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HomeMy WebLinkAbout208-022MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 15, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-223 PRUDHOE BAY UN ORIN V-223 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/15/2024 V-223 50-029-23384-00-00 208-022-0 G SPT 4468 2080220 1500 1262 1271 1264 1264 629 637 638 639 4YRTST P Brian Bixby 7/6/2024 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-223 Inspection Date: Tubing OA Packer Depth 0 2522 2425 2400IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB240707131747 BBL Pumped:3.9 BBL Returned:2.1 Thursday, August 15, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9James B. Regg Digitally signed by James B. Regg Date: 2024.08.16 15:11:45 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor C FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 29, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC V-223 PRUDHOE BAY UN ORIN V-223 Sre: Inspector Reviewed By: P.I. Supry-GL Comm Well Name PRUDHOE BAY UN ORIN V-223 API Well Number 50-029-23384-00-00 Inspector Name: Bob Noble Permit Number: 208-022-0 Inspection Date: 7/18/2020 Insp Num: mitRCN200718170851 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-223 Type Inj w- TVD 4468 Tubing 1660 1685 1660 1660 ' PTD 2080220 Type Test SPT Test psi 1500 IA 57 2720 2609 2586 ' BBL Pumped: 3 BBL Returned: 3 OA 370 376 370 377 Interval 4YRTST IP/F P Notes: ICdue- [, zO1 c � Shut Wednesday, July 29, 2020 Page 1 of I Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Friday, July 10, 2020 2:28 PM To: Regg, James B (CED); Wallace, Chris D (CED) Cc: Stan Golis; Bo York; Oliver Sternicki Subject: OPERABLE: Injector V-223 (PTD #2080220) Requires AOGCC MIT -IA once online Mr. Regg/Mr. Wallace, Injector V-223 (PTD #2080220) was made Not Operable for tracking purposes after missing AOGCC 4 year MIT -IA due in June 2019. The well is ready to be put on injection. At this time the well is reclassified as Operable. Once the well is online and thermally stable an AOGCC witnessed MIT -IA will be performed. Plan forward: 1. Operations: POI as needed 2. Well Integrity: Perform AOGCC MIT -IA once thermally stable Please respond with any questions, Ryan Holt Hilcorp Well Integrity / Compliance 907-659-5102 From: AK, GWO`Me l Integrity Engineer Sent: Saturday, June 8;-2019 9:37 AM To: AK, OPS EOC Specialists OPS EOCSpecialists@bp com>; Ak, OPS GC2 Facility PTL <AKOPSGC2FacilitvOTL@bp.com> OPS GC2 Field PTL <AkOPSGC2FieIdPTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM(lbp.com>; AK, OPS GC ellpad Lead <AKOPSGC2WelIpad Lead na by com>; AK, OPS PCC Ops Lead <AKOPSPCCOPsLead@bp.com>; AK, OPS ProdGontrollers <akopsprodcontrollersl(abp.com>; AK, OPS Well Pad LV <AKOPSWeIIPadLV(aDbp.com>; Alk, Ops West Area T '< kO sWestAreaTL b .com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr bp.com>; AK, RES GPB Wells Opt Engr <AKRESGPBWestWellsOpt2 bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTLCcDbp.com>; Nottingham, Detek <Derek.NottinghamCcDbp.com>; Youngmun, Alex <younak(a)BP.com>;'chris.wallace@alaska.gov'<chris.wallace al' ov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionscupt@bp om>; AK, GWO DHD Well Integrity <AKD&CDHDWelllnteeri@bp.com>; AK, GWO Projects Well Integrity<AKDCPPramectsWelllntegrityEngineerCDbp com>; AK, GWO SUPT Well Integrity <AKDCWelllntegritvCoordinator(aby com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe(a@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpscompRep by com>; AKIMS App User <akimsuser.service(albp.com>; Cismoski, Doug A <>; Daniel, Ryan <Ryan.Daniel(abp.com>; Dempsey, David G <David.Dem psevl(ED bp.com>; Hibbert, Michael <Michael.Hibbert()BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.MonteomeryQbp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH(albp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.TemyelCa)bp.com>; Worthington, Aras J <Aras.Worthinzton(@bp.com>; 'Regg, James B (DOA) (iim.reag@alaska.eov)' gim.regg@alaska.gov> Subject: NOT OPERABLE: Injector V-223 (PTD #2080220) will not be brought online for 4 year AOGCC MIT -IA All, Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Saturday, June 8, 2019 9:37 AM To: 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 LV; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Nottingham, Derek, Youngmun, Alex, Wallace, Chris D (CED) Cc: 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; Regg, James B (CED) Subject: NOT OPERABLE: Injector V-223 (PTD #2080220) will not be brought online for 4 year AOGCC MIT -IA Attachments: V-223.pdf up Injector V-223 (PTD #2080220) is due for its 4 year AOGCC witnessed MIT -IA by the end of June 2019. The well is currently shut in and will not be brought online in the near future. At this time the well is reclassified as Not Operable for tracking purposes. Once the well is ready to be put online it will be reclassified and an AOGCC witnessed MIT will be performed. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,June 08,2015 Jim Regg r !, _ P.I.Supervisor 1- 41- (0 I��I 1 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC V-223 FROM: Bob Noble PRUDHOE BAY UN ORIN V-223 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry iTZ--- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-223 API Well Number 50-029-23384-00-00 Inspector Name: Bob Noble Permit Number: 208-022-0 Inspection Date: 6/6/2015 Insp Num: mitRCN150606163418 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-223 Type Inj G TVD 4468 - Tubing 1494 1496 1491 - 1490 PTD mono - Type Test SPT Test psi 1500 IA 1098 . 2500 - 2472 - 2464 Interval 4YRTST - P/F P__ a OA 407 414 j 414 - 414 - Notes: SCSNE© 1 U Monday,June 08,2015 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, June 06, 2015 5:52 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad LV; Swensen, Brenden; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA) Subject: OPERABLE:WAG Injector V-223 (PTD #2080220) AOGCC MIT-IA Passed Attachments: image001.png; Injector V-223 (PTD #2080220) TIO Plot 06-06-15.docx All, Injector V-223 (PTD#2080220) passed an AOGCC witnessed MIT-IA on 06/06/2015. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. A copy of the TIO plot is included for reference. Thank you, Kevin Parks �Ep JUN 3 Q 2015 (Alternate Whitney Pettus, SCABP Alaska-Well Integrity Coordinator GVVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Saturday, May 30,,2015 9:36 AM To: AK, OPS GC2 OSM; AK,--OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&CIWireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad LV; Swensen, Brenden; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&( DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R;jinvegg@alaska.gov' Subject: OPERABLE: WAG Injector V-223 (PTD #2080220)I'1aced on Injection for AOGCC MIT-IA All, \ Injector V-223 (PTD#2080220) is ready to place on injection for an AOGCC witn ed MIT-IA. The well is reclassified as Under Evaluation and placed on a 28 day clock. \ 1 Injector V-223(PTD#2080220)TIO Plot 06-06-15 - 1 - 00 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, May 30, 2015 9:36 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad LV; Swensen, Brenden;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA) Subject: OPERABLE:WAG Injector V-223 (PTD#2080220) Placed on Injection for AOGCC MIT-IA Attachments: image001.png; Injector V-223 (PTD #2080220) TIO Plot.docx All, Injector V-223 (PTD#2080220) is ready to place on injection for an AOGCC witnessed MIT-IA. The well is reclassified as Under Evaluation and placed on a 28 day clock. Plan forward: 1. Operations: Place on injection 2. DHD: Perform AOGCC MIT-IA to 2500 psi NED JUN 0 9 2015 A copy of the TIO plot is included for reference. SCAN Thank you, Kevin Parks (Alternate Whitney Pettus BP Alaska-Well Integrity Coordinator Gtit' Global �,�'�'e lls M Organizatior Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Tuesday, July 10, 20 17 AM To: 'Regg, James B (DOA)'; 'Schw , Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Doran, Zach; AK, OPS Well Pad LV Cc: AK, D&C Well Integrity Coordinator; Wills, Shane M; Are d, Jon Subject: NOT OPERABLE: WAG Injector V-223 (PTD #2080220) Long Term Shut In Injector Due for 4-Year Compliance Testing All, 1 Injector V-223(PTD#2080220)TIO Plot • t M lak toD t• -a-0006 02,475 OW'S WWI 6IN75 OYdn WPM d.+ Mr* %Si,S OM IS PAN SIM 11Il,16 i<N • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q~ - ®~ o~, Well History File Identifier II ((I'I II I I II I ()III II (II'I II II ~ I II I III Or anizin (done) g 9 Two-sided ^ Rescan Needed RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: iskettes, No. ` ^ Maps: ^ Greyscale Items: her, No/Type: G ~ No ~ ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: , ~ /s/ ProjectProofing III IIIIIIIIIII IIIII BY: Maria Date: ~ Q /s/ 0 ~ ~ Scanning Preparation ~_ x 30 = + ~v =TOTAL PAGES l q ~ (Count does not include cover heet) ~~ / / BY: Maria Date: a ~ d s Production Scanning Stage 1 Page Count from Scanned File: (count does include cov r sheet) tches Number in Scannin Pre aration: YES NO Page Count Ma 9 p BY: Maria Date: I a9~/O /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ IIIIIIII Scanning is complete at this point unless rescanning is required. II I II II II I ReScanned BY: Maria Comments about this file: Date: Quality Checked uoiuuuiim -~-= 10/6/2005 Well History File Cover Page.doc 04/28/11 ScMmnberger NO. 5729 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 15 -09A BBKA -00096 PRODUCTION PROFILE / ' 3 ^ ■ s 03/14/11 1 - 0'7'4 1 17 -06 BBKA -00094 INJECTION PROFILE 0 S(•� ( /5 ^ .gy p 03/10/11 1 t ey -, 1 C -12B BAUJ -00064 MEM PRODUCTION PROFILE SW t`i ' /J � 03/08/11 0��.T h1�� -_ 0-238 BLP0.00079 MEM PRODUCTION PROFILE '3 - r°7 03/09/11 11110131.Weri' i�_- 16-08A BJGT -00022 GLS ' ' 03/07/11 ON -- :: BLPO.00087 1rlar[M:7ti►T t - IEEETIMF7.L'MINEWO11■•1111=111 IMIIIMIEEIEMIIIMII BJGT -00023 : �, 'Za• Fc1111.10 -- til • L -210 BLPO -00086 MEM INJECTION PROFILE ' • 03/23/11 j �l'w - _ V -105 BLP0.00091 MEM INJECTION PROFILE AN _ 03/29/11 E:TT #t.(�ir^, V -220 BBSK -00065 INJECTION PROFILEFL I lll'�it'�Ti . ♦ ♦ �0O 4�llIE111111-- V -212 BD88 -00096 MEM INJECTION PROFILE T' - 04/03/11 1 O. L -214A BCRJ -00073 INJECTION PROFILE I d 03/18/11 1 a t' � __ i BAUJ•00071 MEM INJECTION PROFILE ,t •• i a?AIII ' • I,OA�IrWAO -- BAUJ -00077 • • . • _ ��Oif•S%r�L• 0 -- 3- 05/0 -29 BG4H -00043 In11111MkZK r ' OitallIMIII-- r BLPO -00092 MEM PRODUCTION PROFILE ' PYfl'i�'rT►Y.ill 11M11=1!T BBSK -00057 r �LTL"� '. _ real:k2�O == BLUE- 001 �F�i .�L'ii BD88 -00097 MEM INJECTION PROFILE '"E Wr�j'IEMENE-11111.1111 AWJI- I .h [•21ZU /i9L 44111 •EI f' l IIT 0 -- BG4H -00044 PRODUCTION PROFILE . • 1.111.111=1.1.1. . - BMSA- 00009 - " M R e w MIlillEMIN0 -- 02 -186 BLPO -00087 MEM PRODUCTION PROFILE am, v a EM1111O it170 -- Z -20 BP5G -00010 GLS Uric -(D O 03/29/11 1 Ma 1 -_ Y -29A BCUE -00122 MEM LDL .. a 03/20/11 1 10111a', 11. 