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Home My WebLink About207-041MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 15, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-215 PRUDHOE BAY UN ORIN V-215 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/15/2024 V-215 50-029-23351-00-00 207-041-0 W SPT 4419 2070410 1500 1498 1494 1494 1493 25 120 130 136 4YRTST P Adam Earl 8/14/2024 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN ORIN V-215 Inspection Date: Tubing OA Packer Depth 90 2207 2098 2084IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240814145849 BBL Pumped:1.7 BBL Returned:1.8 Tuesday, October 15, 2024 Page 1 of 1 9 9 9 9 9 9 999 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.15 15:23:23 -08'00' Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. 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 have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 V-215 207041 500292335100 2 12/31/2023 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 27, 2020 SUBJECT: Mechanical Integrity Tests Hileorp North Slope, LLC V-215 PRUDHOE BAY UN ORIN V-215 Src: Inspector Reviewed By: P.I. Supry Comm Well Name PRUDHOE BAY UN ORIN V-215 API Well Number 50-029-23351-00-00 Inspector Name' Lou Laubenstein Permit Number: 207-041-0 Inspection Date: 8/23/2020 Insp Num: mitLOL200823150210 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-215 Type Inj W, TVD 7 4419 Tubing l 880 880 880 880 PTD 1 2070410 'Type Test SPT Test psi 1500 IA 859 2097 2060 2055 BBL Pumped: 0.5 BBL Returned: os OA 382 540 540 538 Interval 4YRTST p/F P Notes: ST— T p-'� 4,o CJZ.i C 4P- - � 1�1- ( 51ZO 1,-, pal- '!gyp Thursday, August 27, 2020 Page 1 of 1 Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Sunday, August 23, 2020 12:28 PM To: Wallace, Chris D (CED) Cc: Stan Golis; Aras Worthington; Oliver Sternicki; Travis Smith - (C); Brodie Wages; Regg, James B (CED) Subject: OPERABLE: Injector V-215 (PTD #2070410) AOGCC MIT -IA Passed Mr Wallace, Injector V-215 (PTD # 2070410) passed a 4 year required AOGCC witnessed MIT -IA on 08/23/20 post put on injection. The well is now classified as OPERABLE. Please respond with 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: Alaska NS - PB - Field Well Integrity Sent: Sunday, August 9, 2020 2:01 PM Regg, James B (CED) <jim.regg@alaska.gov> Cc: n Golis <sgolis@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver. ernicki@hilcorp.com>; Travis Smith - (C) <Travis.Smith@hilcorp.com>; Brodie Wages <David.Wa s@hilcorp.com> Subject: UNDE`f�EVALUATION: Injector V-215 (PTD #2070410) MIT -IA Passed Mr. Regg, Injector V-215 (PTD # 20704'W) was offline for required 4 year AOGCC witnessed MIT -IA due in May 2019. The well subsequently failed MIT -T durin water flood regulator change out / step rate testing in May 2020. Leaks were determined to be near water flood ection mandrels below the uppermost packer set at 5879' MD. A subsequent MIT - IA passed on 08/09/20 verifying prima nd secondary well barrier integrity. The well is now classified as UNDER EVALUTION and can be put on injection. Plan Forward: Operations: Put on injection Downhole Diagnostics: Perform 4 year AOGCC Well Integrity: Further diagnostics as required Please respond with questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity/ Compliance ryan.holt@hilcorp.com P: (907) 659-5102 ssed MIT -IA once thermally stable Wallace, Chris D (CED) From: Regg, James B (CED) Sent: Sunday, August 9, 2020 3:15 PM To: Wallace, Chris D (CED) Subject: FW: UNDER EVALUATION: Injector V-215 (PTD #2070410) MIT -IA Passed Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or jim.reggCcDalaska.gov. From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Sunday, August 9, 2020 2:01 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Stan Golis <sgolis@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Travis Smith - (C) <Travis.Smith@hilcorp.com>; Brodie Wages <David. Wages@hilcorp.com> Subject: UNDER EVALUATION: Injector V-215 (PTD #2070410) MIT -IA Passed Mr. Regg, Injector V-215 (PTD # 2070410) was offline for required 4 year AOGCC witnessed MIT -IA due in May 2019. The well subsequently failed MIT -T during water flood regulator change out / step rate testing in May 2020. Leaks were determined to be near water flood injection mandrels below the uppermost packer set at 5879' MD. A subsequent MIT - IA passed on 08/09/20 verifying primary and secondary well barrier integrity. The well is now classified as UNDER EVALUTION and can be put on injection. Plan Forward: 1. Operations: Put on injection 2. Downhole Diagnostics: Perform 4 year AOGCC witnessed MIT -IA once thermally stable 3. Well Integrity: Further diagnostics as required Please respond with questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well integrity/ Compliance ryan.hoItC@hilcorp.com P: (907) 659-5102 Wallace, Chris D (CED) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Tuesday, May 5, 2020 10:46 AM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W; AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Peru, Cale; Huber, Kenneth J Cc: Regg, James B (CED); AK, GWO DHD Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Janowski, Carrie; Sternicki, Oliver R; Worthington, Aras J; AK, GWO Well Integrity Well Information; Lau, Jack; Mcmullen, John C Subject: UPDATE: NOT OPERABLE: Injector V-215 (PTD #2070410) failed MIT -T All, Injector V-215 (PTD # 2070410) was made Not Operable on 05/27/19, due to impending lapse of its 4 -year AOGCC witnessed MIT -IA. At that time, there were no known integrity issues. On 05/03/20, during wellwork to configure the well to resume injection, it failed an MIT -T. The well remains NOT OPERABLE, and may not be brought online until barrier integrity is restored. Please respond with any questions. Adrienne McVey BP Alaska Well Integrity (Alternate: Ryan Holt) Office: (907) 659-5102 Harmony Radio: 2376 From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Monday, May 27, 2019 2:58 PM To: 'ch ris.waIlace @alaska.gov' <chris.waIlace @alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2Field PTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WeIIpad Lead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWellPad DFTN2@bp.com>; AK, OPS Well Pad HUQ<AKOPSWellPad HUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWeliPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWeliPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Nottingham, Derek <Derek.Nottingham@bp.com>; Youngmun, Alex <younak@BP.com> Cc: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWeIIIntegrityEnginee r@bp.com>; AK, GWO SUPT Well Integrity <AKDCWeIIlntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempseyl@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: NOT OPERABLE: Injector V-215 (PTD #2070410) will lapse on AOGCC MIT -IA All, Injector V-215 (PTD # 2070410) is due for its 4 -year AOGCC witnessed MIT -IA by the end of the month. Currently, there are no plans to bring the well online so it will lapse on the required AOGCC MIT -IA. The well is now classified as NOT OPERABLE for tracking purposes. When it is ready for injection, it will be re-classified to Operable and an AOGCC MIT -IA will be scheduled when thermally stable. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 Date: 5/19/2020 Transmittal Number: 93756 BPXA WELL DATA TRANSMITTAL Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 The digital zip file for the well log package listed below is being provided to you via SharePoint. If you have any questions please contact Merion Kendall: 907-564-5216; merion.kendall@bp.com. SW Name Log Date Company Description Format V-215 5/3/2020 READ Cased Hole Leak Detection Log Zip File Please Sign and Return one copy of this transmittal to GANCPDC@bp365.onmicrosoft.com Thank you, Mer Merion Kendall SIM Specialist ----------------------------------------------------------------------------------------------- BP Exploration Alaska|900 E. Benson Blvd.|Room: 716B|Anchorage, AK ----------------------------------------------------------------------------------------------- AOGCC https://bp365.sharepoint.com/sites/BPtoAOGCCElectronicPermittingandReporting/ Received by the AOGCC 05/19/2020 PTD:2070410 E-Set:33140 Received by: Abby Bell 05/19/2020 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Monday, May 27, 2019 2:58 PM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW, AK, OPS WELL PAD W; AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL, Nottingham, Derek; Youngmun, Alex Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: NOT OPERABLE: Injector V-215 (PTD #2070410) will lapse on AOGCC MIT -IA All, Injector V-215 (PTD If 2070410) is due for its 4 -year AOGCC witnessed MIT -IA by the end of the month. Currently, there are no plans to bring the well online so it will lapse on the required AOGCC MIT -IA. The well is now classified as NOT OPERABLE for tracking purposes. When it is ready for injection, it will be re-classified to Operable and an AOGCC MIT -IA will be scheduled when thermally stable. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-8110 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg I —l DATE: Monday,June 01,2015 P.I.Supervisor I` q ` SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC V-215 FROM: Johnnie Hill PRUDHOE BAY UN ORIN V-215 Petroleum Inspector Src: Inspector Reviewed By: P.1.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-215 API Well Number 50-029-23351-00-00 Inspector Name: Johnnie Hill Permit Number: 207-041-0 Inspection Date: 5/15/2015 Insp Num: mitJWH150516133916 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-215 Type Inj W'1TVD 4419 Tubing) 943 945 - r 944 _ 944 • PTD] 2070410 (Type Test SPT Test psi 1500 - IA 723 2502 2473 . 2467 Interval rYRTST IPF P ✓ OA 361 596 - 593 589 Notes: Sate° jiIL 1 3 2015 Monday,June 01,2015 Page 1 of 1 Image jest Well Hist®ry File Cr Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ (,~ ~ - ~ ~-tJ Well History File Identifier Or anizing (done) 9 ^ Two-sided III II' III II III II III ^ Rescan Needed III II'III II II III III RE AN DIGITAL DATA OVERSIZED (Scannable) l It C No i Diskettes ^ Maps: ems: or o . , ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other.: ~' BY: ~Mari~a Date:. ~' ~' ~ (~ ~' /s/ I -- Pro -ect Proofin I g II I II II II I I III I I III BY: Maria Date: ~ ti ~ ~ ~ /s/ J Scanning Preparation ~~ x 30 = l/~ ~ + ~ =TOTAL PAGES ~ / ~ /~ ~ '"" " ~~ (Count does not include cover sheet) ., / / BY: Maria Date: L, 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: ~ °'°" ~~ ' 1,.~ ~ /s/ ~~~ I Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II'I II I II II I I II ReScanned III IIIIIIIIIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked III I) IIII III II'I III 10/6/2005 Well History File Cover Page.doc • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday, June 22, 2011 / P.I. Supervisor � F'(Z /( SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V -215 FROM: Bob Noble PRUDHOE BAY UN ORIN V -215 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry v j NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN ORIN V - 215 API Well Number: 50 029 - 23351 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110622064808 Permit Number: 207 - 041 - Inspection Date: 6/18/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i V -215 ' Type Inj. 0 I TVD 4419 j IA 0 2700 - 2620 2600 " -1 2070410 I SPT (-- - P.T.D T ypeTest N est psi L 2700 OA 7 1060 1070 1070 Interval 4YRTST p/F P - Tubing 2100 2100 2100 2100 Notes: A . r al 4e si -- 1 5e rs; *AWNED JUG }. 4 ' L E i Wednesday, June 22, 2011 Page 1 of 1 ,. .~,;, ~, ~, ~; ~" ~, rir ~ ~~ _~. ~, ~` 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 August 14, 2009 ~~a~~~,G,~r'.~~'~~ ~~~, ' _ ~~ `~,~i~;~ . bp ~~~~~~~~ OCT ~ 5 2Q09 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, ~8 Oii & Gas Cons. ~a~r~m~a~~n~, Anchorape ~~7~-d ~-1 V ~ ~~J~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- Pad 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) Date V-pad 8/13l2009 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 V-01 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-03 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 5002s233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 V-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 V-102 2020330 50029230700000 NA 7.75 NA 98.2 8/7/2009 V-103 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009 V-104 2021420 50029231030000 NA 1.5 NA 21.3 7/11/2009 V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-106A 2041850 50029230830100 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-109 2022020 50029231200000 NA 1.2 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233000000 NA 1.5 NA 15.3 5l10l2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-1t4A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 5002923t950000 NA 1.5 NA 13.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-122 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 V-2oi 2012220 50029230540000 SC leak NA 4 NA 90.6 8/7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009 V-203 2051680 50029232850000 NA 2 NA 12.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061800 50029233380000 NA 1.8 NA 13.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-210 2042100 50029232310000 NA 2 NA t8.7 7/11/2009 V-211 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-212 2051500 50029232790000 NA 1.2 NA 11.9 6/29/2009 V-213 2Q4/160 50029232t30000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 50029233510000 NA 2.8 NA 30.6 6/30/2009 V-216 2041300 50029232160000 NA 1.5 NA 13.6 6/29/2009 V-21~ 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7/12/2009 V-219 2081420 50029233970000 IVA 1 NA 16.2 7/12/2009 ~e 2080200 50029233830000 NA 1.75 NA ~6 3/9/2008 V-221 2050130 50029232460000 NA 0.8 NA 8.5 6/29/2009 V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9!7/2008 l~ ~-~ DATA SUBMITTAL COMPLIANCE REPORT 5/7/2009 Permit to Drill 2070410 Well Name/No. PRUDHOE BAY UN GRIN V-215 Operator BP EX PLORATION (ALASKA) INC API No. 50-029-23351-00-00 MD 6535 TVD 4945 Completion Date 4/26/2007 Completi on Status WAGIN Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: DIR / GR, GR / RES PWD, AZI-DENS / NEU, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data. Digital Dataset Log Log Run Interval OH / Ty/ae Med/Frmt Number Name Scale Media No Start Stop CH Received Comments og Cement Evaluation 5 Col 0 6400 Case 5/16/2007 USIT, CBL, CCL, GR 23- Apr-2007 `~ p~ CED D Asc Directional Survey 0 6535 Open 5/11/2007 i ~pt Directional Survey 0 6535 Open 5/11/2007 t ;~ C Lis 15452 Induction/Resistivity 97 6535 Open 9/28/2007 LIS Veri, GR, ROP, FET, RAM, DRHO, NPHI w/PDS and TIF graphics ''Log 15452 Induction/Resistivity 25 Blu 108 6353 Open 9/28/2007 MD Vision Services 20-Apr- 2007 d'Log 15452 Induction/Resistivity 25 Blu 108 6353 Open 9/28/2007 TVD Vision Services 20- Apr-2007 Y€D C Lis 15588 Casing collar locator 9 6332 Case 10/26/2007 LIS Veri, USIT, CCL w/PDS graphics Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 517/2009 Permit to Drill 2070410 Well Name/No. PRUDHOE BAY UN ORIN V-215 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23351-00-00 MD 6535 TVD 4945 Completion Date 4/26/2007 Completion Status WAGIN Current Status WAGIN UIC Y ADDITIONAL INFORMATION Well Cored? Y N~ Daily History Received? N Chips Received? <'YTN- Formation Tops ~ N Analysis Y / N Received? __ __ __ _ __ __ Comments: Com liance Reviewed B Date: p Y _ ~ ~ --p~~4J v i Schla~lerger Schlumberger-OCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4454 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris orlon Borealis Date BL Color CD W-213 V-215 11661175 11594491 MEM TEMP/PRESS SURVEY CH EDIT PDC GR U51 09/29/07 04/23/07 1 1 Z-108 71212828 OH WIRELINE PEX EDIT ' 02!05/OB 2 1 5-124 40014242 OH MWDILWD EDIT 11/05106 3 1 5-125P81 40015467 OH MWDILWD EDIT 07/07/07 2 t V-121 40075007 OH MWD/LWD EDIT 3k 03124/07 2 7 V-222 40015319 OH MWDILWD EDIT 06!08/07 2 1 W-210 40014842 OH MWD/LWD EDIT 02126/07 2 1 V-278 40015066 OH MWD/LWD EDIT 04/07/07 2 t W-204 40014637 OH MWDILWD EDIT 01/29/07 2 1 W-204PB7 40014637 OH MWDILWD EDIT 01/24/07 2 1 W-204L1 40074637 OH MWDILWD EDIT 02/07107 1 t W-204L2 40014637 OH MWD/LWD EDIT - liP- 02/20107 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXploration (Alaska) Inc. Petrotechnical Data Center_Lft2-1 - - 900 E Benson Blvd. ~ '~ Anchorage AK 99508-4254, - ~ - Date Delivered: d"a +^~`e a ~- - , i ~ i ' -iL~~..-n 9 .., " 1~ tJ t.i i Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth A Received byt/, J(~/~/~-~ 1a191o7 `I u 09/27/07 l~l ~J J SChl~~~e~g~r Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND E.T RNI G`O ~~~`~~ ~~~CH TO: r a ~ .<1 d ~ f 4,,., NO. 4432 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 700 Anchorage,AK 99507 Field: P. Bay Orion Date BL Color CD W-39 V-275 17216797 40015122 MCNL OH EDIT MWD/LWD 0/29/06 04/20107 1 2 t 1 V-203L2 40072957 OH EDIT MWD/LWD 01130/08 2 t V•203L3 V-203L4 40012957 40072957 OH EDIT MWDILWD OH EDIT MWDILWD / 02/05/06 02/11/06 2 2 1 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-t 900 E Benson Blvd. ~~, ~ I , n ~ rl (~-j Anchorage AK 99508-4254 p O 1111/ Date Delivered: e „~,•I ~"+;}'~"(aST~I"1`~~~)X~ ~~ ~ -± !` Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~r Page 1 of 1 Maunder, Thomas E (DOA} From: Hubble, Terrie L ITerrie.Hubble@bp.com] Sent: Vllednesday, July 11, 2007 1:23 PM To: Maunder, Thomas E (DOA) Subject: RE: V-215 (207-041) Hi Tom, I will be happy to supply a revised 10-407 for this well. 1 was about to do so anyway since it has recently gone on injection. Yes, there was a problem with the tubing summary and a revised summary has since been supplied. Also, I see that the packers exceeded the box size and so they are not showing. I will certainly try harder to make sure I don't make these kinds of errors. As for the diagram, it is part of our routine to include one for every submittal (10-404 and 10- 407). 1 usually locate it at the very back of the package (behind the survey). I'm hoping that it is in your package??? In any case, I will make sure it is in the revised package. Sorry for the trouble and thanks for your help. Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, July 11, 2007 12:52 PM To: Hubble, Terrie L Cc: Saltmarsh, Arthur C (DOA); Smith, Chasity R (DOA) Subject: V-215 (207-041} Terrie, E am reviewing the 407 you submitted at the end of May. I am requesting that you submit a revision. In box 24, the tubing setting depth and packer depth do not agree with what is in the operational summary for April 25. Also, there are 3 packers in the well. You shou{d also include the actual well drawing if available. Thanks in advance. Calf or message with any questions. Tom Maunder, PE AOGCC 7/11/200? • STATE OF ALASKA ~~ ALASKA OIL AND GAS CONSERVATION COM SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revis+llcl QBf11`IAT: ca»cta Tbg k~o arM t~ on x~J.Gion „~ 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC 25.105 zoAAC 2s.~,o ^ GINJ ^ WINJ ^ WDSPL ®WAG ^ Other No. of Completions One 1b. Well Class: ^ Development ^ Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband 4/26/2007- 12. Permit to Drill Number 207-041 ' 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 4/16/2007' 13. API Number S0-029-23351-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 4/20/2007 14. Well Name and Number: PBU V-2151 4657 FEL, SEC. 11, T11 N, R11 E, UM FSL, 1760 Top of Productive Horizon: 1793' FSL, 5108' FEL, SEC. 12, T11 N, R11 E, UM 8. KB (ft above MSL): 81.4' Ground (ft MSL): 52.9' 15. Field /Pool(s): Prudhoe Bay Field / Orion Total Depth: 1493' FSL, 4899' FEL, SEC. 12, T11N, R11E, UM 9. Plug Back Depth (MD+TVD) 6437 4866 Schrader Bluff 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 590544 y- 5969904 Zone- ASP4 10. Total Depth (MD+TVD) 6535 4945 16. Property Designation: ADL 028240 _ TPI: x- 592511 y- 5967064 Zone- ASP4 Total Depth: x- 592725 y- 5966766 Zone- ASP4 11. SSSV Depth (MD+TVD) None None 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): 1793' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIR / GR, GR / RES PWD, AZI-DENS / NEU, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM "SIZE ' CEMENTING RECORD PULLED 20" 215.5# A-53 Surface 108' Surface 108' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 29' 3531' 29' 2885' 12-1 /4" 532 sx AS Lite 409 sx Class 'G' 7" 26# L-80 26' 6521' 26' 4934' 8-3/4" 353 sx Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24: TuewG RECORD If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 4-1/2" Gun Diameter, 5 spf 3-1l2", 9.2#, L-80 6277' 5879', 5990', 6162' MD TVD MD TVD 5920' - 5964' 4451' -44$6' 6002' - 6034' 4516' - 4541' 25 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6046' - 6068' 4551' - 4569' DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED 6182' - 6238' 4660' - 4705' 2475' Freeze Protect w/ 88 Bbls of Diesel 26. PRODUCTION TEST Date First Production: July 1, 2007 Method of Operation (Flowing, Gas Lift, etc.): Waterlnjection Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PfesS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^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 ~ 1. i None ~ S BFL JUL 17 2007 Form 10-407 Revised 02/2007 ~ F.( ~ 1 ` , ~ ~ ~ ~ ~ONTINUED ON REVERSE SIDE 1~~~~,',~~~~,y[7 ~ `~ , 1°L' ~~~~ /~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested . ^ Yes ®No Permafrost Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 1915' 1793' detailed test information per 20 AAC 25.071. Ugnu 3643' 2958' Ugnu MA 5368' 4047' None Ugnu MB1 5441' 4095' Ugnu MB2 5540' 4161' Ugnu MC 5594' 4200' Schrader Bluff NA 5715' 4290' Schrader Bluff NB 5746' 4314' Schrader Bluff NC 5786' 4346' Schrader Bluff NE 5793' 4351' Schrader Bluff NF 5861' 4404' Schrader Bluff OA 5919' 4450' Schrader Bluff OBa 6001' 4515' Schrader Bluff OBb 6045' 4550' Schrader Bluff OBc 6114' 4605' Schrader Bluff OBd 6179' 4658' Schrader Bluff OBe 6258' 4721' Schrader Bluff OBf 6310' 4763' Base Schrader Bluff 6371' 4813' Colville Mudstone 6371' 4813' Formation at Total Depth (Name): Colville Mudstone 6371' 4813' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore ing is true and correct to the best of my knowledge. / Si d ~~ 1 ~ ~ gne { Q~ Terrie Hubble Title Technical Assistant Date PBU V-2151 207-041 Prepared By Name/Number Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Brandon Peltier, 564-5912 INSTRUCTIONS GeNeRAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. 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 TVD 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 25.071. Form 10-407 Revised 02/2007 Submit Original Only STATE OF ALASKA 6~ I~EC~IVED ALASK OIL AND GAS CONSERVATION COM~SSION MAY 3 1 2007 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oi Gas Cons. Commission 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ®WAG ^ Other of Completions One 1 b. Well C ss: ^ D elopment ^ Exploratory ® rvice ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date omp Susp., or Ab 4/26/2007 ~~ 12. ermit to Drill Number 207-041 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 4/16!2007 ~ 3. API Number 50-029-23351-00-00 ' 4a. Location of Well (Governmental Section): Surface: 46 ' ' 7. Date T.D. Reached 4/20/2007 14. Well Name and Number: PBU V-2151 57 FSL, 1760 FEL, SEC. 11, T11 N, R11 E, UM Top of Productive Horizon: 1793' FSL, 5108' FEL, SEC. 12, T11 N, R11 E, UM 8. KB (ft above MSL): .4' Ground (ft MSL): 52.9' - 15. Field /Pool(s): Prudhoe Bay Field / Orion Total Depth: 1493' FSL, 4899' FEL, SEC. 12, T11 N, R11 E, UM 9. Plug Back Depth (M +Typ) 6437 4866 Schrader Bluff 4b. location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 590544 y- 5969904 Zone- ASP4 10. Total Depth ( +TVD) 6535 - 4945 ~ 16. Property Designation: ADL 028240 TPI: x- 592511 y- 5967064 Zone- ASP4 Total Depth: x- 592725 y- 5966766 Zone- ASP4 11. SSSV De (MD+TVD) one None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No ubmit electronic and rinted information er 20 AA 25. 0 19. Wate depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1793' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and print information per 20 AAC 25.071): DIR / GR, GR / RES PWD, AZI-DENS / NEU, USIT 22. CASING, LINER D CEMENTING RECORD CASING SETTING DEPTH M SETTING D EPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP OTT TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 215.5# A-53 Surface Surf 1 42" 260 sx Arctic Se A r x. -5/8" 40# L-80 29' 31' 29' 2885' 12-1/4" 532 sx AS Lite 409 sx Class'G' 7" 26# L-80 26' 521' 26' 4934' 8-3/4" 353 sx Class 'G' 23. Open to production or inject ion? ®Yes o / 24. ' Tue,N` ~, Ro If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open t' G~ rforation Size aYlp Umber): SIZE D H SET MD P KER SET MD 4-1/2" Gun Diameter, 5 spf ~ 1V 3-1/2", 9.2#, L-80 7050' 6574', MD TVD ryW' TVD 5920' - 5964' 4451' - 4486' ~ 6002' - 6034' 4516' - 4541' 25. AGID, FRACTURE, CEMENT__ QUEEZE, ETC. 6046' - 6068' 4551' - 4569' DEPTH INTERVAL MD AMOUN IN OF MATERIAL USED - 6182' - 6238' 4660' - 4705' ~ 2475' Freeze Prote w/ 88 Bb s iesel ~ A j I A `~~ ~ e 26. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours T Sted: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaS g PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORR): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A uired? ^Yes No If Yes to either quest' n, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or ter (submit separates ets with this form, 'rf needed). Submit detailed descriptions, core chips, photographs and laboratory analytical resylts ?O ABC 250.071. ~ ~..,. 0~''' None lqq 6, '0 Form 10-407 Revised 02/2007 /~ ~ ~ ~ { ~ /~ ~ONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS LIST ALL FORMATIONS AN RS ENCOUNTERED): 29. FORMATION TESTS NAME M TVD Well Teste ^ Yes ®No Permafrost Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 1915' 1793' detailed test information per 20 AAC 25.071. Ugnu 3643' 2958' Ugnu MA 5368' 4047' None Ugnu M61 5441' 4095' Ugnu M62 5540' 4161' Ugnu MC 5594' 4200' Schrader Bluff NA 5715' 4290' Schrader Bluff NB 5746' 4314' Schrader Bluff NC 5786' 4346' Schrader Bluff NE 5793' 4351' Schrader Bluff NF 5861' 4404' Schrader Bluff OA 5919' 4450' Schrader Bluff OBa 6001' 4515' Schrader Bluff OBb 6045' 4550' Schrader Bluff OBc 6114' 4605' Schrader Bluff OBd 6179' 4658' Schrader Bluff OBe 6258' 4721' Schrader Bluff OBf 6310' 4763' Base Schrader Bluff 6371' 4813' Colville Mudstone 6371' 4813' Formation at Total Depth (Name): Colville Mudstone 6371' 4813' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoi g is true and correct to the best of my knowledge. ~5/ 3 ~ /O Signed Terrie Hubble Title Technical Assistant Date PBU V-2151 207-041 Prepared By Name/Number. Terrie Hubble, 564-4828 Drilling Engineer: Brandon Peltier, 564-5912 Well Number P rmit N . / 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 welt schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level 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. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and 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. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITeM 29: Provide a 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 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: V-215 Common Name: V-215 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW ~ Surtace Pressure ~ Leak Off Pressure (BHP) EMW -_ __ _ _ __ 4/19/2007 LOT 3,561.0 (ft) 2,891.0 (ft) 8.80 (ppg) ~ 470 (psi) ~ 1,792 (psi) -11.93 (ppg) Printed: 4/30/2007 11:51:45 AM ~ ~ BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: V-215 Common Well Name: V-215 Spud Date: 4/16/2007 Event Name: DRILL+COMPLETE Start: 4/15/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/26/2007 Rig Name: NABOBS 9ES Rig Number: Date From - To !Hours Task i Code NPT Phase 4/15/2007 00:00 - 04:00 ~ 4.00 MOB ~ P ~ PRE 04:00 - 07:00 3.00 DIVRTR P PRE 07:00 - 08:00 1.00 MOB P PRE 08:00 - 09:00 1.001 RIGU ~ P PRE 09:00 - 12:00 I 3.001 DIVRTR I P I I PRE 12:00 - 14:00 I 2.001 RIGU I P I I PRE 14:00 - 17:00 3.00 RIGU P PRE 17:00 - 18:00 1.00 RIGU P PRE 18:00 - 18:30 0.50 RIGU P PRE 18:30 - 19:00 0.50 RIGU P PRE 19:00 - 20:30 1.50 RIGU P PRE 20:30 - 21:00 0.50 RIGU P PRE 21:00 - 21:30 0.50 DIVRTR P PRE 21:30 - 23:00 I 1.501 RIGU I P I I PRE 23:00 - 23:30 I 0.501 DIVRTR I P I I PRE Description of Operations PJSM. Move pit complex away from rig and spot on pad. Move from V-218i around pad and position rig near V-215i. Spot matting boards and lay herculite. Set rig down over V-2151. Install surface hydril on conductor. Spot wellhead equipment behind cellar. Spot and nipple up diverter lines. PJSM with Peak. Spot mud pits. Place matting boards under pits and lay herculite under flowline. Connect high pressure lines in interconnect. Spot cuttings tank. Take on cold water in mud pits. 'Accept rig for operations on V-2151 C~3 09:00 hr., 4/15/2007. PJSM. Nipple up 20" riser and dresser sleeve. Install 4" low pressure valve on conductor. Prepare 4" drillpipe and HWDP in pipeshed. Prepare rig floor. Spot third party work units, mix spud mud. Work on Pre-Spud checklist. PJSM. Pick up 3,250' of 4" drillpipe and rack back in derrick. Pick up 735' of 4" HWDP and rack back in derrick. Make up JAR stand with 5" HWDP and rack back in derrick. Conduct a Rig Evacuation Drill. Held post drill discussion. Mix spud mud while waiting on BHA tools delivery. (Truck availability) Make up 7" DC stand with NB STAB. Conduct Diverter function and accumulator tests. Witnessing of test waived by AOGCC rep Bob Noble. Test witnessed by BP WSL R. French, NAD TPs R. Hunt and R. Axness. Stand back DC stand. PJSM -Pre-spud meeting. Pick up and make up BHA #1: New 12.25" HTC MXL-1 bit, 1.5 deg ABH PDM, NM lead DC, 12.25" NM STAB, MWD, 12.25" NM STAB, NM XO, UBHO, 8.75" NM STAB, NM DC. Fill hole and check for leaks - OK. Pressure test surface lines to 3,000 psi - OK. 23:30 - 00:00 0.50 RIGU P PRE _- 4/16/2007 00:00 - 02:30 2.50 DRILL P SURF 02:30 - 03:00 0.50 DRILL P SURF 03:00 - 12:00 9.00 DRILL P SURF 12:00 - 17:00 I 5.001 DRILL I P I I SURF 17:00 - 17:30 0.50 DRILL P SURF 17:30 - 18:30 1.00 DRILL P SURF 18:30 - 19:30 1.00 DRILL P SURF 19:30 - 20:00 0.50 DRILL P SURF Spud V-2151 ~ 00:01 hr, 4/16/2007. Drill from 108' to 355'. 550 gpm, 655 psi, 65 rpm, .6k TO. Gyro surreys every connection. Wipe 30' without rotating. POH to 173'. Make up JAR stand and run in hole to 268'. Wash down to 355', no fill. Directionally drill from 355' to 1,100'. 550 gpm, 1,700 psi off, 1,866 psi on, 65 rpm, 1.8k TO off, 4.2k TO on, PU - 69k, SO - 55k, RWT - 62k, WOB - 35k. AST - 6.57 hrs, ART - 1.87 hrs. Gyro surveys every connection to 723'. Wipe 30' without rotating. Directionally drill from 1,100' to 1,769'. 700 gpm, 2,490 psi off, 2,600 psi on, 80 rpm, 4.1 k TO off, 6.1 k TO on, PU - 77k, SO - 69k, RWT - 70k, WOB - 35k. AST - 6.57 hrs, ART - 1.87 hrs. Wipe 30' without rotating prior to connections. Circulate bottoms up ~ 700 gpm, 2,490 psi, 2,425 psi FCP. W iper trip from 1,769' to 268'. PU - 81 k, SO - 73k. Run in hole from 268' to 1,578'. Tight from 1,300' to 1,452'. Wash from 1,578' to 1,759', no fill. 700 gpm, 2,300 psi, 80 rpm, 4.2k TO. Printed: 4/30/2007 11:51:50 AM BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: V-215 Common Well Name: V-215 Spud Date: 4/16/2007 Event Name: DRILL+COMPLETE Start: 4/15/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/26/2007 Rig Name: NABOBS 9ES Rig Number: Date ;From - To 1 Hours ' Task ;Code NPT Phase Description of Operations 4/16/2007 20:00 - 00:00 4.00 DRILL ~ P SURF Directionally drill from 1,769' to 2,534'. 700 gpm, 2,685 psi off, 4/17/2007 100:00 - 05:30 5.501 DRILL ~ P 05:30 - 06:00 0.50 DRILL P 06:00 - 06:30 0.50 DRILL P 06:30 - 08:00 I 1.501 DRILL I P 08:00 - 09:00 1.00 DRILL P 09:00 - 10:30 1.50 DRILL P 10:30 - 12:00 1.50 DRILL P 12:00 - 13:00 I 1.001 DRILL I P 13:00 - 16:00 3.00 DRILL P 16:00 - 19:00 3.00 DRILL P 19:00 - 20:30 1.50 CASE P 20:30 - 21:00 I 0.501 CASE I P 21:00 - 00:00 I 3.001 CASE I P 14/18/2007 100:00 - 03:00 I 3.001 CASE I P 2,945 psi on, 80 rpm, 2.4k TQ off, 6.1 k TO on, PU - 84k, SO - 70k, RWT - 78k, WOB - 30k. AST - 4.67 hrs, ART - 2.01 hrs. Wipe 30' without rotating prior to connections. *Hydrates 2,260'. SURF Directionally drill from 2,534' to 3,489'. 700 gpm, 3,275 psi off, 3,490 psi on, 80 rpm, 3.4k TO off, 7.6k TO on, PU - 90k, SO - 70k, RWT - 78k, WOB - 30k. Backream 30' prior to connections. SURF Circulate for samples and log evaluation. SURF Directionally drill from 3,489' - 3541'. - 700 gpm, 3,275 psi off, 3,490 psi on, 80 rpm, 3.4k TO off, 7.6k TO on, PU - 90k, SO - 70k, RWT - 78k, WOB - 30k. Backream 30' prior to connections. SURF CBU 3x - 240 gpm / 700 gpm, 3000 psi -100 rpm / 4k fUlbs -100k PUW / 75k SOW Monitor well for 5 min, static 9.5 ppg in/out SURF POH f/ 3541' - 2820' -25k Overpult and started swabbing slightly SURF Backream from 2820 - 1582' C~1 650 gpm / 2500 psi / 100 rpm No Problems cleaning up hole SURF RIH to 3490' * 20 - 25k drag from 2810 - 3470' SURF CBU @ 240 gpm / 700 gpm, 3000 psi -100 rpm / 4k ft/Ibs -100k PUW / 75k SOW / 88k RtWt Monitor well for 5 min, static 9.5 ppg in/out SURF POH from 3541 - 178' (top of BHA) Precautionary backream 2 stands from 2056' - 1865' Hole started swabbing slightly, Proper fill on the remainder of the trip SURF Lay down BHA #1 down -Clean & Clear rig floor SURF PJSM Make Dummy run with casing hanger -Change out bales and install long bales -M/U Franks fill up tool -R/U casing elevators, Slips, & power tongs -Ready rig floor to run casing SURF PJSM with NAD rig crew, NAD Toolpusher, NAD casing crew and BP WSL SURF -Ran 42 of 86 jts of 40# L-80 9 5/8" BTC surface casing. -Bakerlock Shoe Track -TO to 9200 ft/Ibs / BOL 2000NM pipe dope -25 -Bow Spring centralizers ran on the first 25 joints into hole -Fill every joint SURF Ran a total of 86 jts of 40# L-80 9 5/8" L-80 BTC surface casing. Printed: 4/30/2007 11:51:50 AM BP EXPLORATION Operations Summary Report Page 3 of 10 Legal Well Name: V-215 Common Well Name: V-215 Spud Date: 4/16/2007 Event Name: DRILL+COMPLETE Start: 4/15/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/26/2007 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task ~ Code ~ NPT ~ Phase ~ Description of Operations 4/18/2007 00:00 - 03:00 3.00 CASE P SURF -Bakerlock Shoe Track -TO to 9200 ft/Ibs / BOL 2000NM pipe dope -25 -Bow Spring centralizers ran on the first 25 joints into hole -Fill every joint 168k PUW / 90k SOW **20-25k drag C~ 2031-2153', ran through slow without pumping 03:00 - 03:30 0.50 CASE P SURF R/D Franks Fill up tool and M/U 9 5/8" double plug Cement Head 03:30 - 05:30 2.00 CEMT P SURF Circulate and condition mud, PUW 145 /SOW 105k Break circ ~ 2bpm / 400psi. Reciprocate pipe 15'. -Staged up to 8 bpm / 600 psi. Clear floor of Csg equip. -Treat mud, lower vis to 80 sec/qt and yp to 18 -Comprehensive Pre-Job meeting with D/S cementers, BP WSL, NAD TP & rig crew, -Pre-job meeting with BP WSL, VECO truck drivers, MI mud engineer and Applicable NAD rig hands. 05:30 - 10:00 4.50 CEMT P SURF Switch Over to Dowell -Pump 5 bbls water ahead. -PT lines to U3500 psi. -Pump 70 bbls of 10.5 ppg Mudpush II @ 5bpm -Drop bottom plug. -Pump 427 bbls of 10.7 ppg Arctic Set Lite lead Cement ~ 5 bpm -Pump 83 bbls of 15.8 ppg Class "G" Tail Cmt slurry w/ CemNet in the last 15 bbls @ 5bpm Drop top plug and chase with 10 bbls water Switch over to Rig Pumps - Chase cement with 251.8 bbls of 9.5 ppg mud ~ 5bpm / 650 psi. *Bump plug ~ 3612 strokes and pressure up to 2000 psi, held for 5 min. - CIP ~ 09:55 AM. *Reciprocate pipe until within 85 bbls of bumping plug. *180K up / 80K down. *180 bbls of cement back to surface. Check floats -OK. R/D Cmt head. 10:00 - 15:00 5.00 DIVRTR P SURF R/D Diverter line, flush Riser, Hydril, Landing joint, Flow line and all other related equipment. UD Landing joint, remove 20" Riser. Remove surface Hydrill & secure cellar. R/D Casing elevators & slips. C/O Bales, clear & prep rig floor. 15:00 - 16:30 1.50 WHSUR P SURF C/O 20" Dresser sleeve t/ 16" air boot. PJSM- Lift in well head equipment f/ behind cellar. PJSM- Install Split speed head & test t/ 1000 psi.for 10 minutes OK, Install tubing spool. 16:30 - 18:30 2.00 BOPSU P SURF PJSM- P/U & N/U BOPE, install Riser, M/U turnbuckles. 18:30 - 20:00 1.50 BOPSU P SURF PJSM -R/U & flush stack. -R/U to test BOP's & all related equipment. 20:00 - 00:00 4.00 BOPSU P SURF PJSM, Test BOPE, 250 low, 4000 psi high, holding each test for 5 min. -Test #1 -Top Rams, Dart, HCR Kill, and choke manifold Printed: 4/30/2007 11:51:50 AM • i BP EXPLORATION Operations Summary Report Page 4 of 10 Legal Well Common W Event Nam Contractor Rig Name: Date i Name: ell Name: e: Name: From - To V-215 V-215 DRILL+C NABOB NABOB Hours OMPLE S ALASK S 9ES Task TE A DRI Code LING NPT Start I Rig Rig Phase ~ Spud Date: 4/16/2007 : 4/15/2007 End: Release: 4/26/2007 Number: Description of Operations 4/18/2007 20:00 - 00:00 4.00 BOPSU P SURF valves 1, 2 & 3 -Test #2 -choke manifold valves 4, 5 & 6 &TIW -Test #3 -choke manifold valves 7, 9 -Test #4 -manual choke (tested 250 low / 1500 psi high) -Test #5 - Hyd. Choke, valves 8, 11 -Test #7 -choke manifold valves 10, 13, 14, -Test #8 -choke manifold valve # 12 -Test #9 -choke manifold valve # 15 -Test #10 -Lower IBOP, HCR Choke & Kill valves -Test #11 -Manual Choke & Kill valve, Lower IBOP -Test #12 -Lower Pipes & Upper IBOP -Test #13 -Annular to 250 psi Low, 3500 psi High Accumulator test Initial pressure 3000, 1,600 psi after functioning all valves, 18 sec for 200 psi, 2 min 36 sec for full recovery to 3,000 psi Average charge for 6 bottles of Nitrogen is 2,080 psi -Test #14 -Blind Rams Tested Gas alarms & PVT. Test witnessed by BP WSL Dave Newlon, NAD TP Brian Tiedemann & Randy Axness, Test waived by AOGCC Lou Grimaldi. 4/19/2007 00:00 - 01:00 1.00 BOPSU P SURF Pull test plug & install wear bushing. Clear floor of test equipment. 01:00 - 02:00 1.00 DRILL P PROD1 P/U 24 joints 4" DP & stand back in derrick. 02:00 - 05:00 3.00 DRILL P PROD1 PJSM, Schlumberger Handling RA source on surface M/U BHA #2 8.75" PDC Bit, 6 3/4" PDM, NM Stab, LWD/MWD, 2 x NMDC, XO, HWDP, Jars, HWDP, XO, 24x4" HWDP Successful Shallow hole test of MWD/LWD, 993' / 550 gpm / 1350 psi 05:00 - 07:00 2.00 DRILL P PROD1 RIH Picking up 4" Dp 1 x 1 07:00 - 08:30 1.50 DRILL P PROD1 Slip and cut drilling line -Service Crown, TDS and Drawworks 08:30 - 09:00 0.50 DRILL P PROD1 RIH to 3200', Break circ. F/10 min. 09:00 - 10:00 1.00 DRILL P PROD1 Rig up and Test 9 5/8" casing to 3500 psi for 30 min., Good Test Out of the critical path Safety meeting; Operational procedures for conducting a Stripping Drill NAD rig crew and Toolpusher Kelly Cozby, BP WSL Alan Madsen 10:00 - 12:00 2.00 DRILL P PROD1 Conduct D-6 Stripping Drill and D-5 well control drill with NAD Rig Crews and Toolpusher Kelly Cozby, BP WSL Alan Madsen 12:00 - 12:30 0.50 DRILL P PROD1 Wash down and Tag Float collar @ 3446'md -565 gpm / 2400 psi / 80 rpm PUW 107k /SOW 68k / RtWt 85k 12:30 - 13:30 1.00 DRILL P PROD1 Drill out F/C amd Shoe tract, F/S and 20' of new hole to 3561' and -565 gpm / 2400 psi / 80 rpm / 5-10k WOB PUW 107k /SOW 68k / RtWt 85k 13:30 - 14:00 0.50 DRILL P PROD1 Displace to 8.8 new LSND mud 580 gpm / 1250 psi / 80 rpm Printed: 4/30/2007 11:51:50 AM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: V-215 Common Well Name: V-215 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date ~ From - To Hours Task ~ Code NPT -- 4/19/2007~14:00 - 14:30 I 0.50 DRILL P Start: 4/15/2007 I Rig Release: 4/26/2007 Rig Number: Page 5 of 10 ~ Spud Date: 4/16/2007 End: t Phase Description of Operations PROD1 Perform LOT @ 3561' and / 2891' tvd 8.8 ppg mud in/out 470 psi / 11.96 EMW, Monitor pressures for 10 min Estabilish SPR's and Benchmark ECD's 14:30 - 00:00 I 9.501 DRILL I P PROD1 Drill Directionally as per Anadrill Directional Driller, 3561' - 5589' (4195'tvd) -100Rpm,5kTgoff/7TgOn - 585 gpm, 1950 psi off / 2150 psi on - 10-25k WOB -PUW= 125k, SOW=80k, RtWt= 101k - CECD = 9.72 /AECD = 10.19 - Backream 60' /stand each connection full drilling rates, - reduced pump rates to 75% of drlg. rate on down stroke - Pumped 30 bbl 1.5# Weighted Sweep ~ 4500', 10-15% increase in cuttings AST=1.28 hrs /ART=3.43 hrs./ADT=4.71 4/20/2007 100:00 - 06:00 I 6.001 DRILL I P 06:00 - 06:30 I 0.501 DRILL I P 06:30 - 11:30 I 5.001 DRILL I P 11:30 - 15:30 I 4.001 DRILL I P 15:30 - 17:00 I 1.501 DRILL I P 17:00 - 19:00 2.00 CASE P 19:00 - 21:30 2.50 CASE P 21:30 - 00:00 ~ 2.50 ~ CASE ~ P PROD1 Drill Directionally as per Anadrill Directional Driller, 5589' - 6535'(4945'tvd) -100Rpm,7kTgoff/9TgOn - 585 gpm, 2400 psi off / 2700 psi on - 10-25k WOB -PUW= 148k, SOW=93k, RtWt= 115k - CECD = 9.81 /AECD = 10.43 9.1 ppg MW - Backream 60' /stand each connection full drilling rates, - reduced pump rates to 75% of drlg. rate on down stroke AST = 1.58 hrs /ART = 2.91 hrs /ADT = 4.49 hrs PROD1 Pump 38 bbl 11.1 weighted sweep (21b over) ~ 585 gpm 2400 psi - Start Backreaming when sweep was in case hole - Sweep returned a increase in cuttings by 10-15% PROD1 Backream 6535 - 4820 534 gpm / 2200 psi / 100 rpm / 7k Tq -BR above ghost reamer section, PROD1 Monitor well, static 9.1 ppg MW in/out POH to top of HWDP PROD1 L/D HWDP and BHA #2 *PJSM with Schlumberger on safe practices for handling RA source on surface Clear and ready floor for casing operations Out of hole ~ 16:30 hrs RUNPRD Flush stack and change Upper pipe rams to 7", Test Ram Bonnet seals to 250 psi & 3500 psi for 5 min. /test, Good Test RUNPRD PJSM, R/U to run 7" casing -Make "Dummy run with Landing joint -Changeout Bates, M/U Franks Fill up tool, Install Elevators and slips, R/U Power tongs and scaffolding RUNPRD PJSM on running 7" casing -RIH with 10 jts of 26# BTC-M L-80 -Bakerlock all connections on the first 3 joints Printed: 4/30/2007 11:51:50 AM ~ ~ BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: V-215 Common Well Name: V-215 Spud Date: 4/16/2007 Event Name: DRILL+COMPLETE Start: 4/15/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/26/2007 Rig Name: NABOBS 9ES Rig Number: Date ~ From - To Hours Task ~ Code ! NPT ( Phase - -_- ~ -----1_ 4/20/2007 21:30 - 00:00 2.50 CASE P 4/21/2007 00:00 - 14:30 14.50 CASE P 14:30 - 18:30 4.00 ~ CEMT ~ P Description of Operations RUNPRD -Torqued to 8400 ft/Ibs BOL 2000 NM pipe dope -Fill pipe and checked floats, fill every joint RUNPRD PJSM, M/U 7" 26# L-80 BTC-M casing Ran a total of 35 joints and 1 marker joint with RA tag Avg Torgue 8600 fUlbs on BTC-M, doped with BOL 2000 Fill every joint, break circ every 20 joints Record up and down weights every ten joints 2 centralizers per joint separated with a stop ring on the first 49 joints R/U to run 7" TCII casing, Torque turn every connection Ran 1 XO joint & 123 joints of 26# 7" TCII L-80 -Avg Torgue 10100 fUlbs on TCII, doped with Jet seal dope Landed C~ 6520' PUW = 190k /SOW = 100k RUNPRD Break circulation staging up to 6 bpm / 550 psi -reciprocating casing 15' strokes PJSM covering cement procedures; BP WSL, NAD rig crews and Toolpushers, VECO truck drivers, MI mud engineers in attendence 18:30 - 21:00 2.50 CEMT P RUNPRD Switch to Dowell/Schlumberger and Pump Single stage cement job -Pump 5 bbls. Water. -Test lines to 3500 psi. -Pump 50 bbls Dowell MudPush (~ 10.5 ppg. -Drop bottom plug. -Pump 73 bbls Dowell cement ~ 15.8 ppg. -Drop top Plug, (wash up lines through Tee, no cement on top of plugs) -Displace cement with 247 bbls of 8.4 KCL brine -Bump plug ~ 4254 stks -CIP ~ 20:45 hrs -Bump ~ 850 psi, Pressure up to 2500 psi, O.K. (unable to pressure up to 4000 psi to test csg.due to XO leaking on cement head) Full returns throughout cement job, Reciprocated casing to within 100 strokes of bumping plug Check Floats, O.K. 21:00 - 21:30 0.50 CEMT P RUNPRD Rig Down Cement head and lines, Pull Landing joint 21:30 - 22:00 0.50 CASE P RUNPRD Install 7" Packoff and run in lock down screws - test to 5000 psi for 10 min., Good Test 22:00 - 22:30 0.50 CASE P RUNPRD R/U and test 7" casing to 4000 psi for 30 min -record and charted test, good test 22:30 - 23:30 1.00 CASE P RUNPRD Lay down all casing and cementing equipment 23:30 - 00:00 0.50 CASE P RUNPRD Perform LOT Down OA, -Pump rate ~ 1 bpm , ICP - 725 -Pump 3 bbl, FCP 725 -Shut in pressure after 5 min = 525 psi 4/22/2007 00:00 - 02:00 2.00 CASE P RUNPRD PJSM Flush Stack Change Upper Pipe Rams to 3 1/2 x 6 variables 02:00 - 03:00 1.00 CASE P RUNPRD Test Upper Pipe rams with 3 1/2" test joint to 250 psi low / 4000 psi high Test failed high, leaking between tubing head and BOP Printed: 4/30/2007 11:51:50 AM BP EXPLORATION Operations Summary Report Page 7 of 10 Legal Well Name: V-215 Common Well Name: V-215 Spud Date: 4/16/2007 Event Name: DRILL+COMPLETE Start: 4/15/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/26/2007 Rig Name: NABOBS 9ES Rig Number: Date I From - To I Hours I Task 4/22/2007 02:00 - 03:00 1.00 CASE 03:00 - 03:30 0.50 CASE 03:30 - 04:00 0.50 PERF~ 04:00 - 06:00 2.00 P 06:00 - 09:00 3.00 P 09:00 - 10:00 1.00 P 10:00 - 12:00 2.00 P 12:00 - 13:00 I 1.001 P 13:00 - 14:30 I 1.50 I P 14:30 - 20:00 I 5.50 20:00 - 23:30 I 3.50 Code ~ NPT Phase Description of Operations P RUNPRD -Retighten and tested to 4000 psi for 5 min, O.K. P RUNPRD Install wear bushing P OTHCMP PJSM Surface handling procedures for TPC Perf Guns NAD Rig Crews & TP, Bp WSL and SWS Perf Specialist in attendence P OTHCMP Rig up to Handle Perf Guns - Pick up Perf guns, 337' of HSD-TCP-DP 4.5" 4505 PJ, HMX 5spf -154' LOADED / 182' BLANK -P/U eFire head -Bumper jars and mwd P OTHCMP Run guns in hole with 4" DP to 6346' P OTHCMP Displace hole to 9.0 ppg Brine -105 spm / 257 gpm /. 745 psi puw - 135 /sow - 85 RIH and Tag Float Collar on depth ~ 6436' SIMOPS: Freeze Protected OA, Bullheaded 102 bbls of 9.1 ppg Isnd mud @ 3bpm ICP = 900, FCP = 600, -Rig up LRS, PT line to 3500 psi, Bullheaded 70 bbls of "dead" crude ~ 1.8 bpm, 600 psi, FCP ~ 3.2 bpm = 875 -OA SIP = 700 psi OTHCMP Log from 6436 => 593T Finished displacement while logging -105 spm / 257 gpm /. 745 psi OTHCMP Place top shot on depth ~ 5920' and -PJSM with Schlumberger ,NAD rig Crew, BP WSL Perf 5920 - 5964, 6002 - 6034, 6046 -6068', 6182 - 6238 Total of 154 feet @ 5spf Fire guns as per Schlumberger sequence Good indication that the guns fired Monitor well, initial losses ~ 3 bbls POH 400' till guns above top shot OTHCMP CBU 2x, 80 spm / 340 psi / 200 gpm Total mud loss after circ. = 14 bbls Monitor well for 10 min, gradual loss / 9.0 ppg brine in/out OTHCMP UD 4" Drill pipe -188 jts / 13 bbls loss for trip OTHCMP PJSM, Surface handling of pert guns -UD perf guns andd all handling equipment -clean and clear floor -All shots fired OTHCMP PJSM with SWS logging crewq and NAD drilling crew R/U SWS wireline unit, Pick-up tools OTHCMP PJSM with SWS and NAD rig crew on wireline operations R/U Wireline Truck, Sheaves and equip. Make 5 Gauge ring and Junk Basket runs prior to USIT LOG - #1 5.810" GR to 6420', No Debris in Basket -#2 6.000" GR to 6420', No Debris in Basket -#3 6.125" GR to 6420', 1/2 gal. of debris in Basket -#4 6.125" GR to 6420', 1/2 gal. of debris in Basket -#5 6.125" GR to 6420', less than 1 cup gal. of debris in Basket P P P P P 23:30 - 00:00 I 0.50 I EVAL I P 14/23/2007 100:00 - 17:30 I 17.50 I EVAL I P Printed: 4/30/2007 11:51:50 AM BP EXPLORATION Operations Summary Report Page 8 of 10 ~ Legal Well Name: V-215 Common Well Name: V-215 Spud Date: 4/16/2007 Event Name: DRILL+COMPLETE Start: 4/15/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/26/2007 Rig Name: NABOBS 9ES Rig Number: Date 1 From - To 4/23/2007 00:00 - 17:30 17:30 - 21:00 21:00 - 00:00 4/24/2007 00:00 - 06:00 06:00 - 09:00 09:00 - 10:00 10:00 - 12:00 12:00 - 12:30 12:30 - 14:30 14:30 - 16:30 Hours ~ Task j Code ~ NPT 17.50 EVAL P 3.50 BUNCO 3.00 BUNCO 6.00 BUNCO P 3.00 1.00 2.00 0.50 2.00 2.00 16:30 - 19:00 2.50 19:00 - 00:00 5.00 4/25/2007 100:00 - 04:00 I 4.00 DFAL DFAL DFAL DFAL DFAL DFAL DFAL Phase j Description of Operations _1_- OTHCMP Run USIT Log in primary Depth control mode Run USIT from 6420 to surface R/D SWS sheaves and equipment RUNCMP PJSM oh rig up of tubing running equipment -Clear floor, pull wear bushing -Make Dummy run with landing joint and hanger -Rig up two "I" wire spools and sheaves R/U control line spool -Rig up power tongs RUNCMP PJSM with Schlumberger, HES, and NAD rig crews Run 3 1/2" TCII 9.2# Tubing and completion jewelry M/U torque 2300 ft/Ibs, all connection torque turn Jet Lube seal on connections -Bakerlocked connections below packer RUNCMP PJSM with Schlumberger, HES, and NAD rig crews Run 3 1/2" TCII 9.2# Tubing and completion jewelry M/U torque 2300 fUlbs, all connection torque turn Jet Lube seal on connections Check I-Wire C~ 1401', unable to read temperature on Phoenix Gauge RUNCMP POH Laying down 1x1 - tested ~ 1200', 1000, 800', no joy -pulled to 384' RUNCMP Terminate I-Wire and change out sensor in #3 Packer RUNCMP RIH to 287' & 551', Test, O.K RIH to 994' Test Failed RUNCMP Troubleshoot Phoenix Temperature Sensor failure RUNCMP POH from 994' to 773', Test sensor and Temp & Pressure failed test POH to Sensor C~ #3 packer RUNCMP Replace Sensor, Test, O.K. -RIH 2 joints and place in cold brine, Monitor reading for 1/2 hour Test O.K. RUNCMP RIH with Tubing checking sensors every 500' RUNCMP Run 3 1/2" TCII 9.2# Tubing and completion jewelry M/U torque 2300 ft/Ibs, all connection torque turn Jet Lube seal on connections Verifing I-Wire & sensors every 500' RUNCMP Run 3 1/2" TCII 9.2# Tubing and completion jewelry M/U torque 2300 fUlbs, all connection torque turn Jet Lube seal on connections Verifing 1-Wire & sensors every 500' 3.5" 9.2 # WLEG, 3.5" TC-II -Bottom C~ 6277.5. Tops: 3.5" HES'XN' Nipple: ID 2.750 No-Go X6256'. 3.5" HES 'X' Nipple: 2.813" ID RHC-M Plug ~ 6236'. GLM #1 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 6215'. 3.5" HES 'X' Nipple: 2.813" ID ~ 6,187'. 3.5" x 7" HES single feedthru Packer (1 port) #1 packer C~ 6166'. Printed: 4/30/2007 11:51:50 AM • u BP EXPLORATION Operations Summary Report Legal Well Name: V-215 Common Well Name: V-215 Event Name: DRILL+COMPLETE Start: 4/15/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/26/2007 Rig Name: NABOBS 9ES Rig Number: Date ~ From - To Hours Task Code NPT Phase 4/25/2007 ~ 00:00 - 04:00 4.00 BUNCO 1P ~ RUNCMP 04:00 - 09:30 I 5.501 RUNCOMP I I RUNCMP 09:30 - 10:00 I 0.501 RUNCONIP I I RUNCMP 10:00 - 11:30 ( 1.501 RUNCON~P I I RUNCMP 11:30 - 12:00 0.50 RUNC01~1P RUNCMP 12:00 - 14:00 2.00 BUNCO RUNCMPRUNCMP Page 9 of 10 Spud Date: 4/16/2007 End: Description of Operations 2 jts 3.5" 9.2# L-80 TC-II Tubing (# 1-2 ) GLM #2 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 6,079'. 1 jt 3.5" 9.2# L-80 TC-II Tubing (# 3) GLM #3 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch C~ 6,019'. Phoenix Sensor sub ~ 6003'. 3.5" x 7" HES single feedthru Packer (1 ports) # 2 packer C~ 5993'. 3.5" HES 'X' Nipple: 2.813" ID @ 5979'. GLM #4 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 5960. 3.5" 9.2# L-80 TC-II Pup RA TAG in Centralizer @ 5966. 1 jt 3.5" 9.2# L-80 TC-11 Tubing (# 4) GLM #5 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch 5899. Phoenix Sensor sub @ 5893'. 3.5" x 7" HES Dual feedthru Packer (2 ports) # 3 packer ~ 5879'. 3.5" HES 'X' Nipple: 2.813" ID ~ 5858'. GLM #6 - 3.5" x 1.5" MMG w/ DCR Shear Valve- RKP latch 5830'. 98 jts 3.5" 9.2# L-80 TC-II Tubing (# 5-102 ) 1 - 3.5" 9.2# L-80 TC-II Space out pup 3.5" HES 'X' Nipple: 2.813" ID @ 2700'. 84 jts 3.5" 9.2# L-80 TC-II Tubing (# 103-185 ) 1 - 3.5" 9.2# L-80 TC-II Space out pup 1 jt 3.5" 9.2# L-80 TC-II Tubing (# 186 ) 3.5" 9.2# L-80 TC-II Hanger Pup 4.5" X 3.5" TC-II Crossover FMC Tubing Hanger w/4 1/2" TC-11 Lifting Threads Nabors 9-ES RKB - 23.80' Total of 101 I-Wire Clamps and 15 half clamps used PJSM. Rig up SLB E-line. -Run GR / CCL log for depth correlation Log Showed Completion 4' high RD SWS Lay Out Joints #187 & 186 and Pick up 4' space out pup, And Pick up joint #186 Pick up Hanger and Landing Joint -Terminate I-Wire, test to 5000 psi, good test Land string ~ 6277.45 PUW = 83k /SOW = 59k RILDS Drop 1 5/16" ball & Rod Clear Floor of third party tools and equipment Pressure up on tubing to 4000 psi to set the Halliburton AHR packers and chart & hold 4000 psi for 30 minutes for tubing test. Bleed tubing pressure slowly to 2500 psi, pressure annulus to 4000 psi and hold for 30 minute test. Bleed off annulus pressure first, then tubing pressure, both to zero. Re-pressure the annulus to shear the DCR valve in the #6 GLM, pinned for 2500 psi /sheared at 2,300 psi. Establish Printed: 4/30/2007 11:57:50 AM BP EXPLORATION Page 10 of i0 ~ Operations Summary Report Legal Well Name: V-215 Common Well Name: V-215 Spud Date: 4/16/2007 Event Name: DRILL+COMPLETE Start: 4/15/2007 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/26/2007 Rig Name: NABOBS 9ES Rig Number: Date From - To ~ours Task Code , NPT ~ Phase ~ Description of Operations - __ --- _ _ __ _-a -__ ___ __ _.._-- 4/25/2007 12:00 - 14:00 2.00 BUNCO RUNCMP circulation through valve both ways to confirm shear. Circ. @ 2 bpm 90 psi 14:00 - 14:30 0.50 BUNCO RUNCMP Install TWC, Pressure test from below to 1000 psi for 10 min, Tested O.K. 14:30 - 16:00 1.50 BOPSU P RUNCMP PJSM, Nipple down and set back BOP Stack 16:00 - 19:30 3.50 WHSUR P RUNCMP Install I-Wire in adapter, Test adapter and packoff to 5000 psi f/30 min, good test 19:30 - 21:00 1.50 WHSUR P RUNCMP Install 4 1/16" Dbl. Master Vaive -Fill with diesel and test to 5000 psi for 5 min. on chart 21:00 - 23:30 2.50 WHSUR P RUNCMP Pull TWC with DSM Lubricator Rig up to reverse Circ. -Reverse Circ. 220 bbl of 9.0 ppg brine @ 3 bpm/350 psi, Followed by 90 bbls of 9.0 brine treated with corrision inhibitor 23:30 - 00:00 0.50 W HSUR P RUNCMP PJSM with Little Red and NAD rig crew -PT lines to 3000 psi, O.K. Started pumping 88 bbl of 80 deg. Diesel ~ 2 bpm / 600 psi 4/26/2007 00:00 - 00:30 0.50 WHSUR P RUNCMP Finish pumping 88 bbls of 80 deg. Diesel for Freeze Protect 2 bpm / ICP =600 / FCP =900 psi 00:30 - 01:30 1.00 W HSUR P RUNCMP U-Tube diesel from IA to tubing to freeze protect Tubing Freeze protected to 2475' and / 2200' tvd 01:30 - 03:00 1.50 WHSUR P RUNCMP Lubricate BPV and test from below to 1000 psi for 5 min. Bleed down and secure well 03:00 - 04:00 1.00 WHSUR P RUNCMP Rig down lines and secure cellar -Install VR plugs -Remove outside annulus valves Released Rig ~ 04:00 Printed: M30/2007 11:51:50 AM by ~~~~ ,~~ ~ ~ ~~~~ ~ er Sc~ be .~~~ ~~~~~~ ~~~~~~~~'~~ V-215 Survey g Report Report Date: 20-Apr-07 Survey /DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 145.650° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure /Slot: V-Pad /Plan V-215 (S-I) TVD Reference Datum: Rotary Table Well: V-215 TVD Reference Elevation: 81.40 ft relative to MSL Borehole: V-215 Sea Bed /Ground Level Elevation: 52.70 ft relative to MSL UWI/API#: 500292335100 Magnetic Declination: 23.706° Survey Name /Date: V-215 /April 20, 2007 Total Field Strength: 57635.757 nT Tort / AHD! DDt / ERD ratio: 97.106° / 3847.34 ft / 5.693 / 0.778 Magnetic Dip: 80.894° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: April 17, 2007 Location LaULong: N 70.32751369, W 149.26570033 Magnetic Declination Model: BGGM 2006 Location Grid NIE Y/X: N 5969903.940 ttUS, E 590543.590 ftUS North Reference: True North Grid Convergence Angle: +0.69144459° Total Corr Mag North -> True North: +23.706° Grid Scale Factor: 0.99990931 Local Coordinates Referenced To: Well Head r1 ~J Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Atong Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft n n ft de 00 ft ftUS ftUS H I t u.uu v.uu u.uu -tsi.4u u.uu v.vv v.uv u.uu v.vu u.vv u.uv JaOaaVJ.a4 GYD CT DMS 100.00 0.41 74.42 18.60 100.00 0.12 0.36 0.36 0.10 0.34 0.41 5969904.04 200.00 0.51 99.94 118.60 200.00 0.54 1.15 1.13 0.12 1.13 0.23 5969904.07 300.00 0.67 114.81 218.59 299.99 1.35 2.17 2.11 -0.21 2.10 0.22 5969903.76 400.00 1.24 116.26 318.58 399.98 2.80 3.84 3.72 -0.93 3.60 0.57 5969903.05 500.00 2.22 127.82 418.53 499.93 5.59 6.85 6.63 -2.60 6.10 1.04 5969901.42 Last GYD 600.00 3.78 140.29 518.39 599.79 10.71 12.06 11.61 -6.32 9.73 1.68 5969897.74 MWD+IFR+MS 666.23 5.49 149.73 584.40 665.80 16.05 17.40 16.65 -10.74 12.73 2.82 5969893.36 761.67 7.66 154.09 679.21 760.61 26.89 28.32 27.08 -20.40 17.81 2.33 5969883.76 855.15 9.46 156.17 771.65 853.05 40.61 42.24 40.62 -33.03 23.63 1.95 5969871:20 946.04 11.48 158.92 861.02 942.42 56.76 58.75 56.82 -48.31 29.91 2.29 5969856.00 1043.25 14.86 162.96 955.66 1037.06 78.08 80.89 78.54 -69.26 37.04 3.60 5969835.14 1139.01 17.80 163.51 1047.55 1128.95 103.74 107.81 105.07 -95.04 44.80 3.07 5969809.46 1231.33 21.65 163.23 1134.43 1215.83 133.42 138.96 135.95 -124.89 53.72 4.17 5969779.72 1328.35 25.71 162.71 1223.27 1304.67 170.61 177.92 174.73 -162.13 65.14 4.19 5969742.62 1423.82 27.85 161.85 1308.49 1389.89 211.83 220.93 217.65 -203.10 78.24 2.28 5969701.82 1519.36 30.25 159.51 1392.01 1473.41 256.63 267.31 264.01 -246.86 93.62 2.78 5969658.25 1614.64 34.70 160.61 1472.37 1553.77 306.16 318.46 315.15 -294.94 111.04 4.7i 5969610.38 1709.84 37.16 159.57 1549.45 1630.85 360.26 374.32 371.01 -347.46 130.07 2.66 5969558.11 1806.72 38.58 159.17 1625.93 1707.33 418.03 433.79 430.48 -403.11 151.03 1.49 5969502.72 1901.93 37.63 158.42 1700.85 1782.25 475.24 492.54 489.23 -457.89 172.28 1.11 5969448.20 1996.43 39.65 156.73 1774.66 1856.06 532.97 551.54 548.20 -512.42 194.80 2.41 5969393.95 2092.08 41.18 153.74 1847.49 1928.89 594.11 613.54 610.06 -568.70 220.79 2.58 5969337.99 ~:fU04J.0`J IV /V.JG/O 130y VV 14y.LOO/UVJJ 590543.93 N 70.32751396 W 149.26569754 590544.72 N 70.32751401 W 149.26569119 590545.69 N 70.32751313 W 149.26568333 590547.20 N 70.32751115 W 149.26567116 590549.72 N 70.32750660 W 149.26565088 590553.40 N 70.32749643 W 149.26562139 590556.44 N 70.32748436 W 149.26559713 590561.64 N 70.32745796 W 149.26555593 590567.62 N 70.32742344 W 149.26550868 590574.07 N 70.32738172 W 149.2654 590581.46 N 70.32732448 W 149.2653 590589.52 N 70.32725405 W 149.26533 0 590598.81 N 70.32717251 W 149.26526475 590610.68 N 70.32707076 W 149.26517212 590624.27 590640.17 590658.17 590677.83 590699.46 590721.36 590744.54 590771.21 N 70.32695884 W 149.26506588 N 70.32683930 W 149.26494119 N 70.32670793 W 149.26479999 N 70.32656447 W 149.26464564 N 70.32641242 W 149.26447573 N 70.32626277 W 149.26430345 N 70.32611380 W 149.26412082 N 70.32596003 W 149.26391008 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V-215 (S-I)\V-215\V-215\V-215 Generated 5/25/2007 11:47 AM Page 1 of 3 Comments Measured inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft tt tt n n ft de 100 ft ftUS nUS 2189.02 42.45 152.01 1919.74LUU1.14 658.22 678.17 Ei /4.:i / -628.22L5U.2 / 1. / / 59ti928U.85 2284.57 42.95 151.85 1989.96 2071.36 722.63 742.97 738.82 -683.39 280.76 0.54 5969224.05 2379.68 2475.54 2570.69 2665.69 2760.88 2856.29 2952.33 3047.60 3143.19 3238.94 3334.71 3429.33 3481.94 3555.07 3607.58 3703.32 3798.86 3894.47 3990.69 4085.75 4181.26 4277.16 4372.69 4467.96 4564.23 4659.86 4755.39 4850.92 4947.15 5041.42 44.00 44.92 46.56 48.23 51.50 51.43 51.09 51.71 51.33 51.18 50.89 49.94 50.16 49.38 48.88 49.46 49.77 51.12 53.09 52.16 51.78 51.02 50.31 51.17 50.60 51.67 51.63 51.15 50.86 50.28 149.74 2058.98 2140.38 787.80 808.40 803.81 -740.50 312.70 1.88 5969167.34 147.95 2127.40 2208.80 854.83 875.54 870.31 -797.95 347.44 1.62 5969110.32 146.07 2193.81 2275.21 922.95 943.68 937.58 -855.09 384.55 2.23 5969053.63 142.99 2258.12 2339.52 992.84 1013.59 1006.23 -912.01 425.13 2.96 5968997.21 142.61 2319.47 2400.87 1065.51 1086.36 1077.46 -969.96 469.13 3.45 5968939.80 142.22 2378.91 2460.31 1140.03 1160.99 1150.62 -1029.11 514.65 0.33 5968881.22 142.23 2439.01 2520.41 1214.80 1235.90 1224.19 -1088.32 560.54 0.35 5968822.57 143.48 2498.45 2579.85 1289.17 1310.36 1297.60 -1147.66 605.49 1.21 5968763.77 143.83 2557.93 2639.33 1363.95 1385.19 1371.64 -1207.94 649.84 0.49 5968704.04 143.66 2617.86 2699.26 1438.59 1459.87 1445.64 -1268.16 694.01 0.21 5968644.37 143.29 2678.08 2759.48 142.93 2738.38 2819.78 143.37 2772.16 2853.56 142.16 2819.39 2900.79 142.50 2853.75 2935.15 142.59 2916.35 2997.75 142.86 2978.25 3059.65 142.30 3039.13 3120.53 140.23 3098.23 3179.63 139.98 3155.94 3237.34 140.17 3214.78 3296.18 139.66 3274.61 3356.01 139.73 3335.16 3416.56 139.02 3395.45 3476.85 138.80 3456.18 3537.58 139.97 3516.19 3597.59 140.57 3575.47 3656.87 142.49 3635.08 3716.48 142.39 3695.63 3777.03 142.50 3755.51 3836.91 1513.00 1534.33 1519.44 -1328.00 738.32 0.43 5968585.07 1585.85 1607.25 1591. 71 -1386.32 782.10 1.05 5968527.29 1626.14 1647.58 1631. 72 -1418.59 806.28 0.77 5968495.31 1681.90 1703.41 1687. 07 -1463.04 840.06 1.65 5968451.27 1721.54 1743.12 1726. 42 -1494.47 864.33 1.07 5968420.14 1793.88 1866.55 1940.16 2015.86 2091.05 2165.92 2240.50 2313.98 2387.31 2461.48 2535.50 2610.08 2684.53 2759.20 2831.90 1815.56 1888.34 1962.05 2037.97 2113.51 2188.75 2263.69 2337.58 2411.35 2486.04 2560.50 2635.42 2710.06 2784.85 2857.66 5136.58 50.11 142.25 3816. 43 3897. 83 2904.89 2930 .77 5232.39 50.19 143.78 3877. 82 3959. 22 2978.36 3004 .32 5327.19 49.29 144.41 3939. 09 4020. 49 3050.68 3076 .67 5422.34 49.33 143.75 4001. 12 4082. 52 3122.80 3148 .81 5518.58 47.13 143.52 4065. 23 4146. 63 3194.53 3220 .59 5614.56 42.92 144.54 4133. 05 4214. 45 3262.38 3288 .47 5710.14 39.20 145.91 4205. 11 4286. 51 3325.15 3351 .24 5805.74 38.51 145.74 4279. 56 4360. 96 3385.12 3411 .21 5901.48 37.79 145.49 4354. 85 4436. 25 3444.26 3470 .35 1798.28 -1551.98 1870.54 -1609.89 1943.75 -1668.43 2018.98 -1727.64 2093.68 -1785.60 2168.12 -1843.29 2242.31 -1900.63 2315.45 -1956.98 2388.47 -2012.97 2462.36 -2069.26 2536.15 -2125.79 2610.57 -2183.40 2684.91 -2241.84 2759.51 -2301.13 2832.15 -2358.85 2905.07 -2416.75 2978.51 -2475.50 3050.80 -2534.10 3122.90 -2592.53 3194.61 -2650.32 3262.45 -2705.25 3325.21 -2756.79 3385.18 -2806.41 3444.32 -2855.21 908.38 952.46 997.25 1044.77 1093.22 1141.50 1189.76 1237.56 1285.59 1334.68 1383.14 1431.03 1477.47 1523.06 1567.44 1612.07 1656.32 1698.75 1741.07 1783.63 1823.51 1859.34 1893.03 1926.42 0.61 5968363.18 0.39 5968305.81 1.48 5968247.82 2.66 5968189.19 1.00 5968131.83 59U8U1.:i/ N /U.:i258UL91 W 149.163ti/710 590832.55 N 70.32564671 W 149.26342389 590865.17 N 70.32549069 W 149.26316496 590900.60 N 70.32533375 W 149.26288331 590938.39 N 70.32517764 W 149.26258242 590979.66 N 70.32502214 W 149.26225339 591024.35 N 70.32486380 W 149.26189668 591070.57 N 70.32470222 W 149.26152764 591117.17 N 70.32454045 W 149.26115563 591162.83 N 70.32437830 W 149.26079119 591207.90 N 70.32421363 W 149.26043 591252.78 N 70.32404911 W 149.2600 591297.82 N 70.32388562 W 149.25971439 591342.28 N 70.32372628 W 149.25935956 591366.86 N 70.32363810 W 149.25916350 591401.17 N 70.32351665 W 149.25888968 591425.81 N 70.32343078 W 149.25869297 591470.55 N 70.32327366 W 149.25833587 591515.31 N 70.32311545 W 149.25797861 591560.81 N 70.32295550 W 149.25761551 591609.03 N 70.32279373 W 149.25723033 591658.18 N 70.32263537 W 149.25683761 0.43 5968074.73 591707.15 N 70.32247774 W 149.25644626 0.89 5968017.98 591756.09 N 70.32232106 W 149.25605510 0.75 5967962.22 591804.56 N 70.32216711 W 149.25566771 1.07 5967906.82 591853.25 N 70.32201414 W 149.25527842 0.62 5967851.13 591903.02 N 70.32186032 W 149.25488053 1.47 5967795.20 0.49 5967738.17 1.65 5967680.30 0.31 5967621.57 0.62 5967564.39 0.27 5967507.04 1.23 5967448.83 1.08 5967390.76 0.53 5967332.85 2.29 5967275.58 4.45 5967221.14 4.00 5967170.04 0.73 5967120.84 0.77 5967072.44 591952.16 592000.73 592047.86 592094.16 592139.23 592184.56 592229.51 592272.63 592315.66 592358.90 592399.45 592435.88 592470.17 592504.15 N 70.32170588 W 149.25448772 N 70.32154845 W 149.2540 N 70.32138878 W 149.2537 N 70.32122679 W 149.25335378 N 70.32106907 W 149.25299410 N 70.32091086 W 149.25263241 N 70.32075033 W 149.25227383 N 70.32059023 W 149.25193001 N 70.32043058 W 149.25158703 N 70.32027266 W 149.25124219 N 70.32012258 W 149.25091896 N 70.31998175 W 149.25062868 N 70.31984617 W 149.25035571 N 70.31971282 W 149.25008508 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V-215 (S-I)\V-215\V-215\V-215 Generated 5/25/2007 11:47 AM Page 2 of 3 Comments Measured Inclination Azimuth SulsSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure tt de de n n ft ft tt ft ft de 100 tt ftUS ftUS 5`J`J/.b4 :5/.G4 14b.:SL 44:51.1[ 4blC.bL :ibUL.25L :ib'Lt5.y1 3bUL.t5t5 -'L`J~U:i.4L ly5y.b/ U.btS 5yb/VL4.b5 6092.81 36.87 144.90 4507.07 4588.47 3560.16 3586.26 3560.22 -2950.46 1992.47 0.47 5966978.01 6188.41 36.43 144.97 4583.77 4665.17 3617.23 3643.32 3617.28 -2997.17 2025.26 0.46 5966931.71 6283.93 36.19 145.16 4660.74 4742.14 3673.78 3699.89 3673.83 -3043.54 2057.65 0.28 5966885.74 6379.92 35.63 144.45 4738.49 4819.89 3730.08 3756.18 3730.12 -3089.55 2090.09 0.73 5966840.13 Last MWD+IFR+MS 6464.74 36.14 145.35 4807.21 4888.61 3779.79 3805.90 3779.83 -3130.22 2118.68 0.87 5966799.80 TD (Projected) 6535.00 36.14 145.35 4863.95 4945.35 3821.23 3847.34 3821.26 -3164.31 2142.24 0.00 5966766.00 Survey Type: Definitive Survey NOTES: GYD CT DMS - (Gyrodata -cont. drillpipe m/s -- Gyrodata pump-down multishot surveys with continuous tool (RGS-CT) in drill-pipe.) MWD +IFR + MS - (In-field referenced MWD with mull-stat ion analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) [ftUS] Easting (X) (ftUS] Surface : 4656 FSL 1760 FEL S11 T11 N R11 E UM 5969903.94 590543.59 BHL : 1492 FSL 4900 FEL S12 T11 N R11 E UM 5966766.00 592723.66 byL5:5/.y/ IV /V.:SIyJi577U VV 14y.L4yi57bby 592571.34 N 70.31945257 W 149.24954991 592604.68 N 70.31932494 W 149.24928426 592637.62 N 70.31919824 W 149.24902182 592670.62 N 70.31907252 W 149.24875893 592699.69 N 70.31896138 W 149.24852732 592723.66 N 70.31886823 W 149.24833644 U SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V-215 (S-I)\V-215\V•215\V-215 Generated 5/25/2007 11:47 AM Page 3 of 3 'YELL NFA D - FMC 1GTUATOR -~... Leo' ' B. ELEV = 2$.7' T tF. ELEV = -52.7Q' :C1P- 3C~' ttdx Angie - 53° ~ 3990' . )glum MD = 595€3' >aturnTVD=...........4400' SS 2D" CONDUL'TOR, ID = ? -~10$' ~~~a" cs~, ~, L,BO, ID - 8.835° ~ 353i~ 7" TC 11 to 7" BTC-M cross over jt. 26# L-80 5026' I wires from packers 5879 61 3-'tl2" HES XN NIPPLE 6255 sensor sub ~~ 5892' 3-1/Z" Centralizerwi~Ft RA>~ead I~ 59?0' JtV'{~1 i IYLil W. 17i~111iO~Y JiM M'i"„'J lV1i.. eJ~l)G ~n7!116~..,s. ~W r~vvt~ t~z~ waT~ 2701' ~ 3-112" HES X NIP, Id = 2.813" WATERFLOODIGAS UFTMANDRELS ST MD TVD DE'V TYPE VLV LATCH PART BATE 6 530 4380 38 MMG DCR-1 RKP 1 S" ~ 0412610 5 5899 4434 38 MMGW DUM RK 1.5" 04!2610 4 5~ 4483 37 MMCrW DUM RK °( 5" 04/2610 6010 4522 37 MMGW DUM RK 1.5" Od/2610 2 6070 4570 37 MMGW DUM RK t.5" Q41261C 9 6',106 4f80 36 MMGW DUM RK 1.5" 0412610 ----- 7" MAR#CIrR JC31NT WI RA TAG -~ $._..~ PERFORATION SUMM~IRY REF LOG: SLB USIT O 04123/07 A NGLE A T TOP PERF: 37° Note: SSE 5PF INTERVAL OpnlSc}z DATE 4.5" 5 OA 5920-5984 O 04/22/07 4.5" 5 OBa 6Q02-6034 O 04722!07 4.5" 5 OBb 6046-6Q68 O 04/22107 4.5" 5 OBd 6182-6',?38 O 04122/07 ~-~ 12" TI~~, 9.2#, L-so, Tc~, .0!987 bpf, ~ = 2.992" I-- 6276' PeTI~ ~' csr~, 26#, L-8(J, ID = 6.276" 6521' 5s5~' I-1 3-112" DIES x NIP., Ip = 2.81 ~" §879' I-~ ~" x s-112" Nes AF12 P~~>e~r, IO = 2.21" 5978' 1~ ~-t/2~ HES x NiP, to = 2.813° 59$9' ~ 7"x3-tI2" 31ES ANR Packet, 10} ~ 2.~?t" 6003' Phoenix sensor sub 61$2` ~ 7"X3-112" NES AHR Packer, ID ~ 2."321" 6185' 3-112" HES X NIP, ID = 2.813" 6235' l"""~3-1/2" FIES X NIP. ILt - 2.813" wlRtlC-rn 6255' I"'1 3112" Hl~ xN NIP, IC7 = 2.75" 6277" 1-1 3-112" LEG, I©= 3.t~" DATE REV BY COMMENTS 0)ATE REV BY G4H/~iIENTS ORLON UN(T 02!24/07 BJP Proposed Campletron Ver. 1.0 WELL: V-21S 04!27107 A M Aciuai Cor~ietion P~2MI I' too: 2fi7Q4t 04/341017 ' Tt~AIIPJC CRLG DRAFT COf2REGTIONS API Nn: 50-0-23351 Sec 1i Twp:1lNRge:itE !~ l=xplaraton ~Al~~ita} rl O ^~. SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ................o...: Orion Well .....................: V-215 API number ...............: 50-029-.23351-00 Engineer .................: St. Amour RIG :.....................: Nabors 9ES STATE :...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ---- Permanent datum..........: Depth reference..........: GL above permanent.......: KB above permanent.......: DF above permanent.......: ------------------ Mean Sea Level Driller's Pipe Tally 52.70 ft N/A (Topdrive) 81.40 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 145.65 degrees 20-Apr-2007 09:19:01 Page 1 of 4 Spud date ................: 15-Apr-07 Last survey date.........: 20-Apr-07 Total accepted surveys...: 71 MD of first survey.......: 0.00 ft MD of last survey........: 6535.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2006 Magnetic date ............: 15-Apr-2007 Magnetic field strength..: 57635.80 LAMA Magnetic dec (+E/W-).....: 23.71 degrees Magnetic dip .............: 80.89 degrees ----- MWD survey Reference Reference G ..............: Reference H ..............: Reference Dip ............: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 meal 57636.00 LAMA 80.89 degrees (+/-) 2.50 meal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections -------------------- Magnetic dec (+E/W-).....: 23.71 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.71 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • SCHLUMBERGER Survey Report 20-Apr-2007 09:19:01 Page 2 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.41 74.42 100.00 100.00 0.12 0.10 0.34 0.36 74.42 0.41 BP _GYD CT DMS 3 200.00 0.51 99.94 100.00 200.00 0.54 0.12 1.13 1.13 84.16 0.23 BP _GYD CT DMS 4 300.00 0.67 114.81 100.00 299.99 1.35 -0.21 2.10 2.11 95.63 0.22 BP _GYD CT DMS 5 400.00 1.24 116.26 100.00 399.98 2.80 -0.93 3.60 3.72 104.51 0.57 BP GYD CT DMS 6 500.00 2.22 127.82 100.00 499.93 5.59 -2.60 6.10 6.63 113.07 1.04 BP _GYD CT DMS 7 600.00 3.78 140.29 100.00 599.79 10.71 -6.32 9.73 11.61 123.00 1.68 BP _GYD CT DMS 8 666.23 5.49 149.73 66.23 665.80 16.05 -10.74 12.73 16.65 130.15 2.82 BP _MWD+IFR+MS 9 761.67 7.66 154.09 95.44 760.61 26.89 -20.40 17.81 27.08 138.88 2.33 BP _MWD+IFR+MS 10 855.15 9.46 156.17 93.48 853.04 40.61 -33.03 23.63 40.62 144.42 1.95 BP MWD+IFR+MS 11 946.04 11.48 158.92 90.89 942.42 56.76 -48.31 29.91 56.82 148.24 2.29 BP _MWD+IFR+MS 12 1043.25 14.86 162.96 97.21 1037.06 78.08 -69.26 37.04 78.54 151.86 3.60 BP _MWD+IFR+MS 13 1139.01 17.80 163.51 95.76 1128.95 103.74 -95.04 44.80 105.07 154.76 3.07 BP _MWD+IFR+MS 14 1231.33 21.65 163.23 92.32 1215.83 133.42 -124.89 53.72 135.95 156.73 4.17 BP _MWD+IFR+MS 15 1328.35 25.71 162.71 97.02 1304.67 170.61 -162.13 65.14 174.73 158.11 4.19 BP MWD+IFR+MS 16 1423.82 27.85 161.85 95.47 1389.89 211.83 -203.10 78.24 217.65 158.93 2.28 BP _MWD+IFR+MS 17 1519.36 30.25 159.51 95.54 1473.41 256.63 -246.86 93.62 264.01 159.23 2.78 BP _MWD+IFR+MS 18 1614.64 34.70 160.61 95.28 1553.77 306.16 -294.94 111.04 315.15 159.37 4.71 BP _MWD+IFR+MS 19 1709.84 37.16 159.57 95.20 1630.85 360.26 -347.46 130.07 371.01 159.48 2.66 BP _MWD+IFR+MS 20 1806.72 38.58 159.17 96.88 1707.33 418.03 -403.11 151.03 430.48 159.46 1.49 BP MWD+IFR+MS 21 1901.93 37.63 158.42 95.21 1782.25 475.24 -457.89 172.28 489.23 159.38 1.11 BP _MWD+IFR+MS 22 1996.43 39.65 156.73 94.50 1856.06 532.97 -512.42 194.80 548.20 159.19 2.41 BP _MWD+IFR+MS 23 2092.08 41.18 153.74 95.65 1928.89 594.11 -568.70 220.79 610.06 158.78 2.58 BP _MWD+IFR+MS 24 2189.02 42.45 152.01 96.94 2001.14 658.22 -626.22 250.27 674.37 158.22 1.77 BP _MWD+IFR+MS 25 2284.57 42.95 151.85 95.55 2071.36 722..63 -683.39 280.76 738.82 157.67 0.54 BP MWD+IFR+MS 26 2379.68 44.00 149.74 95.11 2140.38 787.80 -740.50 312.70 803.81 157.11 1.88 BP _MWD+IFR+MS 27 2475.54 44.92 147.95 95.86 2208.80 854.83 -797.95 347.44 870.31 156.47 1.62 BP _MWD+IFR+MS 28 2570.69 46.56 146.07 95.15 2275.21 922.95 -855.09 384.55 937.58 155.79 2.23 BP _MWD+IFR+MS 29 2665.69 48.23 142.99 95.00 2339.52 992.84 -912.01 425.13 1006.23 155.01 2.96 BP _MWD+IFR+MS 30 2760.88 51.50 142.61 95.19 2400.87 1065.51 -969.96 469.13 1077.46 154.19 3.45 BP MWD+IFR+MS SCHLUMBERGER Survey Report 20-Apr-2007 09:19:01 Page 3 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2856.29 51.43 142.22 95.41 2460.31 1140.03 -1029.10 514.65 1150.62 153.43 0.33 BP _MWD+IFR+MS 32 2952.33 51.09 142.23 96.04 2520.41 1214.80 -1088.32 560.54 1224.19 152.75 0.35 BP _MWD+IFR+MS 33 3047.60 51.71 143.48 95.27 2579.85 1289.17 -1147.66 605.49 1297.60 152.18 1.21 BP _MWD+IFR+MS 34 3143.19 51.33 143.83 95.59 2639.33 1363.95 -1207.94 649.84 1371.64 151.72 0.49 BP _MWD+IFR+MS 35 3238.94 51.18 143.66 95.75 2699.26 1438.59 -1268.16 694.01 1445.64 151.31 0.21 BP MWD+IFR+MS 36 3334.71 50.89 143.29 95.77 2759.48 1513.00 -1328.00 738.32 1519.44 150.93 0.43 BP _MWD+IFR+MS 37 3429.33 49.94 142.93 94.62 2819.78 1585.85 -1386.32 782.10 1591.71 150.57 1.05 BP - MWD+IFR+MS • 38 3481.94 50.16 143.37 52.61 2853.56 1626.14 -1418.59 806.28 1631.72 150.39 0.77 BP _MWD+IFR+MS 39 3555.07 49.38 142.16 73.13 2900.79 1681.90 -1463.04 840.06 1687.07 150.14 1.65 BP _MWD+IFR+MS 40 3607.58 48.88 142.50 52.51 2935.15 1721.54 -1494.47 864.33 1726.42 149.96 1.07 BP MWD+IFR+MS 41 3703.32 49.46 142.59 95.74 2997.75 1793.88 -1551.98 908.38 1798.28 149.66 0.61 BP _MWD+IFR+MS 42 3798.86 49.77 142.86 95.54 3059.65 1866.55 -1609.89 952.46 1870.54 149.39 0.39 BP _MWD+IFR+MS 43 3894.47 51.12 142.30 95.61 3120.53 1940.16 -1668.43 997.25 1943.75 149.13 1.48 BP _MWD+IFR+MS 44 3990.69 53.09 140.23 96.22 3179.63 2015.86 -1727.64 1044.77 2018.98 148.84 2.66 BP _MWD+IFR+MS 45 4085.75 52.16 139.98 95.06 3237.34 2091.05 -1785.60 1093.22 2093.68 148.52 1.00 BP MWD+IFR+MS 46 4181.26 51.78 140.17 95.51 3296.18 2165.92 -1843.29 1141.50 2168.12 148.23 0.43 BP _MWD+IFR+MS 47 4277.16 51.02 139.66 95.90 3356.01 2240.50 -1900.63 1189.76 2242.31 147.95 0.89 BP _MWD+IFR+MS 48 4372.69 50.31 139.73 95.53 3416.56 2313.98 -1956.98 1237.56 2315.45 147.69 0.75 BP _MWD+IFR+MS 49 4467.96 51.17 139.02 95.27 3476.85 2387.31 -2012.97 1285.59 2388.47 147.44 1.07 BP _MWD+IFR+MS 50 4564.23 50.60 138.80 96.27 3537.59 2461.48 -2069.26 1334.68 2462.36 147.18 0.62 BP MWD+IFR+MS 51 4659.86 51.67 139.97 95.63 3597.59 2535.50 -2125.79 1383.14 2536.15 146.95 1.47 BP _MWD+IFR+MS • 52 4755.39 51.63 140.57 95.53 3656.87 2610.08 -2183.40 1431.03 2610.57 146.76 0.49 BP _MWD+IFR+MS 53 4850.92 51.15 142.49 95.53 3716.48 2684.53 -2241.84 1477.47 2684.91 146.61 1.65 BP _MWD+IFR+MS 54 4947.15 50.86 142.39 96.23 3777.03 2759.20 -2301.13 1523.06 2759.51 146.50 0.31 BP _MWD+IFR+MS 55 5041.42 50.28 142.50 94.27 3836.91 2831.90 -2358.85 1567.44 2832.14 146.40 0.62 BP MWD+IFR+MS 56 5136.58 50.11 142.25 95.16 3897.83 2904.89 -2416.75 1612.07 2905.07 146.30 0.27 BP _MWD+IFR+MS 57 5232.39 50.19 143.78 95.81 3959.22 2978.36 -2475.50 1656.32 2978.51 146.21 1.23 BP _MWD+IFR+MS 58 5327.19 49.29 144.41 94.80 4020.49 3050.68 -2534.10 1698.75 3050.80 146.16 1.08 BP _MWD+IFR+MS 59 5422.34 49.33 143.75 95.15 4082.52 3122.80 -2592.53 1741.07 3122.90 146.12 0.53 BP _MWD+IFR+MS 60 5518.58 47.13 143.52 96.24 4146.63 3194.53 -2650.32 1783.63 3194.61 146.06 2.29 BP MWD+IFR+MS SCHLUMBERGER Survey Report 20-Apr-2007 09:19:01 Page 4 of 4 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical -------- -------- Displ -------- -------- Displ -------- -------- Total ------- ------- At ----- ----- DLS - - ---- ------ ---- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- --- (ft) -------- -------- (deg) ------ - (deg) ------- (f t) ------ (ft) -------- (ft) -------- (ft) -------- (ft) -------- (ft) -------- (deg) ------- 100f) ----- - type (deg) ---- ------ 61 5614.56 ----- 42.92 ------- 144.54 ------ 95.98 -------- 4214.45 -------- 3262.38 -------- -2705.25 -------- 1823.51 -------- 3262.45 ------- 146.02 ----- 4.45 - BP ---- ------ _MWD+IFR+MS 62 5710.14 39.20 145.91 95.58 4286.51 3325.15 -2756.79 1859.34 3325.21 146.00 4.00 BP _MWD+IFR+MS 63 5805.74 38.51 145.74 95.60 4360.96 3385.12 -2806.41 1893.03 3385.18 146.00 0.73 BP _MWD+IFR+MS 64 5901.48 37.79 145.49 95.74 4436.25 3444.26 -2855.21 1926.42 3444.32 145.99 0.77 BP _MWD+IFR+MS 65 5997.64 37.24 145.32 96.16 4512.52 3502.82 -2903.42 1959.67 3502.88 145.98 0.58 BP MWD+IFR+MS 66 6092.81 36.87 144.90 95.17 4588.47 3560.16 -2950.46 1992.47 3560.22 145.97 0.47 BP _MWD+IFR+MS 67 6188.41 36.43 144.97 95.60 4665.17 3617.22 -2997.17 2025.26 3617.28 145.95 0.46 BP - . MWD+IFR+MS 68 6283.93 36.19 145.16 95.52 4742.14 3673.78 -3043.54 2057.65 3673.83 145.94 0.28 BP _MWD+IFR+MS 69 6379.92 35.63 144.45 95.99 4819.89 3730.08 -3089.54 2090.09 3730.12 145.92 0.73 BP _MWD+IFR+MS 70 6464.74 36.14 145.35 84.82 4888.61 3779.79 -3130.22 2118.68 3779.83 145.91 0.87 BP MWD+IFR+MS 71 6535.00 36.14 145.35 70.26 4945.35 3821.23 -3164.31 2142.24 3821.26 145.90 0.00 Pr ojected to TD [(c)2007 IDEAL ID12 OC O1] • - • ~-a~ i~'C:LQ.NICAL INTEGRITY R~P4RT .~uD ~.-._. ~I~b~~(~`~ QPER c rIEI.D ~~ ~CSC~~E r ~r~~°''~ =..c .~~~._.. ~ . ~'~ ~~~~o~ h~ LL NU2~ER y '~ ~ ~ .~~ LL DAT~_ TD : (oS3~ .?~. t1~~1~~ ; ?BTD : Co`'~3`1 ?-m ~-1S56C~~-v~ Corsi^g : ~1\ Shoe : (2S~~ID ~}~3~ TVD ; DV : N ~Q, ?~ =~~i ~_.,e= . Shoe . '~ T`I:~ ; '.'CP . '•~ _'i~ _.o;,v ~~ ~~.. ?acicer D T'J7i Set at =ole S~ce ~S~l~-\ end Perks S`~i~~ to ~o~ ~~ ~i ~ ~~~~~C~~~ ,~Cr.~?Z=C~_, INTEGRITY - Pa~T #. rnr:u~us Press Test: -? 15 nin ~0 miin Cor~ents - ~s~~ ~J~~„~ ~~G~y~~1S ACV ~'~OQ~ ®5~ yJV~ yam, c'®4~~~~r~ '~'CHPUIC~~, INTEGRITY - PART #Z Cement Vvl~es :: ~~t . Liner 1~R Cs g 'Z~~,h`~ DV~_. C.nt -JOl to cover oers C 3oZO~S ~ ~~~~ ~~~L~~~~~ro ~~~ '~ D Q~-~'~ i~~ v S 5~C C~ ~ _ eoretical TOC ~ ~~~~y~ 2a ~ S -" ~ ~~~ v~ t~ ~ ~~ C~~ Cement Bond Log (Yes or Not ~ In AOGCC File C3L evaluation, gone -' ove perfs Ct.~~~~~~~ ~O - Production Log: Type CUN~LJSIONS: ?art #1: - ?art r2: Evaluation ~ ~~~ C~~ ~~~i aR~ - MEMORANDUM Toy Jim Regg ~ ~ ~~e -~~~~~~, P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 27, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-21 s PRUDHOE BAY UN ORN V-21 s Src: Inspector NON-CONFIDENTIAL Reviewed Sy: P.I. Suprv, Comm Well Name: PRUDHOE BAY UN ORIN V-215 API Well Number: 50-029-2331-00-00 Inspector Name: Bob Noble Insp Num: mitRCN070625075730 Permit Number: 207-041-0 Inspection Date: 6/24/2007 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. - Well j v-z1s ',Type Inj. ; W i TVD a41s I IA 860 azoo zlao 2130 -~ l P.T.D~ 2070410 jTypeTest I SPT I TCSt pSl i 2200 I OA i 180 ~ 300 j 300 ~ 300 i ~_ Interval INITAL P/F P a~ Tnbing ~ 1230 1230 ~ ~ 1230 1230 ~ ~ - Notes: %~~ r%'t~ ~9- ~~~c~~.~.~ I ~~.--'i~~, :~, - -- -- - Wednesday, June 27, 2007 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubertl~admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay / GPB / V-Pad DATE: 06/24/07 OPERATOR REP: Andrea Hughes AOGCC REP: Bob Noble Packer Depth Pretest Initial 15 Min. 30 Min. Well V-215 Type Inj. W TVD 4,418' Tubing 1230 1230 1230 1230 Interval I P.T.D. 2070410 Type test P Test psi 1500 Casing 860 2200 2140 2130 P/F P Notes: MIT-IA post initial injection. OA 180 300 300 300 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) l~o Q ~ .off ~1a5 MIT Report Form BFL 9/1/05 MIT PBU V-215 06-24-07-1.xls Schlumberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well NO. 4256 Company: Alaska Oil & Gas Cons Comm ANn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Job # Log Description Oate BL Color CD osnsio~ • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. ~ -~ ~~ ~ ~ ' Anchorage AK 99508-4254 l ~ t~ s~ ,~ Date Delivered, ,,~~ k` r . ~ t`.C;atlR ~ ,{SC~l:SAI sri(`4~`~ . ~.i ri .}]~-r, ~o~ -c~</ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To Christine Mahnken Well No V-215 Date Dispatched: 14-Apr-07 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 1 Received By: Please sign and return to: Drilling & Measurements LWD Division ~1 ~/~j~ 1 ,~,`r1 2525 Gambell Street, Suite 400 • -- l NU \1 / Anchorage, Alaska 99501 nroselC~slb.com Fax:907-561-8317 LWD Log Delivery V1.1,10-02-03 ab~ - o~~ ~~ ~ SARAH PAUN, GOVERNOR d..d ~ ~7~t'ta OI~ ~ aza47 ~ 333 W. 7th AVENUE, SUITE 100 C011TSFiRQA~l'IO1Q CO1rIIrIISSIOIQ ANCHORAGE, ALASKA 99501-3539 r~ PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 Re: Prudhoe Bay Field, Orion Schrader Bluff, PBU V-215i BP Exploration (Alaska), Inc. Permit No: 207-041 - -Surface Location:- 4656' FSL; 1760' FEL, Sec. 11, Tl 1N, R11E, UM-- --- Bottomhole Location: 1504' FSL, 4887' FEL, Sec. 12, T11N, R11E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager DATED this J day of April, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA V ~ ALAS~IL AND GAS CONSERVATION COMMIN PERMIT TO DRILL ~ DECEIVED N~~,R 2 1 2007 20 AAC 25.005 Alaska Oil $~ Gas Cons. Coftxnissiott 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 is pro 8 ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU V-2151 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 6545' TVD 4949' 12. Field /Pool(s): Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): Surface: 4656' FSL 1760' FEL 11 T11N SEC R11E A S k d 7. Property Designation: ADL 028240 Schrader Bluff , , , , . , ( s ta e ) Top of Productive Horizon: 1769' FSL, 5075' FEL, SEC. 12, T11 N, R11 E, UM 8. Land Use Permit: 13. Approximate Spud Date: April 16, 2007 Total Depth: 1504' FSL, 4887' FEL, SEC. 12, T11 N, R11 E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 6555' 4b. Location of Well (State Base Plane Coordinates): Surface: x-590544 y- 5969904 Zone-ASP4 10. KB Elevation Planned (Height above GL): 28.5 feet 15. Distance to Nearest Well within Pool: 1094' 16. Deviated Wells: Kickoff Depth: p feet Maximum Hole An le: 51.24 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1 e~a ~~ Surface: ~~y 18. a in i . ' r m: S lio ns To - Se i D th - Bo m u n ~t of nt c.f. or sa s Hole Casin Wei ht Grade Cou lin Len th MD TV MD TVD includin sta a data 42" 20" 215. A-53 WLD 108' Surface Surf ce 108' 108' 260 sx Arctic S t A rox. 12-1/4" 9-5/8" 40# L-80 BTC 3493' Surface Surface 3493' 2877' 536 sx AS Lite 411 sx Class'G' 8-3/4" 7" 26# L-80 TC-11! BTC-M 545" S rfa rf 6 4949' 61 sx Clas ' 19. PRESE NT WELL CONDITION SUMMARY (To' be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): asing Length ize ement Volume MD Conductor /Structural Surface Intermediate Producti n Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 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 Brandon Peltier, 564-5912 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/Number: Si nature <-*~~'" ~ Phone ~'~ ~~ 1//~6 Date 3/d~ Sondra Stewman, 564-4750 `Commission Use Onl Permit To Drill Number: ~ © ~ API Number: 50- O ^~~.~J -~' Permit Ap ov Da ~ See cover letter for oth r r it ments Conditions of Approval: r~ If box is checked, we``ll may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ~''~ ` ` ~ C~t`~^C.tl~~'~V C~.l,~, \0~ Samples Req'd: Yes dNo Mud Log Req'd: ^ Yes ~ No t-~i~ ~ ~~ 3tE5~.,Gs ~,G~~~ ^ H2S Measures: Yes ^` No Dire~onal Survey Req'd: (Yes ^ No Other: ~ mar.calf..O~~iA~o~S'C~c~c~s~ct9`~~A~~c~oQ r ~c~u~~k t~*y ljcc ~clv,4vC'v `~ r, 5~,~~~v.i`~~~ieit `av~~vest e a~~ 1~Ca-s ~ 33 ~~~~ Date ~~S^ O APPROVED BY THE COMMISSION COMMISSIONER Form 10-401 Revised 12!2005 ~ ~ ~ ~4 ~ ~ ~ ~ Submit In Duplicate U 1(`"rJ~ NA ~ ~ • Well Name: V-215i Drill and Complete Plan Summary T e of Well service / roducer / in'ector : Injector Tar et X Y Z TVDss Townshi Ran a Section FSL FEL Surface As-Staked 590544 5969904 0 11 N 11 E 11 4656 1760 T t1: To OBa 592545 5967040 4390 11 N 11 E 12 1769 5075 T t2: OBf Base 592736 5966778 4867 11 N 11 E 12 1504 4887 AFE Number: N/A API Number: 50-029-xxxxx Estimated Start Date: April 16, 2007 O eratin da s: 13 Ri Nabors 9ES TMD 6,545' TVD rkb: 4,949' RKB/GL 28.5'/53.7' RTE 82.2' Well Design: USH Grassroots Schrader Bluff Injector 3-'/z", L-80, TC-II, multi acker, zonal in'ection, and zonal monitorin com letion Current Status: New drill General Well Information: Estimated BHP: 2239 psi (8.7 ppg EMW) at 4949' TVD Estimated BHT: 95 deg F at 4949' TVD Formation Markers: Est Formation Tops Est. Formation Tops Uncertainty Commercial Hydrocarbon Bearing Est. Pore Press. Est. Pore press. Formation MD (TVDss) (feet) (Yes/No) (Psi) (ppg EM G1 327 -245 +/-50' No 1l0 8.7 SV6 972 -885 +/-50' No 398 8.7 SV5 1687 -1550 +/-50' No 698 8.7 SV4 1847 -1675 +/-50' No 754 8.7 BPRF 1886 -1715 +/-50' No 772 8.7 SV3 2381 -2085 +/-50' Gas h drates 938 8.7 SV2 2615 -2245 +/-50' Gas h drates 1010 8.7 SVi 3133 -2570 +/-50' Gas h drates 1157 8.7 UG4 3621 _2875 +/-50' Thin Coal 1294 8.7 UG4A 3685 -2815 +/-50' Hea Oil 1312 8.7 Fault 1 ossibie 3764 -2965 +/- 150' MD UG3 4164 _3215 +/-50' Thin Coals 1447 8.7 UG1 4994 -3735 +/-50' Hea Oil 1681 8.7 UG_Ma 5514 -4060 +/-50' No, wet 1827 8.7 UG_Mb1 5577 -4100 +/-50' No, wet 1845 8.7 V-215i Permit to Drill Page 1 • Fault 2 (V-Pad Fault 5608 -4120 +/- 150' MD UG_Mb2 faulted out n/a n/a n/a UG_Mc 5645 -4145 +/-50' No, wet 1865 8.7 SB_Na 5764 -4230 +/-50' No 1904 8.7 SB_Nb 5791 -4250 +/-50' Poor quality sand, Yes 1913 8.7 SB_Nc 5837 -4285 +/-50' No, wet 1928 8.7 SB_Ne 5846 -4292 +/-50' No, wet 1931 8.7 SB_OA 5968 -4390 +/-50' Yes 1975 8.7 SB_OBa 6045 -4455 +/-50' Yes 1850 8.0 SB_OBb 6083 -4485 +/-50' Yes 2025 8.7 SB_OBc 6156 -4545 +/-50' Yes 2050 8.7 SB_OBd 6216 -4595 +/-50' Yes 2040 8.5 SB_OBe 6295 -4660 +/-50' No 2097 8.7 SB_OBf 6343 -4700 +/-50' No 2115 8.7 Base _SB_OBf 6404 -4750 +/-50' No 2138 8.7 ,.~45~ ~u~ Wells within a'/a mile of this injection well, scanned from the top of the reservoir to TD Well Name Dist, Ft. Annulus Inte rit Comments V-119 1094' Bond log shows top of Lite Crete cement at 5624 MD (4049 TVD) in +,, ~~y~ UG1, above Ma. Top of Na is at 4364' TVD. Log shows cement 3~ \ ~_{,~~ isolation. V-205 OBd Lateral 1190' Intermediate hole calculated TOC is at 3970' MD, which is above the Ma ~~~ \ (4470' MD). The distance to Top of Pool (Top Na) is 2300'. Slotted liner ~~~ ~~ com letion. V-205L1 OBa Lateral 1225' Distance to OBa lateral. Slotted liner completion. V-205L2 OA Lateral 1265' Distance to OA lateral. Slotted liner completion. V-01 ~V 1254' Top of cement calculated to be in the UG3 interval at 4339' MD / 3532' ~~~~~ o~~ ' TVD. Top of Na is at 4335' TVD. Calculations show good cement ~ isolation. Casing/Tubing Program: Hole Size Csg/ Tbg O.D. WUFt Grade Connection Length (ft) Top MD/TVD RTE ft Btm MDlTVD RTE ft 42" Insulated 20" 215.5 A-53 WLD 108 GL 108/108 12-'/a" 9-5/8" 40 L-80 BTC 3493 GL 3493/2877 8-3/a" 7" 26 L-80 TC-tl 4992 GL 4992/3816 8-3/a" 7" 26 L-80 BTC-M 1553 4992/3816 6545/4949 Tubin 3-'/z" .9.2 L-80 TC-II 6325 GL 6325/4767 Note: To roduction acker within 200' MD of to erforation Directional: Directional Plan: Schlumber er Feasibilit Stud P3 Ref Elev: 82.2' MD KOP: 300' MD, be in 1.5/100 build Close A roach Wells: All Wells ass Ma'or Risk Scan, reference anti-collision re ort V-215i Permit to Drill Page 2 • • Surve Pro ram: GYD-GC-SS 600' ,MWD 2000' ,MWD + IFR + MS 6545' Maximum Hole An le: 51.24 de rees tan ent section Distance to Nearest Pro a Line: 6555' from PBU bounda Distance to Nearest Well in Pool: 1094' from V-119 at to Na Mud Program: 12-'/a" Surface Hole Mud Pro erties Spud -Freshwater Mud Interval Density PV YP PH Funn Vis FL 0-1896' BPRF 8.8-9.2 30-55 50 - 70 9.0 - 9.5 300-400 NC - 8 1896'-3493' SV1 9.2-9.5 30-55 45 - 60 9.0 - 9.5 250-300 < 8.0 8-3/a" Intermediate Hole Mud Pro erties Freshwater Mud (LSND) Interval Densit PV YP PH API Filtrate MBT 3493'-6545' OBf Base 8.8-9.0 8-14 18-24 9.0-9.5 4 - 7 < 15 Survev and Loaaina Program: 12-'/a" Hole Section: Surface Gyro until MWD surveys are clean. MWD /LWD: Dir/GR O en Hole: None Cased hole: None 8-3/a" Hole Section: Sample as required by well site Geologist MWD /LWD: GR/RES/PWD real time and Azi-Dens/Neu recorded O en Hole: None Cased Hole: USIT in primary depth control mode. Log from PBTD to surface. Cement Calculations: Casin Size Surface Casing - 9 5/8" 40 Ib/ft L-80 BTC -Single Stage Basis Lead: Open hole volume + 250% excess in permafrost and 40% excess below permafrost. TOC at surface Tail: O en hole volume + 40% excess + 80' shoe track. TOC 1000' MD above shoe 2492' MD . Fluid Sequence and A Tam Port collar may be located at 1,000' as a contingency for cement to surface Volume: Wash None S acer 70 bbls of MudPush II wei hted to 10.3 Lead 424 bbls 536 sks 10.7 Ib/ al Arctic Set Lite cement - 4.44 cuft/sk Tail 84 bbls 411 sks 15.8 Ib/ al Class G + Durastone - 1.15 cuft/sk Temp BHST = 52° F from SOR Casin Size Intermediate Casing - 7" 26 Ib/ft L-80 BTC-M x TC-II -Single Stage Basis Lead: None Tail: Open hole volume + 30% excess + 80' shoe track. TOC at 4493' MD, which is 1000' below surface shoe. Fluid Sequence and This cement job is planned for one stage. If two stages are required, 12.5 ppg Lite Volume: Crete will be used as the lead and the TOC will be at the same depth as for one stage. 1 S Sta e Wash None S acer 70 bbl of MUDPUSH XL S acer wei hted to 10.3-Ib/ al Lead none Tail 75 bbl 361 sks 15.8 Class G cement + Latex - 1.16 cuft/sk Temp BHST = 95° F from SOR V-215i Permit to Drill Page 3 • Surface and Anti-Collision Issues: • Surface Shut-in Wells: The closest existing surface wells are V-204 (15' away), and V-114 (30' away). • Close Approach Shut-in Wells: All wells have passed the major risk scan. No wells will require subsurface shut-in during drilling operations. Reference the Anti-collision repoit in the directional plan for a full list of offset well paths. V-2151 Permit to Drill Page 4 • Well Control Surface hole will be drilled with a diverter. The production hole section will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer. This equipment is capable of handling maximum potential surface pressures. BOP equipment will be tested to 4,000 psi. Anticipated surface pressures will not exceed 3,OOOpsi, therefore it will not be necessary to have two sets of pipe rams installed at all times. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Surface Section • BOPE: Hydril GK, 21-1/4", 2000 psi • Maximum anticipated BHP: 1,301 psi - SV1 (8.7 ppg EMW @ 2877' TVD) • Maximum surface pressure: 1,013 psi -Based on a full column of gas C~ 0.10 psi/ft • Planned BOP test pressure: Function Test • 9-5/8" Casing Test: 3,500 psi surface pressure test • Kick Tolerance: NA • Note: It may be necessary to pull the flow paddle while drilling the surface hole permafrost section because of wood, gravel, and other debris interfering with paddle operation. Intermediate Section Kick Tolerance and Integrity Testin • ROPE: Hydril, 13-5/8", 5000 psi • Maximum anticipated BHP: 2,239 psi - OBf Base (8.7 ppg EMW ~ 4949' TVD) • Maximum surface pressure: 1,744 psi -Based on a full column of gas C~ 0.10 psi/ft • Planned BOP test pressure: 4,000 psi/250 psi Rams and 2,500 psi/250 psi Annular • 7" Casing Test: 4,000 psi surface pressure test • Integrity Test - 8-3/4" hole: LOT 20' - 50' from 9 5/a" shoe • Kick Tolerance: 27.0 bbl KT with a 9.0 ppg mud and a 10.4 ppg LOT • Planned completion fluid: Estimated 9.0 ppg Brine / 6.8 ppg Diesel Disposal • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. V-215i Permit to Drill Page 5 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control /Reservoir Pressures: The Schrader Bluff sands are expected to be pressured at 8.0-8.7 ppg EMW. II. Hydrates and Shallow gas: Gas Hydrates are expected at V-pad near the base of the permafrost. Setting casing through the SVi should keep hydrate exposure from extending past the surface hole. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Occasionally hydrates are encountered below the SV1. III. Lost Circulation /Breathing: Lost circulation is considered low at the faults in the production hole section. Seepage losses could occur in the Schrader O-sands. IV. Kick Tolerance /Integrity Testing: Production Section Kick Tolerance and Integrity Testing • Integrity Test - 8-3/4" hole: LOT 20' - 50' from 9 5/e" shoe • Kick Tolerance: 27.0 bbl KT with a 9.0 ppg mud and a 10.4 ppg LOT V. Stuck Pipe There could be slight differential sticking across the open hole while running the 7" casing. Keep the casing moving as much as possible and follow the centralizer program to help with standoff. VI. Hydrogen Sulfide V Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. H2S levels across the pad are typically in the 10 ppm range based on the latest samples taken. Location Well Name H2S Level Date of Readin #1 Closest SHL Well H2S Level V-204 100 m 9/30/2006 #2 Closest SHL Well H2S Level V-109 30 m 12/21/2006 #1 Closest BHL Well H2S Level V-111 30 m 12/22/2006 #2 Closest BHL Well H2S Level V-117 180 m 12/26/2006 VII. Faults There is a low risk of losses incurred when crossin the fault. Formation Where Throw Encounter Fault MD Intersect tvdss Est. Throw Direction Uncertaint Fault #1 ossible 3778 -2965 0-30' Southwest +/-150' M.D. Fault #2 - Ugnu M Sands (V- Pad Fault 5590 -4120 -100' Southwest +/- 150' M.D. CONSULT THE V PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION V-215i Permit to Drill Page 6 • V-215i Drill and Complete Procedure Summary Pre-Rig Work: 1. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the 20" conductor. 2. Prepare pad and neighboring wells for the rig move and sim-ops production. Shut in nearby wells, bleed off process lines, and remove well houses as necessary. Rig Operations: 1. MIRU Nabors 9ES. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. 2. MU 12-~/a" drilling assembly with MWD/GR and directionally drill surface hole to TD with one BHA. Conduct a short trip at the BPRF. The actual surface hole TD will be 225' TVD below the top of the SV1 sands. CBU, short trip, RIH to TD, CBU, then POOH and lay down BHA. 3. Run and cement the 9 5/e", 40.0 Ib/ft. surface casing back to surface. A TAM Port Collar may be run at 1000' MD as a contingency if hole conditions dictate. Use Durastone in the last 15 bbls of tail cement. 4. ND diverter spool and NU and test casing/tubing head. NU BOPE and test to 4000 psi / 2500 psi annular. PU 4" DP as needed. 5. MU 8-3/a" drilling assembly with MWD/GR/Res/Azi-Den/Neu/PWD and RIH to float collar. Confirm 1,000 psi cement compressive strength prior to testing casing. Test the 9 5/8" casing to 3,500 psi for 30 minutes. 6. Drill shoe track and displace over to new 8.8 ppg LSND mud. Drill new formation to 20' below 9-s/8" shoe and perform LOT. 7. Drill ahead to Production hole Target TD (base OBf). Circulate BU, then BR/POOH to run casing. 8. Run and cement the 7", 26#, L-80, BTC-M x TC-II production casing. Displace the casing with seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. Freeze protect the 7"x9 5/a" annulus out of critical path. 9. PU DPC guns and RIH w/ 120' of 4.5" Power Jet 4505 5 spf, pert guns with Schlumberger LWD GR/CCL for gun correlation. 10. Space out perf guns by tagging PBTD and utilizing GR/CCL and RA tags in 7" casing. Once correlated correctly, circulate over to 9.0 ppg brine. Confirm cement compressive strength is at least 1,000 psi before firing. Perforate OA, OBa, OBb, and OBd. POOH LD DP and guns. 11. RU Schlumberger E-line. RIH with gauge ring and junk basket to recover any pert debris. Repeat until clean to at least 50' below the bottom perforation. 12. Run USIT log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. Log from PBTD up to surface. 13. Run the 3-'h", 9.2#, L-80, TCII completion with a 7" x 3-'/z" straddle packer assembly, I-wire, gauges, and injection mandrels. Torque turn TC-II threaded tubing. Before landing tubing, log onto depth using RA marker in tubing and SLB a-line GR/CCL. 14. Run in the lockdown screws and set the packers. Give AOGCC 24 hours prior notice, then test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCR shear valve and pump both ways to confirm circulation ability. 15. Install and test FMC TWC. Nipple down the BOPE. Nipple up & test the dual master valve to 5,000 psi. Note: Tree with electric actuator to be installed post rig. 16. Freeze protect the well to 2,500' TVD by first pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ a hot oil truck, taking clean brine returns to surface. Allow diesel to u-tube into tubing. 17. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-'/z" annulus valve and secure the well. Assure that IA/OA are protected with two barriers. 18. Rig down and move off. Post-Rig Work: 1. Install tree with LEO electric actuator 2. R/U Slick-line and pull ball and rod / RHC from the tailpipe. Replace the DCR shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. 5. Install well house and flow lines. V-2151 Permit to Drill Page 7 TREE= ~ 4-1115' WELLHEAD= FMC ACTUATOR = ~ - Leo KB. ELEV = _ ~ 28.5' BF. ELEV = _ xxx' KOP = 300' Max Angle = cx° @ xxxx' _ Datum ND = xxxx' Datum TV D = _ xxxx' $$ • Proposed WBD SAFETY NOTES: GLM'S ~ STA #1 ~5 ARE V-215 i 3-1/2"X1-1 /2" MMGW WHICHARE WATERFLOOD MANDRELS. 2700' 3-112" HES X NIP, ID = 2.813" WA TERFLOOLYGA S LIFT MA NDREL S 9-5/8" CSG, 40#, L-80, ID = 8.835" 3512' XO from BTC-M to TGII 5513' c I-V1Are run from surface XXXX Minimum ID = 2.813" 3-1 /2" HES X NIPPLE T' MARKER JOINT W/ RA TAG Top Ma CTS gauge ID=xx 5970' 3-1/2" TBG W/ RA Tag in Centralizer Top OA ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 5887 39 MMG DCR-1 RKP 1.5" 5 5977 37 MMGW DUM RK 1.5" 4 6006 34 MMGW DUM RK 1.5" 3 6056 34 MMGW DUM RK 1.5" 2 6106 34 NwV1G-W DUM RK 1.5" 1 6254 34 MMGW DUM RK 1.5" 5936' 3-1/2" HES X NIP, ID = 2.813" CORR~ - 7" Y 7_1/7° I.JCC AND D.an Lnr Ill- 7 07~" 6025' ~~ 3-1/2" HES X NIP, ID = 2.813" 7" MARKER JOINT W/ RA TAG I-I Above O PERFORATION SUMMARY REF LOG: A NGLE AT TOP PERF: Note: SQE SPF INTERVAL Opn/Sqz DATE 4.5" 5 OA - 35' O 4.5" 5 OBa - 25' O 4.5" 5 OBb - 17' O 4.5" 5 OBd - 40' O 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" I~ 6325' I PBTD I 7" CSG, 26#, L-80, ID = 6.276" 6545' 6036' 7" X 3-1/2" HES AHR Packer, ID = 2.921" 6049' CTS gauge ID = xx" 6210' 7" X 3-1/2" HES AHR Packer, ID= 2.921" 6233' 3-112" HES X NIP, ID = 2.813" 6282' 3-112" HES X NIP, ID = 2.813" w /RHGm plug 6303' 3-112" HES X NIP, ID = 2.813" 6325' 3-112" WLEG, ID = 3.00" DATE REV BY COMMENTS DATE REV BY COMMENTS 02/24/07 BJP Proposed Completion Ver. 1.0 ORION UNIT WELL: V-215i PERMfr No: API No: Sec Tw p Rai ~ Exploration (Alaska) 1 ~~: ,... ;'k n ~~ .. ;~,,,y~ V-215 (P3) P Report Date: February 22, 2007 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure 1 Slot: V-Pad / Plan V Slot (S-I) Well: Plan V-215 (S-I) ~~ Borehole: Plan V-215 UWIIAPI#: 50029 Survey Name I Date: V-215 (P3) I April 30, 2007 Tort I AHD I DDI 1 ERD ratio: 72.705° 13841.88 ft 15.567 10.77E Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Location LaflLong: N 70.32751331, W 149.26570026 Location Grid NIE YIX: N 5969903.800 ftUS, E 590543.600 ftUS Grid Convergence Angle: +0.69144466° Say Schlumberger Survey I DLS Computation Method: Minimum Curvature I Lubinski Vertlcal Section Azimuth: 145.650° ~ Vertical Section Origin: N 0.000 ft, E 0.000 ft ND Reference Datum: Rotary Table ND Reference Elevation: 82.20 ft relative to MSL Sea Bed 1 Ground Level Elevation: 53.70 ft relative to MSL Magnetic Declination: 23.691 ° Total Field Strength: 57636.327 nT Magnetic Dip: 80.895° Declination Date: April 30, 2007 Magnetic Deciinaton Model: BGGM 2006 North Reference: True North Total Corr Mag North -> True North: +23.691 ° Measured Vertical Crav°ty Comments inclination Azimuth Sub-Sea TVD TVD NS EW OLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Taol Face ft de de ft ft ft ft ft de de 1100 ft de 100 ft de 1100 ft ftUS ftUS K I t U.UU U.UU 1 /U.UU •t5"L.YU U.UU U.UU U.UU U.UU --- U.UU U.UU U.UU 5y6yyU3.iSU 5yU543.1iU N /U.3Z/51331 W 14y.Z6570026 KOP Crv 1.5!100 300.00 0.00 170.00 217.80 300.00 0.00 0.00 0.00 FIS 0.00 0.00 0.00 5969903.80 590543.60 N 70.32751331 W 149.26570026 G1 327.20 0.41 170.00 245.00 327.20 0.09 -0.10 Os02 HS 1.50 1,50 0.00 5969903.70 590543.62 N 70.32751305 W 149.26570013 Crv 2/100 400.00 1.50 170.00 317.79 399.99 1.19 -1.29 0.23 11.73E 1.50 1.50 0.00 5969902.51 590543.84 N 70.32750979 W 149.26569842 500.00 3.48 163.29 417.69 499.89 5.28 -5.49 1.33 5.03E 2.00 1.98 -6.71 5969898.33 590544.99 N 70.32749832 W 149.26568950 600.00 5.48 161.45 517.38 599.58 12.77 -12.92 3.72 3.20E 2.00 2.00 -1.84 5969890.93 590547.47 N 70.32747801 W 149.26567010 700.00 7.47 160.60 616.74 698.94 23.64 -23.5$ 7.40 2.35E 2.00 2.00 -0.86 5969880.31 590551.28 N 70.32744889 W 149.26564027 800.00 9.47 160.10 715.64 797.84 37.90 -37.46 12.36 1.85E 2.00 2.00 -0.50 5969866.50 590556.41 N 70.32741098 W 149.26560002 Crv 2.5/100 826.34 10.00 160.00 741.60 823.80 42.21 -41.64 13.88 HS 2.00 2.00 -0.37 5969862.33 590557.98 N 70.32739955 W 149.26558770 900.00 11.84 160.00 813.92 896.12 55.73 -54.76 .18,65 HS 2.50 2.50 0.00 5969849.28 590562.91 N 70.32736372 W 149.26554899 SV6 972.88 13.66 160.00 885.00 967.20 71.32 -69.87 24.16 HS 2.50 2.50 0.00 5969834.23 590568.60 N 70.32732242 W 149.26550438 1000.00 14.34 160.00 911.32 993.52 77.68 -76.04 26.40 HS 2.50 2.50 0.00 5969828.09 590570.91 N 70.32730558 W 149.26 18 1100.00 16.84 160.00 1007.63 1089.83 103.71 -101.29 35.59 HS 2.50 2.50 0.00 5969802.95 590580.41 N 70.32723658 W 149.265 1200.00 19.34 160.00 1102.68 1184.88 133.79 -130.47 -46.21 HS 2.50 2.50 0.00 5969773.91 590591.38 N 70.32715687 W 149.26 3 1300.00 21.84 160.00 1196.28 1278.48 167.87 -163.52 58.24 HS 2.50 2.50 0.00 5969741.01 590603.80 N 70.32706659 W 149.26522800 1400.00 24.34 160.00 1288.26 1370.46 205.86 -200.37 71.65 HS 2.50 2.50 0.00 5969704.33 590617.66 N 70.32696591 W 149.26511924 1500.00 26.84 160.00 1378.44 1460.64 247.70 -240.96 $6.43 HS 2.50 2.50 0.00 5969663.92 590632.92 N 70.32685503 W 149.26499946 1600.00 29.34 160.00 1466.66 1548.86 293.32 -285.20 102.53 HS 2.50 2.50 0.00 5969619.88 590649.56 N 70.32673416 W 149.26486888 SV5 1696.79 31.76 160.00 1550.00 1632.20 340.98 -331.43 19y:36 ~ 1iS 2.50 2.50 0.00 5969573.86 590666.94 N 70.32660787 W 149.26473246 1700.00 31.84 160.00 1552.73 1634.93 342.62 -333.02 119.94 HS 2.50 2.50 0.00 5969572.28 590667.53 N 70.32660352 W 149.26472776 1800.00 34.34 160.00 1636.50 1718.70 395.51 -384.32 138.61 NS 2.50 2.50 0.00 5969521.21 590686.82 N 70.32646337 W 149.26457637 SV4 1846.95 35.52 160.00 1675.00 1757.20 421.55 -409.59 147.80 FfS 2.50 2.50 0.00 5969496.07 590696.32 N 70.32639435 W 149.26450182 End Crv 1871.62 36.13 160.00 1695.00 1777.20 435.54 -423.15 152.74 --- 2.50 2.50 0.00 5969482.56 590701.42 N 70.32635729 W 149.26446178 Base Perm 1896.38 36.13 160.00 1715.00 1797.20 449.69 -436.87 157.73 ~- 0.00 0.00 0.00 5969468.90 590706.58 N 70.32631981 W 149.26442129 Crv 2.5/100 1921.15 36.13 160.00 1735.00 1817.20 463.83 -450.59 162.73 46.28E 0.00 0.00 0.00 5969455.24 590711.74 N 70.32628232 W 149.26438080 We1lDesign Ver SP 2.1 Bld(doc40x_100) Plan V Slot (S-I)\Plan V-2.15 (S•:)\Plan V-215\V-215 (P3) Generated 2/22/2007 12:32 PM Page 1 of 2 Measured Vertical GraviQy Comments Inclination Azimuth Sub•Sea ND ND NS EIM OLS Build Rate Walk Rate Northing Easting Latitude Longitude - Depth Section Tool Face ft de de ft ft ft ft i ft de 1 de H00 ft d 1100 ft de 1100 ft ftUS ftUS 2000.00 37.52 157.66 1798.12 1880.32 509.84 -494.65 47°.81 .44.41E 2.50 1.76 -2.97 5969411.40 590729.35 N 70.32616195 W 149.26424232 2100.00 39.34 154.90 1876.46 1958.66 570.92 -551.53 204.$3 42.24E 2.50 1.82 -2.76 5969354.83 590755.05 N 70.32600657 W 149.26403944 2200.00 41.22 152.35 1952.76 2034.96 634.93 -609.42 233.57 40.30E 2.50 1.88 -2.55 5969297.30 590784.48 N 70.32584841 W 149.26380644 2300.00 43.15 149.99 2026.86 2109.06 701.76 -668.22 2ti5.97 38.54E 2.50 1.93 -2.36 5969238.90 590817.59 N 70.32568777 W 149.26354376 SV3 2380.75 44.74 148.20 2085.00 2167.20 757.69 -716.29 294.76 37.26E 2.50 1.97 -2.21 5969191.19 590846.95 N 70.32555645 W 149.26331033 2400.00 45.12 147.79 2098.63 2180.83 771.28 -727.82 301.96 36.97E 2.50 1.99 -2.14 5969179.74 590854.30 N 70.32552495 W 149.26325190 2500.00 47.14 145.74 2167.93 2250.13 843.35 -788.10 341.49 35.55E 2.50 2.02 -2.05 5969119.95 590894.55 N 70.32536027 W 149.26293142 2600.00 49.19 143.82 2234.63 2316.83 917.83 -848.95 384.48 34.26E 2.50 2.05 -1.92 5969059.63 590938.26 N 70.32519404 W 149.26258292 SV2 2615.93 49.52 143.52 2245,00 2327.20 929.91 -858.68 391.64 34.07E 2.50 2.07 -1.85 5969049.99 590945.53 N 70.32516744 W 149.26252487 End Crv 2698.55 51.24 142.04 2297.69 2379.89 993.47 -909.35 430.14 --- 2.50 2.08 -1.80 5968999.79 590984.64 N 70.32502900 W 149.26221272 SV1 3133.53 51.24 142.04 2570.00 2652.20 1331.99 -1176.78 638.79 -- 0.00 0.00 0.00 5968734.92 591196.49 N 70.32429837 W 149.26 9-5/8" Csg Pt 3492.94 51.24 142.04 2795.00 2877.20 1611.70 -1397.75 811:1$ i -- 0.00 0.00 0.00 5968516.07 591371.52 N 70.32369467 W 149.25911 UG4 3620.73 51.24 142.04 2875.00 2957.20 1711.15 -1476.31 872.49 0.00 0.00 0.00 5968438.26 591433.76 N 70.32348002 W 149.25862673 UG4A 3684.62 51.24 142.04 2915.00 2997.20 1760.88 -1515.59 903.14'' ___ 0.00 0.00 0.00 5968399.36 591464.88 N 70.32337269 W 149.25837828 Fault Crossing 3764.49 51.24 142.04 2965.00 3047.20 1823.03 -1564.70 949.45 --- 0.00 0.00 0.00 5968350.72 591503.77 N 70.32323853 W 149.25806774 UG3 4163.83 51.24 142.04 3215.00 3297.20 2133.82 -1810.21 1133.Q0 - . 0.00 0.00 0.00 5968107.56 591698.26 N 70.32256773 W 149.25651506 UG1 4994.45 51.24 142.04 3735.00 3817.20 2780.24 -2320.88 1531.44 -- 0.00 0.00 0.00 5967601.78 592102.79 N 70.32117243 W 149.25328582 Ma 5513.59 51.24 142.04 4060.00 4142.20 3184.26 -2640.05 1780.46 0.00 0.00 0.00 5967285.67 592355.62 N 70.32030033 W 149.25126777 Drp 4/100 5540.61 51.24 142.04 4076.92 4159.12 3205.29 -2656.67 1793.42 174.988 0.00 0.00 0.00 5967269.21 592368.78 N 70.32025494 W 149.25116273 Mbl 5576.92 49.80 142.20 4100.00 4182.20 3233.26 -2678.78 1810.63 174.87E 4.00 -3.98 0.46 5967247.31 592386.25 N 70.32019450 W 149.25102331 5600.00 48.88 142.31 4115.04 4197.24 3250.74 -2692.63 1821.34 174.80,8 4.00 -3.98 0.47 5967233.59 592397.13 N 70.32015667 W 149.25093646 Fault Crossing 5607.52 48.58 142.35 4120.00 4202.20 3256.38 -2697.10 1824.80 174.77E 4.00 -3.98 0.48 5967229.16 592400.64 N 70.32014445 W 149.25090849 Mc 5644.76 47.09 142.54 4145.00 4227.20 3283.94 -2718.99 1841.62 174.658 4.00 -3.98 0.50 5967207.49 592417.73 N 70.32008466 W 149.25077213 5700.00 44.89 142.83 4183.38 4265.58 3323.62 -2750.58 1865.71 174A5R 4.00 -3.98 0.53 5967176.19 592442.19 N 70.31999833 W 149.25057695 Na 5764.40 42.33 143.20 4230.00 4312.20 3367.99 -2786.08 9892.44 174.188 4.00 -3.98 0.57 5967141.04 592469.34 N 70.31990139 W 149.25036038 Nb 5791.23 41.26 143.36 4250.00 4332.20 3385.85 -2800.39 1903.93 174.06E 4.00 -3.98 0.62 5967126.84 592480.20 N 70.31986223 W 149.25027375 5800.00 40.91 143.42 4256.61 4338.81 3391.61 -2805.02 1906.56 174.Q1R 4.00 -3.98 0.63 5967122.25 592483.70 N 70.31984958 W 149.25024590 Nc 5837.15 39.44 143.66 4285.00 4367.20 3415.56 -2824.29 1920.8' 973,rv:,iE 4.00 -3.98 0.66 5967103.15 592498.17 N 70.31979691 W 149.25013047 Ne 5846.20 39.08 143.72 4292.00 4374.20 3421.28 -2828.90 1924.20 173.788 4.00 -3.98 0.68 5967098.58 592501.61 N 70.31978431 W 149.25010303 5900.00 36.94 144.11 4334.39 4416.59 3454.39 -2855.68 1943.71 173.478 4:00 -3.98 0.72 5967072.05 592521.44 N 70.31971116 W 149.241 End Drp / Tgt 5968.38 34.22 144.66 4390.00 4472.20 3494.16 -2888.01 19fE;.88 ... , ~- 4.00 -3.97 0.81 5967040.00 592545.00 N 70.31962281 W 149.24975718 OA 5968.39 34.22 144.66 4390.01 4472.21 3494.17 -2888.02 1966.88' - 0.00 0.00 0.00 5967039.99 592545.00 N 70.31962279 W 149.24975715 Oea 6046.99 34.22 144.66 4455.00 4537.20 3538.37 -2924.08 1992.45 --- 0.00 0.00 0.00 5967004.25 592571.00 N 70.31952426 W 149.24955000 OBb 6083.27 34.22 144.66 4485.00 4567.20 3558.77 -2940.72 1004.?a ~ _ _ "~ ~ --- 0.00 0.00 0.00 5966987.75 592583.00 N 70.31947878 W 149.24945438 OBc 6155.83 34.22 144.66 4545.00 4627.20 3599.57 -2974.01 2027.85 - 0.00 0.00 0.00 5966954.75 592607.00 N 70.31938782 W 149.24926314 Tgt 6210.25 34.22 144.66 4590.00 4672.20 3630.17 -2998.98 2045.55 --- 0.00 0.00 0.00 5966930.00 592625.00 N 70.31931959 W 149.24911971 OBd 6216.30 34.22 144.66 4595.00 4677.20 3633.57 -3001.75 2047.52 ~•- 0.00 0.00 0.00 5966927.25 592627.00 N 70.31931201 W 149.24910377 6294.91 34.22 144.66 4660.00 4742.20 3677.77 -3037.82 2073.09 --- 0.00 0.00 0.00 5966891.50 592653.00 N 70.31921347 W 149.24889660 OBe 6294.92 34.22 144.66 4660.01 4742.21 3677.78 -3037.82 2073.09 -- 0.00 0.00 0.00 5966891.49 592853.00 N 70.31921345 W 149.24889657 Oef 6343.28 34.22 144.66 4700.00 4782.20 3704.98 -3060.01 2088..82 --- 0.00 0.00 0.00 5966869.50 592669.00 N 70.31915283 W 149.24876911 OBfBase 6403.75 34.22 144.66 4750.00 4832.20 3738.98 -3087.75 21Q8.49 -- 0.00 0.00 0.00 5966842.00 592689.00 N 70.31907702 W 149.24860975 TD / 7" Csg 6544.91 34.22 144.66 4866.72 4948.92 3818.35 -3152.51 21.5~.~k0 0.00 0.00 0.00 5966777.81 592735.69 N 70.31890007 W 149.24823774 WeIlDesign Ver SP 2.1 Bld(doc40x_100) Plan V Slot (S-I)\Plan V-215 (S-I)\Plar `d-215\V-215 (P3) Generated 2/22/2007 12:32 PM Page 2 of 2 13 ~~~ -= ~. .. ~. Sehlumberger WELL V-215 (P3) FIELD Prudhoe Bay Unit - WOA STRUCTURE V-Pad Magnetic Para,reb,s Motlel: DGGM NOG DO: 80.895° Date: Apn130, 2001 SuAaos LOCaeon NAD2) Abeka State Pbnee. Z°ne D4, US Feet Lat N101939.008 NaMin9: 5989903.80 %US GriE COm: x0.89144486° Misce9aneaus Sbl: PbnV Sbt(&I) TVD Ref: RoWy Tabb (82.2011 above MSL) Ma9 Dec: x23.G91° FS: 51838.3 nT Lon: W108155G.521 Eaetig: 59050)60 flU5 Scab Faq: 0.9009093129 Plan: V-215 (P3) Srvy Dale: fpr930, NO> 0 600 1200 1800 2400 3000 3600 0 600 1200 1800 O O E :2400 u m U 0 3000 3600 4200 4800 ..... ................: ........................................................................................................w.............................,....,,.......,.,...........,..,.,.,,,..t.,.....,..,...... KOP Crv 7.51100 .._ . ~.._.._.._.._.._.._.._.._..t.._.._.._.._.._.._.._.._..y..._.._.._..-.._.._.._.._.i-.._.._......_.._.._.._.._~._.._.._.._.._.._.. _.._.. _j._.._..-.._.. i Crv 2N 00 ~~ crv z.sn oo Enjf Crv crvzsnoe _ .._.._.. _, _.,_ _.' °3° _. , ErW Crv.,_,._. ~. _......_ ,_.. _..... ,. _..T,._ . .. ....,. _.,_.....,. , _ „_.._.. .._.. _.. s-sle° cag P< Fault Crossing _ _.._.._.._.._.._.. _.._. _.._.._.._.. _.._.._.._ _.._,._.._.._.._.._.._ ._.._.._.._ ..3. _.._ _ ._.._.._.. _.._.._.._.. _.._.._.. _.._.._.._.. _. _.. _.. _.._ Drp 41100 Fault Crossing , , , , , ........................<....,..,........y.....,..,<..,,.,......,,.,......,.q.,..,...,.,,....,.,,,.,,..,......,,5....,<.....,...,..,.,..,,......,..<}.,....,...,..,.....,.......,...,..; ...,..,...,.. ..,......,......;........, ....,.., End Drp I Tgt },-„®„-xe-„-„-,ea„w„-ree-,e-r,-~,-„-„se,®,es,~q,,,-„-.,s„-„ss,-,.a„-r,Ta,s,tsev®„s,.ases®ae see aef-x,r,e-„-,>v,e-„-„w,a®t•®,~v.,a„r.ar t, mr r,a,sa„ j....._,....._..._...-........,..j.._......_.._.._.._.._.._..j.._.._.._.._.,_.._.._.._..j-..._.._.._.._.._..~........_.~_..............,..._.._...... _..,..._.._,.._.,_.. .. ~~'§ Sgt SA .. .. • Bd'.. ...................................s........,......,.....,......,.....a,,.,....,.,..,...,................e.,.,..,..,..,.......,.,..,........~...,........,......,......,.,........,..........,.,.....,,,,....,....... g...... .,.... ~B(Bas V-215 (P3 b TD/7"-Csg 0 600 1200 1800 2400 3000 3600 4200 4800 0 600 1200 1800 2400 3000 3600 Vertical Section (ft) Azim = 145.65°, Scale = 1(in):600(ft) Origin = 0 N!-S, 0 E/-V • ~-'r_I -N.~~~~~ Selumher er g ~, {~ ALL V-215 (P3) FIELD Prudhoe Bay Unit - WOA S~DD,uRE V-Pad MaOneec Palamalels SuRaca L Beon NADP rllavks Stale PIa1N5, Zore O6. US Feel MiuNlane ous Mood: BGGM 2W6 OiP BO.B95- Dale: Apd 30. 2110] LaF N]01939.008 Nabi~g: 598990380 flUG GriO GOIIV: N1.89100088° Sbl: PbnV3M ISI) TVD Ref: Rotary Te8b 182.20fl above MSL) Ma9 Oec: s23.891° F9: 5]fi36.3 nT Lm: W1091556.521 EadM9: 590503.80 flUS Scale FaU: 0.9999093129 Play: V~2151P3) Srvy Dab: Pg1130. 200] 0 400 800 1200 1600 2000 0 -400 -800 ~ -1200 n n Z 0 O V C -1600 m m U V V V -2000 -2400 -2800 -3200 Crv 1.5A OO i i --... i i ..................i....,.............-......,.....,..;..............................,...,;............. ......, ......... ..,......-,......,., ~ zlioo. .... .................................. ..;... v 2.51100 ~/-215 Flt 4375ss N - End Crv Crv 2.5N00 - End Crv t g-Sla^ c>:g rt '. Faun C]ossin~ i 215 Flt 3200ss D]p 4I1Q0 Fault Crossing i /End Drp I Tgt \ 7D 17" Cgg \ ` l 0 400 800 1200 1600 «< W Scale = 1(in):400(ft) E »> 2000 0 -400 -800 -1200 -1600 -2000 -2400 -2800 -3200 BP Alaska Anticollision Report Company: BP Amoco Date: 2/22/2007 Time: 12:45:36 Page: I Field: Prudhoe Bay Reference Site: PB V Pad Co-ordinate(NE) Reference: Well: Plan V-215 (S-I ), True North Reference Well: Plan V-215 (S-I) Vertical (TVll) Keference: V-215 Pla n 82.5 Reference Wellpath: Plan V-215 Db: Oracle NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.80 to 6544.91 ft Scan Method: Trav Cylinder North Maximum Radius:10000.00 ft Error Surface: Ellipse + Casing Survey Program for DeSniHve Wellpath Date: 12/14/2006 Validated: No Version: 4 Planned From To Survey Toolcode Tool Name ft ft 28.80 600.00 Planned: Pla n #3 V1 GYD-GC-SS Gyrodata gyro single shots 600.00 2000.00 Planned: Pla n #3 V1 MWD MWD -Standard 600.00 3460.00 Planned: Pla n #3 V1 MWD+IFR+MS MWD +IFR + Multi Station 3460.00 6544.91 Planned: Pla n #3 V1 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 3493.42 2877.50 9.625 12.250 9 5/8" 6544.91 4948.92 7.000 8.750 7" Summary <--- Offset Wellpath -> Reference Offset Ctr-Ctr No-Go Allowable '~i Site Well Wellpath MD MD Distance Area Deucalion Warning ft ft ft ft ft PB V Pad Plan V-121 (S-R) Plan V-121 V2 Plan: PI 604.03 605.00 175.61 11.40 164.21 Pass: Major Risk PB V Pad Plan V-218 (N-V) Plan V-218 V4 Plan: PI 343.26 345.00 296.41 6.49 289.93 Pass: Major Risk PB V Pad V-01 V-01 V15 1563.76 1555.00 87.57 32:48 55.08 Pass: Major Risk PB V Pad ti/-02 V-02 V12 532.81 545.00 181.20 9.18 172.02 Pass: Major Risk PB V Pad. V-03 V-03 V7 340.40 260.00 309.17 ` .5.52 303.64. Pass: Major Risk PB V Pad V-04 V-04 V7 382.00 385.00 223.16 7.05 216.11 Pass: Major Risk ~ PB VPad V-100 V-100 V7 843.72 845.00 233.46 12.51 220.95 Pass: Major Risk PB V Pad V-101 V-101 V7 328.86 330.00 194.74 5.77. 188.97 Pass: Major Risk ~ PB V Pad V-102 V-102 V5 362.43 365.00 182.96 7.38 175.58 Pass: Major Risk PB V Pad V-103 V-103 V6 284.99 285.00 263.38 5.01 258.37 Pass: Major Risk PB V Pad V-104 V-104 V13 324.06 325.00 182.42 5.59 176.83 Pass: Major Risk PB V Pad V-105 V-105 V13 523.36 535.00 213.03 9.00 204.03 Pass: Major Risk PB V Pad V-106 V-106 V10 309.22 310.00 240.86 5.23 235.64 Pass: Major Risk PB V Pad V-106 V-106A V9 119.70 120.00 240.94 2.30 238.64 Pass: Major Risk PB V Pad V-106 V-106APB1 V6 119.70 120.00 240.94 2.30 238.64 Pass: Major Risk PB V Pad V-106 V-106APB2 V2 119.70 120.00 240.94 2.30 238.64 Pass: Major Risk PB V Pad V-106 V-106AP63 V2 119.70 120.00 240.94 2.30 238.64 Pass: Major Risk PB V Pad V-107 V-107 V5 551.37 565.00 178.71 9.03 169.68 Pass: Major Risk ~ PB V Pad V-108 V-108 V7 245.18 245.00 210.66 4.33 206.33 Pass: Major Risk i PB V Pad V-109 V-109 V2 470.88 470.00 62.06 8.08 53.98 Pass: Major Risk PB V Pad V-109 V-109PB1 V5 470.88 470.00 62.06 8.08 53.98 Pass: Major Risk PB V Pad V-109 V-109P62 V2 470.88 470.00 62.06 8.08 53.98 Pass: Major Risk PB V Pad V-111 V-111 V25 352.97 355.00 286.28 6.67 279.61 Pass: Major Risk PB V Pad V-111 V-111 P61 V8 352.97 355.00 286.28 6.67 279.61 Pass: Major Risk PB V Pad V-111 V-111 PB2 V2 352.97 355.00 286.28 6.67 279.61 Pass: Major Risk PB V Pad V-111 V-111 P63 V6 352.97 355.00 286.28 6.67 279.61 Pass: Major Risk PB V Pad V-112 V-112 V7 336.09 335.00 121.58 6.23 115.35 Pass: Major Risk PB V Pad V-113 V-113 V6 475.19 475.00 92.12 7.53 84.59 Pass: Major Risk PB V Pad V-114 V-114 V5 345.74 345.00 31.34 5.98 25.36 Pass: MajorRisk PB V Pad V-114 V-114A V4 345.74 345.00 31.34 5.98 25.36 Pass: Major Risk PB V Pad V-114 V-114AP61 V4 345.74 345.00 31.34 5.98 25.36 Pass: Major Risk PB V Pad V-114 V-114APB2 V2 345.74 345.00 31.34 5.98 25.36 Pass: Major Risk PB V Pad V-115 V-115 V5 324.35 325.00 267.33 5.51 261.81 Pass: Major Risk PB V Pad V-115 V-115PB1 V4 324.35 325.00 267.33 5.51 261.81 Pass: Major Risk PB V Pad V-117 V-117 V9 388.37 390.00 204.58 6.82 197.77 Pass: Major Risk ~ PB V Pad PB V Pad V-117 V-117 V-117PB1 V6 V-117PB2 V6 388.37 388.37 390.00 390.00 204.58 204.58 6.82 6.82 197.77 197.77 Pass: Major Risk Pass: Major Risk PB V Pad V-119 V-119 V13 2567.62 2655.00 77.60 68.12 9.48 Pass: Major Risk PB V Pad V-120 V-120 V5 255.39 255.00 320.74 4.69 316.05 Pass: Major Risk PB V Pad V-122 V-122 V10 294.64 295.00 221.56 5.27 216.29 Pass: Major Risk PB V Pad V-122 V-122PB1 V10 294.64 295.00 221.56 5.27 216.29 Pass: Major Risk BP Alaska Anticollision Report __ __ ____ Company: BP Amoco Date: 2/22/2007 Time: 12:45:36 Page: 2 Field: Prudhoe Bay Reference Site~c PB V Pad Co-ordinate(NE) Reference: Well: Plan V-215 {S-I), True North Reference Well: Plan V-215 (S-I) Vertical (TVD) Reference: V-215 Plan 82.5 Reference Wellpath: Plan V-215 Db: Oracle Summary < Offset Wellpath > Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD Mll Distance Area Deviation Warning ft ft ft ft ft PB VPad V-201 Plan V-201A V1 Plan: P 309.92 310.00 182.58 5.35 177.23 Pass. Major Risk PB V Pad V-201 V-201 V10 309.92 310.00 182.58 5.35 177.23 Pass: Major Risk PB V Pad V-202 V-202 V9 522.78 535.00 184.15 9.54 174.62 Pass: Major Risk PB V Pad V-202 V-202L1 V5 522.78 535.00 184.15 9.49 174.66 Pass: Major Risk PB V Pad V-202 V-202L2 V5 522.78 535.00 184.15 9.49 174.66 Pass: Major Risk PB V Pad V-203 V-203 V18 505.02 515.00 204.85 10.10 194.75 Pass: Major Risk PB V Pad V-203 V-203L1 V6 1641.06 7715.00 6099.32 No Offset Errors PB V Pad V-203 V-203L2 V4 1700.00 6965.00 5700.33 No Offset Errors PB V Pad V-203 V-203L3 V3 1700.00 6915.00 5661.35 No Offset Errors PB V Pad V-203 V-203L4 V3 505.02 515.00 204.85 10.10 194.75 Pass: Major Risk PB V Pad V-204 V-204 V2 305.37 305.00 15.70 5.35 10.34 Pass: Major Risk PB V Pad V-204 V-204L1 V2 305.37 305.00 15.70 5.35 10.34 Pass: Major Risk PB V Pad V-204 V-204L1 P61 V6 305.37 305.00 15.70 5.35 10.34 Pass: Major Risk PB V Pad V-204 V-204L2 V2 305.37 305.00 15.70 5.35 10.34 Pass: Major Risk PB V Pad V-204 V-204L2P61 V5 305.37 305.00 15.70 5.35 10.34 Pass: Major Risk PB V Pad V-204 V-204L3 V3 305.37 305.00 15.70 5.35 10.34 Pass: Major Risk PB V Pad V-204 V-204PB1 V9 305.37 305.00 15.70 5.35 10.34 Pass: Major Risk PB V Pad V-204 V-204PB2 V2 305.37 305.00 15.70 5.35 10.34 Pass: Major Risk PB V Pad V-205 V-205 V14 777.93 780.00 145.68 13.25 132.44 .Pass: Major Risk PB V Pad V-205 V-205L1 V9 5080.43 6320.00 859.05 No Offset Errors PB V Pad V-205 V-205L2 V8 4968.43 6295.00 886.21 No Offset Errors PB V Pad V-210 V-210 V9 211.40 210.00 182.83 . 3.78 .179.(15 Pass: Major Risk PB V Pad . V-211 V-211 V5 231.59 2.30.01? 202.32. 4.04 198.28 Pass'. Major Risk j PB V Pad V-212 V-212 y/7 359.48 360.00 251.69 6.29 245:39 Pass: Major ~tisk PB V Pad V-213 V-213. V5 284.58 285.00 251.67 5.30 246.37 Pass: Major Risk I PB V Pad V-2 i3 V-213PB1 V5 284.58 285.00 251.67 5.30 .246.37 Pass: Major. Risk. PB V Pad V-214 ~J-214 \(3 270.90 270.00 ^:'90.44 5'.57 184.83 Pass: Major Risk PB V Pad V-214 V-214P61 V2 322.65 320.00 191.03 ' 6.80 1.84.23 Pass: Major Risk P8 V Pad V-214 V-214P62 V3 263.69 260.00 190.77 .5.24 185.53 Pass: Major Risk PB V Pad V-214 V-214P63 VS 263.69 260.00 190.77: 5.24 .185.53 Pass: Major Risk PB V Pad V-214 V-214PB4 V2 263.69 260.00 190.77 5.24 185.53 Pass: Major Risk PB V Pad V-216 V-216 V8 205.88 205.00 274.73 3.85 270.87 Pass: Major Risk PB V Pad V-217 V-217 V5 877.05 875.00 162.31 13.65 148.65 Pass: Major Risk PB V Pad V-221 V-221 V6 295.86 295.00 207.01 6.03 200.99 Pass: Major Risk • ~ FieldPrudhoe Bay SitePB V Pad We11:Plan V-215 (S-I) WellpathElan V-215 3t3 9U0 30x'11 13 $, 9 8 3 O1$ 91 1 8 0 0 0~,~ 1 ~~~ 2 ~ ~ ~'' S ?6 1 $ ~_2 ~gt~ 8,7 170 ~$ 1O7 ~5 ~_ _ ~ ~a f 3Ot3 9 B 1~r173 ~- ~~ ~ 51~ ZQ~ ~~~ ~~11 1 2 8~ 5 ~$ !~ ~~ 1 4 ~, 2 ~~ 7 'P ti",~ s5 4 3 tY ~~ 1 1 ~ ~ ~~- ~ ~ 1 3 p ~ ~ 0 1 1 ~, 12 ~~ 12 f 1! ~ ~ 1 1 !g ~~ ~0 6 A 1 1 1 1 5 1 ~0 ~ ~ ~ '10U ~1 ~ ~$ ~ )7 1 1 ~ ~_ 1 0 .1 0. 9 1 3 ~~7 4 73 ~ 112103 7 $7 g' 1 2 ~ t~C 1 1 9 g ~4 b - , ~t~1 . A~ ~'~ ~ y ~ 0 ,~ ~ $ ~ F 7 6 4 - 0 2 ~~ B ~ 9fl 8 7 `6 ~ , 1 3 65 ~, 14 1 5 ~~--"f 1 ~ 8 1 6 29 17 't 4 1 $ 30 19 f00 iDO 3t 20 21 32 2 3 2 0 3433 6 5 4 - 20 ..200 _ 200 2 50 3 0 0 3 0 0 31 3 n Travelling Cylinder Azimuth (TFO+AZI) (deg] vs Centre t LJ Site: PB V Pad Drilling Target Conf.: 95% Description: Map Northing: 5967040.00 ft Map Easting :592545.00 ft Latitude: 70° 19' 10.642N Shape: Circle Target: V-215 Tgt OA e :Plan V-215 (S-I) Based on: Planned Program Vertical Depth: 4390.00 ft below Mean Sea Level Local +N/-S: -2888.01 ft Local +E/-W: 1966.87 ft Longitude: 149° 14'S9.126W Radius: 50 ft 51 '0( 'St -200 -205 -300 0 0 p~~ ~ ~ 0 0 ~ ~ t ~ - - c~v cv 0 ~ 1 } 0~ Re: V-21 S Variance Request for flow paddle • ~ Subject: Re: V-215 Variance Request forflow paddle From: Thomas Maunder <tom_maunder cr)admin.state.ak.us> Date: Eri, 30 Mar 2007 14:31:01 -0800 To: "Peltier, Brai~clon" <t3rando~~.Pclti~r~ubh.~~~m.~ CC: ~~ I~irhack, EZ~>bert B" [Zohert.l~irpach ~rF3f .c~r1~ . Brandon, Thanks for the reply. I have not had a chance to look in at your attachment. Having good lift pressure does help the case for isolation. As I indicated, the files I could examine did not have that information. If I need anything else, I will get back to you. Tom Maunder, PE AOGCC Peltier, Brandon wrote, On 3/30/2007 2:09 PM: Tam I have been on the slope, so I was not able to respond earlier this week. V-01: Returns were minimal after 75 bbls were outside the shoe. With 75 bbls out, the TOC would be in the CM2, fiherefore the Kuparuk would be covered. The question is if the ichrader Bluff was covered after returns diminished. f reviewed the actual pump pressures {see attached file) and it does show good lift after the pack-off occurred. The actual lift pressure trends do correspond with modeled lift pressure trends, they show about a 1200 psi increase from the time the cement first rounds the corner till pumping is completed (with the actual pressure adjusted for the 1000 psi pack-off pressure increase). That being the case, the cement calculations submitted were for the total volumes pumped. V-205: I attached the cement plot. It shows good lifting pressure during the cement placement. With the plot showing good lifting pressures, the cement calculations used the total volumes pumped. I hope this is helpful. I_et me know if you want additional information. Brandon Peltier BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling (907) 564-5912 (Direct) (907) 748-7838 (Mobile) Brandon. Peltier(c~bp.com _ __ From: Thomas Maunder [mailto:tom maunder@admin,state,ak.us] Sent: Tuesday, March 27, 2007 2:20 PM To: Peltier, Brandon Cc: Tirpack, Robert B Subject: Re: V-215 Variance Request for flow paddle 1 of 4 4/2/2007 l 1:30 AM Re: V-215 Variance Request for flow paddle s ~ Brandon, I am continuing my work on this permit application. In working to confirm the 1 /4 mile information I have developed some questions. 1. I concur with your assessment of V-119. 2. On V-205, the 7" cementing operations report from 1/26/07 indicates that 60 bbls of fluid were lost during the cementing operation. Do you have information that shows pumping pressure increasing throughout the job? Since there is no mention of a "loss of returns", it is probable that the Schrader is isolated. 3. I cannot verify your assessment of V-O1 with the file information I have available. The report of the 7" cementing operations from 6/29/04 indicates that "returns were minimal" with 75 bbls of lead slurry out of the shoe and that a total of 165 bbls of cement was lost during the cement job. 75 bbls of slurry is not sufficient to give the top of cement you list. Do you have additional information that shows pumping pressure rising as the job proceeds? Your comments will be appreciated. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC Peltier, Brandon wrote, On 3/26/2007 10:09 AM: Tom 1 agree that you are correct in regard to the pressures listed in block 17. The pressures shown are surface hole pressures and they should be the intermediate pressures. I haue also at#ached the as-staked for you. It was not done when l submitted the permit application. Brandon Peltier BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling (907) 564-5912 (Direct) (907) 748-7838 (Mobile) Brandon.Peltier b .com From: Thomas Maunder [mailtoYtorri rnaunderadmin.state.ak.us] Sent: Friday, March 23, 2007 4:45 PM To: Peltier, Brandon Subject: Re: V-215 Variance Request for flow paddle Brandon, Your statement will fit the need. Would you please check your calculations on the surface 2 of 4 4/2!2007 11:30 AM Re: V-215 Variance Request for flow paddle pressure? The numbers on the front of the sheet in block 17 are for the surface section not the intermediate. I believe the numbers should be those for the intermediate section. Before I make a change, I need your agreement that that is .appropriate. Thanks, Tom Maunder, PE AOGCC Peltier, Brandon wrote, On 3/23/2007 3: I7 PM. Tom Variance Request * To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line. * To mitigate any risk involved with no flow paddle, the following steps will be taken while the flow paddle is removed from the flow line. Ensure PVT alarms are used and the pit levels are accurately monitored for any pit gain. Visually look down the riser during connections to ensure the well is not flowing. I hope this helps. Brandon Peltier BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling (907) 564-5912 (Direct} (907) 748-7838 (Mobile) Brandor_ . Pe 1 t i er.abp . com -----Original Message----- From: Thomas Maunder [mailto:tom maunder~admin.state.a}c.us] Sent: Friday, March 23, 2007 3:08 PM To: Peltier, Brandon Subject: Re: V-215 Brandon, Sorry for missing the well review. You are correct, it is there. With regard to the paddle, you do state it will be removed. This is somewhat different than requesting a variance to the regulation. I will need a such a request and how you will compensate/mitigate no paddle. Thanks, Tom Maunder, PE AOGCC Peltier, Brandon wrote, On 3/23/2007 1:52 PM: Tom In response to your two points mentioned below: 1. I have included in the V-2151 permit application, on page 2 of the V-2151 drill and complete summary, a scan of all wells within a 1/4 mile of the well path from the top of reservoir to TD. It lists the names of well, the distance, and the annulus integrity status of the 3 of 4 4/2/2007 11:30 AM Re: V-215 Variance Request for flow paddle ! i ', ', wells. The format of that scan matches that of recently submitted V-pad injectors. If this is not what you are looking for, or need additional information, I would be glad to provide it. 2. For the flowline paddle removal, I requested authorization for that on page 5, in the Surface Section on the Well Control page of the application. I hope that clears up any issues. Please contact me if you have any other questions or concerns. Brandon Peltier BP Exploration (Alaska), Inc. Operations Drilling Engineer ', GPB Rotary Drilling (907} 564-5912 (Direct) ', (907) 748-7838 (Mobile) >sra_ndcn. Pelt,=eri~b cc=c -----Original Message----- ] ' From: Thomas Maunder [mailto:tom maunderG~admin.state.ak.:.is] Sent: Friday, March 23, 2007 10:56 AM ', To: Peltier, Brandon ', ' Cc: Tirpack, Robert B Subject: V-215 Brandon, I am just starting to review this application. A couple of questions/points. 1. Since this is an injector, information needs to be provided on the proximity of any wells within 1/4 mile of the intended well path starting at the top of the Schrader Bluff. The primary concern is wells that penetrate the SB within that 1/4 mile radius. Wells ', approaching within zone should be identified, but are generally not of ', as much concern. This includes plug backs. Check with the other ', engineers who have lately submitted permits for V pad. 2. Lately the other engineers have been requesting to have the ', flowline paddle removed for the shallow surface hole (< 1000'). I don't see that mentioned in the application. Again, check with the other engineers. Thanks in advance. Call or message with any questions. ', Tom Maunder, PE AOGCC 4 of 4 4/2/2007 1130 AM 03/29/2007 13:14 1907653 BP WELLS GROUP ~ PAGE 01/09 ~~~~~~~~~~~~ ~C~~~n~ting fob Repo CemCAT v1.D Wetf v-0}. CEtent BP tc7CP •~.. _., ('leld Soreelis 5IR No. 2201054157 EngeAeer pon Zler~e lab Typo Int.erm. Country United States gob Date D6-29-2004 Time ,,,«„ •. ._ .. ._ PreSSnre -- Rate ------ Density -._._.~ Rtig Pressure Messages t 1.0:34 31 t Prc Iob safety meetin g at ;3i Ftlx tvater tCttep, ~7F 10:4$;00 ~ Ro~•,t Total, Vol = 13.71 bbt ' Start Pumping 5pa[er ' tow. pn:grure stall I ~ Prer..uro'~¢st tlna9 f0:$$:00 . t t2,05;00 ~ fnd $par,Qr Drop Bottom Pluq Reset Total, Vat ~ 34.ff8 bbl l Stag Mtxtng t,~7d Slurry 11:15:00 1.1;25:00 i t 1 ' End Lead ShrYry f ResetTOtnl,Vo1 ~ 161.20 bbl { Start titxing Takl Slurry 11:45:00 Et1t1 ttw,rt Slums J R4sat Total, Vol , 39.83 DDI E Drop Top Plug 1 Stag tzixptaermcnt 11:55:00 _ III Rlg R1mpa To Dlspla[e 12:OS:DD Mud p+tah at shoe 1?_;15:00 Lear! [rmcnt at shoo 12:2$:OD Mole pocldnq off . I.frwCf Pump 12ate 12:85:D0 ~ Retttms taillrp Olf cietting abeut 2Dgs, rOturrta t.att rctump Working tlm plea ' Patti 91Ro vrxy smell amount of 1X,~SS:00 ' t2;55:DD i I ~ I.owOr Pomp Rate ~ Dump lop Ping r 8nd blaplacement ' 13:02:18 ~ 61eEd ot F ei+eek ((nt'+ta ~ J ~ floats: h6idlnp Stopped 11cQWektion hh:mm::f. ano foM nvnx Hour ~n[q Sr~'n rtM ?.n ~,e n.r e.n to.n nn fe,d tl.n )f,r ;t#,e R.ne tiro tme- w rmp rva+mrusnw -....,.,~. P91 • _-, ». _, 8/t4 _~ ......~ LBJG '°---- PSI 1 06l29l200d 13^31146 ~+~!~ @3/29/2@@7 13:22 19@7653 BP WELLS GROUP ~ PAGE @9I@9 Schlumberger Well v-205 Field GPB Engineer Gary Giersdorf Country United States Time Pressure 03:30:35 r 03:41:00 03:51:00 04:01:00 • • Cementing .lob Report CemCAT vl-(I Client B.P.Exploration SIR No. 2201073624 Job Type 7 5/8 Intermediate ]ob Date 01-26-2007 - Rate Density Wellhead Pressu Messages Start Jab Start Pumping Water ------ - Pressure Test Lines Rese[ Total, Vol = 4.83 bbl End Water Start Pumping Spacer End Spacer Drop Bottom Plug Reset Total, Vol = 49.66 bbl Stag Mixing Tail Slurry Durostone 04:11:00 04:21:00 1 04:31:00 End Tail Slurry ~ Drop Top Plug Start Pumping Water Reset Total, Vol = 92.26 bbl End Water Reset Total, Vol = 5.21 bbl Mudpush At Shoe 04:41:00 I 04:51:00 Cement Turning the corner 05:01:00 i `l DuraSTONE at Shce I 1 Bump Top Plug 05:13:04 3580 Strokes, 253 bbls mud t End lob hh:mm:ss o.o0 1000 2000 3000 4000 5000 0.00 2.0 4a 6.0 8.0 10.0 5.0 10.0 15.0 20.0 15010.00 833 166) 2500 3333 416) 5000 wz4noo, o:.~,.w PSI B/M _._.__.__.. LB/G SI - - -- - ---- -~1'IV' 01/26/200713:47:53 • • 1 C J ~'RA~ISI~IT"~'AL LETTER C$~ECKI.IST WELL N~~><E ~,dG/ ~=~/S PTD# ~o~o y ~. ®evelopment ~ Service Exploratory Stratigraphiic Test Non-Conventional Welt Circle 4ppropriate Letter /Paragraphs to be Included in Transmittal Letter , CHECK I ADD-ONS I TEXT FOR APPROVAL LETTER w'HAT ; (OPTIONS) APPLIES j 1 ~ N[I1LTI LATERAL The permit is for a new wellbore segment of existing well ' (If last two digits in I Permit No. - - , API No. ~0- ; API number are ; ~ 'between 60-64) Production should continue to be reported as a function of the i original API number stated above. PLOT HOLE [n 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 ~ 2.055. Approval to perforate and produce / infect is contingent ~ ,' !upon issuance of a conservation order approving a spacing j j exception. assumes the ~ i liability of any protest to the spacing exception that may occur. i Non-Conventional Nell Please note the following, special condition of this permit: production or production testing of coal bed methane is not allowed for (name of well) until after (Com~anv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing Rev: t 2~r06 C:'jody~transmittal_checklist DRY D[TCH ~ All dry ditch sample sets submitted to the Commission must be in i SA!~IPLE I no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals j ', ;through target zones. j • • ^^ rn o : ~ ~ .I ~ : ~ ~ ~ ~~ 2 ~ N a' ~ D ~ c. m: o ~ ~ c ° N, ~ Q i ~ N : ~ N. ca : ~ ~ L : : ~ ~ ~ °~~ ai, ~ ~ ~ ~~ p i N, ~ of ~ ~ ~ a a ° ~: ~ ° o W ~ ~ i f a, N: •~~ m _ m, ° N O. ~, m r o a` c`a ~ f6 Q ~ ~: n : o ~ ~ ° o: o ~ ~, ~" C9~ ~, ~ c i II: 3. N' ~ 'o . ~ ~ ~ i ~ c _~ c. M ~ I M' - U ~ ~ W' ~ G Z a ~- ~ a oo m a, a~ ~ I ~ p I No N m ~ '~: ° o. 4 ~ _ > Z ~ °: ° - ~ m. ~ ~ ~ ~~ ~ r ~ ~~ Z U, ~ a ~ °v,~ ~ aci~ .S W ° N ~ ~ ~ p~ ~ i Il ~ U~ ~ a~ >~ w' .Q -~ O: c ~ °~ ~ y~ ~ • n' ~ N. ~~ M ~ ~ : ~ ~ ~ ~ O. ~: ~. 4 y ?~: ~~ ~ ~ ~ ~ N. ~ o :3' ~~ .c. .° ~ a a' a 3. 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