip t/ 9660'. 18:00 18:30 0.50 9,766 9,756 PROD1 DRILL REAM P Wash last stand t/ bottom f/ 9660' - 9766', 540 m, SPP 2800 si. 18:30 00:00 5.50 9,756 9,993 PROD1 DRILL DDRL P Drill ahead f/ 9766' - 9993' MD (4305' TVD) PU 160 klbs, SO 95 klbs, RotWt 125 klbs, ONB Torq 11k ft-Ibs, OFB Torq 9.6k ft-Ibs. Max ECD 11.04, Max Gas 81 units. Flow 615 m. 3010 si. 10/19/2007 00:00 06:00 6.00 9,993 10,500 PROD1 DRILL DDRL P Drill ahead f/ 9993' - 10500'. SPM 250, SPP 3000, Flow 615 m. 06:00 10:30 4.50 10,500 10,888 PROD1 DRILL DDRL P Drill ahead f/ 10500' - 10888' MD (4607' TVD. Pump Hi-Vis Sweep. PU 180 klbs, SO 100 klbs, RotWt 118 klbs, 10:30 11:00 0.50 10,888 10,888 PROD1 DRILL CIRC P PU off bottom when sweep through bit, Reci rotate and rotatate w/CBU, _-._ ~ ~_ e.~~ ~~. . P~r~~ ? ci 1~ • Time Log s _ _ _ Date From To Dur S. De th E. Depth Phase Code Subcode T COM i 10/19/2007 11:00 00:00 13.00 10,888 11,955 PROD1 DRILL DDRL P Cont. Drill ahead f/ 10888' - 11955' MD (5097' TVD). PU 220 klbs, SO 103 klbs, RotWt 130 klbs, ONBTorq 15k ft-Ibs, OFB Torq 18.5k ft-Ibs. Max ECD's 11.09, Max Gas 594 @ Iceberg fmtn. 10/20/2007 00:00 03:30 3.50 11,955 12,213 PROD1 DRILL DDRL P Drill f/ 11955' - 12213' w/dropping an le. 03:30 04:30 1.00 12,213 12,213 PROD1 DRILL CIRC P Pump sweep & follow w/ new partial mud swap to combat high clay content in mud prior to drilling Bermuda. 04:30 09:00 4.50 12,213 12,365 PROD1 DRILL DDRL P Drill ahead f/ 12213' - 12365 MD, control drill 50 ft/hr. for sam les. 09:00 10:30 1.50 12,365 12,365 PROD1 DRILL CIRC P Circ samples, confirm Bermuda fmtn. Flow check. Well stable. 10:30 11:30 1.00 12,365 12,403 PROD1 DRILL DDRL P Drill ahead 8-3/4 hole dretnl, 12365 - 12403 ft. Increase MW to 9.7 while drill. (Slight flow increase with gas peaks) AST 1.44, ART 4.53, BU gas 594, BG as 80 - 230. ECD 10.53 11:30 12:30 1.00 12,403 12,403 PROD1 DRILL PULD P POH stand bk 4 stds DP, RIH 12 sgls for drill ahead TD. Wellbore exc cond. No swab / ain /loss. 12:30 23:00 10.50 12,403 12,836 PROD1 DRILL DDRL P Drill ahead 8-3/4 hole dretnl, 12403 - 12836' MD (5750' TVD). PU 235k1bs, SO 115k1bs, ONBTorq 19.5k ft-Ibs, OFBTorq 20k ft-Ibs. Max ECUs 11 ppg MW, Max Gas 653 units after drillin Bermuda. 23:00 23:30 0.50 12,836 12,836 PROD1 RIGMN' OTHR P Rig Service 23:30 00:00 0.50 12,836 12,836 PROD1 RIGMN RGRP T Rig Downtime: Diagnostics on Top Drive ower ack. 10/21/2007 00:00 07:00 7.00 12,836 12,836 PROD1 RIGMN' RGRP T Rig down time: Replace blower motor on top drive power pack traction motor & Go brushes on traction motor. Circulate and reciprocate at reduced rate until repaired. Unable to rotate or use to drive. 07:00 09:00 2.00 12,836 12,897 PROD1 DRILL DDRL P Drill ahead 8-3/4 hole dretnl, 12836 - 12897 ft. Lose all ower to ri . 09:00 10:00 1.00 12,897 12,897 PROD1 RIGMN RGRP T Troubleshoot /repair rig elect system. 10:00 12:30 2.50 12,897 13,010 PROD1 DRILL DDRL P Drill ahead 8-3/4 hole dretnl, 12897 - 13010ft TD as er Geo cs depth. Slide last 42 ft due to top-drive failure 1104hrs. 12:30 18:00 5.50 13,010 13,010 PROD1 DRILL CIRC P C/C drlg fluids, clean well bore. sweeps /fluid caliper indicates approx 20% washout 8-3/4 hole section. CBU x 4, ull 1 stand, CBU, 18:00 18:30 0.50 13,010 13,010 PROD1 DRILL PULD P B/D Top Drive, prepare to TOH w/ monitor well. 18:30 19:30 1.00 13,010 13,010 PROD1 DRILL WPRT P POOH f 31010' - 12400', monitor well, static. Pum d ~ob, B/D To drive. ~~____---. e f'~g~ ~ of 13 Time Logs_ ____ _ Date From To Dur S De th E De th Phase Code Subco de T COM 10/21/2007 19:30 00:00 4.50 13,010 13,010 PROD1 DRILL _ TRIP P Cont POOH f/ 12400' - 6893'. 10/22/2007 00:00 02:00 2.00 13,010 13,010 PROD1 DRILL WPRT P Finish TOH t/ shoe f/ 6893' - 4215'. 02:00 03:00 1.00 13,010 13,010 PROD1 RIGMN' SVRG P Slip and cut drill line. 03:00 07:30 4.50 13,010 13,010 PROD1 RIGMN' RGRP T Rig Down-time: Replacing top drive ower ack blower motor. 07:30 09:30 2.00 13,010 13,010 PROD1 RIGMN RGRP T Repair complete. RIH to 5036, test / rotate to drive. To drive functioinin . 09:30 10:00 0.50 13,010 13,010 PROD1 WELC OWFF P Flow check, well static. 10:00 13:30 3.50 13,010 13,010 PROD1 DRILL WPRT P RIH to 12920 ft, precaution wash to btm at 13010. No fill. 13:30 20:00 6.50 13,010 13,010 PROD1 DRILL CIRC P C/C fluids in prep for csg run. 20:00 22:00 2.00 13,010 13,010 PROD1 DRILL TRIP P TOH. Rack back 30 stds DP in re aration for runnin rod cs . 22:00 00:00 2.00 13,010 13,010 PROD1 DRILL TRIP P Continue POOH LD 5" DP 10/23/2007 00:00 10:00 10.00 13,010 13,010 PROD1 DRILL TRIP P LD 5" DP in sgls to BHA. Flow check. 10:00 16:00 6.00 13,010 13,101 PROD1 DRILL TRIP P Handle BHA, LD dretnl assy, download data, break bit, clear BHA from shed. 16:00 17:30 1.50 13,101 13,101 COMPZ CASIN( RURD P PJSM, flush BOP, prepare for ram chan e. 17:30 18:30 1.00 13,101 13,101 COMPZ CASIN( OTHR P Pull wear ring & set test plug. 18:30 21:30 3.00 13,101 13,101 COMPZ CASIN OTHR P PJSM-Change upper rams to 4.5" & lower rams to 7". Test same 250-3500 si. 21:30 00:00 2.50 13,101 13,101 COMPZ CASIN OTHR P Load 7" csg. in pipe shed. Load all 7" equipment. Make dummy run with han er. 10/24/2007 00:00 03:00 3.00 13 13,010 COMPZ CASINC OTHR P Finish loading pipe shed w/ remaining 7" cs . & ri u to run 4.5" cs . 03:00 05:30 2.50 13,010 13,010 COMPZ CASINC RNCS P PJSM-Run 4.5" csg. to 805' 26 jts. MU 4-1/2 X 7 SBR. 05:30 09:00 3.50 13,010 13,010 COMPZ CASINC RURD P PJSM-Rig up to run 7" csg. 09:00 00:00 15.00 13,010 13,010 COMPZ CASINC RNCS P Flow check, follow SBR with 7" csg, CBU 1500 ft intervals. 10/25/2007 00:00 01:00 1.00 13,010 13,010 COMPZ CASINC CIRC P PJSM Circulate Casing Volume @ 10,248' MD; 68 BPM @ 600 PSI; PU 220K SO 65K 01:00 02:30 1.50 13,010 13,010 COMPZ CASINC RNCS P RIH W/ 7" Casing f/ 10,248' - 11,726' MD; PU 250K SO 75K 02:30 04:00 1.50 13,010 13,010 COMPZ CASIN CIRC P Circ Casing Volume @ 11,726' MD; 6 BPM 650 PSI 04:00 05:00 1.00 13,010 13,010 COMPZ CASIN RNCS P RIH W/ 7" Casing f/ 11,726' - 12,962' MD; PU 305K SO 77K 05:00 06:30 1.50 13,010 13,010 COMPZ CASIN RNCS P M!U and RIH w/ 7" Casing Hanger; Rig Down Casing Running Tools and R/U Circ Head. Final depths =Shoe 12,960, Float collar 12866 ft. SBE 12131 ft. ®e Page ~ of 13 n Time Loc,~s _ _ - - -__-- - Date From To Dur S De th E. De th Pha e Code Subcode T COM 10/25/2007 06:30 07:30 1.00 13,010 13,010 COMPZ CASINC CIRC P Circ Staging Pumps Up as Follows: 2 BPM @ 350 PSI, 3 BPM @ 390 PSI, 4 BPM 480 PSI, 5 BPM 560 PSI 07:30 08:00 0.50 13,010 13,010 COMPZ CEME~ RURD P R/D Circ Head and Load Plug and R/U Cementin Head 08:00 10:00 2.00 13,010 13,010 COMPZ CEME~ CIRC P Reciprocate Casng and Circulate 5 BPM 560 PSI & Batch Cmnt 10:00 12:00 2.00 13,010 13,010 COMPZ CEME~ DISP P PJSM, test lines 3500 psi, Cement 4 1/2" Production String, 94 bbls, 485 sks "G", f/ 12991' - 11,300' MD (TOC); Displaced w/ 478 BBLS Drilling Fluid. Plug did not bump. Pump calculated 1/2 shoetrack. Recip pipe until just before cmt. Seat hgr, pipe sticking. ICP = 545 psi / 5 bpm, FCP = 687 psi / 5 b m. No cmt to surface. 12:00 12:30 0.50 13,010 13,010 COMPZ CEMEf` OTHR P Check Floats (Good) 12:30 15:30 3.00 13,010 13,010 COMPZ CEME~ RURD P PJSM; R/D SLB Cementing Equipment & Lines and Blow Down Same; Chan a Out Bales 15:30 18:00 2.50 13,010 13,010 COMPZ CEME~ OTHR P PJSM-load 3.5" tbg. in pipe shed. drain & wash bop stack. Install packoff on 7" & test same to 5000 si. OK 18:00 00:00 6.00 13,010 13,010 COMPZ CEME OTHR P Freeze protect 9 5/8" X 7" annulus w/ diesel while loading pipe shed w/ 3.5" completion string. Change out upper i e rams to 3.5". 10/26/2007 00:00 04:00 4.00 13,010 13,010 COMPZ RPCOPo RURD P PJSM on Loading 3 1/2" Completion Tubing in Pipe Shed; Load, Strap, & Drift Remaining 3 1/2" tubing in Pipe Shed; Load Completion Jewelry; Chemical Injection Line and Clam s 04:00 05:00 1.00 13,010 13,010 COMPZ WELCT OTHR P PJSM; Change Rams to 3 1/2" and Test to 250/3500 PSI 05:00 08:00 3.00 13,010 13,010 COMPZ RPCO RURD P PJSM; R/U Chemical Injection Line Shive in Derrick 08:00 12:00 4.00 13,010 13,010 COMPZ RPCOh TRIP P PJSM; RIH w/ 3 1!2" Completion Tubin f/ 0 - 1890' MD 12:00 12:30 0.50 13,010 13,010 COMPZ RPCOb SFTY P PJSM onRIH w/ 3 1/2" Completion Tubing and SIM Training on Accendin /Decendin Stairs 12:30 15:00 2.50 13,010 13,010 COMPZ RPCOti TRIP P RIH w/ 3 1/2" Completion Tubing f/ 1890' - 4759' MD 15:00 17:00 2.00 13,010 13,010 COMPZ RPCOh RURD P PJSM; M/U and Test Chemical In~ection Mandrel and Test Line 17:00 20:30 3.50 13,010 13,010 COMPZ RPCOti TRIP P RIH w/ 3 1/2" Tubing and Chemical Injection Line to 7488' MD. 20:30 21:00 0.50 13,010 13,010 COMPZ RPCOh CIRC P Circ. 3.5" tbg. volume @ 350 psi. 21:00 00:00 3.00 13,010 13,010 COMPZ RPCO PULD P Continue running 3.5" completion from 7488' to 10016' MD. 10/27/2007 00:00 05:00 5.00 13,010 13,010 COMPZ RPCOti TRIP P PJSM; RIH w/ 3 1/2" tubing f/ 10,016' - 12,119' MD; PU 118K SO 50K ._~ >} age 1~ t~f 13~ • Time Lois _ _ _ _ __ _ Date From To Dur S Depth E_ Depth Phase. Code Subcode T COM ____ 10/27/2007 05:00 08:00 3.00 13,010 13,010 COMPZ RPCOti CIRC P Tagged High @ 12,119' MD, Rig Up to Circulate & Circulate Bottoms Up @ 60 SPM (3.5 BPM) at 580 Psi; PU 140K SO 50K; Decision Made to POOH and Clean Cement From Seal Bore Assy and Casing Down to Float Collar 08:00 08:30 0.50 13,010 13,010 COMPZ RPCO SFTY T PJSM; R/D Circ Head & Lines 08:30 15:00 6.50 13,010 13,010 COMPZ RPCOh OTHR T UD 17 Stds 5" DP from Derrick via Mouse Hole and Remove from Pipe Shed 15:00 00:00 9.00 13,010 13,010 COMPZ RPCOh TRIP T PJSM; POOH and Stand Back 3 1/2" Tubing in Derrick, UD Jewelry; PU 118K SO 50K 10/28/2007 00:00 04:00 4.00 13,010 13,010 COMPZ RPCO PULD T Cont'd Pulling 3.5" completion & s oolin SS line. 04:00 05:00 1.00 13,010 13,010 COMPZ RPCO OTHR T Lay down chemical injection mandrel & ri downs oolin a ui ment. 05:00 10:00 5.00 13,010 13,010 COMPZ RPCOh PULD T Finish POOH w/ 3 1/2" Tubing and La Down Jewel 10:00 12:00 2.00 13,010 13,010 COMPZ CEME~ DRLG T Change Out Saver Sub & Complete Ri Service 12:00 13:00 1.00 13,010 13,010 COMPZ RIGMN RGRP T Troubleshoot & Repair Top Drive 13:00 15:00 2.00 13,010 13,010 COMPZ WELCT OTHR T Remove 3 1/2"and 7" Rams and Install 4 " In U er! Lower Positions 15:00 19:30 4.50 13,010 13,010 COMPZ WELC BOPE P Complete Scheduled Test of BOPS to 3500 / 250 PSI -- Next Due 11 Nov 07 (Witness test waived by Bob Noble AOGCC. 19:30 21:00 1.50 13,010 13,010 COMPZ RPCOh OTHR T PJSM-Change out rig tongs & set wear bushin . 21:00 23:00 2.00 13,010 13,010 COMPZ RPCO PULD T PJSM-Load BHA tools & make up same for cleanout. 23:00 00:00 1.00 13,010 13,010 COMPZ RPCO PULD T RIH w/ 5" DC,s & picking up 4" DP. 10/29/2007 00:00 12:00 12.00 13,010 13,010 COMPZ DRILL TRIP T PJSM; RIH w/ 4" DP and Clean Out BHA f/ 235' - 7816' MD; PU 127K SO 57K 12:00 16:00 4.00 13,010 13,010 COMPZ DRILL TRIP T Cont'd RIH f/ 7816' - 11,960' MD 16:00 19:00 3.00 13,010 13,010 COMPZ DRILL MILL T Wash down f/ 11,960' - 12,139' MD; Encountered Cement Stringers Starting @ 12,015' MD Drilled Plug @ . 12,110' MD Torque 13 - 13K, WOB 3 -5K, 84 SPM @ 1150 PSI; Tagged Locator Collar @ 12,139' MD WOB 7K, Torque 10-11 K, 84 SPM @ 1250 PSI 19:00 21:00 2.00 13,010 13,010 COMPZ DRILL CIRC T CBU 6 bpm 1300 psi while shuffling e ui ment in i e shed. Pum d 'ob. 21:00 00:00 3.00 13,010 13,010 COMPZ DRILL PULD T PJSM-POH from 12139' laying down DP. & stand remainder in derrick as derrick is too full of pipe to stand back com lete strin . ~ -~ s ~ ~ ~~~~ ~ I caf 13 ~~ Time Logs _ _ _ Date From To _ Dur S. De tki E Depth Phase Code`_Subcode T COM ___ 10/30/2007 00:00 01:30 1.50 13,010 13,010 COMPZ DRILL TRIP T PJSM; POOH F/ 9335' - 8573' MD; PU 185K SO 58K 01:30 05:00 3.50 13,010 13,010 COMPZ DRILL TRIP T PJSM-POH from 8573' & stand back in derrick. 05:00 06:00 1.00 13,010 13,010 COMPZ DRILL OTHR P PJSM-slip & cut drlg. line. 06:00 07:00 1.00 13,010 13,010 COMPZ DRILL OTHR P PJSM-Service top drive blocks, etc. 07:00 09:00 2.00 13,010 13,010 COMPZ DRILL TRIP T PJSM-POH from 314' & lay down BHA. 09:00 09:30 0.50 13,010 13,010 COMPZ DRILL OTHR T PJSM- Bring up BHA #2. 09:30 10:00 0.50 13,010 13,010 COMPZ DRILL OTHR T Wait on orders. 10:00 12:00 2.00 13,010 13,010 COMPZ DRILL PULD T Build baker BHA #2. 12:00 17:00 5.00 13,010 13,010 COMPZ DRILL TRIP T PJSM-RIH w/ 4" dp to 8676' MD. 17:00 18:30 1.50 13,010 13,010 COMPZ DRILL CIRC T Circ. pipe volume while arranging pipe shed. 18:30 22:30 4.00 13,010 13,010 COMPZ DRILL TRIP T PJSM-RIH w/singles from 8676' to 12096' MD. 22:30 00:00 1.50 13,010 13,010 COMPZ DRILL REAM T Wash down from 12096' to 12158' & to . Drl . on same 12158'. 10/31/2007 00:00 02:00 2.00 13,010 13,010 COMPZ DRILL REAM T Clean Out SBE f/ 12,127' - 12,190' MD; @ 12,127 Circulated 40 SPM @ 1000 PSI, Washed Down to 12,158' MD, Motor Stalled @ 12,158' Circ'ed 40 SPM @ 1048 PSI and Pressure Climbed to 1700 PSI During Stall, then Circ'ed @ 50 SPm @ 1180 PSI With Same Result; WOB 4 -10K, Stopped Circulating and Pushed Plug f/ 12,158' - 12,190' MD, Pulled 1 Stand Out and Washed Down with Mud Motor and Baker Clean Out Mill f/ 12, 12T - 12,190' MD 4 Times. Dropped Ball & Rod and Circulated Bottoms Up. Cement Plug Remains Below 12,190' MD. 02:00 02:30 0.50 13,010 13,010 COMPZ DRILL OTHR T Push plug down to 12190' MD w/ 5-10k wt. & no um . 02:30 03:00 0.50 13,010 13,010 COMPZ DRILL CIRC T Work back thru from 12127' to 12190' 4 times while circ. same. 03:00 03:30 0.50 13,010 13,010 COMPZ DRILL OTHR T Drop ball & rod. Ball on seat & sheared circ. sub w/ 2500 si. 03:30 04:30 1.00 13,010 13,010 COMPZ DRILL CIRC T CBU & pump dry job. 04:30 05:00 0.50 13,010 13,010 COMPZ DRILL OTHR T Blow down top drive. 05:00 19:00 14.00 13,010 13,010 COMPZ DRILL PULD T PJSM-POH laying down 4"drill pipe. 19:00 21:30 2.50 13,010 13,010 COMPZ DRILL PULD T Lay down BHA #2 & kick out tools. 21:30 23:00 1.50 13,010 13,010 COMPZ DRILL OTHR T Clean floor, take pipe out of shed & ull wear rin . ~~ ~~e ~f2 t~f fi J i Time Logs ____ ______ _ Date From To D ur S. De th E. De th Phase Code Subcod e T COM _ 10/31/2007 23:00 _ 00:00 _ _ 1.00 13,010 13,010 COMPZ DRILL _ OTHR T _ _ PJSM-Set test plug & change out u er rams to 3.5". 11/01/2007 00:00 01:00 1.00 13,010 13,010 COMPZ DRILL OTHR T PJSM-Rig up to run 3.5" completion . Fill stack to test 3.5" rams. 01:00 01:30 0.50 13,010 13,010 COMPZ DRILL OTHR T Test 3.5" rams 350-3500 psi. OK 01:30 03:00 1.50 13,010 13,010 COMPZ DRILL OTHR T PJSM-Rig down test equipment & finish ri u to run 3.5" com letion. 03:00 18:00 15.00 13,010 13,010 COMPZ RPCOh PULD T PJSM-RIH w/ 3.5" completion. 18:00 19:00 1.00 13,010 13,010 COMPZ RPCO OTHR T Make up circ. lines. Locate top of PBR @ 12143' MD. Run seals in 16' to 12159'. 19:00 21:00 2.00 13,010 13,010 COMPZ RPCOti HOSO P Space out 2' above PBR w/ locator sub. Make up tbg. hanger & landing jt.. Make up control line to tbg. han er. 21:00 00:00 3.00 13,010 13,010 COMPZ RPCOh CIRC P Displace well to seawater @ 3 bpm. 1000 si to 360 si. 11/02/2007 00:00 01:00 1.00 13,010 13,010 COMPZ RPCOti CIRC P PJSM-Continue displacing well to seawater 3 b m. 01:00 02:00 1.00 13,010 13,010 PROD1 RPCOh CIRC P Spot 10 Bbls SW w/ corrosion inhibitor @ 3 bpm. Spot on bottom in IA from seal assy to above bottom G LM. 02:00 03:00 1.00 13,010 13,010 PROD1 RPCOh HOSO P PJSM-Drain stack & land tbg. RILDS. 03:00 04:30 1.50 13,010 13,010 PROD1 RPCOh DHEO P PJSM-Rig up to test tbg. & annulus. Test tubing to 2500 psi for 15 minutes. OK. Test IA (3-1/2" Tbg x 7" Csg) to 2500 psi, holding 2000 psi on Tbg, for 30 minutes, OK. 04:30 05:00 0.50 13,010 13,010 PROD1 RPCO OTHR P Bleed off tubing & shear open SOV in bottom GLM @ 11918' MD. Bleed off ressures. RD lines. 05:00 08:00 3.00 13,010 13,010 COMPZ RPCOPo OTHR P Set 2 way check & verify set w/ 2000 psi. & change out upper & lower pipe rams to 5". 08:00 11:00 3.00 13,010 13,010 COMPZ RPCOh NUND P PJSM- nipple down hope. 11:00 16:30 5.50 13,010 13,010 COMPZ RPCOti NUND P PJSM-Dress hanger-nipple up adapter. Terminate injection line. Test adapter 5000 psi. Nipple up tree & open actuator. 16:30 17:00 0.50 13,010 13,010 COMPZ RPCO DHEO P Test tree 250-5000 psi for 10 mins. 17:00 21:00 4.00 13,010 13,010 COMPZ RPCOh FRZP P PJSM-Rig up lines. Test to 3500 psi freeze protect well w/ 165 bbls. diesel &'U' tube same. 21:00 00:00 3.00 13,010 13,010 PROD1 RPCOh OTHR P Clean out mud pits secure diverter. (Release rig @ 2400 hrs. 11-2-07) Final pressures: Tbg & IA = 0, OA = 500 si. Page 13 Est 1~ ~~~ • 2L-319 Well Events Summary DATE Summary 11/22/07 TAG "D" NIPPLE AT 12,073' RKB/ 12,061' SLM W/ 2.805 CENT. TAG TOP OF CEMENT AT 12,128' SLM W/ 2.72 SWAGE & SAMPLE BAILER. JOB COMPLETE. 12/6/07 SET CATCHER IN D NIPPLE. PULLED SOV @ 11918' RKB & REPLACED WITH DV. MIT IA, PASSED. PULLED CATCHER, READY FOR CTU. 12/8/07 ATTEMPT TO MILL WIPER PLUG AND CEMENT IN LINER. RIH WITH MOTOR AND JUNK MILL TO 12190' CTM .MOTOR STALLED @ 12190.6' CTMD. MADE SEVERAL ATTEMPTS TO MILL. MOTOR CONTINUED STALLING SEVERAL TIMES. ERRATIC WT SWINGS WHEN PICKING UP. APPEARS TO HAVE TRASH ON BOTTOM. 12/9/07 USED WEATHERFORD 2.625" OD VENTURI JUNK BASKET TO RECOVER 1/2 CUP OF CEMENT AND SMALL METAL PIECES. SECOND RUN WITH 2.70" OD DIAMOND SPEED MILL TAGGED HARD @ 1639' CTMD. STACKED 5K# ON OBSTRUCTION WITHOUT SUCCESS. RAN 2.78" OD IMPRESSION BLOCK. IMPRESSION INCONCLUSIVE. 12/12/07 Perform Wiper plug Millout, RIH with 2.73 Concave Mill, Tagged obstruction @ 1628 CTMD, Worked down to 2936 CTMD, Was able to mill on plug @ this depth. RIH to tag of 12198 CTMD, Milled out soft cement to 12860 RKB. Heavy cement in rtns, Freeze protected 12/13/07 Underream Cement in production liner from 12170 CTMD to 12860 RKB, Flushed well with S/W, Freeze protected with 40 diesel. Performed successful MIT on tubing. Turned over to E-Line. 12/22/07 TAG FILL @ 12832' SLM. RECOVERED SAMPLE. DRIFTED TBG WITH 21' X 2.63" DUMMY GUN & TAGGED @ 12832' SLM. JOB COMPLETE. 12/23/07 RAN SCMT LOG. NECESSARY TO CONFIGURE WITH ROLLERS ABOVE AND BELOW SCMT TO GET DOWN. STUCK TOOL IN BAKER CMU SLIDING SLEEVE. PULLED FREE WITH MAX SAFE PULL ON CABLE. 12/27/07 PULLED DV @ 11,918' RKB, LOAD TUBING & IA W/ 420 BBLS DIESEL, LDFN, IN PROGRESS. 12/28/07 PULL AND SET NEW DMY @ 11918' RKB, MIT IA 3500 PSI GOOD , BRUSHED CMU @ 12000' RKB, RETAG @ 12836' WLM 12/31/07 RAN A SCMT CEMENT BOND LOG CEMENT QUALITY WAS POOR TO FAIR OVER THE INTERVAL 12824' TO 12160', WITH SOME IRREGULAR AREAS AND VOIDSPERFO SPF HYPERJET, f- EH= 0.43", PENT= 13.1". TAGGED BOTTOM AT 12837' 1/1/08 DRIFT 2.71" GAUGE TO 12818' SLM.PERFORMED SBHPS @ (12490' RKB PSI 2371) WITH GRADIENT @ (10962' RKB PSI 2025) DRIFT FOR TREE SAVER WITH 2.90" GAUGERING TO 10' SLM. COMPLETE 1/4/08 PUMP BERMUDA SAND FRACTURE TREATMENT USING 50# X-LINKED GEL AT 20 BPM. PUMPED A TOTAL OF 149,617# OF 16/20 CARBOLITE PROPPANT PLACING 9 PPA ON PERFS AND 117,808# BEHIND PIPE. FRAC SCREENED OUT WITH 109 BBLS OF 9 PPA IN FORMATION. PUMPED 50 BBLS 15% HCI PRIOR TO BREAKDOWN AND 1,100 BBL BRACKETFRAC PRIOR TO SAND STAGES. RECOVERED ALL TREESAVER RUBBERS. Halliburton Company Survey Report ~._ , r Company: ConocoPhillips Alaska Inc. Da te: 11/12/2007 Time: 09:41:14 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 2L-319, True North Site: Kuparuk 2L Pad Ve rtical (TVD) Reference: 2L-319: 145.3 Well: 2L-319 Section (VS) Reference: Well (O.OON,O.OOE,84A4Azi) Wellpath: 2L-319 Survey Calculation Method: Minimum Curva ture Db: Oracle Field: Kuparuk River Unit I North Slope Alaska United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 ~ Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre 1 Sys Datum: Mean Sea Level Geomagnetic Modet: bggm2007 ~ Well: 2L-319 Slot Name: '~ 2L-Oscar ~ '~ Well Position: +N/-S -48.28 ft Northing: 592764 7.91 ft Latitude: 70 12 47.797 N I +E/-W -204.30 ft Fasting : 460873.38 ft Longitude: 150 18 55.979 W ~ Position Uncertainty: 0.00 ft ~~ ' Wellpath: 2L-319 Drilled From: Well Ref. Point 4 ~ 50-103-20552-00 Tie-on Depth: 30.04 ft ' Current Datum: 2L-319: Height 14 5.34 ft _ Above System Datum: Mean Sea Level '~ Magnetic Data: 10/5/2007 Declination: 22.73 deg Field Strength: 57583 nT Mag Dip Angl e: 80.67 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg I 30.04 0.00 0.00 _84.04 _ I Survey Program for Definitive Wellpath ~j Date: 9/13/2007 Validated: No Version: 4 ~ Actual From To Survey Toolcode Tool Name ! ~_ ft ft 78.00 717.00 2L-319 gyro (78.00-717.00) CB-GYRO-SS Camera based gyro sin gle shot 748.50 13010.00 2L-319 (748.50-13010.00) M WD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC _. _ Survey _ _ _ ~MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool '~ I ft deg deg ft ft ft ft ft ft ~ 30.04 0.00 0.00 30.04 -115.30 - 0.00 0.00 5927647.91 - 460873.38 - TIE LINE ~ 78.00 0.07 72.85 78.00 -67.34 0.01 0.03 592x647.92 460873.41 CB-GYRO-SS 170.00 0.22 18.45 170.00 24.66 0.19 0.14 592+648.10 460873.52 CB-GYRO-SS 266.00 0.64 9.10 266.00 120.66 0.90 0.28 592x648.81 460873.67 CB-GYRO-SS i 357.00 1.43 1.00 356.98 211.64 2.53 0.38 592x650.44 460873.77 CB-GYRO-SS 448.00 2.22 10.13 447.93 302.59 5.40 0.71 5922653.31 460874.12 CB-GYRO-SS { 534.00 2.86 19.34 533.85 388.51 9.07 1.71 5922656.97 460875.14 CB-GYRO-SS 628.00 5.09 41.85 627.62 482.28 14.39 5.27 5927662.27 460878.73 CB-GYRO-SS 717.00 7.00 50.52 716.13 570.79 20.78 12.09 5927668.62 460885.58 CB-GYRO-SS ' 748.50 7.95 54.61 747.36 602.02 23.26 15.35 5922671.09 460888.85 MWD+IFR-AK-CAZ-SC 781.02 9.96 59.67 779.48 634.14 25.98 19.61 592x673.79 460893.13 MWD+IFR-AK-CAZ-SC 812.97 10.75 64.42 810.91 665.57 28.67 24.69 5927576.44 460898.21 MWD+IFR-AK-CAZ-SC ' 843.60 11.62 68.25 840.96 695.62 31.04 30.13 592x678.79 460903.67 MWD+IFR-AK-CAZ-SC 875.26 13.49 73.04 871.86 726.52 33.30 36.62 5927681.02 460910.17 t MWD+IFR-AK-CAZ-SC 905.90 15.90 75.75 901.50 756.16 35.38 44.11 5927683.05 460917.67 i MWD+IFR-AK-CAZ-SC `1 935.49 17.45 78.60 929.84 784.50 37.25 52.39 5927684.89 460925.96 MWD+IFR-AK-CAZ-SC 969.27 18.62 80.89 961.96 816.62 39.11 62.68 5927686.69 460936.25 MWD+IFR-AK-CAZ-SC I 999.04 20.39 82.46 990.02 844.68 40.54 72.51 5927688.07 460946.09 MWD+IFR-AK-CAZ-SC '~ ~ 1030.12 21.90 84.00 1019.01 873.67 41.86 83.65 592x689.33 460957.23 MWD+IFR-AK-CAZ-SC ~ 1062.87 23.87 84.78 1049.18 903.84 43.10 96.32 5922690.50 460969.91 MWD+IFR-AK-CAZ-SC 1094.88 26.10 84.60 1078.19 932.85 44.35 109.78 592'7691.69 460983.38 MWD+IFR-AK-CAZ-SC 1125.35 28.57 83.91 1105.26 959.92 45.75 123.70 5927fi93.02 460997.30 MWD+IFR-AK-CAZ-SC 1158.50 30.72 83.13 1134.07 988.73 47.61 139.99 5927694.79 461013.60 MWD+IFR-AK-CAZ-SC 1189.45 31.77 84.06 1160.53 1015.19 49.40 155.94 5927696.49 461029.56 MWD+IFR-AK-CAZ-SC 1219.79 32.38 84.60 1186.24 1040.90 50.99 171.98 5927698.00 461045.60 MWD+IFR-AK-CAZ-SC I 1252.38 33.78 84.43 1213.54 1068.20 52.69 189.68 5927699.61 461063.31 MWD+IFR-AK-CAZ-SC 1285.23 35.10 82.74 1240.64 1095.30 54.77 208.14 592x701.59 461081.78 MWD+IFR-AK-CAZ-SC ~ 1315.21 37.28 81.79 1264.83 1119.49 57.15 225.68 5927703.89 461099.33 MWD+IFR-AK-CAZ-SC 1347.15 39.92 81.63 1289.79 1144.45 60.03_ 245.40 5927706.66 461119.06 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report - -~ Company: ConoooPhill ips Alaska I nc. Date: 11/ 12/2007 Tim e: 09:41:14 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: WeIL 2L-319, True North Site: Ku paruk 2L Pad Vertical (TVD) Reference: 2L-319: 145.3 Well: 2L-319 Sectio n (VS) Reference: Well (0.00N,O. 04Azi) 00E,84 Wellpath: 2L -319 Survey Calc ulation Method: ~ Minimum Curvature Db: Oracle Survey _ MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ~ ft deg deg ft ft ft ft ft ft 1408.22 44. 