1 C 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc Alaska Data & Consulting Services Petrotechmcal Data Center LR2 -1 2525 Gambelt Street, Suite 400 900 E. Benson Blvd Anchorage, AK 99503 -2838 • • JUG: 1 20 - ---- - - - - -- -- STATE OF ALASKA "' ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other Q WAG SWAP Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^ Exploratory ^ '~ 208-0220 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ 6. API Number: Anchorage, AK 99519-6612 '~ 50-029-23384-00-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ADLO-028240 ~ PBU V-223 10. Field/Pool(s): `- PRUDHOE BAY FIELD I SCHRADER BLUFF POOL 11. Present Well Condition Summary: Total Depth measured 6725 feet Plugs (measured) 6445' 6/10/08 feet true vertical 5000.67 feet Junk (measured) None feet Effective Depth measured 6521 feet Packer (measured) 6041 6139 6208 true vertical 4838.83 feet (true vertical) 4468 4543 4596 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# A-53 SURFACE - 80 SURFACE - 80 Surface 3424 9-5/8" 40# L-80 29 - 3424 29 - 2822 5750 3090 Intermediate Production 6716 7" 26# L-80 26 - 6716 26 - 4996 7240 5410 Liner Liner -, ., '~ ~~ :i ~ ~ :, ~"x L w ~ ~' ' ~-~ "- ~ t « _ _ : Perforation depth: Measured depth: SEE ATTACHED - = True Vertical depth: _ _ _ = Tubing: (size, grade, measured and true vertical depth) 3-1/2" 9.2# LL-80 0 - 6467 0 - 4797 Packers and SSSV (type, measured and true vertical depth) 3-1/2" HES RCP Packer 6041 4468 3-1/2" HES RCP Packer 6139 4543 3-1/2" HES RCP Packer 6208 4596 3-1/2" HES RCP Packer 6325 4686 12. Stimulation or cement squeeze summary: Intervals treated (measured): ? 5 ~ ~ c~ '~ z Q 1 Q , Treatment descriptions including volumes used and final pressure: ~il~lSj(8 ~ ~ GAY C~~ ~~pj$SIOfI 13. Representative Daily Average Production or Injecti n a Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 681 1455 Subsequent to operation: 1229 1300 14. Attachments: 15. Well Class after work: , Copies of Logs and Surveys Run Exploratory^ Development ^ Servce ^~ Daily Report of Well Operations X 16. Well Status after work: ~~ Oil Gas WDSPL GSTOR ^ WAG Q GINJ ^ WINJ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature hone 564-4944 Date 7/27/2010 runn iv--rvY rvcviacu ncvva -~ /~ 7 z 8-/L7 V-223 208-022 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base V-223 3/22/08 PER 6,084. 6,134. 4,500.56 4,538.87 V-223 3/22/08 PER 6,170. 6,206. 4,566.53 4,594.25 V-223 3/22/08 PER 6,226. 6,248. 4,609.68 4,626.67 V-223 3/22/08 PER 6,360. 6,414. 4,713.36 4,755.28 V-223 6/10/08 BPS 6,445. 6,446. 4,779.4 4,780.18 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • v-223 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 6/13/2010 "WELL ON INJECTION UPON ARRIVAL""` (pre mi swap) 3 SET 3-1/2" X-CATCHER SUB @ 6,201' SLM/6,227' MD PULL RK-P15XJR WFR @ 6,168' SLM/6,189' MD j (BRUSH AND FLUSH TBG W/ 3-1/2"BRUSH, 2.63 G. RING TO 6,180' SLM SET RK-P15XJR (300 BWPD, 15/64 light spring) WFR @ 6,168 SLM/6,189 MD ~ PERFORM PASSING INJECTIVITY TEST (see Irs report) PULL X C-SUB @ 6,201' SLM/6,277' MD SET MCX (ser.# BPX-323, .5" bean) @ 2,825' SLM/2,858' MD I ~ PERFORM PASSING CLOSURE TEST ON MCX. ~ "**WELL S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** ~ 6/13/2010 T/I/0=400/0/100 Assist S-Line W/WFR (UIC Compliance) Established injection rates of 0.35 BPM @ 1300 psi, 0.4 BPM @ 1500 psi, and 0.42 BPM @ 1700 psi. S- Line set flow sleeve in station # 4. Pumped 100 bbls 180* Diesel down Tbg while S- Line brushed tbg. S-Line set WFR in station # 4. Attempt to establish rate @ 1300 psi. Could not establish rate @ 1300 psi. Establish rate Of .3 bpm @ 1500 psi. Establish rate of .45 bpm @ 1700 psi. FWHP=1100/0/80. IA & OA open. Slickline still on location upon LRS departure. FLUIDS PUMPED BBLS 121 DIESEL 121 Total TREE= 4-1/16" CM! WEILHEArD = F ACTUATOR = LEO KB. ELEV = 81.4' BF. ELEV = KOP = 400' Max Angle = 56° @ 3136' Datum MD = 6059' Datum TVD = 4400'. SS V-223 ~i -1 87' I- I4-1/2" X 3-1/2" XO, ID = 2.992" 2858' 3-1/2" HES X NIP, ID = 2.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 5993 4431 41 MMG DMY RK 0 06/09!08 WATER INJECTION MANDRELS 20" CONDUCTOR, 91.5#, A-53, ID = 19.124" 80~ 9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" ~~ 3424' 7" CSG, 26#, L-80 TCII XO TO L-80 BTGM 4948 3-1/2" HES X NIP, ID = 2.813 6010 7" X 3-1/2" HES DUAL FEEDTHRU PKR, ID = 2.965" 6041' Minimum ID (V-223) = 2.75" @ 6445' 3-1 t2"HES XN NIPPLE 7' MARKER JOINT wlRA PIP TAG --~61' ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 6080 4497 40 MMG-W DMY RK 0 03125/08 6 6109 4519 44 MMG-W P-15XJR RK 13 02/18/10 5 6160 4559 40 MMG-W DMY RK 0 03!25!08 4 6189 4581 40 MMG-W P-15XJR RK 15 06/14110 3 6238 4619 39 MMG-W DMY RK 0 03/25!08 2 6286 4656 39 MMG-W DMY RK 0 06!13/08 1 6395 4740 39 MMG-W DMY RK 0 07/11/09 3-1/2" NDPG MULTI-SENSOR SUB , ID = 2.992 3-1/2" HES X NIP, ID = 2.813" 17" X 3-112" DUAL FEEDTHRU PKR, ID = 2.965" ~ 3-1 /2" NDPG MULTI-SENSOR SUB , ID = 2.992 3-112" RA PIP TAG PERFORATION SUMMARY REF LOG: USIT LOG ON 03(23/08 ANGLE AT TOP PERF: 40 ° @ 6084' Note: Refer to Production DB for historical perf data SIZE SPF ZONE INTERVAL Opn/Sqz DATE 4-112" 5 OA 6084 - 6134 O 03/22/08 4-112" 5 OBa 6170 - 6206 O 03!22/08 4-112" 5 OBb 6226 - 6248 O 03/22/08 4-1/2" 5 OBd 6360 - 6414 O 03/22/08 3-1/2"' TBG, 9.2#, L-80 TCII, .0087 bpf, ID = 2.992" PBTD 7" CSG, 26#, L-80 BTGM, .0383 bpf, ID = 6.276" 6208' -~7" X 3-1/2" SINGLE FEEDTHRU PKR, ID = 2.965" 6221' 3-112" NDPG MULTI-SENSOR SUB , ID = 2.992 6227' - 3-1/2" HES X NIP, ID = 2.813" 6325' 7" X 3-1/2" SINGLE FEEDTHRU PKR, ID = 2.965" 633x' I--j 3-1/2" NDPG SINGLE-SENSOR SUB , ID = 2.992 6374 3-1/2" HES X NIP, ID = 2.813" 3-1/2" HES X NIP,ID = 2.813" 6445' - j 3-112" HES XN NIP, ID = 2.750" 6467• 6445 3-1/2" PXN PLUG (06/10l08~ 6630' ,....,._~7~ 3-1/2" WLEG, ID = 2.992" ELMD NOT LOGGED --, DATE REV BY COMMENTS DATE REV BY COMMENTS 03(26108 N9ES ORIGINAL COMPLETION 02127/10 DTR/PJC PXN SET (06/10/08) 04121/08 ?l PJC DRLG DRAFT CORRECTIONS 02127/10 DTR/PJC WFR GO (02/18/10) 05/09/08 TW/JPJC DRLG DRAFT CORRECTIONS 06118!10 WEGBL WFR CO (06!13/10) 05/20/08 TH(SV PERF CORRECTION 07/16/09 SEWlSV WFR GO (07/11/09) 02/04110 RPGPJC WFR CORRECTIONS (06109) ORION UNIT WELL: V-223 PERMff No:'2080220 API No: 50-029-23384-00 SEC 11, T11 N, R11 E, 598' FNL & 1663' FEL BP Exploration (Alaska) DATA SUBMITTAL COMPLIANCE REPORT 1/2812010 Permit to Drill 2080220 Well Name/No. PRUDHOE BAY UN ORIN V-223 Operator BP EXPLORATION (ALASK~y INC API No. 50-029-23384-00-00 MD 6725 TVD 5001 Completion Date 3/26/2008 Completion Status WAGIN Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Ye DATA INFORMATgN Types Electric or Other Logs Run: MWD / GR / RES / NEU / AZI /DEN / PWD / CBL (data taken from Logs Portion of Master Well Data Maint We11 Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / ly Metl/h~umDer Name 5Ca1e meola No Start 0 Stop 6725 GN O ReCelVetl 4/2/2008 GOmments D D Asc Directional Survey pen Rpt Directional Survey 0 6725 Open 4/2/2008 D C Asc ~ Directional Survey 0 1195 Open 4/7/2008 Rpt Directional Survey 0 1195 Open 4/7/2008 9 Cement Evaluation 5 Col 38 6520 Case 4/10/2008 CEL, USIT, GR, CCL 23- Mar-2008 D C Pds 1611(3~Cement Evaluation 38 6520 Case 4/10/2008 CEL, USIT, GR, CCL 23- Mar-2008 (~D C Lis 16307/ Sonic 50 6525 Case 5/23/2008 LIS Veri, USIT, CCL ~D C Lis ~~ 16395 vlnduction/Resistivity 109 6725 Open 6/6/2008 LIS Veri, GR, ROP, FET, ' RPM, RAM, DRHO, NPHI, TRPM Log Induction/Resistivity 25 Blu 100 6683 Open 6/6/2008 MD Vision Service 20-Mar- 2008 Log Induction/Resistivity 25 Blu 100 6683 Open 6/6/2008 TVD Vision Service 20-Mar- 2008 ~g Injection Profile 5 Blu 5807 6430 Case 1/14/2009 Injection Pro, PSP, Pres, Temp, Spin, GR, CCL 29- Dec-2008 ED C Pds 17432~njection Profile 5807 6430 Case 1/14/2009 Injection Pro, PSP, Pres, Temp, Spin, GR, CCL 29- Dec-2008 • DATA SUBMITTAL COMPLIANCE REPORT 1/28/2010 Permit to Drill 2080220 Well Name/No. PRUDHOE BAY UN GRIN V-223 Operator BP EXPLORATION (ALASKA INC MD 6725 TVD 5001 Completion Date 3/26/2008 Completion Status WAGIN Current Status WAGIN Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Chips Received? "YTR-'- Analysis `l~N- Received? Daily History Received? (~/ N Formation Tops~~' N API No. 50-029-23384-00-00 UIC Y Comments: Compliance Reviewed By: Date: l- BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 by ECEI V ~~ OCT 0 6 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, shake Oil & Gas Cons. Gammin>Eion Anchoragl~ `jam ~~~ V 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 8/13/2009 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 50029233910000 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 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 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-2o1 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 18.7 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 2041160 50029232130000 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-217 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 NA 1 NA 16.2 7/12/2009 2080200 50029233830000 NA 1.75 NA 4g 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 01 /08/09 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth wen ~,.~ ,. N0.5029 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 K-05C AWJB-00016 •• MEM PROD PROFILE ~e;C -_ ' -~ '.a. •y ~! vaac 12/29/08 o~ 1 t,olof VU 1 2-54/0-12 11968974 _ SBHP SURVEY ; `, :5:. 4_ 1°"~ -- `_~"~ •'"•} C, "''_> ~ 11/23!08 1 1 V-223 AXBD-0001 MEM INJECTION PROFILE .)`1.; ~ -j- _ r = .Lr~ 12/29/08 1 1 18-24B 12066555 MCNL ~~r-„-J<, ~'~ '--f ~; °.~ 10/18/08 1 1 J-18 12103680 RST %' ~ . - ' ~ `; i j ' ~J ~; ..~)!l 09/25/08 1 1 1-45/0-26 12086686 RST ] ;r°rj .- ( -: f;' 1-" 1. ~' % ~•~ 09/22/08 1 1 V-219 40018249 OH MWD/LWD EDIT ~~~; ~ - ~ .:.+ _~ ~;', t L;( ~ >~,, 11/17/08 2 1 PI FASF ACKNr1Wl Frf(]C ~C r~c~oT ev c~r_w uw~n_ eun nGTI ~rnuur. ~. -_-___.__________._..~~~.. ~....v......w.-...v •.a.•v.a. •.~~V V~~t=rVfa GNVfI IV. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 " -°' r "' P 900 E. Benson Blvd. _ ,_. r Anchorage, Alaska 99508 Date Delivered: F ~.~~ ~'~~ !j /~ ? ~~~ 4~) Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ' Anchorage, AK 995,Q3-2838 /~ ATTN: Beth ~ / I ~~ j ~ Received by: ~ ;' ~_____.__----~" ~~ i t-. :~ ~, ~+ ~®~~~ • Toy Jim Regg `~ P.I. Supervisor ~ ~LC( ~' ~'~1 FROM: John Cnsp Petroleum Inspector Mate ®f Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 15, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-223 PRUDHOE BAY UN ORIN V-223 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv '~~~--- Comm Well Name• PRUDHOE BAY UN GRIN V-223 API Well Number: 50-029-23384-00-00 Inspector Name: John Crisp Insp Num: mitJCr080714090322 Permit Number: 2os-022-o Inspection Date: 7/10/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well v-zz3 Type Inj. ~ TVD aa6s ~ ' IA ~ X40 ~ zsoo zaao za4o P.T. zoaozzo TypeTest ~ ~ Test psi I >~~ OA zso soo ~ slo szo Interval INITAL ~ Pte, F ~ Tubing 16zo I 1640 1640 1640 ~ Notes' 2 bbl's pumped for test. The State required test pressure for this well is 1500 psi. I did not request the Operator to exceed State required test • pressure, the Operator volunteered to exceed State required IA test pressure to have IA > than 500 psi above tubing pressure. ;~'l,' ~~. -~~j+l~~s~~;~~ 1 ~~~i~ Tuesday, July I5, 2008 Page 1 of 06/04/08 • ~~~~~~~ NO.4736 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Lo Descri tion Date BL Color CD L-220 11975963 CH EDIT PDC GR (USIT) / 04/22/08 1 L-221 11962592 CH EDIT PDC GR (USIT) 04/07/08 1 V-223 40016679 OH MWD/LWD EDIT ^ 03/20/08 2 1 W-30 12034892 RST ~ -( ~/ 04/11/08 1 1 G-116 11963085 MCNL 0~- / 04!01/08 1 1 05-28B 11649987 MCNL (p.- 08/17/07 1 1 P2-36A 11209594 MCNL 03/26/06 1 1 07-O1B 12021155 MCNL 9D 04/28/08 1 1 OS-34 11966251 CH EDIT PDC GR (USIT) 04/13/08 1 17-12 12057613 PRODUCTION PROFILE - ~ 05/23/08 1 1 W-31 11999015 LDL 05/25!08 1 1 GNI-02A 12057618 _ PRESS/TEMP SURVEY (o - 3 g 05/24/08 1 1 13-12 11982434 USIT _ L ~-~- 05/29/08 1 1 r~ciax Al:Rrvl)vvLtutit FitGEIF'I IiY ,ItiNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Ina Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: '"' '~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503- 83 ATTN: Beth Received by: 05/20/08 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WPII .Inh # NO.4712 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 nn nnc InfG.... n.,f~ of r,. t.... MPB-04A 12021150 MEM PROD PROFILE ty 04/17/08 1 1 MPG-13 12021151 MEM INJECTION PROFILE C _ 04/18/08 1 1 Z-26A 11978454 MEM GLS ~(p- 04/23/08 1 1 Z-29 11978453 MEM GLS - 04/22/08 1 1 Y-36 12005204 MEM GLS C,/ 02/12/08 1 1 4-14A/S-37 12031471 PRODUCTION PROFILE W/FSI 04/12/08 1 1 Y-07A 11966254 SCMT / 05/02/08 1 1 02-01 B 11966257 LDL ~ (p 05/10/08 1 1 X-16A 11975771 USIT L~ C 05/14/08 1 1 07-26 12061688 USIT - 05/16/08 1 1 05-34 11966251 USIT 04/13/08 1 1 05-23A 118966257 USIT / 05/13/08 1 1 S-33 11962596 USIT 04/15/08 1 1 V-223 12061688 CH EDIT PDC GR (USIT `~ - ~ 03/23/08 1 V-220 40016600 OH MWD/LWD EDIT ap _ 03/03!08 2 1 4-14A/S-37 40016545 OH MWD/LWD EDIT p~-~U ( / 02/18/08 2 1 05-228 11628800 MCNL 10/22/07 1 1 05-136 12021140 MCNL S 01/31/08 1 1 Z-10 12066520 RST ~ 04/10/08 1 1 D-10 11975766 RST 04/25/08 1 1 I-a.GMJG M~n1YV VVLGVVC nG\.Gr 1 D7 JIVIiY11VU NIVV nCl Vrt1V11VU VIVC \.VYT CHl.ri I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 „ ~ ~ ~ 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~ Date Delivered: ,~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: u ~\ V-223 7" Ram test Chart Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, May 19, 2008 10:48 AM To: 'Peltier, Brandon' Cc: Tirpack, Robert B Subject: RE: V-223 7" Ram test Chart Brandon and Rob, Thanks for the reply. My question is answered. Tom Maunder, PE AOGCC Page 1 of 1 ~~ Fs-oaa From: Peltier, Brandon [mailto:Brandon.Peltier@bp.com] Sent: Friday, May 16, 2008 12:41 PM To: Maunder, Thomas E (DOA) Cc: Tirpack, Robert B Subject: V-223 7" Ram test Chart Tom I have been asked to follow up on your question regarding the 7" ram test on 3/20/08 for V-223. 1 have attached the 7" Ram pressure test chart. This test would require a 7" test joint. Let me know if you have any more questions. Brandon Peltier BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling (907) 564-5912 (Direct} (907) 748-7838 (Mobile) Brandon. Peltier@bp. com «V-223 7 in ram test.ZlP» 5/19/2008 ~o~. ~~~ \ .. t fA ~ !3 ` ~ ~ i ~" ~~; . ~~~:. ~O s•~~ ~ F I • Maunder, Thomas E (DOA) From: Stewman, Sondra D [Sondra.Stewman@bp.com] Sent: Thursday, May 08, 2008 3:48 PM To: Maunder, Thomas E (DOA) Subject: RE: V-223 (208-022} Attachments: V-223, 10-407.pdf Tom, ,. .,. fj.. ~ ... • As we discussed pertaining to items 1 & 2, I have made following corrections to the attached 10-407: Item 1 - V-223 Orion Pool not Polaris Pool and therefore a WAG Item 2 - I have verified the yield on both of the Class G cement volumes is 1.16 (445 sx) Please advise of any questions or concerns. Sondra Stewman ADW Drilling Technologist ~e recxl, he present ara~ ~~t reef aZt ~e 7'~,SI~'I~EI From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, May 08, 2008 2:29 PM To: Kolstad, Scott R; Stewman, Sondra D Cc: Regg, James B (DOA) Subject: V-223 (208-022) Scott and Sondra, I am reviewing the 407 recently submitted for this well and have a few items ... 1. The well was permitted as a service well, however AIO 25A only allows WAG wells on separate approval. As such, it is not possible to directly designate the well as WAG. WINJ is the correct designation. 2. Woutd you please check the cement volume reported for the surface tail? 168 sx only gives 35 bbls, while the tail volume given in the report (3/16/08) is 78 + 15 = 93 bbls or 445 sx. 3. On 3/20/08 7" rams were installed in the BOP. It is stated that the door seals were tested. Please confirm and provide documentation that the rams were tested with a 7" test joint. With regards to 1 and 2, it may be possible to make hand corrections on the 407. Give me a call with the information. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 5/8/2008 STATE QF ALASKA ALASKA Q(L ANQ GAS Ct?NSERVATIQN CflMMiSSIt7N t a. Wetl Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned (~ Suspended a~nAC 2s cos zs.sra ^ GINJ ®WINJ Q WDSPL ®WAG [~ Other No. of Completions One 1 b. Well Class: ^ Development ~ Expkxatory ~ Service ^ Strati raphic 2. Operator Name: BP Exploraticm {Alaska) Inc. 5. Date Comp., Susp., or ~ ~~'" ~ t 2. Permit to Drill Number ~~~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 311312008 i3. API Number ~-029-23384-t1t1-00 4a, Location of Well (Gavemmentai Section}: Surface: 7. Date T.D. Reached 3119 14. Well Name and Number: P$U V--223 a6$1` FSL, 1663' FEL, SEC. i 1, T11N, Rt1E, UM Top of Productive Horizon: 3262` FSL, 3684' FEL, SEC. 12, T11N, R11E, UM 8. KB (tt above MSL}: $1.40 Grourxi {ftiNSL}: 52.9 15. Field! Pal{s): Prudhoe Ba Field 1 Orion Y l Total Depot: 3113` FSL, 3309' FEL, SEC. i 2, T11 N, R11 E, UM 9. Plug Back Depth {MD+TVD} 6521' 4839' Schrader Bluf 4b. Location of Well {State Base Plane Coordinates, NAD 27): - 5969930 Zane- ASP4 590640 f S 10. Total Depth {MD+TVD} 6725' 5(K}1' 16. Property Designation: ADL 028240 y ace: x ur TPI: x- 593917 y- 5968551 z«~- ASPa ASP4 ^ 1 t. SSSV Depth (#AD+TVD] NIA 17. Land Use Permit: 594293 y- 5968406 Zone- Total. Depot: x f Permafrost (f VD}: Thi k 0 18. Directional Survey ®Yes ~ No n inform r 19. Water , if offs NIA ft MSL ness o c 2 . 1~0' (~pP~•) 21. Logs Obtained (List all logs here and submit electr©nic and printed information per 20 AAC 25A71): AA1ND , GR ,RES., NEU, AZI DEN, PWD, CBL 22. GaS9N6, (xe:rt Arro GEaExr~+c RECC~ao CASING SETTBJG DEPTH 1~ SE'TT1HC' DEi'M Td4 HOLE A-~tT Wr. PER FT. Gw~E ToP Bona~e T~ BoTTCser S~zE CEr~rmNC RecaRO Pui.LErr N ~! 7" 26# - 0 71 Open to production or inject 23 ~rt? ~ Yes ^ No 2a. Tt~wc R~corto . I# Yep, ~+~t ~ ° ,~t~r+r~l open cu¢E DEr'TH SET rat PAC~a SET Mo :v of Top & Bottom Perforation S¢e ~~ Num~e}: t =-; 5 SPF " ~ 7~2" x 3-1d2'. ~2. x 9.211r L-80 &tfl4° 6p41' 8839' 62~' ~ 5325' Gun Diameter, 4 112 MD TVD MD TVD ~ ~ 6080' - 5130' 4498' - 4536' ' ' 25. Acs, ~RACTI~E, CEUENr SQt~eze, Erc. - 4591 6'!55` -6202' 4553 5222' - 6244' 460?' - 4624' DEPTH i~rrEtave-~ act Atantx+r & Kx~ ~ MATEWat. UsEO 6355' -6410' 4110' - 4732' 2$51)` Freeze Protected with 101 Bt~S of Diesel ~. Peoouctbra TEST Date First Production: Not on In' "on Metixtd of Operation (Flowing, Gas Lift, etc.}'. NIA Date of Test Hours Tested; PrtooucTgN Fort TEST PERtoo O~ Stu: Gas-Mc,F: WnTEr CHC~E Ste: G,~-O~ RATao: Flow Tubing Casing Press: Ca-rEO On-B~.: Gas-Mc~: WArER-Bec: O~ GRaAVrTr-API {coca;): Press. 2a-tio~ F2aTe..R 27. GoaE DATa Conventional Core(s) Acquired? ~ Yes ~ No Sidewall s A aired? ^Yes ®No H Yes to either question, list formations and interval coed (MD+TVD of tap and battorra of each}..and surmnar'¢e t"itltolo9Y and presence of oil, gas or water (submit separate Sheets with this form, if need}. Sutxnit detai~f descrrts, care ct~gu, photagcaphs acrd ~tcoratex}r analytical results per 20 AAG 250.071. i GC;Nt'~ET 0 Norte ~~ "0~ ~d ~~~ ~.. Forth 10-407 Revised 0212007 CcxsTwa~o ON REVEr:,sE ~ ~'~~ ~ J~ 11~ {'~ WELL COMPLETION QR RECQMPLETION REPORT AN LC3G ~/ ~~ I r+ _ - _.._.__-~ 28. GEOLOGIC MARKERS {LIST Alt FORMATIONS AND RS ENCOUNTERED}: 29. FORMATION TESTS NAME MR TVD Welt Tested? (~ Yes ~ No Permafrost Top 28.5' 28 5' ff yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 1855' 1701' detailed test information per 20 AAC 25.071. Top of Ugnu 3566' 2907' Ugna MA 5534' 4088' None Ungu MB1 560T 4143' Ugnu MB2 5687' 4202` Ugnu MC 5762' 4258' Schrader Bluff NA 5866' 4336' Schrader Bluff NB 5897' 4359' Schrader Bluff NC 5941' 4392' Schrader Bluff NE 5950' 4399' Schrader Bluff NF 6022' 4453` Schrader Blu€f fJA 6080` 4498' Schrader Bluff OBa 6165' 4563' Schrader Bluff QBb 6212' 4599' Schrader Bluff OBc 6285' 4655' Schrader Bluff OBd 6353' 470$' Schrader Bluff QBe 6438' 4774° Schrader Bluff OBf 6488` 4813' Base Schrader Bluff OBf {Top Goiville) 6555' 4866' Formation at Tots! Depth {Name}: Colville Muds#one 6725' 5001' 30. List of Attachments: Summary of Daily Dulling Reports, PasfiWell Work Summary, Welt Schematic Diagram, Surveys and al=eak t7ff Test Summa . 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra ewman .~--~ Drilling Technologist Date ~" PBU V-223 208-022 Prepared By lVameJNumber. Sondra Stewman, 564-4750 Well Number Permit No. I Aooroval No. or<rirrgg Engineer: Amanda Rebat, 564-5543 (NSTRUC710NS GeNeaa~: 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 weft 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 tnjection, Water Injection, Water-Attemating-Gas Injection, Satt Water Disposal, Water Supply for Injection, Observation, or Other. Muttipie 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. ITeN 4b: TP! (Top of Producing interval). ITea 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. tlse same as reference for depth measurements given in other spaces on this form and in any attachments. ITe~ 13: The API dumber reported to AOGGC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and T VD for the top and base of permafrost in Box 28. ITeea 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). Irerr 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-ln, 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 RAC 25.071. (TEM 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 ~~ C I~C:3A.NICAL INTEGRITY R :PORT - ~ - °UD u'.T~ : ~ ~'~~~~ ~ OPER ~ FIELD _~ `~ .G ~~'.,Sr~~. - ~~aC,-atS~ riLL NI]MBER Q~iph ~'~~- NtLL DAT_ ~_ TD : Co~~~?~-. ~Q 1 Z"V'D ; PBTD : ~~ ` ~ID ~~ TVD C as i^ g ~ t` Shoe : `1~ ~ b ~ID t-14~c~ TVD ; L V . ~ ~ ?~ •'T'jr~i ~~:ae_ . ~~. Shoe. :~ 'f'Vr ; ~OP . '_-JJ ',J ~y~ ~ :~D,~° X11 `~3 P2.CKer~,_~ TVD; Set at ~o~CJ ole S_~e ~S~l`t and N'P. Pe~f ~6~ to ~,\~ L~o~s~~> ~'C'r'..ei?~IC~...., _NTEGi2?"TY - PART #? Ynr~uius Press Test: _? ; 15 rein ~0 min Comments : ~~~:~ ~ ~ . ~~ '~p ~"~~ ~. `1C~c~ ~C~~ `rc~~ '.~CH~+~iIC?~, INTEGRIT`~ -PART # Z t----~I ~~ t~~rj~c~ Cement Volumes : ~~t. L:~ner ~ ~_; Csg ~!~ ~o ~,~ DV '~1 Cu,t sol to cover per~s ~®Uh-~s c~~-~-~el~-c~-~- ~ CCs heoretical TOC C ~~~,Y,~ ~'~~ ~Vr--~L-\ 3I~3- Cement Bond Log (Yes or No) In AO~~ File -~c~. _ C5L Evaluation, gone above perfs tic ~` r~~ ~w~ ~ Production Lag: Type Evaluation i C0~1G:LJSIOt1S : t ?arm ~1 STATE OF ALASKA '~~ ALASKA OIL AND GAS CONSERVATION COM ISSION RECEfVE® APR 2 1 2008 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas Cons. Commission 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ~ zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WIN ^ WDSPL ®WAG ^ Other No. of Completions One 1 b. Well CI ^ Development ^ Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska c. 5. Date Comp., Susp., or Aband,/ 3/26/2008 ~~, ~ 12. Permit to Drill Number 208-022 3. Address: P.O. Box 196612, Anchora Alaska 99519-6612 6. Date Spudded 3/13/2008 ~ 13. API Number 50-029-23384-00-00 4a. Location of Well (Governmen Section): Surface: ' ' 7. Date T.D. Reached 3/19/2008 ~ 14. Well Name and Number: PBU V-223 4681 FSL, 1663 FEL, SEC. 11, T , R11 E, UM Top of Productive Horizon: 3262' FSL, 3684' FEL, SEC. 12, T11 N, 11 E, UM g KB (ft above MSL): 81.40 Ground (ft MSL): 52.9 15. Field /Pool(s): Prudhoe Ba Field / Po Is Pool Y Total Depth: 3113' FSL, 3309' FEL, SEC. 12, T11N, R1 , UM 9. Plug Back Depth (MD+TVD) 6521' 4839' 4b. Location of Well (State Base Plane Coordin s, NAD 27): Surface: x- 590640 y- 5969930 Zone- SP4 10. Totat Depth (MD+TVD) 6725' 5001' 16. Property Designation: ADL 028240 TPI: x- 593917 y_ 5968551 Zone- P4 Total Depth: x- 594293 y- 5968406 Zone- A 11. SSSV DeN A(MD+TVD) 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submi I ctronic nd rinted inf rmati n er 20 AA 25.0 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic a MWD , GR , RES, NEU, AZI DEN, PWD, CBL printed information per 20 AAC 25.071): 22. CASING, LINER D CEMENTING RECORD CASING SETTING DEPTH MD: NG DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM T BOTTOM SIZE CEMENTING REGORD PULLED 20" 91.5# A-53 Surface 80' Surfa 80' 42" 260 sx Arctic S t A rox. 9-5/8" 40# L-80 29' 3424' 29' 2822' 12-1/4" 620 sx Dee Crete 1 sx Class'G' 7" 26# L-80 26' 6716' 26' 96' 8-3/4" 433 sx Class'G' 23. Open to production or inject ion? ®Yes ^ No 24. Tue{NG RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 4-1/2" Gun Diameter, 5 SPF 4-1/2" x 3-1/2", 12.6# x 2#, L-80 6404' 6041' 6139', 6208' 8 6325' MD TVD MD TVD ~ c 60$0' - 6130' 4498' - 4536' C1 ~P~~~~~~ 6166' - 6202' 4563' - 4591' v~,/ 25~ CID, CTURE, CEMENT SQUEEZE, ETC. 6222' - 6244' 4607 - 4624' DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED ~~~~~~/ 6356' -6410' 4710' - 4752' 2850' Freeze rotected with 101 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Injection Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE E: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PfesS: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY I (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A uir ? ^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 o il, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results ~e AAG.,~50.071. 4, (;ii~;'t~' ~ iQ~ None y pA -~ y ~, Form 10-407 Revised 02/2007 ;~`'~ F NTINUED ON REVERSE .SIDE 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested . ^ Yes ®No Permafrost Top 28.5' 28.5' If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 1855' 1701' detailed test information per 20 AAC 25.071. Top of Ugnu 3566' 2907' Ugna MA ~ 5534' 4088' None Ungu M61 5607' 4143' Ugnu MB2 5687' 4202' Ugnu MC 5762' 4258' Schrader Bluff NA 5866' 4336' Schrader Bluff NB 5897' 4359' Schrader Bluff NC 5941' 4392' Schrader Bluff NE 5950' 4399' Schrader Bluff NF 6022' 4453' Schrader Bluff OA 6080' ' 4498' ' ~~~~~®~® Schrader Bluff OBa 165 4563 Schrader Bluff OBb 12' 4599' ~ Schrader Bluff OBc 6 4655' ~~ "''!~ ~~~ ~~ Schrader Bluff OBd 635 4708' Schrader Bluff OBe 6438' 4774' Schrader Bluff OBf 6488' 4813' Base Schrader Bluff OBf (Top Colville) 6555' 4866' Formation at Total Depth (Name): Colville Mudstone 6725' 50 ' 30. list of Attachments: Summary of Daily Drilling Reports, Post W Work Summary, Well Schematic Diagram, Surveys and a Leak Off Test Summa 31. I hereby certify that the foregoing is true a_nd correct to the best of my owledge. Signed Sond a Stewma ~ T' le Drilling Te ologist Date - ~ '~~ PBU V-223 208-022 Prepared ByName/IVumber. Sondra Stewman, 564-4750 Well Number P rmi No. / A rov I N Drilling Engineer: Amends Rebol, 564-5543 INSTRUCTIONS GeNeRAL: This form is designed for submitting a complete and correct well completion report and Ikon 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 r rt when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injectio Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one I 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 fol~epth 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 ox 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the locatio f 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, a 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 se ately 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 er (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed descripti 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 information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original TREE _ 4-1/16" CIW WELLHEAD= FMC ACTUATOR = AXELSON ~ KB. ELEV - 81.4' BF. ELEV...- KOP = 400' Max Angle = 56~"~a 3136' Datum MD = 6059' Datum TV D = 4400' SS S g :~ [L _ 9-5/8" CSU, 40#, I_-8f3, ID = 8.835" XO from TGII to BTC-M ?" MARKER JO~VTWI RA TAG I~ 6041" Tt3G Wf RA Tag irs Centralizer 1-a 6170" Mnmlum 113 = 2.75" cr fi445' 3-112~~ F1E a ~'~ NiPP~E PERFORATION SUMMARY REF LOG: Scirlur~erger AND 3/2012408 ANGLEATTOPPERF; 40° X6080' Note:. SfZE SPF INTERVAL O~ntSgz DATE 4.5" 5 60$0 ' 6 t 30 O 43/22/08 4.5" 5 6168 - 6242 O 43162108 4.S' 5 6222 - 6244 O 43122108 4.5" 5 6356 -6410 O 03122/48 NOTES: $$_~~4-1/2" x 3-1/2" XO STUB $~,$' 3-112" HES X N4P ID = 2.813„ WATERFLOO~GAS LIFT MANDRELS ST MD TVD DEV TYPE ' VLV . LATCH PORT DATE 8 5993 4431 41 ° MMG C7CK-1 RKP 4 43125148 6084 4497 44° ti1Nu1C-W CJM1' RK 4 0312510$ 6 6109 '' 4519 44° tJ1viG-W CMA1' ' RK 0 43/25/08 5 6160 '4559 40° TdIhAG-Nt CKUIY RK 0 03/25i€I8 4 6189 ' 4581 39° MMfa-W DMY RK 0 03/25Jt18 3 6238 4619 39° +AG- DMY RK 0 03/25148 2 6286 4656 39° f-W DMY RK 4 43125K18 1 6395 474D 39° 1VIhA0-1N DMi' RK 0 03125/48 6Q10' ~ 3-112'" HITS X NIP, fCl = 2.813" 6041` ?" X 3-112" HES AHR Packer, ID = 2 6055' NDPG Press/Temp Sensor Sub I-Wire run from surface 6128' ~ 3-1 l2" HES X NIP, ID = 2.813" ~ 6139' 7". X 3-112" HE.S AHR Packer, ID = 2.9 6152' NDPG Press/Temp Sensor Sub 6208' 6221' ~ 6227' 7" X 3-1/2" HES AHR Packer, ID = 2.f NDPG Press/Temp Sensor Sub 3-1/2" HES X NIP, ID = 2.813" 6325' ~ ?'" X 3-112" HES AHR Packer, ID = 2.921„ 6339' NDPG PressiTemp Sensor Sub 6374' 3-112" HES X NIP, ID = 2.813" 6424' 3~-1i2" HES X NIP, ID 2 813" w1RHGm pig 64-45' 1 I 3-112" HES XN NIP. tD = 2.75" 13-112" TBG, 9.2fF, L-80, .0487 bpf, ID = 2.992„ I 6466' PBTD 6521' 7" CSG, 26#, L-84, ID = 6.2?6"' 6716' TE REV BY COM1IYuII~VI'S DATE. 6108 fVW3f~ OF~IGINAL COMPLETIC3N I 3-1/2" WLEG, ID= 3.00" I ORLON UNCf 11VI=LI: V-223 f'ERIST No: 2484224 Fief No: 50-429-233844000 Sec 1 i ; T11 N; R11 E; UM BP Ertpl~ratian {Afastta) BP EXPLORATION Page 1 of 12 Operations Summary Report Legal Well Name: V-223 Common Well Name: V-223 Spud Date: 3/13/2008 Event Name: DRILL+COMPLETE Start: 3/11/2008 End: 3/26/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/26/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To 'i Hours Task 'Code NPT Phase Description. of Operations 3/11/2008 12:00 - 18:00 6.00 MOB P PRE Pull pits away from sub, move rig from V-220 to V-223, spot rig over well, lay out herculite, and set mats for the rig. 18:00 - 19:30 1.50 RIGU P PRE Move pits from V-220 to V-223, spot pits and set mats. 19:30 - 00:00 4.50 RIGU P PRE Hook up interconnect, steam, and water to pit room. Rig up flow line, stairs, berm around rig, pits, and set cuttings box. 3/12/2008 00:00 - 05:00 5.00 DIVRTR P PRE Rig Accept on 3-12-08 at 00:00. Install 20" riser, hydraulic accumulator hoses to Hydrill and knife valve, function test diverter, load pipe shed with drill pipe, and take on fresh water. 05:00 - 06:30 1.50 RIGU P PRE Change out saver sub and gripper dies. 06:30 - 10:00 3.50 RIGU P PRE Strap drill pipe, build spud mud. 10:00 - 17:00 7.00 RIGU P PRE Pick up 99 single joints of drill pipe, building stands and rack back in derrick. Pick up 24 single joints of HWDP, building stands and rack back in derrick. (Tagged bottom at 108') 17:00 - 18:00 1.00 RIGU P PRE Pick up BHA tools to rig floor. 18:00 - 20:30 2.50 RIGU P PRE PJSM. Make up Jar, drill collar stands and rack back in derrick. 20:30 - 21:00 0.50 DIVRTR P PRE Perform diverter function test and accumulator drawdown test. Knife valve opened in 15 sec, annular closed in 40 sec. Witnessing of test waived by AOGCC rep Chuck Scheve. Test witnessed by BP WSL R. French and NAD TP C. Page. 21:00 - 21:30 0.50 RIGU P PRE Hold Pre-Spud meeting with Ralph Langham's crew, mud engineer, SLB DD, MWD, and Gyro Data. 21:30 - 00:00 2.50 RIGU P PRE Make up BHA #1: New 12 1/4" HTC MXL-iX bit, 1.5' ABH PDM, NM lead DC, NM Stab, MWD, NM Stab, NM XO, UBHO. 3/13/2008 00:00 - 02:00 2.00 RIGU P PRE Rig up Sperry Sun E-line and Gyro Data. 'Held Pre-Spud meeting with Dale Kekoni's crew during Pre-Tour Safety Meeting. 02:00 - 02:30 0.50 RIGU P PRE Fill lines and conductor, check for leaks - OK. Pressure test mud lines and kell hose to 3;500 si - OK. 02:30 - 05:30 3.00 DRILL P SURF S ud 'n V-223i 0 0 hr 3/ 2 Drill 12 1/4" surface hole from 108' to 351' Gyro survey every stand. 550 gpm, 700 psi off, 800 psi on 60 rpm, .5k TO off, 1.5k TO on PU - 53k, SO - 53k, RWT - 53k, WOB 5-10k. 30 ft wipes and circ 5 minutes prior to connections and Gyro surveys. 05:30 - 07:00 1.50 DRILL P SURF POH from 351' to 109'. Make up NM Stab in DC stand. Pick up Jar stand and run back in hole to 351'. 07:00 - 12:00 5.00 DRILL P SURF Drill 12 1/4" surface hole from 351' to 750'. Gyro as needed. 550 gpm, 1,100 psi off, 1,260 psi on 80 rpm, 1 k TQ off, 2-5k TO on PU - 60k, SO - 60k, RWT - 63k, WOB 20-30k. 30 ft wipes and circ 5 minutes prior to connections when Gyro surveys were run. AST - 1.91 hrs, ART - 2.36 hrs 12:00 - 18:00 6.00 DRILL P SURF Drill 12 1/4" surface hole from 750' to 1,286'. G ro as needed. 550 gpm, 1,150 psi off, 1,260 psi on 80 rpm, 1-2k TO off, 2-5k TO on PU - 60k, SO - 60k, RWT - 65k, WOB 20-30k. 30 ft wipes and circ 5 minutes prior to connections when Gyro surveys were run. Nrimea: an vzuua 1GJZ:UZ YM BP EXPLORATION Page 2 of 12 Operations Summary Report Legal Well Name: V-223 Common Well Name: V-223 Spud Date: 3/13/2008 Event Name: DRILL+COMPLETE Start: 3/11/2008 End: 3/26/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/26/2008 Rig Name: NABORS 9ES Rig Number: Date From - To Hours ' Task Code NPT -- Phase Description of Operations _ _ _- 3/13/2008 18:00 - 18:30 0.50 DRILL P 18:30 - 23:30 5.00 DRILL P 23:30 - 00:00 I 0.501 DRILL I P 3/14/2008 100:00 - 00:30 I 0.501 DRILL I P 00:30 - 02:30 2.00 DRILL P 02:30 - 03:00 0.50 DRILL P 03:00 - 04:30 1.50 DRILL P 04:30 - 12:00 7.50 DRILL P 12:00 - 19:15 ~ 7.25 ~ DRILL ~ P 19:15 - 20:30 I 1.251 DRILL I P 20:30 - 22:30 I 2.001 DRILL I P 22:30 - 00:00 1.50 DRILL P 3/15/2008 00:00 - 00:45 0.75 DRILL P 00:45 - 02:00 I 1.251 DRILL I P SURF Rig down Gyro Data. SURF Drill 12 1/4" surface hole from 1.286'to 1.766'. 550 gpm, 1,650 psi off, 1,720 psi on 80 rpm, 2-3k TO off, 3-4k TO on PU - 80k, SO - 75k, RWT - 80k, WOB 20-30k. 30 ft wipes prior to connections. AST - 4.58 hrs, ART - 2.78 hrs SURF Circulate 1 bottoms up C?~ 550 gpm, 1,620 psi. 2nd bottoms up C~3 600 gpm, 1,760 psi 80 rpm, 1.7k TO. MW - 9.2 ppg, Vis 330 SURF Continue circulating for total of 3 1/2 bottoms before shakers cleaned up. 600 gpm, 1,760 psi. 80 rpm, 1.7k TO. MW - 9.2 ppg in and out, Vis 330. Monitor well, well static SURF Short trip to Jar stand from 1,766' to 238' without pumping and with minimal drag. Wiped 25k overpulls clean. SURF Service topdrive. SURF Run in hole without problem from 238'to 1,766'. No fill. SURF Drill 12 1/4" surface hole from 1.766' to 2.720'. 650 gpm, 2,350 psi off, 2,500 psi on 80 rpm, 3-4k TO off, 5-7k TO on PU - 85k, SO - 75k, RWT - 83k, WOB 20-25k. 30 tt wipes prior to connections. MW - 9.4ppg in 9.4+ppg out, Vis 190 in, 340 out. AST - 3.30 hrs, ART - 1.97 hrs. SURF Drill 12 1/4" surface hole from 2 720' to TD ~ 3.434 MD.2> 650 gpm, 2,770 psi off, 2,890 psi on 80 rpm, 3-4k TO off, 5-7k TO on PU - 98k, SO - 81 k, RWT - 91 k, WOB 20-25k. 30 ft wipes prior to connections. MW - 9.4ppg in 9.4+ ppg out, Vis 200 in, 250 out. AST - 1.13 hrs, ART - 2.28 hrs. `H drates encountered at 3 250' Normal amount SURF Circulate for short trip. 1st bottoms up C~ 660 gpm, 2,750 psi ICP, 2,730 FCP. Next 2 bottoms up C~3 720 gpm, 3,115 psi ICP, 2,910 FCP. 100 rpm, 3.5k TO, Shakers clean after 2nd bottoms up. MW - 9.2 ppg in and out Monitor well, well static SURF Short trip to from 3,434' to 2,710'. 1st 2 stands pulled OK. Continued pulling dry from 3,200' to 2,710', having to work pipe for overpulls and occational swabbing. SURF Backream from 2,710'to 1,861'. 550 gpm, 1,950 psi, 80 rpm, 3-5k TO. SURF Continue backreaming from 1,861'to 1,766'. Blowdown topdrive. Pull 2 more stands from 1,766' to 1,586' without problem. SURF Run in hole from 1,586' to 3,380' without problem. rnnted: anvzuus ~z:~cuzrnn • ~ BP EXPLORATION Page 3 of 12 Operations Summary Report Legal Well Name: V-223 Common W ell Name: V -223 Spud Date: 3/13/2008 Event Nam e: DRILL+C OMPLE TE Start : 3/11/2008 End: 3/26/2008 Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 3/26/2008 Rig Name: NABOBS 9ES Rig N umber: Date From - To Hours i Task Code NPT Phase Description of Operations 3/15/2008 00:45 - 02:00 1.25 DRILL P SURF Precautionary wash to bottom. No fill. 02:00 - 04:00 2.00 DRILL P SURF Circulate for trip out of hole. Stage up pumps to 610 gpm, 2,525 psi ICP, 2,475 psi FCP. Heave amount of clay and pea gravel circulating 1st bottoms u. Increase rate to 710 gpm, 3,100 psi ICP, 3,000 psi FCP. Large amount of clay, some pea gravel during 2nd circulation. Moderate amount of cuttings during 3rd circulation. 4th and 5th bottoms u were clean. MW 9.4 ppg in and out. 04:00 - 07:30 3.50 DRILL P SURF Blowdown topdrive, observe well -well static. POH to run 9 5/8" casing from 3,434' to 270' without problem. 25k overpull below the permafrost. 07:30 - 10:30 3.00 DRILL P SURF Stand back Jar and DC stands. Laydown BHA #1. Bitgrade:2-3-RG-G-E-1 -ER-TD. 10:30 - 12:00 1.50 DRILL P SURF Clear rig floor of drilling tools. Clean rig floor. 12:00 - 15:00 3.00 CASE P SURF Rig up to run 9 5/8" surface casing. Make hanger dummy run. 15:00 - 16:30 1.50 CASE P SURF Pick up and Baker-Lok shoe track. Check floats - OK. 16:30 - 21:00 4.50 CASE P SURF Continue running in hole from 125' to tight spot @ 2,164'. Attempt to work through without pumping without success. Make up casing with BOL NM dope to 9,500 ft/Ibs TO. Bowspring centralizers on 1st 25 joints. Fill pipe every joint and top off every 10 joints. 21:00 - 22:15 1.25 CASE P SURF Wash casing down from 2,164'to 2.287' 3.5 bpm, 380 psi. 22:15 - 00:00 1.75 CASE P SURF Run in hole without pumping from 2,287' to 2,656'. Washed 1 more joint down from 2,409' to 2,451' 'No mud losses. 3/16/2008 00:00 - 01:15 1.25 CASE P SURF Continue running in hole without pumping from 2,656' to 3,106 Started pushing awa mud. 01:15 - 02:00 0.75 CASE P SURF Circulate and reciprocate casing at 2 bpm, 520 psi. Had minimal returns startin out then had full circulation. `Lost 34 bbls total from pushing mud away and circulating. 02:00 - 02:30 0.50 CASE P SURF Continue running in hole from 3,106' to 3,392' with full pipe displacement. 02:30 - 03:00 0.50 CASE P SURF Make up casing hanger and land casing on depth C~ 3,424'. PU - 150k, SO - 90k (without pumping) Halliburton 9 5/8" Float Shoe, Set C~ 3,424 ft. 2 Jts 9 5/8" 40# L-80 BTC Casing (#1- #2) Halliburton 9 5/8" Float Collar 81 Jts 9 5/8" 40# L-80 BTC Casing (#3-#83) ~ 9 5/8" 40# L-80 BTC Hanger P x P Pup Jt 9 5/8" Fluted Casing Hanger Baker-Lok Shoe-track Jts #1-3 Bowspring Centralizers: 1 on stop ring 5' above shoe on jt #1 1 on joints #2- #25 25 Total Centralizers 03:00 - 04:00 1.00 CEMT P SURF Rig down Franks tool, rig up Dowell 2 plug cement head. 04:00 - 09:30 5.50 CEMT P SURF Stage pump up from 1.5 bpm to 6 bpm over one bottoms up. No mud losses. Printed: 4/11/2008 12:32:02 PM ~ ~ BP EXPLORATION Page 4 of 12 Operations Summary Report Legal Well Name: V-223 Common Well Name: V-223 Spud Date: 3/13/2008 Event Name: DRILL+COMPLETE Start: 3/11/2008 End: 3/26/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/26/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Haurs Task Code NPT Phase Description of Operations 3/16/2008 04:00 - 09:30 5.50 CEMT P SURF Circulate and condition mud for cement job ~ 6 bpm, 420 psi ICP, 280 psi FCP. Vis - 75, PV - 15, YP - 18. PU - 137k, SO - 102k initial string weights. PU - 160k SO - 115k final strin wei hts. Reci rocate casin in 20 ft strokes. *Held Cementing PJSM while circulating. 09:30 - 13:30 4.00 CEMT P SURF Switch to Dowell. Pump 5 bbls of fresh water. Pressure test lines to 4,000 psi - OK. Pump 100 bbls of 10.0 ppg MudPush II spacer ~ 5.5 bpm avg, 210 psi ICP, 120 psi FCP. Drop bottom plug with positive indication of plug exit. Mix on the fly and pump 420 bbls of 10.7 ppg DeepCRETE cement @ 5 bpm avg, 250 psi ICP, 400 psi FCP. Mixon the fly (valve on pump frozen) and pump 78 bbls of 15.8 ppg Class "G" Tail cement ~ 2 bpm avg, 300 psi ICP, 180 psi FCP. *Landed casing after switching to Tail cement due to sticky. down weight. PU - 155k, SO - 75k. *MudPush spacer returned to surface with 45 bbls of tail away. Mix on the fly and pump 15 bbls of 16.3 ppg Class "G" DuraSTONE tail cement C~? 2 bpm, 140 psi ICP, 100 psi FCP. Drop top plug and kick out with 5 bbls of fresh water. Positive indication of plug exit. Switch to rig and displace cement with 249 bbls of 9.4 ppg Spud Mud C«~ 5 bpm, 480 psi ICP, 800 psi FCP. *Cement to surface with 99 bbls of mud awa * Slow pump to 2 bpm, 11 bbls prior to bumping plug. 670 psi ICP, 700 psi FCP. Bump plug with 1,200 psi, 96.3% pump efficency. Hold pressure for 2 minutes. Bleed off pressure and check floats - OK. CIP @ 13:14 hr. *Returned 150 bbls of cement back to surface = 165% washout factor. 13:30 - 14:00 0.50 CEMT P SURF Pressure test 9 5/8" casing to 3,500 psi - 30 minutes -Good es . 14:00 - 18:30 4.50 CEMT P SURF Rig down casing and cementing equipment. Flush out surface hydril. Laydown landing joint. Clean out from under rotary table. Clean surface equipment of all cement residue. *Changed pump liners to 5". *Load pipeshed with 4" drill pipe. 18:30 - 00:00 5.50 DIVRTR P SURF Nipple down Diverter system. 3/17/2008 00:00 - 01:30 1.50 DIVRTR P SURF Continue nipple down diverter. Secure hydril in cellar. 01:30 - 04:30 3.00 WHSUR P SURF Nipple up casing head. Test metal to metal seals to 1,000 psi - 15 min - OK. Nipple up tubing head. Printed: a/it/zoos 1z:32:oz NM BP EXPLORATION Page 5 of 12 Operations Summary Report Legal Well Name: V-223 Common Well Name: V-223 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES ~ Date From - To I Hours Task Code NPT . 3/17/2008 04:30 - 10:00 5.50 BOPSU P 10:00 - 13:00 3.00 BOPSU P 13:00 - 17:30 4.50 BOPSU P 17:30 - 19:00 ~ 1.50 ~ BOPSUFj P 19:00 - 21:00 2.00 DRILL P 21:00 - 00:00 3.00 DRILL P 3/18/2008 00:00 - 00:45 0.75 DRILL P 00:45 - 01:15 0.50 DRILL P 01:15 - 03:00 I 1.751 DRILL I P 03:00 - 06:30 I 3.501 DRILL I P 06:30 - 08:30 2.00 DRILL P 08:30 - 10:00 1.50 DRILL P 10:00 - 11:00 1.00 DRILL P 11:00 - 11:15 0.25 DRILL P 11:15 - 12:00 0.75 DRILL P 12:00 - 12:30 0.50 DRILL P 12:30 - 13:00 0.50 DRILL P Spud Date: 3/13/2008 Start: 3/11 /2008 End: 3/26/2008 I Rig Release: 3/26/2008 Rig Number: Phase Description of Operations SURF Nipple up BOPE. SURF Rig up to test BOPE. SURF Pressure test BOPE to 250 psi low, 4,000 psi high for 5 minutes each test. Test annular preventer to 250 psi low, 3,500 psi high for 5 minutes each test. Perform accumulator draw down test. Witnessing of test waived by AOGCC rep Chuck Sheve. Test witnessed by BP WSL J. LeBlanc and NAD TP M. Ashley. SURF Rig down BOPE test equipment. Blowdown surface lines. Install wear bushing. PROD1 Pick up 24 single joints of drill pipe and rack back in derrick. PROD1 Make up BHA #2: Re-built 8 3/4" HTC HCM5062 bit, 1.15' ABH PDM, NM Stab, LWD/ARC, MWD, LWD/ADN, tea NM DCs, Saver Sub, Jar stand. PROD1 Run in hole with BHA #2 on HWDP to 988'. PROD1 Shallow hole test MWD tools - OK. 506 gpm, 1,120 psi. PROD1 Continue running in hole, picking up single joints of drill pipe from 988' to 2,225'. Picked up Ghost reamer at 1,556'. PROD1 Hold unannounced D-1 BOP drill. PJSM on Stripping D-6 Drill and D-5 Well Kill Drills. Apply 200 psi on annulus. Strip in hole 3 joints with personnel taking turns on choke. Bleed off pressure and open annular preventer. Make up topdrive and take slow pump rate. Close BOP and apply 200 psi to annulus by pumping down drill pipe. Shut down, record pressures. Bring up pump to kill rate while holding constant casing pressure, then practice holding constant drill pipe pressure simulating circulating out kick. Redo process and change positions on pump operator and choke operator several times. Hold Post Drill review and POH 1 stand to retrieve safety valves. Blowdown surface lines & choke manifold. PROD1 Continue running in hole, picking up single joints of drill pipe from 2,225' to 3,079'. PROD1 Make up topdrive, install topdrive blower hose. Wash from 3,079' to top Landing Collar, on depth at 3,339'. 500 gpm, 1,750 psi, 60 rpm, 2-3k TO PU - 100k, SO - 70k, RWT - 85k. PROD1 Drill out Float Collar, cement, Float Shoe and rathole to 3,434'. 400 gpm, 1,950 psi, 60 rpm, 4-5k TO. Start mud change out from Spud Mud to 8.8 ppg LSND mud the last 10 ft of the shoe track. PROD1 Drill 20 feet of new hole from 3,434' to 3,454'. 500 gpm, 1,200 psi, 60 rpm, 4-5k TO. PROD1 Finish mud change out to LSND mud. 500 gpm, 1,200 psi, 60 rpm, 4k TO. PU - 105k, SO - 70k, RWT - 87k. PROD1 Perform 9 5/8" shoe LOT: 3,424' MD, 2,821' TVD MW - 8.8 ppg, LOP - 500 psi EMW - 12.21 PROD1 Obtain benchmark ECD's and SPR's r~rmtea: an vzuua 12:JZ:U2 YM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: V-223 Common Well Name: V-223 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date From - To Hours Task 'Code NPT 3/18/2008 12:30 - 13:00 0.501 DRILL P 13:00 - 00:00 I 11.001 DRILL I P 3/19/2008 ~ 00:00 - 12:30 ~ 12.50 ~ DRILL ~ P 12:30 - 13:30 I 1.001 DRILL I P 13:30 - 18:00 4.50 DRILL P 18:00 - 18:30 0.50 DRILL P 18:30 - 19:30 1.00 DRILL P 19:30 - 20:00 0.50 DRILL P 20:00 - 21:30 1.50 DRILL P 21:30 - 00:00 2.50 DRILL P 3/20/2008 100:00 - 02:30 I 2.501 DRILL I P 02:30 - 03:30 1.00 DRILL P 03:30 - 05:00 1.50 DRILL P 05:30 - 07:30 2.001 DRILL ~ P 07:30 - 08:00 0.50 CASE P 08:00 - 10:00 2.00 CASE P 10:00 - 14:30 4.50 CASE P 14:30 - 15:00 0.50 CASE P Start: 3/11 /2008 Rig Release: 3/26/2008 Rig Number: Page 6 of 12 ~ Spud Date: 3/13/2008 End: 3/26/2008 Phase Description of Operations PROD1 587 gpm, 1,510 psi. CECD - 9.15 ppg (without ARC correction of .22) PROD1 Directionally drill 8 3/4" hole from 3,454' to 5,270'. 585 gpm, 2,130 psi off, 2,375 psi on 100 rpm, 5.2k TO off, 6.Sk TO on PU - 117k, SO - 84k, RWT - 97k, WOB - 10-25k. CECD - 9.38 ppg, AECD - 10.37 ppg. AST - 1.88 hrs, ART - 3.28 hrs. 'Pumped 30 bbl Hi-Vis sweep C~ 4,220' and returned a 20% increase in cuttings when sweep was back to surface. 'No mud losses for the day. PROD1 Directionally drill 8 3/4" hole from 5,270' to TD 6,725' MD, 5001 585 gpm, 2,700 psi off, 3,000 psi on 100 rpm, 7-8k TO off, 8-10k TO on PU - 150k, SO - 100k, RWT - 120k, WOB - 5-20k. CECD - 9.83 ppg, AECD - 10.38 ppg. AST - 1.60 hrs, ART - 5.07 hrs 'Pumped a 30 bbl Hi-Vis sweep C~ 5,270' without an increase in cuttings when sweep was back to surface. PROD1 Circulate a 30 bbls H-Vis sweep surface to surface. 585 gpm, 2,760 psi, 100 rpm, 8.1 k TO. No increase in cuttings when sweep was back to surface. PROD1 Backream ghost reamer to shoe from 6,725' to 4,984'. 585 gpm, 2,560 psi, 100 rpm, 5.8k TO. PROD1 Circulate bottoms up while pulling up from 4,984' to 4,888' 585 gpm, 2,360 psi. MW - 9.2 ppg in and out. PROD1 Blowdown topdrive. Observe well - OK. POH from 4,888' to 3,366'. PROD1 Pump dry job. Blowdown topdrive and disconnect blower hose. PROD1 POH from 3,366'to 1,562'. Laydown ghost reamer. Continue POH to 998'. PROD1 POH laying down HWDP from 998'to 254'. 'No mud losses for 8 3/4" interval. PROD1 PJSM on nuclear source. Laydown BHA #2. Bitgrade:3-4-BT-A-X-2-WT-TD PROD1 Clear and clean rig floor. PROD1 Pull wear bushing. Make up stack jetting tool and clean out BOP stack. PRODi Set BOPE test plug. Change upper rams from 3.5" x 6" VBR's to 7". Test door seals to 250 psi low, 4,000 psi high - OK. RUNPRD Make dummy casing hanger run. RUNPRD Rig up to run 7" casing. RUNPRD PJSM. Baker-Lok and make up 7" 26# L-80 BTC-M casing shoe track. Check floats - OK. Continue running in hole with 43 joints of 7" BTC-M casing to crossover joint C~? 1,808'. Fill every joint and break circulation every 15 joints. 8,000 fUlbs make up torque. Used BOL 2000 NM pipe dope. Installed 2 straight blade centralizers, separated by stop ring, per joint RUNPRD Change casing running equipment to Torque-Turn for TCII casing. F'fllll8tl: 4/11lLUUC 1L:JL:UL YM BP EXPLORATION Page 7 of 12 Operations Summary Report Legal Well Name: V-223 Common Well Name: V-223 Spud Date: 3/13/2008 Event Name: DRILL+COMPLETE Start: 3/11/2008 End: 3/26/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/26/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To ,Hours. Task Code NPT Ph ase ~ Description of Operations 3/20/2008 14:30 - 15:00 0.50 CASE P RUNPRD Circulate l~ 175 gpm, 305 psi. 15:00 - 19:00 4.00 CASE P RUNPRD Continue running in hole with 7" BTC-M /TCII casing from 1,808' to 3,390'. Fill every joint and break circulation every 15 joints. 10,100 ft/Ibs make up torque. Used JetLube Seal Guard pipe dope. Installed 2 straight blade centralizers, separated by stop ring, per joint, on the 1st 12 jts. Ran total of 111 centralizers and 55 stop rings. PU - 105k, SO - 84k, 19:00 - 19:30 0.50 CASE P RUNPRD Circulate 1.5 annular volumes ~ 5 bpm, 440 psi ICP, 365 psi FCP. 19:30 - 00:00 4.50 CASE P RUNPRD Run in open hole from 3,424' to 4,556'. Fill every joint and circulate down every 10 jts C~? 4 bpm, 570 psi. 'No mud losses. 3/21/2008 00:00 - 07:00 7.00 CASE P RUNPRD Continue running 7" BTC-M x TCII production casing in open hole from 4,556' to 6,687'. Pick up hanger and landing joint and remove casing slips. Land casing on depth ~ 6,716'. PU - 210k, SO - 110 (without pumps) Fill every joint and circulate down every 10 jts @ 4 bpm, 660 psi. 'No mud losses. HES Float Shoe -Set C~ 6,715.8 ft. 2 Jts 7", 26#, L-80 BTC-Mod (#1-2) HES Float collar - Top ~ 6,630 ft. 14 Jts 7", 26#, L-80 BTC-Mod (#3-16) 7", 26#, L-80 BTC-Mod Marker Pup w/ RA in collar -Top ~ 6,041 ft. 27 Jts 7", 26#, L-80 BTC-Mod (#17-43) 7" 26# L-80 TC-II X BTC-M crossover joint - Top ~ 4,907 ft. 122 Jts 7", 26#, L-80 TC-II (#1 - 122) 7" 26# L-80 TC-II Hanger P x P Pup Jt. FMC Hanger -Top C~ 26.2 ft. PUW = 220k, SOW = 110k 7 1/8" x 8 1/4" Rigid Straight Blade Centralizers Jt. # 1 2 cent. locked down next to shoe. BTC-M Jts. #2 thru # 16 2 ea. Floating with stop ring in the middle BTC-M 20' Marker joint 1 ea. with no stop ring. BTC-M Jts. #17 thru # 43 2 ea. Floating with stop ring in the middle Cross over joint 2 ea. Floating with stop ring in the middle TC-II Jts #1 - #12 2 ea. Floating with stop ring in the middle 111 ea Total Centralizers, 55 ea Total stop rings 07:00 - 07:45 0.75 CASE P RUNPRD Rig down Franks tool. Blowdown topdrive. Make up Dowell 2 rnntea: anvzuuts iz:az:uzrm ~ ~ BP EXPLORATION Page 8 of 12 Operations. Summary Report Legal Well Name: V-223 Common Well Name: V-223 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date From - To ~ Hours Task Code NPT Start: 3/11 /2008 Rig Release: 3/26/2008 Rig Number: Spud Date: 3/13/2008 End: 3/26/2008 3/21/2008 07:00 - 07:45 0.75 CASE P 07:45 - 10:00 2.25 CEMT P 10:00 - 12:15 ~ 2.25 ~ CEMT P 12:15 - 13:00 0.75 CEMT P 13:00 - 15:00 2.00 CEMT P 15:00 - 16:00 1.00 CEMT P 16:00 - 17:00 ~ 1.00 ~ CEMT P 17:00 - 19:00 2.00 CEMT P 19:00 - 21:00 2.00 CEMT P 21:00 - 23:00 2.00 CEMT P 23:00 - 00:00 1.00 PERFO P 3/22/2008 00:00 - 01:30 1.50 PERFO P 01:30 - 03:30 2.00 PERFO P 03:30 - 05:00 1.50 PERFOB, P 05:00 - 05:30 0.50 PERFO P Phase Description of Operations RUNPRD plug head. Rig up circulating lines. RUNPRD Stage up pump from 1 bpm, 305 psi to 5 bpm, 550 psi ICP, 510 psi FCP. Initial PU - 197k, SO - 104k. Final PU - 202k, SO - 102k. Reci rocate casin in 10 ft strokes. Held cementing PJSM during circulation. RUNPRD Switch to Dowell. Pump 5 bbls of fresh water. Test lines to 4,100 psi - OK. Pump 46 bbls of 10 ppg MudPush II spacer. Drop bottom plug. Pump 89.5 bbls of batched mixed 15.8 ppg Class "G" Tail cement C~ 4.5 bpm, 660 psi ICP, 320 psi FCP. Shut in head and flush cement lines to Tee. Drop Top Plug. Displace cement with 254 bbls of 9.0 ppg brine. 1st 200 bbls C~3 5 bpm, 190 psi ICP, 1,135 psi FCP. Next 30 bbls @ 2 bpm, 1,100 psi ICP, 1,220 psi FCP. Last 24 bbls ~ 1 bpm, 1,030 psi ICP, 1,380 psi FCP. Bump plug on schedule (95.3% effc.) with 4,000 psi. CIP C~ 12:15 hr. Bleed off pressure, check floats - OK. *Reciprocated casing in 10 ft strokes. *Landed casing with 227 bbls of displacement away. PU - 157k, SO - 69k. *No mud losses. RUNPRD Pressure test 7" casing to 4,000 psi -Good test. RUNPRD Rig down cementing and casing equipment. RUNPRD Set 9 5/8" x 7" pack-off. Test same to 5,000 psi - 30 minutes - OK. RUNPRD Perform Post cement OA LOT and injectivety test. 3,424' MD, 2,821' TVD MW - 9.2 ppg, LOP - 500 psi EMW - 12.6 ppg. Inject 3 bbls of 9.2 ppg mud @ 500 psi ICP, 800 psi FCP. RUNPRD Chan a to rams from 7" to 3.5" x 6" VBR's. RUNPRD Pressure test to bottom rams and annular r v nter with 3.5" test joint. Test top rams with 4" test joint. Ram tests - 250 psi low, 4,000 psi high. Annular preventer - 250 psi low, 3,500 psi high. *Sim Ops: Injected 120 bbls of 9.2 ppg mud down OA ~ 3 bpm, 850 psi ICP, 500 psi FCP. RUNPRD Rig down test equipment. Install wear bushing. OTHCMP Pick up DPC perforation running tools to rig floor. OTHCMP Rig up to run DPC pert guns. *Sim Ops: Freeze protect OA with 80 bbls of 100* dead crude to 2,500' TVD. 1 bpm, 750 psi ICP, 1000 psi FCP. OTHCMP PJSM. Pick up and make 352' of 4.5" 5SPF PJ DPC pert assembly. Make up bumper sub and MWD. OTHCMP Run in hole with pert assembly from 394' to 1,600'. OTHCMP Attempt MWD shallow hole test multiple times without success. rnmea: nnuzuua irsz:uzrm ~ ~ BP EXPLORATION Page 9 of 12 Operations Summary Report Legal Well Name: V-223 Common Well Name: V-223 Spud Date: 3/13/2008 Event Name: DRILL+COMPLETE Start: 3/11/2008 End: 3/26/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/26/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task ~ Code ~ NPT ~ Phase ~ Description of Operations 3/22/2008 05:00 - 05:30 0.50 PERFO P OTHCMP 180 gpm, 150 psi. 05:30 - 06:00 0.50 PERFO P OTHCMP Run in hole with pert assembly from 1,600' to 2,180. Stop for MWD shallow hole test. 06:00 - 06:30 0.50 PERFO P OTHCMP Shallow hole tedt MWD - OK. 275 gpm, 525 psi. 06:30 - 08:30 2.00 PERFO P OTHCMP Continue running in hole with DPC pert assembly from 2,180' to 6,643'. Tagged Float Collar 13 ft deep. 08:30 - 11:00 2.50 PERFO P OTHCMP Log from 6,643' to 6,410' (Bull nose depths) 6,272' to 6,039' (MWD depths) Correlate GR to MWD logs. 4.5 ft correction. 280 gpm, 920 psi. PU - 135k, SO - 85k. Place guns on depth for top shot @ 6.080' and bottom shot ~ 6 410' 11:00 - 11:30 0.50 PERFO P OTHCMP Initiate gun firing sequence. Fire guns with strong indication of shots fired. 9.0 ppg brine in and out. 11:30 - 12:00 0.50 PERFO P OTHCMP POH from 6,410' to 6,062'. PU - 135k, SO - 80k. `Lost 5 bbls of brine from guns firing to noon. 12:00 - 13:00 1.00 PERFO P OTHCMP Circulate bottoms up ~ 340 gpm, 980 psi. 9.0 ppg brine in and out. 13:00 - 15:30 2.50 PERFO P OTHCMP Monitor well -static. POH laying down drill pipe from 6,062' to 4,060'. 15:30 - 17:00 1.50 PERFO P OTHCMP Monitor well -static. Slip and cut drilling line 98 ft. Inspect brakes. 17:00 - 21:00 4.00 PERFO P OTHCMP Continue POH, laying down drill pipe from 4,060' to 500'. 21:00 - 00:00 3.00 PERFO P OTHCMP PJSM. Finish laying down drill pipe from 500' to 394'. Laydown MWD and bumper sub. Laydown pert gun assembly from 352' to 189'. 'Lost 8 bbls of brine from noon to midnight. 'Lost total of 13 bbls total for the day. 3/23/2008 00:00 - 01:00 1.00 PERFO P OTHCMP Continue laying down pert guns from 189' to surface. All guns 01:00 - 01:30 0.50 PERFO P OTHCMP Clear rig floor of pert gun running tools. 01:30 - 02:30 1.00 PERFO P OTHCMP Run in hole with excess drill pipe and POH, laying down 18 joints of drill pipe. 02:30 - 03:00 0.50 PERFO P OTHCMP Clear floor of unnecessary tools. 03:00 - 04:30 1.50 EVAL P OTHCMP Rig up SLB E-line equipment for junk basket and USIT logging runs. 04:30 - 07:30 3.00 EVAL P OTHCMP E-line Run #1: Run in hole with 5.91" gauge ring and junk basket with CCL to 6,530'. POH and clean out junk basket. Very little debris. 07:30 - 11:30 4.00 EVAL P OTHCMP Change out gauge ring to 6.125". E-line Run #2: Run in hole with 6.125" gauge ring and junk basket with CCL to 6,548'. POH and clean out junk basket. Very little debris. 'Debris able to be picked up with magnet. 11:30 - 12:00 0.50 EVAL P OTHCMP Change out wireline head for USIT log. 12:00 - 14:00 2.00 EVAL N WAIT OTHCMP Lost continuity from tool to E-line unit. Wait on other E-line unit to replace the one on location. *SLB deducted 2 hrs off of ticket. 14:00 - 15:00 1.00 EVAL P OTHCMP Rig up and make up USIT logging tools. Run surface test - OK. Pri nt2tl: 4/11/"LUUt3 11::1"L:UL PM BP'EXPLORATION Page 10 of 12 ~ Operations-Summary Report Legal Well Name: V-223 Common Well Name: V-223 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date From - To ~ Hours j .Task Code NPT 3/23/2008 15:00 - 20:00 5.00 EVAL P 20:00 - 21:00 1.00 EVAL P 21:00 - 23:00 2.00 BUNCO 23:00 - 00:00 1.00 RU 3/24/2008 00:00 - 01:30 1.50 RU 01:30 - 10:00 8.50 RU 10:00 - 00:00 I 14.001 RU 3/25/2008 100:00 - 02:00 2.001 RU 02:00 - 04:30 2.50 RU 04:30 - 07:00 2.50 RU 07:00 - 07:30 0.50 RUN 07:30 - 09:00 1.50 RUN P Spud Date: 3/13/2008 Start: 3/11/2008 End: 3/26/2008 I Rig Release: 3/26/2008 Rig Number: i Phase Description of Operations OTHCMP Run in hole with USIT logging tools to 6,525'. Log from 6,525' to su ace in nmary ept ontro mo e. Strong cement stringers from 4,400' to 9 5/8" shoe ~ 3,425'. Partial cement stringer from 3,425' to 3,050'. OTHCMP Laydown USIT logging tools. Rig down SLB E-line. RUNCMP Pull wear bushing. Make up hanger to landing joint and make dummy hanger run. Laydown hanger and landing joint. RUNCMP Rig up to run 3.5" I-wire completion. RUNCMP Continue rigging up to run I-wire completion. RUNCMP PJSM. Make up and run in hole with 3.5" 9.2# L-80 TCII, 4 packer, 8 GLMs, completion jewelry to 479'. Make I-wire connections and test pressure gauges as needed. 2,300 ft/Ibs of make up torque, using Torque Turn equipment. Used Jet Lube Seal Guard pipe dope. All connections below 1st packer were Baker-Lok'd. RUNCMP Continue running in hole with 3.5" 9.2# L-80 TCII tubing from 479' to 5,638'. Test I-wire continuity every 1,000' - OK. 'Lost 2 bbls of 9.0 ppg brine from midnight to midnight. RUNCMP Continue running in hole with 3.5" 9.2# L-80 TCII tubing from 5,638' to planned setting depth C~ 6,467'. PU - 90k, SO - 63k (with 33k blocks) RUNCMP Rig up to log in completion. PJSM. Rig up SLB E-line. RUNCMP Run in hole with GR/CCL logging tools and log in packers correlating to LWD real-time logs. On depth - No correction. POH with logging tools. RUNCMP Rig down SLB E-line. RUNCMP Laydown 1 joint. Make up tubing hanger and landing joint. Terminate and test I-wire connection. Land tubing C~ 6,467'. Drop 1 5/16" rod and ball. Laydown landing joint. W LEG set C~? 6,467' Tops: 'XN' Nipple - 6,445' 'X' Nipple:w/ RHC-M Plug - 6,424' GLM #1 - 6,395' 'X' Nipple - 6,374' NDPG Single Sub - 6,339' -+~ HES Single feed thru Packer #1 - 6,325' GLM #2 - 6,286' GLM #3 - 6,238' 'X' Nipple - 6,227' NDPG Single Sub - 6,221' HES Single feed thru Packer #2 - 6,208' GLM #4 - 6,189' Pup w/ RA Tag on Centralizer ~ 6,170' GLM #5 - 6,160' NDPG Single Sub - 6,152' -~. HES Single feed thru Packer #3 - 6,139' 'X' Nipple - 6,128' GLM #6 - 6,108' GLM #7 - 6,080' NDPG Single Sub - 6,055' -~- HES Single feed thru Packer #4 - 6,041' Printed: 4/112008 lY:9Z:U2 rnn • ~ BP EXPLORATION Page 11 of 12 ~, Operations Summary Report Legal Well Name: V-223 Common Well Name: V-223 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date 'From.- To Hours Task 'Code. NPT Spud Date: 3/13/2008 Start: 3/11/2008 End: 3/26/2008 Rig Release: 3/26/2008 Rig Number: Phase ~ Description of Operations 3/25/2008 07:30 - 09:00 1.50 BUNCO RUNCMP 'X' Nipple - 6,010' GLM #8 w/ DCK Shear Valve - 5,993' 98 jts 3.5" 9.2# L-80 TC-II Tubing (#1 - #98 ) 'X' Nipple -2,858' 88 jts 3.5" 9.2# L-80 TC-II Tubing (#99 - #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-II Lifting Threads Up wt = 90k, Dn wt = 63k 100 full Cannon clamps, 20 Half clamps 09:00 - 11:30 2.50 BUNCO RUNCMP Rig up to set packers. Pressure u on tubin to 4,000 si and hold for 30 minute test - OK. Bleed tubing pressure to 2,500 psi. Pressure up on IA to 4,000 psi and hold for 30 minute test - OK. Bleed IA pressure to 0 psi. Bleed tubing pressure to 0 psi. Pressure up on IA and shear out DCK valve ~ 2,375 psi. Circulate briefly through valve both ways - OK. *Witnessin of test waived b AOGCC Tom Maunder. 11:30 - 12:00 0.50 BUNCO RUNCMP Drain BOP stack and blowdown lines. 12:00 - 13:00 1.00 WHSUR P RUNCMP Set 2-way check valve with T-bar. Test from below to 1,000 psi -10 min-OK. 13:00 - 15:30 2.50 BOPSU P RUNCMP Laydown mouse hole. Remove BOP turn buckles. Pull drilling nipple. Change out 16" drilling nipple adaptor to 20". 15:30 - 17:30 2.00 BOPSU P RUNCMP Nipple down BOPE. 17:30 - 21:00 3.50 WHSUR P RUNCMP Prep tubing spool and hanger neck. Nipple up tree adaptor. Terminate and test I-wire and connections. Test adaptor to 5,000 psi - 30 minutes - OK. 21:00 - 22:30 1.50 WHSUR P RUNCMP Nipple up 2 valve dry hole tree. Fill and pressure test with diesel for 15 minutes - OK. 22:30 - 00:00 1.50 WHSUR N WAIT RUNCMP Wait on Drill Site Maintenance. Called DSM ~ 20:00 hr for 2 hour callout. Only one crew and lubricator available and were being held up on Doyon 14. Work on miscellaneous tasks to prepare for rig move. 3/26/2008 00:00 - 04:30 4.50 WHSUR N WAIT RUNCMP Continue waiting on Drill Site Maintenance. Continue preparing for rig move. *DSM on location C~? 04:30 hr. 04:30 - 06:00 1.50 WHSUR P RUNCMP Rig up DSM lubricator. Test to 500 psi - OK. Pull 2-way check valve. 06:00 - 06:30 0.50 WHSUR P RUNCMP Rig up to reverse circulate. 06:30 - 08:00 1.50 WHSUR P RUNCMP Reverse circulate with 150 bbls of clean 9.0 ppg brine, followed by 60 bbls of corrosion inhibited 9.0 ppg brine, followed by 30 bbls of clean 9.0 ppg brine. 3 bpm, 390 psi. 08:00 - 08:30 0.50 WHSUR P RUNCMP Rig up LRHOS. Test lines to 3,000 psi. 08:30 - 10:30 2.00 WHSUR P RUNCMP Freeze protect IA and tubing to 2,850' MD, 2,500' TVD. Reverse 101 bbls of 60* diesel ~ 4 bpm, 450 psi ICP, 750 psi FCP. U-tube diesel back to tubing. 10:30 - 12:00 1.50 WHSUR P RUNCMP Rig up DSM lubricator. Install BPV. Test BPV to 1,000 psi from below for 10 minutes - OK. 12:00 - 14:00 2.00 WHSUR P RUNCMP Install OA and IA VR plugs. Secure tree. 14:00 - 16:00 2.00 WHSUR P RUNCMP Finish cleaning mud pits and remove remaining fluids. F'flflt8tl: 4/11/LUUi3 1 L::SG:UC YM ~ ~ BP EXPLORATION Page 12 of 12 Operations Summary Report Legal Well Name: V-223 Common Well Name: V-223 Spud Date: 3/13/2008 Event Name: DRILL+COMPLETE Start: 3/11/2008 End: 3/26/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/26/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code NPT Phase ~', Description of Operations 3/26/2008 ~ 14:00 - 16:00 ~ 2.00 ~ WHSUR ~ P ~ ~ RUNCMP 'Release rig from V-2231 operations at 16:00 hr, 3/26/2008 rrintea: unvzuuu iz~z:uzrnn Digital Well File Well: V-223 Well History ~ ~ Well Date Summary V-223 3/26/2008 T=O; pulled 4-1/16" CIW "H" TWC thru dry-hole tree; no ext. used, tagged @ 90"; ***Complete*** (Best/Wortham) V-223 3/27/2008 Set 4 1/16" CIW BPV#250 for rig completion. Also set VR plugs in I/A's. T/I/O/= 0/0/0 V-223 3/28/2008 (TREE CHANGE-OUT) ***JOB COMPLETE*** Initiated permit and had face to face with the pad operator. Signed on mastercard and placed lock on the lock box. Removed upper master valve on dry hole tree and installed a 4 1/16" Cameron model FLS tree with a Halliburton Leo actuator. Pressure tested tree to 5000 psi. for 10 minutes. PASSED. Notified operator tree was installed and tested. Signed off on mastercard, permit, and removed lock from the lock box before leaving location. NOTE: BPV STILL IN HOLE V-223 4/5/2008 T/I/O 0/0/0 Pull 4" ciw bpv thru tree post rig work. Pull 2 each 2" fmc yr plugs out of the i/a's post rig work. Print Date: 4/19/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx Page 1 of 1 4/19/2008 BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: V-223 Common Name: V-223 - ---- Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW - _ _ - - - 3/18/2008 LOT 3,424.0 (ft) 2,821.4 (ft) 8.80 (ppg) 500 (psi) 1,790 (psi) 12.21 (ppg) Printed: M11/2008 12:31:57 Piu by V-223 Survev Report Schlumhergen Report Date: March 19, 2008 Survey /DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 113.170° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure /Slot: V-Pad / Plan V Slot (S-M) 7VD Reference Datum: Rotary Table Well: V-223 TVD Reference Elevation: 81.40 ft relative to MSL Borehole: V-223 Sea Bed /Ground Level Elevation: 52.90 ft relative to MSL UWIIAPI#: 500292338400 Magnetic Declination: 23.062° Survey Name /Date: V-223 /March 14, 2008 Total Field Strength: 57645.950 nT Tort /AHD / DDI / ERD ratio: 103.383° / 3985.53 ft / 5.744 / 0.797 Magnetic Dip: 80.873° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Declination Date: Mardi 12, 2008 Location LaULong: N 70 19 39.290, W 149 15 53.697 Magnetic Declination Model: BGGM 2007 Location Grid NiE Y/X: N 5969929.570 ftUS, E 590640.020 ftUS North Reference: True North Grid Convergence Angle: +0.69218358° Total Corr Mag North -> True North: +23.062° Grid Scale Factor: 0.99990933 Lowl Coordinates Referenced To: Well Head u Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ri ft ft ft tt de 00 ri riUS ftUS HIE U.UU U.UU U.UU -tS1.4U U.UU U.UU U.UU U.UU U.UU U.UU U.UU by6yy'1y.b/ byU64U.UL N /U 1 y 3y.2yU W 14y lb b3.6y/ GYD CT DMS 100.00 0.32 165.48 18.60 100.00 0.17 0.28 0.28 -0.27 0.07 0.32 5969929.30 590640.09 N 70 19 39.287 W 149 15 53.695 200.00 0.44 145.76 118.60 200.00 0.66 0.94 0.93 -0.86 0.36 0.18 5969928.72 590640.39 N 70 19 39.281 W 149 15 53.687 300.00 0.70 151.24 218.59 299.99 1.47 1.93 1.92 -1.71 0.87 0.27 5969927.87 590640.91 N 70 19 39.273 W 149 15 53.672 400.00 0.89 150.02 318.58 399.98 2.57 3.32 3.30 -2.92 1.55 0.19 5969926.67 590641.60 N 70 19 39.261 W 149 15 53.652 500.00 1.33 166.53 418.56 499.96 3.89 5.24 5.21 -4.72 2.21 0.54 5969924.88 590642.28 N 70 19 39.243 W 149 15 53.633 600.00 3.18 156.62 518.48 599.88 6.59 9.17 9.13 -8.40 3.58 1.88 5969921.22 590643.70 N 70 19 39.207 W 149 15 53.593 700.00 5.49 139.75 618.19 699.59 12.88 16.68 16.53 -14.59 7.77 2.61 5969915.07 590647.96 N 70 19 39.146 W 149 15 53.470 800.00 7.26 135.16 717.57 798.97 23.02 27.77 27.41 -22.73 15.32 1.84 5969907.03 590655.61 N 70 19 39:066 W 149 15 53.250 900.00 8.81 129.90 816.59 897.99 36.22 41.74 41.10 -32.12 25.65 1.71 5969897.77 590666.05 N 70 19 38.974 W 149 15 52.948 1000.00 9.92 128.29 915.25 996.65 51.87 58.01 57.10 -42.37 38.28 1.14 5969887.67 590678.81 N 70 19 38.873 W 149 15 52 1100.00 13.52 125.49 1013.15 1094.55 71.61 78.32 77.12 -54.50 54.57 3.64 5969875.74 590695.24 ~ N 70 19 38.754 W 149 15 52. 1195.00 16.55 125.88 1104.89 1186.29 95.66 102.96 101.52 -68.88 74.58 3.19 5969861.61 590715.42 N 70 19 38.613 W 149 15 51.520 MWD+IFR+MS 1228.62 17.63 125.52 1137.03 1218.43 105.31 112.84 111.33 -74.64 82.60 3.23 5969855.94 590723.51 N 70 19 38.556 W 149 15 51.286 1323.20 19.80 128.94 1226.60 1308.00 134.72 143.18 141.58 -93.03 106.72 2.57 5969837.84 590747.85 N 70 19 38.375 W 149 15 50.582 1418.80 21.63 131.18 1316.02 1397.42 167.06 176.99 175.38 -114.81 132.58 2.09 5969816.38 590773.96 N 70 19 38.161 W 149 15 49.827 1514.48 24.46 128.01 1404.06 1485.46 202.99 214.43 212.81 -138.63 161.47 3.23 5969792.92 590803.13 N 70 19 37.927 W 149 15 48.984 1609.79 28.12 129.78 1489.50 1570.90 243.60 256.63 255.00 -165.16 194.29 3.93 5969766.78 590836.27 N 70 19 37.666 W 149 15 48.026 1704.86 28.89 129.15 1573.04 1654.44 287.15 302.00 300.36 -193.99 229.31 0.87 5969738.38 590871.64 N 70 19 37.382 W 149 15 47.003 1800.46 32.91 127.98 1655.06 1736.46 334.48 351.09 349.43 -224.57 267.71 4.25 5969708.27 590910.40 N 70 19 37.081 W 149 15 45.882 1895.67 33.83 127.88 1734.57 1815.97 385.12 403.45 401.77 -256.76 309.02 0.97 5969676.58 590952.09 N 70 19 36.765 W 149 15 44.677 1991.57 36.52 124.29 1812.96 1894.36 438.95 458.68 456.89 -289.24 353.68 3.54 5969644.65 590997.13 N 70 19 36.445 W 149 15 43.373 2086.84 39.15 121.13 1888.20 1969.60 496.57 517.11 514.96 -320.76 402.85 3.43 5969613.72 591046.68 N 70 19 36.135 W 149 15 41.937 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V Slot (S-M)\V-223\V-223\V-223 Generated 4/19/2008 1:41 PM Page 1 of 3 Comments Measured Inclination Azimuth Subsea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100ft ftUS ftUS L IOG.31 4V.6/ IIO. OC 101.33 LU4L./3 7J/.JI J/i3 .48 J/J ./I -3J 1.41 4Jb.UL L..S2Y JybybtS:S ./.S Jyl1UU.Ll IV /U ly :ib .tS:i4 W14y 154U.:it55 2277. 70 42.15 117. 35 2032. 76 2114. 16 620.49 641 .70 638 .14 -381. 16 511.80 1.69 5969554 .66 591156. 34 N 70 19 35 .541 W 149 15 38. 757 2373. 26 43.44 117. 25 2102. 88 2184. 28 685.24 706 .62 702 .27 -410. 93 569.49 1.35 5969525 .58 591214. 38 N 70 19 35 .248 W 149 15 37. 073 2469. 19 45.62 115. 85 2171. 26 2252. 66 752.39 773 .88 768 .73 -440. 99 629.67 2.49 5969496 .26 591274. 91 N 70 19 34 .953 W 149 15 35. 317 2564. 16 48.24 112. 75 2236. 12 2317. 52 821.73 843 .25 836 .97 -469. 49 692.90 3.65 5969468 .53 591338. 47 N 70 19 34 .672 W 149 15 33. 471 2659. 59 50.82 110. 71 2298. 06 2379. 46 894.30 915 .84 908 .00 -496. 34 760.33 3.15 5969442 .50 591406. 22 N 70 19 34 .408 W 149 15 31. 503 2755. 07 53.52 111. 95 2356. 61 2438. 01 969.66 991 .24 981 .93 -523. 78 830.57 3.01 5969415 .91 591476. 78 N 70 19 34 .138 W 149 15 29. 453 2850. 31 54.73 111. 28 2412. 42 2493. 82 1046.80 1068 .41 1057 .87 -552. 20 902.31 1.39 5969388 .36 591548. 85 N 70 19 33 .859 W 149 15 27. 359 2944. 47 55.30 111. 57 2466. 41 2547. 81 1123.91 1145 .56 1133 .92 -580. 38 974.13 0.66 5969361 .05 591620. 99 N 70 19 33 .581 W 149 15 25. 262 3039. 70 55.82 109. 76 2520. 27 2601. 67 1202.37 1224 .09 1211 .30 -608. 10 1047.61 1.66 5969334 .23 591694. 80 N 70 19 33 .309 W 149 15 23. 118 3135. 86 56.01 109. 30 2574. 16 2655. 56 1281.85 1303 .73 1289 .67 -634. 72 1122.66 0.44 5969308 .52 591770. 17 N 70 19 33 .047 W 149 15 20. 3230. 61 55.25 109. 04 2627. 65 2709. 05 1359.87 1381. 94 1366 .68 -660. 40 1196.53 0.83 5969283 .73 591844. 33 N 70 19 32 .794 W 149 15 18 ~ 3323. 91 54.70 109. 26 2681. 20 2762. 60 1436.08 1458 .34 1442 .04 -685. 46 1268.71 0.62 5969259 .55 591916. 80 N 70 19 32 .547 W 149 15 16. 664 3373. 69 53.83 108. 82 2710. 27 2791. 67 1476.38 1498 .75 1481 .93 -698. 65 1306.91 1.89 5969246 .83 591955. 15 N 70 19 32 .418 W 149 15 15. 549 3486. 94 52.66 110. 54 2778. 04 2859. 44 1566.94 1589 .48 1571 .73 -729. 19 1392.34 1.60 5969217 .32 592040. 94 N 70 19 32 .117 W 149 15 13. 056 3581. 27 53.37 110. 11 2834. 79 2916. 19 1642.20 1664 .83 1646 .49 -755. 36 1463.00 0.84 5969192 .01 592111. 90 N 70 19 31 .860 W 149 15 10. 993 3677. 04 54.84 109. 11 2890. 94 2972. 34 1719.63 1742 .41 1723 .40 -781. 39 1536.08 1.75 5969166 .86 592185. 28 N 70 19 31 .603 W 149 15 8. 860 3770. 96 54.50 107. 39 2945. 26 3026. 66 1795.96 1819 .03 1799 .17 -805. 39 1608.84 1.54 5969143 .75 592258. 32 N 70 19 31 .367 W 149 15 6. 737 3865. 61 55.85 106. 20 2999. 31 3080. 71 1873.18 1896 .73 1875 .78 -827. 83 1683.22 1.76 5969122 .21 592332. 96 N 70 19 31 .146 W 149 15 4. 566 3959. 83 55.10 107. 39 3052. 71 3134. 11 1950.32 1974 .35 1952 .40 -850. 26 1757.54 1.31 5969100 .68 592407. 54 N 70 19 30 .926 W 149 15 2. 397 4056. 11 55.94 107. 18 3107. 22 3188. 62 2029.27 2053 .72 2030 .92 -873. 84 1833.32 0.89 5969078 .02 592483. 59 N 70 19 30 .694 W 149 15 0. 185 4151. 60 56.01 106. 63 3160. 65 3242. 05 2107.93 2132 .86 2109 .21 -896. 85 1909.04 0.48 5969055 .93 592559. 58 N 70 19 30. 467 W 149 14 57. 975 4246. 80 55.10 107. 46 3214. 49 3295. 89 2185.99 2211 .37 2186 .96 -919. 86 1984.10 1.20 5969033 .83 592634. 90 N 70 19 30 .241 W 149 14 55. 784 4341. 59 54.68 108. 99 3269. 02 3350. 42 2263.24 2288 .91 2263 .99 -944. 11 2057.75 1.39 5969010 .47 592708. 83 N 70 19 30 .002 W 149 14 53. 635 4436. 73 55.25 109. 14 3323. 63 3405. 03 2340.94 2366 .81 2341 .54 -969. 55 2131.38 0.61 5968985 .92 592782. 75 N 70 19 29 .751 W 149 14 51. 486 4532. 36 54.73 109. 18 3378. 50 3459. 90 2419.08 2445 .13 2419 .54 -995. 26 2205.36 0.54 5968961 .11 592857. 04 N 70 19 29 .498 W 149 14 49. 326 4627. 29 55.95 110. 26 3432. 48 3513. 88 2497.02 2523 .22 2497 .38 -1021. 61 2278.86 1.59 5968935 .65 592930. 84 N 70 19 29 .239 W 149 14 47. 181 4722. 80 55.24 110. 28 3486. 45 3567. 85 2575.72 2602 .02 2576 .01 -1048. 91 2352.78 0.74 5968909 .25 593005. 08 N 70 19 28 .970 W 149 14 45. 4818. 34 54.90 110. 38 3541. 15 3622. 55 2653.95 2680 .35 2654 .18 -1076. 13 2426.23 0.37 5968882 .93 593078. 85 N 70 19 28 .702 W 149 14 42 ~ 4914. 36 54.23 110. 90 3596. 83 3678 .23 2732.11 2758 .58 2732 .29 -1103. 70 2499.45 0.83 5968856 .24 593152. 38 N 70 19 28 .431 W 149 14 40. 5009. 45 54.12 110. 73 3652. 48 3733 .88 2809.14 2835 .68 2809 .28 -1131. 10 2571.51 0.19 5968829 .72 593224. 77 N 70 19 28 .161 W 149 14 38. 640 5105. 19 51.71 110. 50 3710. 21 3791 .61 2885.44 2912 .05 2885 .54 -1157. 99 2642.99 2.52 5968803 .70 593296. 56 N 70 19 27 .897 W 149 14 36. 554 5200. 41 49.50 111. 79 3770. 64 3852 .04 2958.97 2985 .63 2959 .05 -1184. 52 2711.62 2.55 5968778 .00 593365. 50 N 70 19 27 .635 W 149 14 34. 552 5295. 51 46.71 112. 37 3834. 14 3915 .54 3029.74 3056 .41 3029 .81 -1211. 12 2777.21 2.97 5968752 .20 593431. 40 N 70 19 27 .374 W 149 14 32. 637 5391. 06 43.87 112. 76 3901. 35 3982 .75 3097.63 3124 .31 3097 .69 -1237. 17 2839.92 2.99 5968726 .91 593494. 41 N 70 19 27 .117 W 149 14 30. 808 5486. 75 41.88 114. 02 3971. 48 4052 .88 3162.73 3189 .41 3162 .80 -1263. 00 2899.67 2.26 5968701 .80 593554. 47 N 70 19 26 .863 W 149 14 29. 064 5581. 69 41.71 115. 03 4042. 26 4123 .66 3225.99 3252 .69 3226 .06 -1289. 26 2957.24 0.73 5968676 .24 593612. 34 N 70 19 26 .604 W 149 14 27. 384 5677. 00 41.92 113. 05 4113. 30 4194 .70 3289.52 3316 .23 3289 .60 -1315. 15 3015.27 1.40 5968651 .06 593670. 67 N 70 19 26 .350 W 149 14 25. 690 5771. 93 41.78 112. 86 4184. 01 4265 .41 3352.85 3379 .56 3352 .93 -1339. 85 3073.59 0.20 5968627 .07 593729. 28 N 70 19 26 .106 W 149 14 23. 989 5867. 70 41.59 113. 39 4255. 53 4336 .93 3416.54 3443 .25 3416 .62 -1364. 86 3132.16 0.42 5968602 .77 593788. 15 N 70 19 25 .860 W 149 14 22. 279 5962. 90 40.97 113. 01 4327. 07 4408 .47 3479.35 3506 .06 3479 .42 -1389. 60 3189.89 0.70 5968578 .73 593846. 16 N 70 19 25 .617 W 149 14 20. 595 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V Slot (S-M)\V-223\V-223\V-223 Generated 4/19/2008 1:41 PM Page 2 of 3 Measured Vertical Along Hole Comments Inclination Azimuth Sub-Sea TVD TVp Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de t00ft ftUS ftUS (iUb/.b/ 4U.G'L 11'L .yU 4;SyiS.yb 4425U.3b ;ib4U.yb :i5b/.lib Jb41.U'L -141J .b:i :iL4b.b1 U.tiU 5yEi25555. :iy 6150.62 39.80 112 .99 4470.23 4551.63 3600.77 3627.49 3600.84 -1436 .95 3301.70 0.46 5968532. 74 6246.24 39.39 112 .76 4543.91 4625.31 3661.72 3688.43 3661.78 -1460 .64 3357.85 0.46 5968509. 73 6341.54 39.22 111 .75 4617.65 4699.05 3722.08 3748.80 3722.13 -1483 .51 3413.72 0.69 5968487. 55 6437.18 38.91 111 .41 4691.91 4773.31 3782.32 3809.07 3782.37 -1505 .67 3469.77 0.39 5968466. 06 6532.76 38.18 110 .52 4766.66 4848.06 3841.84 3868.63 3841.87 -1526 .99 3525.38 0.96 5968445. 42 6628.94 37.17 110 .91 4842.79 4924.19 3900.57 3927.41 3900.59 -1547 .78 3580.36 1.08 5968425. 30 Last Survey 6656.39 37.24 110 .22 4864.65 4946.05 3917.15 3944.01 3917.17 -1553 .61 3595.90 1.54 5968419. 66 TD (Projected) 6725.00 37.24 110 .22 4919.27 5000.67 3958.61 3985.53 3958.63 -1567 .96 3634.86 0.00 5968405. 78 Survey Type: Definitive Survey NOTES: GYD CT DMS - (Gyrodata -cont. drillpipe m/s -- Gyrodata pump-down multishot surveys with conti nuous tool (RGS-CT) in dril l-pipe.) MWD + IFR + MS - (In-field referenced MWD wi th mutt-station analysis and correction appl ied in po st-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Descri ption: Northing (Y) fftUSl Easting (X) fftUSl Surface : 4681 FSL 1663 FEL S11 T11 N R11 E UM 5969929.57 590640.02 BHL : 3112 FSL 3309 FEL S12 T11 N R11 E UM 5968405.78 594293.22 Sy~yU;i.1 / N /U 1 yLb.:itSU W 14y 14 1 tS.y;iy 593958.53 N 70 19 25.151 W 149 14 17.332 594014.96 N 70 19 24.917 W 149 14 15.693 594071.09 N 70 19 24.692 W 149 14 14.063 594127.40 N 70 19 24.474 W 149 14 12.428 594183.26 N 70 19 24.264 W 149 14 10.805 594238.49 N 70 19 24.059 W 149 14 9.200 594254.09 N 70 19 24.002 W 149 14 8.747 594293.22 N 70 19 23.861 W 149 14 7.610 s SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V Slot (S-M)\V-223\V-223\V-223 Generated 4/19/2008 1:41 PM Page 3 of 3 Page 1 of 1 Maunder, Thomas E (DOA) From: Stewman, Sondra D [Sondra.Stewman@bp.com] Sent: Thursday, May 08, 2008 3:48 PM To: Maunder, Thomas E (DOA) Subject: RE: V-223 (208-022) Attachments: V-223, 10-407.pdf Tom, As we discussed pertaining to items 1 & 2, I have made following corrections to the attached 10-407: Item 1 - V-223 Orion Pool not Polaris Pool and therefore a WAG Item 2 - I have verified the yield on both of the Class G cement volumes is 1.16 (445 sx) Please advise of any questions or concerns. Sondra Stewman ADW Drilling Technologist Be real, be present and most of ail be I'O.SITIVF,! From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, May 08, 2008 2:29 PM To: Kolstad, Scott R; Stewman, Sondra D Cc: Regg, James B (DOA) Subject: V-223 (208-022) Scott and Sondra, I am reviewing the 407 recently submitted for this well and have a few items ... 1. The well was permitted as a service well, however AIO 25A only allows WAG wells on separate approval. As such, it is not possible to directly designate the well as WAG. WINJ is the correct designation. 2. Would you please check the cement volume reported for the surface tail? 168 sx only gives 35 bbls, while the tail volume given in the report (3/16/08) is 78 + 15 = 93 bbls or 445 sx. 3. On 3/20/08 7" rams were installed in the BOP. It is stated that the door seals were tested. Please confirm and provide documentation that the rams were tested with a 7" test joint. With regards to 1 and 2, it may be possible to make hand corrections on the 407. Give me a call with the information. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 5/812008 04/09/08 wu a ~~i~~~m~~~~~~ NO. 4657 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Orion r..w w ~ .... ne~...c..t~.,., Rata RI Cnlnr CD 03-10 12045070 USIT -~ 03/24/08 1 1 1-21/K-25 11998996 USIT 03/25/08 1 1 V-223 12061688 CEMENT EVALUATION LOG /(p 03/23/08 1 1 V-214 11978449 MI INJECTOR U - ~ (p t 0 04/01/08 1 1 18-138 12061689 PRODUCTION PROFILE ~ _~-( '~ 03/27/08 1 1 E-10A 11998994 USIT (~ '} 03/28/08 1 1 02-12B 11628789 MCNL a / ! U '" 08/21/07 1 1 15-456 11963079 MCNL p 02/14/08 1 1 V-220 12031459 CH EDIT PDC GR (USIT)~(5~ /(o .b 03!07/08 1 V-214 40016214 OH MWD /LWD 04/01/08 2 1 -~ 1 PLEASE ACKNOWLEDGE REGEIPI t3Y SIGNING ANU Ittl uFirvmCd vrvt c~rx nHCn i v: BP Exploration (Alaska) Inc. '~ ~~ - Petrotechnical Data Center LR2-1 ~ - ~ ~ "' 900 E. Benson Blvd. Anchorage, Alaska 99508 ,~ r ary .., ~~ ,- d [,~; Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 ATTN: Beth Received b C~ gyro ata Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston. