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207-129
By Grace Christianson at 12:53 pm, Apr 22, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.04.22 09:25:39 - 08'00' Sean McLaughlin (4311) 325-245 *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. *Window milling on service coil not approved on 10-403, refer to sidetrack PTD for approval. *Sealing whipstock with < 100' for liner lap cement JJL 4/22/25 10-407 DSR-4/24/25 , ADL 028312 SFD SFD 4/24/2025*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.24 14:04:03 -08'00'04/24/25 RBDMS JSB 042525 To: Alaska Oil & Gas Conservation Commission From:Ryan Ciolkosz Drilling Engineer Date: April 21, 2025 Re:14-18B Sundry Request Sundry approval is requested to set a whipstock and mill a window in the 14-18B wellbore as part of the drilling and completion of the proposed 14-18C CTD lateral. Proposed plan: Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line or coil will mill the XN- nipple. E-line will set a 4-1/2" packer whipstock. Coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to pre-rig, the rig will set the 4-1/2" packer whipstock and mill a single string 3.80" window + 10' of formation. The well will kick off drilling in the Shublik and lands in Ivishak Zone 4. The lateral will continue in Zone 4 to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Prudhoe Pool perfs. This Sundry covers plugging the existing perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in May 1st, 2025) x Reference 14-18C Permit submitted in concert with this request for full details. 1. Slickline : Set DGLV 2. Coil : Mill XN nipple. Dress LNR across perfs near KOP. 3. Slickline : Redrift for Whipstock 4. Eline : Set 45 PKR WS at 10,740' at 0 deg ROHS 5. Coil : Mill Window 6. Valve Shop : Pre-CTD Tree Work 7. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in June 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,387 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” Window (if not done pre-rig). 3. Drill build section: 4.25" OH, ~356' (35 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~1819' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr solid liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 29 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL*. 7. Only if not able to do with service coil extended perf post rig – Perforate Liner 8. Freeze protect well to a min 2,200' TVD. 9. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : Liner lap test. Set LTP if necessary. Set live GLVs 3. Service Coil : Post rig RPM, CBL, and perforate 30' Ryan Ciolkosz CC: Well File Drilling Engineer Joe Lastufka 907-244-4357 Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3-1/8" Pipe / Slip Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 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:PB Wells Integrity To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Oliver Sternicki; Bo York; PB Wells Integrity Subject:UNDER EVALUATION: Producer 14-18B (PTD #2071290) IA over MOASP, failed TIFL Date:Sunday, April 21, 2024 7:31:26 AM Attachments:14-18B.pdf Mr. Regg, Producer 14-18B (PTD #2071290) was reported to have IA casing pressure above MOASP on 04/20 after the well was shut-in. A warm TIFL on 04/21 failed, indicating a failure of a well barrier. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Slickline (pending): Replace SO 3. DHD: warm TIFL Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. PBU 14-18B PTD 2071290 TIO Pressures Plot PBU 14‐18B (PTD 2071290) 4/21/2024 1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Saturday, August 26, 2023 6:22 AM To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Bo York; Oliver Sternicki; PB Wells Integrity Subject:OPERABLE: Producer 14-18B (PTD #2071290) warm TIFL passed Mr. Regg, Producer 14‐18B (PTD # 2071290) was put online on 08/24 and passed a warm TIFL on 08/25. The passing TIFL indicates two competent well barriers and the well is now classified as OPERABLE. Please respond with any quesƟons. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, August 8, 2023 3:04 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: chris.wallace@alaska.gov; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Producer 14‐18B (PTD #2071290) IA casing pressure above MOASP, failed TIFL Mr. Regg, Producer 14‐18B (PTD #2071290) was reported to have IA casing pressure above MOASP on 08/07/23 aŌer the well was shut‐in for the FS3 TAR. On 08/08/23 DHD bled the IAP to ~980 psi and performed a failing cold TIFL. The failed TIFL indicates a failure of a well barrier and the well will now be classified as UNDER EVALUATION and is on the 28‐day clock for diagnosƟcs. Plan Forward: 1.DHD: Perform warm TIFL when FS3 is back online 2.Well Integrity: AddiƟonal diagnosƟcs as needed Please respond with any quesƟons. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com 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. PBU 14-18BPTD 2071290 2 P: (907) 659‐5102 M: (307)399‐3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Tuesday, August 8, 2023 3:04 PM To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Bo York; Oliver Sternicki; PB Wells Integrity Subject:UNDER EVALUATION: Producer 14-18B (PTD #2071290) IA casing pressure above MOASP, failed TIFL Attachments:14-18B.pdf; TIOChart.jpg Mr. Regg, Producer 14‐18B (PTD #2071290) was reported to have IA casing pressure above MOASP on 08/07/23 aŌer the well was shut‐in for the FS3 TAR. On 08/08/23 DHD bled the IAP to ~980 psi and performed a failing cold TIFL. The failed TIFL indicates a failure of a well barrier and the well will now be classified as UNDER EVALUATION and is on the 28‐day clock for diagnosƟcs. Plan Forward: 1.DHD: Perform warm TIFL when FS3 is back online 2.Well Integrity: AddiƟonal diagnosƟcs as needed Please respond with any quesƟons. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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. PBU 14-18BPTD 2071290 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:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Producer 14-18B (PTD #2071290) TIFL Passed Date:Tuesday, August 30, 2022 8:53:04 AM Attachments:image001.png image002.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, August 30, 2022 5:26 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Producer 14-18B (PTD #2071290) TIFL Passed Mr. Regg, Producer 14-18 (PTD #207129) passed a TIFL on 08/29/22 post gas lift valve change out. The passing TIFL demonstrates competent primary well barrier. At this time, the well is classified as OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Tuesday, August 9, 2022 6:31 AM To: jim.regg@alaska.gov Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUTION: Producer 14-18B (PTD #2071290) Sustained Casing Pressure IA All, Producer 14-18 (PTD #207129) was reported by operations with IA pressure over NOL ~2330 psi during pad shut down on 08/08/22. A subsequent TIFL failed on 08/09/22 which indicates a failure of one or more well barriers. At this time, the well is classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Downhole Diagnostics: Warm TIFL once pad is brought back online 2. Well Integrity: Further intervention as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, September 8, 2016 8:08 PM To: AK, OPS FS3 OSM <AKOPSFS3OSM1@bp.com>; AK, OPS FS3 Facility OTL <AKOPSFS3FacilityOTL@bp.com>; AK, OPS FS3 Field OTL <AKOPSFS3FieldOTL@bp.com>; AK, OPS FS3 DS Ops Lead <AKOPSFS3DSOpsLead@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; G GPB FS3 Drillsites <ggpbfs3drillsites@BP.com>; Vohra, Prachi <Prachi.Vohra@bp.com> Cc: AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Pettus, Whitney <Whitney.Pettus@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Troy <Troy.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: OPERABLE: Producer 14-18B (PTD #2071290) TIFL Passed Post-Gas Lift Work All, Producer 14-18B (PTD #2071290) passed a cold TIFL on 09/07/16, following gas lift valve work. The well is reclassified as Operable. Work Completed: 1. Slickline: Pull Orifice GLV, set Dummy GLV 2. Downhole Diagnostics: Perform Cold TIFL – PASSED 3. Slickline: Set Barrier Orifice GLV Thanks, Adrienne McVey Well Integrity Superintendent – GWO Alaska (Alternate: Jack Lau) O: (907) 659-5102 C: (907) 943-0296 H: 2376 Email: AKDCWellIntegrityCoordinator@BP.com From: AK, GWO SUPT Well Integrity Sent: Monday, September 05, 2016 4:23 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Facility OTL; AK, OPS FS3 Field OTL; AK, OPS FS3 DS Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; G GPB FS3 Drillsites; Vohra, Prachi Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO Completions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy; Worthington, Aras J Subject: UNDER EVALUATION: Producer 14-18B (PTD #2071290) TIFL Failed All, Producer 14-18B (PTD #2071290) failed a warm TIFL on 09/03/16, indicating a lack of two competent well barrier envelopes. The well is reclassified as Under Evaluation. As MOASP was not exceeded, no notification to the AOGCC is necessary. Plan Forward: 1. Slickline: change out OGLV 2. DHD: re-TIFL 3. Well Integrity Engineer: Additional diagnostics as required Please reply if in conflict with proposed plan. Thanks, Adrienne McVey Well Integrity Superintendent – GWO Alaska (Alternate: Jack Lau) O: (907) 659-5102 C: (907) 943-0296 H: 2376 Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, November 01, 2015 7:22 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou, Irwin Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Dickerman, Eric; Sayers, Jessica Subject: OPERABLE: Producer 14-18B (PTD #2071290) MIT-IA Passed post valve changeout All, Producer 14-18B (PTD #2071290) passed a MIT-IA to 2500 psi on October 28, 2015 following gas lift valve work. This passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. Please use caution when bringing the well online as the annuli are fluid packed. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate: Kevin Parks) BP Alaska - Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, July 29, 2015 2:07 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Chou, Irwin Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer Subject: NOT OPERABLE: Producer 14-18B (PTD #2071290) TIFL Failed All, Producer 14-18B (PTD #2071290) failed a TIFL on 07/26/2015. The failing TIFL indicates a lack of two competent barriers in the wellbore. The well is reclassified as Not Operable until tubing integrity is restored and verified. Proposed plan forward: 1. Slickline to dummy gas lift valves and MIT-IA 2. APE to evaluate for LDL if MIT-IA Fails Please call with any questions or concerns. Thank you, Kevin Parks (Alternate: Whitney Pettus) BP Alaska - Well Integrity Coordinator Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@bp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 20 71 29 BA ER0 • • UGHES PRINT DISTRIBUTION LIST 2 9 2 8 7 a GE company Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-1 WELL NAME 14-18B 900 E.Benson Blvd. Anchorage,Alaska 99508 or AKGDMINTERNAL@bp.com FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY PRUDHOE BAY LOG TYPE RPM:PNC3D-CO BHI DISTRICT Alaska --- LOG DATE March 7,2018 AUTHORIZED BY Paul Canizarest,�� EMAIL Paul.Canizaresbhqe.com TODAYS DATE May 29,2018 Revision MAY 3 0 2018 STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las,dlis, PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OFPRINTS #OF I'NIN I S n#OF COPIES #OF COPIES #OF COPIES V V V fj v 1 BP North Slope. 0 1 1 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aides Attn:Benda Glassmaker&Peggy O'Neil J U N 1 Q 900 E.Benson Blvd. SCANS) Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 1 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99501 3 ExxonMobil,Alaska 0 0 1 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 .Anchorage,AK 99503 41State of Alaska -AOGCC 0 1 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division ofOil&Gas *** 0 0 1 Attn:Garret Brown 550 West 7th Avenue,Suite 1100 Anchorage,Alaska 99501 r *Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn: Gerardo Cedillo TOTALS FOR THIS PAGE: 0 2 5 0 0 R Erl STATE OF ALASKA E F I V • 0 ALASKA OIL AND GAS CONSERVATION CO ION REPORT OF SUNDRY WELL OPER NSAPR 9 too 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations kusocinm, Suspend 0 Perforate H Other Stimulate 0 Alter Casing 0 Change A Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 207-129 3. Address: P.O.Box 196612 Anchorage, Development ® Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20551-02-00 7. Property Designation(Lease Number): ADL 028312,028313 8. Well Name and Number: PBU 14-188 1 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 11130 feet Plugs measured None feet true vertical 8973 feet Junk measured None feet Effective Depth: measured 11045 feet Packer measured 10446 feet true vertical 8915 feet Packer true vertical 8505 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 31-111 31-111 1530 520 Surface 2620 13-3/8" 29-2648 29-2648 5380 2670 Intermediate 3481 9-5/8" 27-3507 27-3507 6870 4760 Liner 7344 7" 3354-10698 3354-8677 7240 5410 Liner 574 4-1/2" 10557-11131 8581 -8974 8430 7500 Perforation Depth: Measured depth: 10700-10943 feet True vertical depth: 8678-8844 feetS�rl'e1Y g k Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 24-10565 24-8586 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perri Packer 10446 8505 true vertical depth) No SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 105 856 377 1299 272 Subsequent to operation: 275 2789 802 1212 258 14.Attachments:(required per 20 AAC 25.070 25 071,a 25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory 0 Development I! Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. C 1.0° Sundry Number or N/A if C.O.Exempt: _ / Vii. 0 ' N/A Authorized Name: Vohra,Prachi 11331)1.4 Contact Name: Vohra,Prachi Authorized Title: Production Engr Contact Email: Prachi.Vohra@bp.com Authorized Signature: la, Date: 11124 201g Contact Phone: +1 9075644677 — Form 10-404 Revised 04/2017 I/T L 1-/2e'/l f3 A4f 01( Submit Original Only Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) March 30, 2018 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Perforate for Well PBU 14-18B, PTD #207-129. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration Alaska Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • Daily Report of Well Operations PBU 14-18B ACTIVITYDATE SUMMARY ***WELL FLOWING ON ARRIVAL*** (SLB ELINE CONVEYED RPM LOG/PERF) INITIAL T/I/O=850/1150/100 PSI MIRU SLB AND LRS, PT, FREEZE PROTECT FLOWLINE RIH W/BAKER RPM TO PERFORM RPM BORAX TD TAGGED @ 10967'. LOG TWO SIGMA PASS UP @ 15 FPM OVER INTERVAL 10680'-10967' 3/6/2018 ***JOB CONTINUED ON 07-MAR-2018*** T/I/O=977/1193/97 Assist E-Line. Freeze protect FL prior to Assisting Eline, Pumped 10 bbls 60/40 meth spear per DSO Gordon, Followed by 50 bbls crude to FP FL. Load well with 245 bbls 1 %kcl at max rate. 3/6/2018 Pumped .5 bpm for 66 bbls for RPM log.***WSR continued on 03-07-2018*** ***WSR continued from 03/06/2018*** Assist E-Line Pumped 137 bbls for RPM log. Pumped 110 bbls borax with 6 bbls of 60/40 meth pills for spacer on borax. Pumped a total of 437 bbls KCL for flush. Freeze protected well with 2bbls 60/40 and 40 bbls crude.(see log for details) Final WHP's 465/1700/110 E-line on well at 3/7/2018 departure IA, OA=OTG AL=Closed at casing ***JOB CONTINUED FROM 06-MAR-2018*** (SLB ELINE CONVEYED RPM LOG/PERF) IN HOLE W/HEAD(1.375 FN)/ERS(1.375"FN)/WEIGHT/BAKER RPM. OAL=44',OAW=250#, MAXOD=1.7" LOG THREE C/O PASSES UP @ 2 FPM OVER INTERVAL 10830'-10967' LOG TWO BORAX PASSES UP @ 40 FPM OVER INTERVAL 10680'-10967' LOG PLUSH PASS UP @ 40 FPM OVER INTERVAL 10680'-10967'.CONFIRM BORAX IS FLUSHED. GUN 1: RIH W/10'X 3-3/8"POWERJET NOVA HSD,6 SPF,60 DEG PHASE. GUN FAILED TO FIRE, POOH, FIND DAMAGED WIRE IN WPSA. GUN 1, SECOND ATTEMPT: RIH W/10'X 3-3/8"POWERJET NOVA HSD,6 SPF,60 DEG PHASE. PERFORATED INTERVAL=10930'-10940'. CCL TO TOP SHOT=7.3', CCL STOP DEPTH= 10922.7'. GUN 2: RIH W/10'X 3-3/8"POWERJET NOVA HSD,6 SPF,60 DEG PHASE. PERFORATED INTERVAL= 10920'-10930'. CCL TO TOP SHOT=7.3',CCL STOP DEPTH= 10912.7'. GUN 3: RIH W/10'X 3-3/8"POWERJET NOVA HSD,6 SPF,60 DEG PHASE. PERFORATED INTERVAL= 10910'-10920'. CCL TO TOP SHOT=7.3',CCL STOP DEPTH=10902.7'. GUN 4: RIH W/10'X 3-3/8"POWERJET NOVA HSD,6 SPF,60 DEG PHASE. PERFORATED INTERVAL= 10900'-10910'. CCL TO TOP SHOT=7.7', CCL STOP DEPTH=10892.3'. GUN 5: RIH W/10'X 3-3/8"POWERJET NOVA HSD,6 SPF,60 DEG PHASE. ALL PERF PASSES TIED INTO SLB JEWELRY LOG DATED 08-DEC-2007 3/7/2018 ***JOB CONTINUED ON 08-MAR-2018*** ***JOB CONTINUED FROM 07-MAR-2018*** (SLB ELINE PERF) IN HOLE W/GUN 5: 10'X 3-3/8"POWERJET NOVA HSD,6 SPF,60 DEG PERFORATED INTERVAL=10890'-10900'. CCL TO TOP SHOT=7.3',CCL STOP DEPTH= 10882.7'. GUN 6: RIH W/10'X 3-3/8"POWERJET NOVA HSD,6 SPF,60 DEG PHASE. PERFORATED INTERVAL= 10860'-10870'. CCL TO TOP SHOT=7.4',CCL STOP DEPTH= 10852.6'. ALL PERF PASSES TIED INTO SLB JEWELRY LOG DATED 08-DEC-2007 WELL S/I ON DEPARTURE, FINAL T/I/O=130/1300/60 3/8/2018 ***JOB COMPLETE ON 08-MAR-2018*** Fluids Summary Bbls Type 1 Diesel 91 Crude 875 1% KCL 23 60/40 Methanol 113 Borax ?}EE= 4-1/16'( ,V VVI3LtEAD= _ GRAY • 1 4-1 8B • SAFETY NOTES:""4-1/,2-CH E IBM*"AC1L1ATOR=___- BAKB2 C KB.ELEV=- 71' - - i BF.ELEV= KOP= — ; Mu Ange= 51°4t 5615' / I 2203' H4-1/2'HE'S X NP,D=3.813' ( tum MD= 10981' 2574' 9-5/8"DV PKR Datum ND= 8800'SS ' GAS LFT MANDRB.S © ST MD TVD DEV TYFE VLV LATCH PORT DA 20"CONDUCTOR,91.511,H-40,D=19.124" 110' 7 2849 2849 0 KBG2 DAY BK 0 07/11 6 4009 3995 19 KBG2 DONE BK 16 rs 1-. 6 13-3/8°CSG,729,L-80 BTC,I)=12.347' H 266V 5 5252 4995 48 KBG2 DAY BK 0 1$ l: 5 4- 4 6781 6014 47 KBG2 DOME BK 16 ': STATE OF ALASKA *ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate Q Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 207-129 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20551-02-00 7. Property Designation(Lease Number): ADL 0028313 8. Well Name and Number: PBU 14-18B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 11130 feet Plugs measured feet MAY9 2olu true vertical 8973 feet Junk measured feet Effective Depth: measured 11045 feet Packer measured 10446 feet D� � true vertical 8915 feet Packer true vertical 8504.63 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 31 -111 31-111 1530 520 Surface 2620 13-3/8"72#L-80 29-2648 29-2648 4930 2670 Intermediate 3481 9-5/8"47#L-80 27-3507 27-3507 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10700-10720 feet 10885-10905 feet 10928-10930 feet 10930-10943 feet 10943-10974 feet True vertical depth: 8678-8691 feet feet 8804-8817 feet 8833-8835 feet 8835-8844 feet 8844-8865 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 24-10565 24-8586 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): :SCANNED Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 16 404 97 1473 258 Subsequent to operation: 219 0 361 1233 228 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature A Phone +1 907 564 4424 Date 5/19/16 Form 10-404 Revised 5/2015 VTL 5/2 31IL Submit Original Only 5-72146 RBDMS (-`' MAY z 3 2016 • • m Q o 0 0 0 0 0 my I- O O O Cfl N- v U7 U7 p Up N Nt UD I- N- U y 0 0 0 0 0 0 M M I- N' M 0) IC) C)) a0 N N Ca s CO N- 00 O • a0 f� N. V CD V' O ti r` O CD tocoOU) N M 00 OD M F- 7- 0) N- U7 00 V M N N M UD N M M W- O O CO COLc) CO t!') N M O c- O V 0 M/� , W e Q rLo c- CD N- U') u0 Nr M N N M cp N coggr r .Q O a O O O O \ 00 00 O i J M J 2: 4t 04 Cl) V N V 4# N up U O o N N - N N M 0) O CD O▪ ON O NT Nr up C 00 CD M O up U) J N M W O C 0 W • U U 0 u_ c E Z Z a W W W m Q D H Z Z D 0 Cn Z J J • Packers and SSV's Attachment PBU 14-18B SW Name Type MD TVD Depscription 14-18B PACKER 3365.67 3365.62 7" Baker ZXP Top Packer 14-18B TBG PACKER 10445.82 8504.63 4-1/2" Baker S-3 Perm Packer 14-18B PACKER 10568.38 8588.31 5" Baker ZXP Top Packer • • iii / // 0 _1 a - 0 / 0 0z z z D D D E. w 0 0 0 / 0 LL ± ± / ® 2 2 2 2 / U)0 0 / - \ / f Co I / \ _i / 0 r / \ \ cv 0 / \ H I I h R_ CD \ < / \ / CD- c Ct d ± / / e ± p E ƒ E E N 0 » 2E % CD E CO g 2 E < / / 6 r E co 7 0 m % o Cr) q co / % E / / Z $ ?% / Co $ \ o c R c f / w / ! 0 6 0 6 0 & / f — m m o G O # o a 0 O E @7 \ / ± E u 3 ƒ \ ƒ / ƒ \ ± 0 0 3 E A _ I.1 \ E : / \ -- / / / cD / cD ƒ m < R < I < I -t CO * » E < U � ± ICt@OCR \ � � / 7 \ / $ � (0 � h / i ? ƒ m @ < 02 ± - $ ~ � � ± c20O 2 > 00 < \ NO QOQO0 \ / Z & Z O w m w@ a R L O U 4t CJ) 4t m R 0 ® / \ / ^ 2 2 2 0 2 0 2 51 \ L D Z x ® u 2 = U 2 G D G E ± E / Co 3 2 2 = 0 / / \ 0 / ƒ w 2au_ \ LU / \ § % § � $ \ / w0_ / 0 -JW000 0E0EOk / / L I I I I = O \ \ \ \ / / 00ZZD / / / � � $ : » t 2 0 = 0 2 0 9 2 = : o : : a » : : 2 F- H OC : 5 2 \ CO e (0 / \ TS CV d / 5. \ / \ 00 0 # # # < TREE= 4-1/16"CNV 411 1 -1 8B ` TREE=EAD= GRAY I SAFE iV NOTES:***4-1/2"CHROME TBG' ACTUATOR= BAKER C KB ELEV= 71' BF. ELEV= KOP= 3505' 2203' 4-,l2"HE5 X NP,D=3.813" Max Angle= 51"�5615' 1 1 Datum MD= 10981' 2574' —9-5/8"DV PKR Datum TVD= 8800'SS .� GAS UFT MtANDF213S ST MD TVD DEV TYPE VLV LATCH PORT DATE 20"CONDUCTOR,91.5#,H-40,D=19.124' — 110' 7 2849 2849 0 KBG2 DMY BK 0 07/11/08 6 4009 3995 19 KBG2 DOME BK 16 11/22/15 13-3/8"CSG,72#,L-80 BTC,D=12.347" H 2651' 5 5252 4995 48 KBG2 DMY BK 0 10/28/15 L, 4 6781 6014 47 KBG2 DOME BK 20 11/22/15 9-5/8"X 7'BKR G2 ZXP LW H 3353' J 3 8273 7011 48 KBG2 DMY BK 0 11/12/07 w/11.6'TIEBACK,D=6.30' 2 9430 7809 46 KBG2 DMY BK 0 03/23/10 1 10335 8428 45 KBG2 DMY BK 0 11/12/07 9-5/8"X 7"FLEX LOCK LNR HGR,D=6.33" —j 3371' MLLOUT Wt DOW(14-18B) 3506 -3522' I Minimum ID = 3.726" a@ 10661' 4.1/2" HEX XN NIPPLE 40' 9-5/8"VN-IFSTOCK(10/27/07) — 3502' 9-5/8"CSG,47#,L-80 BTC,0=8.681" H —3502' I 10414' —14-1/2"HES X NP,D=3.813" t_ 10445' —7"X 4-1/2"BKR S-3 Z PKR,D=3.875" I 10478' —14-112"HES X NP,D=3.813" 1 - 4-1l2"TBG,12.6#, 13CR-80 VAM TOP, .0152 bpf,D=3.958" H 10563' I 10551' H4-1/2"HES XN NP,ID=3.725" 10556' —7"X 5"BKR ZXP LTP I w/11.41'TEBACK,D=4.250" 10563' H4-1/2"WLEG,ID=3.958" 10574' —7"X 5"BKR FMC LNR FiGR D=4.420" 7'LNR,26#,L-80 BTC-M, .0383 bpf,ID=6.276` ---1 10697' 10580' —15"X 4-1/2"XO,D=3.958" PERFORATION SU4ARY V , M REF LOG:CCL ON 12/08/07 ANGLE AT TOP PERE 46"@ 10930' I Note:Refer to Production DB for historical pert data SIZE SPF MYTERVAL Opn/Sqz DATE 2-7/8" 6 10700-10720 S 04/06/12 I 2-7/8" 6 10700- 10720 0 04/27/16 2-7/8" 6 10885- 10905 0 04/27/16 2-7/8" 6 10928-10943 0 02/03/16 I 2-7/8" 6 10928-10943 0 04/27/16 2-7/8" 6 10930-10974 S 12/08/07 PBTt)1H 11045' ►+•♦ 0 i�ii •4-1/2"TBG,12.6#,L-80 VAM TOP,.0152 bpf,ID"3.958' H 11130' V e 1 i t I DATE REV BY' WPW'TTS DATE REV BY COMVENTS FT JJHJEBAY UNIT- 07/04/81 NT07/04/81 PKR 191 ORIGINAL COMPLETION 11/25/15 SW /JMC GLV C/O(11/22/15) WELL: 14-18B 05/27/92 D16 RWO 02/12/16 JCMJMD ADPERFS(02/03/16) FERMI No. 2071290 05/10/98 N4/3S CTD SDTRACK(14-18A) 05/02/16 CJS/JMD REFE2FS/ADPERF(04/27/16) API No: 50-029-20551-02 05/15/99 N4/3S CTD EXTENSION(14-18A) SEC 9,T1ON,R14E,1659'FNL 8 1784'FEL 11/14/07 N2E5 SIDETRACK(14-18B) 11/17/15 CJS/JMD CMT SOZ(11/14/15) BP Exploration(Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMIIIION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations Q Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate Q Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: e(1^-_`i7-5T.. Er 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 207-129 3. Address: P.O.Box 196612 Anchorage, Development .Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20551-02-00 7. Property Designation(Lease Number): ADL 0028313 8. Well Name and Number: PBU 14-18B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 11130 feet Plugs measured feet true vertical 8973 feet Junk �/,-�, 0 measured feet i,,,� R 3 2016 Effective Depth: measured 11045 feet Packer measured 10446 feet AO hh�� true vertical 8915 feet Packer true vertical 8504.63 feet Af llA , Casing: Length: Size: MD: TVD: Burst: Collapse:R Structural Conductor 80 20"94#H-40 31 -111 31 -111 1530 520 Surface 2620 13-3/8"72#L-80 29-2648 29-2648 4930 2670 Intermediate 3481 9-5/8"47#L-80 27-3507 27-3507 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10700-10720 feet 10928-10930 feet 10930-10943 feet 10943-10974 feet True vertical depth: 8678-8691 feet feet 8833-8835 feet 8835-8844 feet 8844-8865 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 24-10565 24-8586 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): y �`NE,y l'< r ' 10700'-10720',10930'-10974'. 4 {, Treatment descriptions including volumes used and final pressure: 71.6 Bbls 15.8 ppg LARC Cement,6 Bbls Methanol,146 Bbls Diesel,83.4 Bbls 60/40 Methanol/Water,146 Bbls Diesel,117 Fresh Water,63 Bbls 1%KCL w/SafeLube,63 Bbls PowerVis, 3000 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 461 1304 7513 1791 284 Subsequent to operation: 16 404 97 1473 258 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Pte'' Com— Phone +1 907 564 4424 Date 3/3/16 Form 10-404 Revised 5/2015 tr rr 41,0y�6 >v Submit Original Onl 3!i/./!t RBDMS MAR 0 4 2016 y • • Q,o00000 N � (O '— OO � N 'tI ) I O N ch U M M I,- OM COY) Ln O) CO N d' m (O I- co U) OD N- N O • V' 0 I,- N- CO tf) (0 O) L0 N CO CO CO CO ✓ O in▪ OD M N N M Ln M 00 d0f� O) MCID N co co r O r r T- (1)V MM 1 1 1 1 1 1 4-0 W co _ '— L0 r � rn � Ln• , � _a M N N cM Es N _ r W CL O O O 00 Wch C4t T- N, N N � 0) O) - - OT- (Ni CO N - U (NI 0;r O) 4 7 .ca crO O)O N U) NI- C OD CO V' CO N ti in J N CO Ln W cc Q C O 0 ' U W w V O u_ t CecLZ O Z Z U U) Z J J 1— • • Packers and SSV's Attachment PBU 14-18B SW Name Type MD TVD Depscription 14-18B PACKER 3365.67 3365.62 7" Baker ZXP Top Packer 14-18B TBG PACKER 10445.82 8504.63 4-1/2" Baker S-3 Perm Packer 14-18B PACKER 10568.38 8588.31 5" Baker ZXP Top Packer • • z 5, E N 0 0r p cca o - n m • U a) o 0 co m ,t O Q-O C Q U) • O O -Q C O .0 M a a) O >, C I _ .c � co 3 O •N N N a) ,� o c 1 to M p ca O `- Q 0 Q 0> O > o ) a) 0-12- ..... ,.- O Q 4 � N. O U 13 CO 2 C ' 7 0 ,M O 0 E o a) M co a) ca cp a, ra m 0 a) = = o � � � 0 as l � cn t c a N a) a) r a 13 0 •Q a) a s• 0 d r a) ° W a) 0 o U .c I u) N- d 0 o c aa)) o = s Q v rn m 7- o E > oa co a ° 0 t 0 ami y'3 E a) co Ha > -0 W * a1- Q0 a) co . p s • CD _ U) LO A- . • a) a) U �: _0 co •c N -0 o . 2 o C 3 c Q > I- g D m o a) c N a`) co co ?O m N � + a Q o ,� m � F- c)o awi 7 -0 aa)) rn o a) (X L° rn 0 Ii.) 5I c � o co F- U) 0 EM = E c oC W m - 'E �.*� a O u_ o •Q o N o ,•-=‘, J _o J m co d N cti '� c� C a) J 0 o) 0 45 O Ch 00° m cO cJ °) 3 a) f° 2p = g W o co a� ° ecu L c ao o c 0 m - as w n c '++ HJ cl- 3 � Q •N v � c � a0 � � 0 � o) N +' � � z L < wu) c0) 0 — p QO a) � mNY-COOceLL °'ao •c_ of m p- m c0 0 UM �c2 ,- u_ .cQoQ u') 3 aci , LO 0om0 •� 13 co •E a) o a) .6 >, a3 O AM N 1 In Nos o 15pN 0 m U) J4tCC000wU) Q a) M 0.o E > 00 0 a) CD 1-- co =M Q p> Z 0_ co Q u) Q o U O � 0W Q W O m 3 ac) ' ac) a >,•N r co O = m � cc) � Y w aim � 2 . a) J cA n m 0 � F- P ami Q U o c) N a) o 0_ o Dm Em al-om0li cu) `' mm c5N � WJQ0 a) E �c wv c v) a a) w cp J _Z N i • 0- . 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EEas coo 3 0 U) -c) * Fa- u a2 * F- co nHco., - 0 * CLLLI U) _i � a=. * 002 m rnU .S = 0 .a? 3 ? 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E m c ~ c 3 a) c N cEa 2 ,- a) 0 v S Z p 3 0 » w > - m ctrl a u a) rn O .o m E V a O -c-.)ca W 0 0 J (N 9 3 mH cu .EmcY a) o ° , U 3 mZ m ° � o � >-• C7iwo ai > oa) U • � cocoo � U a3a) aca U ._ co_ii 0 co - � � � JN > � it '? c Z c O � 4-2_ cLi rn c •coati. E > + E �n J ,_ Z .._as H cn Z 0 0 u_i Lu Y Y 0 J � > 0 .�c � � a'C rnE rn2 = OD a)= � O c °' = � � � ps � � � � � � � wp ,c5 I— -0—' 00 c m a) cam ° a� O � H � O -8 •••=...-- o off * EE 49 ° 3 51 51 � > UOUm c3 U CI= U o .° CCa : UOQ -o2w * 0 * I- Ecn * aacnv) a : F- Um 0 0 0 0 0 r T- .- r N- c0 0 0 0 0 0 0 cIS N N N N N N N N N CN N- r r .- r 0 • EN 0 in % / c w E▪ : �/ _ w w o 45u) 2 7q CI § WN in / /o °_) 7k '8 in q \ k 4, / ,- / k R 2 | � - -I • - & 0 $ $ 3 hcN * bE / 0) II f z z \ / 2 : q WwO C 2 u) 2 0 k � � 2 O $ / Ce / e z a) « o u_ LL E m &- x c= 2 � CL CL f 0- 0 0 \ 12ccb ƒ ƒ 0 I- -, 00 $ ® � 2 0 > w * x / ® _7 ■ k 0 f < D R i 2 0 z T_ - � 7 E co EN - 0 W w I- 0 o D � 0 \ $ NO _J ceko 0 t alE � � � wmm W 0 « o a- a)7 ° 2 2021 8 / ft / 0 : n * 0 0 ƒ ƒ k % / Ere \ � >, kA _I2 2w8E2 / 7k � � w E / R R / - < 2 x % CCI � , : & a) 13 2G 0_ 0 cia - 26 - x - w E ® 7 / 2G G ¥ ER _2 _b / / 2w / 03 � � / \ �_ / b � 0 � � � / a_ / fUk 7w N � m � ¥ . = I < e = O m � R k -I -IAEE _I - - - _1 _ w � � w w / ww / w & U _1 _1 = kQo °-j.c / JCI ƒ CTOE7) - RfhkL7 ktfk � uj � 0k : 2 2 IX O O . ; : � Ce Ce 0 LI 5 : 5 2 0 2 2 .- ƒ 0_ u_ 0 0 / / 2Ga $ % = a \ n2 @ _ - n n n ¥ moors o % q TREE = 41!16"CM/ • 1418B WELLHEAD= GRAY SAFETY NOTES:'"" " 4-1/2"CHROME TBG" " ACTUATOR= BAKER C KB.RiEV 71' BF.H-EV KOP= � 3505 Ma2203' 4-1/2-FEB X NP,D=3.813" I Mix Angle'._._.__.51 r_,5615' 1 H Datum IVO= 10981' �_ 2574' —19-518"DV PKR Datum TVD= 8800'SS ' GAS LIFT MANDRILS ST MO TVD DEV TYPE VLV LATCH PORT DATE 20"CONDUCTOR 91.5#,1+40,D=19.124" 110' 1111 ' 7 2849 2849 0 KBG2 DMY BK 0 07/11/08 6 4009 3995 19 KBG2 DOME BK 16 11/22/15 13-3/8"CSG,72#,1-80 BTC,0=12.347- —{ 2651' 5 5252 4995 48 KBG2 DMY BK 0 10/28/15 4 6781 6014 47 KBG2 DOME BK 20 11/22/15 9 5/8'X 7"BKR C-2 DIP LTP --I 3353' 3 8273 7011 48 KBG2 DMY BK 0 11/12/07 w!11.6'TEBACK D=6.30" 2 9430 7809 46 KBG2 DMY BK 0 03/23/10 1 10335 8428 45 KBG2 DMY BK 0 11/12107 9-518'X 7"FLEX LOCK LNR HGR,0=6.33" H 3371' Minimum ID= 3.726"@ 10561' "�t aur vur�oow(l4-lee) 3506'-3527 4-1/2" HEX XN NIPPLE 19-5/8'WI-PSTOCK(10/27/07) H 3,602' MENOW 10414' H4-1/2-I- XNP,0=3.813' I •iii, '•••••••4-- 10445' I-7'X 4-1/2"BKR S-3 9-5/8'USV(10/27/07) —i 3628' .�•••••�•� �� ►: •!���•�!� PKR,D=3.875" 41/2-TUBING STUB(10/04/07) H 6002' !C•:• ► ••• i I 10478' H41J2'HES XNP,D=3.813" J ►••4 441,41 I••�•• I 10551' H4-112"HES XN NP,13=3.725" ►•i 2 --tom „2._ 3 RECEIVED WA itBAKER PRINT DISTRIBUTION LIST MAY 2 8 2015 HUGHES AOGCC COMPANY BP Exploration Alaska,Inc. INTERMEDIATE FINAL Yes (mandatory) DATA LOGG WELL NAME 14-18B RUN NUMBER 1 R (mandatory) to/1�reo1g IA.K.BENDER FIELD Prudhoe Bay Unit BH SALESMAN Paul Canizares (mandatory) (mandatory) COUNTY North Slope BH DISTRICT Prudhoe Bay,AK (mandatory) (mandatory) STATE Alaska PAGE 1 OF 1 (mandatory) LOG DATE: May 3,2015 TODAYS DATE: 5/4/2015 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Paul Canizares (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY A B C D ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) L.I.S. FILM PERSON ATTENTION #OF PRINTS#OF COPIES#OF COPIES#OF COPIES#OF COPIES#OF COPIES 1 ConocoPhillips Alaska Inc. 1 1 I 1 1 Attn:Ricky Elgaricio A= 14-18_RPM_PNC3D_RAW_3MAY2015_BHI.meta ATO 3-344 14-18_RPM_CO_RAW_3MAY2015_BHI.meta 700 G Street Anchorage,AK 99510 B= *(Folder 1 on cd/dvd) 14-18_RPM_PNC3D_RAW_3MAY2 14-18_RPM_CO_RAW_3MAY2015_ 2 ExxonMobil,Alaska 1 1 I 1 1 I Attn:Lynda M.Vaskell and/or Leonardo Elias 3700 Centerpointe Dr.Suite 600 Anchorage,AK 99503 3 State of Alaska-AOGCC r 1 1 I 1 I 1 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 4 DNR-Division of Oil&Gas 0 1 0 I I I I I Attn:Sean Clifton 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 5 I I I SCANNED JUN 1 5 2015 TOTALS FOR THIS PAGE: 3 3 4 4 0 0 TOTALS FOR ALL PAGES: 3 3 4 4 0 0 • imec~e i'rt~~ecx Wei( F-ii~tQry Fiie Gayer i~~~e ?~ I-tVl' F^:: This page idcntifi~a fihose items that were not scanned dur~irty the initial prodt~rtian scanning phase. They are available in the original file, may be scanned during a special rescar~ activity or are viewable by direct inspection of the file. O~Q - ~ ~, Well History File Identifier Organizing (aone> RE AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: o.~.,d~ iiumiiuiiiuui DIG AL DATA Diskettes, No. ~' ^ Other, No/Type: ae,~,~~reaed iuuiuuiuiuu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: ~ Maria Date: ~ ,.~,~ ~ b 1 (~ ~ /s/ ~ (` Project Proofing () ~ II II II I I II I I III BY: Maria Date: ~ D /s/ Scanning Preparation ~o _ x 30 = + ~ =TOTAL PAGES (J (Count does not include cover sheet) BY: Maria Date: /s/ Production Scanning Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: _~,~YES NO BY: Maria Date: `~ I ~ Og' /s/ ~, Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: o~,,,.~~a«ea iiumiuiumiii 10/6!2005 Well History File Cover Page.doc 0 la RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 2 0 2012. REPORT OF SUNDRY WELL OPERATIONS AOGCC 1 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska) , Inc. DevelopmentJloratory ❑ - 207 -129 3. Address: p.0. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, Alaska 99519 -6612 50- 029 - 20551 -02 -00 7. Property Designation (Lease Number): _ 8. Well Name and Number: _ ADL- 028313 - PBU 14 -18B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 11130 feet Plugs measured NONE feet true vertical 8973 feet Junk measured NONE feet Effective Depth measured 11045 feet Packer measured SEE BELOW feet true vertical 8 914 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 30' -110' 30' -110' 1490 470 Surface 2622 13 -3/8" 72# L -80 29' - 2651' 29' - 2651' 4930 2670 Production 3474' 9 -5/8" 47 L -80 28' -3502' 28' -3502' 6870 4760 Liner 7356' 7" 26# L -80 3341'- 10697' 3341' -8676' 7240 5410 Liner 574' 4 -1/2" 12.6# 13Cr80 10556'- 11130' 8580' -8973' 8430 7500 Perforation depth Measured depth SEE ATTACHED feet True Vertical depth feet 4 -1/2" 12.6# 13Cr80 27'- 10563' 27' -8585' Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L - 80 10563 8585 7" BKR C -2 ZXP LTP 3353' 3353' Packers and SSSV (type, measured and true vertical depth) 4 -1/2" BKR S -3 PKR 10445' 8504' 5" BKR ZXP LTP 10556' 8580' 12. Stimulation or cement squeeze summary: Intervals treated (measured): !it„,AWNED APR : ZOlL Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 154 1844 4699 205 Subsequent to operation: 171 1710 4449 225 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ® - Service ❑ Stratigraphic ❑ Daily Report of Well Operations 16. Well Status after work: Oil - ® Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Printed Name Nita Summ-rh -ys Title Data Manager � Ye� _ - ' Phone 564 -4035 Date 04/19/2012 RE3DMS APR 2 0 201 ((-z ` z-- Form 10-404 Revised 11/2011 C am , ,j/, , ',2- Submit Original Only 14 -18B 207 -129 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 14 -18B 12/8/07 APF 10,930. 10,974. 8,834.7 8,865.43 14 -18B 4/6/12 APF 10,700. 10,720. 8,677.82 8,691.42 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE • MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 1 • • 14 -18B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 2/19 /2012 ** *WELL SHUT IN ON ARRIVAL * * *(ad -pert) RAN 20'x3 -3/8" DMY GUN, SAT DOWN @ 10,180' SLM. RDFN. ** *LEFT WELL SHUT IN TURNED WELL OVER TO PAD OPER * ** 2/20/2012 * * *CONT FROM TICKET 2 /19 /12 * * *(ad -perf) RIH W/ 20'x2 -7/8" DMY GUN, S.BAILER, S/D @ 10,946' SLM. NO REC RIH W/ 3.0" DD BAILER, S/D @ 10,946' SLM BAILER FULL OF FORMATION SAND. RIH W/ 3.5" CENT, 4 -1/2" BRUSH, 3.0" SCALE BUCKET, S/D @ 10,946' SLM. REC SAMPLE OF SCALE RIH W/ 10'x3 -3/8" DMY GUN, SAT DOWN @ 10,946' SLM, RDMO. ** *LEFT WELL SHUT IN TURNED WELL OVER TO DSO * ** 4/6/2012 ** *WELL FLOWING ON ARRIVAL * ** INITIAL T /I /O 250/1250/700 TIED INTO SPERRY CTN LOG DATED 10- NOV -07' USING GR AT 10700'. NOTICED SPERRY LOG WAS SEGMENTED AND SECTIONS DO NOT LINE UP WITH CONTINUOUS UP LOG ON WIRE. JEWELRY LOG RAN WITH PERFORATION RECORD DATED 8- DEC -07 IS TIED IN ON BOTTOM, BUT IS 2 FEET OFF AFTER OPEN HOLE LOG CHANGES RUN NUMBERS. ABLE TO CORRECT DEPTH TO MATCH REQUESTED TIE -IN LOG INTERVAL, SHOT 10700'- 10720' ON SPERRY CNT MWD LOG WITH 2.88" HSD 6SPF 60 DEGREES PHASED 2906 PJ OMEGA GUN. CONFIRMED ALL SHOTS FIRED, RETURN WELL TO PRODUCTION, HAND OVER WITH DSO PRIOR TO DEPARTURE. FINAL T /I /O = 250/1250/500. ** *JOB COMPLETED * ** FLUIDS PUMPED BBLS 5 DIESEL 5 TOTAL TREE= ' 4-1/16" cm • WEI4HEAD = GRAY ETY NOTES: "*4-112" CHROME TM*" ACTUATOR = BAKERt 1 4-1 8B wB.ELEv;- - ---ff, I BF. ELEV = KOP = 3505' 2203' 1-14-1/2" HES X NIP, ID = 3.813" 1 , Max Angle = 51 © 5615' Datum M) = Teigiff' — 2574' 9-5/8" DV PKR Ditain = - — Mew §§ GAS LIFT MANDRELS ST 1 1VD DEV TYPE VLV LATCH FORT DATE 20" CONDUCTOR 91.5#, H-40,10 = 19.124" 110' ilin ai kg) , 7 2849 2849 0 KBG2 DAY BK 0 07/11/08 6 4009 3995 19 10302 DOME BK 16 03/23/10 1 13-3 / 8 " CSG, 72#, 1-80 BTC, ID = 12.347" H 2861' 5 5252 4995 48 K802 DOME BK 16 03/23/10 4 6781 6014 47 1(902 SO BK 22 03123/10 9-5/8" X 7" BKR C-2 ZXP LW MEM P I I 3 8273 7011 48 KBG2 DMY BK 0 11/12107 w /11.6' TIEBACK, ID = 6.30" 2 9430 7809 46 KBG2 DMY BK 0 03/23/10 1 10335 8428 45 KBG2 DAY BK 0 11/12/07 19-5/8" X 7" FLEX LOCK LNR HGR, ID = 6.33" H 3371' NILLOUTMIDOW (14-18E4 3506' - 3522' Minimum ID = 3.726" @ 10661' kts, . ., , 4-1/2" HEX XN NIPPLE ----, ....—............ 10414' H4-1/2" HES X NP, 0) = 3.813" 1 19-518" WHIPSTOCK (10/27/07) H 3602' . 10445' 1— r X 4-1/2" BKR 5-3 k7,1 r I . . . . 19-5/8 F2SV (10/27/07) 1 3528' ••• • • • I * • • PKR, 0 = 3.875" &Vete' 0 :1".1 0; 4-1/2" TUBING STUB (10/04/07) 8002' .14,41■4 4 •410 ' 10478' H4-1/2" HES X NIP, 0 = 3.813" 1 'e n I 10551' —14-1/2" HES XN MP, ID = 3.725" I 0 0 I 1 10556' 1— 7" X 5" BKR ZXP LTP 19-5/8" CSG, 47#, L-80 BTC, ID = 8.681" H 9266' ■ • .:**: w /11.41' TIEBACK, ID = 4.250" . e ■ • : ii, 'A C I * 10583' 4-1/7' WLEG, ID = 3.958" 1 4 • M4 b , , e, 4 I t, 0 &At I , * PERFORATION SUIVMARY re** — *A A 10574' 1-7" X 5" BKR MC REF LOG: CCL ON 12/08/07 LNR HGR, ID = 4.420" ANGLE AT TOP FERF: 46* @ 10930' 10580' H5- X 4-1/2" X0, ID = 3.958" 1 Nbte: Refer to Production OB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE z 2-7/8" 6 10700 - 10720 0 04/06/12 Y 2-718" 6 10930 - 10974 0 12108/07 I <----' 3 14-1/2" TBG, 12,6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" H 10583' 1r LNR, 26#, 1-80 BTC-M, .0383 bpf, ID = 6.276" H 10697' PBTD 11045' I ■•••• **** ..4- i 1 • , ;Ir..* ■ 0 "'■ .7.0"ii, 14-1/2" TBG, 12,8#, L-80 VAM TOP, .0152 bpf, ID = 3.958" H 11130' DATE REV BY COMMENTS DATE REV BY CONVENTS PRUDDE BAY umr ... 07/04181 PKR 191 ORIGINAL COM PLETIO 04/02110 CJNISV GLV CIO (03/23/10) WELL: 14-188 05/27/92 016 MVO 04/10112 CRH1.0.40 ADERF (04/06/12) PERMT No: "2071290 05110/98 N4/36 CM SDTRACK (14-18A API I43: 50-029-20551-02 05115199 144/3S CTD EXTENSION (14-18A) SEC 9, T1ON, R14E,1659' FM. & 1784' FEL 11/14107 N2ES SIDETRACK (14-18B) 12/08/07 TEURIC INfl1AL PERFORATIONS „ BP Exploration (Alaska) • ~~ ~~ y ~. ~~ ~, t ~ ~a.~~~ ~ ~s MICROFILMED .6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 ' ""°~ ~ °' Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 07, 2009 '`~~~ ~l ~ I' y ~' ~ a ~ ~' bP F_~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 14 Dear Mr. Maunder, ~a --~a`~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-14 Date: 12/05/09 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 14-o1A 1931850 500292031701 Sealed Conductor NA NA 14-02C 2071150 500292031803 Sealed Conductor NA NA 74-03A 1961290 500292031901 Sealed Conductor NA NA 14-04A 1961640 500292032001 Sealed Conductor NA NA 14-05A 1920010 500292032701 Sealed Conductor NA NA t4-06A 2040360 500292032801 Sealed Conductor NA NA 14-07 1780660 500292032900 Sealed Conductor NA NA 14-08A 2022100 500292033001 Sealed Conductor NA NA 14-096 1820340 500292053402 Sealed Conductor NA NA 14-10 1801300 500292052800 Sealed Conductor NA NA 14-11A 2051260 500292052901 Sealed Conductor NA NA 14-12 1811090 500292063700 Sealed Conductor NA NA 14-13 1811010 500292062400 Sealed Conductor NA NA 14-14 1811020 500292062500 Sealed Conductor NA NA 14-15 1810840 500292061100 Sealed Conductor NA NA 14-16A 1971670 500292060801 Sealed Conductor NA NA 14-17A 2030010 500292056201 Sealed Conductor NA NA 14-188 2071290 500292055102 Sealed Conductor NA NA 14-i9 1810450 500292057800 Sealed Conductor NA NA 14-20 1810700 500292059800 Sealed Conductor NA NA 14-21A 2051070 500292075601 Sealed Conductor NA NA 14-22A 1921230 500292074701 Sealed Conductor NA NA 14-23A 2090200 500292075701 NA 4 NA 25.50 10/20/2009 14-24 1830910 500292097000 NA 0.6 NA 3.40 10/20/2009 14-25 1831020 500292098100 NA 2.1 NA 15.30 11/16/2009 14-26 1811100 500292063200 Sealed Conductor NA NA 14-27 1831700 500292104600 NA 3 NA 17.00 10/25/2009 14-28 1820120 500292070800 Sealed Conductor NA NA 14-29 1811680 500292068000 Sealed Conductor NA NA 14-30 2050940 500292067901 Sealed Conductor NA NA 14-31 1831110 500292098900 Sealed Conductor NA NA 14-32 1831220 500292099900 NA 0.6 NA 3.40 10!19/2009 14-33 1831250 500292100200 Sealed Conductor NA NA 14-34 1831330 500292101000 NA 7.3 NA 47.60 10/20/2009 74-35 1831420 500292101800 Sealed Conductor NA NA t4-36 1831630 500292103900 NA 0.7 NA 3.40 10/20/2009 14-37 1880490 500292181000 NA 1.3 NA 5.10 10/20/2009 14-38 1881030 500292186200 NA 0.8 NA 3.40 10/24/2009 14-4oA 2011350 500292187501 Sealed Conductor NA NA 14-41 1920960 500292229000 NA 0.8 NA 6.80 10/18/2009 14-43 1921080 500292229600 NA 1.4 NA 10.20 10/23/2009 14-44A 2021930 500292257301 NA 10 NA 88.40 11/24/2009 ~~ ~ - -. .. ~_ • Date: 08-27-2009 Transmittal Number:93091 BPXA WELL DATA TRANSMITTAL p~ ~'~~ 1•~M~,M " .. ~ -i-~ : +. ~~j'f;;~~~1 Enclosed are the materials listed below. ~°~- .~~t:~ If vou have anv auestions. nlease contact 3oe Lastufka at (907)564-4091 Delivery Contents Bottom SW Name Date Com an Run To De th De th Descri tion BAKER CARBON/OXYGEN LOG 12-09 09-06-2008 HUGHES 1 8840 9079 GAMMA RAY RESERVOIR PERFORMANCE BAKER MONITO CARBON OXYGEN 12-09 03-03-2009 HUGHES 1 8926 8952 ANA~YSIS BAKER RESERVOIR PERFORMANCE 12-09 09-07-2008 HUGHES 1 8840 9079 MONITOR RESERVOIR PERFORMANCE BAKER MONITOR GASVIEW 12-09 02-09-2009 HUGHES 1 8926 8952 SATURATION ANALYSIS BAKER INTERPRETATION OF RPM 12-09 09-07-2008 HUGHES DATA CD-ROM - RPS/GSA PRM RPM/COA CARBON/OXYGEN BAKER LOG/GR META, LAS, PDF 12-09 08-19-2009 HUGHES FORMAT BAKER RESERVOIR PERFORMANCE 11-17A 08-17-2008 HUGHES 1 9850 10370 MONITOR RESERVOIR PERFORMANCE BAKER MONITOR GASVIEW 11-17A 01-30-2009 HUGHES 1 10107 10362 SATURATION ANALYSIS BAKER INTERPRETATION OF RPM 11-17A 08-17-2008 HUGHES DATA CD-ROM - RPM/GSA PRM BAKER META, LAS, AND PDF 11-17A 08-19-2009 HUGHES FORMAT BAKER RESERVOIR PERFORMANCE 14-18B 08-24-2008 HUGHES 1 i0580 11043 MONITOR RESERVOIR PERFORMANCE BAKER MONITOR GASVIEW 14-18B 01-29-2009 HUGHES 1 10700 11018 SATURATION ANALYSIS BAKER INTERPRETATION OF RPM 14-186 08-24-2008 HUGHES DATA CD-ROM - RPM/GSA PRM BAKER META, LAS, AND PDF 14-188 08-19-2009 HUGHES FORMAT BAKER RESERVOIR PERFORMANCE M-04 08-25-2008 HUGHES 1 11100 11370 MONITOR M-04 01-29-2009 BAKER 1 11212 11374 RESERVOIR PERFORMANCE . Petrotechnical Data Center LR2-1 900 E. Benson Slvd. PO Box 19661~ Anchorage, AK 99~ 19-6612 r-, ~ • . i BP Alaska Interpretation of RPM Data Well: '14-18B Field: Prudhoe Bay Report Status: Final Report Authors: Yonghwee Kim and Rafay Ansari Reviewed: David Chace Logged Date: 24th Au ust 2008 Report Date: 3 st July 2009 ~ ... u ~ ~~~ ~ ~ ~~~_. ~._ >- f` ~~~.~~~~~ ~~~~~ . _~k~:y ~_~~ ~z n {~ ,,~ ~~.~ r. um ~ . :. ~,,~ ~.. ;~.~ ,Y ». ~: ~~• ,~ .,. . T~, , ~~~.. ~~~.. ~ a ~ ~*~ ~ ~'~ ~ ' u~ ~ ~ ~ ~,~., .:~,~'.w_~. ~~.,. ~, , ~~~ ~ ~ Y'f~~,,~ .a:~ ,..~? ; -~: ~,k~r.t.._ . s ~~~~w~~:: , ~: ~s~ t.: » ~~' ~ k ~^s~=: ~ x~~ ~~~' ~ ~ ~ ~ ~ ~ ~~~°.°~,~ ,, . . x.~ . . .. ~.. ~' : ~i .' f~sW~.4, = . . ,.,.rt. ~~ . ~ . http://www.bake rhu g h es.com/bake ratlas • ~0~ - ( ~~1 ri~~ BAKER NU6HES Baker Atlas ~ ~ ~ ~ ~ IN MAKING INTERPRETATIONS OF LOGS OUR EMPLOYEES WILL GIVE THE CUSTOMER THE BENEFIT OF THEIR BEST JUDGEMENT, BUT SINCE ALL INTERPRETATIONS ARE OPINIONS BASED ON INFERENCES FROM ELECTRICAL OR OTHER MEASUREMENTS WE CANNOT AND DO NOT GUARANTEE THE ACCURACY OR THE CORRECTNESS OF ANY INTERPRETATION. WE SHALL NOT BE LIABLE OR RESPONSIBLE FOR ANY LOSS, COST, DAMAGES, OR EXPENSES WHATSOEVER INCURRED OR SUSTAINED BY THE CUSTOMER RESULTING FROM ANY INTERPRETATION MADE BY ANY OF OUR EMPLOYEES. ~ II • BP Alaska - Prudhoe - Well 14-186- RPM Saturation Analysis Page i CONTENTS 1 INTRODUCTION 1 1.1 Objectives 1 1.2 Results 1 1.3 Data Set 1 1.4 Sequence of Events 1 2 ANALYSIS AND INTERPRETA710N 3 2.1 RPM Overview 3 2.2 GasView Analysis Methodology 3 3 DATA DISCUSSION 6 3.1 GasView Analysis and Discussion 6 RPM REFERENCES 10 LIST OF TABLES AND FIGURES Table 2.1 Parameters Used for Input to GasView Modelling Figure 2.1 GasView Response Chart Figure 2.2 Example of GasView Results Figure 3.1 Processed GasView Results of Sag Interval Figure 3.2 Processed GasView Results of Ivishak Interval Baker Hughes Inc. ~ BP Alaska - Prudhoe - WeII 14-186- RPM Saturation Analysis Page 1 1 INTRODUCTION (Source: BP Logging Program) 14-18B is a gas lifted producer in the GDWFI area. This well is currently on-line producing ~1200 BOPD; the SI time required to obtain the log will result in a small production impact. • Current Status: Producer • Last test: 7/26/08: 1197 BFPD, 1009 BOPD, 14680 GOR, 16% WC • Max Deviation: 48° @ 9864' MD • Min. (D:3.725" through 4-1/2" XN nipple C«~ 10551' MD • Last TD tag: 12/5/07: Drift w/ 3.625" centralizer; SD at 11042' MD • Last Downhole Ops: 7/23/08: C/O GLVs • Latest H2S Level: NA • Tie-in Log: LWD OH Logs, GRMM_MWD -11//9/2007 • 1.1 Objectives This RPM surveillance will provide a quantitative estimate of gas saturation, oil saturation and define the GOC, OWC in the Ivishak and Sag production intervals. Through comparison with the historical log data of the well, we will have a better understanding of the capacity and limitation of this improved pulsed neutron tool. 1.2 Results • The RPM data was of good quality and repeatability, and an analytical result of good confidence has been achieved. • By utilizing GasView methodology, a gas saturation curve (Sg) has been calculated while two water saturation curves (Sw and Sw_HT) provided by BP have been displayed for comparison. • In ivishak interval, analysis shows that gas is mostly present above and below the perforated zone (10,940-10,972 ft). Since this well was under water injection while logging, the in-situ gas may have been replaced by water in the near wellbore area. 1.3 Data Set This well was logged on 24th Aug 2008. The RPM data has been recorded through two different borehole/completion configurations. 1) 8.5inch borehole and 7inch casing (10,600-10,697 ft) ~ 2) 6.125inch borehole and 4.5inch casing (10,698-11,040 ft) Three passes were recorded at 10 ft/min. The GasView passes were recorded with a source output of 800,000 cps (counts per second). 1.4 Sequence of Events • Log was correlated to HBW/ALD-CTN-DGR-EWR-ROP (reference log) DATE i ith Nov 2007. • Log started at 13:00 on 24th Aug 2008 and finished at 19:00 on the same day. • The top logged interval was 10,580 ft and the bottom logged interval was 11,043 ft. • 13:30 205 BBLS AWAY 3 BPM 1300 • 13:45 240 BBLS AWAY 3 BPM 1500 • 13:51 225 BBLS AWAY 0.5 BPM 550 • 14:00 LOGGING DOWN • 14:05 262 BBLS AWAY 0.5 BPM 400 • 14:30 ON BOTTOM ~ Baker Hughes Inc. ~ BP Alaska - Prudhoe - Well 14-186- RPM Saturation Analysis Page 2 • 14:41 280 BBLS AWAY 0.5 BPM 450 LOGGING UP • 15:13 295 BBLS AWAY 0.5 BPM 500 • 15:27 300 BBLS AWAY 0.5 BPM 500 • 15:47 310 BBLS AWAY 0.5 BPM 600 • 16:08 320 BBLS AWAY 0.5 BPM 550 • 16:32 330 BBLS AWAY 0.5 BPM 500 • 16:51 LOGGING UP • 17:34 360 BBLS AWAY 0.5 BPM 500 • 17:34 SWITCH TO CRUDE • 17:45 5BBLS CRUDE AWAY 0.4 BPM 400 • 17:57 STATIONARY READING'S • POOH ~a 18:05 ~ ~ Baker Hughes Inc. ~ BP Alaska - Prudhoe - Well 14-186- RPM Saturation Analysis Page 3 2 ANALYSIS AND INTERPRETATION 2.1 RPM Overview The Baker Atlas RPM is a pulsed neutron instrument capable of acquiring data in several modes. PNC (Pulsed Neutron Capture) data is used to evaluate the formation saturation in known high salinity formations and to identify gas, while C/O (Carbon/Oxygen) is used to evaluate the formation saturation in low- or unknown-salinity formations. Further to the water saturation calculation modes the tool can also be operated in AFL (Annular Flow Log) mode to quantify water velocity in both continuous passes and stations. Also, borehole holdup can be calculated utilizing the PNHI (Pulsed Neutron Holdup Indicator) mode; this is particularly useful in horizontal or highly deviated wells where the accuracy of conventional production logging instruments is greatly reduced. More recently, the modified RPM-C tool has allowed us to carry out gas saturation analysis ( GasViews"' ) analysis from three detector PNC data. ~ 2.2 GasView Analysis Methodology Baker Atlas has enhanced the Reservoir Performance Monitor (RPM) service by introducing three features: improved instrumentation, a new characterization, and advanced interpretive techniques. The GasView service utilizes the improved resolution of the RPM-C tool, a new gas response characterisation, and a new petrophysical algorithm to deliver a better method for identifying gas and measuring gas saturation. The three detector RPM-C instrument allows gas detection ratios to be taken over longer spacing than conventional instruments. These new measurements are substantially more sensitive to the change in neutron-gamma distribution that indicates a change from liquid to gas-filled porosity. This improved sensitivity allows the instrument to resolve the presence of gas where conventional instruments cannot, and it provides better resolution in the gas saturation calculation. Characterization of tool response allows more accurate quantification of saturation. A global tool response characterization database has been constructed for standard open hole and cased hole completions. This includes varying combinations of mineralogy, fluid density, and gas pressure/density. The following table states the parameters which have been used in the modelling of the predicted curve response for Prudhoe well 14-18B. Table 2.1 Parameters used in GasView modellin of well 14-18B ~ Parameter Value Borehole Size 6.125 inch Casin Size 4.5 inch Borehole Fluid Water Matrix T e Sandstone Gas Densit 0.26 /cc Oil Densit 0.8 /cc Water Densit 1.00 /cc A GasView job planner is available to design optimal logging programs. The following chart shows the expected response of the RIN13 curve (this chart is an example only and not relevant to this specific case of well 14-186). Baker Hughes Inc. I'~~ • BP Alaska - Prudhoe - Well 14-186- RPM Satur tion Analysis Page 4 JJ? Del~a Sgme v: Fama~ian Pwwity ~ DeAa Si~na vs Famaum WNa SaGnAy I Ges Coeffipent Fie IrpN Gaa Chart I Ratio: Pox Detector degree d It ~~ ~ QAKiR -~ gas chaih ~ 1- 3 ~ I" ~ M~K1~'S Baka~ At19s Bwdwb Iluid darciliy: Fnmatian fM~id densily FmnMion yas density 0.10 Q69 0.69 Sa"a.E~1O^ PriM/Export CoeFfwants RIN I • wet gas Porosiy 0.40 Cxicd Figure 2.1 GasView Response Chart The Dynamic Gas Envelope (DGE) interpretation explicitly accounts for variations in porosity and shale volume in the saturation result. While these effects must be removed from the saturation solution, they are included in the visual DGE representation for greater insight into the processing. See example GasView results below. For results of well 14-186, see section 3.1. ~~ Baker Hughes Inc. O.W 0.05 0.10 0.15 0.20 0.25 0.30 0.35 ~ BP Alaska- Prudhoe - Well 14-186- RPM Satu ation Analysis Page 5 EXAMPLE I• I• I • Baker Hughes Inc. Figure 2.2 Example of GasView Results • BP Alaska - Prudhoe - Well 14-18B- RPM Saturation Analysis Page 6 3 DATA DISCUSSION 3.1 GasView Analysis and Discussion A GasView analysis has been carried out using the three passes logged on the 24th Aug 2008. All passes were recorded at 10 ft/min with a source output of 800,000 cps. All the passes have been shifted on depth using open hole GR provided by BP. All data looks to be of good quality and repeatability. Curves from three recorded passes have been averaged to create one final data set to be used for analysis. A result of good confidence has been achieved. The pre-modelling software for GasView uses a number of lab test calibration points, these lab tests are carried out using pure quartzite for a sandstone environment and tombstone marble for limestone environment. It is very unlikely that this type of matrix would be present down hole therefore a single value calibration is made to the RIN13 curve to correct for material differences in the matrix. This parameter should be used to normalize the RIN13 curve in a zone of known saturation. ~ In the process of the GasView analysis, RIN13 normalization value was used as -8 and the shale calibration value was 90. Also, note that the pick up depth is 11,018 ft based on the BKS change (BKS- short spaced background countrate). The perforation interval (10,940-10,972 ft) was used for wet zone normalization since the well was under injection while logging. No single thick shale zone was present in the provided volumetrics. Therefore, shale calibration was performed on zones with relatively higher shale value. Moreover, GasView model is based on sandstone lithology; however, dolomite is present in Sag interval. The RIN13 matrix point is higher for dolomite compared to sandstone. Therefore, the presence of dolomite has been corrected by adjusting the RIN13 curve. The results of this analysis can be observed in Figures 3.1 and 3.2. The presented results are analyzed with formation gas density of 0.26 g/cc and volumetrics provided by BP. The results show the Dynamic Gas Envelope (DGE explained in section 2.2) overlaid with the normalized RIN13 curve. The position of the RIN13 curve between the Gas line (red) and the Liquid line (blue) of the DGE determines the gas saturation. The figure shows how the measured curve moves between the liquid and gas lines and the resulting gas saturation curve (Sg). The perforated interval appears to be filled with injected liquid. Above and below this interval (10,940- 10,972ft), the porosity is dominantly filled with gas and the calculated Sg agrees reasonably well with the two water saturation curves provided by BP. ~ I ~ Baker Hughes Inc. ~ I r BP Alaska - Prudhoe - Well 14-186- RPM Satu~ation Analysis "~ Page 7 FLUID WEf-G45 ETNELOPE FLUID GAS ~ G4S INdIG4TI0N ~SAND NORA1 C6hIG . C B~' ~AIAMA RAY (RPM-C GL as Saturation ;~S IJNE ENVE~OFE i-it:• ti7 _ - ~,~5 ; __ - DOLO V5H TQTAL POROSfTY G41AM4 RAY (O~H; ~i Swe: BP wET uNE ENVELAPE EFFEC"fIVE PdROSITY EfF~1114PC(dC81Y N =,,,:a_I-?: . hJORkt4LJZE6 i-~, ~ - o l~~'$i IJ ~ - - r f - ~ - Figure 3.1 Processed GasView Results of Sag Interval ~~ Baker Hughes Inc. BP Alaska - Prudhoe - Well 14-186- RPM Saturation Analysis Page 9 Baker Hughes Inc. Figure 3.2 Processed GasView Results of Ivishak Interval i ~ BP Alaska - Prudhoe - Well 14-186- RPM Sat tion Analysis Page 10 RPM References Chace, D.M., Trcka, D.E., and Dawe, B.A., "Application and interpretation of continuous oxygen activation logs for measuring complex water flow profiles in injection wells," SPE 69th Annual Technical Conference and Exhibition, New Orleans, Louisiana, Paper 28412, 1994. Trcka, D., van den Berg, F., Manan, W.A., Peeters, M., and Mickael, M., "Measuring three-phase holdups in horizontal wellbores using pulsed neutron instruments," SPE Annual Technical Conference and Exhibition, Denver, Colorado, Paper 36561, 1996. Gilchrist, W.A. Jr., Prati, E., Pemeper, R., Mickael, M.W., and Trcka, D., "Introduction of a New Through- Tubing Multifunction Pulsed Neutron Instrument," SPE paper 56803, Annual SPE Technical Conference and Exhibition, Houston, Texas, Oct. 1999. Trcka, D.E., and Chace, D.M., "Improved method for measuring annular water flow in injection wells using continuous oxygen activation logging," SPE 68th Annual Technical Conference and Exhibition, Houston, Texas, Paper 26450, 1993. Chace, D.M., Trcka, D.E., Wang, J., Bousche, O., van der Spek, A., al Nasser, H., "A new production logging service for horizontal wells," SPWLA 39th Annual Symposium, Keystone, CO, 1998, Paper H. Mickael, M.W., Trcka, D.E., Pemper, R., "Dynamic Mutti-Parameter Interpretation of Dual-Detector Carbon/Oxygen Measurements", SPE Annual Technical Conference and Exhibition, Houston, Texas, Oct. 1999. Chace, D., Trcka, D., Georgi, D., Wang, J., Bousche, O., van der Spek, A., al Nasser, H., "New instrumentation and methods for production logging in multiphase horizontal wells," SPE MEOS, Bahrain, Paper 53220, 1999. David Chace, Jianrong Wang, Roman Mirzwinski, Jorge Maxit, and Darryl Trcka, "Applications of a New Multiple Sensor Production Logging System for Horizontal and Highly-Deviated Multiphase Producers", SPE paper 63141, Annual SPE Technical Conference and Exhibition, Dallas, Texas, October, 2000. Trcka, D., Oliver, D., Mickael M., Chace, D., Georgi, D., and Wang, J., "Reservoir performance monitoring in the new millennium", Proceedings of the Tunisian Oil Conference, April, 2000. Riley, S., Guivarch, B., Chace, D.M., Trcka, D.E., Clark, J., "Production logging in horizontal gravel- packed highly viscous oil producers in the North Sea", SPE Annual Technical Conference and Exhibition held in Denver, Colorado, Oct. 2003. Baker Hughes Inc. DATA SUBMITTAL COMPLIANCE REPORT 12/3/2008 Permit to Drill 2071290 Well Name/No. PRUDHOE BAY UNIT 14-18B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20551-02-00 MD 11130 TVD 8973 Completion Date 12/8/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surve Yes `~ DATA INFORMATI ON Types Electric or Other Logs Run: USIST, DIR, GR, RES, PWD, MWD, ABI, Az Dens, NEU, Stratasteer, (data taken from Logs Portion of Master Well Data Maint Well Log Informat ion: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments g See Notes 5 Col 1 40 4020 Case 11/19/2007 Isolation Scannerw/PDC, IBCS-C, USIT-D, GPIT, EDTC, CAL-Y 26-Oct-2007 D Asc Directional Survey 28 11130 Open 1/16/2008 R Directional Survey 28 11130 Open 1/16/2008 pt LIS Verification 3242 11051 Open 1/31/2008 LIS Veri, GR, RPM, FET, RPD, RPX, RPS, ROP, NCNT, RHOB, FCNT, NPHI, DRHO C Lis 15863vlnduction/Resistivity 3242 11051 Open 1/31/2008 LIS Veri, GR, RPM, FET, RPD, RPX, RPS, ROP, NCNT, RHOB, FCNT, ~ NPHI, DRHO (.Cog Pressure Blu 1 9950 11018 Case 1/22/2008 SNPS, Pres, Temp, GR, CCL 8-Dec-2007 g Gradiometer 2 Blu 10530 11075 Case 9/16/2008 Mem Gradio, Pres, Temp 24-Aug-2008 D C Pds 16895 radiometer 10530 11075 Case 9/16/2008 Mem Gradio, Pres, Temp 24-Aug-2008 g Induction/Resistivity 25 Col 3506 11130 Open 11/3/2008 MD DGR, ROP, EWR, II ALD, CTN 10-Nov-2008 ! Log Induction/Resistivity 25 Col 3506 11130 Open 11/3/2008 TVD DGR, ROP, EWR, ALD, CTN 10-Nov-2008 ~'~ C , // 17129GJsee Notes 0 0 Open 11/3/2008 PDS, EMF and CGM of ', EWR logs Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 12/3/2008 Permit to Drill 2071290 Well Name/No. PRUDHOE BAY UNIT 14-18B Operator BP EXPLORATION (ALASKA) INC MD 11130 TVD 8973 Completion Date 12/8/2007 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL INFORMATION Well Cored? Y ~N Chips Received? Y / N Analysis Y / N Received? Comments: Compliance Reviewed By: Daily History Received? (~Y / N Formation Tops `~/ N Date: API No. 50-029-20551-02-00 UIC N • • 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: 14-18B October 30, 2008 AK-MW-5042392 14-18B: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20551-02 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20551-02 Digital Log Images: 1 CD Rom 50-029-20551-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Date: Signed: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Bryan Burinda Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 907-273-3536 - 3 09/16/08 • ~~~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wall .Inh Ik ~ n.. N0.4881 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 14-188 11978479 MEM GRADIOMANOMETER LOG _I 08/24/08 1 04-28 11968951 LDL (REVISED) ~ = 06/29/08 1 1 R-12 12066544 MEM FLUID PROPERTIES LOG j j~p 08/20/08 1 1 PSI-05 12103673 MEM DENSITY LOG 08/23/08 1 1 05-35 11962620 USIT f .- (a 08/26/08 1 1 B-36 12017516 USIT ~ ~ 09/03/08 1 1 V-207 12057639 USIT D - 08/11/08 1 1 Z-19A 40013908 OH MWD/LWD EDIT - - / 09/10/06 3 1 12-28A 11962607 RST - U 07/01/08 1 1 B-12A 11998993 RST ~ 03/05/08 1 1 V-207 12057639 CH EDIT (USIT) 08/11/08 1 of OACC wnv~~nau. r n..... BP Exploration (Alaska) Inc. ___ . r Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ..........,.... v.,.~uw vwc a.vr t cNa.n ~ v: I tp ~ n, ;i Alaska Data & Consulting Services 2525 Gambell Street, to 400 Anchorage, AK 950 - 38 ATTN: Beth Received by: ~~ ~:J(I ,, i3 OPERABLE: 14-18B (PTD #1290) Tubing Integrity Restored ~ Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, July 19, 2008 6:59 PM ~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Winslow, Jack L.; Bommarito, Olivia O; GPB, Gas Lift Engr; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 14-18B (PTD #2071290) Tubing Integrity Restored AI I, Well 14-188 {PTD #2071290} passed a TIFL on 07/19/08. The passing test confirms that tubing integrity has been restored. The well has been reclassified as Operable and may be put on production after slickline sets gas lift valves. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, July 08, 2008 7:23 PM To: GPB, FS3 DS Ops Lead; GPB, F53 OTL; GPB, Area Mgr Central (GCl/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Bommarito, Olivia 0; GPB, Gas Lift Engr Subject: UNDER EVALUATION: 14-186 (PTD #2071290) for Sustained casing pressure due to TxIA Comm Hi all, Well 14-18B (PTD #2071290) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to SSV/2290/10 psi on 06/29/08. Due to the constraint of not being able to bleed pressure down to the production system due to the shut-down, the diagnostic work took more days to complete. On 07/08/08, a TIFL failed confirming TxIA communication. The well has been reclassified as Under Evaluation and placed on a 28-day clock. Operations may allow the IA pressure to continue to build pressure. The plan forward for the well is as follows: 1. DHD: TIFL -FAILED 2. Well Integrity Engineer: Evaluate for gas lift valve change out 3. slickline: Change out gas lift valves 4. DHD: re-TIFL A TIO plot and wellbore schematic have been included for reference. Please call with any questions. 8/29/2008 OPERABLE: 14-18B (PTD #1290) Tubing Integrity Restored ~ Page 2 of 2 Thank you, Anna ~u6e, ~. E. Well Integrity Coordinator GPB Wells Group Phone: {907) 659-5102 Pager: {907} 659-5100 x1154 8/29/2008 FW: UNDER EVALUATION14-18B (PTD #2071290) for Sustained~ing pressure du... Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, July 08, 2008 8:02 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) ~~~ Cc: NSU, ADW Well Integrity Engineer Subject: FW: UNDER EVALUATION: 14-18B (PTD #2071290) for Sustained casing pressure due to TxIA Comm Attachments: 14-18 TIO PIot.BMP; 14-18B.pdf I apologize !missed you on the original distribution list. Anna From: NSU, ADW Well Integrity Engineer Sent: Tuesday, July O8, 2008 7:23 PM To: GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GCl/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Bommarito, Olivia O; GPB, Gas Lift Engr Subject: UNDER EVALUATION: 14-186 (PTD #2071290) for Sustained casing pressure due to TxIA Comm Hi all, Well 14-18B (PTD #2071290) has been found to have sustained casin~ressure on the IA. The wellhead pressures were tubing/IA/OA equal to SSV/2290/10 psi on 06/29/08. Due to the constraint of not being able to bleed pressure down to the reduction s stem due to the shut-down, the diagnostic work took more days o comp a e. n 07/08/08, a TIFL failed confirming TxIA communication. The well has been reclassified as Under Evaluation and placed on a 28-day clock. Operations may allow the IA pressure to continue to build pressure. The plan forward for the well is as follows: 1. DHD: TIFL -FAILED 2. Well Integrity Engineer: Evaluate for gas lift valve change ou# 3. Slickline: Change out gas lift valves 4. DHD: re-TIFL A TIO plot and wellbore schematic have been included for reference. «14-18 TIO PIot.BMP» «14-186.pdf» Please call with any questions. Thank you, Anna ~u6e, ~? 2. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 8/29/2008 PBU 14-18B PTD 207-129 4 ,000 ................................................ ~~ =T8'1~t7 P ~bY.............. 3,000 2,000 i.~. hAAASP 1,000 0 418/2008 4/23/2008 5/8/2008 5123/2008 6812008 ~ Tbg f- IA -~ OA 11812008 7/23/2008 OOA f OOOA u i TREE= 4-1/16" CMJ WELLHEAD = GRAY ACTUATOR - BAKER C KB ELEV = 71' BF. ELEV..- KOP = 3505' Max Angfe = 51~ @ 5695' -- Datum MD = 10981' ', Datum ND = 8800' SS ~ 14-18 B 20" CONDUCTOR 91.5#, H-40, ID = 19.124" i-1 110' 13-3f8" CSG, 72#, L-80 BTC, ID = 12.347" 2651' 9-518" X 7" BKR C-2 ZXP LTP 3353' w /11.6' TIEBACK. ID = 6.30" 9-5/8" X 7" FLIX LOCK LNR HGR, ID = 6.33" 3371' Minimum ID = 3.725" @ 10551' 4-112" HEX XN NIPPLE 9-5/8" WHIPSTOCK {10/27f07) 3502' 9-5(8" EZSV (10127f07) 3528' 4-1f2" TUBING STUB {10!04!07) 6002' 9-5/8" CSG, 47#, L-80 BTC, 1D = 8.681" (~ 9266' ', PERFORATION SUMMARY ', REF LOG CCL ON 12/08/07 ', ANGLE AT TOP PERF: 46° @ 10930' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2-7i8" 6 10930 - 10974 O 12f0$(07 4-1i2" TBG, 12.6#, 13CR-80 VAM TOP, A152 bpf, ID = 3.958" ~-~ 10563' 7" LNR, 26#, L-80 BTGM, .0383 bpf, ID = 6.276" 1 fl697' PBTD 11045' 1/2" TBG, 12.6#, L-80 VAM TOP, .0152 bpf, ID = 3.958" 11130' FETY NOTES:4-112" CHI20METBG 220-~4-1/2" HES X NIP, ID = 3.813" 2574' 9-5f8" DV PKR GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 7 2849 2849 0 K8G2 DOME BK 16 12105/07 6 4009 3994 19 KBG2 SO BK 20 12105(07 5 5252 4995 48 KBG2 DMY BK 0 11;12/07 4 6781 6014 47 KBG2 DMY BK 0 11112/07 3 8273 7011 48 KBG2 DMY BK 0 11!12!07 2 9430 7809 46 KBG2 DMY BK 0 11f12f07 1 10335 8428 45 KBG2 DMY BK 0 11/12/07 DATE REV BY COMMENTS DATE REV BY COMMENTS 07!04/81. PKR 191 ORIGINAL COMPLETION 12i08i07 TELIPJC INfTIAL PERFORATIONS 05!27192 D1& RWO 07101(08 KNClPJC DRLG DRAF~CORRECTIONS 05/10!98 N4/3S CTD SDTRACK (14-18A} 05/15/99 N413S CTD EXTENSION (14-18A} 11114!07 N2ES SIDETRACK (14-186} 12/05/07 TEL JPJC GLV C/O MILLOUT WINDOW {14-18B) 3506' - 3522' 1fl414' ~4-1/2" HES X NIP, ID = 3.813" 10445' 7" X 4-1f2" BKR S-3 PKR, ID = 3.875" 10478' 4-112" HES X NIP, ID = 3.813" 10551 ` 4-1 /2" HES XN NiP, ID = 3.725" 10556' 7" X 5" BKR ZXP LTP w /11.41' TIEBACK, ID = 4.250" 10563' -~4-112" WLEG: ID = 3.958" 10574' 7" X 5" BKR HMC LNR HGR, ID = 4.420" 10~ 5" X 4-112" XQ, IQ = 3.958" PRUDHOE BAY UN{T WELL: 14-186 PERM(f No:2071290 API No: 50-029-20551-02 SEC 9, T10N, R14E,1659' FNL & 1784` FEL BP Exploration {Alaska) WELL LOG TRANSMITTAL To: State of Alaska January 29, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~h Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 14-18b AK-MW-5042392 1 LDWG formatted CD rom with verification listing. API#: 50-029-205 51-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMTTTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 ,~ ~: ~, ~; .~. Date: ~~. ~ ~~ t ~'~~ Signed: :,., ." . . ~o-~-- ~a~ ~ ~ s~ ~3 01/11/08 ~~i~t~~Ll~a~~~~ NO. 4547 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt. Wall .Inh f! Loa Description Date BL Color CD Z-06 11594523 STATIC TEMP LOG 09109107 1 14-186 11975743 SBHP SURVEY 12/08/07 1 14-02C 11767144 SBHP LOG - 11/02/07 1 H-24A 11963073 MEM CBL - ( 11130107 1 C-35A 11624351 CEMENT BOND & GRAVEL PACK ^a 11/03/07 1 MPH-19 11982423 USIT (p ~ 12/10/07 1 1 E-03A 11628773 MEM PROD PROFILE _ 05109107 1 E-11 B 11434760 OH LDWG EDIT (DSI) - G 10/29106 1 1 G-06A 11209587 MCNL - (~ L~ 02/25/06 1 1 D-07B 11162822 MCNL - f ~ 12/04/05 1 1 G-10C 11209607 MCNL Q(p - 'ol 06115/06 1 1 G-09B 11649989 MCNL ~ ~-) j (~ j ~`~~ 09/11/07 1 1 K-08B 11745243 MCNL 9 "-L ~ 11/06/07 1 1 V-07 11978425 COMPOSITE CBL 12106107 1 V-07 11978425 USIT 12!06107 1 L2-33 11970801 RST j ' V ~ 07/07/07 1 1 03-14A 40013340 OH MWD/LWD EDIT ~ I 04/23/06 2 1 ~~ PLEASE ACKNOWLEDGE RECEIPT 6Y SIGNING AND RETURNING ONE DOPY EAGM TU: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. " Anchorage, Alaska 99508 ii Date Delivered: ' ~ ~„ ~? ~ ~,1' `~ "~ ~~~!i Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~% ~ /~ Received by: ~ STATE OF ALASKA ~ ~ ALASKA~IL AND GAS CONSERVATION COMIG~i `SSION~E~'~'~ WELL COMPLETION OR RECOMPLETION REPORT AND LO~N 0 $ 200$ 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZS.~os zoaoczs.i~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One I s . "' ®D ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Ab 12/8/2007 %~ 12. Permit to Drill Number 207-129 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded a 10/2'2007 13. API Number 50-029-20551-02-00 ' 4a. Location of Welf (Governmental Section): Surface: ' ' 7. Date T.D. Reached 11/09/2007 ~ 14. Well Name and Number: PBU 14-186 FNL, 1784 1659 FEL, SEC. 09, T10N, R14E, UM Top of Productive Horizon: 1042' FSL, 459' FEL, SEC. 05, T10N, R14E, UM 8. KB (ft above MSL): 70.46 Ground (ft MSL): 15. Field /Pool(s): Prudhoe Bay Field / Prud~ioe Bay Total Depth: 1124' FSL, 656' FEL, SEC. 05, T10N, R14E, UM 9. Plug Back Depth (MD+TVD) 11045' 8914' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27}: Surface: x- 674699 y- 5938669 Zone- ASP4 10. Total Depth (MD+TVD) 11130' 8973' 16. Property Designation: . ADL 028313 TPI: x- 670676 y- 5941279 Zone- ASP4 Total Depth: x- 670477 y- 5941356 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ~ USIT, DIR, GR, RES, PWD, MWD, ABI, Az Dens, NEU, Stratasteer, Gyro ~.vDosJ~ ,350eSMD ~.~Sj>6 TYQ 22. CASING, LINER AND CEMENTING RECORD CASING .SETTING DEPTH Mp SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP .BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surfac 80' Surfa 80' 32" 300 sx Permafrost 13-3/8" 72# L-80 Surface 2651' Surface 2651' 17-1/2" 2615 sx Fonda 400 sx AS II 9-5/8" 47# L-80 Surface Surface 3506' 12-1/4" 500 sx Class 'G' 7" 26# L-80 41' 10 97' 1' 8676' 8-1/2" 437 sx I s'G' 169 sx Cla s'G' 4-1/2" 12.6# 13Cr 10556' 11130' 8580' 8973' 6-1/ " 102 sx Ciass'G' 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter, 6 SPF ~ 4-1/2", 12.6#, 13Cr80 10563' 10445' MD TVD MD TVD 10930' - 10974' 8835' - 8865' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protected with 151 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Date of Test: 12-13-2007 HOUrS Tested: $ PRODUCTION FOR TEST PERIOD OIL-BBL: 835 GAS-MCF: 785 WATER-BBL: 123 CHOKE SIZE: 84 GAS-OIL RATIO: 940 Flow Tubing Press. 228 Casing PreSS: 1860 CALCULATED 24-HOUR RATE.• OIL-BBL: 2505 GAS-MCF: 2355 WATER-BBL: 370 OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A aired? ^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.~50,Q71. ~ !~ ,, ;• C?sate j None ~~-> ~rt!~~ t 20~~ ~ s~ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN KERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste ~ ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Ugnu 4 4468' 4415' Ugnu 3 4683' 4593' None Ugnu 1 .5560' S19T West Sak 2 6375' 5734' West Sak 1 6820' 6041' Colville Mudstone 3 7126' 6248' Colville Mudstone 2 7903' 6764' Colville Mudstone 1 8735' 7317' Top of HRZ 9375' 7770' Base of HRZ 9604' 7929' Top of Sag River 10696' 8675' Top of Shublik 10722' 8693' Zone 4B / 46P 10837' 8771' Zone 46 / 45P 10927' 8833' Zone 4B / 44P 10966' 8860' Zone 4B / 43P 11039' 8911' Formation at Total Depth (Name): Zone 4B / 43P 11039' 8911' 30. List of Attachments: Summary of Daily Drilling Reports, Well History summary, Well Schematic Diagram, Surveys, teak-Off Test Summa 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra tewman ~ Title DriNing Technologist Date '~ '~~~ PBU 14-186 207-129 Prepared By NameMumber. Sondra Stewman, 564-4750 Well Number Drilling Engineer: Jim Nigh, 564-5220 P rmit No. / A royal No. INSTRUCTIONS GeNeRA~: 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. ireM 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. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 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. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.07E Form 10-407 Revised 02/2007 Submit Original Only TRi< = Uri,--. ~~ GEN ~ilJELLriFJ1©- GRAY -- ~^,C7UATQR= -- :,XF1SGfJ K6. F1FV = lOr1&' (3F ELCJ _ 4t yn' KOP = 35fj0' l~sax Ang;e = 51 ~ Sd1 `; ' C?atu~nMD= _ 10981" D=~IumTVD-~ 8800 SSI 4-1/2" 13CR-80 VAM Top TBG Top of 4-1/Z° TF3G Gut GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 2849 2849 0 KBG2 DOME BK 16 12/05/07 6 4009 3994 19 KBG2 SO BK 20 12/05/07 5 5252 4995 48 KBG2 DMY BK 0 11/12/07 4 6781 6014 47 KBG2 DMY BK 0 11/12/07 3 8273 7011 48 KBG2 DMY BK 0 11/12/07 2 9430 7809 46 KBG2 DMY BK 0 11/12/07 1 10335 8428 46 KBG2 DMY BK 0 11/12/07 10,414' 10 445' HES 4-1/2" X Nipple, ID=3.813" 7" x 4-1/2" BKR S-3 PKR 10 478' - 10 551' - HES 4-1/2" X Nipple, ID=3.813" HES 4-1/2" XN Nipple, ID=3.725" 10 555' - Han er/Liner To Packer 10,563' 4-1/2" WLEG 4.5" 12.6# L-80 Vam to Solid liner 11,130' 9,266` 9-5/8", 47#, L-80, ID=8.861" PERFORATION SUMMARY REF LOG: CCL ON 12108107 ANGLE AT TOP PERF: 46` @ 10930' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-71'8" 6 10930 - 10974 O 12;08!07 DATE REV BY CO'v'NUIENTS DATE REV SY CflMCv1ENT5 1991 f3RIGIrtAL £Ot~1PLECIC~Af Odl13;98 R]G SIDETRACK _ 05115199 CTD HOR1Z SIDETRACK 11/14/07 N2ES SIDt=TRACK 12i051Q7 TELIPJC GLV GO 1'~rC}8r07 TELIPSC fNITtALPERFORATt{~NS PRUDHCE 6AY UNR` WELL: 14-183 PERMIT No .'1 '~~: Ah'I No: SO-0~9-2QSS1-C BP Exploration (Alaska) 3,506' KOP 3506 9-5/8" Top of Window 3,528' 9-5/8" EZSV ~14-18B ~ BP EXPLORATION Page 1 of 15 Operations Summary Report Legal Well Name: 14-18 Common Well Name: 14-18 Spud Date: 4/8/1981 Event Name: REENTER+COMPLETE Start: 10/23/2007 End: 11/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/23/2007 04:00 - 11:00 7.00 MOB P PRE Prep shop for move. Unplug and rig down buildings. Move cuttings tank and welding shop. Disconnect jack and pull pits away. PJSM. Jack up sub. Pull malts and move sub off well. Line up sub on well 14-18. Lay herculite and spot sub over well. PJSM. Spot pits and hook up interconnect. Berm sub and pits. Install cuttings tank, mud lab, camp, shop and MWD shack. 11:00 - 13:30 2.50 RIGU P PRE Install pump-in flange on OA. Rig up circulating lines from #2 kill to OA. Take on seawater in pits. Rig up secondary annulus valve on IA. Rig up to test 9-5/8" x 13-3/8" annulus. IA and OA at 0 psi. Rig accept at 1100 hours. 13:30 - 14:30 1.00 WHSUR P DECOMP PJSM. Test 9-5/8" x 13-3/8" annulus to 2000 psi for 30 minutes. Test OK. 14:30 - 15:30 1.00 WHSUR P DECOMP PJSM. Rig up DSM lubricator. Test to 500 psi. Test OK. Pull BPV and rig down DSM. 15:30 - 17:00 1.50 WHSUR P DECOMP PJSM. Rig up to circulate out diesel. Test mud lines to 3000 psi. 17:00 - 19:30 2.50 WHSUR P DECOMP PJSM. Circulate diesel out of tubing at 145 gpm with 310 psi. Swap hoses and circulate down tubing at 155 gpm with 240 psi. Blow down lines and rig down. 19:30 - 22:30 3.00 WHSUR P DECOMP PJSM. Rig up DSM lubricator and test to 500 psi. Test OK. Set BPV and install dart to convert to TWC. Test from below to 1000 psi. Test OK. Attempt to test from above. Flange leaking on tree. Tighten up flange. Still leaking. Rig down. 22:30 - 00:00 1.50 WHSUR P DECOMP PJSM. Nipple down tree and adaptor flange. ~! 10/24/2007 00:00 - 01:00 1.00 WHSUR P DECOMP PJSM. Function lock down screws on tubing spool. Check hanger neck threads, 18-1/2 turns by hand. Strap RKB's. 01:00 - 04:00 3.00 BOPSU P DECOMP PJSM. Nipple up BOP stack. Install mouse hole. 04:00 - 06:00 2.00 BOPSU N RREP DECOMP Remove top drive torque tube guide rail. Bolts worn. No new bolts for new rails. Reinstall old rail and bolts. Torque and safety wire bolts. 06:00 - 16:00 10.00 BOPSU P DECOMP PJSM. Make up 4-1/2" test joint. Fill stack and test BOPE. Unable to get low pressure tests. Trouble shoot and isolate valves. Pull test joint and test BPV/Dart against blind rams. Drain stack and change out dart. Resume testing. Test BOPE to 250 psi low, 3500 psi high and annular to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by Chuck Scheve with AOGCC. Test witnessed by WSL Dick Maskell and Toolpusher Charlie Henley. Rig down test equipment and blow down. 16:00 -19:00 3.00 DHB P DECOMP PJSM. Rig up DSM lubricator and extension. Close top rams on lubricator extension. Test to 500 psi. Bleed to 0 psi. Pull dart and BPV. R/D lubricator. 19:00 - 19:30 0.50 PULL P DECOMP PJSM. Clear derrick of frost and ice. Inspect derrick. 19:30 - 21:00 1.50 FISH P DECOMP PJSM. Make up spear assembly. Spear tubing. Back out lock down screws, (BOLDS). Pull tubing free with 180k. Pull to floor with string weight of 90k. Lay down spear assembly and hanger. ! 21:00 - 22:00 1.00 PULL P DECOMP PJSM. Rig up casing tools and control line spooler. 22:00 - 00:00 2.00 PULL P DECOMP PJSM. Pull 4-1/2" tubing, laying down to 4825'. Recovered 1SS bands and 13 clamps. 10/25/2007 00:00 - 05:00 5.00 PULL P DECOMP PJSM. Pull 4-1/2" tubing and control line to SVLN. Rig down Prinied: 12/19/2007 2:43:36 PM • BP EXPLORATION Page 2 of 15 Operations Summary Report Legal Well Name: 14-18 Common Well Name: 14-18 Spud Date: 4/8/1981 Event Name: REENTER+COMPLETE Start: 10/23/2007 End: 11/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2007 Rig Name: NABORS 2ES Rig Number: Date. (From - To ~ Hours I Task ~ Code I NPT I Phase ~ Description of Operations 10/25/2007 00:00 - 05:00 5.00 PULL P DECOMP spooling unit. Continue to pull 4-1/2" tubing. Recovered 148 full joints, 1 cut joint at 18.50', 2 GLM, 1 SVLN, 2 SS bands and 28 control line clamps. 05:00 - 06:00 1.00 PULL P DECOMP Clear and clean floor. Prepare for testing BOPE. 06:00 - 10:30 4.50 BOPSU P DECOMP PJSM. Make up 5" test joint. Install test plug and test rams, lower mud cross and top drive valves. Test to 250 psi low, 3500 psi high and Hydril to 250 psi low, 2500 psi high as per AOGCC. Test witness waived by Chuck Scheve with AOGCC. Test witnessed by WSL Dick Maskell and Toolpusher Charlie Henley. Unable to get a good test on the manual IBOP. 10:30 - 11:30 1.00 BOPSU P DECOMP PJSM. Change out manual top drive TIW valve and adjust grabber. 11:30 - 13:30 2.00 BOPSU P DECOMP Make up floor valve to test joint. Continue to test BOPE as per AOGCC. Rig down and blow down lines. Install wear ring. 13:30 - 14:00 0.50 CLEAN P DECOMP Clear and clean floor. 14:00 - 14:30 0.50 CLEAN P DECOMP PJSM. Pick BHA up beaver slide. 14:30 - 15:00 0.50 CLEAN N RREP DECOMP Columbia installing skate indicator lights. 15:00 - 16:30 1.50 CLEAN P DECOMP PJSM. Make up 9-5/8" scraper BHA to 559'. 16:30 - 20:30 4.00 CLEAN P DECOMP PJSM. Pick up 5" DP and RIH to 4250'. Pull one stand and rack back. 20:30 - 21:30 1.00 CLEAN P DECOMP Circulate hi-vis sweep surface to surface at 575 gpm with 750 psi. Pump dry job. Install rubbers. Mud weight in and out 8.5 ppg. Up and down weight 110k. 21:30 - 22:30 1.00 CLEAN P DECOMP PJSM. POOH to 559'. i 22:30 - 23:30 1.00 CLEAN P DECOMP PJSM. Stand back HWDP. Lay down bit, scraper, bit sub and float sub. Clear floor. 23:30 - 00:00 0.50 EVAL P DECOMP PJSM. Pick E-line logging tools up beaver slide. 10/26/2007 00:00 - 01:30 1.50 EVAL P DECOMP PJSM. Rig up E-line unit. 01:30 - 06:30 5.00 EVAL P DECOMP Run GR/CCL/USIT log up from 4000' in corrosion and cement modes. 06:30 - 09:00 2.50 DHB P DECOMP Re-head line for bridge plug. (Town reviewing USIT data). 09:00 - 10:00 1.00 DHB P DECOMP RIH with CIBP on E line. Attempt to set - no success. 10:00 - 12:30 2.50 DHB N DFAL DECOMP POH with tools. Found bad connection in GR tool. Change GR and firing head. Re-run CIBP. 12:30 - 14:30 2.00 DHB P DECOMP Log on depth and set CIBP with top at 3519' ELMD (5' above casing coupling). POH and RD SWS. 14:30 - 15:30 1.00 DHB P DECOMP PJSM. Test CIBP and 9-5/8" casing to 3500 psi for 30 minutes. Test OK. 15:30 - 17:00 1.50 BOPSU P DECOMP PJSM. Lay down mouse hole. Pull wear ring. Nipple down BOP stack. 17:00 - 19:00 2.00 WHSUR P DECOMP PJSM. Nipple down tubing spool and remove from cellar. Bring in new tubing spool. Make up running tool and pull 9-5/8" packoff. 19:00 - 22:00 3.00 WHSUR P DECOMP Install new packoff and tubing spool. Set BOP stack down on spool. Torque flange and test void to 5000 psi for 30 minutes. Test OK. 22:00 - 23:00 1.00 BOPSU P DECOMP PJSM. NU BOP stack. Install riser and mouse hole. 23:00 - 00:00 1.00 BOPSU P DECOMP PJSM. Install test plug and test flanges to 250 psi low, 3500 psi high as per AOGCC. Pull test plug. 10/27/2007 00:00 - 01:00 1.00 WHSUR P DECOMP PJSM. Blow down kill line. Attempt to install wear ring. Unable to jay into ring. Running tool hanging up on inside of wear ring. Grind out inside of wear ring running profile. 01:00 - 02:00 1.00 STWHIP P WEXIT PJSM. Bring 9-5/8" whipstock assembly up beaver slide while Pnntetl: 72/79/2007 2:43:36 PM ~~ < ~~ BP EXPLORATION Page 3 of 15 ..Opera#ions Summary Report Legal Well Name: 14-18 Common Well Name: 14-18 Spud Date: 4/8/1981 ,r Event Name: REENTER+COMPLETE Start: 10/23/2007 End: 11/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code -NPT Phase Description of Operations 10/27/2007 01:00 - 02:00 1.00 STWHIP P WEXIT getting new wear ring delivered. 02:00 - 02:30 0.50 STWHIP P WEXIT Install new wear ring. RILDS. Break out running tool and lay down. 02:30 - 07:30 5.00 STWHIP P WEXIT PJSM. Pick up and make up 9-5/8" whipstock BHA. Scribe -~ whipstock slide face. Adjust UBHO sub for allignment with slide. PU/MU HWDP, bumper sub, drill collars, HWDP and RIH to 913'. 07:30 - 10:00 2.50 STWHIP P WEXIT PJSM. Install rubber and air slips. RIH to 3467'. Fill pipe at 200 gpm with 140 psi. Remove air slips. Install blower hose. Up weight 125k, down 130k. Break out top drive. Blow down. 10:00 - 11:30 1.50 STWHIP P WEXIT PJSM. Pick Gyro tools up beaver slide. Hang sheaves. MU tools. 11:30 - 14:00 2.50 STWHIP P WEXIT RIH with Gyro to UBHO sub. Work pipe and orient to 224 degrees. Shoot survey. POOH with Gyro. Re-run for confirmation shot. POOH. Lay down Gyro tools. Bring Geo-Pilot skid up to rig floor and spot. ^ h 14:00 - 14:30 0.50 STWHIP P WEXIT Make up last DP stand. RIH and tag EZSV at 3528'. Stand F back one stand and PU single. RIH and set whipstock anchor with 20k down. Pick up and confirm set. Shear slide lug with ,r`~ 45k down. Pick up. 14:30 - 15:00 0.50 STWHIP P WEXIT Pump 40 bbl spacer and displace well to 9.5 ppg milling fluid. Pump at 600 gpm with 1000 psi. 15:00 - 00:00 9.00 STWHIP P WEXIT Begin milling operations. Top of window at 3506'. Bottom of window at 3522'. Mill ahead to 3531' MD. Pump at 440 gpm with 620 psi. Rotate at 70 to 100 rpm with 1 to 4k torque. WOB 2-5k. Up wei ht 125k, down 130k. 10/28/2007 00:00 - 01:30 1.50 STWHIP P WEXIT Mill ahead to 3555' MD. Pump at 440 gpm with 610 psi. otate at 70 to 100 rpm with 1-2k torque off bottom, 2-3k torque on bottom. WOB 2-5k. Up weight 125k, down 130k. Work through window several times. Pull up shut down and run through `~ ~ window with no problems. Circulate hole clean. Mud weight in and out 9.5 ppg. 01:30 - 02:00 0.50 STWHIP P WEXIT PJSM. Perform FIT to 11.77 ppg EMW with 420 psi at surface. Bleed off, open rams and blow down lines. Lay down single. Monitor well for 10 minutes -static. 02:00 - 02:30 0.50 STWHIP P WEXIT Pump dry job at 250 gpm with 325 psi. Bleed off and blow down. Remove blower hose. Install rubbers and air slips. 02:30 - 04:00 1.50 STWHIP P WEXIT PJSM. POOH to 913'. Remove air slips. 04:00 - 05:00 1.00 STWHIP P WEXIT PJSM. Rack back HWDP. Lay down 9-5/8" whipstock assembly. Upper mill in gauge. 05:00 - 06:00 1.00 STWHIP P WEXIT Rig up BOP stack flushing tool. Flush stack, flow line and possum belly. Clear and clean floor. Prepare to PU 8-1/2" drilling assembly. Recovered a total of 250 Ibs of metal from hole. 06:00 - 10:00 4.00 STWHIP P WEXIT PJSM. Pick up remaining 8-1/2" BHA. PU motor, MU bit and BHA to UBHO sub. Scribe and orient sub. Verify gyro will seat with head. 10:00 - 11:30 1.50 STWHIP P WEXIT Plug in and upload MWD. Make up to top drive. Surface test MWD at 450 gpm with 740 psi. Test OK. 11:30 - 15:30 4.00 STWHIP P WEXIT PJSM. RIH picking up 5" DP to 3474'. 15:30 - 17:30 2.00 DRILL P INT1 PJSM. Cut and slip 96' of drilling line. Inspect brakes and traction motor brushes. Lube Elmago Splines. Investigate and Printed: 12/19/2007 2:43:36 PM BP EXPLORATION Page 4 of 15 Operations Summary Report Legal Well Name: 14-18 Common Well Name: 14-18 Spud Date: 4/8/1981 Event Name: REENTER+COMPLETE Start: 10/23/2007 End: 11/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2007 Rig Name: NABORS 2ES Rig Number: Date (From - To 1 Hours I Task I Code I NPT I ..Phase I Description of Operations 10/28/2007 15:30 - 17:30 2.00 DRILL P INT1 measure a bad hose under the draworks. 17:30 - 18:00 0.50 DRILL P INT1 Service top drive. Install blower hose. 18:00 - 20:00 2.00 DRILL P INT1 PJSM. Rig up Gyro. RIH and orient motor to 224 degrees. POOH with Gyro. Hang back wire line. 20:00 - 00:00 4.00 DRILL P INT1 Fill pipe. Up and down weight 120k. Drift window with no problems. Wash from 3528' to 3555'. Time drill ahead to 3560' at 2 fph. Pump at 525 gpm with 1435 psi. Kick off with 10k WOB. Slide to 3569'. Mud weight in and out 9.5 ppg. 10/29/2007 00:00 - 03:00 3.00 DRILL P INT1 PJSM, Directional drill ahead to 3592'. Pump at 525 gpm with 1440 psi off bottom, 1475 on bottom. Up weight 125k, down 120k. Weight in and out 9.5 ppg. SPR's at 0100 hours/3592'. Pump #1 30/180, 45/250. Pump #2 30/180, 45/240. 03:00 - 05:30 2.50 DRILL P INT1 Directional drill ahead to 3664' MD. Pump at 525 gpm with 1400 psi off bottom, 1500 psi on bottom. WOB 5-15k. Up weight 125k, down 120k. Mud weight in and out 9.5 ppg. 05:30 - 06:30 1.00 DRILL P INT1 RIH with Gyro. Take single shot survey for orientation. 06:30 - 00:00 17.50 DRILL P INT1 Continue to drill ahead to 4041' MD. Pump at 525 gpm with 1530 psi off bottom, 1720 psi on bottom. WOB 15-30k. Torque 1-2k off bottom, 2-4k on bottom at 80 rpm. Down weight 120k, up weight 118k, RT 120k. Mud weight in and out 9.5 ppg. SPR's at 3992'. Pump #1 30/190, 45/250. Pump #2 30/190, 45/260. AST 3.99, ART .52. Continue to drill ahead to 4755' MD, 4650' TVD. Up weight 140k, down 127k, RT 137k. WOB 10-20k. Torque 3-4k off bottom, 4-5k on bottom at 80 rpm. Pump at 525 gpm with 1500 psi off bottom, 1700 psi on bottom, ECD 10.35. SPR's both pumps at 1930 hours/4514', 30/200, 45/260. Mud weight in and out 9.5. Minor pack off on connections at 4375' to 4514'. AST 3.48, ART 4.32. '..,10/30/2007 00:00 - 11:00 11.00 DRILL P INT1 Directional drill ahead to 5554' MD, 5195' TVD. Pump at 525 to 575 gpm with 1600 to 1800 psi off bottom, 1800 to 2100 psi on ~ bottom. WOB 10-30k. Torque 3-4k off bottom, 4-6k on bottom at 80 rpm. Up weight 150k, down 125k, RT 140k. Mud weight in and out 9.5 ppg. ECD 10.36. SPR's at 5367'. Pump #1 30/230, 45/290. Pump #2 30/230, 45/300. AST - 1.42, ART - 6.51. 11:00 - 12:00 1.00 DRILL P INT1 Circulate weighted sweep surface to surface at 480 gpm with j 1310 psi. SPR's at 5554'/1200 hours, both pumps, 30/240, ~ 45/300. Mud weight in and out 9.5+ ppg. 12:00 - 15:00 3.00 DRILL P INT1 POOH to 832'. Up weight 160k. Max pull 190k at 5345'. No problems in open hole or at window while POOH. 15:00 - 19:00 4.00 DRILL P INT1 PJSM. Stand back HWDP and flex drill collars. Lay down CCV. Flush MWD tools and download. Break bit. Lay down DM, MWD, TM, float sub and motor. Clear and clean floor. ', 19:00 - 20:00 1.00 DRILL P INT1 PJSM. Service draworks and top drive. 20:00 - 21:00 1.00 DRILL N RREP INT1 Repair bad o-ring on rig HPU system return, filter housing. 21:00 - 00:00 3.00 DRILL P INT1 PJSM. PU Geo-Pilot. MU bit, MWD, TM, DM HOC and collars. Upload data to MWD. Make up float sub, stabilizer, flex drill collars, ball catcher/CCV and 1 stand HWDP. Flow test and function Geo-Pilot at 500 gpm with 650 psi. 10/31/2007 00:00 - 01:00 1.00 DRILL P INT1 PJSM. Continue to RIH with BHA to 832'. 01:00 - 01:30 0.50 DRILL P INT1 Surface test MWD at 500 gpm with 790 psi. Send commands to Geo-Pilot with confirmation. Break out top drive and blow Printed: 12/19/2007 2:43:36 PM c: BP EXPLORATION Page 5 of 15 Operations Summary Report Legal Well Name: 14-18 Common Well Name: 14-18 Spud Date: 4/8/1981 Event Name: REENTER+COMPLETE Start: 10/23/2007 End: 11/14/2007 (Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/31/2007 01:00 - 01:30 0.50 DRILL P INT1 down. 01:30 - 03:00 1.50 DRILL P INT1 PJSM. Pick up 5" DP to 3289'. Make up top drive. Circulate at 500 gpm with 1070 psi. Check MWD. Test OK. Break out top drive. 03:00 - 08:30 5.50 DRILL P INT1 PU single, MU top drive. Set up for MAD pass. Circulate at 600 gpm with 1340 psi. MAD pass from 3300' to 3500' at 87 fph. MWD not getting data. Lower pump rate to 500 gpm with 1000 psi. Finish MAD pass. 08:30 - 09:30 1.00 DRILL P INT1 PJSM. Continue to PU 5" DP. Heading into open hole up and down weight 120k. At 4640' take 20k down. Wipe clean. 09:30 - 10:00 0.50 DRILL P INT1 Make up top drive and circulate at 580 gpm with 1570 psi. Pump open hole volume. Increase pump rate to 600 gpm with 1625 psi. Pump up MWD survey. Break out top drive. 10:00 - 11:00 1.00 DRILL P INT1 Continue RIH to 5003'. Make up top drive. Wash and ream through tight hole at 600 gpm with 1700 psi and 40 rpm. Break out top drive. PU remainging singles of 5" DP to 5366'. Pick up stands and wash to bottom at 5554'. 11:00 - 12:00 1.00 DRILL P INT1 Circulate sweep surface to surface at 640 gpm with 1900 psi. Up weight 152k, down 130k, RT 140k. 12:00 - 00:00 12.00 DRILL P INT1 Directional drill ahead to 6614' MD, 5896' TVD. Torque 8-9k off bottom, 9-12k on bottom at 120 rpm. WOB 20-30k. Pump at 625 gpm with 1900 psi off bottom, 1950 psi on bottom. ART - 9.02. Mud weight in and out 9.7 ppg. Up weight 175k, down 130k, RT 150k. SPR's at 1130 hours/6592'. Pump #1 30/220, 45/270. Pump #2 30/230, 45/280. 11/1/2007 00:00 - 01:30 1.50 DRILL P INT1 PJSM. Directional drill ahead to 6646' MD, 5918' TVD. Pump at 625 gpm with 1920 psi off bottom, 1980 psi on bottom. WOB 20-30k. Torque 7-10k off bottom, 10-15k on bottom at 120 rpm. String stalling at higher torque. Pull off bottom to investigate Geo-Pilot failure. Take survey, attempt to communicate with Geo-Pilot with no success. Reciprocate and rotate while trouble shooting. Cut pump rate to 500 gpm. 01:30 - 02:00 0.50 DRILL N DFAL INT1 Circulate sweep surface to surface at 500 gpm with 1320 psi until clean. Calculated ECD 10.2, actual ECD 10.29.Up weight 175k, down 130k. Break out top drive. 02:00 - 03:30 1.50 DRILL N DFAL INT1 POOH to 3506' into window. Hole appears in good shape. No problems. 03:30 - 04:00 0.50 DRILL N DFAL INT1 Make up top drive. Pump dry job. Remove blower hose. Install air slips. Blow down top drive and Geo-Skid. 04:00 - 05:00 1.00 DRILL N DFAL INT1 Continue to POOH to BHA at 832'. 05:00 - 08:00 3.00 DRILL N DFAL INT1 PJSM. Rack back HWDP. Lay down circ sub. Rack back flex collars and BHA. Download MWD. Continue to LD BHA to Geo-Pilot. LD bit. 08:00 - 09:00 1.00 DRILL N DFAL INT1 Clear and clean floor. Lay down DM and PU new DM. 09:00 - 11:00 2.00 DRILL N DFAL INT1 PJSM. Pick up motor, break and adjust bend to 1.22 degrees. MU bit and DM, scribe. Make up BHA to stabilizer. Upload MWD. Continue making up BHA to 927'. Surface test at 500 gpm with 340 psi - OK. 11:00 - 14:30 3.50 DRILL N DFAL INT1 PJSM. RIH to TOW at 3506'. Fill pipe. Install blower hose. Pass through window with 115k down. No problems. RIH to 6496'. 14:30 - 15:00 0.50 DRILL N DFAL INT1 Fill pipe. Wash and ream to 6646'. 15:00 - 00:00 9.00 DRILL P INT1 Break in bit, slowly increasing weight and pump rate. Printed: 12/19/2007 2:43:36 PM • BP EXPLORATION Page 6 of 15 Operations Summary Report Legal Well Name: 14-18 Common Well Name: 14-18 Spud Date: 4/8/1981 Event Name: REENTER+COMPLETE Start: 10/23/2007 End: 11/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/1/2007 15:00 - 00:00 9.00 DRILL P INT1 Directional drill ahead to 7552' MD, 6331' TVD. Pump at 605 gpm with 2390 psi on bottom, 2045 psi off bottom. Torque 11-13k on bottom, 9-10k off bottom at 100 rpm. WOB 15-20k. Up weight 185k, down 140k, RT 165k. AST - 1.01, ART - 4.58. Mud weight in and out 9.7 ppg. SPR's at 7159'/2130 hours. Pump #1 30/300, 45/360. Pump #2 30/290, 45/350. Calculated ECD 10.44, PWD ECD 10.73. 11/2/2007 00:00 - 00:00 24.00 DRILL P INT1 Directional drill ahead to 8199' MD. Pump at 625 gpm with 2370 psi off bottom, 2700 psi on bottom. Torque 9-10k off bottom, 10-13k on bottom at 80-100 rpm. WOB 10-20k. Up weight 200k, down 145k, RT 170k. Mud weight in and out 9.7 ppg. Calculated ECD 10.48, PWD ECD 11.08. Pumping sweeps as needed to clean hole. AST - 1.6, ART - 5.59. SPR's at 8199'/1130 hours. Pump #1 30/260, 45/330. Pump #2 30/260, 45/320, Continue to drill ahead to 8885' MD, 7420' TVD. Pump at 630 gpm with 2530 psi off bottom, 2900 psi on bottom. Torque 8-10k off bottom, 12-16k on bottom at 80 to 100 rpm. WOB 15-20k. Up weight 220k, down 155k, RT 180k. Mud weight in and out 9.7+. AST - 2.19, ART - 5.18. SPR's at 8859'/2230 hours. Pump #1 30/300, 45/360. Pump #2 30/290, 45/350. Calculated ECD 10.47, PWD ECD 10.6. 11/3/2007 00:00 - 00:00 24.00 DRILL P INT1 Directional drill ahead to 9144' MD, 7610' TVD. Pump at 550 to 630 gpm with 1550 to 2530 psi off bottom, 1800 to 2900 psi on bottom. Torque 10-13k off bottom, 10-15k on bottom. Up weight 220k, down 155k, RT 180k. WOB 5-25k. Spiked mud system to 10.1 ppg with black product for HRZ, Calculated ECD 10.81, PWD ECD 11.07. SPR's both pumps at 0430 hours/9002', 30/180, 45/240. Continue to drill ahead to 9619' MD, 7939' TVD. Pump at 500 to 625 gpm with 2621-2700 psi off bottom, 2629-3200 psi on bottom. Torque 10-12k off bottom, 12-15k on bottom. WOB 15-25k. Up weight 220k, down 165k, RT 190k. Spike mud system to 11.1 ppg in three stages. Mud weight in and out 11.1 ppg. SPR's at 9521'/2200 hours with 10.8 ppg mud in hole. Pump #9 30/250, 45/360. Pump #2 30/250, 45/330. At 9614'/2330 hours weight up complete and hole taking fluid. Drill pipe torqued up and stalled out twice iust before losses started. Total losses at midni ht 63 bbls. Adding LCM for losses. AST - 9.34, ART - 4.53. Calculated ECD 11.75, PWD ECD 12.09 11/4/2007 00:00 - 11:30 11.50 DRILL P INT1 Directional drill ahead to 10280' MD, 8385' TVD. Pump at 475 gpm with 2300 psi off bottom, 2730 psi on bottom. Torque 11-12k off bottom, 11-17k on bottom. WOB 15-30k. Up weight 230k, down 165k, RT 190k. MW in and out 11,1 ppg. Calculated ECD 11.77, PWD ECD 12.12. Still adding LCM for losses. SPR's both pumps at 9619'!0015 hours, 30/340, 45/430, 11:30 - 12:00 0.50 DRILL P INT1 Circulate hole clean to avoid high ECD's. Pump at 475 gpm with 2270 psi. Hole stopped taking fluid. 12:00 - 23:30 11.50 DRILL P INT1 Drill ahead to 10697' MD, 8679' TVD. Pump at 500 gpm with 2455 psi off bottom, 2760 psi on bottom. Torque 12-13k off P~f1t2tl: 1L19/2007 2:43:36 PM ~ r BP EXPLORATION Page 7 of 15 `operations Summary Report Legal Well Name: 14-18 Common Well Name: 14-18 Spud Date: 4/8/1981 Event Name: REENTER+COMPLETE Start: 10/23/2007 End: 11/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/4/2007 12:00 - 23:30 11.50 DRILL P tNT1 bottom, 13-17k on bottom. WOB 15-30k. Up weight 245k, down 170k, RT 200k. Mud weight in and out 11.1+ ppg. Calculated ECD 11.84, PWD ECD 12.02. At 10650' MD begin control drilling. Pump at 500 gpm with 2455 psi off bottom, 2520 psi on bottom. Rotate at 100 rpm with 11-13k torque off bottom, 13-15k on bottom. At 10691' spot hard cap marker with ROP dropping from 50-80 fph to 18 fph. At 10693' drilling picked up to 30 fph then 40 fph. Drill to 10697' begin seeing a decrease in flow from 43% to 36%, stop, mark pipe and pull up. 23:30 - 00:00 0.50 DRILL P INT1 Pull up reciprocating pipe. Shut down pumps and check hole. Loosin mud while static. Kick pumps back on. Begin adding LCM for losses while circulating up for samples. Losses at 100 lus b h. Decrease pump rate to 385 gpm with 1530 psi. Losses decreased to 70 bbls per hour. Mix LCM pill and pump surface to surface for sweep. Losses drop to 5-10 bph as sweep goes around. Losses for tour 125 bbls, for day 205 bbls, Geologist checking for samples. Geologists call casing point at 10697' MD, 8679' TVD. AST - 6.53, ART - 9.06. SPR's at 10464'. Pump #1 30/350, 45/440. Pump #2 30/330, 45/430. Continue to circulate hole clean. 11/5/2007 00:00 - 01:00 1.00 DRILL P INT1 Continue to circulate hi-vis sweep surface to surface at 385 gpm with 1550 psi. Mud weight in and out 11.1 ppg. SPR's both pumps at 0100 hours/10697', 30/260, 45/360. Circulate out sweep. Shut down. 01:00 - 04:30 3.50 DRILL P INT1 PJSM. POOH for wiper trip to 6400'. Swabbing and pulling tight from 7200' to 7000' with 25-35k over pull. Wipe 3 times, clean. At 7000' over pulling to 60k. Attempt to wipe. MU top drive and pump through to 6960' at 285 gpm with 810 psi. Wipe 3 times, clean. Break out top drive. Over pull at 6750' to 6590' of 40k. Wipe 3 times, clean. Pull to 6400' with no problems. Monitor well while cleaning floor. Losses of 19 bbls on wiper trip out. 04:30 - 08:00 3.50 DRILL P INT1 PJSM. RIH to 10697'. Went back through previous tight spots with no problems. Took 25k down weight at 10550'. Wash and ream to 10697' at 485 gpm with 2540 psi. Torque 11-13k at 80 rpm. 08:00 - 10:30 2.50 DRILL P INT1 Circulate hi-vis sweep surface to surface at 550 gpm with 2770 psi. Rotate 120 rpm with 12-13k torque. Spot bead pill. Monitor well - OK. Drop CCV activation ball to open circ. sub. Did not shear open: pumped through at 1900 psi. Pump dry job, break and blow down top drive. MW in and out 11.1 ppg. Calc. ECD - 11.8 ppg. PWD ECD - 11.92 ppg. 10:30 - 14:30 4.00 DRILL P INT1 PJSM. POOH to 3008' with no problems. Up weight 260k. 14:30 - 1.5:30 1.00 DRILL P INT1 PJSM. Remove high pressure lines from Geo-Pilot skid. Plug valves. Bring up thread protectors to rig floor. 15:30 - 17:30 2.00 DRILL P INT1 Lay down 5" DP to 834'. Monitor well and hold PJSM. 17:30 - 20:30 3.00 DRILL P INT1 Lay down BHA to flex collars. Flush with fresh water. PU to RLL and plug in for download. Download MWD. Continue to LD BHA to motor. Break bit. Bit in gauge. Recover 1 activation ball from ball catcher. Clean and clear floor. 20:30 - 21:30 1.00 DRILL P INT1 PJSM. Lay BHA down beaver slide. PU casing equipment. 21:30 - 22:30 1.00 BOPSU P LNR1 PJSM. Pump out stack. Pull wear ring. Install test plug. Close Printed: 12!19/2007 2:43:36 PM ! +M BP EXPLORATION Page 8 of 15 Operations Summary Report Legal Well Name: 14-18 Common Well Name: 14-18 Spud Date: 4/8/1981 Event Name: REENTER+COMPLETE Start: 10/23/2007 End: 11/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2007 ii Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/5/2007 21:30 - 22:30 1.00 BOPSU P LNR1 blind rams. Pull variable top rams. 22:30 - 23:00 0.50 BOPSU P LNR1 Install 7" rams in the to cavity. CO handling equipment. 23:00 - 00:00 1.00 BOPSU P LNR1 PU test joint. Make up TIW and XO. Install test joint. Fill stack. Check for leaks - OK. Rig up to test 7" rams. Total losses for 24 hour period - 90 bbls. No losses since trip out. 11/6/2007 00:00 - 03:30 3.50 BOPSU P LNR1 PJSM. Test 7" rams to 250 psi low, 3500 psi high as per AOGCC. No test on hig pressure. ea mg at collar. Investigate leak. Make several tries to tighten. Back out and change seal ring. Retested, good test. 03:30 - 04:00 0.50 CASE P LNR1 PJSM. Rig up to run 7", 26#, L-80, BTC-M liner. 03:30 - 10:30 7.00 CASE P LNR1 PJSM. Run 7", 26#, L-80, BTC-M liner to 3502' - PUW = 100k /SOW = 100k. -Avg Torque 3500 ft/Ibs 10:30 - 11:30 1.00 CASE P LNR1 Circulate Liner Volume @ Window (3502') -210 gpm = 250 psi 11:30 - 18:30 7.00 CASE P LNR1 Run 177 joints of 7", 26#, L-80, BTC-M liner to 7317' - PUW = 145k /SOW = 115k. -Avg Torque 8800 ft/Ibs -Started pushing mud away when Liner enter open hole -Lost 383 bbls runnin 7" Liner in o en hole MWT in /Out = 11.1 ppg 18:30 - 19:00 0.50 CASE P LNR1 Attempt to circulate -131 gpm = 658 psi, -PUW = 197k SOW = 130k -Only Apx. 5 - 10% Returns 19:00 - 22:00 3.00 CASE P LNR1 Continue running in hole on Drill pipe , No Problems running in -3 to 5% returns -M/U Cement head and Cement line -PUW - 255k SOW - 133k -Wash to Bottom @ 10697' Pick up and put into tension with 250k. 22:00 - 00:00 2.00 CEMT P LNR1 PJSM with Schlumberger cement crew and NAD drill crew -Batch up cement and Mud Push II -Fill cement lines and Test to 4500 psi, good test Pump 50 bbls of 11.4 Mud Push II, Pump 212 bbls of 11.6 ppg Lite-Crete, The MudPush II and cement slurries contained 1 ppb of CemNet to help control losses. 11/7/2007 00:00 - 03:00 3.00 CEMT P LNR1 Finish Mixing and Pumping 212 bbls (437 sx) of 11.6 ppg LiteCRETE lead slurry, followed by 35 bbls (169 sx) of batch mixed, 15.8 ppg Class G tail slurry. The MudPush II and '~ cement slurries contained 1 ppb of CemNet to help control losses. Release the DP wiper dart and kick out of head with 5 bbls WATER. Follow with 331 bbls of Mud. Bumped on schedule, CIP @ 02:15 Pressure up to verify seated. Bleed off pressure and verify that the floats are holding. Pressure up to 3000 psi to set the liner hanger as per Baker rep. Slack off to confirm set. Pressure up to 4000 psi to set liner top packer. Rotate 15 turns to the right. Confirm release. Printed: 12/19/2007 2:43:36 PM ~ ~ Event Name: REENTER+COMPLETE Start: 10/23/2007 End: 11/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT `Phase Description of Operations 11/7/2007 00:00 - 03:00 3.00 CEMT P LNR1 Pressure up to 1000 psi and hold while un-stinging from packer BP EXPLORATION Page 9 of 15 Operations Suimrnary Report Legal Well Name: 14-18 Common Well Name: 14-18 Spud Date: 4/8/1981 top. Circulate at 13 bpm to circulate out cement. CBU, No i cement back to surface 03:00 - 03:30 0.50 CEMT P LNR1 Rig Down Cement head and all liner running equipment, - Prepare floor to Laydown Drill pipe - Flush and blow down lines - L/D 6 joints of 5" drill pipe 03:30 - 04:30 1.00 CEMT P LNR1 CBU 2x @ 550 gpm / 440 psi 04:30 - 07:00 2.50 CEMT P LNR1 Slip and cut drilling line -Inspect Derrick -Service Top Drive, Crown and Draw Works 07:00 - 08:00 1.00 CASE N RREP LNR1 Troubleshoot the Maximum RPM's issue on the Top Drive 08:00 - 11:00 3.00 CASE P LNR1 Laydown 3137' of 5" Drill Pipe 11:00 - 13:00 2.00 CASE P LNR1 RIH with 2836' of 5" Drill Pipe 13:00 - 16:30 3.50 CASE P LNR1 Laydown 2836' of 5" Drill Pipe 16:30 - 17:30 1.00 BOPSU P LNR1 Suck out stack and Pull Wear bushing -Install Test Plug 17:30 - 18:30 1.00 BOPSU P LNR1 PJSM on changing Rams 18:30 - 00:00 1 5.501 BOPSUF~ P ~ I LNR1 I PJSM, Test BOPE, 250 low, 3500 psi high, holding each test 4" Test Joint -Test #1 -Blind Rams, HCR Kill, and choke manifold valves 1,2,3,16 -Test #2 -choke manifold valves 4, 5, 6 -Test #3 -choke manifold valves 7, 8, 9 -Test #4 -hydraulic choke & manual choke -Test #5 -choke manifold valves 10, 11 -Test #6 -choke manifold valves 12, 13, 14 4" Test Joint, -Test #7 -Top Rams, Dart, Manual valve on Kill Line, choke manifold valve 15 -Test #8 -HCR Choke, TIW -Test #9 -Annular, Manual Choke -Test #10 -Bottom Rams 5" Test Joint, -Test #11 -Top Rams, Dart Accumulator Test -3000 psi initial ,bleed down to 1600 psi 200 psi recovery 31 secs Full 3000 psi recovery 1 min 47 sec 6 Bottles of Nitrogen avg. 2200 psi Tested Gas alarms & PVT. Test witnessed by BP WSL Dave Newton, NAD TP Jon Castle, Witness of test waived by Jeff Jones, AOGCC. 11/8/2007 00:00 - 02:00 2.00 BOPSU P LNR1 Finish Testing BOP's with 5" Test Joint -Test #12 - Bottom Rams -Test #13 -Top Drive manual IBOP, Outside Mud Cross valves -Test #14 -Top Drive Hydraulic IBOP, Inside Mud Cross Printed: 12/19/2007 2:43:36 PM ~ ~ BP EXPLORATION Page 10 of 15 Operatiolns Summary Report Legal Well Name: 14-18 Common Well Name: 14-18 Spud Date: 4/8/1981 Event Name: REENTER+COMPLETE Start: 10/23/2007 End: 11/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2007 Rig Name: NABORS 2ES Rig Number: Date.' From - To Hours Task Code NPT Phase Description of Operations 11/8/2007 00:00 - 02:00 2.00 BOPSU P LNR1 valves -Blow down Choke Manifold -Pull test plug and Set Wear Bushing Test witnessed by BP WSL Dave Newlon, NAD TP Jon Castle, Witness of test waived by Jeff Jones, AOGCC. 02:00 - 02:30 0.50 CASE P LNR1 Test Casing and TOL for 5 min before making up Drilling BHA -Ready Cellar after testing ', 02:30 - 03:00 0.50 CASE P LNR1 Laydown 1 stand of drill pipe and flush stack and flowline -P/U BHA from outside -P/U Handling Equipment 03:00 - 08:00 5.00 DRILL P PROD1 Make up 6 1/8" Bit and BHA -M/U MWD and Plug in to verify tool -Shallow hole test MWD / LWD -PJSM on Loading Nukes -Changeout handling equipment 08:00 - 10:00 2.00 DRILL P PROD1 P/U 4" Drill Pipe from 397 -2287' -Fill Pipe 250 gpm @ 1590 psi 10:00 - 13:00 3.00 DRILL P PROD1 PJSM on Stripping Drill Procedure -Conducted stripping drill with 250 psi on well -Everyone on crew operated choke and participated in drill -Blow down equipment 13:00 - 14:00 1.00 DRILL P PROD1 Continue picking up 4" drill pipe down to top of 7" liner -Fill pipe 247 gpm / 1660 psi -Run through TOL, 2k bobble entering 7" liner 14:00 - 20:00 6.00 DRILL P PROD1 Continue picking up 4" drill pipe to 8899' -filling pipe @ 90 stands in 250 gpm / 1790 psi 20:00 - 21:30 1.50 DRILL P PROD1 Change to 5" handling equipment Strap Pipe to verify tally 21:30 - 23:00 1.50 DRILL P PROD1 Wash down from 10400' to 10501' -no indication of cement or cement strin ers -CBU and condition mud for casing test -287 gpm 2867 psi ICP, Pressure drop to 1200 psi @ 273 gpm 23:00 - 23:30 0.50 DRILL P PROD1 PJSM on testing casing -Test casing and Liner top to 3500 psi for 30 min 23:30 - 00:00 I 0.501 DRILL I P I I PROD1 11/9/2007 100:00 - 00:30 I 0.501 DRILL I N I DFAL I PROD1 00:30 - 03:00 I 2.501 DRILL I N I DFAL I PROD1 03:00 - 03:30 0.50 DRILL N DFAL PROD1 03:30 - 04:00 0.50 DRILL N DFAL PROD1 04:00 - 06:00 2.00 DRILL N DFAL PROD1 06:00 - 08:00 2.00 DRILL P PROD1 Make up Top Drive and establish parameters -301 gpm / 1200 gpm -PUW 215k Sow 130k -MW In /Out 9.8 ppg Troubleshoot Possible washout -Pressure loss of 950 psi since 2230 hrs -Check Surface equipment, O.K. -Pressure continued to decrease and no MWD signal POH looking for washout -found washout on 40 stands out, 2 foot above pin end of 4" drill pipe UD bad joint and replace joint Break Circ. and verify circulating pressure 254 gpm / 2170 psi RIH to 10500' Drill cement and Float equipment to 10 feet from shoe Printed: 12/19/2007 2:43:36 PM • • BP EXPLORATION Page 11 of 15 Operations.Sumlma ry Report Legal Well Name: 14-18 Common Well Name: 14-18 Spud Date: 4/8/1981 Event Name: REENTER+COMPLETE Start: 10/23/2007 End: 11/14/2007 Contractor Name: NABORS ALASIG4 DRILLING I Rig Release: 11/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/9/2007 06:00 - 08:00 2.00 DRILL P PROD1 -250 gpm / 2340 psi -60 rpms 10.5k TQ - 5-10k WOB 08:00 - 10:30 2.50 DRILL P PR001 Displace to 8.4 ppg Flo-Pro Drilling Fluid -Pump 50 bbls of Fresh water -45 bbl of Hi-Vis Sweep, -8.4 Flo-Pro Once the clean Flo-pro got back to surface, we shut down and finish cleaning surface equipment and ready pit room for drilling operations 10:30 - 11:00 I 0.501 DRILL I P 11:00 - 12:30 1.50 DRILL I P 12:30 - 13:00 0.50 DRILL P 13:00 - 20:00 I 7.00 I DRILL I P 20:00 - 21:30 I 1.501 DRILL I P 21:30 - 23:30 I 2.001 DRILL I P 11/10/2007 100.30 - 01:00 0.50 DRILL I P 01:00 - 01:30 I 0.501 DRILL I P 01:30 - 03:00 I 1.501 DRILL I P 03:00 - 06:30 3.50 DRILL I P 06:30 - 07:00 0.50 DRILL P 07:00 - 08:30 1.50 DRILL I P 08:30 - 12:00 3.50 DRILL P PROD1 Drill out float shoe and 20' of new hole to 10717' - 60 Rpm , 3k Tq off / 4k Tq On - 300 gpm, 2200 psi off / 2250 psi on - 10-15k WOB - PUW 175k / SOW 155k / RtWt 165k\ PROD1 CBU @ 300 gpm 2200 psi PROD1 Perform FIT test to 10 p EMW -Pump 23 strokes / 750 psi -Charted test and record pressure for 10 min PROD1 Directionally drill from 10717 to 11,130' (TD') ~ - 100 Rpm , 3k Tq off / 5k Tq On - 300 gpm, 2350 psi off / 2550 psi on - 10-20k WOB - PUW 185k / SOW 155k / RtWt 170k -ART = 2.19 hrs AST = 3.15 hrs ADT = 5.34 hrs MW = 8.4 in /out PROD1 Circulate Hi-Vis Sweep around -300 gpm / 2400 psi -no increase in cutting with sweep returns PROD1 POH to shoe MAD pass logging -200 gpm / 900 psi -35 rpm / 3500 ft/Ibs TQ Mad Passed 11,010 - 10,740 @ 300 fph Max No Problems on trip to shoe PROD1 Service Rig, Top Drive, Crown and Draw Works PROD1 RIH to bottom, no problems running in PROD1 Circ. 2x Open hole -Monitor well, static -8.4 MW in /out PROD1 Pump out to shoe -200 gpm 900 psi -No problems pulling to shoe PROD1 Drop 1.76" ball and open Circ Sub. pumping 2 bpm / 780 psi -Ball Land and pressure up to 2050 psi and open -2 bpm = 480 psi -CBU @ 412 gpm / 1550 psi PROD1 POH PROD1 Position Circ. Valve at Top of 7" Liner -Flush TOL @ 410 gpm / 530 psi PROD1 POH to BHA PROD1 PJSM on UD BHA and Removing RA source from BHA -Flush BHA with Water, UD all BHA components Printed: 12/19/2007 2:43:36 PM • • BP EXPLORATION Page 12 of 15 Operations Summary Report Legal Well Name: 14-18 Common Well Name: 14-18 Spud Date: 4/8/1981 Event Name: REENTER+COMPLETE Start: 10/23/2007 End: 11/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2007 Rig Name: NABORS 2ES Rig Number: Date l From - To I Hours ~ Task I Code E NPT ( Phase I Description of Operations 11/10/2007 08:30 - 12:00 12:00 - 13:30 13:30 - 16:30 3.50 1.50 3.00 DRILL CASE CASE P P P PROD1 RUNPRD RUNPRD -Clear floor of third party equipment Bring up Liner Running equipment and Rig up to run 4 1/2" liner Run 4-1/2" # 13Cr-80 Vam-Top liner as oer Running Order. Make up shoe track as per tally and check floats. Pick up remaining liner (total - 13 Jts.), filling liner on the run with fill-up line. Top off every 5 Jts. Make up liner hanger, xo, and 1 stand of 4" DP. Circulate -2 x liner volume @ 201 gpm / 90 psi Baker-Lok shoe track through landing collar 1 - 4.75" x 5.75 "centralizer per running detail (11 total). PUW 35k / SOW 35k Jet Lube seal Guard thread compound, torque 4440 ft/Ib. 16:30 - 18:00 1.50 CASE P RUNPRD RIH with Liner filling every 20 stands 18:00 - 18:30 0.50 CASE P RUNPRD CBU @ 7" Liner Top 300 gpm / 310 psi 18:30 - 23:30 5.00 CASE P RUNPRD RIH with Liner to 7" Shoe, filling every 20 stands 23:30 - 00:00 0.50 CASE P RUNPRD CBU @ 7" Shoe 210 gpm / 780 psi MW 8.4 ppg in /out 11/11/2007 00:00 - 00:30 0.50 CASE P RUNPRD Finish CBU at 7" shoe -PJSM with Schlumberger Cementing Crew And NAD Rig Crew -210 gpm / 780 psi ~ PUW - 182k /SOW - 152K 00:30 - 01:00 0.50 CASE P RUNPRD RIH with 4 1/2" liner - No Problem running in 01:00 - 01:30 0.50 CEMT P RUNPRD R/U Cement Head and Cement lines -Batch Mix Mud Push II and cement slurry 01:30 - 02:00 0.50 CEMT P RUNPRD Break Circ., Stage up to 5 bpm / 810 psi PUW - 194k /SOW - 158K 02:00 - 03:00 1.00 CEMT P RUNPRD Pump 5 bbl water to cement head, test lines to 4000 psi. Pump 30 bbl MudPush II at 11.4 ppg. Pump 21 bbl of 15.8 ppg class "G"w/GasBlok tail at 5 BPM. Pump 5 bbl water to clear lines through tee back to flow line Drop Plug, Kick out plug and displace with 15 Bbls Perf Pill followed by 113 bbls.,8.4 ppg Flo-Pro mud. Slow down pump rate to 3 bpm during latch up to wiper plug. Bump plug to 3,800 psi to set hanger as directed by Baker rep. Slack off 60k confirm hanger is set. Bleed pressure and check floats. Rotate 20 turns to release from the liner. Pressure up string to 1000 psi, pick up slowly, noted pressure loss as pack-off was pulled from RS bushing. Immediately circulated 30 bbl. up hole at 523 gpm 2720 psi. Slow pumps to 1.5 BPM, set 70k down to set ZXP liner top packer. CIP @ 02:45 03:00 - 05:00 2.00 CEMT P RUNPRD Pick up and circulate out cement at 523 gpm 2720 psi. A- Px 8 bbls of cement returns. Overboarded cement and contaminated mud, Continue Circ. Bottoms up 1 more time 05:00 - 05:30 0.50 CEMT P RUNPRD Lay Down Cement Head and cementing equipment 05:30 - 07:00 1.50 CEMT P RUNPRD Cut Drilling Line, Service TDS, Draw Works, and Crown Section 07:00 - 08:30 1.50 CEMT P RUNPRD Displace Flo-Pro to Seawater -Pump 20 bbl. Soap Pill, Chase with Clean Seawater -490 gpm / 2450 psi Printed: 12/19/2007 2:43:36 PM BP EXPLORATION Page 13 of 15 Operations Summary Report Legal Well Name: 14-18 Common Well Name: 14-18 Spud Date: 4/8/1981 Event Name: REENTER+COMPLETE Start: 10/23/2007 End: 11/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2007 Rig Name: NABORS 2ES Rig Number: Date.. I From - To I Hours I Task I Code ~ NPT I Phase ( Description of Operations 11/11/2007 07:00 - 08:30 1.50 CEMT P RUNPRD -Circ. till clean seawater to surface 08:30 - 17:30 9.00 CASE P RUNPRD Lay Down 4" and 5" Drill Pipe 17:30 - 18:00 0.50 CASE P RUNPRD Clear Handling equipment from Rig Floor -Pull Wear Bushing 18:00 - 19:00 1.00 CASE P RUNPRD Test 4 1/2" Liner and liner Lap to 3500 psi for 30 min. Recorded test on chart, Good Test 19:00 - 21:00 2.00 RUNCO RUNCMP Bring Chrome Tubing handling equipment to floor -Rig up Double stack Power Tongs and Compensator 21:00 - 00:00 3.00 RUNCO RUNCMP PJSM with BOT tool hand, NAD casing Hand and NAD Rig Crews -Run 4.5" 12.6# 13Cr-80 Vam To tubing as per running detail. -Bakerlok all connections up to the Baker S-3 Packer 11/12/2007 00:00 - 11:30 11.50 RUNCO RUNCMP PJSM with BOT tool hand, NAD casing Hand and NAD Rig Crew that came on at Midnight -Run 4.5" 12.6# 13Cr-80 Vam Top tubing as per running detail. L/D 3 Joints, Make Up Space out Pups, Run 1 full joint, Rig Down Tubing running equipment, M/U Hanger and Landing joint, Land in tubing spool with 7.69' of swallow from TOL to WLEG, PUW - 144k SOW - 110k Land with 80k on hanger, RILDS, Back out Landing joint TOL top is @ 10,555' Completion as follows 4.5" WLEG 9CR 4.5" 12.6# 13Cr-80 TCII Tubing Pup XN Nipple w/RHC-M plug (3.725" bore) 4.5" 12.6# 13Cr-80 XO pup Vam Top box x TCI I pin 1 jt 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin 4-1/2" HES X Nipple 9Cr 3.813" Pkg Bore 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin Baker S-3 7"x 4.5" Packer TCII Box x Pin 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin 4-1/2" HES X Nipple 9Cr 3.813" Pkg Bore 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 1 jt 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM #1 4.5"x1" KBG2-1 R 9Cr w/DV RK latch 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 21 jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM #2 4.5"x 1" KBG2-1 R 9Cr w/DV RK Latch 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 27 jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM #3 4.5"x 1" KBG2-1 R 9Cr w/DV RK Latch 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCtI P 35 jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM #4 4.5"x 1" KBG2-1 R 9Cr w/DV RK Latch Printed: 12/19/2007 2:43:36 PM • ~ $P EXPLORATION Page 14 of 15 Operations Summary Report Legal Well Name: 14-18 Common Well Name: 14-18 Spud Date: 4/8/1981 Event Name: REENTER+COMPLETE Start: 10/23/2007 End: 11/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2007 Rig Name: NABORS 2ES Rig Number: Date I From - To I Hotars I Task I Code f NPT I Phase ( Description of Operations 11/12/2007 100:00 - 11:30 I 11.501 RU 11:30 - 13:00 I 1.50 13:00 - 16:00 I 3.001 RU 16:00 - 18:00 I 2.00 RUNCMP 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 36 jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM # 5 4.5"x 1" KBG2-1 R 9Cr w/DV RK Latch 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 29 jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM #6 4.5"x 1" KBG2-1 R 9Cr w/DV RK Latch 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 27 jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin GLM # 7 4.5"x 1" KBG2-1 R 9Cr w/ DCR Shear & RKP 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 15 jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin 4-1/2" HES X Nipple 9Cr 3.813" Pkg Bore 4.5" 12.6# 13Cr-80 XO pup jt Vam top Bx TCII P 50 jts (#194-242) Jts 4.5" 12.6" 13Cr-80 Vam Top tubing Space Out PUPs 9.90', 9.96', 2.07' 1 jts 4.5" 12.6" 13Cr-80 Vam Top tubing 4.5" 12.6# 13 Cr-80 XO pup TCII box x Vam Top pin Cameron Tubing Hanger 13.625" x 4.5" TCII Box x Pin RUNCMP Land Tubing, RILDS (550 ff/Ib torque) -Rig Down Running equipment RUNCMP PJSM, Rig up to reverse circulate -Reverse 160 bbls of seawater, -followed by 161 bbls of Inhibited Seawater (treated with 110 gals of corrision inhibitor) -128 gpm / 200 psi RUNCMP Droa Ball and Rod. Set Packer -Test Tubin to 3500 psi for 30 min, good test -Bled tubing pressure to 1500 psi and pressure up on annulus to 3500 for 30 min ood test -All test charted -Bled off annulus pressure to zero, bled off tubing pressure to zero, -Pressure upon annulus to 2100 psi and sheared out DCK valve in GLM #7, -Pump 5 bbls both ways and confirm shear 18:00 - 19:00 1.00 RUNCO RUNCMP Dry Rod Two-Way Check in -Test to 1000 psi from below fo 5 min, good test -Test to 1000 psi for 5 min from above, -TWC not holding, Cycled pressures up from below and top without success 19:00 - 22:00 3.00 RUNCO SEAL RUNCMP Rig up to change out Two Way Check Valve, Lubricating TWC out - Mobilize Drill Site maintenance for Lubricator - Mobilize Tool Service for the Lubricator extension 22:00 - 00:00 2.00 RUNCO SFAL RUNCMP PJSM with DSM, NAD rig crew on R/U and Testing Lubricator -R/U up Extension and place into stack, install Lubricator, test to 500 psi, good test -Pull Two Way Check, TWC appeared to have debris in poppet area of valve P~ntCtl: 12/19/2007 1:43:36 PM BP EXPLORATION Page 15 of 15 `Operations Summary Report Legal Well Name: 14-18 Common Well Name: 14-18 Spud Date: 4/8/1981 Event Name: REENTER+COMPLETE Start: 10/23/2007 End: 11/14/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/14/2007 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/12/2007 22:00 - 00:00 2.00 RUNCO SFAL RUNCMP -Install new TWC -Test From above to 1000 psi for 5 min, good test -Test from below to 1000 psi for 5 min, good test -R/D Extension and Lubricator 11/13/2007 00:00 - 01:30 1.50 BOPSU P RUNCMP Nipple down riser and BOP's -Set Back on stump and secure 01:30 - 06:00 4.50 WHSUR P RUNCMP Nipple up Adaptor flange and tree -Test Adaptor Flange to 5000psi for 30 min, good test -Test Tree to 5000 psi for 10 min, good test 06:00 - 07:00 1.00 WHSUR P RUNCMP PJSM with DSM and Rig Crew -R/U DSM Lubricator and test to 500 psi f/5min -Pull TWC 07:00 - 10:00 3.00 WHSUR P RUNCMP PJSM with Little Red and Rig Crew -R/U to Pump Freeze Protect Diesel -Pump 151 bbls at 2 bpm / 1900 psi Let Diesel U-Tube annulus to tubing 10:00 - 11:30 1.50 WHSUR P RUNCMP Install BPV with Drill Site Maintenance -Test from below to 1000 psi, Good Test -Rig Down Little Red Pumping Services -R/D Drill Site Maintenance 11:30 - 12:30 1.00 WHSUR P RUNCMP Remove rig secondary annulus valves and install flanges and gauges on tree -Secure Well 12:30 - 00:00 11.50 WHSUR N WAIT RUNCMP Standby for Security -Security escorting Nabors 7es -Ready Rig for move -Clean Rig -Change out torque tube guide rails on Top Drive 11/14/2007 00:00 - 22:00 22.00 WHSUR N WAIT RUNCMP Standby for Security -Security escorting Nabors 7es -Ready Rig for move -Clean Rig Release Rig @ 22:00 hrs Printed: 12/19/2007 2:43:36 PM Well History Well Date Summary 14-18B 12/2/2007 T=O. Pull 4 1/ 16 CIW "H" BPV. (Post Rig) Pulled 4 1/16 CIW "H" BPV at 104" No Problems. 14-18B 12/4/2007 ***WELL S/I ON ARRIVAL***(post sd trk) PULL BALL & ROD FROM 10527' SLM. RIH W/ 4 1/2" OK-06 TO STA. 6 @ 4009' MD COULD NOT LOC OR SET DOWN. PUH TO STA. 7 @ 2849' MD. PULLED A COUPLE FRICTION BITES, OOH W/NO VALVE CONTINUED ON 12-05-07 14-18B 12/5/2007 ***CONT JOB FROM 12-4-07*** PULL ST# 6 BK-DGLV @ 4009' MD.PULL ST# 7 BEK-DCR @ 2849' MD SET ST# 7 BK-LGLV @ 2849' MD. SET ST# 6 BK-OGLV @ 4009' MD. PULLED 4 1/2" RHC PLUG BODY FROM 10551' MD. DRIFT W/ 2 7/8" DUMMY GUN, S-BAILER SD @ 11044' MD. ICE IN SAMPLE BAILER DRIFT W/ 3.625" CENT, 10' O 1 7/8" STEM, 3.625" CENT SD @ 11042' MD. ***WELL LEFT S/I OPER NOTIFIED*** 14-18B 12/8/2007 ***WELL SHUT IN ON ARRVAL*** INITIAL T/ V O = 0/ 0/ 0 PSI. / PERFORATE 10,930' - 10,974' W/ 2-7/8" PJ OMEGA, 6 SPF. STATIC BOTTOMHOLE PRESSURE SURVEYS AT 10,880', 10,732', 10,585' MD. WELL LEFT SHUT IN. TURNED OVER TO DSO TP POP. ***JOB COMPLETE***FINAL T/ V O = 0/ 0/ 0 PSI. 14-186 12/12/2007 T/V0= 700/1750/75 Temp= S/I Hot Oil Treatment Tbg- Pumped 130 bbls 190*F crude dow n Tbg. Purrped 15 bbls neat down IA. DSO to POP w elt. FWHP= 150/1720/100 "Annulus casing valves left open on departure" 14-18B 12/30/2007 T/V0=210/1150/410. Temp=Online. Eval cellar glaciation (FO call-in). A/L is online. Ice/water up to 1" below floor grating. No noticeable cellar activity. Took sample of w ater, installed heater in w ellhouse. 14-18B 12/31/2007 T/VO = 210/1120/420. Temp =Hot. Monitor WHPs (eval glaciation). AL online, ALP= 1120 psi. Water in cellar is 8" below floor grating, there are no signs of activity. Print Date: 1/4/2008 Page 1 of 1 BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: 14-18 Common Name: 14-18 Test Date Test Type.. Test Depth (TMD), Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 10/28/2007 LOT 3,555.0 (ft) 3,555.0 (ft) 9.50 (ppg) 420 (psi) 2,174 (psi) 11.77 (ppg) 11/9/2007 LOT 10,697.0 (ft) 8,679.0 (ft) 8.40 (ppg) 723 (psi) 4,510 (psi) 10.00 (ppg) Printed: 12/19/2007 2:43:30 PM • Sperry Drilling Services Survey Report Company: BP AmoCO Date: 11/28/2007 'l'ime: 16:17:44 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 14-18, True N orth Site: PB DS 14 Vertical (TVDI Reference: 41.96BF+28.5KB@ 70.46 70.5 Well: 14-18 Section (VS) Reference: Well (O.OON,O.OOE,303.80Azi) Wellpath: 14-188 Survey Calculationl iethod: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Pla ne 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 Well: 14-18 Slot Name: 18 14-18 Well Position: +N/-S -920.47 ft Northing: 5938669.45 ft Latitude: 70 14 17.293 N +E/-W 527.66 ft Easting : 674699.23 ft Longitude: 148 35 21.389 W Position Uncertainty: 0.00 ft Wellpath: 14-186 Drilled From: 14-18 500292055102 Tie-on Depth: 3499.46 ft Current Datum: 41.96 6E+28.5K6@70.46 Height 70.46 ft Above System Datum: Mean Sea Level Magnetic Data: i 0/26/2007 Declination: 23.57 deg Field Strength: 57660 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28 .46 0.00 0.00 303.80 Survey Program for Definitive Wellpath Date: 11/28/2007 Validated: No Version: 6 Actual From To Survey Toolcode Tool Name ft ft 99.46 3499.46 14-18 CB-GY RO-MS SD C #1 (99.46 CB-GYRO-MS Camera based gyro multishot 3533.16 11092.48 14-186 IIFR+MS+SAG (3533.16-11 MWD+IFR+MS MWD +IFR + Multi Station Survey MD; Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 28.46 0.00 0.00 28.46 -42.00 0.00 0.00 5938669.45 674699.23 TIE LINE 99.46 0.00 0.00 99.46 29.00 0.00 0.00 5938669.45 674699.23 CB-GYRO-MS 199.46 0.00 0.00 199.46 129.00 0.00 0.00 5938669.45 674699.23 CB-GYRO-MS 299.46 0.00 0.00 299.46 229.00 0.00 0.00 5938669.45 674699.23 CB-GYRO-MS 399.46 0.25 180.00 399.46 329.00 -0.22 0.00 5938669.24 674699.23 CB-GYRO-MS 499.46 0.00 0.00 499.46 429.00 -0.44 0.00 5938669.02 674699.24 CB-GYRO-MS 599.46 0.50 205.00 599.46 529.00 -0.83 -0.18 5938668.62 674699.06 CB-GYRO-MS 699.46 0.00 0.00 699.46 629.00 -1.23 -0.37 5938668.22 674698.89 CB-GYRO-MS 799.46 0.00 0.00 799.46 729.00 -1.23 -0.37 5938668.22 674698.89 CB-GYRO-MS 899.46 0.50 180.00 899.46 829.00 -1.66 -0.37 5938667.78 674698.90 CB-GYRO-MS 999.46 0.00 0.00 999.45 928.99 -2.10 -0.37 5938667.35 674698.91 CB-GYRO-MS 1099.46 0.25 203.00 1099.45 1028.99 -2.30 -0.45 5938667.14 674698.83 CB-GYRO-MS 1199.46 0.00 0.00 1199.45 1128.99 -2.50 -0.54 5938666.94 674698.75 CB-GYRO-MS 1299.46 0.25 179.50 1299.45 1228.99 -2.72 -0.54 5938666.72 674698.75 CB-GYRO-MS 1399.46 0.50 198.00 1399.45 1328.99 -3.35 -0.67 5938666.09 674698.64 CB-GYRO-MS 1499.46 0.50 194.00 1499.45 1428.99 -4.19 -0.91 5938665.24 674698.41 CB-GYRO-MS 1599.46 0.00 0.00 1599.45 1528.99 -4.61 -1.02 5938664.82 674698.32 CB-GYRO-MS 1699.46 0.25 179.57 1699.45 1628.99 -4.83 -1.01 5938664.60 674698.33 CB-GYRO-MS 1799.46 1.00 180.00 1799.44 1728.98 -5.92 -1.01 5938663.51 674698.35 CB-GYRO-MS 1899.46 0.00 0.00 1899.43 1828.97 -6.80 -1.01 5938662.64 674698.37 CB-GYRO-MS 1999.46 0.75 166.00 1999.43 1928.97 -7.43 -0.85 5938662.01 674698.55 CB-GYRO-MS 2099.46 0.00 0.00 2099.43 2028.97 -8.07 -0.70 5938661.37 674698.72 CB-GYRO-MS 2199.46 0.75 185.00 2199.43 2128.97 -8.72 -0.75 5938660.72 674698.68 CB-GYRO-MS 2299.46 0.00 0.00 2299.42 2228.96 -9.37 -0.81 5938660.07 674698.63 CB-GYRO-MS 2399.46 0.50 164.00 2399.42 2328.96 -9.79 -0.69 5938659.65 674698.76 CB-GYRO-MS 2499.46 0.25 198.00 2499.42 2428.96 -10.42 -0.64 5938659.03 674698.83 CB-GYRO-MS 2599.46 0.00 0.00 2599.42 2528.96 -10.62 -0.70 5938658.82 674698.77 CB-GYRO-MS 2699.46 0.50 195.00 2699.42 2628.96 -11.05 -0.82 5938658.39 674698.67 CB-GYRO-MS 2799.46 0.00 0.00 2799.42 2728.96 -11.47 -0.93 5938657.97 674698.56 CB-GYRO-MS ! ~ Sperry Drilling Services Survey Report Company: BP Amoco Date: 11/28/2007 Time: 16:17:44 Page: 2 Field: P[u dhoe Bay Co-ordinate(NE) Reference: Well: 14-18, True North Site: PB DS 14 Vertical (TVD) Refer ence: 41 .966E+28.5KB@70.46 70.5 Well: 14- 18 Section (VS},Referen ce: Well (O.OON,O.OOE,303.80Azi) Wellpath: 14- 186 Survey Calculation Method: Mi nimum Curvatu re llb: Oracle Survey MD Incl Azim TVD SysTVD N/S F./W MapN NtapE Tool ft deg deg it ft ft tt ft ft 2899.46 0.50 195.00 2899.42 2828.96 -11.89 -1.04 5938657.55 674698.46 CB-GYRO-MS 2999.46 0.25 195.00 2999.41 2928.95 -12.52 -1.21 5938656.91 674698.31 CB-GYRO-MS 3099.46 0.00 0.00 3099.41 3028.95 -12.73 -1.27 5938656.70 674698.25 CB-GYRO-MS 3199.46 0.00 0.00 3199.41 3128.95 -12.73 -1.27 5938656.70 674698.25 CB-GYRO-MS 3299.46 0.00 0.00 3299.41 3228.95 -12.73 -1.27 5938656.70 674698.25 CB-GYRO-MS 3399.46 0.00 0.00 3399.41 3328.95 -12.73 -1.27 5938656.70 674698.25 CB-GYRO-MS 3499.46 0.25 195.00 3499.41 3428.95 -12.94 -1.33 5938656.49 674698.20 CB-GYRO-MS 3533.16 1.33 224.00 3533.11 3462.65 -13.29 -1.62 5938656.13 674697.92 MWD+IFR+MS 3564.04 2.54 224.00 3563.97 3493.51 -14.04 -2.34 5938655.36 674697.21 MWD+IFR+MS 3626.73 6.65 223.93 3626.45 3555.99 -17.66 -5.82 5938651.67 674693.81 MWD+IFR+MS 3721.16 13.48 233.90 3719.37 3648.91 -28.09 -18.53 5938640.94 674681.36 MWD+IFR+MS 3815.18 16.19 248.72 3810.28 3739.82 -39.31 -39.60 5938629.24 674660.55 MWD+IFR+MS 3910.26 18.46 267.39 3901.12 3830.66 -44.81 -67.02 5938623.10 674&33.27 MWD+IFR+MS 4005.34 18.83 276.89 3991.23 3920.77 -43.66 -97.30 5938623.56 674602.98 MWD+IFR+MS 4099.85 18.70 279.14 4080.71 4010.25 -39.42 -127.40 5938627.09 674572.79 MWD+IFR+MS 4195.29 21.90 294.76 4170.28 4099.82 -29.53 -158.70 5938636.26 674541.27 MWD+IFR+MS 4290.18 24.88 299.42 4257.37 4186.91 -12.30 -192.16 5938652.70 674507.41 MWD+IFR+MS 4383.44 27.84 303.74 4340.93 4270.47 9.43 -227.37 5938673.62 674471.72 MWD+IFR+MS 4479.22 31.03 305.28 4424.34 4353.88 36.12 -266.13 5938699.39 674432.35 MWD+IFR+MS 4574.57 33.63 307.76 4504.91 4434.45 66.49 -307.07 5938728.80 674390.72 MWD+IFR+MS 4668.57 36.63 307.60 4581.78 4511.32 99.54 -349.88 5938760.86 674347.16 MWD+IFR+MS 4764.39 40.02 308.80 4656.94 4586.48 136.30 -396.55 5938796.52 674299.65 MWD+IFR+MS 4859.63 42.84 310.82 4728.34 4657.88 176.67 -444.93 5938835.75 674250.35 MWD+IFR+MS 4954.41 47.08 311.74 4795.39 4724.93 220.85 -495.24 5938878.76 674199.04 MWD+IFR+MS 5048.05 47.69 312.81 4858.79 4788.33 267.21 -546.22 5938923.92 674147.00 MWD+IFR+MS 5142.55 48.11 312.12 4922.15 4851.69 314.55 -597.95 5938970.04 674094.19 MWD+IFR+MS 5236.69 48.35 312.74 4984.86 4914.40 361.92 -649.77 5939016.20 674041.29 MWD+IFR+MS 5329.86 48.58 311.85 5046.64 4976.18 408.85 -701.36 5939061.92 &73988.63 MWD+IFR+MS 5424.28 48.91 313.32 5108.90 5038.44 456.88 -753.61 5939108.72 673935.28 MWD+IFR+MS 5520.27 49.59 312.20 5171.56 5101.10 506.25 -807.01 5939156.84 673880.76 MWD+IFR+MS 5615.25 50.76 313.13 5232.39 5161.93 555.69 -860.64 5939205.02 673826.00 MWD+IFR+MS 5709.47 50.50 311.79 5292.16 5221.70 604.86 -914.37 5939252.92 673771.15 MWD+IFR+MS 5804.56 50.17 311.26 5352.86 5282.40 653.38 -969.17 5939300.17 673715.24 MWD+IFR+MS 5898.27 48.60 310.06 5413.86 5343.40 699.74 -1023.13 5939345.25 673660.23 MWD+IFR+MS 5992.61 46.90 309.36 5477.29 5406.83 744.36 -1076.84 5939388.61 673605.50 MWD+IFR+MS 6085.56 47.60 309.60 5540.38 5469.92 787.75 -1129.52 5939430.77 673551.83 MWD+IFR+MS 6179.80 47.55 310.96 5603.96 5533.50 832.73 -1182.59 5939474.50 673497.74 MWD+IFR+MS 6275.31 48.68 308.80 5667.73 5597.27 878.30 -1237.16 5939518.80 673442.13 MWD+IFR+MS 6369.37 47.39 306.72 5730.63 5660.17 921.14 -1292.43 5939560.34 673385.88 MWD+IFR+MS 6466.13 46.00 309.87 5797.00 5726.54 964.74 -1347.70 5939602.65 673329.63 MWD+IFR+MS 6560.04 46.08 314.10 5862.20 5791.74 1009.94 -1397.92 5939646.67 673278.38 MWD+IFR+MS 6604.08 46.79 314.75 5892.56 5822.10 1032.28 -1420.71 5939668.47 673255.08 MWD+IFR+MS 6652.43 46.71 315.69 5925.68 5855.22 1057.28 -1445.51 5939692.89 673229.70 MWD+IFR+MS 6747.42 46.77 315.60 5990.78 5920.32 1106.74 -1493.88 5939741.21 673180.21 MWD+IFR+MS 6842.23 46.15 314.79 6056.09 5985.63 1155.50 -1542.30 5939788.84 673130.67 MWD+IFR+MS 6936.97 47.65 314.31 6120.82 6050.36 1204.03 -1591.60 5939836.20 673080.26 MWD+IFR+MS 7031.81 47.67 315.08 6184.70 6114.24 1253.33 -1641.43 5939884.34 673029.30 MWD+IFR+MS 7124.39 47.74 314.98 6247.00 6176.54 1301.78 -1689.83 5939931.65 672979.80 MWD+IFR+MS 7216.67 48.77 313.52 6308.45 6237.99 1349.82 -1739.15 5939978.52 672929.38 MWD+IFR+MS 7310.70 48.83 313.64 6370.38 6299.92 1398.59 -1790.40 5940026.09 672877.02 MWD+IFR+MS 7406.88 48.61 315.07 6433.84 6363.38 1449.11 -1842.08 5940075.41 672824.18 MWD+IFR+MS 7501.05 48.85 310.04 6495.98 6425.52 1496.95 -1894.19 5940122.02 672770.98 MWD+IFR+MS Sperry Drilling Services Survey Report Company: BP AmoCO Date. 11/28/2007 Time: 16:17:44 Page: 3 Field: Pru dhoe Bay ' _ Co-ordinate(NE) Reference: Well: 14-18, True North Site: PB DS 14 Vertcal(TVD) Refer ence: 41 .966E+28.5KBQa 70.46 70.5 .Well: 14- 18 Section (VS) Reference: Well (O.OON,O.OOE,303.80Azi) Weppath: 14- 18B Survey Calculation M ethod: Mi nimum Curvatu re Db: Oracle Survey IVID Inel ',Azim TVD Sys TVD N/S E!W b1apN MapE Tool ft deg deg ft ft ft ft ft ft 7594.04 48.14 309.17 6557.60 6487.14 1541.35 -1947.85 5940165.16 672716.32 MWD+IFR+MS 7688.64 48.61 310.79 6620.44 6549.98 1586.78 -2002.03 5940209.32 672661.11 MWD+IFR+MS 7783.25 48.10 311.20 6683.31 6612.85 1633.16 -2055.39 5940254.45 672606.69 MWD+IFR+MS 7878.58 47.90 311.64 6747.10 6676.64 1680.03 -2108.51 5940300.07 672552.49 MWD+IFR+MS 7973.51 47.14 311.10 6811.21 6740.75 1726.30 -2161.05 5940345.11 672498.90 MWD+IFR+MS 8068.20 48.53 312.21 6874.77 6804.31 1772.95 -2213.48 5940390.53 672445.41 MWD+IFR+MS 8161.98 48.57 312.65 6936.85 6866.39 1820.38 -2265.37 5940436.74 672392.44 MWD+IFR+MS 8256.48 47.84 312.46 6999.83 6929.37 1868.02 -2317.26 5940483.16 672339.46 MWD+IFR+MS 8350.57 47.45 312.93 7063.22 6992.76 1915.17 -2368.37 5940529.11 672287.28 MWD+IFR+MS 8444.69 50.02 313.25 7125.29 7054.83 1963.50 -2420.02 5940576.23 672234.52 MWD+IFR+MS 8539.84 49.27 313.11 7186.90 7116.44 2013.12 -2472.90 5940624.60 672180.51 MWD+IFR+MS 8634.08 48.59 313.07 7248.82 7178.36 2061.65 -2524.78 5940671.92 672127.52 MWD+IFR+MS 8729.25 47.25 311.09 7312.60 7242.14 2109.00 -2577.19 5940718.03 672074.03 MWD+IFR+MS 8824.29 45.32 310.03 7378.28 7307.82 2153.67 -2629.37 5940761.48 672020.83 MWD+IFR+MS 8918.05 43.90 306.08 7445.03 7374.57 2194.26 -2681.18 5940800.86 671968.10 MWD+IFR+MS 9013.36 43.45 304.75 7513.97 7443.51 2232.40 -2734.82 5940837.75 671913.60 MWD+IFR+MS 9108.42 43.98 303.82 7582.68 7512.22 2269.41 -2789.10 5940873.48 671858.48 MWD+IFR+MS 9202.78 45.46 298.19 7649.75 7579.29 2303.54 -2845.98 5940906.29 671800.83 MWD+IFR+MS 9298.80 45.63 292.67 7717.03 7646.57 2332.95 -2907.83 5940934.25 671738.31 MWD+IFR+MS 9393.80 45.29 290.69 7783.66 7713.20 2357.96 -2970.75 5940957.80 671674.84 MWD+IFR+MS 9488.35 46.83 289.32 7849.27 7778.81 2381.24 -3034.72 5940979.59 671610.35 MWD+IFR+MS 9582.85 46.65 289.04 7914.03 7843.57 2403.85 -3099.72 5941000.68 671544.85 MWD+IFR+MS 9676.53 47.03 287.61 7978.12 7907.66 2425.33 -3164.59 5941020.66 671479.51 MWD+IFR+MS 9771.01 47.19 288.56 8042.42 7971.96 2446.82 -3230.39 5941040.61 671413.23 MWD+IFR+MS 9864.22 48.08 291.63 8105.24 8034.78 2470.49 -3295.04 5941062.77 671348.05 MWD+IFR+MS 9958.39 46.82 291.71 8168.92 8098.46 2496.10 -3359.51 5941086.89 671283.00 MWD+IFR+MS 10052.56 45.82 292.35 8233.95 8163.49 2521.65 -3422.65 5941110.96 671219.30 MWD+IFR+MS 10147.78 47.81 292.52 8299.11 8228.65 2548.14 -3486.82 5941135.96 671154.54 MWD+IFR+MS 10243.29 46.75 293.05 8363.91 8293.45 2575.32 -3551.51 5941161.62 671089.24 MWD+IFR+MS 10337.12 45.43 294.39 8428.98 8358.52 2602.50 -3613.40 5941187.36 671026.74 MWD+IFR+MS 10432.33 46.26 290.39 8495.32 8424.86 2628.49 -3676.54 5941211.89 670963.02 .MWD+IFR+MS 10526.31 47.25 284.10 8559.74 8489.28 2648.74 -3741.86 5941230.61 670897.25 MWD+IFR+MS 10621.46 47.17 279.59 8624.39 8553.93 2663.06 -3810.17 5941243.35 670828.63 MWD+IFR+MS 10652.33 47.11 279.55 8645.39 8574.93 2666.83 -3832.48 5941246.60 670806.24 MWD+IFR+MS 10751.05 47.23 284.22 8712.53 8642.07 2681.73 -3903.28 5941259.85 670735.11 MWD+IFR+MS 10844.47 47.41 293.92 8775.94 8705.48 2704.13 -3968.04 5941280.74 670669.86 MWD+IFR+MS 10939.91 45.60 291.83 8841.63a 8771,17 2731.05 -4031.82 5941306.18 670605.48 MWD+IFR+MS 11034.80 46.17 293.11 8907.68 ~ 8837.22 2757.09 -4094.76 5941330.75 670541.95 MWD+IFR+MS 11092.48 47.21 292.24 8947.25 8876.79 2773.27 -4133.49 5941346.03 670502.86 MWD+IFR+MS 11130.00 47.21 292.24 8972.74 8902.28 2783.69 -4158.98 5941355.86 670477.14 PROJECTED to TD 10-Jan-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 14-18B Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 3,499.46' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 11,130.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~~ Signed _ ~J Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~~ -' ~`~ 11/12/07 ~~ J Schfamb~rg~r N0.4496 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Lisburne Well _Inh i! 1 nn nnmrrlnHnn n~a., o~ r..i... rn L3-08 11637143 LDL - 10/27/07 1 L3-08 11637143 LDL -. < 3 10I28I07 1 N-12 11626132 LDL ( (-~(~ 11/03/07 1 14-18B 11637368 ISOLATION SCANNER '~-- 10126/07 1 NGI-13A 11637144 CEMENT BOND & IMAGE LOG 10/28/07 1 GNI-04 11676971 USIT ~-- J'~- 11/05/07 1 1'LGMJC MVn1YVYYLCUbC RCliClr'1 6T JWn111VV HMV KCIUKIVIIVV VNt G(JYY tAl:Ft IU: BP Exploration (Alaska) Ina ~ • I ~ f ~~: Petrotechnical Data Center LR2-1 ~', ~ ";~ „ `~ . i~ - Xr ro- +-~ ~', 900 E. Benson Blvd. Anchorage, Alaska 99508 $(~' jr yN Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: L_ ` / • ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Hobbs, Greg S (ANC) [Greg.Hobbs@bp.com] Sent: Tuesday, October 02, 2007 3:48 PM To: Maunder, Thomas E {DOA) Cc: Nigh, Jim Subject: RE: DS 14-188 Tom- Sorry for the late reply- Thanks for the call also. Iran through the calculations and concur with 544 sacks of the 12.5 slurry for the 7" lead cement job. Sorry I did not re-calculate in the initial a-mail. Thanks for the help- Greg From: Maunder, Thomas E (DOA) {mailto:tom.maunder@alaska.gov] Sent: Tuesday, October 02, 2007 9:42 AM To: Hobbs, Greg S (ANC) Cc: Nigh, Jim Subject: RE: DS 14-18B Thanks Greg. With the yield change on the 7" lead slurry, will the sack count be reduced? Keeping the slurry volume at 218 bbl, I calculate 544 sx at 2.25 yield. Thanks in advance, Tom Maunder, PE AOGCC From: Hobbs, Greg S (ANC) [mailto:Greg.Hobbs@bp.com] Sent: Monday, October Ol, 2007 4:15 PM To: Maunder, Thomas E (DOA) Cc: Nigh, Jim Subject: RE: DS 14-18B Tom- The yield for the 12.5 ppg lead slurry on the 7" is 2.25 cult/sk. As far as the 4 1/2" liner, it will have a 150' overlap with the 7" for a top at a minimum of 10673' MD. The permit document captures the start of the 6 118" hole section, not the liner top. Sorry it took me a bit to get to this- Ifthere are further questions, let me know. Greg 10/3/2007 . • Page 2 of 2 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, September 28, 2~7 2:31 PM To: Nigh, Jim Cc: Hobbs, Greg S {ANC) Subject: DS 14-18B Jim, I am reviewing the application. 1. Would you check the 4-1/2" liner top as listed on the 401? It appears no overlap is allowed. The summary on page 3 does not indicate any overlap either. 2. On the lead slurry for the 7°. Is the yield correct? 1.16 seems a little kwv fora 12.5 ppg sluny. I may have other questions as i review further, however I wanted to get this out Call or message with any questions. Tom Maunder, PE AOGCC 10/3/2007 r~ U O SARAH PAUN, GOVERNOR L>•i/A-71~ OTij ~ ~ 333 W. 7th AVENUE, SUITE 100 C011T5ER~Ati.'I011T COMl~II5SIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Senior Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 14-18B BP Exploration Alaska, Inc. Permit No: 207-129 Surface Location: 1659' FNL, 1784' FEL, SEC. 09, T11N, R14E, UM Bottomhole Location: 1217' FSL, 740' FEL, SEC. 05, TlON, R14E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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). Sincerely, Dan T. Seamount Commissioner DATED this ~ day of October, 2007 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. - STATE OF ALASKA y_/~D~ R~~~~~~ ALASK~L AND GAS CONSERVATION COMMIS~IN ,t~~'._ PERMIT TO DRILL f"' ~~'"~-- ~~~~ ~ 9 2007 20 AAC 25.005 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well i~s propos o : ' ^ Coalbed Methane ^ (mss ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 14-18B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11589 TVD 9107 12. Field /Pool(s): Prudhoe Bay Field !Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1659' FNL 1784' FEL SEC R14E UM 09 T10N 7. Property Designation: ADL 028313 Pool , , . , , , Top of Productive Horizon: 1225' FSL, 1059' FEL, SEC. 05, T10N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: October 10, 2007 Total Depth: 1217' FSL, 740' FEL, SEC. 05, T10N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 17,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-674699 y-5938669 Zone-ASP4 10. KB Elevation Plan (Height above GL): 69.7 feet 15. Distance to Nearest Well Within Pool: 74' 16. Deviated Wells: Kickoff Depth: 4300 feet Maximum Hole An le: 55 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3300 Surface: 2420 18:? Casin iPr ram; S fica io ns To - Settin h =Bo ttom uantit of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD 5 includin sta a data 8-1 /2" 7" 26# L-80 BTC-M 6823' 4150' 4150' 10823' 8677' sx Class 'G' 91 sx C ss 'G' 6-1/8" 4-1/2" 12.6# 13Cr VamTo 767' 10823' 8677' 11590' 9107' 131 sx Class'G' ~ 19: PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill'and Re-entry Operations) Total Depth MD (ft): 10815 Total Depth TVD (ft): 8740 Plugs (measured): None Effective Depth MD (ft): 10773 Effective Depth TVD (ft): 8740 Junk (measured): None Casing Length ize Cement Volume MD TVD Conductor /Structural 0' 20" 300 sx Permafrost 80' 80' Surface 2651' 13-3/8" 2615 sx Fondu 400 sx AS II 2651' 2651' Intermediate 9266' 9-5/8" 500 sx Class 'G' 9266' 8707 Prod cti n Liner 372' 7" 450 sx Class'G' 8913' - 9285' 8417' - 8721' Liner 1090' 3-1/2" x 3-3/16" 140 sx Class LARC 8898' - 9988' 8405' - 8766' Liner 18 2-3/ " Uncement d Slo d Liner 9886' - 0804' 8766' - 8740' Perforation Depth MD (ft): Slotted: 10266' - 10773' Perforation Depth TVD (ft): 8750' - 8740' 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Jim Nigh, 564-5220 Printed Name Greg bb ~ Title Senior Drilling Engineer Prepared By Name/Number: Si nature Phone 564-4191 Date ~~ `' „a Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: ~ API Number: 50-029-20551-02-00 Permit A proval See cover letter for Date: oth r re uirements Conditions of Approval: 1 If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: a1 Samples Req'd: ~ Yes ~ No Mud Log Req'd: Yes L1J No HZS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No Other: 350 ~~ ~ ~3~~ ~~~ ~-- D ~ APPROVED BY THE COMMISSION Date ,COMMISSIONER Form 10-401 Devised'~2/200$ / ~ Submit In Duplicate ORIGINAL ~~~- Ilan To: Alaska Oil & Gas Conservation Commission From: Jim Nigh Date: September 17, 2007 Re: 14-18B Sidetrack Permit to Drill The 14-18B sidetrack is scheduled to be drilled by Nabors Rig 2ES in October The purpose of this sidetrack is to create offtake in the Sag River Formation. This new sidetrack will replace 14-18A, which has been a long term shut-in well since 2000 The Ivishak reservoir (e.g. Z4) will be completed if it turns out to be economically attractive. Should the Ivishak reservoir be completed, the Sag target will be preserved as a future CTD candidate. N2ES will pull the existing tubing string before the well is sidetracked at 4,300' to the 8.5" TD at -10,973' to top set the Sag River. A 7" liner will be run, fully cemented. A 6-1/8" pilot hole will be drilled out of the 7" shoe down to the Ivishak. Depending on the logging results, the Asset Team may case and produce this pilot hole (via cemented and perforated solid liner) or plug it back with cement and drill horizontally into the Sag for 2,500' to a TD of 13,481' MD (Should this Sag River horizontal contingency occur, it will be permitted separately). This horizontal production hole would be completed with a 4-1 /2"slotted liner. A 4- 1/2" chrome tubing string will be run for production in either scenario. 14-18B Well Plan Summary Well 14-18B Well Sidetrack / Target Ivishak Type Producer Ob'ective AFE Number: PBD4P2621 API Number: 50-029-20551-02 f S Northin Eastin Offsets TRS ur ace Location 5938669 674699 1659' FNL / 3496' FWL Sec 9, T10N, R14E Northing Easting Offsets TRS TVDSS Target 4054' FNL / 4220' Sec 5, Location 1 5941448 670072 FWL T10N, -8681 R14E Northing Easting Offsets TRS TVDSS Target 4250' FNL / 4866' Sec 5, Location 2 5941267 670722 FWL T10N, -8719 R14E 14-18B Sidetrack Page 1 ~ ~ Northing Easting Offsets TRS TVDSS Bottom ' ' Sec 5 Location 5941447 670391 4062 FNL / 4540 , T10N -9036 FWL , R14E Planned KOP: 4300' MD Planned S ud: 10/10/07 Planned Lateral TD: 11,589' Planned Lateral TVD: 9,107' TVD Ri Nabors 2ES GL: 41.2' RTE: 69.7' Directional Program Approved Well plan: W P8 Exit oint: 4300' MD / 4300' TVD Maximum Hole Inclination: ~55° from 11,035' to 11,100' Proximity Issues: All proximity issues will be minor risked (1:200) Survey Program: Gyro orientation will not be required for the initial kick-off (since > 7 de rees). Standard MWD+IIFR+MS. Nearest Well: 14-24, 73.55' Nearest Property Line 17,000' Logging Program Hole Section: Required Sensors /Service 9-5/8" Cased hole USIT to in to determine corrosion and to of cement 8-1/2" Intermediate: DIR/GR/RES/PWD 6-1/8" Production: DIR/GR/ABI/RES/Az Dens/Neu/Stratasteer Mud Program Hole Section /operation: 8-1/2" Intermediate Hole Type: Fresh Water LS ND Depth (ft) Density ( ) PV yp API FL (ml/30min MBT pH 4300-9450 9.5 - 9.8 10 - 18 18 - 28 4.0 - 7.0 < 20 9 - 10 9450-11030 11.5 12 - 22 18 - 28 4.0 - .60 < 20 9 - 10 Hole Section /operation: 6-1/8" Production Interval Type: FloPro SF Depth (ft) Density (ppg) PV YP LSRV MBT pH 11030-11650 8.5 6 - 12 22 - 28 > 20,000 < 4 9.0 - 9.5 14-18B Sidetrack Page 2 Casing /Tubing Program Hole Casing/Tubing Wt. Grade Connection Length Top Bottom Size Size (MD /TVD (MD /TVD) 8-1/2" 7" Drl Liner 26# L-80 BTC-M 6823' 4150' / 4150' 10823' / 8677' 6.1/8„ 4-1/2" Solid 12.6# 13Cr VamTop 767' 10823' / 8677' 11590' / 9107' Liner Tubin 4-1/2" 12.6# 13Cr VamTo 10823' Surface 10823' / 8677' Cementing Program Casing String: 7", 26#, L-80, BTC-M Intermediate Liner Lead slurry: Remainder of 8-1/2" x 7" annulus with 40% excess, plus 150' of 9-5/8" X 7" liner lap. Slurry Design Basis: Tail slurry: 500' of 8-1/2" x 7" annulus with 40% excess, plus 80' of 7", 26# shoe track. Pre-Flush TBD Fl id S /V l S acer TBD :a- u s equence o ume: ` ' Lead Slurr 218 bbl / 1224 ft / sx Class , 12.5 ft /sk. G Tail Slurr 19 bbl / 106 ft / 91 sx Class `G', 15.8 ; 1.16 ft /sk. Casing String: 4-1 /2", 12.6#, 13CR, Solid Production Liner Lead slurry: None planned. Slurry Design Basis: Tail slurry: 620' of 6-1 /8" x 4-1/2" annulus with 40% excess, plus ~80' of 4- 1/2" shoe track, lus 150' of 7" x 4-1/2" liner la annulus. Pre-Flush TBD Fl id S /V l S acer TBD u s ume: equence o Lead Slurr None tanned. Tail Slurr 27 bbl / 151 ft / 131 sx Class `G', 15.8 ; 1.16 ft /sk. Formation Integrity Testing Test Test Point Test Type Test pressure 9-5/8" Window 20' beyond mid-window FIT 11.7 ppg EMW 7" Shoe 20' beyond shoe FIT 10.0 ppg EMW Well Control Well control equipment consisting of 5,000psi working pressure pipe rams, blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8'h" intermediate interval Maximum antici ated BHP: 3,198psi at 8606' TVD Maximum surface ressure: 2,337psi (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) Calculated kick tolerance: 56 bbls with 11.7 ppg EMW FIT Planned BOPE test pressure: 250psi low / 3,500psi high - 7 day test cycle until a window is milled in 9- 5/8" casin . Once a window is milled a 14 da test c cle can commence. 14-18B Sidetrack Page 3 Well Interval: 6-1/8" production liner section Maximum anticipated BHP: 3300psi at 8800' TVD MaXimum SUrfaCe preSSUre: 2420pS1 (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) Calculated kick tolerance: Infinite with 10.0 ppg EMW FIT Planned BOPE test pressure: 250psi low / 3500psi high Planned com letion fluid: 8.8ppg seawater / 7.1 ppg Diesel Disposal Annular Injection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo e Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 ~ for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. Geologic Prognosis Est. Formation Tops UrT.certainty Commercial Hydrocc~rbo n Bearing Est. Pore Press. FOYY12C6t1012 (TVDss) (feet) (Yes/No) (Psi) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation to s are re uired from surface to TD for all new wells S V 4 -2595 SV 1 -3715 UG4 -4330 +/- 30' n UG3 -4495 +/- 30' n UG 1 -5140 +/- 30' n WS2 -5685 +/- 30' n WS1 -5950 +/- 50' n CM3 -6180 +/- 50' CM2 -6675 +/- 50' n CMI -7280 +/- 50' n THRZ -7695 +/- 50' n BHRZ -7860 +!- 50' n LCU -7895 +/- 50' n TKNG -7895 +/- 50' n TJB -8419 +/- 50' n TSGR -8606 +/- 30' 3198 TSHU -8635 +/- 30' n 3206 TSAD/TZ4B -8715 +/- 30' y 3234 TZ4A NR +/- 30' y TD -8655 +/- 30' GOC / MGOC assumed to be -8575 MHOT NR MOWC NR 14-18B Sidetrack Page 4 Fault Prognosis 1 2 3 4 5 6 o~'~~ 7 8 9 ~30~- 10. Displace to 9.5 ppg fresh water LSND milling fluid (per MI). 11. Mill window in 9-5/8" casing at ± 4,300 MD, plus approximately 20' from mid window. Circulate well bore clean. 12. Pull up into 9 5/8" casing and conduct an FIT to 11.7 ppg EMW. POOH. 13. M/U 8-1/2" Dir/GR/RES/PWD RSS w/ gamma at bit assembly. 14. RIH to window. Drill ahead to top of Sag River per directional plan to the 7" casing point, allowing mud weight to increase to 9.8ppg. May have to trip for a new bit (pre-planned contingency). Mud wt. ~~~~ ~~ should be weighted up to 11.5 ppg 150' before drilling HRZ. ~~~,~~" 15. Circulate the well bore clean. Short trip, circulate the well bore. POOH, UD assembly. 16. Change out to 7" rams and test. 17. RU / MU /RIH 7" liner to bottom on drill pipe, circulate and condition the hole Formation ~~7iere Fucomxer Fault ftMD Intersect ftTYDSS Intersect Est. Throw ft Throw Direction Uncertainty Fault#1 Outside Polygon Fault #2 is intersected by the well lei 11816 8620 10-20 E +.~- '150 ftMD Fault #3 is intersected t~ the well lan 12933 8625 15-25 \''J +l- 150 ftMD Fault #4 Outside Polygon Fault #5 Outside Polygon t'oirunents Estimation of fault intersection locations were made using the 14-1 &B_SS_wp04 trajectory. Actual values will depend on the final drilled :trajectory and depth uncertainty. Faulk. ('aar[liuazrs foi 1tila ~ riu~ x 1` ftNDSS Fault #1 First Point Outside Polygon Fault#1 SecundPoint. Outside Polygon Fault #2 First Point 670072 5941448' 8610 Fault#2 Second Point 670038 5941083 8625 Fault#3 First Point 668$86 5941409 8610 Fault#3 Second Point 668919 5940925 8625 Fault #4 First Point Outside Polygon Fault #1i Second Point Outside Polygon Fault#~ First Point Outside Polygon Fault#5 Second Point Outside Polygon Rig Operations: MI / RU Nabors rig 2ES. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. Set TWC. Nipple down tree and adaptor. Nipple up and test BOPE to 3,500 psi. Pull TWC. Back out lockdown screws, pull hanger (WSL may want a spear on location). Pull 4-1/2" tubing from the pre-rig cut at 6,000' MD. P/U drill pipe. MU/PU scraper assembly. RIH, picking up DP, to the 4-1/2" tubing stub, and circulate the well bore with 9.8ppg brine. RU E-line, run USIT. USIT results will be used to determine the 9-5/8" cement picture and to evaluate the condition of the 9-5/8". Note: According to available well file data, there appears to be no cement behind the 9-5/8" casing at the 4,300' planned KOP. Rig up E-line, MU a 9-5/8" EZSV on DP, RIH and set at 4,330' MD, test to 4000 psi. PU 9 5/8" whipstock and TIH to EZSV at 4,325', orient and set whipstock on bridge plug. Shear off whipstock, POOH. 14-18B Sidetrack Page 5 18. Cement the entire 7" liner through the 8-1/2" hole a minimum of 150' across the 7" x 9-5/8" lap at 4,300'. Set the hanger and packer. Displace cement with mud. Cementing will be done in two stages. 19. Circulate bottom up, POOH. L/D liner running tool. 20. Change out to variable rams and test. 21. MU clean-out assembly. 22. RIH to HES cementer and test casing to 3,500 psi. 23. Drill out of HES cementer and test casing to 3,500 psi. 24. RIH to 7" liner landing collar. Drill out of the cement and float equipment to shoe. Test casing to 3,500 psi, record the test. 25. Displace to 8.5 ppg Flo Pro drilling fluid. 26. POOH for directional drilling BHA. 27. MU 6-1/8" BHA with DIR/GR/RES/Az Den-Neu/Near bit gamma on a bent motor. 28. RIH, and drill out of the 7" shoe plus 20' of new formation. Pull up into the shoe and conduct FIT. 29. Drill hole to TD in the Ivishak formation. 30. CBU, Short trip, circulate and condition the hole. POOH. 31. Based on this hole section's evaluation results (whether or not it has been water `swept'. Ref SOR Section 7) and the ODE's direction, execute one of these two options: a. Complete Ivishak Pilot hole with a cemented and perforated, solid liner b. Plug back pilot hole with cement, kick off, and drill horizontally in the Sag River Option A -Complete Ivishak Production Hole 32. Run and cement a 4-'/z", 12.6#, L-80 IBT-M solid liner. Ensure that there is 150' of overlap from the 7" shoe. Set liner hanger and liner top packer. Displace well to clean seawater above the liner top. 33. RU Schlumberger and RIH w/TBD' 2-'/8" 2906 Powerjet guns set @TBD SPF. Tag PBTD. 34. Put guns on depth and fire. POOH and verify all shots fired. 35. Skip to `COMPLETION' section of operations Option B -Plug back pilot hole with cement, kick off, and drill horizontally in the Sag River (A new permit will be submitted if this course of action is decided upon) 36. RU SLB Cementer. RIH and plug back pilot hole. 37. POOH for 6-1/8" horizontal BHA with a PDC bit and ABI/GR/Res/Az Den-Neu/Stratasteer/near bit gamma on bent motor. 38. RIH to the bottom, kickoff cement plug, drill ahead build section. Trip for new motor. 39. RIH with less aggressive bend motor, drill horizontal section to planned TD per directional. 40. CBU, Short trip, circulate and condition the hole for running the 4-1/2" slotted liner. POOH, UD excess drill pipe. Clear the floor of unnecessary equipment. 41. RU, MU TBD length of 4-1/2" slotted liner plus TBD length of blank 4-1/2" 12.6#, L-80, BTC-M liner for overlap into the 7" liner. 42. RIH to shoe, circulate string. RIH to bottom, circulate and condition the hole. 43. Release, set packer, circulate bottom up. 44. POOH. L/D liner running tool. 45. RU, test BOPE if needed. 46. Test casing and liner. 47. Continue to `COMPLETION' section of operations COMPLETION 48. R/U, M/U TBD length (depending on whether Option A or B is executed) of 4-1/2" 13CR, Vam Top completion tubing. 49. RIH, space and land the completion tubing into the 4-1 /2" liner top, RILDS. 50. Reverse circulate to seawater and corrosion inhibitor. 51. Drop ball and rod, set packer. 52. Test tubing and annulus separately to 4,000 psi each, record the test. 53. Install and test TWC. 54. Nipple down BOPS 55. Nipple tree and adaptor flange, test tree to 5,000 psi. Pull TWC. 56. Reverse in diesel freeze protect to _2,200' U-tube. Install BPV. 57. Secure well. Release rig. 14-18B Sidetrack Page 6 Post-Rig Operations: 1 O Install wellhouse and flowlines. New S-riser will be manufactured. 2 S MIRU slick line. Pull the ball and rod / RHC plug from `XN' nipple. Install gas lift valves. 14-18B Sidetrack Page 7 14-18B Potential Drilling Hazards (Post on Rig) • Pre-job HAZOP's and Safety meetings are recommended when there is a clear change in work scope. If at any time things don't feel or look right, STOP the job and discuss the situation before making the next move. • Flash Points o Dead Crude= <40degF o Methanol (neat)= 52degF o Diesel=100degF • Hydrogen Sulfide o DS 14 is designated as an H2S site since 14-06, 14-07, 14- 22, 14-31, 14-37, and 14-41 all have H2S readings between 100 and 300ppm o Standard Operating Procedures for H2S precautions should still be followed at all times. • Bottom Hole Pressure 0 3250 psi @ 9188' TVD • Maximum anticipated wellhead pressure: 0 2420 psi w/full column of gas • Potential for loss circulation o High • Close Approaches (awaiting gyro run data on both of these wells for increased reliability of tolerances) o X-15A - 143' ctr - ctr 12,140' MD 0 14-19 - 122' ctr - ctr 7,276' MD 14-18B Sidetrack Page 8 TREE= GRAY GEN 2 WELLHEAD= GRAY ACTUATOR= AXELSON KB. ELEV = 71' BF. ELEV - KOP = 5300' Max Angle = Datum MD = 99 ~ 10227' 9558' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I~ 2651' 4-1/2" TBG-IPC, 12.6#, L-80, 0.0152 bpf, ID = 3.958" I~ $$7 j' TOP OF 4-1/2" TBG-CR 8875' ITOPOF3-1/2" LNR ~ 8$98' TOP OF 7" LNR 8913' Minimum ID = 1.995" (~ 9886' GS FISHING NECK I4-1/2" TBG, 12.6#, 9-CR, 0.0152 bpf, ID = 3.958" I 8960' 3-1/2" LNR, 8.8#, L-80, FL4S, .0087 bpf, ID = 2.992" 9254' TOP OF3-3/16" LNR 9254' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9266' ~TOPOF2-3/8" LNR ~ 9886' 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID= 2.80" 9986' PERFORATION SUMMARY REF LOG: JEWELRY 10G ON 08/28/98 ANGLE AT TOP PERF: 98 ~ 10266' Note: Refer to R~oduction DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 2-3/8" 2 10266 - 10773 O 05/15/99 14' 1 ~~ AFETY NOTES: 70° @ 9397' AND 90° ~ 9468' 2263' --I 4-1l2 OTIS HRQ SV LN NIP, ID = ? GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3074 3074 0 MMG RK 2 5607 5595 19 MMG RK 3 7537 7284 32 MMG RK 4 8220 7854 36 MMG RK 5 8746 8280 35 MMG RKP 8776' --I 4-1 /2" PARKER SWS NIP, ID = 3.813" 8836' 9-5/8" X 4-1/2" BAKER SB-3A PKR $$76' 4-1/2" PARKER SWS NIP, ID = 3.810" $$9$' 3-1/2" BAKER SETTING SLV 8944' 4-1/2" PARKER SWN NIP, ID = 3.73" (BEHIND LNR) 8960' -1 4-1/2" TUBING TAIL (BEHIND LNR) 8965' ELMD TT LOGGED 08/28/98 9~ 3-1/2" X 3-3/16" XO 7 " MILLOUT WINDOW ~ 9289' PBTD I-I 10773' I I PRE-DRLD LNR, 4.6#, .0037 bpf, ID = 1.995" ~~ 10266' 2-3/8" LNR, 4.6#, A037 bpf, lD= 1.995" 1080+4' I 10815' I DATE REV BY COMMENTS DATE REV BY COMMENTS 1981 ORIGINAL COMPLETION 04/13/98 RIG SIDETRACK 05!15/99 CTD HORIZ SIDETRACK 02/27/02 RN/TP CORRECTIONS 09/24/03 BHGKK LINER TOP CORRECTION PRUDHOE BAY UNff WELL: 14-18A PERMff No: 1980070 API No: 50-029-20551-01 SEC 9, T10N, R14E, 5132.29 FEL 1881.93 FNL BP Exploration (Alaska) 14-18B Proposed Compl~n AFETY NOTES: 70° ~ 9397' AND 90° ~ 9468' TREE = GRAY GEN 2 -2,250' ':- TOC from downsgeeze - __ -2,200' -4-1/2" BKR Landing Nipple - -- 1 2,651' -13-318" CSG, 72#, N-80,ID-12.347" -- - __ -4,300' - KOP -4,325' 9-5/8" BKR Whipstock _ ~~ - - -- ~4,330' - 9-5/8" HES CIBP 4-1/2" 13CR-80 VAM Top TBG' 7" Csg, 26#„ L-8Q BTC-M - 11 ,Q3Q''~ 10,843' ',HES 4-1/2" X Nipple io=s.813° - - - 10~853' ',- - 7" x 4-1/2" BKR PKR _ _10,880' I - I HES 4-1/2" X Nipple, ID=3.813" 10 900' , - HES 4-1/2" XN Nlpple ID=3 7zs' 000'' 6 , - , , 10 90T : H~cn er/Liner Top Packer Top of 4 1/2_' TBG Cut. 10,910' - --' 4-1/2" WLEG ~' _ _ __- - R R~6 ~- TOC' 4.5" 12.6#, Chrome Vam top Solid liner 11,650' 9,266` 9-5/8", 47#, L-80, ID=8.861" 9,886` ~--~ CIBP WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = BF. ELEV = 71' KOP = 4300' Max Angle = Datum MD Datum TVD = ST MD TVD DEV TYPE 6 3100 3100 5 5407 5000 4 7108 6150 3 8365 7000 2 9548 7800 1 10658 8550 DATE REV BY COMMENTS DATE REV BY COMMENTS 1981 ORIGINAL COMPLETION 04/13/98 RIG SIDETRACK 05/15/99 CTD HORIZ SIDETRACK 02/27/02 RN/TP CORRECTIONS 09/24!03 BHC/KK LINER TOP CORRECTION 08/21/07 JN PROPOSED ST BP Exploration (Alaska) FNL PRUDHOE BAY UNIT WELL: 14-18B PERMIT No: 1980070 API No: 50-029-20551-02 SEC 9. T10N. R14E, 5132-29 FEL 1881 • • ° ° _ F ° m g D nm. p . e m P ~ ~ ~ ~ _ i-. ~ ~ ~ P ~ I ~ v - I - I 1 1 1 - I _ ~ G c _ N ~ ° ^ ~ ~+ v,P 0000 --cm-. - ~ _ ~. ~ f I y ~ 3 x . > ~ ~.. ri~o~c N S C R v, , ~ i ~ . ~. ~ I i ~. ~ _ '. p' ~ U O O C ~ ~p ~ ~ m J v i ~ 3 ~ ^~ v O O O n O O O ooo~.,o,.,o I . 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U$ ~ ~ „ O F A c -m a•o o.n n rn rn- v n .n .o .novarv-ri oo oo .., .naowrv i o ~ ti M - v _i3~ ' v. m $ r ~ ~ ~ ~ O . p ~ .- a ,rva rvv ~n-rvrvrvc. o.ovc•ncm-rio aa•nrrv•n ORVrvind a~ooTP PPOOj- Q u p a ~ ~ _ -"' ~~r,-, 'v'° •1 ,•, O i~ ~N~V A~N~ ~ J ~ r ---- o ~ --- v~- ==-x~<x A ~ ~ oosoosooooaaoo=o = = o v~=v. - 3 ~ L ~ O .o-a-anon a.° -a .o- oa-~nrv~ncv, a.•~,aarn noao p r -r r> - /- rl r c = U / C`I ~ ~ ~ Q•nN1~Orvt~en l~P PPR ar•r Rahh•eaar,r r•rr`m mmm ~ oap ~ ~ -rvnR•nar Z rnR~n al~o°P--.~--- ~~.~~a P O O d C O 0 ~ o P j i o o n P v 00 Sperry-Sun BP Planning Report Company: BP Amoco Date: 9/14/2007 Time: 14:40:08 Pagc: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 14-1$ True North ...Site: PB DS 14 Vertical (TVI)) Reference: 37:18 4/811981 00:00 7 1.0 Well:. 1418 Section (VS) Reference:` Well (O.OON,O.OOE,304.1 4Azi) Wellpath: Piarr 14186 P61 Survey Calculation Method: 'Minimum Curvature Db: Oracle Plan: 14-186 Pb1 Wp 8.0 Date Composed: 3/13/2007 Version: 24 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope 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: PB DS 14 TR-10-14 UNITED STATES :North Slope Site Position: Northing: 5939577.43 ft Latitude: 70 14 26.346 N From: Map Easting: 674150.48 ft Longitude: 148 35 36.726 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.32 deg Well: 14-18 Slot Name: 18 14-18 Well Position: +N/-S -920.47 ft Northing: 5938669.45 ft Latitude: 70 14 17.293 N +E/-W 527.66 ft Easting : 674699.23 ft Longitude: 148 35 21.389 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 10973.02 8677.00 7.000 8.500 7" Formations MI) TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 SV4 0.00 0.00 0.00 SV1 0.00 0.00 4401.61 4401.00 UG4 0.00 0.00 4567.38 4566.00 UG3 0.00 0.00 5243.03 5211.00 UG1 0.00 0.00 5999.42 5756.00 WS2 0.00 0.00 6450.64 6021.00 WS1 0.00 0.00 6842.26 6251.00 CM3 0.00 0.00 7685.10 6746.00 CM2 0.00 0.00 8715.23 7351.00 CM1 0.00 0.00 9421.85 7766.00 THRZ 0.00 0.00 9702.80 7931.00 BHRZ 0.00 0.00 9762.39 7966.00 LCU 0.00 0.00 9762.39 7966.00 TKNG 0.00 0.00 10654.61 8490.00 TJB 0.00 0.00 10973.02 8677.00 TSGR 0.00 0.00 11022.85 8706.00 TSHU 0.00 0.00 11156.23 8786.00 TSAD/TZ46 0.00 0.00 Targets Map Map 4-- Latitude -> <-- Longitude --> Name Description TVD +N/-S +E/-W Northing Fasting Deg Min Sec Deg hlin Sec Dip. Dir. ft #t ft ft ft 14-186 Fault 1. 8681.00 2885.21 -4561.90 5941448.00 670072. 00 70 14 45.655 N 148 37 34.034 W -Polygon 1 8681.00 2885.21 -4561.90 5941448.00 670072. 00 70 14 45.655 N 148 37 34.034 W -Polygon 2 8681.00 2521.07 -4604.35 5941083.00 670038. 00 70 14 42.074 N 148 37 35.262 W -Polygon 3 8681.00 2885.21 -4561.90 5941448.00 670072. 00 70 14 45.655 N 148 37 34.034 W -Plan out by 726.26 at 8681.00 2661.06 -3871.09 5941239.94 670767. 77 70 14 43.455 N 148 37 13.944 W 14-18B PB1 T1 8719.00 2689.00 -3916.65 5941266.81 670721. 58 70 14 43.729 N 148 37 15.269 W -Plan hit target Sperry-Sun BP Planning Report Company: BP Amoco Date: 9/14/2007 Time 14:40:08 Page: 2 Field: Prudhoe Bay Co-ordinate{NE) Reference: Welh 14-18, True North Site: PB DS 14 Vertical (TVD) References 37:184/8/1981 00:00 71.0 Well: 14-18 Section (VS) Reference: Well (O.OON,t).OOE,304.14Azi) Wellpath: Plan 14-18B PB1 Survey Calculation Method: Minimum Curvature Db: OraGe Plan Section Information MD Intl' Azim TVD'` +N/-S +FJ-W DLS Build ' Turn TFO Target ff deg deg ft ft ft deg/100ft deg/t00ft deg/100ft deg 4250.00 0.63 165.00 4249.94 -15.52 -1.88 0.00 0.00 0.00 0.00 4270.00 2.37 80.03 4269.93 -15.56 -1.45 12.00 8.74 -424.87 260.00 4395.00 7.37 80.03 4394.44 -13.72 9.01 4.00 4.00 0.00 0.00 5882.85 54.03 303.70 5687.54 372.23 -438.92 4.00 3.14 -9.16 -139.57 10966.35 54.03 303.70 8673.09 2655.05 -3861.96 0.00 0.00 0.00 0.00 11045.43 55.00 300.00 8719.00 2689.00 -3916.65 4.00 1.22 -4.68 -73.30 14-186 PB1 T1 11589.21 33.25 300.00 9107.00 2877.16 -4242.55 4.00 -4.00 0.00 180.00 Survey MD ft 4250.00 4270.00 4300.00 4395.00 4400.00 4401.61 4500.00 4567.38 4600.00 4700.00 4800.00 4900.00 5000.00 5100.00 5200.00 5243.03 5300.00 5400.00 5500.00 5600.00 5700.00 5800.00 5882.85 5900.00 5999.42 6000.00 6100.00 6200.00 6300.00 6400.00 6450.64 6500.00 6600.00 6700.00 6800.00 6842.26 6900.00 7000.00 7100.00 7200.00 7300.00 7400.00 7500.00 ncl Azim TVD SysTVD VS N/S deg deg ft ft ft ft 0.63 165.00 4249.94 4178.94 -7.15 -15.52 2.37 80.03 4269.93 4198.93 -7.53 -15.56 3.57 80.03 4299.89 4228.89 -8.65 -15.29 7.37 80.03 4394.44 4323.44 -15.15 -13.72 7.22 78.99 4399.40 4328.40 -15.60 -13.60 7.17 78.65 4401.00 4330.00 -15.75 -13.56 4.98 46.86 4498.86 4427.86 -21.00 -9.43 4.94 15.30 4566.00 4495.00 -20.70 -4.63 5.42 1.84 4598.48 4527.48 -19.43 -1.74 8.12 336.06 4697.80 4626.80 -10.90 9.44 11.59 324.25 4796.32 4725.32 4.53 24.06 15.32 317.97 4893.56 4822.56 26.80 42.03 19.16 314.13 4989.05 4918.05 55.80 63.28 23.05 311.54 5082.33 5011.33 91.39 87.70 26.97 309.67 5172.94 5101.94 133.39 115.17 28.66 309.01 5211.00 5140.00 153.39 127.90 30.91 308.24 5260.44 5189.44 181.60 145.56 34.86 307.11 5344.40 5273.40 235.78 178.71 38.82 306.18 5424.41 5353.41 295.68 214.48 42.79 305.40 5500.09 5429.09 360.99 252.67 46.76 304.73 5571.06 5500.06 431.40 293.12 50.74 304.14 5636.98 5565.98 506.57 335.61 54.03 303.70 5687.54 5616.54 572.19 372.23 54.03 303.70 5697.61 5626.61 586.07 379.93 54.03 303.70 5756.00 5685.00 666.53 424.58 54.03 303.70 5756.34 5685.34 667.00 424.83 54.03 303.70 5815.07 5744.07 747.93 469.74 54.03 303.70 5873.80 5802.80 828.87 514.65 54.03 303.70 5932.53 5861.53 909.80 559.55 54.03 303.70 5991.26 5920.26 990.74 604.46 54.03 303.70 6021.00 5950.00 1031.72 627.20 54.03 303.70 6049.99 5978.99 1071.67 649.37 54.03 303.70 6108.72 6037.72 1152.61 694.27 54.03 303.70 6167.45 6096.45 1233.54 739.18 54.03 303.70 6226.18 6155.18 1314.47 784.09 54.03 303.70 6251.00 6180.00 1348.68 803.06 54.03 303.70 6284.91 6213.91 1395.41 828.99 54.03 303.70 6343.64 6272.64 1476.34 873.90 54.03 303.70 6402.37 6331.37 1557.28 918.81 54.03 303.70 6461.10 6390.10 1638.21 963.71 54.03 303.70 6519.83 6448.83 1719.15 1008.62 54.03 303.70 6578.56 6507.56 1800.08 1053.52 54.03 303.70 6637.29 6566.29 1881.02 1098.43 E/W DLS MapN MapE TooUCo ft deg/100ft ft ft -1.88 0.00 5938653.89 674697.70 Start Dir 1: -1.45 12.00 5938653.87 674698.14 Start Dir 4~ 0.08 4.00 5938654.18 674699.67 MWD+IFR 9.01 4.00 5938655.95 674708.55 MWD+IFR 9.63 4.00 5938656.08 674709.17 MWD+IFR 9.83 4.00 5938656.12 674709.37 UG4 18.97 4.00 5938660.47 674718.41 MWD+IFR 21.87 4.00 5938665.33 674721.20 UG3 22.29 4.00 5938668.23 674721.55 MWD+IFR 19.58 4.00 5938679.35 674718.58 MWD+IFR 10.84 4.00 5938693.76 674709.51 MWD+IFR -3.88 4.00 5938711.38 674694.37 MWD+IFR -24.51 4.00 5938732.15 674673.26 MWD+IFR -50.95 4.00 5938755.94 674646.26 MWD+IFR -83.07 4.00 5938782.66 674613.52 MWD+IFR -98.60 4.00 5938795.02 674597.70 UG1 -120.71 4.00 5938812.17 674575.19 MWD+IFR -163.69 4.00 5938844.31 674531.45 MWD+IFR -211.80 4.00 5938878.95 674482.53 MWD+IFR -264.81 4.00 5938915.91 674428.65 MWD+IFR -322.46 4.00 5938955.00 674370.08 MWD+IFR -384.47 4.00 5938996.05 674307.12 MWD+IFR -438.92 4.00 5939031.39 674251.83 End Dir -450.47 0.00 5939038.82 674240.11 MWD+IFR -517.42 0.00 5939081.90 674172.15 WS2 -517.81 0.00 5939082.15 674171.75 MWD+IFR -585.14 0.00 5939125.48 674103.40 MWD+IFR -652.48 0.00 5939168.81 674035.04 MWD+IFR -719.81 0.00 5939212.14 673966.69 MWD+IFR -787.15 0.00 5939255.47 673898.34 MWD+IFR -821.25 0.00 5939277.42 673863.72 WS1 -854.49 0.00 5939298.81 673829.98 MWD+IFR -921.82 0.00 5939342.14 673761.63 MWD+IFR -989.16 0.00 5939385.47 673693.27 MWD+IFR -1056.50 0.00 5939428.80 673624.92 MWD+IFR -1084.95 0.00 5939447.11 673596.03 CM3 -1123.83 0.00 5939472.13 673556.56 MWD+IFR -1191.17 0.00 5939515.46 673488.21 MWD+IFR -1258.50 0.00 5939558.79 673419.86 MWD+IFR -1325.84 0.00 5939602.13 673351.50 MWD+IFR -1393.18 0.00 5939645.46 673283.15 MWD+IFR -1460.51 0.00 5939688.79 673214.79 MWD+IFR -1527.85 0.00 5939732.12 673146.44 MWD+IFR Sperry-Sun BP Planning Report Company:.. BP Amoco Date: 9/14/2007 Time: 14;40:08 Pxge: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well; 14-18, True North Site: PB DS 14 - Vertical (TYD) Reference: 37 :18 4/8!1981 00:00 71.0 Well: 14-18 Section (VS) Reference: Well (O.OON,O.OOE,304.14Azi) Wellpath:- Plan 14-186 P61 Survey Calculation Method: Minimum Cuwature Db: Oracle Survey MD Inc! Azim . TVD Sys TVD VS N/S E/W DLS MapN MapE TooUCo #t deg . .deg ft ft ft ft ft deg/100ft ft ft 7600.00 54.03 303.70 6696.02 6625.02 1961.95 1143.34 -1595.19 0.00 5939775.45 673078.08 MWD+IFR 7685.10 54.03 303.70 6746.00 6675.00 2030.82 1181.55 -1652.49 0.00 5939812.32 673019.92 CM2 7700.00 54.03 303.70 6754.75 6683.75 2042.88 1188.24 -1662.52 0.00 5939818.78 673009.73 MWD+IFR 7800.00 54.03 303.70 6813.48 6742.48 2123.82 1233.15 -1729.86 0.00 5939862.11 672941.38 MWD+IFR 7900.00 54.03 303.70 6872.21 6801.21 2204.75 1278.06 -1797.20 0.00 5939905.44 672873.02 MWD+IFR 8000.00 54.03 303.70 6930.94 6859.94 2285.69 1322.96 -1864.53 0.00 5939948.78 672804.67 MWD+IFR 8100.00 54.03 303.70 6989.67 6918.67 2366.62 1367.87 -1931.87 0.00 5939992.11 672736.31 MWD+IFR 8200.00 54.03 303.70 7048.40 6977.40 2447.56 1412.78 -1999.20 0.00 5940035.44 672667.96 MWD+IFR 8300.00 54.03 303.70 7107.13 7036.13 2528.49 1457.68 -2066.54 0.00 5940078.77 672599.60 MWD+IFR 8400.00 54.03 303.70 7165.86 7094.86 2609.42 1502.59 -2133.88 0.00 5940122.10 672531.25 MWD+IFR 8500.00 54.03 303.70 7224.59 7153.59 2690.36 1547.49 -2201.21 0.00 5940165.43 672462.90 MWD+IFR 8600.00 54.03 303.70 7283.33 7212.33 2771.29 1592.40 -2268.55 0.00 5940208.76 672394.54 MWD+IFR 8700.00 54.03 303.70 7342.06 7271.06 2852.23 1637.31 -2335.89 0.00 5940252.10 672326.19 MWD+IFR 8715.23 54.03 303.70 7351.00 7280.00 2864.55 1644.15 -2346.14 0.00 5940258.69 672315.78 CM1 8800.00 54.03 303.70 7400.79 7329.79 2933.16 1682.21 -2403.22 0.00 5940295.43 672257.83 MWD+IFR 8900.00 54.03 303.70 7459.52 7388.52 3014.10 1727.12 -2470.56 0.00 5940338.76 672189.48 MWD+IFR 9000.00 54.03 303.70 7518.25 7447.25 3095.03 1772.03 -2537.89 0.00 5940382.09 672121.12 MWD+IFR 9100.00 54.03 303.70 7576.98 7505.98 3175.96 1816.93 -2605.23 0.00 5940425.42 672052.77 MWD+IFR 9200.00 54.03 303.70 7635.71 7564.71 3256.90 1861.84 -2672.57 0.00 5940468.75 671984.42 MWD+IFR 9300.00 54.03 303.70 7694.44 7623.44 3337.83 1906.75 -2739.90 0.00 5940512.08 671916.06 MWD+IFR 9400.00 54.03 303.70 7753.17 7682.17 3418.77 1951.65 -2807.24 0.00 5940555.41 671847.71 MWD+IFR 9421.85 54.03 303.70 7766.00 7695.00 3436.45 1961.47 -2821.95 0.00 5940564.88 671832.77 THRZ 9500.00 54.03 303.70 7811.90 7740.90 3499.70 1996.56 -2874.58 0.00 5940598.75 671779.35 MWD+IFR 9600.00 54.03 303.70 7870.63 7799.63 3580.64 2041.47 -2941.91 0.00 5940642.08 671711.00 MWD+IFR 9700.00 54.03 303.70 7929.36 7858.36 3661.57 2086.37 -3009.25 0.00 5940685.41 671642.65 MWD+IFR 9702.80 54.03 303.70 7931.00 7860.00 3663.83 2087.63 -3011.13 0.00 5940686.62 671640.73 BHRZ 9762.39 54.03 303.70 7966.00 7895.00 3712.07 2114.39 -3051.26 0.00 5940712.44 671600.00 TKNG 9800.00 54.03 303.70 7988.09 7917.09 3742.50 2131.28 -3076.58 0.00 5940728.74 671574.29 MWD+IFR 9900.00 54.03 303.70 8046.82 7975.82 3823.44 2176.18 -3143.92 0.00 5940772.07 671505.94 MWD+IFR 10000.00 54.03 303.70 8105.55 8034.55 3904.37 2221.09 -3211.26 0.00 5940815.40 671437.58 MWD+IFR 10100.00 54.03 303.70 8164.28 8093.28 3985.31 2266.00 -3278.59 0.00 5940858.73 671369.23 MWD+IFR 10200.00 54.03 303.70 8223.01 8152.01 4066.24 2310.90 -3345.93 0.00 5940902.06 671300.87 MWD+IFR 10300.00 54.03 303.70 8281.74 8210.74 4147.18 2355.81 -3413.27 0.00 5940945.40 671232.52 MWD+IFR 10400.00 54.03 303.70 8340.47 8269.47 4228.11 2400.72 -3480.60 0.00 5940988.73 671164.17 MWD+IFR 10500.00 54.03 303.70 8399.20 8328.20 4309.05 2445.62 -3547.94 0.00 5941032.06 671095.81 MWD+IFR 10600.00 54.03 303.70 8457.93 8386.93 4389.98 2490.53 -3615.27 0.00 5941075.39 671027.46 MWD+IFR 10654.61 54.03 303.70 8490.00 8419.00 4434.17 2515.05 -3652.04 0.00 5941099.05 670990.13 TJB 10700.00 54.03 303.70 8516.66 8445.66 4470.91 2535.44 -3682.61 0.00 5941118.72 670959.10 MWD+IFR 10800.00 54.03 303.70 8575.39 8504.39 4551.85 2580.34 -3749.95 0.00 5941162.05 670890.75 MWD+IFR 10900.00 54.03 303.70 8634.12 8563.12 4632.78 2625.25 -3817.28 0.00 5941205.38 670822.39 MWD+IFR 10966.35 54.03 303.70 8673.09 8602.09 4686.48 2655.05 -3861.96 0.00 5941234.14 670777.04 Start Dir 4° 1 10973.02 54.11 303.38 8677.00 8606.00 4691.88 2658.03 -3866.46 4.00 5941237.01 670772.47 7" 10979.85 54.19 303.06 8681.00 8610.00 4697.42 2661.06 -3871.09 4.00 5941239.94 670767.77 14-186 Fa I 11000.00 54.43 302.11 8692.76 8621.76 4713.78 2669.88 -3884.88 4.00 5941248.43 670753.78 MWD+IFR 11022.85 54.71 301.05 8706.00 8635.00 4732.37 2679.62 -3900.74 4.00 5941257.81 670737.70 TSHU 11045.43 55.00 300.00 8719.00 8648.00 4750.80 2689.00 -3916.65 4.00 5941266.81 670721.58 14-186 PB 11100.00 52.82 300.00 8751.14 8680.14 4794.78 2711.05 -3954.84 4.00 5941287.97 670682.90 MWD+IFR 11156.23 50.57 300.00 8786.00 8715.00 4838.79 2733.11 -3993.05 4.00 5941309.14 670644.19 TSAD/TZ4 11200.00 48.82 300.00 8814.31 8743.31 4872.08 2749.80 -4021,95 4.00 5941325.15 670614.91 MWD+IFR 11300.00 44.82 300.00 8882.73 8811.73 4944.79 2786.25 -4085.09 4.00 5941360.13 670550.95 MWD+IFR 11400.00 40.82 300.00 8956.07 8885.07 5012.57 2820.23 -4143.94 4.00 5941392.73 670491.33 MWD+IFR 11500.00 36.82 300.00 9033.97 8962.97 5075.07 2851.56 -4198.21 4.00 5941422.80 670436.35 MWD+IFR Went 7S 1S 7S 1S AS 4S QS 9S 9S ~S QS QS 7S QS QS QS ~S ~S ~S ~S ~S AS AS ~S AS AS AS ~S 1. AS T1 AS AS AS ~S AS Sperry-Sun BP Planning Report :Company: BP Amoco Date; 9/14(2007 "time: 14:40:08 Puge: 4 Field: Prudhoe Bay Co=ordinate(NE) Reference: Well: 14-18, True North Site: PB DS 14 Vertical (TVD) Reference:. 37:18 4/8/1981 00:00 71.0 Well: 14-18 Section(VS)Reference: Well (O.OON,O.OOE,304.14Azi) Wellpath:' Plan 14-186 PBT Survey Calcutstion Method: Minimum Curvature Db: Oracle Survey MD Incf Azim TVI) SysTVD VS N/S E/W DLS blupV MapE TooVCo ft deg °deg - ft ft ft ft ft deg/100ft H ft 11589.21 33.25 300.00 9107.00 9036.00 5126.14 2877.16 -4242.55 4.00 5941447.36 670391.43 Total Dep gent N' -W-\ ~IIW IJ I} )_II J] __]JI~ wPV.lxrrnu+ NUMwg IdLRE I~Inmb l.rRkauJn tilUt _NNrlr)WS fi]JIfY)._r ]II IJ'I ]..YJN IJN' 15:I.IN'`/W IN ANTI-COLLISION SETTWGS Inte1polation Me16odMD Intenal: 25.1111 Depth Range From: 425p.u11 TO: 115%Y.21 Maximum Range: 1356.112 Reference: Plan: 14-1%B Pbl Wp ri.0 comrnrvv UC7A1Lx tll'Am Iak W McIhW: M ('unaturt• ism m~~w b: ru. t rlimlo N'~nh Imrt sa.ra.r: YTl4,l.al ~ t:~ W afwog A4-Ihud: Ituks tlacd slnevsv rka:RAM Ikrlh Plu Iklah l'u lurv y/Plan fUUI J7511JNI IISti`)_I i'Luwed: I+INtl PbI Wp S.U V_J MWII~IrK~M1Iti WIlaYAlll UIIAIhti 160 Flom Colou[ TO MD Plan l+Intl rtll r~nm wel~mh la-Ix 150 4250 4500 Ic.a MU: J7wm 33 0 asoo - also k,, ~l~' 7]:Ih JT IVaI ~NqN, ]I,Nitl 4750 5000 5000 5250 v waa. IAgu rx~n SauJmE n~lt 7a--s I-w In~m Ivu 125 s2so ssoo ,I»„ I,I~ ~»I _J~.I ssoo 5750 s7so 6000 6000 6250 6250 6500 Ilec:PrJu 100 6500 a _ 6750 - 6750 _ 7000 iiu<~iiJi+isnl niaw~RUA ~ IJJIStl IIJNI_<tlA Alajru Rid 7000 O 7250 7250 7500 IJJM IIJJ)fN/Alar1~ kuk IJ-11 I IJ-I11. h1aMU W.k -- I+n a+unl. Awi'v xr+A 30 I+1111 J-1I AYtllI~ hlaau ki.4 ' 5 14-IN (1+Ib I Nl>IikRUk% IJ-IN'(1+IXAI. NUF]lkUkS - IJ-IA(I+IN'APtl1A NOI~RRUkti I+IA (1+1nA1'tl'_IN111~~kkUk% 1+1%II+I~AI'k71~N11Fkk1)R\ - 1+1h'lI J-I NAI'kJI. NIJI~kkUR\ ' IJ-1 111+IUI. AIaYrt RUk - IJ-IV IIJ-IVPtl I). Alaru kl~ I+?U (1+' 111 Mayu Rf>~ O _ . - IJ--'_? ll+'_JI. AIaNrt kuk I+?I IPIu~ l+'_7A1_ AIaRu kifk - IJ-_ill+?JI~AIarrt RI.Y - X-IS(%-ISAI. AWF'I kuk %-Ifi(%-I61. Maly K,>k %-Ifi lX-I W I. AIaNU Risk ~ PW I+1Nk PPI 25 - I+INN YhI WPN11 0 270 90 25 ,~~, 0 ,~ ;' 5 ' 240 '~ 120 ^ ;. ~ ~ ' fA` ~ 100 ~ • ~~3~ `; `I ~; Pre Plans R emoved. , , See AC Scan for Plans ~ ~ -t~ ' ~ Parents Profile @ No Errors 125 f %1'1'rR)N U6rAtlS ~ I ' Te V ' 21 \a AIU hf. 50 I J751I.IIU Ufii An lVll 14 IMI J_'JY.'1 ,uECI -w Ulaq xa ~N -% ~ks xt I55'_ -I.Mh O.al U.a) 71: J_'TLW 7.77 J7vs.a1 zn NU.U7 J'_rN.vl n1u1J J7w.JJ -ISSr. -1.45 17.W ]elm ~] ct -u?z vm 4al o.al -IS.Is 1Co .•77 J SxN: AS 54111 I~rMl.1< [J ff1 Jt JUJ ]U 5µ].5J 1i11.71i li(~7~IYl n]I' ixi 7]?.'_I -UA.`J'_ iW -IJY.S'/ 57'_.IY - -~hLl!K Olxl rl.lxl Nw~G JN 1'111 5 JINI -]1 1U J]Si I \II IJ-I~It l'Ifl I I ( f I 160 1 !. IIiWi IISS•i 71 ,_ 80 i uxl iNi Y111]INI , - . . Ie -J'_J'_SS JINJ 14u lNl 517r,H 'v] / Travelling Cylinder Azimuth (TFO+AZI) [ deg] vs Centre to Centre Separation [SOfI1in] ~~ • • ! Sperry-Sun Anticollision Report Company: BP Amoco Date: 9/14/2007 Time: 14:32:59 Page: 1 Field: Prudhoe Bay. Reference: Site: PB`DS 14 ' Co-ordinate(NE)Referenee: '. Well: 14- 1$ True No rth Reference Well: 1418 Vertical (TVD) Reference: 37:18 4/811981 00:00 71:0 Reference Wellpath: Plan 44-186 P61 Db: Orate GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are TNfaidTewdls in this fl2tiltcipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 4250.00 to 11589.21 ft Scan Method: Trav Cylinder North Maximum Radius: 1356.02 ft Erro r Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 4/19/2007 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 100.00 4250.00 14-18 CB-GYRO-MS SDC #1 (100.00-10200(DBj(@QfRO-SS Camera based gyro single shots 4250.00 11589.21 Planned: 14-186 Pb1 Wp 8.0 V24 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in m 10973.02 8677.00 7.000 8.500 7" Summary <-------- Offset Wellpath - -> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ff PB DS 14 14-05 14-05 V1 4660.53 4675.00 593.53 70.12 523.41 Pass: Major Risk PB DS 14 14-05A 14-05A V1 4660.53 4675.00 593.53 70.12 523.41 Pass: Major Risk PB DS 14 14-056 14-056 V3 Plan: Undefi 4660.53 4675.00 593.53 70.12 523.41 Pass: Major Risk PB DS 14 14-06 14-06 V4 4355.82 4450.00 504.80 101.88 402.92 Pass: Major Risk PB DS 14 14-06 14-06A V2 4355.82 4450.00 504.80 101.88 402.92 Pass: Major Risk PB DS 14 14-11 14-11 V1 4398.88 4400.00 117.15 82.49 34.67 Pass: Major Risk PB DS 14 14-11 14-11A V2 4398.50 4400.00 117.15 82.48 34.67 Pass: Major Risk PB DS 14 14-11 14-11APB1 V5 4398.50 4400.00 117.15 82.48 34.67 Pass: Major Risk PB DS 14 14-18 14-18 V5 4250.00 4250.00 0.00 0.65 -0.65 FAIL: NOERRORS PB DS 14 14-18 14-18A V5 4250.00 4250.00 0.00 0.65 -0.65 FAIL: NOERRORS PB DS 14 14-18 14-18AP61 V8 4250.00 4250.00 0.00 0.65 -0.65 FAIL: NOERRORS PB DS 14 14-18 14-18APB2 V2 4250.00 4250.00 0.00 0.65 -0.65 FAIL: NOERRORS PB DS 14 14-18 14-18AP63 V2 4250.00 4250.00 0.00 0.65 -0.65 FAIL: NOERRORS PB DS 14 14-18 14-18AP64 V2 4250.00 4250.00 0.00 0.65 -0.65 FAIL: NOERRORS PB DS 14 14-18 Plan 14-186 V2 Pla n: 1 9500.00 9500.00 0.00 0.61 -0.61 FAIL: NOERRORS PB DS 14 14-19 14-19 V11 4267.04 4300.00 270.62 51.21 219.41 Pass: Major Risk PB DS 14 1419 14-19PB1 V4 4267.04 4300.00 270.62 51.21 219.41 Pass: Major Risk PB DS 14 14-20 14-20 V1 5141.54 5075.00 189.60 56.52 133.08 Pass: Major Risk PB DS 14 14-23 14-23 V1 4266.20 4500.00 1091.52 65.66 1025.86 Pass: Major Risk PB DS 14 14-23 Plan 14-23A VO Pla n: 1 4267.47 4500.00 1092.43 65.74 1026.70 Pass: Major Risk PB DS 14 14-24 14-24 V1 5534.54 5475.00 73.55 61.31 12.24 Pass: Major Risk PB DS 14 1425 14-25 V1 4257.13 4425.00 787.14 62.70 724.44 Pass: Major Risk PB X Pad X-15 X-15A V15 11584.38 10750.00 838.65 172.19 666.46 Pass: Major Risk PB X Pad X-16 X-16 V4 11589.21 10075.00 1235.90 700.01 535.90 Pass: Major Risk PB X Pad X-16 X-16A V16 Out of range Site: PB DS 1 4 Well: 14-05 Rule Assigned: Major Risk Wellpath: 14-05 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Cfr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ' ft ft deg deg in ft ft ft 4278.67 4278.59 4250.00 4249.86 3.15 8.47 84.41 4.39 627.43 68.29 559.14 Pass 4322.85 4322.68 4275.00 4274.86 3.15 8.54 84.42 4.39 625.39 68.50 556.90 Pass 4366.76 4366.40 4300.00 4299.85 3.15 8.62 84.43 4.40 622.56 68.70 553.86 Pass 4400.00 4399.40 4325.00 4324.85 3.14 8.68 84.44 5.44 619.01 68.88 550.13 Pass 4419.81 4419.07 4350.00 4349.84 3.15 8.70 84.44 9.98 615.51 68.93 546.58 Pass 4438.22 4437.36 4375.00 4374.84 3.15 8.71 84.45 14.93 612.30 68.97 543.33 Pass 4456.66 4455.71 4400.00 4399.83 3.15 8.72 84.49 20.72 609.37 69.01 540.36 Pass 4475.15 4474.11 4425.00 4424.83 3.15 8.73 84.54 27.40 606.74 69.06 537.68 Pass 4493.66 4492.54 4450.00 4449.82 3.15 8.74 84.61 34.99 604.36 69.10 535.26 Pass 4512.19 4511.01 4475.00 4474.82 3.16 8.76 84.69 43.35 602.23 69.14 533.09 Pass Alaska Department of Natural Resources Land Administration System Page 1 of 2 ~~~A.:ska ~ as ~t_,~_ _rrcl '=:cor;{~'. ta`u _ E'!~!s ~?acorder s Search State Cabins ~tlaittuf'~ 5~D41E'~+es Alaska DN Case Summary File Type AFL _: File Number: _ _ _ ~83s3 -' ~ printable Case File_Summary See Township, Range, Section and Acreage? C: Yes ~" NO New Search i_AS n~lenu I Case Abstract I Case Detail I Land Abstract .. F[/e: :~llL 28313 ~''"t'. _ Search for Status Plat Updates .~~s of 09.' 1912007 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 7€34 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISS/APPRV/ACTV/ AUTH Status Date: 09/14/1965 Total Acres: 2501.000 Date Initialed: 05/28/1965 O~ce of Prinurry Responsibility: DOG DN OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: ~i NORTH SLOP1= Last Transaction: AA-NRB ASSIGNMENT APPROVED 11IL'rlL~lail; ~ ~Olt7LS'{11h: TON R[lll~t: O14E. .Si'CllOil: ~~~ :~~CL'tli)71.~'~Gre'S: 640 Plats illPl'1cI1c1)1: L~ I UU~i7.C~llJ): U ~ ~)N Ran,~~e: ~) ~ ~~. .~~NCt1U11: (16 ,~E'C//U71 AL~rC'.C. 609 ;llr~riclr~ri7: L! 7uic~rti~hip: 010N Raf~~~e: 014E .Srclron: 07 Sc~ctir~n ;lcrc~e: 612 tlcrrc~rcrrl: LJ Irnrn~{uh: OION R<<~t~c: 01=1 E. ,S'c~c7ior~: OS .Scclrnn.~lc~rr~.t~: 6=10 Leal DescT•iption OS-28-1965 * * * SALE NOTICE LEGAL DESCRIPTION CI ~-13~ TION, RI=IE, UM 5, 6, 7, 8 2501.00 end of Case Summary Search Last updated on 09/19/2007. http : //www. dnr. state . ak. us/las/Case_Summary. cfm?F ileType=ADL&FileNumber=28 313 &... 9/ 19/2007 Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, September 05, 2007 10:34 AM To: Nigh, Jim Cc: Hobbs, Greg S (ANC) Subject: RE: 14-18 B Jim, That would be fine. My concern with the possible need for 2 permits is the x-y distance that might exist between the BHLs. That will be an issue we will settle when and if necessary. Look forward to seeing the permit. Tom Maunder, PE AOGCC From: Nigh, Jim [mailto:Jim.Nigh@bp.com] Sent: Wednesday, September 05, 2007 10:14 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: 14-18 B Tom, The Asset Team feels as though there is a fairly high chance that they will be completing the Ivishak pilot/production hole. I would like to proceed with just permitting for that plan and keeping the Sag River horizontal as a contingency to be addressed if needed. Thoughts? Thank you, -Jim From: Nigh, Jim Sent: Tuesday, September 04, 2007 2:57 PM To: 'Maunder, Thomas E (DOA)' Cc: Hobbs, Greg S (ANC); Schafer, Daniel B; Urban, Dennis M; Ramjit, Neil (Sperry Sun) Subject: RE: 14-18 B Hi Tom, Updated directional programs attached. What is the criteria dictating separate permits? Team geologist, geophysicist, and well planner cc'd. Thank you, -Jim 10/2/2007 Page 2 of 2 From: Maunder, Thomas E (DOA) Sent: Friday, August 31, 2007 10:36 AM To: ]im Nigh Subject: 14-18 B Jim, I am reviewing the plugging sundry for 14-18A. Just a question looking ahead on the completion options for 14- 186; are the Ivishak and Sag BHLs the same (at least in x -y)? It is possible that separate permits will be needed. Just a heads up. If you can share the directional information, that would help. Regards, Tom Maunder, PE AOGCC 10/2/2007 TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ ~~",~~ PTD# o~~~~v? 90 Development Service Exploratory Non-Conventional Well Stratigraphic Test 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 between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for. well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /infect 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 (Campany Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing ro am. Rev: 7/13/2007 ~ ~ , : , rn o a ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ai~ c b' 0 N N, N N, ~ `~ ~ c. ~ L 'O ~, f6 ~ m ~ o ~ °- c N ~ ~ ti ~ = E O o` m ' >i °, c. m. rn o C9. a a~, .c, 0 a 0 ~ o -o. ~ w w s, i I v 3 ~, ~. ins ~ . Q ~ v; o, o ; ~ rn ~ ~ ~ c o c, N' ~ C. ~ fl, d, ~ Q '~ ~ O. ~~ ~ ~ ~ ~ ' c O) ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Q ~ . ~, W. ~~ d' ~~ ~ N. ~I ~~ , ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ U , (6 ~ N Z' ~ U N (~ O ~ m' ~ a 3' CV ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ifT ' N. ~ ~ ~ Z' ~ H~ O' N. ~ N• ` M O ~ Q m ~ ~ ~ ~ ~ ~ ~ ~ p. C O. ~ ~ U' ~ ~ Vl' ~ ~ p, O: C' ~ . ~ ~ ~ pp ~ L. ~ W ~ ~ ~ ~ ~ ~ ~ ~ 00~ 7. ~, N ~ O; ~ N~ '~ ~~ ~ R ~ ~ a, ,~ N~ ~ O ~ ~ ~ ~ ~ ~ ~,, ~ ~ ~ ~ ~~ U. C• 3. ~ O, ~ N' -p. O. N. ~ ~ ~~ -a, ~ 00~ ~ ~ ~ ~ - ~ p, ~ ~ ~, m, v. ~,, ~, c. ~ t, ~3, ~ 4 f6. ~~ ~, ~ ~, ~ ~ ~ '~; f0. a, ~ , o; n. ~ ~ ~ ~ ~ *k, Ol C ~ ~ a ~ ~ -~ N. ~ ~ ~ N. N, ~ ~ ~, ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ U' ~ , O. ~ ~ ~ t0~ ~6~ C U tl~ N, ~ ~ ~ Z ~ O _ >~ ~ ~ . 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W ' 3, ~' ~ . n . v J m ~' ~ a ~ a>i ` N. ~ ~ c 3, ~ c ~' c ~ F-' H 1- .N, ~ ~ ~ ~' d' O o a Y ~ ~ ° : N m c '~ ~ o; ~' ~ ~ . c, ~' ~' ~, ~ ~ m n Q ' a~ a~, m ~ i - o' ' ' o ' ~ ~' ~' ' ~' m a, ~ • ~, a O' o . p' t, o , ' ai a . o ~ ~ ~: <° o <, ~ a, , ~, , , ~; ~; ~-; O , O; ~; a, U Q; a; z ~ U cn; c~: U c~; c~; a ~: ; m; ¢ ~ m, Q ~ ~ ~ m O ~ N M tT ~ (O 1~ W O O N N N ~ O N M V ' ~ M ~ W O O ~ N M V ~ CO t~ W O ~ _- _ __ _~ _ ~ ~ - __ _ _-'-~ r" ~ ~- N N N N N N N M M M M ~ M M M M_M M U _ _ . _ .._ __ _ __ ___- _ ._ __ _. . _ ... _ V ~ ~ p ~ ~ ~ ~ N C w O y I r U N .r ~ ~ ~ ~ ~ ~ ' ~~ ~ N W p, o ~ _ °' ~ ~ ~ I _ o' ~ ~ E J N ~ C ~ i d ~ I~ C9 E O O E Q C G~ O G U ll.I a Q p, Q U ¢ ~ L Q W Q F- ~ l ~ Q. U Q Q l i • Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 14-18b.tapx Sperry-sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jan 25 16:47:47 2008 Reel Header Service name .............LISTPE Date . ...................08/01/25 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Tape Header Service name .............LISTPE Date . ...................08/01/25 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS Lis Writing Physical EOF • Library. scientific Technical Services Library. scientific Technical Services Comment Record TAPE HEADER Prudhoe Bay unit MWD/MAD LOGS WELL NAME: 14-18B API NUMBER: 500292055102 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 25-JAN-08 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 Job NUMBER: Mw0005042392 Mw0005042392 Mw0005042392 LOGGING ENGINEER: SHAWN POLAK SHAWN POLAK SHAWN POLAK OPERATOR WITNESS: DICK MASKELL BILL DECKER BILL DECKER MWD RUN 4 MAD RUN 4 JOB NUMBER: Mw0005042392 Mw0005042392 LOGGING ENGINEER: SHAWN POLAK SHAWN POLAK OPERATOR WITNESS: BILL DECKER BILL DECKER SURFACE LOCATION SECTION: 9 TOWNSHIP: lON RANGE: 14E FNL: 1659 FSL: FEL: 1784 FWL: Page 1 c9d~' ~~ ~ ~~~~ ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 8.500 2ND STRING 6.125 3RD STRING PRODUCTION STRING REMARKS: 14-18b.tapx 70.46 41.96 CASING DRILLERS SIZE (IN) DEPTH (FT) 9.625 3506.0 7.000 10697.0 ~~ 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 3506' MD/3505'TVD,IN THE 14-18 WELLBORE. 4. MWD RUNS 1-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR), UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4). MWD RUNS 1-3 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). MWD RUN 4 ALSO INCLUDED AZIMUTHAL LITHO-DENSITY (ALD) AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). UPHOLE SGRC TIE-IN DATA WERE MERGED WITH MWD RUN 1 DATA. MAD PASS DATA WERE ACQUIRED OVER THE MWD RUN 4 INTERVAL WHILE POOH AFTER REACHING FINAL TD. 5. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO A SCHLUMBERGER GAMMA RAY LOG RUN IN 14-18 ON 30 APRIL 1981. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THESE PDC DATA WERE PROVIDED BY DOUG DORTCH (SAIC/BP) ON 13 DECEMBER 2007, AS AUTHORIZED BY DANIEL SCRAPER (BP). THE SHIFTED MWD DATASET IS THE PDC FOR THIS WELL. 6. MWD RUNS 1-4 REPRESENT WELL 14-186 WITH API# 50-029-20551-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11330'MD/8973'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 Page 2 14-18b.tapx RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). 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 = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR. DISTANCE. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125~~ MUD WEIGHT: 8.4 PPG MUD SALINITY: 4000 PPM CHLORIDES FORMATION WATER SALINITY: 11500 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPM FET RPD RPX RPS ROP NCNT PEF RHOB FCNT NPHI DRHO 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3242.5 3438.0 3438.0 3438.0 3438.0 3438.0 3497.0 10676.0 10676.0 10676.0 10676.0 10676.0 10676.0 BASELINE CURVE FOR SHIFTS: STOP DEPTH 11064.0 11071.0 11071.0 11071.0 11071.0 11071.0 11121.0 11036.0 11051.0 11051.0 11036.0 11036.0 11051.0 Page 3 14-18b.tapx CURVE SHIFT DATA (MEASURED DEPT H) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 3242.5 3253.0 3244.0 3254.5 3259.0 3268.0 3265.5 3274.0 3267.0 3275.5 3281.0 3289.5 3296.5 3305.5 3302.0 3313.0 3310.5 3320.0 3314.0 3323.5 3316.0 3325.0 3317.0 3327.0 3326.5 3335.5 3352.5 3362.5 3357.0 3367.5 3366.5 3376.5 3377.5 3386.5 3382.0 3392.0 3388.0 3398.5 3395.0 3405.0 3412.0 3422.5 3446.5 3458.0 3458.0 3466.0 3467.5 3473.5 3481.0 3488.0 3485.5 3494.0 3487.0 3496.0 3489.5 3497.0 3491.0 3499.0 3494.5 3502.0 3496.0 3505.0 3500.0 3509.0 3504.0 3513.0 11064.0 11073.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 1 3253.0 5555.0 MwD 2 5555.0 6642.0 MwD 3 6642.0 10698.0 MwD 4 10698.0 11130.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging 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 Page 4 14-18b.tapx 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 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3242.5 11121 7181.75 15758 3242.5 11121 FCNT MWD CP30 93.48 3524.11 802.928 721 10676 11036 NCNT MwD CP30 13226 50850 27625.6 721 10676 11036 RHOB MWD G/CC 1.381 3.556 2.42367 751 10676 11051 DRHO MWD G/CC -1.391 1.121 0.0675792 751 10676 11051 RPD MWD OHMM 0.68 2000 26.2684 15267 3438 11071 RPM MWD OHMM 0.67 2000 13.1821 15267 3438 11071 RPS MWD OHMM 0.6 1855.39 6.74404 15267 3438 11071 RPX MWD OHMM 0.31 1855.23 5.85543 15267 3438 11071 FET MWD HR 0.14 110.92 2.16861 15267 3438 11071 GR MwD API 5.65 546.41 103.181 15644 3242.5 11064 PEF MWD B/E 1.07 13.22 2.93186 751 10676 11051 ROP MWD FPH 0.07 1200.2 140.184 15249 3497 11121 NPHI MwD PU-S 4.57 65.87 22.3592 721 10676 11036 First Reading For Entire File..........3242.5 Last Reading For Entire File...........11121 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/25 Maximum Physical Record..65535 File Type ................LO 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.......08/01/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER Page 5 FILE NUMBER: EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE NPHI RAT PEF FCNT GR RPD NCNT DRHO RPX RPS RHOB RPM FET 14-18b.tapx 2 clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 10679.0 10679.0 10679.0 10679.0 10679.0 10679.0 10679.0 10679.0 10679.0 10679.0 10679.0 10679.0 10679.0 STOP DEPTH 10912.0 10993.5 10928.5 10912.0 10941.0 10948.0 10912.0 10928.5 10948.0 10948.0 10928.5 10948.0 10948.0 MERGED DATA SOURCE PBU TOOL CODE MWD REMARKS: MERGED MAD PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 MERGE TOP MERGE BASE 10641.0 11130.0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 FCNT MAD CP30 4 1 68 4 2 NCNT MAD CP30 4 1 68 8 3 RHOB MAD G/CC 4 1 68 12 4 DRHO MAD G/CC 4 1 68 16 5 RPD MAD OHMM 4 1 68 20 6 RPM MAD OHMM 4 1 68 24 7 RPS MAD OHMM 4 1 68 28 8 RPX MAD OHMM 4 1 68 32 9 FET MAD HR 4 1 68 36 10 GR MAD API 4 1 68 40 11 PEF MAD B/E 4 1 68 44 12 RAT MAD FPH 4 1 68 48 13 NPHI MAD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10679 10993.5 10836.3 630 10679 10993.5 Page 6 MAD RUN N0. MAD PASS NO. 4 1 14-18b.tapx FCNT MAD CP30 98.88 3343.44 955.994 467 10679 10912 NCNT MAD CP30 13480.1 47829.8 29652.9 467 10679 10912 RHOB MAD G/CC 1.896 3.03 2.49488 500 10679 10928.5 DRHO MAD G/CC -0.898 0.606 0.0659 500 10679 10928.5 RPD MAD OHMM 0.08 2000 81.1156 539 10679 10948 RPM MAD OHMM 0.08 2000 100.445 539 10679 10948 RPS MAD OHMM 0.68 1423.57 70.0276 539 10679 10948 RPX MAD OHMM 0.54 1421.27 56.5898 539 10679 10948 FET MAD HR 3.47 120.18 12.4126 539 10679 10948 GR MAD API 16.03 565.52 97.192 525 10679 10941 PEF MAD B/E 1.07 13.02 3.27042 500 10679 10928.5 RAT MAD FPH 0.01 5390.04 428.878 630 10679 10993.5 NPHI MAD PU-S 4.66 62.11 20.1758 467 10679 10912 First Reading For Entire File..........10679 Last Reading For Entire File...........10993.5 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/25 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3253.0 5511.5 RPD 3449.5 5498.5 RPS 3449.5 5498.5 RPM 3449.5 5498.5 RPX 3449.5 5498.5 FET 3449.5 5498.5 RoP 3506.0 5555.0 LOG HEADER DATA DATE LOGGED: 30-OCT-07 SOFTWARE Page 7 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 14-18b.tapx Insite 74.11 Memory 5555.0 3506.0 5555.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 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 1.3 49.3 TOOL NUMBER 232687 81390 8.500 .0 Fresh Water Gel 9.50 59.0 9.2 2100 7.6 2.170 58.0 1.210 109.4 2.030 58.0 1.910 58.0 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 Page 8 ~ ~ 14-18b.tapx FET MWDO10 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 3253 5555 4404 4605 3253 5555 RPD MWDO10 OHMM 0.8 2000 42.7816 4099 3449.5 5498.5 RPM MWDO10 OHMM 1 2000 7.07356 4099 3449.5 5498.5 RPS MWDO10 OHMM 0.41 1855.39 6.72593 4099 3449.5 5498.5 RPX MWDO10 OHMM 0.31 1855.23 5.76133 4099 3449.5 5498.5 FET MWDO10 HR 0.14 6.38 1.10517 4099 3449.5 5498.5 GR MWDO10 API 5.65 130.27 69.508 4518 3253 5511.5 ROP MWDO10 FPH 0.74 1200.2 166.27 4099 3506 5555 First Reading For Entire File..........3253 Last Reading For Entire File...........5555 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSL26.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/25 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 5499.0 6588.5 RPS 5499.0 6588.5 RPx 5499.0 6588.5 RPM 5499.0 6588.5 RPD 5499.0 6588.5 GR 5512.0 6601.5 ROP 5555.5 6642.0 Page 9 14-18b.tapx LOG HEADER DATA DATE LOGGED: O1-NOV-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 6642.0 TOP LOG INTERVAL (FT): 5555.0 BOTTOM LOG INTERVAL (FT): 6642.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 46.0 MAXIMUM ANGLE: 50.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232687 EWR4 ELECTROMAG. RESIS. 4 230207 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 3522.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): .0 MUD PH: 9,1 MUD CHLORIDES (PPM): 1800 FLUID LOSS (C3): 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.170 58.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.140 116.6 MUD FILTRATE AT MT: 2.030 58.0 MUD CAKE AT MT: 1.910 58.0 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 Log~iny 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 MWD020 OHMM 4 1 68 4 2 Page 10 14-18b.tapx 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 5499 6642 6070.5 2287 5499 6642 RPD MWD020 OHMM 0.8 23.9 2.66249 2180 5499 6588.5 RPM MWD020 OHMM 0.71 28.08 2.64481 2180 5499 6588.5 RPS MWD020 OHMM 0.6 23.13 2.60844 2180 5499 6588.5 RPX MWD020 OHMM 0.62 26.91 2.62008 2180 5499 6588.5 FET MWD020 HR 0.21 26.2 1.95198 2180 5499 6588.5 GR MWD020 API 19.39 126.42 65.1541 2180 5512 6601.5 ROP MWD020 FPH 0.07 405.5 162.33 2174 5555.5 6642 First Reading For Entire File..........5499 Last Reading For Entire File...........6642 File Trailer Service name... .......STSL2B.004 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/01/25 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 6589.0 10640.5 FET 6589.0 10640.5 RPx 6589.0 10640.5 RPM 6589.0 10640.5 RPD 6589.0 10640.5 GR 6602.0 10653.5 Page 11 i- i 14-18b.tapx ROP 6642.5 10698.0 LOG HEADER DATA DATE LOGGED: 04-NOV-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10698.0 TOP LOG INTERVAL (FT): 6642.0 BOTTOM LOG INTERVAL (FT): 10698.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 43.9 MAXIMUM ANGLE: 50.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 232687 EWR4 ELECTROMAG. RESIS. 4 230207 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 3522.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (5): 46.0 MUD PH: 9,Q MUD CHLORIDES (PPM): 1800 FLUID LOSS (C3): 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.760 50.6 MUD AT MAX CIRCULATING TERMPERATURE: .650 148.0 MUD FILTRATE AT MT: 1.780 49.7 MUD CAKE AT MT: 1.560 1.6 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 Page 12 ~ ~ 14-18b.tapx Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MwD030 OHMM 4 1 68 16 5 FET MwD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6589 10698 8643.5 8219 6589 10698 RPD MwD030 OHMM 0.68 22 2.93956 8104 6589 10640.5 RPM MWD030 OHMM 0.67 28.3 2.85447 8104 6589 10640.5 RPS MWD030 OHMM 0.71 17.39 2.76396 8104 6589 10640.5 RPX MWD030 OHMM 0.79 18.95 2.75103 8104 6589 10640.5 FET MwD030 HR 0.23 16.08 1.32408 8104 6589 10640.5 GR MwD030 API 33.61 424.96 135.119 8104 6602 10653.5 ROP MWD030 FPH 0.68 368.58 121.494 8112 6642.5 10698 First Reading For Entire File..........6589 Last Reading For Entire File...........10698 File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/25 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLI6.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5TSL26.005 Comment Record FILE HEADER FILE NUMBER: 6 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 RPM 10641.0 11080.0 RPS 10641.0 11080.0 RPX 10641.0 11080.0 Page 13 • • 14-18b.tapx RPD 10641.0 11080.0 FET 10641.0 11080.0 GR 10654.0 11073.0 PEF 10685.0 11060.0 FCNT 10685.0 11045.0 DRHO 10685.0 11060.0 RHOB 10685.0 11060.0 NCNT 10685.0 11045.0 NPHI 10685.0 11045.0 ROP 10698.5 11130.0 LOG HEADER DATA DATE LOGGED: 09-NOV-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11130.0 TOP LOG INTERVAL (FT): 10698.0 BOTTOM LOG INTERVAL (FT): 11130.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 45.6 MAXIMUM ANGLE: 47.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 9999 CTN COMP THERMAL NEUTRON 231708 EWR4 Electromag Resis. 4 156404 ALD Azimuthal Litho-Dens 231386 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10697.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 50.0 MUD PH: $.7 MUD CHLORIDES (PPM): 4000 FLUID LOSS (C3): 8.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .917 57.3 MUD AT MAX CIRCULATING TERMPERATURE: .330 171.0 MUD FILTRATE AT MT: .963 59.8 MUD CAKE AT MT: 1.100 58.8 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Page 14 14-18b.tapx 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 MWD040 CP30 4 1 68 4 2 NCNT MwD040 CP30 4 1 68 8 3 RHOB 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 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-S 4 1 68 52 14 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 10641 11130 10885.5 979 10641 11130 FONT MWD040 CP30 93.48 3524.11 802.928 721 10685 11045 NCNT MWD040 CP30 13226 50850 27625.6 721 10685 11045 RHOB MwD040 G/CC 1.381 3.556 2.42356 751 10685 11060 DRHO MWD040 G/CC -1.391 1.121 0.0747843 751 10685 11060 RPD MwD040 oHMM 1.62 2000 220.837 879 10641 11080 RPM MWD040 OHMM 1.19 2000 164.137 879 10641 11080 RPS MWD040 OHMM 1.07 1598.82 54.8942 879 10641 11080 RPx MWD040 OHMM 0.79 1742.34 43.159 879 10641 11080 FET MwD040 HR 0.26 110.92 15.3959 879 10641 11080 GR MWD040 API 14.15 546.41 74.9713 839 10654 11073 PEF MwD040 B/E l.ll 13.22 2.93758 751 10685 11060 ROP MWD040 FPH 11.23 388.69 136.191 864 10698.5 11130 NPHI MWD040 Pu-S 4.57 65.87 22.3592 721 10685 11045 First Reading For Entire File..........10641 Last Reading For Entire File...........11130 File Trailer Service name... .......STSLIB.006 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/01/25 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.007 Physical EOF Page 15 • i 14-18b.tapx File Header Service name... .......STSLIB.007 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 10688.0 10957.0 RPS 10688.0 10957.0 RPX 10688.0 10957.0 FET 10688.0 10957.0 GR 10688.0 10950.0 RAT 10688.0 11002.5 RPD 10688.0 10957.0 NPHI 10688.0 10921.0 PEF 10688.0 10937.5 NCNT 10688.0 10921.0 DRHO 10688.0 10937.5 FONT 10688.0 10921.0 RHOB 10688.0 10937.5 LOG HEADER DATA DATE LOGGED: 09-NOV-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11000.0 TOP LOG INTERVAL (FT): 10641.0 BOTTOM LOG INTERVAL (FT): 11000.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 45.6 MAXIMUM ANGLE: 47.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 9999 CTN COMP THERMAL NEUTRON 231708 EWR4 Electromag Resis. 4 156404 ALD Azimuthal Litho-Dens 231386 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10697.0 BOREHOLE CONDITIONS Page 16 ~ ~ 14-18b.tapx MUD TYPE: Lignosulfanate MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 50.0 MUD PH: $,7 MUD CHLORIDES (PPM): 4000 FLUID LOSS (C3): 8.1 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .917 57.3 MUD AT MAX CIRCULATING TERMPERATURE: .330 171.0 MUD FILTRATE AT MT: .963 59.8 MUD CAKE AT MT: 1.100 58.8 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 FCNT MAD041 CP30 4 1 68 4 2 NCNT MAD041 CP30 4 1 68 8 3 RHOS MAD041 G/CC 4 1 68 12 4 DRHO MAD041 G/CC 4 1 68 16 5 RPD MAD041 OHMM 4 1 68 20 6 RPM MAD041 OHMM 4 1 68 24 7 RPS MAD041 OHMM 4 1 68 28 8 RPx MAD041 oHMM 4 1 68 32 9 FET MAD041 HR 4 1 68 36 10 GR MAD041 API 4 1 68 40 11 PEF MAD041 B/E 4 1 68 44 12 RAT MAD041 FPH 4 1 68 48 13 NPHI MAD041 PU-S 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 10688 11002.5 10845.3 630 10688 11002.5 FONT MAD041 CP30 98.88 3343.44 955.994 467 10688 10921 NCNT MAD041 CP30 13480.1 47829.8 29652.9 467 10688 10921 RHOB MAD041 G/CC 1.896 3.03 2.49488 500 10688 10937.5 DRHO MAD041 G/CC -0.898 0.606 0.0659 500 10688 10937.5 RPD MAD041 OHMM 0.08 2000 81.1156 539 10688 10957 RPM MAD041 OHMM 0.08 2000 100.445 539 10688 10957 RPS MAD041 OHMM 0.68 1423.57 70.0276 539 10688 10957 Page 17 14-18b.tapx RPX MAD041 OHMM 0.54 1421.27 56.5898 539 10688 10957 FET MAD041 HR 3.47 120.18 12.4126 539 10688 10957 GR MAD041 API 16.03 565.52 97.192 525 10688 10950 PEF MAD041 B/E 1.07 13.02 3.27042 500 10688 10937.5 RAT MAD041 FPH 0.01 5390.04 428.878 630 10688 11002.5 NPHI MAD041 PU-S 4.66 62.11 20.1758 467 10688 10921 First Reading For Entire File..........10688 Last Reading For Entire File...........11002.5 File Trailer Service name... .......STSLIB.007 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/01/25 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/01/25 origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number....,.01 Next Tape Name.........,.UNKNOWN Comments .................STS LIS writing Library. Reel Trailer service name .............LISTPE Date . ...................08/01/25 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Physical EOF Physical EOF End Of LIS File scientific Technical services scientific Technical services Page 18