93 82. 30 1334.86 1189 .52 65. 77 286. 18 5927712.19 461159.87 MWD+lFR-AK-CAZ-SC 1441.23 46. 71 82. 76 1357.86 1212 .52 68. 85 309. 65 5927715.15 461183.35 MWD+IFR-AK-CAZ-SC 1473.12 49. 01 84. 12 1379.26 1233 .92 71. 55 333. 14 5927717.72 461206.86 MWD+IFR-AK-CAZ-SC 1504.08 51. 03 84. 63 1399.15 1253 .81 73. 87 356. 75 5927719.92 461230.47 MWD+IFR-AK-CAZ-SC 1537.43 52. 85 84. 52 1419.71 1274 .37 76. 35 382. 89 5927722.27 461256.62 MWD+IF'R-AK-CAZ-SC ! I 1571.18 55. 01 84. 42 1439.58 1294 .24 78. 98 410. 04 5927724.76 461283.79 MWD+IFR-AK-CAZ-SC 1600.39 56. 44 84. 84 1456.03 1310 .69 81. 24 434. 07 5927726.89 461307.82 MWD+IFR-AK-CAZ-SC 1634.07 58. 35 84. 81 1474.17 1328 .83 83. 80 462. 33 5927729.30 461336.09 MWD+IFR-AK-CAZ-SC 1663.56 60. 45 85. 12 1489.18 1343 .84 86. 03 487. 61 5927731.40 461361.38 MWD+IFR-AK-CAZ-SC 1693.23 61. 58 83. 95 1503.56 1358 .22 88. 50 513. 45 5927733.74 461387.23 MWD+IFR-AK-CAZ-SC 1727.83 63. 32 84. 40 1519.56 1374 .22 91. 61 543. 96 5927736.69 461417.76 MWD+IFR-AK-CAZ-SC ~ 1758.76 i 64. 86 82. 32 1533.08 1387 .74 94. 83 571. 59 5927739.77 461445.40 MWD+IFR-AK-CAZ-SC 1786.87 65. 85 82. 38 1544.80 1399 .46 98. 23 596. 92 5927743.04 461470.74 MWD+IFR-AK-CAZ-SC 1821.67 66. 67 81. 98 1558.81 1413 .47 102. 57 628. 47 5927747.21 461502.32 MWD+IFR-AK-CAZ-SC 1851.97 67. 94 80. 93 1570.50 1425 .16 106. 72 656. 12 592775'!.22 461529.98 MWD+IFR-AK-CAZ-SC 1879.77 68. 55 81. 11 1580.81 1435 .47 110. 75 681. 62 5927755.12 461555.50 MWD+IFR-AK-CAZ-SC I 1914.66 68. 53 81. 29 1593.57 1448 .23 115. 72 713. 71 5927759.92 461587.61 MWD+IFR-AK-CAZ-SC 1945.86 68. 55 81. 58 1604.99 1459 .65 120. 04 742. 42 5927764.09 461616.34 MWD+IFR-AK-CAZ-SC 1974.40 68. 20 82 .08 1615.50 1470 .16 123. 81 768. 68 5927767.73 461642.62 MWD+IFR-AK-CAZ-SC 2064.11 66. 92 80. 94 1649.75 1504 .41 136. 05 850. 69 5927779.54 461724.68 MWD+IFR-AK-CAZ-SC 2160.22 68. 21 83 .75 1686.43 1541 .09 147. 87 938. 72 5927790.90 461812.76 MWD+IFR-AK-CAZ-SC I1 2252.26 69. 28 85 .91 1719.80 1574 .46 155. 60 1024. 15 5927798.18 461898.22 MWD+IFR-AK-CAZ-SC 2348.15 68. 30 85 .81 1754.49 1609 .15 162. 05 1113. 31 5927804.17 461987.40 MWD+IFR-AK-CAZ-SC 2442.34 70. 50 85 .65 1787.63 1642 .29 168. 61 1201. 22 5927810.28 462075.34 MWD+IFR-AK-CAZ-SC 2537.49 72. 03 85 .24 1818.19 1672 .85 175. 77 1291. 04 5927816.97 462165.19 MWD+IFR-AK-CAZ-SC 2630.17 72. 58 83 .58 1846.36 1701 .02 184. 37 1378. 91 5927825.12 462253.10 MWD+IFR-AK-CAZ-SC 2726.30 72. 52 85 .22 1875.19 1729 .85 193. 32 1470. 18 5927833.59 462344.40 MWD+IFR-AK-CAZ-SC 2816.85 72. 95 83 .63 1902.07 1756 .73 201. 72 1556. 24 5927841.55 462430.49 MWD+IFR-AK-CAZ-SC 2913.12 73. 42 84 .06 1929.92 1784 .58 211. 60 1647. 86 592785[I.95 462522.15 MWD+IFR-AK-CAZ-SC 3008.21 72. 93 82 .33 1957.44 1812 .10 222. 39 1738. 23 5927861.27 462612.57 MWD+IFR-AK-CAZ-SC 3103.75 72. 89 82 .81 1985.52 1840 .18 234. 20 1828. 79 5927872.60 462703.18 MWD+IFR-AK-CAZ-SC i 3197.92 72. 89 81 .47 2013.23 1867 .89 246. 50 1917. 94 5927884.45 462792.38 MWD+IFR-AK-CAZ-SC 3293.97 70. 17 80 .63 2043.65 1898 .31 260. 67 2007. 93 5927898.15 462882.43 MWD+IFR-AK-CAZ-SC 3386.68 70. 02 80 .74 2075.22 1929 .88 274. 78 2093. 95 5927911.81 462968.52 MWD+IFR-AK-CAZ-SC 3480.57 69. 07 83 .95 2108.04 1962 .70 286. 50 2181. 12 5927923.08 463055.74 MWD+IFR-AK-CAZ-SC ' 3578.83 68. 55 84 .77 2143.55 1998 .21 295. 51 2272. 29 5927931.61 463146.95 MWD+IFR-AK-CAZ-SC 3674.35 68. 97 85 .19 2178.16 2032 .82 303. 30 2360. 98 5927938.94 463235.67 MWD+IFR-AK-CAZ-SC 3767.42 70. 96 86 .10 2210.04 2064 .70 309. 93 2448 .16 5927945.12 463322.87 MWD+IFR-AK-CAZ-SC 3862.07 71. 37 85 .91 2240.60 2095 .26 316. 17 2537. 52 5927950.90 463412.26 MWD+IFR-AK-CAZ-SC ~ 3956.42 70. 76 86 .02 2271.22 2125 .88 322. 45 2626. 55 5927956.72 463501.30 MWD+IFR-AK-CAZ-SC 4049.89 I 71. 10 83 .46 2301.76 2156 .42 330. 55 2714. 50 5927964.36 463589.29 MWD+IFR-AK-CAZ-SC ~ 4146.67 69. 80 83 .80 2334.14 2188 .80 340. 67 2805. 14 5927974.01 463679.97 MWD+IFR-AK-CAZ-SC 4236.44 69. 68 84 .32 2365.23 2219 .89 349. 39 2888. 90 5927982.29 463763.77 MWD+IFR-AK-CAZ-SC 4335.06 69. 10 84 .78 2399.94 2254 .60 358. 16 2980. 79 5927990.58 463855.70 MWD+IFR-AK-CAZ-SC 4430.30 68. 37 84 .62 2434.49 2289 .15 366. 36 3069. 17 5927998.32 463944.10 MWD+IFR-AK-CAZ-SC 4524.35 68. 77 84 .85 2468.85 2323 .51 374. 39 3156. 35 5928005.90 464031.31 MWD+IFR-AK-CAZ-SC 4616.59 70. 03 85 .27 2501.30 2355 .96 381. 82 3242 .37 5928012.89 464117.36 MWD+IFR-AK-CAZ-SC 4709.86 69. 19 84 .73 2533.80 2388 .46 389. 44 3329 .46 5928020.05 464204.48 MWD+IFR-AK-CAZ-SC 4804.43 70. 35 84 .47 2566.50 2421 .16 397. 79 3417 .80 5928027.95 464292.86 MWD+IFR-AK-CAZ-SC 4898.19 70. 29 84 .15 2598.07 2452 .73 406. 54 3505 .65 5928036.24 464380.74 MWD+IFR-AK-CAZ-SC 4991.60 69 .91 84 .05 2629.87 2484 .53 415 .57 3593 .01 5928044.82 464468.15 MWD+IFR-AK-CAZ-SC 5088.13 70 .69 84 .07 2662.41 2517 .07 424 .98 3683 .41 5928053.75 464558.58 MWD+IFR-AK-CAZ-SC 1 Halliburton Company Survey Report Company: C onoo oPhill ips Ala ska I nc. Date: 11/ 12/2 007 Tim e: 09:41:14 Page: 3 Field: Ku paru k Riv er Unit Co-or dinate (NE) Reference: Well: 2L-31 9, True North Site: Ku paru k 2L Pad Vertical (TVD) Reference: 2L-319: 145.3 Well: 2L-319 Sectio n (VS ) Reference: Well (O.OON,O. OOE,84.04Azi) Wellpath: 2L-319 Survey Calculati on Method: Minimum C urvature Db: Oracle Survey MD Inc l Azim TVD Sys TVD N/S E/W MapN _ MapE Tool ft d eg de g ft ft ft ft ft ft 5181.39 70 ,00 84. 21 2693. 78 2548. 44 433 .95 3770 .77 5928062.27 464645. 98 MWD+IFR-AK-CAZ-SC 5275.59 70 .70 84. 30 2725. 45 2580. 11 442 .83 3859 .04 5928070.69 464734. 28 MWD+IFR-AK-CAZ-SC I 5370.30 70 .43 84. 50 2756. 97 2611. 63 451 .54 3947 .93 5928078.94 464823. 21 MWD+IFR-AK-CAZ-SC 5465.11 69 .96 84. 61 2789. 09 2643. 75 460 .01 4036 .73 5928086.95 464912. 04 MWD+IFR-AK-CAZ-SC 5560.75 71 .00 84. 22 2821. 05 2675. 71 468 .78 4126 .44 5928095.25 465001. 79 MWD+IFR-AK-CAZ-SC 5655.91 70 .43 83. 70 2852. 47 2707. 13 478 .23 4215 .76 592810424 465091. 15 MWD+IFR-AK-CAZ-SC 5751.39 69 .63 83. 24 2885. 08 2739. 74 488 .43 4304 .92 5928113.98 465180. 35 MWD+IFR-AK-CAZ-SC 5845.45 69 .77 83. 55 2917. 72 2772. 38 498 .58 4392 .55 5928123.67 465268. 02 MWD+IFR-AK-CAZ-SC 5940.16 69 .37 83. 10 2950. 78 2805. 44 508 .90 4480 .70 5928133.53 465356. 22 MWD+IFR-AK-CAZ-SC 6035.50 68 .53 85. 30 2985. 02 2839. 68 517 .89 4569 .21 5928142.07 465444. 77 MWD+IFR-AK-CAZ-SC 6130.32 68 .36 84. 59 3019. 86 2874. 52 525 .66 4657 .06 5928149.38 465532. 64 MWD+IFR-AK-CAZ-SC 6225.66 70 .41 84. 19 3053. 43 2908. 09 534 .39 4745 .86 5928157.65 465621. 48 MWD+IFR-AK-CAZ-SC 6320.32 70 .81 84. 12 3084. 85 2939. 51 543 .48 4834 .69 592816628 465710. 34 MWD+IFR-AK-CAZ-SC 6414.04 70 .28 84. 80 3116. 07 2970. 73 552 .01 4922 .64 5928174.35 465798. 33 MWD+IFR-AK-CAZ-SC ~ I 6507.33 70 .37 84. 54 3147. 48 3002. 14 560 .17 5010 .11 5928182.06 465885. 83 I MWD+IFR-AK-CAZ-SC I I 6601.78 71 .00 84. 62 3178. 72 3033. 38 568 .59 5098 .84 5928190.02 465974. 60 MWD+IFR-AK-CAZ-SC 6695.31 70 .15 83. 76 3209. 82 3064. 48 577 .52 5186 .59 5928198.49 466062. 39 MWD+IFR-AK-CAZ-SC 6788.70 70 .65 84. 31 3241. 15 3095. 81 586 .66 5274 .09 5928207.18 466149. 93 MWD+IFR-AK-CAZ-SC 6883.36 69 .91 83. 90 3273. 09 3127. 75 595 .81 5362 .73 5928215.87 466238. 60 MWD+IFR-AK-CAZ-SC 6977.87 71 .15 85. 96 3304. 60 3159. 26 603 .68 5451 .48 5928223.27 466327. 38 MWD+IFR-AK-CAZ-SC ~ 7072.80 70 .36 85. 01 3335. 89 3190. 55 610 .73 5540 .83 5928229.86 466416. 75 MWD+IFR-AK-CAZ-SC 7167.66 71 .28 85. 56 3367. 05 3221. 71 618 .10 5630 .12 5928236.76 466506. 07 MWD+IFR-AK-CAZ-SC 7262.80 70 .33 84. 90 3398. 33 3252. 99 625 .57 5719 .65 5928243.77 466595. 64 MWD+IFR-AK-CAZ-SC 7356.81 71 .36 85. 35 3429. 18 3283. 84 633 .11 5808 .14 5928250.86 466684. 15 MWD+IFR-AK-CAZ-SC ~ 7450.38 70 .49 84. 78 3459. 76 3314. 42 640 .72 5896 .24 5928258.00 466772. 28 MWD+IFR-AK-CAZ-SC 7542.90 71 .86 84. 64 3489. 61 3344. 27 648 .79 5983 .44 5928265.63 466859. 51 MWD+IFR-AK-CAZ-SC 7638.11 71 .09 84. 35 3519. 86 3374. 52 657 .45 6073 .30 5928273_$2 466949. 40 MWD+IFR-AK-CAZ-SC I 7732.67 71 .33 83. 92 3550. 32 3404. 98 666 .60 6162 .35 5928282.50 467038. 49 MWD+IFR-AK-CAZ-SC 7829.52 71 .66 85. 18 3581. 06 3435. 72 675 .32 6253 .77 5928290.75 467129. 95 MWD+IFR-AK-CAZ-SC 7922.72 70 .80 84. 40 3611. 05 3465. 71 683 .33 6341 .65 5928298.31 467217. 86 MWD+IFR-AK-CAZ-SC i 8017.34 70 .94 84. 26 3642. 06 3496. 72 692 .17 6430 .61 5928306-68 467306. 86 MWD+IFR-AK-CAZ-SC I 8110.88 70 .37 83. 75 3673. 04 3527. 70 701 .38 6518 .38 5928315.44 467394. 67 MWD+IFR-AK-CAZ-SC j 8206.23 69 .63 84. 17 3705. 65 3560. 31 710 .81 6607 .48 5928324.40 467483. 81 MWD+IFR-AK-CAZ-SC 8298.64 69 .85 84. 27 3737. 65 3592. 31 719 .54 6693 .74 5928332.69 467570. 10 MWD+IFR-AK-CAZ-SC 8392.67 70 .11 84. 90 3769. 85 3624. 51 727 .88 6781 .69 5928340.57 467658. 08 MWD+IFR-AK-CAZ-SC 8487.04 71 .09 85. 84 3801. 19 3655. 85 735 .06 6870 .41 5928347.29 467746. 83 MWD+IFR-AK-CAZ-SC 8581.20 70 .21 85. 50 3832. 39 3687. 05 741 .77 6958 .99 5928353.54 467835. 44 MWD+IFR-AK-CAZ-SC 8674.82 69 .54 85. 50 3864. 60 3719. 26 748 .67 7046 .63 5928359.98 467923. 10 MWD+IFR-AK-CAZ-SC 8768.80 70 .40 86. 13 3896. 79 3751. 45 755 .11 7134 .69 5928365:96 468011. 18 MWD+IFR-AK-CAZ-SC 8863.96 69 .70 86. 26 3929. 26 3783. 92 761 .04 7223 .94 592837t_44 468100. 45 MWD+IFR-AK-CAZ-SC 8957.89 71 .28 84. 61 3960. 63 3815. 29 768 .10 7312 .19 5928378:03 468188. 73 MWD+IFR-AK-CAZ-SC 9054.27 70 .47 84. 98 3992. 21 3846. 87 776 .36 7402 .87 5928385_$2 468279. 45 MWD+IFR-AK-CAZ-SC 9147.95 71 .28 83. 49 4022. 90 3877. 56 785 .25 7490 .93 5928394.26 468367. 54 MWD+IFR-AK-CAZ-SC 9242.12 70 .26 83. 34 4053. 92 3908. 58 795 .45 7579 .26 5928403.99 468455. 91 MWD+IFR-AK-CAZ-SC 9336.19 69 .98 82. 17 4085. 91 3940. 57 806 .60 7667 .01 5928414.69 468543. 72 MWD+IFR-AK-CAZ-SC 9433.92 69 .91 81. 60 4119. 42 3974. 08 819 .56 7757 .90 5928427.18 468634. 66 MWD+IFR-AK-CAZ-SC 9528.38 70 .88 82. 11 4151. 11 4005. 77 832 .17 7845 .98 5928439,33 468722. 80 MWD+IFR-AK-CAZ-SC 9622.19 71 .32 84. 15 4181. 50 4036. 16 842 .78 7934 .09 5928449.48 468810. 95 MWD+IFR-AK-CAZ-SC 9717.20 70 .87 83. 81 4212. 29 4066. 95 852 .21 8023 .48 5928458.45 468900. 38 MWD+IFR-AK-CAZ-SC 9808.73 70 .48 83. 56 4242. 58 4097. 24 861 .71 8109 .33 5928467.50 468986. 27 MWD+IFR-AK-CAZ-SC I 9901.43 70 .23 85. 34 4273. 74 4128. 40 870 .15 8196 .22 5928475:49 469073. 19 MWD+IFR-AK-CAZ-SC 9998.79 69 .44 85. 26 4307. 31 4161. 97 877 .64 8287 .30 5928482.51 469164. 31 MWD+IFR-AK-CAZ-SC ~ 10092.91 69 .93 85. 36 4339. 98 4194. 64 884 .86 8375 .27 5928489..27 469252. 30 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report • Company: ConocoPhillips Alaska Inc. Date: 11/12/2007 Time: 09:41:14 Page: 4 Field: Ku paruk River Unit Co-ordinate(NE) Reference: Well: 2L-31 9, True North Site: Kuparuk 2L Pad Vertical (TVD) Reference: 2L-319: 145.3 Well: 2L -319 Sec tion (VS) Reference: Well (O.OON,O. OOE,84.04Azi) I Wellpath: 2L-319 1~---- -- Survey Calc ulati on Method: Minimum C _. urv ature Db: Oracle _ Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 10185.05 70.96 86. 05 4370. 82 4225. 48 891. 36 8461. 85 5928495 .32 469338. 91 MWD+IFR-AK-CAZ-SC 10281.62 69.96 85. 74 4403. 12 4257. 78 897. 87 8552. 63 5928501 .36 469429. 70 MWD+IFR-AK-CAZ-SC ~ 10375.28 71.22 86. 39 4434. 25 4288. 91 903. 93 8640. 75 5928506 .97 469517. 85 MWD+IFR-AK-CAZ-SC 10469.98 70.04 85. 55 4465. 66 4320. 32 910. 21 8729. 87 5928512 .78 469606. 99 MWD+IFR-AK-CAZ-SC 10564.37 71.23 85. 25 4496. 95 4351. 61 917. 35 8818. 63 5928519 .46 469695. 78 MWD+IFR-AK-CAZ-SC 10655.70 70.20 84. 85 4527. 12 4381. 78 924. 79 8904. 51 5928526 .45 469781. 69 MWD+IFR-AK-CAZ-SC 10753.10 69.22 83. 73 4560. 89 4415. 55 933. 87 8995. 41 5928535 .07 469872. 63 MWD+IFR-AK-CAZ-SC 10839.90 70.24 83. 35 4590. 96 4445. 62 943. 03 9076. 32 5928543 .81 469953. 57 MWD+IFR-AK-CAZ-SC 10940.80 71.15 83. 02 4624. 32 4478. 98 954. 34 9170. 87 5928554 .62 470048. 17 MWD+IFR-AK-CAZ-SC 11034.91 70.02 82. 70 4655. 60 4510. 26 965. 37 9258. 94 5928565 .19 470136. 29 MWD+IFR-AK-CAZ-SC 11129.90 70.15 84. 27 4687. 96 4542. 62 975. 50 9347. 67 5928574 .86 470225. 06 MWD+IFR-AK-CAZ-SC 11223.52 69.43 84. 04 4720. 30 4574. 96 984. 45 9435. 07 5928583 .35 470312. 50 MWD+IFR-AK-CAZ-SC 11317.44 66.10 84. 51 4755. 84 4610. 50 993. 12 9521. 56 5928591 .58 470399. 02 MWD+IFR-AK-CAZ-SC 11414.56 63.00 84. 80 4797. 57 4652. 23 1001. 29 9608. 86 5928599 .30 470486. 36 MWD+IFR-AK-CAZ-SC 11507.32 60.39 84. 83 4841. 55 4696. 21 1008. 67 9690. 19 5928606 .26 470567. 71 MWD+IFR-AK-CAZ-SC 11603.10 59.32 84. 49 4889. 65 4744. 31 1016. 38 9772. 66 5928613 .54 470650. 21 MWD+IFR-AK-CAZ-SC 11696.33 56.84 84. 25 4938. 94 4793. 60 1024. 14 9851. 40 5928620 .89 470728. 99 MWD+IFR-AK-CAZ-SC 11791.57 53.79 84. 11 4993. 13 4847 .79 1032. 08 9929. 30 5928628 .42 470806. 92 MWD+IFR-AK-CAZ-SC 11886.44 50.21 85. 43 5051. 53 4906 .19 1038. 91 10003. 73 5928634 .87 470881. 38 MWD+IFR-AK-CAZ-SC 11984.70 47.56 84. 28 5116. 14 4970 .80 1045. 53 10077. 46 5928641 .11 470955. 13 MWD+IFR-AK-CAZ-SC 12078.62 46.20 82. 21 5180 .34 5035 .00 1053. 58 10145. 53 5928648 .80 471023. 23 MWD+IFR-AK-CAZ-SC 12173.24 44.33 82. 72 5246 .93 5101 .59 1062. 40 10212. 16 5928657 .28 471089. 90 MWD+IFR-AK-CAZ-SC 12267.91 43.65 81. 97 5315 .04 5169 .70 1071. 16 10277. 32 5928665 .69 471155. 10 MWD+IFR-AK-CAZ-SC 12362.86 41.63 83. 52 5384 .89 5239 .55 1079. 30 10341 .12 5928673 .50 471218. 93 MWD+IFR-AK-CAZ-SC 12456.17 40.62 83. 67 5455 .17 5309 .83 1086. 14 10402 .10 5928680 .03 471279 .95 MWD+IFR-AK-CAZ-SC 12550.64 40.10 84. 73 5527 .16 5381 .82 1092. 33 10462 .96 5928685 .90 471340 .84 MWD+IFR-AK-CAZ-SC 12645.59 39.45 84. 09 5600. 13 5454 .79 1098. 24 10523 .42 5928691 .50 471401 .32 MWD+IFR-AK-CAZ-SC 12740.70 38.17 83. 98 5674. 25 5528 .91 1104. 44 10582. 71 5928697 .39 471460. 63 MWD+IFR-AlC-CAZ-SC 12836.65 37.09 83. 95 5750 .23 5604 .89 1110. 60 10640. 96 5928703 .24 471518. 91 MWD+IFR-AK-CAZ-SC 12931.31 35.77 83. 72 5826 .39 5681 .05 1116. 63 10696. 85 5928708 .99 471574. 82 MWD+IFR-AK-CAZ-SC 12968.08 35.24 83. 77 5856 .33 5710 .99 1118. 96 10718. 08 5928711 .20 471596. 06 MWD+IFR-AK-CAZ-SC 13010.00 35.24 83. 77 5890 .57 ~ 5745 .23 1121. 58 10742. 12 5928713 .70 ~ 471620 .12 •MWD+IFR-AK-CAZ-SC i • ` j ~ ~ KRU 2L-319 ~t"JI'1t~CC,~PI'til~i~?$ A1~iS~Cal, ~n~. 2 L-319 APL 501(X32055200 Well T e: SVC An le a) TS: de aI TuaING SSSV Type: NIPPLE Orig 11/2/2007 Angle @ TD: 35 deg @ (0-12159, OD:3 500 COm letion: . , iD:2.992) Annular Fluid: Last W/O: Rev Reason: TAG BOTTOM, SURFACE PERF, GLV C/O (o-a2ss, OD:9 625 I' Reference Lo : 35' KB Ref Lo Date: Last U date: 1/2/2008 . , wt:ao.oo) Last Ta : 12837 ELM TD: 13010 ftK6 Last Tag Date: 12/31/2007 _ _Max Hole Angle: 73 deg (() 2913 Casing 5trin~ -ALL STRINGS i Descri ion Size To Bottom TVD YVt Grade Thread CONDUCTOR 16.000 0 110 110 65.00 H-40 WELDED SURFACE 9.625 0 4295 2386 40.00 L-80 BTC PRODUCTION UPPER 7.000 0 12163 5240 26.00 L-80 IBT MOD PRODUCTION TAPER 5.000 12163 12183 5254 24.00 L-80 BTC PRODUCTION LOWER ___ __ 4.500 _ 12183 __ 12963 5852 12.60 L-80 IBT MOD Tubing String -TUBING I Size ~ Top ~ Bottom ~ TVD ~ Wt ~ Grade ~ Thread 3 500 0 12159 5237 9.20 LEO __ _._ _ DarF..r.~+:....c C~.mm~ra _ _ ___~ Interval N_D_ _ Zone Status Ft SPF Date Type _ Comment 12480-12500 5473-5489 20 G 1J31/2007 IPEP,F HYPERJETPERFS Chemical Mandrels/Valves I St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv Cmnt 2 7416 3449 CAMCO MG-LTS-C DMY 1.0 BK-5 0.000 0 11/1/2007 1 1. CHEMICAL INJECTION VALVE Gas Lift MandrelsNalves _ _ St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TR© Date Run Vlv CmM 1 4737 2543 CAMCO KBMG DMY 1.0 BK-5 0.000 0 11/1/2007 3 8184 3698 CAMCO KBMG DMY 1.0 BK-5 0.000 0 11/1/2007 4 10962 4631 CAMCO KBMG DMY 1.0 BK-5 0.000 0 11/1/2007 5 11918 5072 CAMCO KBMG DMY 1 0 BK 0.000 0 12/28/200 umer ~piugs, equip., e>:c.~ - wmr~c i dun DB th TVD T e 36 36 HANGER FMC TUBING HANGS 510 510 NIP CAMCO'DS' NIPPLE LOCATOR 12142-12143, OD:4.500) 'RODUCTION LOWER 12183-12963, OD:4.500, Wt12.60) Perf :12480.12500) 12073 5176 NIP CAMCO'D' NIPPLE NO GO PROFILE 2.750 12142 5225 LOCATOR BAKER LOCATOR SUB 2' ABOVE NO GO 12139' 3.000 12143 5226 SEAL BAKER SEAL ASSEMBLY w/15' STRIKE 3.000 General Notes _ _ ~~ Date I Note _ __ 1/26/200 NOTE: 12163' Beain 7" Production Casino Taoer. 12183' Beain 4.5"Production Casino to 12963' ~ ~ '~ ~ ~ c~~~ ~ ~ ~ Transmittal #700 Detail Date: 1/8/2008 To (External Party): From (PAI Contact): Email: christine.mahnken@alaska.gov Email: richard.e.elgarico@conocophillips.com First Name: Christine Last Name: Mahnken Phone (907) 793-1225 Number: Company: AOGCC Address: 333 W. 7th Ave. Ste. 100 City: Anchorage State: AK Zip Code: 99501 First Name: Ricky Last Name: Elgarico Phone (907) 265-6580 Number: Company: CPAI Address: 700 G St. ATO-1484 City: Anchorage State: AK Zip Code: 99501 Transmittal Info: Sent Via: Hand Delivery Tracking #: Justification: 2L-319 AOGCC Compliance ~~~~ ~ ~ Data Detail: l S~S~ Quantity Description Type 1 2L-319 Tarn Field Epoch Final Report with Report with CDROM enclosed color mudlog prints Attachments: Filename: None Filesize: Received By: Signature: - Approver: Signature: JAN 0 S`~00~ ~D ~~:~1 Date: u 19-Nov-07 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2L-319 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 30.04' MD Window /Kickoff Survey 0.00' MD (if applicable) Projected Survey: 13,010.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 . rr.. Date ~~ ~~_~'~ Signed `~ V Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager At4~rhmgnt~gi __ ~- • ~~Q~[~ 0~~ ~~~G!~~I~n, AL1lSSA OIL ~D r`ir~S COlITSERQ.ATI011T COIrII~IISSIOI~T Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 278-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Tarn Oil Pool, 2L-319 ConocoPhillips Alaska, Inc. Permit No: 207-112 Surface Location: 199' FNL, 777' FEL, SEC. 2?., T10N, R7E, UM Bottomhole Location: 901' FSL, 593' FEL, SEC. 13, T10N, R7E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this ~ day of August, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com August 2, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Dri112L-319 Dear Commissioners, ~'~~~ 1 ~ 2007 Alaska Oil Gas Cons. Commission Anchorage i ConocoPhillips Alaska, Inc hereby applies for a Permit to Drill for the onshore injection we112L-319. The well will be drilled and completed using Nordic Rig #3. The planned spud date for 2L-319 is September 24th, 2007. . Please fmd attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information, please contact Jason Brink at 907-265-6419. Sincerely, Randy Thomas Kuparuk Drilling Team Leader COi'lOCO~'11~EIpS ~ivE~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ,~ ~~v~D ~~t13 ~~~~ ~ ~ 2aQ~ Alaska ~Jil &t Gas Cons. Co+tuniss~oR 1 a. Type of Work: Drill ~ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service 0 Development Gas ^ Multiple Zone^ Single Zone ^ 1 c. Specify if well is proposed f r: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 2L-319 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12994' - TVD: 5895' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 199' FNL, 77T FEL, Sec. 22, T10N, R7E, UM ` 7. Property Designation: ADL 380052, 380051 Tarn Oil Pool Top of Productive Horizon: 864' FSL, 1027' FEL, Sec. 13, T10N, R7E, UM 8. Land Use Permit: ALK 4600, 4599 13. Approximate Spud Date: 9/24!2007 Total Depth: 901' FSL, 593' FEL, Sec. 13, T10N, R7E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 593' ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 460873 ~ y- 5927648 = Zone- 4 10. KB Elevation (Height above c~): 145' AMSL ~ feet 15. Distance to Nearest Well within Pool: 3135' , 2L-311 16. Deviated wells: Kickoff depth: 300 ~ ft. Maximum Hole Angle: 70° ~ deg 17. Maximum Anticipated Pressures in psig (see zo AAC 25.oa5) Downhole: 2419 psig Surface: 1828 psig ` 18. Casing Program S ecifications Setting Depth Quantity of Cement Size p Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.5# H-40 Welded 120' 40' 40' 120' 120' 15.7# AS 1 12.25" 9-5/8" 40# L-80 BTC 4262' 40' 40' 4262' 2400' 660 sx AS Lite, 170 sx DeepCRETE 8.75" 7" x 26# L-80 BTCM 12200' 40' 40' 12200' ~ 5286' 440 sx Class G w/ GasBLOK 8.75" 4.5" 12.6# L-80 IBTM 794' 12200' 5286' 12994' ' 5895' ~ see above 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Totat Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ^ BOP Sketch Drilling Program / Time v. Depth Plot ^ Shallow Hazard Analysis Q/ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ~/ 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact JaSOn Brink @ 265-6419 Printed Name ~ ndy Thomas Title Drilling Team Leader Signature C__~~~~~( l ~ /~~1~. Phone~l~'iG~~ Date Q~p~ -] ® b0 C. U J ha n All k Commission Use Only Permit to Drill Number: ~.(,7~• ~(Z, API Number: 50- /~~ .- ~S~Z --(~~ Permit Approval Date: See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed~me/thane, gas hydrates, or gas tained in shales: '~'~ \ \ ~ ~Si.r"~tc`^~ ~`,4i ~~. ~t,^ ~ Samples req'd: Yes ^ No L~ Mud log q'd: ` Yes ^ No [y~ Other: -~~~~ ~ ~®~ ~c~1i2S measures: Yes []~ No ^ rection s q' Yes [/]/ No ^ N.~ i~'~~~w` ~1~~~.~~ o`~~t~.~Zc~~.st^~c~oc~ ~ ~ A l S ~ ~ ~(~ ~ ED Y THE COMMISSION DATE: ,COMMISSIONER Form 10-401 Revised 12/2005 ubmit in Duplicate „/~~'~ ' /S ' ° 7 A~tion for Permit to Drill, Well 2L-319 Saved: 2-Aug-07 -~• Permit It -Well 2L-319 Injector Application for Permit to Drill Document Table of Contents 1. Well Name .................................................................................................................................2 Requirements of 20 AAC 25.005 (1J .................................................... .................................................................... 2 2. Location Summary ...................................................................................................................2 Requirements of 20 AAC 25.OOS(c) (2) ............................................... .................................................................... 2 Requirements of 20 AAC 25.050(b) .................................................... .................................................................... 2 3. Blowout Prevention Equipment Information ........................................................................3 Requirements of ZO AAC 25.005(c)(3) ............................................... .................................................................... 3 4. Drilling Hazards Information .................................................................................................3 Requirements of 20 AAC 25.005 (c)(4) .............................................. .................................................................... 3 5. Procedure for Conducting Formation Integrity Tests .........................................................3 Requirements of 20 AAC 25.005 (c)(5) .............................................. .................................................................... 3 6. Casing and Cementing Program ............................................................................................5 Requirements of 20 AAC 25.OOS(c) (6) ............................................... .................................................................... S 7. Diverter System Information ..................................................................................................5 Requirements of 20 AAC 25.005(c)(7) ............................................... .................................................................... S 8. Drilling Fluid Program .................................................. ..........................................................5 Requirements of 20 AAC 25.005(c)(8) .............................................. ..................................................................... S 9. Abnormally Pressured Formation Information .......... ..........................................................5 Requirements of 20 AAC 25.005 (c)(9) ............................................. ..................................................................... S 10. Seismic Analysis ............................................................. ..........................................................6 Requirements of 20 AAC 25.005 (c)(10) ........................................... ............................................................,......... 6 11. Seabed Condition Analysis ............................................ ..........................................................6 Requirements of 20 AAC 25.005 (c)(I1) ........................................... ..................................................................... 6 12. Evidence of Bonding ...................................................... ..........................................................6 Requirements of 20 AAC 25.005 (c)(12) ........................................... ..................................................................... 6 13. Proposed Drilling Program ........................................... ..........................................................6 Requirements of 20 AAC 25.005 (c)(13) ........................................... ..................................................................... 6 2L-319 APD Page 1 of 7 Printed: 2-Aug-07 OR161NAL A~tion for Permit to Drill, Well 2L-319 Saved: 2-Aug-07 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .......................................8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................................ 8 15. Attachments ..............................................................................................................................8 Attachment 1 Directional Plan .............................................................................................................................. 8 Attachment 2 Drilling Hazards Summary ............................................................................................................. 8 Attachment 3 Well Schematic ................................................................................................................................ 8 Attachment 4 Cement Summary ............................................................................................................................. 8 1. Well Name Requirements of 20 AAC 25.005 (~ Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well witTi multiple well branches, each branch must similarly be identified by a unique name and API nun2ber by adding a suffix to the name designated for the ~a~ell by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 2L-319. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Perniit to Drill must be accompmaied by each of the follrnving items, exceptfor an item already on file with the commission and identified in the application: (2) a plat tdent~ing the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the 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 199' FNL, 778' FEL, Sec. 22, T10N, R7E, UM ` NGS Coordinates RKB Elevation 145.3' AMSL rv Northings: 5,927,647 ` Eastings: 460,873 P Pad Elevation 115.3' AMSL Location at Top of Productive Interval (Bermuda 864' FSL, 1027' FEL, Sec. 13, T10N, R7E, UM NGS Coordinates . Measured De th, RKB: 12,316' Northings: 5,928,664 Eastings: 471,187 Total Vertical De th, RKB: 5,375' Total Vertical Depth, SS: 5,230' Location at Total De th 901' FSL, 593' FEL, Sec. 13, T10N, R7E, UM NGS Coordinates Measured Depth, RKB: 12,994' Northings: 5,928,699 Eastings: 471,621 Total Vertical Depth, RKB: 5,895' Total Vertical Depth, SS: 5,750' and (D) ot7zer information required by 20 SAC 2~.050(b); Requirements of 20 AAC 25.050(b) If a well is to he intentionally deviated, the application for a Permit to Drill (Form 1'0-401) must (1) include a plat, drawn to a suitable scale, slxowing 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 (2J for a77 wells x~ithin 200 feet of the proposed wellbore (AJ list the names of the operators of those wells, to the extent that those names are Inaolvn or discoverable in public records, and show that each named operator has been furnished a copy of the application by certifred mail; or (B) state Xhat the applicant is the only affected owner. 2L-319 APD Page 2 of 7 Printed: 2-Aug-07 a~IG{NAL • A~tion for Permit to Drill, Well 2L-319 Saved: 2-Aug-07 -~. 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 Drill must be accompanied by each of the following stems, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Nordic 3. 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 folloi~~ing items, exceptfor an item already on file with the commission and identifed in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the Bermuda sands in the 2L-319 area will exhibit more normal pore pressure at ~ 8.4 ppg. This pressure is predicted based on actual bottom hole pressure data from existing wells in the field together with reservoir model forecasts: 2403 psi Equivalent Mud Weight @TD = = 8.6 ppg 5375'TVD x 0.052 The maximum potential surface pressure (MPSP) while drilling 2L-319 is calculated using the predicted 2403 psi reservoir pressure, a 0.11 psi/ft gas gradient, and a Bermuda top TVD of 5375'. MPSP = ~GradientMud ,- Gradient~QS TVD GradientMua = 8.6ppg x 0.052 = 0.45 f t t Gradientcas = 0.11 f tt t TVD = 5375 ft MPSP = 0.45 psa - 0.11 pst 5375 ft =1828psi r ft ft (B) data on potential gas =ones; The well bore is not expected to penetrate any gas zones. and (C) data concenaing potential causes of hole problems such as abnoi,mally geo-pressured strata, lost circulation=ones, and pones that have a propensity for d~erential sticking; Please see Attachment 2 -Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An application for a Permit to Drill must be accompanied by each of the following itenzs, except for an item already on file with the commission and identified in the application: (S) a description of dve procedure for conducting formation integrity tests, as required under 20 AAC 25.0300; ORIGINAL 2L-319 APD Page 3 of 7 Printed: 2-Aug-07 • A~tion for Permit to Drill, Well 2L-319 Saved: 2-Aug-07 Drill out surface casing shoe and perform LOT test or FIT in accordance with the Kuparuk LOT /FIT procedure that ConocoPhillips Alaska has on file with the Commission. 2L-319 APD Page 4 of 7 Printed: 2-Aug-07 ORIGINAL ~~ A~tion for Permit to Drill, Well 2L-319 Saved: 2-Aug-07 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 t1~e following items, exceptfor an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre perforated liner, or screen to be installed; Casin and Cementin Pro ram Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) Ib/ft Grade Conn. ft ft ft Cement Program Cemented to surface with 16 24 62.5 H-40 Welded 120' Surf 120' / 120' : ASi 15.7# Cemented to Surface with 9-5/8 12-1/4 40.0 L-80 BTC 4,262 Surf 4,262% 2400' ~ 660 sx ASLite Lead, 170 sx Dee CRETE Tail 26 0 BTCM 12 200' Surf 200' / 5,286' 12 Cement Top planned @ 11,300' MD / ' 7 x 4-1/2 8-3/4 . 12.6 L-80 IBTM , 794' 12,200 % 5,286' , 12,994 % 5,895' F TVD. Cemented w/ 4,750 440 sx Class "G' w/ GasBLOK 7. Diverter System Information Requirements of 20 AAC 25.005(c) (7) An application for a Permit to Drill must be accompanied by each of the folloia~ing items, exceptfor an item already on file with the commission and ident~ed in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission undzr 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Nordic 3. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; '~ Drilling will be done using mud systems having the following properties: Surface Interval Production Interval Mud T e S ud Mud LSND Densi ( 8.5-10.2 9.6 Funnel Viscosity(sec) 150-250* 45-55 Yield Point (cP) 30-50 22-28 Plastic Viscosity b/100 s 20-60 14-25 10 sec. Gel (Ib/100 s 10-35 5-9 API Filtrate (cc) NC-6 4-6 H 8.5-9.5 9-9.5 Solids %) +10 < 5% *Spud mud should be adjusted to a FV between 150-250 sec/qt to drill gravel beds Diagram of Nordic 3 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. f 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: 2L-319 APD Page 5 of 7 Printed: 2-Aug-07 O~I~INAL A~tion for Permit to Drill, Well 2L-319 Saved: 2-Aug-07 (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25.0330; N/A -Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an Item already on file with the commission and ident~ed in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A -Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); N/A -Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill 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 showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, exceptfor an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to Attachment 3: Well Schematic. 1. MIRU Nordic 3 on 2L-319 Conductor. 2. NU and function test diverter system and prepare spud mud. 3. Place warning signs on location indicating that the rig has diverter equipment rigged up. 4. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (4262' MD/ 2400' TVD) according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. ' 5. Run and cement 9-5/8" 40.0# L-80 BTCM casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with mud. 6. Nipple down diverter, remove warning signage, and install wellhead and test to 5000 psi.. Nipple up BOPE and test to a minimum of 3500 psi. Record results. 7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. 8. RIH clean out to float collar 9. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. ~ 10. Directionally dri118-3/4" hole to 12994' MD/ 5895' TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 11. Run 7" 26# L-80 BTCM x 4-1/2" 12.3# L-80 IBTM tapered casing to TD with crossover at approximately 12200' MD. Pump cement and drop wiper plug that wipes both 7" and 4-1/2". Displace with mud, land casing hanger and bump plug. (Crossover contains a 3-1/2" tbg seal bore for landing tbg string) 12. Install packoff. 2L-319 APD Page 6 of 7 n ~ ~ ~ ~ ~ ~ Printed: 2-Aug-07 ~.A R L~ A~tion for Permit to Drill, We112L-319 Saved: 2-Aug-07 13. Run 3-1/2" tubing with GLMs and chemical injection mandrel with control line attached to OD of tbg. Land 3- 1/2" completion tubing string in the seal bore at the 7" x 4-1/2" crossover point and pressure test to 3000 psi. Record results. 14. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 15. Pressure up to shear out valve in lowest GLM and freeze protect annulus with diesel to below the permafrost. Set BPV. Release rig. 16. Clean location and RDMO Nordic 3. ~+ ~~u~~/~\ ~~~Py ,~i ~ ~~ 17. MIRU E-Line and perforate well "~` 18. Secure well and handover to production. 2L-319 APD Page 7 of 7 Printed: 2-Aug-07 R1~INAL • A~tion for Permit to Drill, Well 2L-319 Saved: 2-Aug-07 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, exceptfor an item already on file with the commission and identified in tlae application: (14) a general description of how the operator plmss to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authori_ation under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska does intend to request authorization for the use of this well for annular disposal operations at a later date provided the well meets the regulatory requirements. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary 2L-319 APD Page 8 of 7 Printed: 2-Aug-07 ORIGINAL ~onocoPhillips Alaska, In~ CPAI Plan Report Company: ConocoPhillips Alaska Inc. Date: 7!11/2007 Time: 13:47:34 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: Plan: 2L-319, True North Site: Kuparuk 2L Pad Vertical (TVD) Reference: 2L-319wp03 145.3 Well: Plan: 2L-319 Section (VS) Reference: Well (O.OON,O.OOE,84.11Azi) Wellpath: Plan: 2L-319 Survey Calculation Method: Minimum Curvature s Db: Oracle Plan Section Information h1D lncl Azim 'fVD +N/-S +E!-W DLS Build Turn T['O Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 30.00 0.00 0.00 30.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 525.00 5.63 20.00 524.64 10.37 3.77 2.50 2.50 0.00 20.00 725.00 9.39 67.99 723.06 25.72 22.28 3.50 1.88 24.00 84.35 1954.37 70.45 84.35 1623.18 130.56 764.33 5.00 4.97 1.33 17.59 11245.72 70.45 84.35 4731.58 992.13 9477.81 0.00 0.00 0.00 0.00 12115.99 40.00 85.00 5222.09 1058.43 10181.16 3.50 -3.50 0.07 179.18 12315.99 40.00 85.00 5375.30 1069.63 10309.23 0.00 0.00 0.00 0.00 2L-319wp03 T-3 12994.80 40.00 85.00 5895.30 1107.66 10743.90 0.00 0.00 0.00 0.00 Plan: 2L-319wp03 Date Composed: 7/11/2007 Version: 7 Principal: Yes Tied-to: From Well Ref. Point Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: Kuparuk 2L Pad Site Position: Northing: 5927695.13 ft Latitude: 70 12 48.272 N From: Map Easting: 461077.91 ft Lougitude: 150 18 50.048 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.30 deg Well: Plan: 2L-319 Slot Name: 2L-Oscar Well Position: +N/-S -48.28 ft Northing: 5927647.91 ft° Latitude: 70 12 47.797 N +E/-W -204.30 ft Easting : 460873.38 ft ~ Longitude: 150 18 55.979 W Position Uncertainty: 0.00 ft Wellpath: Plan: 2L-319 Drilled From: Well Ref. Point Tie-on Depth: 30.00 ft Current Datum: 2L-319wp03 Height 145.30 ft Above System Datum: Mean Sea Level Magnetic Data: ,1/18/2006 Declination: 23.61 deg Field Strength: 57535 nT Mag Dip Angle: 80.65 deg ' Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.00 0.00 0.00 84.11 Survey Program for Definitive Wellpath Date: 1/18/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name , ft ft ORIGINAL M '. ~ O '', ___ M .. a __. ... ', N 4000 3 ° 0 w ° V] O O z o Q M O ~ ~ ~ Q O O 0 Q ~ o° P .~ o ~ .--i M M y .r ~ a ~ ~ ~ a N a O O O V ° . ~. o 0 A ° ~ o o M z F _~ M O M ~. N p W ~ O M O -- ~~O ~ d fi,~° Z ~oooU A p ^ M y M ' z 3N~N !, ~~.rJ] N N N N 'LS ^ C C C ~ O W ~ ~ N ~ :~ WWWW,~~ ~~~~ o ,~._ ~~ ~ a,~ ~ a A U c~~~U v~~ o~ ~ U ~ r~ i V Q J I L 00 ~~ a¢ z N 7 o, o "' .~ 0 z~ -°'o [~ a, ~ ~ v tV 0 O r b0 00 ~~-/]] ~ M Q w W H ~ W ~ Q ~ r-~ .~ __ Q\ z N 3 ° M V W N v~ o0 N z + ~ M .a N N z a v F, ~ ~ zM k.MONN yN y~oo oo ~.~ yvl N~_ pip bn ~ ~.y ~ ~ aCa o ~ ~ ~Q ~ d~ F-~ bp~ O ~ C O O ~ v w ° w ~ 3 0 ~ , Q M U~ O W O N bM H N ~ ~. _ ~ yA~ a z p ~ o c ~ o ~ °, aQ ~~ (x 5 .......... ~ __ __ .. o O .+.. '. O O , I h .-. 3 U U ~~ ~w ~~ C7 H U /. ,~ V 11 QI 7 ~~ ~~ V] M M "' N N^^ C ~ as O O F'i 00 00 S-' O ~ Q O N w o0 Y c a. °. °o Ca o 0 ... ...... _ l.._ ... ... . !Jy . o~ ~ _ e O 0 I~/lIOOOZ] 43da4 ~ea~yaA array O O ~onocoPhillips Alaska, In~ CPAI Plan Report Company: Field: ConocoPhillips Alaska Inca Kuparuk River Unit Date: 7/11/2007 Time: 13 Co-ordinate(NE) Reference: Well: - -- :47:34 Nage: Plan: 2L-319, True North 2 ~~ Site: Ku paruk 2L Pad Vertical (TVD) Reference: 2L-31 9wp03 1 45.3 ~ R'ell: Plan: 2L-319 Section (VS) Reference: Well ( O.OON,O. OOE,84.11Azi) ~i'ellpath: Plan: 2L-319 Sun~ey Calculation Method: Minimum Curvature Db: - -- - Oracle - Survey - - - D tncl Azim TVD Sys TVD N/S E/W MapN MapE DL5 TFO Comment ft deg deg ft ft ft ft ft ft deg/100ft deg 30. 00 0.00 0.00 30.00 -115.30 0. 00 0.00 5927647.91 460873.38 0.00 0.00 100. 00 0.00 0.00 100.00 -45.30 0. 00 0.00 5927647.91 460873.38 0.00 0.00 200. 00 0.00 0.00 200.00 54.70 0. 00 0.00 5927647.91 460873.38 0.00 0.00 300. 00 0.00 0.00 300.00 154.70 0. 00 0.00 5927647.91 460873.38 0.00 0.00 KOP ~ 400. 00 2.50 20.00 399.97 254.67 2. 05 0.75 5927649.96 460874.14 2.50 0.00 500. 00 5.00 20.00 499.75 354.45 8. 20 2.98 5927656.09 460876.40 2.50 0.00 525. 00 5.63 20.00 524.64 379.34 10. 37 3.77 5927658.26 460877.21 2.50 0.00 600. 00 6.44 43.99 599.23 453.93 16. 85 7.95 5927664.72 460881.42 3.50 84.35 700. 00 8.71 64.54 698.37 553.07 24. 14 18.68 5927671.95 460892.18 3.50 60.49 725. 00 9.39 67.99 723.06 577.76 25. 72 22.28 5927673.51 460895.79 3.50 40.11 800. 00 13.02 73.03 796.62 651.32 30. 48 36.04 5927678.20 460909.57 5.00 17.59 900. 00 17.93 76.58 892.97 747.67 37. 34 61.80 5927684.93 460935.37 5.00 12.65 1000. 00 22.88 78.64 986.67 841.37 44. 75 95.85 5927692.16 460969.45 5.00 9.22 1100. 00 27.84 79.99 1077.00 931.70 52. 64 137.93 5927699.83 461011.57 5.00 7.29 1200. 00 32.82 80.97 1163.29 1017.99 60. 96 187.73 5927707.89 461061.40 5.00 6.06 1300. 00 37.80 81.71 1244.87 1099.57 69. 64 244.85 5927716.27 461118.57 5.00 5.22 1400. 00 42.79 82.30 1321.12 1175.82 78. 61 308.88 5927724.92 461182.63 5.00 4.61 1500. 00 47.78 82.79 1391.46 1246.16 87. 82 379.31 5927733.75 461253.10 5.00 4.16 1600. 00 52.76 83.21 1455.35 1310.05 97. 18 455.62 5927742.72 461329.45 5.00 3.82 1700. 00 57.76 83.57 1512.32 1367.02 106. 63 537.23 5927751.74 461411.10 5.00 3.55 1800. 00 ~ 62.75 83.90 1561.92 1416.62 116. 09 623.50 5927760.76 461497.41 5.00 3.34 1900. 00 67.74 84.20 1603.79 1458.49 125. 50 713.79 5927769.70 461587.74 5.00 3.18 1954. 37 70.45 84.35 1623.18 1477.88 130. 56 764.33 5927774.50 461638.30 5.00 3.05 2000. 00 70.45 84.35 1638.45 1493.15 134. 79 807.12 5927778.51 461681.11 0.00 0.00 2100 .00 70.45 84.35 1671.90 1526.60 144. 07 900.90 5927787.29 461774.93 0.00 0.00 2200 .00 70.45 84.35 1705.36 1560.06 153. 34 994.68 5927796.08 461868.74 0.00 0.00 2300 .00 70.45 84.35 1738.81 1593.51 162 .61 1088.46 5927804.86 461962.56 0.00 0.00 2400 .00 70.45 84.35 1772.27 1626.97 171 .89 1182.24 5927813.65 462056.38 0.00 0.00 2500 .00 70.45 84.35 1805.72 1660.42 181 .16 1276.02 5927822.44 462150.20 0.00 0.00 2600 .00 70.45 84.35 1839.18 1693.88 190 .43 1369.80 5927831.22 462244.02 0.00 0.00 2700 .00 70.45 84.35 1872.63 1727.33 199 .70 1463.58 5927840.01 462337.84 0.00 0.00 2800 .00 70.45 84.35 1906.09 1760.79 208 .98 1557.36 5927848.79 462431.65 0.00 0.00 2900 .00 70.45 84.35 1939.54 1794.24 218 .25 1651.15 5927857.58 462525.47 0.00 0.00 3000 .00 70.45 84.35 1973.00 1827.70 227 .52 1744.93 5927866.37 462619.29 0.00 0.00 3100 .00 70.45 84.35 2006.45 1861.15 236 .80 1838.71 5927875.15 462713.11 0.00 0.00 3200 .00 70.45 84.35 2039.90 1894.60 246 .07 1932.49 5927883.94 462806.93 0.00 0.00 3300 .00 70.45 84.35 2073.36 1928.06 255 .34 2026.27 5927892.72 462900.74 0.00 0.00 3400 .00 70.45 84.35 2106.81 1961.51 264 .61 2120.05 5927901.51 462994.56 0.00 0.00 3500 .00 70.45 84.35 2140.27 1994.97 273 .89 2213.83 5927910.29 463088.38 0.00 0.00 3600 .00 70.45 84.35 2173.72 2028.42 283 .16 2307.61 5927919.08 463182.20 0.00 0.00 3700 .00 70.45 84.35 2207.18 2061.88 292 .43 2401.39 5927927.87 463276.02 0.00 0.00 3800 .00 70.45 84.35 2240.63 2095.33 301 .70 2495.17 5927936.65 463369.84 0.00 0.00 3900 .00 70.45 84.35 2274.09 2128.79 310 .98 2588.95 5927945.44 463463.65 0.00 0.00 4000 .00 70.45 84.35 2307.54 2162.24 320 .25 2682.73 5927954.22 463557.47 0.00 0.00 4100 .00 70.45 84.35 2341.00 2195.70 329 .52 2776.51 5927963.01 463651.29 0.00 0.00 4200 .00 70.45 84.35 2374.45 2229.15 338 .80 2870.29 5927971.80 463745.11 0.00 0.00 4262 .32 70.45 84.35 2395.30 2250.00 344 .57 2928.73 5927977.27 463803.57 0.00 0.00 9 5/8" x 12 1/4" 4300 .00 70.45 84.35 2407.91 2262.61 348 .07 2964.07 5927980.58 463838.93 0.00 0.00 4400 .00 70.45 84.35 2441.36 2296.06 357 .34 3057.85 5927989.37 463932.74 0.00 0.00 4500 .00 70.45 84.35 2474.82 2329.52 366 .61 3151.63 5927998.15 464026.56 0.00 0.00 4591 .12 70.45 84.35 2505.30 2360.00 375 .06 3237.09 5928006.16 464112.05 0.00 0.00 C80 (K10) 4600 .00 70.45 84.35 2508.27 2362.97 375 .89 3245.42 5928006.94 464120.38 0.00 0.00 4700.00 70.45 84.35 2541.73 2396.43 385.16 3339.20 5928015.72 464214.20 0.00 0.00 ~onocoPhillips Alaska, In~ CPAI Plan Report -- Company: - ConocoPhillips Alaska Ina Date: 7/11/2007 Time. 13:47:34 - Yage: 3 Field. Kuparuk River Un it Co-ordi nate(NE) Reference: Well: Plan: 2L -319, True North Site: Kuparuk 2L Pad Vertical (T~ D) Reference: 2L-31 9wp03 1 45.3 R'ell: Plan : 2L-319 Section (VS) Referen ce: Well (O.OON,O .OOE,84.11Azi) N'ellpath: Plan : 2L-319 Surrey Calculation Method: Mi nimum Curvature Db: Oracle Sun ey D1D Incl Azim TVD Sys T~' D N/S E/W A1apN MapF. DLS TFO Comment, ft deg deg ft ft ft ft ft ft deg/100ft deg 4800. 00 70.45 84. 35 2575. 18 2429. 88 394.43 3432.98 5928024. 51 464308. 02 0.00 0.00 4900. 00 70.45 84. 35 2608. 64 2463. 34 403. 71 3526.76 5928033. 30 464401. 83 0.00 0.00 5000. 00 70.45 84. 35 2642. 09 2496. 79 412. 98 3620.54 5928042. 08 464495. 65 0.00 0.00 5100. 00 70.45 84. 35 2675. 54 2530. 24 422. 25 3714.32 5928050. 87 464589. 47 0.00 0.00 5200. 00 70.45 84. 35 2709. 00 2563. 70 431. 52 3808.10 5928059. 65 464683. 29 0.00 0.00 5300. 00 70.45 84. 35 2742. 45 2597. 15 440. 80 3901.88 5928068. 44 464777. 11 0.00 0.00 5400. 00 70.45 84. 35 2775. 91 2630. 61 450. 07 3995.66 5928077. 22 464870. 93 0.00 0.00 5500. 00 70.45 84. 35 2809. 36 2664. 06 459. 34 4089.44 5928086. 01 464964. 74 0.00 0.00 5600. 00 70.45 84. 35 2842. 82 2697. 52 468. 62 4183.22 5928094. 80 465058. 56 0.00 0.00 5700. 00 70.45 84. 35 2876. 27 2730. 97 477. 89 4277.00 5928103. 58 4651.52. 38 0.00 0.00 5800. 00 70.45 84. 35 2909. 73 2764. 43 487. 16 4370.78 5928112. 37 465246. 20 0.00 0.00 5900. 00 70.45 84. 35 2943. 18 2797. 88 496. 43 4464.56 5928121. 15 465340. 02 0.00 0.00 6000. 00 70.45 84. 35 2976. 64 2831. 34 505. 71 4558.34 5928129. 94 465433. 83 0.00 0.00 6100. 00 70.45 84. 35 3010. 09 2864. 79 514. 98 4652.12 5928138. 73 465527. 65 0.00 0.00 6200. 00 70.45 84. 35 3043. 55 2898. 25 524. 25 4745.90 5928147. 51 465621. 47 0.00 0.00 6300. 00 70.45 84. 35 3077. 00 2931. 70 533. 52 4839.68 5928156. 30 465715. 29 0.00 0.00 6400. 00 70.45 84. 35 3110. 46 2965. 16 542. 80 4933.47 5928165. 08 465809. 11 0.00 0.00 6500. 00 70.45 84. 35 3143. 91 2998. 61 552. 07 5027.25 5928173. 87 465902. 93 0.00 0.00 6600. 00 70.45 84. 35 3177. 37 3032. 07 561. 34 5121.03 5928182. 65 465996. 74 0.00 0.00 6700. 00 70.45 84. 35 3210. 82 3065. 52 570. 62 5214.81 5928191. 44 466090. 56 0.00 0.00 6800. 00 70.45 84. 35 3244. 28 3098. 98 ~ 579. 89 5308.59 5928200. 23 466184. 38 0.00 ~ 0.00 6900. 00 70.45 84. 35 3277. 73 3132. 43 589 .16 5402.37 5928209. 01 466278. 20 0.00 0.00 7000 .00 70.45 84. 35 3311. 18 3165. 88 598 .43 5496.15 5928217. 80 466372. 02 0.00 0.00 7100 .00 70.45 84 .35 3344. 64 3199. 34 607 .71 5589.93 5928226. 58 466465. 83 0.00 ` 0.00 7200 .00 70.45 84 .35 3378. 09 3232. 79 616 .98 5683.71 5928235. 37 466559. 65 0.00 0.00 7300 .00 70.45 84 .35 3411. 55 3266. 25 626 .25 5777.49 5928244. 16 466653. 47 0,00 0.00 7400 .00 70.45 84 .35 3445 .00 3299. 70 635 .53 5871.27 5928252. 94 466747. 29 0.00 0.00 7500 .00 70.45 84 .35 3478 .46 3333. 16 644 .80 5965.05 5928261. 73 466841 .11 0.00 0.00 7600 .00 70.45 84 .35 3511 .91 3366. 61 654 .07 6058.83 5928270. 51 466934 .92 0.00 0.00 7700 .00 70.45 84 .35 3545 .37 3400. 07 663 .34 6152.61 5928279. 30 467028 .74 0.00 0.00 7800 .00 70.45 84 .35 3578 .82 3433 .52 672 .62 6246.39 5928288. 08 467122 .56 0.00 0.00 7900 .00 70.45 84 .35 3612 .28 3466 .98 681 .89 6340.17 5928296. 87 467216 .38 0.00 0.00 8000 .00 70.45 84 .35 3645 .73 3500 .43 691 .16 6433.95 5928305. 66 467310 .20 0.00 0.00 8100 .00 70.45 84 .35 3679 .19 3533. 89 700 .44 6527.74 5928314. 44 467404 .02 0.00 0.00 8200 .00 70.45 84 .35 3712 .64 3567 .34 709 .71 6621.52 5928323. 23 467497 .83 0.00 0.00 8300 .00 70.45 84 .35 3746 .10 3600 .80 718 .98 6715.30 5928332. 01 467591 .65 0.00 0.00 8400 .00 70.45 84 .35 3779 .55 3634 .25 728 .25 6809.08 5928340. 80 467685 .47 0.00 0.00 8500 .00 70.45 84 .35 3813 .01 3667 .71 737 .53 6902.86 5928349. 58 467779 .29 0.00 0.00 8600 .00 70.45 84 .35 3846 .46 3701 .16 746 .80 6996.64 5928358 .37 467873 .11 0.00 0.00 8656 .31 70.45 84 .35 3865 .30 3720 .00 752 .02 7049.45 5928363 .32 467925 .94 0.00 0.00 C50 8700 .00 70.45 84 .35 3879 .91 3734 .61 756 .07 7090.42 5928367 .16 467966 .92 0.00 0.00 8800 .00 70.45 84 .35 3913 .37 3768 .07 765 .34 7184.20 5928375 .94 468060 .74 0.00 0.00 8900 .00 70.45 84 .35 3946 .82 3801 .52 774 .62 7277.98 5928384 .73 468154 .56 0.00 0.00 9000 .00 70.45 84 .35 3980 .28 3834 .98 783 .89 7371.76 5928393 .51 468248 .38 0.00 0.00 9100 .00 70.45 84 .35 4013 .73 3868 .43 793 .16 7465.54 5928402 .30 468342 .20 0.00 0.00 9200 .00 70.45 84 .35 4047 .19 3901 .89 802 .44 7559.32 5928411 .09 468436 .02 0.00 0.00 9300 .00 70.45 84 .35 4080 .64 3935 .34 811 .71 7653.10 5928419 .87 468529 .83 0.00 0.00 9400 .00 70.45 84 .35 4114 .10 3968 .80 820 .98 7746.88 5928428 .66 468623 .65 0.00 0.00 9500 .00 70.45 84 .35 4147 .55 4002 .25 830 .25 7840.66 5928437 .44 468717 .47 0.00 0.00 9600 .00 70.45 84 .35 4181 .01 4035 .71 839 .53 7934.44 5928446 .23 468811 .29 0.00 0.00 9700 .00 70.45 84 .35 4214 .46 4069 .16 848 .80 8028.22 5928455 .01 468905 .11 0.00 0.00 9792.18 70.45 84 .35 4245 .30 4100 .00 857 .35 8114.67 5928463 .11 468991 .59 0.00 0.00 C40 ORIGINAL ~onocoPhillips Alaska, In~ CPAI Plan Report Cmnpany: ConocoPhillips Alaska Inc. Date: 7/11/2007 Time: 13 :47:34 Pagr. 4 Field: K uparuk River Unit Co-ordi nate(NE) Reference: Well: Plan: 2L-319, True North Site: K uparuk 2L Pad Vertical (TVD) Reference: 2L -31 9wp03 145.3 Nell: Pl an: 2L-319 Section (VS) Reference: Well ( O.OON,O.OOE,84.11Azi) W'eltpath: Pl an: 2L-319 Survey Calculation Meth od: Mi nimum Curvature Db: Oracle Surve~~ MD Incl Azim TVD S~~s TV D N/S E/1V MapN MapE DLS I'FO Comment ft deg deg ft ft ft ft ft ft deg/100ft deg 9800. 00 70.45 84. 35 4247. 92 4102. 62 858. 07 8122.00 5928463.80 468998. 92 0.00 0.00 9900. 00 70.45 84. 35 4281. 37 4136. 07 867. 35 8215.79 5928472.59 469092. 74 0.00 0.00 10000. 00 70.45 84. 35 4314. 83 4169. 53 876. 62 8309.57 5928481.37 469186. 56 0.00 0.00 10100. 00 70.45 84. 35 4348. 28 4202. 98 885. 89 8403.35 5928490.16 469280. 38 0.00 0.00 10200. 00 70.45 84. 35 4381. 74 4236. 44 895. 16 8497.13 5928498.94 469374. 20 0.00 0.00 10300. 00 70.45 84. 35 4415. 19 4269. 89 904. 44 8590.91 5928507.73 469468. 01 0.00 0.00 10360. 11 70.45 84. 35 4435. 30 4290. 00 910. 01 8647.28 5928513.01 469524. 41 0.00 0.00 C37 10400. 00 70.45 84. 35 4448. 65 4303. 35 913. 71 8684.69 5928516.52 469561. 83 0.00 0.00 10500. 00 70.45 84. 35 4482. 10 4336. 80 922. 98 8778.47 5928525.30 469655. 65 0.00 0.00 10600. 00 70.45 84. 35 4515. 55 4370. 25 932. 25 8872.25 5928534.09 469749. 47 0.00 0.00 10700. 00 70.45 84. 35 4549. 01 4403. 71 941. 53 8966.03 5928542.87 469843. 29 0.00 0.00 10763. 64 70.45 84. 35 4570. 30 4425. 00 947. 43 9025.71 5928548.46 469902. 99 0.00 0.00 iceberg sand/silt 10800. 00 70.45 84. 35 4582. 46 4437. 16 950. 80 9059.81 5928551.66 469937. 11 0.00 0.00 10900. 00 70.45 84. 35 4615. 92 4470. 62 960. 07 9153.59 5928560.44 470030. 92 0.00 0.00 11000. 00 70.45 84. 35 4649. 37 4504. 07 969. 35 9247.37 5928569.23 470124. 74 0.00 0.00 11100. 00 70.45 84. 35 4682. 83 4537. 53 978. 62 9341.15 5928578.02 470218. 56 0.00 0.00 11200. 00 70.45 84. 35 4716. 28 4570. 98 987. 89 9434.93 5928586.80 470312. 38 0.00 0.00 11245. 72 70.45 84. 35 4731. 58 4586. 28 992. 13 9477.81 5928590.82 470355. 27 0.00 0.00 11300. 00 68.56 84. 38 4750. 58 4605. 28 997. 12 9528.41 5928595.55 470405. 89 3.50 179.18 11400. 00 65.06 84. 44 4789. 96 4644. 66 1006. 07 9619.87 5928604.02 470497. 39 3.50 179.17 11500. 00 ~ 61.56 84. 50 4834. 88 4689. 58 1014. 69 9708.78 5928612.17 470586. 34 3.50 179.15 11600. 00 58.06 84. 56 4885. 16 4739. 86 1022. 93 9794.81 5928619.97 470672. 40 3.50 179.12 11700. 00 54.56 84. 63 4940. 63 4795. 33 1030. 76 9877.63 5928627.37 470755. 25 3.50 179.09 11800. 00 51,06 84. 70 5001. 07 4855. 77 1038. 17 9956.93 5928634.37 470834. 58 3.50 179.05 11806. 72 ` 50.82 84. 71 5005. 30 4860. 00 1038. 65 9962.13 5928634.82 470839. 78 3.50 179.01 T7 11900 .00 47.56 84. 79 5066. 26 4920. 96 1045 .11 1.OOe04 5928640.92 470910. 10 3.50 179.00 12000 .00 44.06 84. 88 5135. 95 4990. 65 1051 .57 1.01 e04 5928647.01 470981. 52 3.50 178.95 12100 .00 40.56 84 .98 5209. 89 5064. 59 1057 .52 1.01e04 5928652.61 471048. 59 3.50 178.89 12115 .99 40.00 85 .00 5222. 09 5076. 79 1058 .43 1.01 e04 5928653.46 471058. 89 3.50 178.81 12133 .23 40.00 85 .00 5235. 30 5090. 00 1059 .39 1.01 e04 5928654.37 471069. 93 0.00 0.00 T4 12185 .45 40.00 85 .00 5275 .30 5130. 00 1062 .32 1.02e04 5928657:12 471103. 38 0.00 0.00 7"x 8 3/4" long stri 12200 .00 40.00 85 .00 5286 .45 5141. 15 1063 .13 1.02e04 5928657.89 471112. 70 0.00 0.00 12300 .00 40.00 85 .00 5363 .05 5217. 75 1068 .74 1.02e04 5928663.16 471176 .76 0.00 0.00 12315 .99 40.00 85 .00 5375 .30 5230. 00 1069 .63 1.03e04 5928664.00 471187 .00 0.00 0.00 2L-319wp03 T-3 12400 .00 40.00 85 .00 5439 .66 5294 .36 1074 .34 1.03e04 5928668.43 471240 .81 0.00 0.00 12485 .69 40.00 85 .00 5505 .30 5360 .00 1079 .14 1.04e04 5928672.94 471295 .71 0.00 0.00 T2 Base Reservoir 12500 .00 40.00 85 .00 5516 .26 5370 .96 1079 .94 1.04e04 5928673.70 471304 .87 0.00 0.00 12577 .07 40.00 85 .00 5575 .30 5430 .00 1084 .26 1.04e04 5928677.76 471354 .24 0.00 0.00 C35 base (K3) 12600 .00 40.00 85 .00 5592 .86 5447 .56 1085 .54 1.04e04 5928678.97 471368 .93 0.00 0.00 12700 .00 40.00 85 .00 5669 .47 5524 .17 1091 .14 1.05e04 5928684.24 471432 .98 0.00 0.00 12746 .77 40.00 85 .00 5705 .30 5560 .00 1093 .76 1.05e04 5928686.70 471462 .94 0.00 0.00 Top Albian 12800 .00 40.00 85 .00 5746 .07 5600 .77 1096 .75 1.06e04 5928689.51. 471497 .04 0.00 0.00 12900 .00 40.00 85 .00 5822 .68 5677 .38 1102 .35 1.06e04 5928694.78 471561 .09 0.00 0.00 12994 .80 40.00 85 .00 5895 .30 , 5750 .00 1107 .66 1.07e04 5928699.77 471621 .82 0.00 0.00 4 1 /2" x 8 3/4" Ion Targets ~ ~ Map D1ap <- --- Latitu de ----> <--- Longitude ---> Nam e Descr iptio n TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Uir. ft ft ft ft ft 2L-319wp03 T-3 5375.30 1069.63 10309.23 5928664.00 471187.00 7 0 12 58. 248 N 150 13 56.656 W -Circle (Radius: 100) -Plan hit target ORIGINAL ~onocoPhillips Alaska, In~ CPAI Plan Report Company: ConocoPhillips Alaska Inc. Date: 7/11/2007 Time: 13:47:34 Pape: Field: Kuparuk Rive r Unit Co-ordinate(NE) Reference: Well: Plan: 2L-319, True North Site: Kuparuk 2L P ad Vertical (TVD) Reference: 2L-319wp03 145.3 R'cII: Plan: 2L-319 Section (VS) Reference: Well (O.OON,O.OOE,84.11Azi) ~Vellpath: Plan: 2L-319 Suney Calculation Method: Minimum Curvature Db: Oracle Annotation _ _ '~fD TVll i ft ft ___ t a 300.00 300.00 KOP Casing Points __ MD '['VD Diameter Hole Sice Name ft ft in in 4262.32 2395.30 9.625 12.250 9 5/8" x 12 1/4" 12185.45 5275.30 7.000 8.750 7"x 8 3/4" long string 12994.80 5895.30 4.500 8.750 4 1/2" x 8 3/4" long string Formations - - ~1D TVll Formations - Lithology Dip Ingle Dip Direction ft ft deg deg 4591.12 2505.30 C80 (K10) 0.00 0.00 8656.31 3865.30 C50 0.00 0.00 9792.18 4245.30 C40 0.00 0.00 10360.11 4435.30 C37 0.00 0.00 10763.64 4570.30 iceberg sand/silt 0.00 0.00 11806.72 5005.30 T7 0.00 0.00 12133.23 5235.30 T4 0.00 0.00 12315.99 5375.30 T3 Top Reservoir 0.00 0.00 12485.69 5505.30 T2 Base Reservoir 0.00 0.00 12577.07 5575.30 C35 base (K3) 0.00 0.00 12746.77 5705.30 Top Albian 0.00 0.00 , ORIGINAL ~onocoPhillips Alaska, In~ Anticollision Report Company: Conoco Phillips Alaska Inc. Date: 7/11/2007 Time: 13:53:19 Page: 1 Field: Kuparuk River Unit Reference Site: Kuparuk 2L Pa d Co-ordinate(NE) Refer ence: Well: Pla n: 2L-319, T rue North Reference ~'1'ell: Plan: 2L-319 Vertical (TV D) Referen ce: 2L-319wp03 145.3 Reference Wellpath: Plan: 2L-319 Db: Oracle GLOBAL SCAN APP LIED: All well paths within 200'+ 100/1000 of reference Reference: Plan: 2L-319wp03 & NOT PLANNED PR Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 30.00 to 1 2994.80 ft Scan Method: Trav Cylinder North Maximum Radius: 1496.48 ft Error Surface: Ellipse + Casing Casing Points ~7D T~'D Diameter Hole Size Name ft ft in in 4262.32 2395.30 9.625 12.250 9 5/8" x 12 1/4" 12185.45 5275.30 7.000 8.750 7"x 8 3/4" long string 12994.80 5895.30 4.500 8.750 4 1/2" x 8 3/4" long string Plan: 2L-319wp03 Date Composed: 7/ 11/2007 Version: 7 Principal: Yes Tied-to: From Well Ref. Point Summary _ <- --------------- Offset ~'1'ellpath - ---------------- ---> __ Reference _ Offset (tr-Ctr No-Co Allowable 1 Site ~~'ell Wellpath MD A1D Distance Arca Deviation V1'arning I ft ft ft ft ft Kuparuk 2L Pad 2L-03 2L-03 Baker Plan VO 1372.83 1275.00 148.83 23.15 125.67 Pass: Major Risk Kuparuk 2L Pad 2L-03 2L-03 V2 1385.39 1275.00 156.64 23.68 132.97 Pass: Major Risk Kuparuk 2L Pad 2L-305 2L-305 V2 1295.06 1225.00 96.23 20.94 75.29 Pass: Major Risk Kuparuk 2L Pad 2L-307 2L-307 V2 1762.23 1625.00 139.21 44.46 94.75 Pass: Major Risk Kuparuk 2L Pad 2L-309 2L-309 V5 1417.53 1325.00 150.54 23.54 127.00 Pass: Major Risk Kuparuk 2L Pad 2L-309 2L-309P61 V6 1417.53 1325.00 150.54 23.54 127.00 Pass: Major Risk Kuparuk 2L Pad 2L-311 2L-311 VO 1048.57 1000.00 123.50, 17.09 106.41 Pass: Major Risk Kuparuk 2L Pad 2L-313 2L-313 V2 1016.54 1000.00 42.96 16.38 26.58 Pass: Major Risk Kuparuk 2L Pad 2L-315 2L-315 V2 881.56 875.00 36.40 14.43 21.97 Pass: Major Risk Kuparuk 2L Pad 2L-317 2L-317 V2 267.48 275.00 30.80 4.80 26.00 Pass: Major Risk Kuparuk 2L Pad 2L-317 2L-317A V6 267.48 275.00 30.80 4.80 26.00 Pass:' Major Risk Kuparuk 2L Pad 2L-321 2L-321 V2 373.61 375.00 29.55 6.27 23.28 Pass: Major Risk Kuparuk 2L Pad 2L-323 2L-323 V2 373.15 375.00 60.03 6.20 53.82 Pass: Major Risk Kuparuk 2L Pad 2L-325 2L-325 V2 299.07 300.00 92.03 5.32 86.71 Pass: Major Risk Kuparuk 2L Pad 2L-329 2L-329 V2 371.63 375.00 148.76 6.60 142.16 Pass: Major Risk Kuparuk 2L Pad 2L-329 2L-329A V2 371.63 375.00 148.76 6.60 142.16 Pass: Major Risk Kuparuk 2L Pad Plan: 2L-302 Plan: 2L-302 VO Plan: 1301.15 1200.00 195.77 21.24 174.53 Pass: Major Risk Kuparuk 2L Pad Plan: 2L-319 Prelim: 2L-319ST V1 PI 12994.80 1 2993.50 0.00 250.55 -250.55 FAIL: Major Risk Kuparuk 2L Pad Plan: 2L-330 Plan: 2L-330 V2 Plan: 395.96 400.00 165.59 8.03 157.56 Pass: Major Risk Kuparuk 2L Pad TDed: 2L-327 Plan: 2L-327wp07 VO PI 346.83 350.00 120.43 7.21 .113.22 Pass: Major Risk Kuparuk 2L Pad TDed: 2L-327 TDed: 2L-327 V8 371.16 375.00 119.39 6.98 112.41 Pass: Major Risk Site: Kuparuk 2L Pad Well: 2L-03 Rule Assigned: Major Risk Wellpath: 2L-03 Baker Plan VO - Inter-Site Error: -- 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable ~ MD TVll MD TVD Ref Offset TFO+AZI T)'O-HS Casing/ H~istance Area Deviation Warning ~ ft ft ft ft ft ft deg deg in ft ft ft 43.30 43.30 50.00 50.00 0.02 0.01 76.74 76.74 7.000 239.97 1.00 238.97 Pass 68.30 68.30 75.00 75.00 0.04 0.02 76.74 76.74 7.000 239.97 1.36 238.61 Pass 93.30 93.30 100.00 100.00 0.07 0.04 76.74 76.74 7.000 239.97 1.71 238.25 Pass 118.30 118.30 125.00 125.00 0.12 0.05 76.74 76.74 7.000 239.97 2.13 237.84 Pass 143.30 143.30 150.00 150.00 0.18 0.06 76.74 76.74 7.000 239.97 2.56 237.41 Pass 168.30 168.30 175.00 175.00 0.23 0.08 76.74 76.74 7.000 239.97 2:99 236.97 Pass 193.30 193.30 200.00 200.00 0.29 0.09 76.74 76.74 7.000 239.97 3.43 236.54 Pass 218.30 218.30 225.00 225.00 0.35 0.11 76.74 76.74 7.000 239.97 3.86 236.11 Pass 243.30 243.30 250.00 250.00 0.40 0.12 76.74 76.74 7.000 239.97 4.29 235.68 Pass 268.30 268.30 275.00 275.00 0.46 0.13 76.74 76.74 7.000. 239.97 4.72 235.24 Pass 293.30 293.30 300.00 300.00 0.52 0.15 76.74 76.74 7.000 239.97 5.16 234.81 Pass 319.41 319.41 325.00 325.00 0.58 0.18 76.74 56.74 7.000 240.01 5.64 234.37. Pass 345.94 345.93 350.00 350.00 0.63 0.21 76.76 56.76 7.000. 240.06 6.13 233.93 Pass 372.46 372.45 375.00 374.99 0.69 0.24 76.80 56.80 7.000 240.11 6.62 233.49 Pass 398.98 398.95 400.00 399.98 0.75 0.26 76.87 56.87 7.000 240.17 7.11 233.06 Pass RAM ORIGINAL 00000000 OOOOv~O~n0000 • OtnO~ON V'~t~OViO~n ~IIIIII Q F U ~ ~. 0 0 0 0 0 0 0 0 0 _ M v~ O v1 ~"O ~n O O da ~ r [L N~~.,4~.. .-n~~NN a ~ ;'~ / vo ~ ss~°~~~~~ P~ . n. 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F ~~ ` - ~ M ` \ o ">~g~° a~~ z S N ~ ~~_ -- U O ~48~ M E i 3N-N~ S ~m N advf =gyp`' g - - - - .- .n o 5' i 0 i $ r m~~ u _ - - '``F 8'y3 - ----- -- = -_ __- __-_ ? _ IIIIIIIIIIIIIIIIIIII I L` 0oooooc O ~ ~ ~ ~ o v X1111 ~i i ~~~ ~ ~ ~ ~ ~ N M •-.~ .-. ~ '. M ra N_ l~ ..r O .. .a ,.] ~N r 0 M N ~ zs h 9 ~ 'c' fi+: ~_ ~~-~~ ~3`;~ a o~ $v ~ ~.~~y~ _~~.~ ~ ~C~e~ 3 • • 2L-319 Drilling Hazards Summary Surface Hole Risks Event Risk Level Miti ation Strate /Contin enc Broach of conductor Low Monitor cellar & pad continuously durin interval Gas Hydrates Moderate Minimum mud weight of 10.0 ppg. If observed - ~ control drill, reduce pump rates, reduce drilling fluid tem eratures, addition of Lecithin Running sands & gravel Moderate Maintain planned mud parameters, Increase mud weight/viscosity, Use weighted sweeps, monitor fill on connections Hole swabbing/Tight hole on Moderate Circulate hole clean prior to trip, proper hole filling trips (use of tri sheets), pumpin out of hole as needed Production Hole Risks Event Risk Level Miti ation Strate /Contin enc Insufficient or undetermined Low Importance of LOT communicated to all parties, all LOT ~ ~ parties familiar with LOT procedure. Test will be carried out until leak off is observed or to an FIT of 16 MW e uivalent Swabbing Campaignian sands Moderate Minimum mud weight of 9.6 ppg, mandatory flow (50 ft TVD below C-80) check above sands on all tri s High reservoir pressure Low i Contingency 7" top set above the Bermuda is available High ECD /Tight hole on trips/ Moderate Condition mud & clean hole prior to trips. Monitor Swabbing ECDs with PWD tool while drilling across reservoir interval. Hole cleaning best practices. Backream out on trips as a last resort, proper hole filling (use of tri sheets) Lost circulation Moderate Keep hole clean -use PWD to monitor hole cleaning. If losses occur -reduce pump rates and mud rheology, use LCM ~~~~~~~ 2L-319 Injec~r wp(03) ~ ~-`~ Proposed Completion Schematic ~~~~~~~~'~~~ 3-1/2" Completion String Circulate corrosion inhibitor up to bottom GLM before landing tubing hanger. 3 '/z" 9.2# L-80 EUE 8rd Spaceout Pups as Required 3 'h" 9.2# L-80 EUE 8rd Tubing to Surface 16" 62.6# 3 '/z" Camco 'DS' nipple w/ 2.875" No-Go Profile. 3 '/z" x 6' L-80 EUE 8rd crossover handling pups installed above and below, set at +/- 500' MD Completion, from hanger to `DS' nipple, to be be drifted to 2.91 ". Station # Depth (MD) Depth ~TVD~ GLM1 4727 2550 GLM2 8165 3700 GLM3 10961 4636 GLM4 2 jts above sliding sleeve Surface csg. 9-5/8" 40# L-80 BTC F/- 4262' MD / 2,400' TVD 3-'/z" x 1" KBMG-LTS Schlumber-~er Chemical Inj Mandrel n_ XXXX' MD 3 ''/z" x 1" Camco 'KBMG' mandrels with dummy valves 3 ''/z" x 6' L-80 with EUE 8rd crossover handling pups installed above and below. Lowest 3 '/z" x 1" Camco'KBMG' mandrel w/ shear valve, pinned for 2000 psi shear (casing to tubing differential). Load rest of GLMs with dummy valves 3 %z" Baker'CMU' sliding sleeve w/ 2.813" Camco DS profile EUE 8rd, with 3 '/2" x 6' L-80 EUE 8rd handling crossover pups installed 7" 26# L-80 BTCM x 4 ''/z" 12.6# L-80 IBTM seal bore extension at +/- 12,200' MD / 5286' TVD 3'/s" Camco 'D' nipple w/ 2.75" No-Go profile. 3 Yi' x 12' L-80 EUEBRD Mod spaceout pup installed above, 3'/z' x 6' handling pup installed below 3 ''/z" Baker 80-40 GBH-22 casing seal assembly w/ 15' stroke, 3 '/z" x 6' L-80 EUE 8rd crossover handling pup installed on top Baker Seal Bore Extension SBE set at +/- 200' MD above the top of the Bermuda Target interval and just above 7" x 4-''/z" crossover Bermuda top at 12316' MD/ 5375' TVD Production csg 7" 26# L-80 BTCM x PESI 4-'/z" IBTM float shoe 4 ''/z" 12.6# L-80 IBT Mod t oar +/- 12,994' MD / 5895' TVD ... O 1 \ ~ ~~~~ 7/25/2007 JAB ' Schlumberger CemCADE Preliminary Job Design 9 5/8" Surface Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Nordic 3 Location: Tarn Client: ConocoPhillips Alaska, Inc. Revision Date: 7/27/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 80' MD I < Base of Permafrost at 1,600' MD (' ND) < Top of Tail at 3,462' MD < 9 5/8", 40.0# casing in 12 1/4" OH TD at 4,262' MD (2,400' ND) Mark of Schlumberger Volume Calculations and Cement Systems Volumes are based on 300% excess in the permafrost and 50% excess below the permafrost. The top of the tail slurry is designed to be at 3,462' MD. Lead Slurry Minimum pump time: 280 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.4895 ft3/ft x (80') x 1.00 (no excess) = 119.2 ft3 0.3132 ft3/ft x (1600' - 80') x 4.00 (300% excess) = 1904.3 ft3 0.3132 ft3/ft x (3462' - 1600') x 1.50 (50% excess) = 874.8 ft3 119.2 ft3 + 1904.3 ft3+ 874.8 ft3 = 2898.3 ft3 2898.3 ft3 / 4.45 ft3/sk = 651.3 sks Round up to 660 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 190 min. (pump time plus 120 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.3132 ft3/ft x (4262' - 3462') x 1.50 (50% excess) = 375.8 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 375.8 ft3 + 34.1 ft3 = 409.9 ft3 409.9 ft3/ 2.47 ft3/sk = 166 sks Round up to 170 sks BHST = 51 ~, Estimated BHCT = 59~. (BHST calculated using a gradient of 2.2/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time, Cumulative Stage Volume Time (bpm) tbbll (min) (mint CW 100 5 50 10.0 10.0 Drop Bottom Plug 15.0 25.0 MudPUSH II 5 50 10.0 35.0 Lead Slurry 6 523 87.2 122.2 Tail Slurry 5 75 15.0 137.2 Drop Top Plug 5.0 142.2 Water 5 20 4.0 146.2 Switch to Rig Pum s 5.0 151.2 Displacement 7 287 41.0 192.2 Slow Rate 3 10 3.3 195.5 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: 10.5 ppg MudPUSH" I I, Pv = 17-21, TY = 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ~!~~'~~. ' Schlumberger CemCADE Preliminary Job Design 7" to 4 1 /2" Lon strin Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Nordic 3 Location: Tarn Client: ConocoPhillips Alaska Revision Date: 7/27/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907)265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com ^ revlous sg. 9 5/8", 40# casing @ 4262' MD 7", 26.0# casing < Top of Tail at 11,300' MD Taper at 12,200' MD 4 1/2", 12.6# casing in 8 3/4" OH TD at 12,994' MD (5,895' ND) Mark of Schlumberger Volume Calculations and Cement Systems Volumes are based on 50% excess through 7" casing section, and 22.5% excess thorugh 4.5" casing section. The mean annular excess is 43.5%. Tail Slurry Minimum thickening time: 240 min. (pump time plus 120 min.) 15.8 ppg Class G w/ GasBLOK Annular Volume (7.0"casing): 0.1503 ft3/ft x (12200' - 11300') x 1.50 (50% excess) = 202.9 ft3 Annular Volume (4.5"casing): 0.3071 ft3/ft x (12994' - 12200') x 1.225 (22.5% excess) = 289.7 ft3 Shoe Volume: 0.0854 ft3/ft x 80' x 1.00 (no excess) = 6.8 ft3 Totals: 202.9 ft3+ 289.7 ft3+ 6.8 ft3= 508.4 ft3 508.4 ft3/ 1.17 ft3/sk = 435 sks Round up to 440 sks BHST = 128`F, Estimated BHCT = 97~. (BHST calculated using a gradient of 2.2/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Cumulative Stage (bpm) Volume Time Time bbl min min CW 100 5 10.0 2.0 2.0 Pressure Test 10.0 12.0 CW 100 5 40.0 8.0 20.0 Drop Wiper Plug 5.0 25.0 MudPUSH II 5 50.0 10.0 35.0 Tail Slurry 5 91.7 18.1 53.1 Drop Top Plug 5.0 58.1 Switch to rig pump 6 427.5 71.3 129.4 Displacement 3 50.0 16.7 145.1 MUD REMOVAL Mud Properties: 9.6 ppg, Pv = 19, Tv = 25. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* II, Pv = 19-22, TY = 31-35 Centralizers: Recommend 2 perjoint from 11,300' MD to TD for proper cement placement. ORIGINAL • • ~ r ~ ' J ; N r 1 r M J M ~ r ('V ~ ~~! M M J J 1` 0 M ~_ N i~ r r O M i z J ~ Cy 4 Lt') r fr3 i Z ~ I N L Cfl ~ r EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) i 6050000 6000000 5950000 5900000 5850000 400000 500000 600000 700000 ~~~ 800000 • • TRANSMITTAL LETTER CHECKLIST WELL NAME 2GC Z G "~~~ PTD# ~ ~ ~ / ~~ Development / Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK. ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. ,API No. 50- - - API number are Production should continue to be reported as a function of the between 60-69) original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until. after (Co ~any Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. SCompan~Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/ 13/2007 • • ^^ m N ~ ~ ~ ~ ~ : O) O Q ~ ~ ~ ~ ~ C' O ~ ~ ~ ~ ~ ~ - - ~ ~ a vo E : ~ ; ; ; ~ m. c rn 4 Z• c ° i ) co N ~ ~ C, ~ ~ ~ ~ ~ ~ j~ ~ ' N' ~ ~ ~ ~ C' L. ~~ f4 O' ' W U U ~ °- ' a N, `~ of ° ~, f0 v a ~ °; N N' O' Ol t' N E O ~ to: ~ o~ ~ ~ ~ ~ ~ ~ a ~ o °' ~ ~ ~~ ~' rn N ~ 00: ~ ~ ~ ~ ~ ~ O: ~ T .p-. ~ - C: d o; ; Q ~ ; ; ; ; ; ; ; ~: ~; ; ~ ; o, ; m ~ Q' M. fl. W' ~~ ~ ~ ~ ~ ~ N~ ~ f6 ~ ~ ~ N• G N, a 0 ~ ,~, a 3 a N f6 ° ~ 4 ~ °~ 3 a• M. L: M. ~ ~ ~ O. 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O; a; a; U ~ ~; Q; ' a; z' ' ~' U; cn U ~ U ~' U ~' ~ U; Q ° o; ~; Q ~ ' o; _ O d ~ m; m; U; o: ~, o' ~; ~'; ~' ~, a ~ .~; ~ o; cn cn; o c~ p U , , , , , , , , , , , , , , , ~ ~ W d O N M ~ LL) CO I~ OO O O N M V ~ CO f~ M O O N M V t0 (O I~ a0 m ~p /\ ~~/ V ~ ~ N __ M~ In (O I~ W d1 _- -- ~ ~ N N N N N N N N N N M M M M M M M M M M U O _ __ _ _. ~ O O N r C O O N p N ~ N U G N _ a ,, Y y ~ ~ _ °° I a1 L 0 (O °° ~ ~_ °° O N N ~ ~ N ~ J N d ~ ~ O --~ ~ ~ ~ a~ ~ a ~ w ~ a~ U Q d Q Q ~ ~ L Q f- ~ Q U l • 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 f71e and to simplify finding infom~ation, information of t1~is nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize ibis category of information. • 21-319.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed Jan 23 15:05:35 2008 Reel Header Service name .............LISTPE Date . ...................08/01/23 Ori in ...................STS Ree~ Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ............. ....08/01/23 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Physical EOF comment Record TAPE HEADER Tarn MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 W-0005274952 0. OBI D. BREEDEN scientific Technical services 2L-319 501032055200 ConocoPhillips Alaska, Inc Sperry Drilling Services 23-JAN-08 MWD RUN 2 MWD RUN 4 w-0005274952 w-0005274952 O. OBI A. MENEZES D. BREEDEN D. MORRIS SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 22 lON 7E 199 777 145.34 115.30 Page 1 ao~--ltd ~`t 5~~a 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: • OPEN HOLE BIT SIZE (IN) 12.250 8.750 21-319.tapx CASING DRILLERS SIZE (IN) DEPTH (FT) 16.000 80.0 9.625 4295.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). RESISTIVITY PHASE-4 (EWR4). MWD RUN 4 ALSO INCLUDED AZIMUTHAL LITHO-DENSITY (ALD), COMPENSATED THERMAL NEUTRON (CTN), BI-MODAL ACOUSTIC TOOL (BAT), AND PRESSURE WHILE DRILLING (PWD). MWD RUN 3 WAS A CLEAN-OUT RUN - NO DATA WERE ACQUIRED. 3. MWD RUNS 1-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE 4, MWD DATA WERE NOT DEPTH-SHIFTED PER E-MAIL FROM DERIK KLEIBACKER (CPAI) TO ROB KALISH (SDS) DATED 1/4/2008. 5. MWD RUNS 1-4 REPRESENT WELL 2L-319 WITH API#: 50-103-20552-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13010'MD/5891'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX,HSI-DERIVED). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = NON-ROTATED INTERVALS ADJUSTED FOR BIT-TO-SENSOR DISTANCE. DTCP = SMOOTHED COMPRESSIONAL WAVE SLOWNESS POST-WELL PROCESSED. DTSP = SMOOTHED SHEAR WAVE SLOWNESS POST-WELL PROCESSED. Page 2 21-319.tapx VPVS = RATIO OF COMPRESSIONAL AND SHEAR VELOCITIES. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: HSI-DERIVED (8.75~~ BIT) MUD WEIGHT: 9.6-9.7 PPG MUD SALINITY: 700-1200 PPM CHLORIDES FORMATION WATER SALINITY: 19149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE File Header Service name... .......sTSLI6.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/23 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPM 175.5 12955.5 RPD 175.5 12955.5 RPS 175.5 12955.5 RPX 175.5 12955.5 FET 176.0 12955.5 GR 183.5 12963.0 ROP 225.5 13010.5 PEF 4285.0 12927.0 NPHI 4285.0 12913.5 NCNT 4285.0 12913.5 DRHO 4285.0 12927.0 FCNT 4285.0 12913.5 RHOB 4285.0 12927.0 DTC 4305.0 12888.0 DTSH 4314.0 12884.0 SCRA 4314.0 12884.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 1 175.5 2042.0 2 2042.0 4305.0 4 4305.0 13010.5 REMARKS: MERGED MAIN PASS. Page 3 21-319.tapx Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units Size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 l 68 48 13 NPHI MWD Pu-s 4 1 68 52 14 DTC MWD USPF 4 1 68 56 15 DTSH MWD USPF 4 1 68 60 16 SCRA MWD 4 1 68 64 17 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 175.5 13010.5 6593 25671 175.5 13010.5 FONT MWD CP30 492.71 3289.93 900.78 17258 4285 12913.5 NCNT MWD CP30 101722 192376 127514 17258 4285 12913.5 RHOB MwD G/CC 0.258 2.845 2.31576 17285 4285 12927 DRHO MWD G/CC -2.776 0.39 0.0743414 17285 4285 12927 RPD MWD OHMM 0.03 2000 19.3555 25561 175.5 12955.5 RPM MWD OHMM 0.21 2000 17.1271 25561 175.5 12955.5 RPS MWD OHMM 0.86 1260.85 10.4976 25561 175.5 12955.5 RPX MWD OHMM 0.58 117.7 7.8521 25561 175.5 12955.5 FET MWD HR 0.01 134.53 1.64154 25560 176 12955.5 GR MWD API 13.45 226.03 110.374 25560 183.5 12963 PEF MwD B/E 2.11 12.19 2.93682 17285 4285 12927 ROP MWD FPH 1.43 1830.89 155.503 25571 225.5 13010.5 NPHI MWD Pu-S 1.37 64.92 36.1918 17258 4285 12913.5 DTC MWD USPF 64.52 127.53 101.813 17167 4305 12888 DTSH MwD USPF 118 309 216.917 16107 4314 12884 SCRA MWD 1.5 2.94 2.1295 16107 4314 12884 First Reading For Entire File..........175.5 Last Reading For Ent ire File...........13010 File Trailer Service name... .......STSLIB.001 service Sub Level Name... version Number...........1.0.0 Page 4 ~ ~ 21-319.tapx Date of Generation.......08/01/23 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......sTSLI6.002 Service Sub Level Name... version Number. .. ....1.0.0 Date of Generation.... .08/01/23 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 175.5 1992.5 RPx 175.5 1992.5 RPM 175.5 1992.5 RPS 175.5 1992.5 FET 176.0 1992.5 GR 183.5 2000.0 ROP 225.5 2042.0 LOG HEADER DATA DATE LOGGED: O8-OCT-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 2042.0 TOP LOG INTERVAL (FT): 225.0 BOTTOM LOG INTERVAL (FT): 2042.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: 68.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132478 EWR4 ELECTROMAG. RESIS. 4 77613 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 80.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud Page 5 ~ ~ 21-319.tapx MUD DENSITY (LB/G): ~ 10.00 MUD VISCOSITY (5): 155.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 8.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 5.000 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 4.090 81.0 MUD FILTRATE AT MT: 5.300 65.0 MUD CAKE AT MT: 5.100 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWDO10 OHMM 4 1 68 4 2 RPM MWDO10 OHMM 4 1 68 8 3 RPS MWDO10 OHMM 4 1 68 12 4 RPX MWDO10 OHMM 4 1 68 16 5 FET MwD010 HR 4 1 68 20 6 GR MWDO10 API 4 1 68 24 7 ROP MWDO10 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 175.5 2042 1108.75 3734 175.5 2042 RPD MWDO10 OHMM 1.73 2000 83.25 3635 175.5 1992.5 RPM MwD010 OHMM 1.57 2000 80.6646 3635 175.5 1992.5 RPS MWDO10 OHMM 1.79 330.66 41.9011 3635 175.5 1992.5 RPX MWDO10 OHMM 2.1 114.63 25.4685 3635 175.5 1992.5 FET MwD010 HR 0.01 4.81 0.866932 3634 176 1992.5 GR MwD010 API 13.45 111.8 67.2706 3634 183.5 2000 ROP MWDO10 FPH 1.43 1830.89 195.034 3634 .225.5 2042 First Reading For Entire File..........175.5 Last Reading For Entire File...........2042 File Trailer Page 6 ~ ~ 21-319.tapx Service name... .......STSLIB.002 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/01/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header service name... .......STSLI6.003 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/23 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 1993.0 4255.5 RPX 1993.0 4255.5 RPM 1993.0 4255.5 RPS 1993.0 4255.5 RPD 1993.0 4255.5 GR 2000.0 4263.0 ROP 2042.5 4305.0 LOG HEADER DATA DATE LOGGED: 09-OCT-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4305.0 TOP LOG INTERVAL (FT): 2042.0 BOTTOM LOG INTERVAL (FT): 4305.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 66.9 MAXIMUM ANGLE: 73.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132478 EWR4 ELECTROMAG. RESIS. 4 77613 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 80.0 Page 7 21-319.tapx BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 • Native/spud Mud 10.20 160.0 9.3 400 6.2 5.000 65.0 3.190 105.8 5.300 65.0 5.100 65.0 Name Service order Units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MwD020 OHMM 4 1 68 12 4 RPX MwD020 OHMM 4 1 68 16 5 FET MwD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last Name service unit Min Max. Mean Nsam Reading Reading DEPT FT 1993 4305 3149 4625 1993 4305 RPD MWD020 OHMM 3.57 93.67 9.8612 4526 1993 4255.5 RPM MwD020 OHMM 3.9 33.89 9.38734 4526 1993 4255.5 RPS MWD020 OHMM 3.67 46.97 8.92102 .4526 1993 4255.5 RPX MWD020 OHMM 3.18 30.91 8.30548 4526 1993 4255.5 FET MWD020 HR 0.22 61.38 1.96363 4526 1993 4255.5 GR MWD020 API 46.8 146.69 90.8048 4527 2000 4263 ROP MWD020 FPH 4.18 1361.8 152.557 4526 2042.5 4305 First Reading For Entire File..........1993 Last Reading For Entire File...........4305 Page 8 • 21-319.tapx File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/23 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/23 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPx 4256.0 12955.5 RPM 4256.0 12955.5 FET 4256.0 12955.5 RPD 4256.0 12955.5 RPS 4256.0 12955.5 GR 4263.5 12963.0 NCNT 4285.0 12913.5 RHOB 4285.0 12927.0 NPHI 4285.0 12913.5 FCNT 4285.0 12913.5 PEF 4285.0 12927.0 DRHO 4285.0 12927.0 DTC 4305.0 12888.0 RoP 4305.5 13010.5 SCRA 4314.0 12884.0 DTSH 4314.0 12884.0 LOG HEADER DATA DATE LOGGED: 21-OCT-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13010.0 TOP LOG INTERVAL (FT): 4305.0 BOTTOM LOG INTERVAL (FT): 13010.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 9 • MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CTN ALD BAT 21-319.tapx BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON Azimuthal Litho-Dens Bi-modal Acoustic 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 (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN)~: TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 35.2 71.9 TOOL NUMBER 53516 105242 179954 10640608 782187 8.750 4295.0 Polymer 9.60 44.0 10.1 400 5.0 3.500 74.0 2.210 121.0 3.000 74.0 2.600 74.0 Name service order units size Nsam Rep code Offset Channel DEPT FT 4 1 68 0 1 FONT MWD040 CP30 4 1 68 4 2 NCNT MWD040 CP30 4 1 68 8 3 RHOS MWD040 G/CC 4 1 68 12 4 DRHO MWD040 G/CC 4 1 68 16 5 RPD MWD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MWD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HR 4 1 68 36 10 Page 10 • • 21-319.tapx GR MWD040 API 4 1 68 40 11 PEF MWD040 B/E 4 1 68 44 12 ROP MwD040 FPH 4 1 68 48 13 NPHI MWD040 PU-5 4 1 68 52 14 DTC MWD040 USPF 4 1 68 56 15 DTSH MWD040 USPF 4 1 68 60 16 SCRA MWD040 4 1 68 64 17 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4256 13010.5 8633.25 17510 4256 13010.5 FONT MWD040 CP30 492.71 3289.93 900.78 17258 4285 12913.5 NCNT MWD040 CP30 101722 192376 127514 17258 4285 12913.5 RHOB MWD040 G/CC 0.258 2.845 2.31576 17285 4285 12927 DRHO MWD040 G/CC -2.776 0.39 0.0743414 17285 4285 12927 RPD MWD040 OHMM 0.03 2000 8.47709 17400 4256 12955.5 RPM MWD040 OHMM 0.21 2000 5.8668 17400 4256 12955.5 RPS MWD040 OHMM 0.86 1260.85 4.34721 17400 4256 12955.5 RPX MWD040 OHMM 0.58 117.7 4.05397 17400 4256 12955.5 FET MWD040 HR 0.25 134.53 1.71954 17400 4256 12955.5 GR MwD040 API 44.85 226.03 124.467 17400 4263.5 12963 PEF MWD040 B/E 2.11 12.19 2.93682 17285 4285 12927 ROP MWD040 FPH 1.52 651.58 148.018 17411 4305.5 13010.5 NPHI MwD040 PU-s 1.37 64.92 36.1918 17258 4285 12913.5 DTC MWD040 USPF 64.52 127.53 101.813 17167 4305 12888 DTSH MWD040 USPF 118 309 216.917 16107 4314 12884 SCRA MWD040 1.5 2.94 2.1295 16107 4314 12884 First Reading For Entire File..........4256 Last Reading For Entire File...........13010.5 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/01/23 Maximum Physical Record..6553.5 File Type ................Lo Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/01/23 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................08/01/23 Ori9in ...................STS Reel Name ................UNKNOWN writing Library. scientific Technical services Page 11 Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF End Of LIS File 21-319.tapx writing Library. Page 12 • scientific Technical services ~ ConocoPhillips q,a=,a , FINAL WELL REPORT TARN 2L-319 • 199' FNL, 778' FEL Sec 22 - T10N - R7E, UM North Slope, Alaska Steve Pike -Logging Geologist Mainuddin Chowdhury -Logging Geologist Ryan Massey -Logging Geologist October 26, 2007 [~ EPOCH • ~o~-~~ ~ ~ ~S~3a ConocoPhillips Tarn 2L-319 r~ U • • Table of Contents ........................................................................................ Page No. 1 MUDLOGGING EQUIPMENT & CREW .................................................. Error! Bookmark not defined. 1.1 Equipment Summary .................................................................... Error! Bookmark not defined. 1.2 Crew ................................................................................................. ............................................4 2 GENERAL WELL DETAILS ..................................................................... ............................................5 2.1 Objectives ....................................................................................... ............................................5 2.2 Well Summary ................................................................................ ............................................5 3 GEOLOGICAL DATA ............................................................................... ............................................6 3.1 Lithostratigraphy ............................................................................ ............................................7 3.2 Mudlog Summary ........................................................................... ............................................8 3.3 Gas Samples ................................................................................... ..........................................26 3.4 Sampling Program /Sample Dispatch ......................................... ..........................................27 4 PRESSURE /FORMATION STRENGTH DATA ..................................... ..........................................28 4.1 Formation Integrity/Leak Off Tests .............................................. ..........................................29 4.2 Pore Pressure Evaluation Introduction ....................................... ..........................................30 4.3 Pore Pressure Summary ............................................................... ..........................................30 5 DRILLING DATA ...................................................................................... ..........................................31 5.1 Daily Activity Summary ................................................................. ..........................................31 5.2 Bit Record ....................................................................................... ..........................................33 5.3 Mud Record .................................................................................... ..........................................38 Enclosures 2" = 100' Scale 2" = 100' Scale 2" = 100' Scale 2" = 100' Scale Mudlog Drilling Dynamics Log LWD Lithology Log Gas Ratio Log ~ EPOCH r1 LJ .1 Equipment Summary Parameter Equipment Type /Position Total Comments Downtime QGM electric gas trap Flame Replace agitator in top hole Ditch gas ionization total & chromatograph 4 hours section.; Sample line froze detector u . H2S Detector (H2S) Variable resistivity cell. Sample _ No Epoch H2S detector line, drill floor, mud its & shakers installed Rate of penetration (ROP) BEI Encoder- Primary draw works - No problems block position indicator RIGWATCH Turck Magnetic Minor adjustments Pum stroke counter (SPM proximit sensor - while drillin Hook Load (HLKD) /Weight RIGWATCH Ametek Hydraulic on bit WOB ressure cell - No roblems Not receiving Torque signal Tor ue RTOQ To Drive Feed - from Totco To drive rotar RPM To Drive Feed - Totco Wits feed Standpipe & casing pressure (SPP/CSIP) Totco H draulic ressure cell - Mud flow out FLOW Totco Flow Paddle - Totco Wits Feed Ball Float sensors in all pits & trip Pit levels x 6 tank - Totco Wits Feed Mud logging unit computer s stem Compac Pentium III - No problems Geolo fist's workstation Com ac Pentium III Totco Workstation Compan Man's workstation Com ac Pentium III - Totco Workstation Tool usher's workstation Com ac Pentium III - Totco Workstation Epoch Azonix Touch Screen Class Driller's workstation I Div II - Totco Workstation ~ EPOCH ConocoPhiliips Tarn 2L 319 1.2 Mudlogging Unit and Crew Unit Type Unit Number : Arctic ML012 Mudloggers Years '~ Days On Pad Geotechnicians Years Days On Pad Technician Trainees Steven Pike 4 25 Allan Williams 0 25 Ryan Massey 0 21 Mainuddin Chowdhu 1 16 * Years experience as Mudlogger Additional Comments Two spare poly-flow gas lines were run through a heated umbilical to insure non freezing for the gas lines and rig air lines to the unit. The QGM gas trap was routinely cleaned of drilling mud and the gas lines blown back with rig air during connections and bit trips. Pump Pressure was calibrated relative to Totco. Block height was recalibrated to ensure accuracy after every cut and slip, and after casing runs. Calibration of Gas Detection and Chromatograph was checked and recalibrations performed if necessary to confirm accuracy. Calibrations on all equipment held extremely well throughout the well. r1 ~J 4 ~-.. ConocoPMillips Tarn 2L 319 . 2. General Well Details 2.1 Objectives 2L-319 is a combination Exploration and Development well whose primary purpose is to establish reservoir quality and injection support on the eastern margin of the Bermuda reservoir. 2L-319 well design consists of a 9 5/8" surface casing, and 7" production liner was set and cemented. 2.2 Well Summary 50-103- Well 2L-319 API 20552-0o Classification Exploration Block N/A Nordic 199' KB Elevation 148.6' KB Rig Name / Drilling/ Surface Co- FNL, 7~s' FEL, AMSL Elevation 30' Type Land Ordinates sEC 22, Nordic # 3 T10N, R7E, UM Primary Bermuda T- Primary 12309 MD/ Secondary Secondary 12620'/ Target 3 Target 5345' Target CAIRN/ Target 5580' Depth TvD ESKER Depth 13010' Spud Date 10/6/2007 TD Depth 5s o~ss TD Formation ESKER TD Date 10/21/07 TVD Completion N/A Suspension N/A Days Drilling 16 Days N/A Status _5887 Date Testing Maximum TD Mud FIT Hole Depth Formation Weight Deviation Coring Casing Shoe Depth (pp ) Section (ppg) (o inc) /Liner MDRT TVDSS ft ft 12.25" 4305' -2645 WEST SAK 9.6 - 10.4 0 -70° NONE 9 5/8" 4295 2244 16.0 8.5" 13010' -5890 ESKER 9'6 9.7 70° -38° NONE 7" 12991.67' - 5608 Epoch commenced logging the 2L-319 on 10/6/07 at 80' drilling out of 16" conductor pipe, tagging ice at 115'. Samples were caught at 50' intervals to 4305'. Gas bags were collected at 300' intervals from 4300 and at gas kicks to a depth of 12,100'. Sample catchers were used throughout the well. Isotubes were collected in 30' intervals starting from 100' above the Bermuda Formation (12,200') and a 10' sampling program was started with ditch cuttings. No hole problems were encountered drilling the surface hole. Permafrost gravel 5 conotaPhillips Tarn 2L 319 caused minor problems with the gas trap, with gravel being caught in the agitator spindles and breaking off one of the three spindle prongs. The spindle was replaced and drilling commenced under the Permafrost and again gas trap problems occurred with massive thick clays plugging off the gas trap and overloading the possum belly. Rig crew hands were consistently washing down the shale shakers to enhance sample recovery and keep from losing drilling mud fluids off the shale shakers. Running sands and gravel were limited in scope with maintained mud parameters. Sample Catchers checked and cleared the gas trap of clay accumulation at each sample interval, and whenever a change in gas or lithology was noted. Gas hydrates flows showed a maximum recording of 3942 units with mud weights running 9.6 to 10.1 The mud system was swapped from Spud mud to LSND at 4305'. No hole problems were encountered while drilling from 3530' to the top of the Bermuda (Intermediate Hole Section). Good hole cleaning techniques were used drilling the deviated hole (70°) with high viscosity sweeps and good flow rates. Each connection allowed circulating time to clean the hole of cuttings above the BHA. All hole trips showed no drag or sticking. Slower trip and connection speeds prevented swab/surge damage to the hole. Good maximum ROP effective rates were obtained to clean the angled hole with assistance of using torque and drag trends, ECD and shale shakers productivity to establish a clean hole baseline. The production hole section drilled with no hole or drilling problems. No lost circulating or hole sticking was encountered. The drill string was kept moving whenever possible to avoid sticking. The ROP was controlled to 50 ft/hr to record good ditch cuttings throughout the production zone. Additionally, care and attention was taken to avoid over washing. • 6 ~-- CanotoPNilli~s Tarn 2L 319 • • 3. Geological Data 3.1 Lithostratigraphy Drilling picks & actual wireline tops refer to provisional picks provided by the wellsite Geologist. DRILLING ACTUAL WIRELINE HIGH/LOW FORMATION PROGNOSED PICK PICK (ft) MDRT TVD/TVDSS MDRT (ft) (ft) (ft) MD TVD/TVDSS 9 5/8" Casing 4300' 2387'/-2242' 4295' 2386'/ Shoe -2240' C80 (K10) 4591' 2505'/-2360' 4616' 2501'/ ' -4, -2356 Camp Sand NA NA N/A N/A NA C50 8656' 3865'/-3720' 8778' 3900'/ ' 35' -3755 C40 9792' 4245'/-4100' 9975' 4298 / ' 53' -4153 C37 10360' 4435'/-4290' 10550' 4492/ 57' -4347' Iceberg 10763' 4570'/-4425' 10800' 4577'/ ' 7' sand/silt -4432 T7 10806' 5005'/-4860' 11770' 4980'/ -25' -4835 T4 12133' 5235'/-5090' 12206' 5270'/ 35' -5125 T3 Top 12315' 5375'/-5230' 12309' 5345'/ -30' Reservoir -5200' T2 12485' 5505'/-5360' 12466' 5462'/ -43' -5317' T1 Base N/A N/A 12583' 5552'/ N/A Reservoir -5407' C35 (K-3) 11577' 5575'/-5430' 12620' 5580'/ 5' 5435' Esker (Top) 12746' 5705'/5560' 12703' 5645'/ -60' -5500' TD 12994' 5895'/5750' 13010' ~~ ~~~. 7 ConocoPhiffips Tarn 2L 319 • 3.2 Mudlog Summary The following text provides a brief summary of the defining lithological and drilling characteristics for that part of the well, over which drill cuttings were collected. Surface to Surface Casing Point 80' to 3530' MDRT (+68' to -2248' TVDSS) The 2L-319 was commenced on 10/06/07 from surface. Formation was encountered at 80' as drilling progressed under surface conductor pipe. Mud weight was 9.6 ppg at surface with an increase to 10.14by 4305'. Surface casing was run to 4295'. FIT was run with an EMW of 16.0 ppg. Trip gas of 0 units was recorded after the Leak Off Test. Samples collected from surface to the top of the permafrost were predominantly coarse grain sands (conglomerate) with heavy thick clays. The clays composed of clay and claystone being light gray to medium gray and very soft. The overall consistency and tenacity of the clay was malleable to sectile when cohesive, lumpy to clotted to gelatinous to slimy overall. Clays exhibited moderate to good cohesion with very good adhesion. There were no visible structures with a rare silty texture. Solubility was fair to moderate with moderate expansion and easily hydrated. • Abundant pebble conglomerate was collected from roughly 85' to 950'. The lithologic color was very light gray to light medium gray and scattered light green to dark brown and various hues of all. Clayt size ranged from pebble (possible cobble) to very coarse with scattered medium to lower coarse grain as matrix sands. Cuttings displayed an abundant angularity with bit impacted fragments scattered with sub round to sub angular matrix sands throughout the conglomerate section. Most sands displayed low to moderate developed sphericity with very poor sorting and a general polished texture with pitting to impacted textures in matrix sands. No visible cement was noted and samples appeared to be of sub mature nature. Matrix material was very slight to non existent. Cuttings contained greater than 50% lithics with fair to good estimated porosity and permeability and no show of oil. Conglomerate sands graded finer downward to a coarse grained sand towards the base of the conglomerate zone (900'). • C©noco`Philfips Tarn 2L 319 Texture was dominantly clayey with massive homogeneous clay composed of greater than 90% clay with minor silt, very fine grain sand, pyroclastic relic shards and various detrital materials. Overall; clean clay. The unconsolidated sands were light gray to very light gray, soft, moderate to well sorted with clast size ranging from fine lower to fine upper grains. Grains displayed sub angular to sub rounded shape with translucent quartz predominantly with common milky and smoky quartz. Scattered in minor amount were common medium gray lithic grains with trace various colored lithics. The sands graded to and became interbedded with associated siltstones. Sands were primarily grain supported with occasional thin beds of poorly indurated fragments displaying abundant clay matrix support. Drill Rate (ft/hr) Total Gas (%) Maximum Minimum Avera a Maximum Minimum Avera e 334 4 204 3942 0 135 Surface Casing to C-80 4305' to 4616' MDRT (-2240' to -2356' TVD From under surface casing to the top of the C-80, samples consisted of predominantly claystones being light gray to dark gray with a very slight brownish gray secondary hue. Samples were mushy to pasty, moderately soft with dull earthy to gritty luster with a slight sandy/gritty texture. Samples noted a plated to irregular in habit. Throughout the samples are traces of fine carbonaceous inclusions and trace very thin carbonaceous micro lamina. Overall the clays were interbedded and grading upward to very fine grain silty sand. Drill Rate (ft/hr) Total Gas (%) Maximum Minimum Avera a Maximum Minimum Avera e 326 65 156 113 44 77 C-80 to C-50 4616' to 8778' MDRT (-2356' to -3755' TVDSS) From 4616' to 5875' samples consisted of predominantly Claystone, and siltstone with secondary sands. The Claystone was dark gray to grayish brown and displaying poor to some moderate induration; being generally very brittle and crumbly to crunchy. Cuttings showed a slight cohesiveness with non to slight adhesiveness and showed an earthy fracture with a sub nodular habit and dull earthy luster. Textures were silty to gritty to an occasional sub sucrosic texture when grading upward to a very fine grained sandstone. 9 Conoto/Phillips Tarn 2L 319 • From 5875' to 8778' a drastic decrease in the claystone content was observed and a dramatic increase in siltstone, sandstone and sand was noticed. The sandstones and sand were clear to translucent with some light gray to white and light brownish gray and generally unconsolidated with scattered poorly consolidated fragments. Clast size ranges from very fine upper to fine lower with sub angular to sub spheroidal to occasionally sub rounded clear to translucent white quartz. Sandstones show grain support and matrix support with poor porosity and permeability and grade to associated siltstones. The sandstones were clear to translucent with light gray and white hues. Clast size ranges from fine lower to very fine lower and grading to silt in a clayey to very silty ashy matrix. Sand grains are sub angular to sub round with moderate developed sphericity with poor sorting. Drill Rate (ft/hr) Total Gas (% Maximum Minimum Avera a Maximum Minimum Avera e 382 51 197 150 10 46 C-50 to C-40 8778' to 9975' MDRT (-3755' to -4153' TVDSS) The C-50 is composed of gradational siltstone and very fine grained sandstones with sands and minor clays. The siltstones are light brownish gray to pale yellowish brown to yellowish gray and various hues of all colors. Overall consistency is mushy to pasty and being non to moderate cohesive and moderate adhesive. The fracture of cuttings is amorphous to blocky and shapes are massive to sub nodular with a dull earthy luster. Textures are clayey to silty with massive gradational silt, clay and silty sandstones present. Sandstones and very minor sand were translucent to clear to light gray to off white with clayt sizes ranging from fine lower to very fine grained and grading to silt. Sphericity is moderate and grains are poorly sorted. ~J The sands display slight calcareous cement and trace carbonaceous specs interbedded with a overall poor porosity and permeability. Claystones are minor in percentage and appear dark gray to medium dark gray with some grayish brown. Hardness is brittle to slightly firm with a irregular to amorphous fracture and amorphous cutting habit. All display very earthy to dull luster's with a clayey texture with thin inter beds of siltstone, sandstone and sand. Drill Rate (ft/hr) Total Gas (%) Maximum Minimum Avera a Maximum Minimum Avera e 301 12 178 70 6 27 10 ~-, ConotoPhillips Tarn 2L 319 C-40 to C-37 9975' to 10550' MDRT (-4153' to -4347' TVDSS) • r1 U The C-40 interval is represented by predominantly siltstone with thin bedded sands. A lower sequence of carbonaceous silty shale comprises the bottom of the formation. The siltstone is brownish gray to light brownish gray and grading to dark brown to medium grayish brown with depth. Samples are firm to stiff with an amorphous fracture and amorphous cuttings habit. Silts display a very dull earthy texture with some slightly gritty textures within very thin lenses of sand and minor gritty claystones. Clays are dark gray to brownish gray with some slight light olive gray. Samples are firm to brittle with a irregular to amorphous fracture and amorphous cuttings habit. Overall, a very earthy to dull luster with a clayey texture with some slight gritty lenses of siltstone and very fine grained sandstone. The carbonaceous silts are brownish gray distinctly mottled brownish black and various hues of both colors. Samples are brittle to flexible displaying a planar fracture and a flaky to scaly habit with a greasy to earthy luster. Textures are matte to mottled silty with thin to laminae beds of very carbonaceous silt and shale all with planar orientation. Drill Rate (ft/hr) Total Gas (%) Maximum Minimum Avera a Maximum Minimum Avera e 384 23 143 129 10 66 C-37 toT-7 10550' to 11770' MDRT (-4347' to -4835' TVDSS) This sequence is comprised of siltstones and predominant unconsolidated sand. The siltstones are dark brown to medium grayish brown with hues of pale reddish brown, dusky red and dark yellowish orange, moderately stiff to firm, with irregular to slightly splintery fractures. Cuttings habit is amorphous with a dull earthy luster. Textures very silty with very thin interbedded with very thin lenses of sand throughout. The predominant lithology of sand is translucent to clear, white to frosted white with light gray colors. Composed of predominantly quartz grains in very fine grain size to lower medium grain sizes samples are poorly sorted with sub round to sub angular with very well rounded to very angular grains. Sands were frosted to pitted to some polished surface textures. Fair to moderate porosity and permeability with scattered aggregate pyrite crystals with no show of oil cuts was noted. Drill Rate (ft/hr) Total Gas (%) Maximum Minimum Avera a Maximum Minimum Avera e 11 ConocoPhillips Tarn 2L 319 405 31 158 595 10 85 • T-7 to T-4 (Iceberg) 11770' to 12206' MDRT (-4835' to -5125' TVDSS) This section is comprised of siltstones which become gradational and becoming interbedded with unconsolidated sand. The siltstones are medium dark gray to gray becoming brownish gray with some hues of reddish brown, dusky red and yellowish orange. Samples are stiff to firm with irregular to slightly splintery fracture with an amorphous cuttings habit and a prominent dull earthy luster with a very silty texture and thinly interbedded with very thin lenses of sand. The sand and minor sandstones are thinly bedded and become interbedded with siltstone. Colors are light gray to white with some translucent to clear quartz grains throughout. Clast size ranges from fine upper to medium lower with sub angular to sub rounded shape with moderate sphericity with fair porosity and permeability. Drill Rate (ft/hr) Total Gas (%) Maximum Minimum Avera a Maximum Minimum Avera e 310 40 124 112 23 39 T-4 to T-3 (Top Reservoir) 12206' to 12309' MDRT (-5125' to -5200' TVDSS) This section is comprised of a sequence of siltstones, sand and sandstone. The siltstone is medium gray to light gray with some dark brownish gray and very dark gray in parts. Cuttings were very soft to slimy with irregular to amorphous to irregular fracture and habit. The luster was very dull to somewhat earthy with a silty to slightly gritty texture. Sand and sandstones were thinly bedded to some interbedded throughout the short section. Samples were predominantly quartz grain sandstone very light gray with some white. Clast size ranges from very fine lower to very fine upper with some medium lower. Clasts were sub round to round with moderate developed sphericity with poor to moderate sorting. Textures were pitted and overall sandstones being sub mature in nature. Moderate grain overgrowths were noted giving fair porosity and permeability. Continued 75% to over 90% even to light yellow sample fluorescence with no developed oil cuts. Drill Rate (ft/hr) Total Gas (%) Maximum Minimum Avera a Maximum Minimum Avera e 55 23 35 595 150 170 12 .~ ConocoPhillips Tarn 2L 319 • • 13 ConocoPhillips Tarn 2L 319 • • 14 ConocciPhittips Tarn 2L 319 T3 To Reservoir to T1 Base Reservoir ~ p ) ~ ) • • 12309' to 12583' MDRT (-5200' to -5407' TVDSS) From the top of the T-3 to the top of the T-2 samples were predominantly sand and sandstone, with varying amounts of siltstone and shale. Continued C-5 through the formation marked by three gas kicks. Average background readings were 75 to 155 units. The first kick (12410' to 12415') was 605 units. The second kick (12428' to 12448') was 644 units, with the third gas kick (12450' to 12460' was 655 units. Samples were 70% unconsolidated sand and 30% sandstone. The sands were light gray to medium gray with white to clear and translucent colors. Sands were mostly quartz grains with clast size ranging from very fine upper to fine upper. Sands were moderately sorted and sub angular to sub round with moderate sphericity. Visible evidence of hydrocarbons were observed in the sample matrix. Fair to good apparent porosity and permeability were observed. Sample fluorescence was 80 to over 90% dull pale yellow with an no oil cut. Drill Rate (ft/hr) Total Gas (%) Maximum Minimum Avera a Maximum Minimum Avera e 60 21 45 655 32 142 15 ConocoPhillips Tarn 2L 319 • • 16 ConocoPhillips Tarn 2L 319 • r~ L J • 17 -~ ConocoPhillips Tarn 2L 319 • • • 18 ConocoPhillips Tarn 2L 319 • • • 19 .-° CortotoP'hiltips Tarn 2L 319 T1 (Base Reservoir) to C35 12583' to 12620' MDRT (-5407' to -5435' TVDSS) The T-1 to the C-35 consists of sandstone grading to siltstone and shale. The sandstones were clear to translucent with gray to light gray with some white. Clast size ranges from very fine upper to fine lower and consisting of predominantly quartz. Samples are moderately sorted with sub angular grains and moderate sphericity. Textures display slightly frosted and etched markings. Porosity is moderate to poor with slight calcareous cement. Moderate grain overgrowths are noted with poor permeability. The sandstones grade into a light gray and medium gray siltstone. Silts are poor to moderately indurated and brittle to stiff in parts and display moderate cohesiveness and non adhesiveness with a sub planar fracture and a sub platy habit. Lusters are dull to earthy with a silty texture with gradational sands decreasing with depth. Drill Rate (ft/hr) Total Gas (%) Maximum Minimum Avera a Maximum Minimum Avera e 178 48 58 136 43 78 • 20 ConocoPhillips Tarn 2L 319 C] • (C-35) to Albian-Esker (Top) 12620' to 12703' MDRT (-5435' to -5500' TVDSS) The C-35 to the top of the Esker formation is comprised of siltstone and very carbonaceous silts and clay. The carbonaceous silts are very thinly bedded to being micro laminated throughout the siltstones. Very minor sandstones are interbedded, especially towards the bottom. At 11600' a minor bed of sandstone interbedded with tuff is noted, which appears reworked and redeposited. Average background readings were 43 to 91 units. The carbonaceous silt is brownish gray mottled pale yellowish brown to dark gray and various hues of all. Samples are brittle to flexible with planar fracture with a micro flaky habit. Lusters are dull and greasy with a matte to silty texture. Occurs as thin to micro laminated beds of very carbonaceous silt and appears very heterogeneous. The siltstones are light gray mottled with micro laminae of brownish gray to brownish black. Induration is poor to moderate with a sub planar fracture and a sub platy habit. 21 CcmotoPhillips Tarn 2L 319 • Lusters are dull and earthy with a silty texture. Bedding occurs as a massive gradational bed of silt and very carbonaceous silt with minor sandstones with interbedded tuff. Drill Rate (ft/hr) Total Gas %) Maximum Minimum Avera a Maximum Minimum Avera e 67 12 37 34 7 15 Albian-Esker (Top) to TD 12703' to 13101' MDRT (-5500' to -5890' TVDSS) This section of formation is comprised of predominantly siltstone with varying amounts of sand, sandstone, shale and carbonaceous shale. The siltstone encountered in this section is comprised of medium gray mottled pale yellowish brown to dark gray and various hues of all. Samples are brittle to crunchy with amorphous to planar fracture. Lusters are dull and greasy with a matte to silty texture. The siltstones are light gray mottled with micro laminae of brownish gray to brownish black. Induration is poor to moderate with a sub planar fracture and a sub platy habit. Lusters are dull and earthy with a silty texture. Average background readings were 25 to 116 units. One gas kick (12717' to 12733') was encountered in this section with maximum gas readings of 580 units. Drill Rate (ft/hr) Total Gas (%) Maximum Minimum Avera a Maximum Minimum Average 180 46 89 580 21 81 • 22 -~ ConocoPhillips Tarn 2L 319 • • • 23 -~ ConocoPhillips Tarn 2L 319 • 24 .~ ConocoPhillips Tarn 2L 319 • • • 25 ConocoPhillips Tarn 2L 319 3.3 Sampling Program /Sample Dispatch • Set T pe /Purpose Interval Frequenc Dispatched to Wet: No wet samples collected Bayview Lab ConocoPhillips Alaska, Inc. 619 Ship Creek Ave., Ste. 100 Anchorage, AK 99501 Attn: D. Przywojski (907)-263-4859 1 80' - 3300' 50' 3350' - 7000' 50' Bayview Lab ConocoPhillips Alaska, Inc. Washed, screened & 7000' - 10750' 50' 619 Ship Creek Ave., Ste. 100 dried Dry Samples 10800' -13010' 50' + 10' + 30' Anchorage, AK 99501 4 Boxes Set A Attn: D. Przywojski (907)-263-4859 1 Washed, screened & 80' - 3300' 50' dried Dry Samples 3350' - 7000' 50' 4 Boxes Set B 7000' - 10750' 50' Bayview Lab ConocoPhillips Alaska, Inc. 10800' - 13010' 50' + 10' + 30' 619 Ship Creek Ave., Ste. 100 Anchorage, AK 99501 Attn: D. Przywojski (907)-263-4859 1 Gas Bags Box "A" 300' or as g 4300' - 9700' 4300' - 9700' kicks ISOTECH LABORATORIES 1 1308 Parkland Court Gas Bags Box "B" ' ' 10900' -12100' 300' or gas Champaign, IL. 61821 1 10000 -12100 kicks 1 12200' -13010' 217-398-3490/FAX 217-398-3493 IsoTubes One box of 30 or gas mail isotechlabs.com 25 + 4 kicks Sample frequency was locally altered according to drill rate constraints. 26 Conoc~'hilti~s Tarn 2L 319 • 3.4 Cali Bond Gas Bag Sample and IsoTube Inventory • Gas Bag # Depth Gas Units IsoTube # Depth Gas Units 1 4300 75 1 12200 128 2 4600 90 2 12230 75 3 4900 50 3 12260 75 4 5200 55 4 12290 60 5 5500 40 5 12320 30 6 5800 22 6 12350 47 7 6100 50 7 12380 270 8 6400 26 8 12410 240 9 6700 25 9 12440 520 10 7000 40 10 12470 320 11 7300 32 11 12500 125 12 7600 21 12 12530 228 13 7900 32 13 12560 89 14 8200 2 14 12590 88 15 8500 15 15 12620 94 16 8800 27 16 12650 78 17 9100 15 17 12680 72 18 9400 30 18 12710 99 19 9700 12 19 12726 530 20 10000 34 20 12740 156 21 10300 115 21 12770 115 22 10600 95 22 12800 71 23 10840 285 23 12830 72 24 10900 50 24 12860 2 25 11200 60 25 12890 74 26 11500 50 26 12920 120 27 11800 74 27 12950 128 28 12100 109 28 12980 90 29 13010 200 ~ EPOCH 27 ..- ConotoPhiUips Tarn 2L 319 • 4. Pressure and Formation Strength Data 4.1 Formation Integrity/Leak Off Tests Equivalent mud weight (EMW) is calculated from rotary table (RT). MDRT (ft) TVDSS (ft) LOT/FIT (ppg EMW) FORMATION 4305' -2645' 16.0 CSG SHOE + 30' LOT (Leak Off Test) in bold italics. 4.2 Pore Pressure Evaluation Introduction Trend Indicators The following pore pressure parameters are considered to provide reliable indicators for pore pressure trends during the drilling of this well; Background Gas (BG) Connection Gas (CG) Trip Gas (TG) Hole Corrected D exponent (DXC) 1 Mud Weight (MW) Conditions (HC) Sonic (SON) Wireline Density (WDEN) Resistivity (RES) Pressure Tests (RFT) n U 28 ConQCa~Phillips Tarn 2L 319 4.3 Pore Pressure Summary Equivalent mud weight (EMW) is calculated from rotary table (RT). Pore Pressure Trend Source of Formation Primary Interval Tops (EMW) Indicators Quantitative Interval Lithology MDRT TVDSS Estimate (ft) (ft) SL C80 SLTST/SS 4616' -2501' 9.7 9.8 INCR CG CG/MW C50 SLTST/SS 8778' -3900' 9.7 9.8 BG/CG BG/CG EVEN C40 SLTST 9975' -4298' 9.7 9.8 EVEN BG/CG/MW BG/CG SL C37 SLTST/SAND 10550' -4492' 9.7 9.8+ INCR CG/BG BG SL ICEBERG SLTST 10800' -4577' 9.6 9.7 DECR BG/CG BG/CG T7 SLTST/SAND 11770' -4980' 9.6 9.7 EVEN BG/CG BG/CG SL T4 SAND/SS 12206' -5270' 9.7 9.8 INCR BG BG/CG T3 Top SAND/ SS 11270' -5355' 7 9 9 8 SL BG/CG BG/CG Reservoir . . INCR T2 12466' -5462' 9.7 9.8 I CR BG/CG BG SAND/SS/SLTST T1 Base SL Reservoir SS/SLTST 12583' -5552' 9.6 9.7 DECR BG/CG BG C-35 (K-3) SLTST 12620' -5580' 9.6 9.7 EVEN BG/CG BG SL Esker (Top) SLTST/SS 12703' -5645' 9.6+ 9.7 INCR BG BG " Refer to Section 4.3 for explanation of abbreviations used. 29 ~~ Cor~ocaC'hillips Tarn 2L 319 • 5. Drilling Data 5.1 Daily Activity Summary 10/06/07 Epoch rigged up and ready to Log at 0430 Hrs, 10/06/07 10/07/07 Load 9 5/8. M/U 12 1/4 Bit, Mud Motor and stabilizer. R/U gyro. Spud well, tag fill at 90 FTMD. Drill from 90-225FTMD. POOH to P/U MWD tools. Drill at present report time. 10/08/07 Drill from 457' to 974' MD. Work dogleg from 818' to 915' MD. Drilling continuing at report time. Max gas 2735U'. 10/09/07 Drilled ahead from 2890', circulated sweep two bottoms up. P.O.O.H. to change adjustment on mud motor. T.I.H. back to bottom, continue drilling ahead 2890' at report time. Max gas 2460U. 10/10/07 Drill ahead to 4305' MD/2645' TVD. Pumped 35 bbl HI sweep with nut plug marker to obtain lag time. Sample to surface at 8500 +/- strokes. Max gas 376U. • 10/11/07 Make up top drive after short trip when back on bottom, at around 2500 strokes. The flow line plugged up from chunks of clay from formation. Circulate and condition mud system. Short trip to 2890'. Circulate sweep around. P.O.O.H. to 3836', pump dry job, P.O.O.H. to surface down load MWD. Run in the hole with hole opener and clean out hole. Max gas 236U. 10/ 12/07 Continue to bottom with clean out assembly, circulate hi weight/hi viscosity sweep with slight increase of cuttings at shaker. Pump dry job, P.O.O.H. to surface, lay down BHA. Rig up and run 9 5/8" casing to 4295'. Max gas 168U. 10/13/07 Complete running 9 5/8" casing, cement, and bump plug at 4297 strokes. Casing shoe depth recorded at 4295'. Max gas Ou. 10/14/07 Nipple up BOPs and test. Pick up R&T drill pipe. Max gas Ou. 10/15/07 Continue to run in hole with drill assembly. Pressure test casing. Run in hole to 4203' tag up cement, drill out shoe track and 30' NEW HOLE TO 4335'. Pump seep in from of new mud and displace with new LSND mud system. Continue drilling ahead at report time. Max gas 187u. • 10/16/07 Continue drilling ahead to 7115'. Pump high viscosity sweep and circulate bottoms up. Drill to 7922'. Max gas 71 u. 30 ConotoPhi{lips Tarn 2L 319 • 10/17/07 Continue drilling ahead to 7965'. Max gas 89u. 10/18/07 Continue drilling ahead to 9563'. Max gas 70u. 10/19/07 Continue drilling to 9733', mix and pump 30 bbls high viscosity sweep. Drill down to 9766', pumped second pill. Pump dry job, P.O.O.H. for short trip to 4279'. R.I.H. and continue drilling ahead. Max gas 78u. 10/20/07 Continue to drill, rotate and slide as per directional drilling. Max gas 595u. 10/21 /07 Continue drilling ahead, control drill rate through pay zone. Drill ahead to 12403', short trip to pick up additional drill pipe. Continue drilling to 12832'. Change out cooling motor for top drive. Max gas 655u. 10/22/07 Complete working on top drive cooling motor, continue drilling ahead to 13010' measured depth / 5890' TVD total depth for well. Circulate sweep around and four bottoms up, pump dry job and pull out of hole for short trip to casing shoe. Max gas 232u. 10/23/09 Finish dummy trip to 4283'MD. Run in the hole to 13010'MD. Pumped weighted sweep and three bottoms up. Spot casing running fluid. Pull out of hole to 8465'MD. Max gas 298u. 10/24/07 Rig up to run 7" liner. 10/25/07 Load 7" casing, run 4.5" casing to 805' MD. Run 7" casing to 10255'MD. Circulate B/U at surface casing shoe and every 1500' there after. Max gas 97. • 31 ConocoPhiltips Tarn 2L 319 • 5.2 Bit Record Total Bit O WOB PP Run Make Type Jets Depth R P RPM Wear BHA Footage Hrs (klbs) (psi) In (ft) (ft/hr) 12.25" HOLE 1 1X13, 41 w/ 0-0-NO- HTC MXL-1 3X15 80 4305 27.5 156 20 slide 1456 A-E-I-NO TD 8.5" HOLE 2 1-1-CT- HTC HCM605Z 5X16 4305 13010 72.10 121 24 83 w/ 2424 G-X-2- TD slide NO-TD • 32 -- ConocoPhifiips Tarn 2L 319 5.3 Survey Record • • Measured Depth Inclination Azimuth TVD Coordinates Dog Leg Feet Degrees Degrees Depth N / S E / W Degrees/ 100 ft 30.04 0.00 0.00 30.04 O.OON 0.00E 0.00 78.00 0.07 72.85 78.00 0.01 N 0.03E 0.15 170.00 0.22 18.45 170.00 0.19N 0.14E 0.16 266.00 0.64 9.10 266.00 0.90N 0.28E 0.44 357.00 1.43 1.00 356.98 2.53N 0.38W 0.88 448.00 2.22 10.13 447.93 5.40N 0.71 W 0.92 534.00 2.86 19.34 533.85 9.07N 1.71 W 0.88 628.00 5.09 41.85 627.62 14.39N 5.27W 6.72 717.00 7.00 50.52 716.13 20.78N 12.09W 2.37 748.50 7.95 54.61 747.36 23.26N 15.35W 3.45 781.02 9.96 59.67 779.48 25.98S 19.61 W 6.63 812.97 10.75 64.42 810.91 28.67S 24.69W 3.64 843.60 11.62 68.25 840.96 31.04S 30.13E 3.73 875.26 13.49 73.04 871.86 33.30S 36.62E 6.76 905.90 15.90 75.75 901.50 35.38S 44.11E 8.18 935.49 17.45 78.60 929.84 37.25S 52.39E 5.92 969.27 18.62 80.89 961.96 39.11 S 62.68E 4.05 999.04 18.62 80.89 961.96 39.11 S 62.68E 4.05 1030.12 21.90 84.00 1019.01 41.86S 83.65E 5.18 1062.87 23.87 84.78 1049.18 43.10S 96.32E 6.09 1094.88 26.10 84.60 1078.19 44.35N 109.78E 6.97 1125.35 28.57 83.91 1105.26 45.75N 123.70E 8.17 1158.50 30.72 83.13 1134.07 47.61 N 139.99E 6.59 1189.45 31.77 84.06 1160.53 49.40N 155.94E 3.73 1219.79 32.38 84.60 1186.24 50.99N 171.98E 2.22 1252.38 33.78 84.43 1213.54 52.69N 189.68E 4.31 1285.23 35.10 82.74 1240.64 54.57N 208.14E 4.96 33 ~-.. ConotoPhillips Tarn 2L 319 f~ • Measured Inclination Azimuth TVD Coordinates Do Le Feet Degrees Degrees Depth N / S E / W 1315.21 37.28 81.79 1264.83 57.15N 225.68E 7.51 1347.15 39.92 81.63 1289.79 60.03N 245.40E 8.27 1408.22 44.93 82.30 1334.86 65.77N 286.18E 8.24 1441.23 46.71 82.76 1357.86 68.85N 309.65E 5.48 1473.12 49.01 84.12 1379.26 71.55N 333.14E 7.87 1504.08 51.03 84.63 1399.15 73.87N 356.75E 6.65 1537.43 52.85 84.52 1419.71 76.35N 382.89E 5.46 1571.18 55.01 84.42 1439.28 78.98N 410.04E 6.40 1600.39 56.44 84.84 1456.03 81.24N 434.07E 5.04 1634.07 58.35 84.81 1474.17 83.80N 462.33E 5.67 1663.56 60.45 85.12 1489.18 86.02N 487.61E 7.18 1693.23 61.58 83.95 1503.56 88.50N 513.45E 5.14 1727.83 63.32 84.40 1519.56 91.61 N 543.96E 5.16 1758.76 64.86 82.32 1533.08 94.83N 571.59E 7.83 1786.87 65.85 82.38 1544.80 98.73N 596.92E 3.53 1821.67 66.67 81.98 1558.81 102.57N 628.47E 2.58 1851.97 67.94 80.93 1570.50 106.72N 656.12E 5.27 1879.77 68.55 81.11 1580.81 110.75N 681.62E 2.28 1914.66 68.53 81.29 1593.57 115.72N 713.71E 0.48 1945.86 68.55 81.58 1604.99 120.04N 742.42E 0.87 1974.40 68.20 82.08 1615.50 123.81 N 768.68E 2.04 2064.11 66.92 80.94 1649.75 136.05N 850.69E 1.85 2160.22 68.21 83.75 1686.43 147.87N 938.72E 3.02 2252.26 69.28 85.91 1719.80 155.60N 1024.15E 2.48 2348.15 68.30 85.81 1754.49 162.05N 1113.31E 1.03 2442.34 70.50 85.65 1787.63 168.61 N 1201.22E 2.34 2537.49 72.03 85.24 1818.19 175.77N 1291.04E 1.66 2630.17 72.58 83.58 1846.36 184.37N 1378.91E 1.81 2726.30 72.52 85.22 1875.19 193.32N 1470.18E 1.63 2913.12 73.42 84.06 1929.92 211.60N 1647.86E 0.65 3008.21 72.93 82.33 1957.44 222.39N 1738.23E 1.82 3103.75 72.89 82.81 1985.52 234.20N 1828.23E 0.48 34 ConocaPhillips Tarn 2L 319 Measured Depth Inclination Azimuth TVD Coordinates Coordinates Feet Degrees Degrees Depth N / S E / W Degrees/ 100 ft 3197.92 72.89 81.47 2013.22 246.50N 1917.94E 1.36 3293.97 70.02 80.74 2043.65 274.78N 2007.93E 2.95 3386.68 70.02 80.74 2075.22 274.78N 2093.95E 0.20 3480.57 69.07 83.95 2108.03 286.50N 2181.12E 3.36 3578.83 68.55 84.77 2143.55 295.51 N 2272.29E 0.94 3674.35 68.97 85.19 2178.16 303.30N 2360.98E 0.60 3767.42 70.96 86.10 2210.04 309.93N 2448.16E 2.33 3862.07 71.37 85.91 2240.60 316.17N 2537.52E 0.47 3956.42 70.76 86.02 2271.21 322.45N 2626.55E 0.66 4049.89 71.10 83.46 2301.76 330.55N 2714.51E 2.61 4146.67 69.80 83.80 2334.14 340.67N 2808.14E 1.38 4236.44 69.68 84.32 2365.23 349.39N 2888.90E 0.56 4335.06 69.10 84.82 2399.94 358.12 2980.80 0.76 4430.30 68.37 84.77 2434.48 366.18 3069.19 0.77 4524.35 68.77 84.43 2468.85 374.41 3456.34 0.54 4709.86 69.19 84.75 2533.80 398.81 3329.43 1.03 4804.43 70.35 84.17 2566.50 398.38 3417.75 1.35 4898.19 70.29 84.15 2598.07 406.54N 3505.65E 0.33 4991.60 69.91 84.05 2629.87 415.57N 3593.02E 0.42 5088.13 70.69 84.07 2662.41 424.98N 3683.41E 0.81 5181.39 70.00 84.21 2693.77 433.94N 3770.77E 0.75 5275.59 70.70 84.30 2725.45 442.82N 3859.04E 0.75 5370.30 70.43 84.50 2756.96 451.54N 3947.93E 0.35 5465.11 69.96 84.61 2789.09 460.OON 4036.73E 0.51 5560.75 71.00 84.22 2821.04 468.78N 4126.44E 1.15 5655.91 70.43 83.70 2852.47 478.23N 4215.76E 0.79 5751.39 69.63 83.24 2885.08 488.43 4304.92 0.95 5845.45 69.77 83.55 2917.71 498.58 4392.55 0.34 5940.16 69.37 83.10 2950.77 508.89 4480.70 0.61 6035.50 68.53 85.30 2985.02 517.89 4569.22 2.33 6130.32 68.36 84.59 3019.86 525.66 4657.06 0.72 6225.66 70.41 84.19 3053.43 534.38 4745.86 2.19 Feet Degrees Degrees Depth N / S E / W Degrees/ 35 ConocoPhillips Tarn 2L 319 r~ I~ • Measured Depth Inclination Azimuth TVD Coordinates Coordinates Feet Degrees Degrees Feet N/S E/W Degrees/100 ft 6320.32 70.81 84.12 3084.85 543.48 4834.69 0.43 6414.04 70.28 84.80 3116.07 552.01 4922.64 0.89 6507.33 70.37 84.54 3147.48 560.17 5010.11 0.28 6601.78 71.00 84.62 3178.72 568.59 5098.84 0.67 6788.70 70.65 84.31 3241.15 586.66 5274.10 0.77 6883.36 69.91 83.90 3273.09 595.81 5362.73 0.88 6977.87 71.15 85.96 3304.59 603.68 5451.48 2.44 7072.80 70.36 85.01 3335.88 610.73 5540.83 1.26 7167.66 71.28 85.56 3367.05 618.09 5630.12 1.11 7262.80 70.33 84.90 3398.33 625.56 5719.66 1.19 7356.81 71.36 85.35 3429.18 633.11 5808.14 1.19 7450.38 70.49 84.78 3459.76 640.71 5896.24 1.09 7542.90 71.86 84.64 3489.61 648.79 5983.44 1.49 7638.11 71.09 84.35 3519.86 657.45 6073.30 0.86 7732.67 71.33 83.92 3550.32 666.60 6162.35 0.50 7829.52 71.66 85.18 3581.06 675.32 6253.77 1.28 7922.72 70.80 84.40 3611.05 683.33 6341.65 1.22 8017.34 70.94 84.26 3642.05 692.16 6430.61 0.20 8110.88 70.37 83.75 3673.04 701.38 6518.38 0.80 8206.23 69.63 84.17 3705.65 710.81 6607.49 0.88 8298.64 69.85 84.27 3737.65 719.54 6693.74 0.26 8392.67 70.11 84.90 3769.84 727.87 6781.69 0.69 8487.04 71.09 85.84 3801.19 735.06 6870.41 1.40 8581.20 70.21 85.50 3832.39 741.76 6959.00 0.99 8674.82 69.54 85.50 3864.60 748.66 7046.63 0.72 8768.80 70.40 86.13 3896.79 755.10 7134.69 1.11 8863.96 69.70 86.26 3929.26 761.04 7223.94 0.75 8957.89 71.28 84.61 3960.63 768.09 7312.19 2.36 9054.27 70.47 84.98 3992.20 776.35 7402.87 0.92 9147.95 71.28 83.49 4022.90 785.25 7490.93 1.73 9242.12 70.46 83.34 4053.76 795.45 7579.31 0.88 9336.19 69.98 82.17 4085.59 806.61 7667.12 1.28 9433.92 69.91 81.60 4119.11 819.57 7758.01 0.55 9528.38 70.88 82.11 4151.11 832.16 7845.98 1.15 9622.19 71.32 84.15 4181.50 842.78 7934.09 2.11 9717.20 70.87 83.81 4212.28 852.20 8023.48 0.58 9808.73 70.48 83.56 4242.57 861.70 8109.33 0.50 9901.43 70.23 85.34 4273.74 870.15 8196.22 1.83 9998.79 69.44 85.26 4307.30 877.63 8287.31 0.82 10092.91 69.93 85.36 4339.98 884.85 8375.28 0.53 10185.05 70.96 86.05 4370.82 891.35 8461.85 1.32 10281.62 69.96 85.74 4403.12 897.87 8552.63 1.08 10375.28 71.22 86.39 4434.24 903.93 8640.75 1.50 10469.98 70.04 85.55 4465.65 910.20 8729.87 1.50 10564.37 71.23 85.25 4496.95 917.34 8818.63 1.30 10655.70 70.20 84.85 4527.11 924.78 8904.52 1.20 10753.10 69.22 83.73 4560.89 933.87 8995.42 1.47 10839.90 70.24 83.35 4590.96 943.03 9076.32 1.24 10940.80 71.15 83.02 4624.32 954.33 9170.87 0.96 ConocaRhillips Tarn 2L 319 • • Measured Depth Inclination Azimuth TVD Coordinates Dog Leg Feet Degrees Degrees Depth N / S E / W Degrees/ 100 ft 11034.91 70.02 82.27 4655.60 965.36 9347.67 1.24 11129.90 70.15 84.27 4687.96 975.49 9347.67 1.56 11223.52 69.43 84.04 4720.30 984.44 9435.07 0.80 11317.44 66.10 84.51 4755.83 993.11 9521.56 3.58 11414.56 63.00 84.80 4797.56 1001.29 9608.86 3.20 11507.32 60.39 84.83 4841.54 1008.67 9690.19 2.81 11603.10 59.32 84.49 4889.64 1016.37 9772.66 1.16 11696.33 56.84 84.25 4938.93 1024.13 9851.40 2.67 11791.57 53.79 84.11 4993.12 1032.07 9929.30 3.20 11886.44 50.21 85.43 5051.52 1038.91 10003.74 3.93 11984.70 48.56 84.28 5116.13 1045.53 10077.46 2.84 12078.62 46.20 82.21 5180.33 1053.58 10145.53 2.16 12173.24 44.33 82.72 5246.92 1062.40 10212.16 2.01 12267.91 43.65 81.97 5315.04 1071.15 10277.32 0.90 12362.86 41.63 83.52 5384.88 1079.29 10341.12 2.40 12456.17 40.62 83.67 5455.17 1086.14 10402.10 1.09 12550.64 40.10 84.73 5527.15 1092.32 10462.97 0.91 12645.59 39.45 84.09 5600.13 1098.24 10523.42 0.81 12740.70 38.17 83.98 5674.24 1104.43 10582.71 1.35 12836.65 37.09 83.95 5750.23 1110.59 10640.97 1.13 12931.31 35.77 83.72 5826.39 1116.62 10696.85 1.40 12968.08 35.24 83.77 5856.32 1118.95 10718.08 1.44 13010.00 35.24 83.77 5890.56 1121.58 10742.13 0.00 37 ConotoPhillips Tarn 2L 319 • 5.4 Mud Record M-I Drilling Contractor: Fluids Spud Mud to 3520' LSND TO Mud Type: Mud Type : 11840' Date Depth MW Vis PV YP Gels API FL Solids Oil/Water Sand PH CI Ca 10/6/07 457 9.6 170 16 57 29/37/39 NA 7 0/93 TR 9.3 600 TR 10/7/07 1606 10.2 155 21 56 22/63/67 8.2 10.75 0/89 TR 8.8 300 TR 10/8/07 2632 10.4 160 30 55 25/55/58 6.2 11 0/89 0.25 9.3 400 60 10/9/07 4305 10.4 70 27 42 23/32/45 4.6 10 1 /90 0.75 9.8 400 40 10/10/07 4305 10.4 121 28 44 20/32/48 5.6 12 0/88 0.5 9.5 400 40 10/11 /07 4305 10.5 100 30 50 21 /54/60 5.4 12 1 /88 0.5 9.4 400 40 10/12/07 4305 10.4 61 23 19 8/9/12 5.4 10 1/89 TR 9.1 400 40 10/13/07 4305 10.5 65 22 20 8/9/11 6 10 0/90 TR 8.9 400 60 10/14/07 4305 10.5 65 23 17 7/8/10 7 10 TR/90 TR 8.8 400 60 10/15/07 4305 10.5 65 23 17 7/8/10 7 10 TR/90 TR 8.8 400 60 10/16/07 5696 9.6 55 15 27 10/12/14 5.5 6 1/93 TR 10.3 200 40 10/17/07 7805 9.7 52 16 22 8/11/12 4.5 8 1/91 0.5 10.2 400 60 10!18/07 9455 9.6 48 14 22 10/14/16 5.4 8 2/90 0.25 9.9 400 60 10/19/07 9993 9.6 52 14 23 9/12/15 4.8 10 2/89 0.1 9.9 400 60 10/20/07 11955 9.6 43 10 21 8/11/12 5.4 8 2/90 0.1 9.3 400 60 10/21/07 12836 9.7 44 8 22 10/13/14 5 9 2/89 TR 10.1 400 80 10/22/07 13010 9.7 40 8 22 10/12/14 4.4 9 2/89 0.15 9.5 400 60 38 • • Daily Report Page 1 of 1 CONOCOPHILLIPS TARN DAILY WELLSITE REPORT ~~~~ 2L-319 REPORT FOR RICEIMURPHY DATE Oct 07, 2007 DEPTH 689.00000 PRESENT OPERATION DRILLING TIME 03:14:39 YESTERDAY 1.00000 24 HOUR FOOTAGE 688 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 357' 1.43 1.00 356' 448' 2.22 10.13 44T BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #1 12.250" HUGHES MXL-1 5121612 689' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 689.00000 0 @ 689.00000 0.0 185.46185 FT/HR SURFACE TORQUE 0 @ 689.00000 0 @ 689.00000 0.0 0.00000 AMPS WEIGHT ON BIT 0 @ 689.00000 0 @ 689.00000 0.0 14.78109 KLBS ROTARY RPM 0 @ 689.00000 0 @ 689.00000 0.0 0.00000 RPM PUMP PRESSURE 0 @ 689.00000 0 @ 689.00000 0.0 210.92952 PSI DRILLING MUD REPORT DEPTH 457' MW 9.6 VIS 170 PV 16 YP 57 FL NC Ge ls 27/37/39 CL- 600 FC 1/N/A SOL 7 SD TR OIL 0 MBL 25 pH 9.3 Ca+ TR CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 12 @ 689.00000 0 @ 689.00000 0.0 TRIP GAS N/A CUTTING GAS 0 @ 689.00000 0 @ 689.00000 0.0 WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 10000 @ 689.00000 0 @ 689.00000 0.0 CONNECTION GAS HIGH 0 ETHANE (C-2) 0 @ 689.00000 0 @ 689.00000 0.0 AVG 4u PROPANE (C-3) 0 @ 689.00000 0 @ 689.00000 0.0 CURRENT 4u BUTANE (C-4) 0 @ 689.00000 0 @ 689.00000 0.0 CURRENT BACKGROUND/AVG 4u PENTANE (C-5) 0 @ 689.00000 0 @ 689.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SANDY CONGLOMORATE AND SAND WITH CLAY PRESENT LITHOLOGY 10% CONGLOMORATE, 30% CONGLOMORATE SAND, 60% SAND DAILY ACTIVITY LOAD 9 5/8. M/U 12 1/4 BIT, MUD MOTOR AND STABILIZER. R/U GYRO. SPUD WELL, TAG FILL AT 90 SUMMARY FTMD. DRILL FROM 90-225FTMD. POOH TO P/U MWD TOOLS. DRILLING AT PRESENT REPORT TIME. EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 REPORT BY RYAN MASSEY file://C:\Documents%20and%20Settings\RigUser\Desktop\20071007.htm 10/7/2007 • • Daily Report Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT ~,~~~ 2L-319 REPORT FOR RICE/MURPHY DATE Oct 08, 2007 DEPTH 1645' PRESENT OPERATION DRILLING TIME 00:40:00 YESTERDAY 689' 24 HOUR FOOTAGE 956' CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1094.88' 26.10 84.60 1078.19' 1571.18' 55.01 84.42 1439.58' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE H OURS T/B/C PULLED #1 12.250" HUGHES MXL-1 1645' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 1645.00000 0 @ 1645.00000 0.0 314.05392 FT/HR SURFACE TORQUE 0 @ 1645.00000 0 @ 1645.00000 0.0 0.00000 AMPS WEIGHT ON BIT 0 @ 1645.00000 0 @ 1645.00000 0.0 24.37583 KLBS ROTARY RPM 0 @ 1645.00000 0 @ 1645.00000 0.0 0.00000 RPM PUMP PRESSURE 0 @ 1645.00000 0 @ 1645.00000 0.0 52.20862 PSI DRILLING MUD REPORT DEPTH 1606' MW 10.2 VIS 155 PV 21 YP 56 FL 8.2 Gels 22/63/67 CL- 300 FC 3/N/A SOL 10.75 SD TR OIL MBL 22 pH 8.8 Ca+ TR CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 2735 @ 1645.00000 0 @ 1645.00000 0.0 TRIP GAS N/A CUTTING GAS 0 @ 1645.00000 0 @ 1645.00000 0.0 WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 31770 @ 1645.00000 0 @ 1645.00000 0.0 CONNECTION GAS HIGH 234u ETHANE (C-2) 0 @ 1645.00000 0 @ 1645.00000 0.0 AVG PROPANE (C-3) 0 @ 1645.00000 0 @ 1645.00000 0.0 CURRENT 224u BUTANE (C-4) 0 @ 1645.00000 0 @ 1645.00000 0.0 CURRENT BACKGROUND/AVG 224u PENTANE {C-5) 0 @ 1645.00000 0 @ 1645.00000 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CLAYSTONE AND SANDSTONE PRESENT LITHOLOGY 90% CLAYSTONE, 10% SANDSTONE DAILY ACTIVITY DRILL 457 TO 974 FT/MD. WORK DOGLEG FROM 818 TO 915 FT/MD. DRILL 925' TO 1645 FT/MD. SUMMARY DRILLING CONTINUING AT REPORT TIME. MAX GAS WAS 2735u. EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 REPORT BY RYAN MASSEY • file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CPAL.. 10/8/2007 Daily Report • • Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT ~~'~~~ 2L-319 REPORT FOR RICE/MURPHY DATE Oct 09, 2007 DEPTH 2890' PRESENT OPERATION DRILLING TIME 00:40:00 YESTERDAY 1645' 24 HOUR FOOTAGE 1245' CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 2537' 72.03 84.54 1818.20' SURVEY DATA 2630' 72.58 83.26 1846.37' 2726' 72.52 85.47 1875.20' 2816' 72.95 83.62 1902.07' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #1 12.250" HUGHES MXL-1 1645' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ pgl DRILLING MUD REPORT DEPTH 2632' MW 10.4 VIS 160 PV 30 YP 55 FL 6.2 Gels 25/55/58 CL- 400 FC 2/N/A SOL 11 SD 0.25 OIL MBL 20 pH 9.3 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 2460u @ @ TRIP GAS 2460u CUTTING GAS 0 @ @ WIPER GAS N!A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 82000 @ 2890' @ CONNECTION GAS HIGH 2O3u ETHANE (C-2) 0 @ @ AVG PROPANE (C-3) 0 @ @ CURRENT 25u BUTANE (C-4) 0 @ @ CURRENT BACKGROUND/AVG 25u PENTANE (C-5) 0 @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CLAYSTONE AND SANDSTONE AND OCCASIONAL CARBONACEOUS SHALE PRESENT LITHOLOGY 80% CLAYSTONE, 20% SANDSTONE DAILY ACTIVITY DRILLED AHEAD TO 2890' CIRCULATED SWEEP 2 BOTTOMS UP. PULL OUT OF HOLE FOR CHANGING SUMMARY ADJUSTMENT ON MOTOR. TRIP IN HOLE BACK TO BOTTOM, CONTI NUE DRILLING AHEAD 2890' AT REPORT TIME. MAXIMUM TRIP GAS 2460u. EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 REPORT BY RYAN MASSEY file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CPAL.. 10/9/2007 Daily Report C7 • Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT ~ ~~~ 2L-319 , REPORT FOR RICE/MURPHY DATE Oct 10, 2007 DEPTH 4305' PRESENT OPERATION SHORT TRIP @ TD TIME 00:40:00 YESTERDAY 2890' 24 HOUR FOOTAGE 1415' CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 3578.83' 68.55 84.77 2143.55' SURVEY DATA 3956.42' 70.76 86.02 2271.21' 4049.89' 71.90 83.46 .2301.76' 4146.67' 69.80 83.80 2334.14' 4236.44' 69.68 84.32 2365.23' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #1 12.250" HUGHES MXL-1 4305' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 4305' MW 10.4 VIS 70 PV 27 YP 42 FL 4.6 Gels 23/32/46 CL- 400 FC 2/N/A SOL 10 SD 0.75 OIL MBL 32 pH 9.8 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 360u @ @ TRIP GAS 376u CUTTING GAS 0 @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 18950 @ 4298' @ CONNECTION GAS HIGH 314u ETHANE (C-2) 0 @ @ AVG PROPANE (C-3) 0 @ @ CURRENT 55u BUTANE (C-4) 0 @ @ CURRENT BACKGROUND/AVG 55u PENTANE (C-5) 0 @ ~p HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CLAYSTONE AND SANDSTONE AND OCCASIONAL CARBONACEOUS SHALE PRESENT LITHOLOGY 70% CIAYSTONE, 30% SANDSTONE DAILY ACTIVITY DRILL DOWN TO 4305'MD/2645TVD. PUMPED 3566E HI WEIGHT SWEEP WITH NUT PLUG MARKER TO SUMMARY OBTAIN LAG TIME. SAMPLE TO SURFACE AT 8500 +/- STROKES. MAX GAS 376u. EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 . REPORT BY RYAN MASSEY file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CPA... 10/10/2007 • • Daily Report Page 1 of 1 CONOCO PHILLIPS. TARN DAILY WELLSITE REPORT ~~~~; 2L-319 REPORT FOR BREEDEN/VAAGEN DATE Oct 11, 2007 DEPTH 4305' PRESENT OPERATION CIRCULATE FOR CASING TIME 00:40:00 YESTERDAY 4305' 24 HOUR FOOTAGE 0' CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE. TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #1 12.250" HUGHES MXL-1 4305' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACETOROUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 4305' MW 10.4 VIS 121 PV 28 YP 44 FL 5.6 Gels 20/32/48 CL- 400 FC 1/N/A SOL 12 SD 0.5 OIL MBL 33 pH 9.5 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 236u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT 42u BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 42u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CLAYSTONE AND SANDSTONE AND OCCASIONAL CARBONACEOUS SHALE PRESENT LITHOLOGY 70% CLAYSTONE, 30% SANDSTONE MAKE UP TOP DRIVE AFTER SHORT TRIP WHEN BACK ON BOTTOM, AT AROUND 2500 STKS, THE FLOW DAILY LINE PLUGGED UP FROM CHUNKS OF CLAY FROM FORMATION. CIRCULATE AND CONDITION SYSTEM. ACTIVITY SHORT TRIP TO 2890', CIRCULATE SWEEP AROUND, PULL OUT OF HOLE TO 3836' PUMP DRY JOB, PULL SUMMARY OUT OF HOLE TO SURFACE DOWN LOAD MWD. RUN IN THE HOLE AT REPORT WITH DRILLING ASSEMBLY FOR CLEAN OUT PRIOR TO RUNNING CASING, 4216' AT PRESENT TIME. MAX GAS 236u. EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 REPORT BY RYAN MASSEY • file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CPA... 10/11 /2007 • Daily Report Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT ~~~~~ 2L-319 REPORT FOR BREEDEN/VAAGEN DATE Oct 12, 2007 DEPTH 4305' PRESENT OPERATION RUN IN HOLE WITH 9.625" CASING. TIME 00:40:00 YESTERDAY 4305' 24 HOUR FOOTAGE 0' CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #1 12.250" HUGHES MXL-1 4305' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 4305' MW 10.5 VIS 100 PV 30 YP 50 FL 5.4 Gels 21/54/60 CL- 400 FC 2IN/A SOL 12 SD 0.5 OIL 1 MBL 34 pH 9.4 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 168u CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT 57u BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 57u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CLAYSTONE AND SANDSTONE AND OCCASIONAL CARBONACEOUS SHALE PRESENT LITHOLOGY 70% CLAYSTONE, 30% SANDSTONE DAILY ACTIVITY CONTINUE TO BOTTOM WITH CLEAN OUT ASSEMBLY, CIRCULATE HI-WEIGHT/ HI-VISCOSITY SWEEP SUMMARY WITH SLIGHT INCREASE OF CUTTINGS AT SHAKER. PUMP DRY JOB, PULL OUT OF HOLE TO SURFACE LAY DOWN BHA, RIG UP RUN 9.625" CASING TO 4300' AT REPORT TIME. MAX GAS 168u. EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 REPORT BY RYAN MASSEY file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CPA... 10/12/2007 • Daily Report Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT ~,~~~, 2L-319 REPORT FOR BREEDENNAAGEN DATE Oct 13, 2007 DEPTH 4305' PRESENT OPERATION WOC N/U BOP TIME 00:40:00 YESTERDAY 4305' 24 HOUR FOOTAGE 0' CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #1 12.250" HUGHES MXL- 1 4305' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 4305' MW 10.4 VIS 61 PV 23 YP 19 FL 5.4 Gels 8/9/12 CL- 400 FC 1/N/A SOL 10 SD TR OIL 1 MBL 28 pH 9.1 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm} SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT Ou BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG Ou PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CLAYSTONE AND SANDSTONE AND OCCASIONAL CARBONACEOUS SHALE PRESENT LITHOLOGY 70% CLAYSTONE, 30% SANDSTONE DAILY ACTIVITY COMPLETE RUNNING 9.625" CASING, CEMENT IN PLACE AT 12:30 PM, BUMP PLUG AT 4237 SUMMARY STROKES. CASING SHOE DEPTH RECORED AT 4295'. MAX GAS Ou. EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 REPORT BY RYAN MASSEY file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CPA... 10/13/2007 Daily Report Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT ~~~~ 2L-319 REPORT FOR BREEDENNAAGEN DATE Oct 14, 2007 DEPTH 4305' PRESENT OPERATION PICK UP DP TIME 00:40:00 YESTERDAY 4305' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625"@4295' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #2 8.750 HUGHES- PDC 7107627 4305' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 4305' MW 10.5 VIS 65 PV 22 YP 20 FL 6.0 Gels 8/9/11 CL- 400 FC 1/N/A SOL 10 SD TR OIL 0 MBL 28 pH 8.9 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT Ou BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG Ou PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CLAYSTONE AND SANDSTONE AND OCCASIONAL CARBONACEOUS SHALE PRESENT LITHOLOGY 70% CLAYSTONE, 30% SANDSTONE DAILY ACTIVITY SUMMARY NU/BOP AND TEST SAME. PICK UP R&T DRILL PIPE AT REPORT. MAX GAS Ou. EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 REPORT BY RYAN MASSEY • file://C:\Documents%20and%20Settings\RigUser\My%20Documents\My%20Wells\CPA... 10/14/2007 • s Daily Report Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT ~~~~,H 2L-319 REPORT FOR BREEDEN/VAAGEN DATE Oct 15, 2007 DEPTH 4305' PRESENT OPERATION TRIP IN THE DRILLING ASSEMBLY TIME 00:40:00 YESTERDAY 4305' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625"@4295' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #2 8.750 HUGHES HCM 6052 7107627 4305' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 4305' MW 10.5 VIS 65 PV 23 YP 17 FL 7.0 Gels 7/8/11 CL- 400 FC 2/N/A SOL 10 SD TR OIL TR MBL 28 pH 8.8 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) @ @ CONNECTION GAS HIGH N/A ETHANE (C-2) @ @ AVG PROPANE (C-3) @ @ CURRENT Ou BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG Ou PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CLAYSTONE AND SANDSTONE AND OCCASIONAL CARBONACEOUS SHALE PRESENT LITHOLOGY 70% CLAYSTONE, 30% SANDSTONE DAILY ACTIVITY FINISH RUN IN HOLE OPERATION WITH BHA TO 4100'. SLIP AND CUT DRILL LINE AT REPORT SUMMARY TIME. MAX GAS Ou. EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 REPORT BY RYAN MASSEY .7 file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\20071008.htm 10/15/2007 Daily Report • Page 1 of 2 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT ~ ~ P~~; 2L-319 , REPORT FOR BREEDENNAA GEN DATE Oct 16, 2007 DEPTH 5665' PRESENT OPERATION DRILLING TIME 00:40:00 YESTERDAY 4305' 24 HOUR FOOTAGE 1360' CASING INFORMATION 9.625"@4295' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 5275.59' 70.70 84.30 2725.45' SURVEY DATA 5370.30' 70.43 84.50 2756.96' 5465.11' 69.96 84.61 2789.09' 5560.75' 71.00 84.22 2821.04' 5655.91' 70.43 83.70 2852.47' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #2 8.750 HUGHES HCM 6052 7107627 5665' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACETOROUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 5696' MW 9.6 VIS 55 PV 15 YP 27 FL 5.5 Gels 10/12/14 CL- 200 FC 1/2 SOL 6 SD TR OIL 1 MBL 5 pH 10.3 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 187u CUTTING GAS 145u @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 10719.921 @ 5665' @ CONNECTION GAS HIGH 145u ETHANE (C-2) 66.501 @ 5665' @ AVG PROPANE (C-3) @ @ CURRENT 60u BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 60u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY CLAYSTONE AND SANDSTONE AND SILTSTONE PRESENT LITHOLOGY 70% CLAYSTONE, 20% SANDSTONE, 10% SILTSTONE DAILY CONTINUE RUN IN HOLE WITH DRILL ASSEMBLY, PRESSURE TEST CASING, RUN IN HOLE TO 4203', TAG ACTIVITY UP CEMENT, D RILL OUT SHOE TRACK AND 30' NEW HOLE TO 4335'. PUMP SWEET IN FRONT OF NEW SUMMARY MUD, AND DISPLACE WITH NEW LSND SYSTEM. CONTINUE DRILLING AHEAD AT REPORT TIME. MAX GAS 187u. • EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\20071008.htm 10/16/2007 Daily Report REPORT BY RYAN MASSEY • • Page 2 of 2 file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\20071008.htm 10/16/2007 Daily Report • • Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT ~,~QQ,~ 2L-319 REPORT FOR MORRISNAAGE N DATE Oct 17, 2007 DEPTH 7922' PR ESENT OPERATION DRILLING TIME 00:40:00 YESTERDAY 5665' 24 HOUR FOOTAGE 2257 CASING INFORMATION 9.625"@4295' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 7356.81' 71.36 85.35 3429.18' 7450.38' 70.49 84.78 3459.76' SURVEY DATA 7542.50' 71.86 84.64 3489.61' 7638.11' 71.09 84.35 3519.86' 7732.67' 71.33 83.92 3550.32' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE H OURS T/B/C PULLED #2 8.750 HUGHES HCM 6052 7107627 7922' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT(HR SURFACETOROUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 7805' MW 9.7 VIS 52 PV 16 YP 22 FL 4.5 Gels 8/11/12 CL- 400 FC 1/2 SOL 8 SD 105 OIL 1 MBL 18 pH 10.2 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS 71u @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm} SURVEY N/A METHANE (C-1) 4517.000 @ 7844' @ CONNECTION GAS HIGH 34u ETHANE (C-2) 47.072 @ 7844' @ AVG PROPANE (C-3) @ @ CURRENT 21u BUTANE (C-4) @ @ CURRENT BACKGROUND/AVG 21u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SANDSTONE, CLAYSTONE, AND SILTSTONE PRESENT LITHOLOGY 20% SANDSTONE, 80% SILTSTONE DAILY ACTIVITY CONTINUE DRILLING AHEAD, TO 7115' PUMPED HI-VISCOSITY SWEEP AND CIRCULATE BOTTOM UP. SUMMARY DRILL TO 7922' AT TIME OF REPORT. MAX GAS 71 u. EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 • REPORT BY RYAN MASSEY file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\20071008.htm 10/17/2007 • `r~~ `J r ~J Daily Report DAILY WELLSITE REPORT ~ EPOCH CONOCO PHILLIPS TARN 2L-319 REPORT FOR MORRISNAAGEN DATE Oct 18, 2007 TIME 00:40:00 CASING INFORMATION 9.625"@4295' DEPTH 9054.27' SURVEY DATA 9147.95 9242.12' 9336.19' 9433.92' BIT INFORMATION NO. SIZE TYPE #2 8.750 HUGHES HCM 6052 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.6 VIS 48 PV FC 1/2 SOL 8 SD MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) DITCH GAS CUTTING GAS 70u TRIP GAS N/A WIPER GAS N/A SURVEY N/A CONNECTION GAS HIGH 34u AVG CURRENT 15u CURRENT BACKGROUND/AVG 15u PENTANE (C-5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SANDSTONE, CLAYSTONE, AND SILTSTONE PRESENT LITHOLOGY 20% SANDSTONE, 70% SILTSTONE, 10% CLAYSTONE DAILY ACTIVITY SUMMARY CONTINUE DRILLING AHEAD AT TIME OF REPORT. MAX GAS 70u. DEPTH 9563' YESTERDAY 7922' 24 HOUR FOOTAGE 1641' PRESENT OPERATION DRILLING TH VERTICAL DEPTH 8 3992.20' 9 4022.90' 4 4053.76' 7 4085.59' 0 4119.11' CONDITION REASON HOURS T/B/C PULLED CURRENT AVG Page 1 of 1 FT/HR AMPS KLBS RPM PSI 5.4 Gels 10/14/16 CL- 400 22 pH 9.9 Ca+ 60 CCI HIGH LOW AVERAGE @ @ @ @ CHROMATOGRAPHY (ppm) METHANE (C-1) 4764 @ 9463' @ ETHANE (C-2) 116.193 @ 9463' @ PROPANE (C-3) 20.000 @ 9463' @ BUTANE (C-4) @ @ EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 REPORT BY RYAN MASSEY INCLINATION AZIMU 70.47 84.9 71.28 83.4 70.46 83.3 69.98 82.1 69.91 81.6 INTERVAL S/N JETS IN OUT FOOTAGE 7107627 7922' HIGH LOW AVERAGE @ @ @ @ @ @ @ @ @ @ DEPTH 9455' 14 YP 22 FL 0.25 OIL 2 MBL file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\20071008.htm 10/18/2007 Daily Report • L' Page 1 of 2 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT ~,P~~~ 2L-319 REPORT FOR MORRlS/VAAGEN DATE Oct 19, 2007 DEPTH 10129' PRESENT OPERATION DRILLING TIME 00:40:00 YESTERDAY 9563' 24 HOUR FOOTAGE 566' CASING INFORMATION 9.625"@4295' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 9622.19' 71.32 84.15 4181.50' SURVEY DATA 9717.20' 70.87 83.81 4212.28' 9808.73' 70.48 83.56 4242.57' 9901.43' 70.23 85.34 4273.74' 9998.79' 69.44 85.26 4307.30' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #2 8.750 HUGHES HCM 6052 7107627 7922' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9993' MW 9.6 VIS 52 PV 14 YP 23 FL 8.6 Gels 9/12/15 CL- 400 FC 1/2 SOL 10 SD 0.1 OIL 2 MBL 24 pH 9.9 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 78u CUTTING GAS 45u @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 7017.000 @ 10025' @ CONNECTION GAS HIGH 34u ETHANE (C-2) 305.954 @ 10025' @ AVG PROPANE (C-3) 132.460 @ 10025' @ CURRENT 22u BUTANE (C-4) 84.500 @ 10025' @ CURRENT BACKGROUND/AVG 22u PENTANE (C-5) 20.839 @ 10025' @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SANDSTONE, CLAYSTONE, SILTSTONE, AND CARBONACEOUS SHALE PRESENT LITHOLOGY 10% SANDSTONE, 60% SILTSTONE, 10% CLAYSTONE, 20% CARBOBACEOUS SHALE DAILY CONTINUE DRILLING TO 9733' MD/417'TVD, MIX AND PUMP 30 BARRELS HIGH VISCOSITY AT 1.5PPG OVER ACTIVITY MUD WEIGHT. DRILL DOWN TO 9766', PUMPED SECOND PILL 27 BARRELS HIGH VISCOSITY/ HIGH WEIGHT SUMMARY 1.5 PPG OVER, CIRCULATED OUT TO ROCKWASHER. PUMPED DRY JOB, PULL OUT OF HOLE SHORT TRIP TO 4279'. RUN IN HOLE AND CONTINUE DRILLING AHEAD AT REPORT TIME. MAX GAS 78u. EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\20071008.htm 10/19/2007 Daily Report REPORT BY RYAN MASSEY C. Page 2 of 2 file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\20071008.htm 10/19/2007 • • Daily Report Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT ~,~~~,~ 2L-319 REPORT FOR MORRISNAAGEN DATE Oct 20, 2007 DEPTH 12021' PRESENT OPERATION DRILLING TIME 00:40:00 YESTERDAY 10129' 24 HOUR FOOTAGE 1892' CASING INFORMATION 9.625"@4295' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 11603.10' 59.32 84.49 4889.64' 11696.33' 56.84 84.25 4938.93' SURVEY DATA 11791.57' 53.79 84.11 4993.12' 11886.44' 50.21 85.43 5051.52' 11984.70' 47.56 84.28 5116.13' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYP E S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #2 8.750 HUGHES HCM 6052 7107627 7922' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 11955' MW 9.6 VIS 43 PV 10 YP 21 FL 5.4 Gels 8/11/12 CL- 400 FC 1l2 SOL 8 SD 0.1 OIL 2 MBL 28 pH 9.3 Ca+ 6.0 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS 595u @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 17117.000 @ 11916' @ CONNECTION GAS HIGH 119u ETHANE (C-2) 7028.259 @ 11916' @ AVG PROPANE (C-3) 486.254 @ 11916' @ CURRENT 59u BUTANE (C-4) 351.789 @ 11916' @ CURRENT BACKGROUND/AVG 59u PENTANE (C-5) 152.118 @ 11916' @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SANDSTONE, CLAYSTONE, SILTSTONE, AND CARBONACEOUS SHALE PRESENT LITHOLOGY 50% SANDSTONE, 40% SILTSTONE, 10% CLAYSTONE DAILY ACTIVITY SUMMARY CONTINUE TO DRILL, ROTATE AND SLIDE AS PER DIRECTIONAL DRILLING. MAX GAS 595u. EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 REPORT BY RYAN MASSEY file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\20071008.htm 10/20/2007 Daily Report J • Page 1 of 2 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT ~ El'O-~~I 2L-319 REPORT FOR MORRIS/VAAGEN DATE Oct 21, 2007 DEPTH 12832' PRESENT OPERATION DRILLING TIME 00:40:00 YESTERDAY 12021' 24 HOUR FOOTAGE 811' CASING INFORMATION 9.625"@4295' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12362.86' 41.63 83.52 5384.88' SURVEY DATA 12456.17 40.62 83.67 5455.17 12550.64' 40.10 84.73 5527.15' 12645.59' 39.45 84.09 5600.13' 12740.70' 38.17 83.98 5674.24' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #2 8.750 HUGHES HCM 6052 7107627 7922' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 12836' MW 9.7 VIS 44 PV 8 YP 22 FL 5 Gels 10/13/14 CL- 400 FC 1/2 SOL 9 SD TR OIL 2 MBL 18 pH 10.1 Ca+ 80 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS 655u @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 17119.000 @ 12830' @ CONNECTION GAS HIGH 490u ETHANE (C-2) 5918.432 @ 12830' @ AVG PROPANE (C-3) 510.389 @ 12830' @ CURRENT 71u BUTANE (C-4) 351.946 @ 12830' @ CURRENT BACKGROUND/AVG 71u PENTANE (C-5) 156.611 @ 12830' @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SANDSTONE, CLAYSTONE, SILTSTONE, AND CARBONACEOUS SHALE PRESENT LITHOLOGY 20% SANDSTONE, 60% SILTSTONE, 10% CLAYSTONE, 10% CARBONACEOUS SHALE DAILY ACTIVITY CONTINUE DRILLING AHEAD, CONTROL RATE THROUGH PAY ZONE. DRILL DOWN 12403' SHORT TRIP SUMMARY TO PICK UP ADDITIONAL DRILL PIPE, CONTINUE DRILLING TO 12832' AT REPORT TIME. CHANGE OUT COOLING MOTOR FOR TD. MAX GAS 655u. EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 REPORT BY RYAN MASSEY file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\20071008.htm 10/21/2007 • • • Daily Report Page 2 of 2 file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\20071008.htm 10/21/2007 Daily Report • • Page 1 of 2 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT ~~"(~~~ 2L-319 REPORT FOR MORRIS/VAAGEN DATE Oct 22, 2007 DEPTH 13010' PRESENT OPERATION SHORT TRIP TIME 00:40:00 YESTERDAY 12832' 24 HOUR FOOTAGE 178' CASING INFORMATION 9.625"@4295' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH 12740.70' 38.17 83.98 5674.24' SURVEY DATA 12836.65' 37.09 83.95 5750.23' 12931.31' 35.77 83.72 5826.39' 12968.08' 35.24 83.77 5856.32' 13010.00' 35.24 83.77 5890.56' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #2 8.750 HUGHES HCM 6052 7107627 7922' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13010' MW 9.7 VIS 40 PV 8 YP 22 FL 4.4 Gels 10/12/14 CL- 400 FC 1/ SOL 9 SD 0.15 OIL 2 MBL 23 pH 9.5 Ca+ 60 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS N/A CUTTING GAS 232u @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 35450.000 @ 13010' @ CONNECTION GAS HIGH 131u ETHANE (C-2) 12820.000 @ 13010' @ AVG PROPANE (C-3) 1629.000 @ 13010' @ CURRENT 1u BUTANE (C-4) 1039.000 @ 13010' @ CURRENT BACKGROUND/AVG 1u PENTANE (C-5) 324.000 @ 13010' @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SANDST ONE, SILTSTONE, SHALE, AND CARBONACEOUS SHALE PRESENT LITHOLOGY 20% SANDSTONE, 40% SILTSTONE, 10% CARBONACEOUS SHALE, 30% SHALE COMPLETE WORKING ON TOP DRIVE COOLING MOTOR, CONTINUE DRILLING AHEAD TO 13010' DAILY ACTIVITY MEASURED DEPTH / 5890' TVD TOTAL DEPTH FOR WELL. CIRCULATE SWEEP AROUND AND FOUR SUMMARY BOTTOMS UP, PUMP DRY JOB AND PULL OUT OF HOLE FOR SHORT TRIP TO CASING SHOE. MAX GAS 232 • EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\20071008.htm 10/22/2007 • • Daily Report REPORT BY RYAN MASSEY Page 2 of 2 file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\20071008.htm 10/22/2007 • Daily Report Page 1 of 1 CONOCO PHILLIPS TARN DAILY WELLSITE REPORT ~~Q~~ 2L-319 REPORT FOR MORRIS/VAA GEN DATE Oct 23; 2007 DEPTH 13010' PRESENT OPERATION PULL OUT OF HOLE TIME 00:40:00 YESTERDAY 13010' 24 HOUR FOOTAGE 0' CASING INFORMATION 9.625"@4295' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED #2 8.750 HUGHES HCM 6052 7107627 7922' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT/HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 13010' MW 9.8 VIS 64 PV 14 YP 30 FL 3.2 Gels 10/20/22 CL- 100 FC 1/N/A SOL 9 SD 0.1 OIL 1 MBL 18 pH 10.2 Ca+ TR CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 298u CUTTING GAS 0 @ @ WIPER GAS N/A CHROMATOGRAPHY (ppm) SURVEY N/A METHANE (C-1) 35450.000 @ 13010' @ CONNECTION GAS HIGH N/A ETHANE (C-2) 12820.000 @ .13010' @ AVG PROPANE (C-3) 1629.000 @ 13010' @ CURRENT Ou BUTANE (C-4) 1039.000 @ 13010' @ CURRENT BACKGROUND/AVG Ou PENTANE (C-5) 324.000 @ 13010' @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SANDS TONE, SILTSTONE, SHALE, AND CARBONACEOUS SHALE PRESENT LITHOLOGY 20% SANDSTONE, 40% SILTSTONE, 10% CARBONACEOUS SHALE, 30% SHALE DAILY ACTIVITY FINISH DU MMY TRIP TO 4283' MD. RUN IN HOLE TO 13010' MD, PUMP WEIGHTED SWEEP AND THREE SUMMARY BOTTOMS UP. SPOT CASING RUNNING FLUID. PULL OUT OF HOLE TO 8465' MD. MAX GAS 298. EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 REPORT BY RYAN MASSEY • file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\20071008.htm 10/23/2007 I ~J Cl C] Daily Report Page 1 of 1 CONOCO PHILLIPS TARN 2L-319 REPORT FOR MORRIS/DINK DATE Oct 24,2007 TIME 00:40:00 DAILY WELLSITE REPORT DEPTH 13010' YESTERDAY 13010' 24 HOUR FOOTAGE 0' [~ F,POCH PRESENT OPERATION CASING CASING INFORMATION 9.625"@4295' SURVEY DATA DEPTH BIT INFORMATION NO. SIZE TYPE #2 8.750 HUGHES HCM 6052 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 10.0 VIS 52 PV FC 1/ SOL 9.5 SD MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) DITCH GAS CUTTING GAS 0 TRIP GAS N/A WIPER GAS N/A SURVEY N/A CONNECTION GAS HIGH N/A AVG CURRENT Ou CURRENT BACKGROUND/AVG Ou PENTANE (C-5) 324.000 @ 13010' @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SANDSTONE, SILTSTONE, SHALE, AND CARBONACEOUS SHALE PRESENT LITHOLOGY 20% SANDSTONE, 40% SILTSTONE, 10% CARBONACEOUS SHALE, 30% SHALE DAILY ACTIVITY PULL OUT OF THE HOLE. LAY DOWN BHA. FLUSH STACK AND PULL WEAR RING. CHANGE UPPER SUMMARY RAMS TO 4.5" AND LOWER RAM TO 7". TEST RAMS. LOAD 7" CASING AT REPOR TIME. MAX GAS Ou INCLINATION AZIMUTH VERTICAL DEPTH INTERVAL S/N JETS IN OUT FOOTAGE 7107627 7922' HIGH LOW AVERAGE @ @ @ @ @ @ @ @ @ @ DEPTH 13010' 12 YP 23 0.1 OIL 1 CONDITION REASON HOURS T/B/C PULLED CURRENT AVG FT/H R AMPS KLBS RPM PSI FL 3.8 Gels 10/15/16 CL- 200 MBL 20 pH 9.0 Ca+ TR CCI HIGH LOW AVERAGE @ @ @ @ CHROMATOGRAPHY(ppm) METHANE (C-1) 35450.000 @ 13010' @ ETHANE (C-2) 12820.000 @ 13010' @ PROPANE (C-3) 1629.000 @ 13010' @ ~I BUTANE (C-4) 1039.000 @ 13010' @ EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 REPORT BY MAINUDDIN CHOWDHURY file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\20071008.htm 10/24/2007 • L C Daily Report DAILY WELLSITE REPORT CONOCO PHILLIPS TARN 2L-319 REPORT FOR MORRIS/DINK DATE Oct 25,2007 TIME 00:40:00 DEPTH 13010' YESTERDAY 13010' 24 HOUR FOOTAGE 0' Page 1 of 1 E~ EPOCH PRESENT OPERATION CIRCULATE CASING INFORMATION 9.625"@4295' SURVEY DATA DEPTH BIT INFORMATION NO. SIZE TYPE #2 8.750 HUGHES HCM 6052 DRILLING PARAMETERS RATE OF PENETRATION SURFACE TORQUE WEIGHT ON BIT ROTARY RPM PUMP PRESSURE DRILLING MUD REPORT MW 9.8 VIS 43 PV FC 1/ SOL 9.0 SD MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) DITCH GAS g5 CUTTING GAS 0 TRIP GAS N/A WIPER GAS 95u SURVEY N/A CONNECTION GAS HIGH N/A AVG CURRENT 38u CURRENT BACKGROUND/AVG 38u PENTANE (C-5) 324.000 @ 13010' @ HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY SANDSTONE, SILTSTONE, SHALE, AND CARBONACEOUS SHALE PRESENT LITHOLOGY 20% SANDSTONE, 40% SILTSTONE, 10% CARBONACEOUS SHALE, 30% SHALE DAILY ACTIVITY LOAD 7" CASING. RUN 4.5" CASING TO 805' MD. RUN 7" CASING TO 10255'MD. CIRCULATE B/U AT SUMMARY SURFACE CASING SHOE AND EVERY 1500' THERE AFTER. MAXIMUM GAS 97u . INCLINATION AZIMUTH VERTICAL DEPTH INTERVAL S/N JETS IN OUT FOOTAGE 7107627 7922' HIGH LOW AVERAGE @ @ @ @ @ @ @ @ @ @ DEPTH 13010' 13 YP 20 FL Tr OIL 1 MBL CONDITION REASON HOURS T/B/C PULLED CURRENT AVG FT/HR AMPS. KLBS RPM PSI 5.4 Gels 9113/13 CL- 150 17 pH 9.0 Ca+ Tr CCI HIGH LOW AVERAGE @ 5240' @ @ @ CHROMATOGRAPHY (ppm) METHANE (C-1) 35450.000 @ 13010' @ ETHANE (C-2) 12820.000 @ 13010' @ PROPANE (C-3) 1629.000 @ 13010' @ BUTANE (C-4) 1039.000 @ 13010' @ EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335 REPORT BY MAINUDDIN CHOWDHURY file://C:\Documents and Settings\RigUser\My Documents\My Wells\CPAI\20071008.htm 10/25/2007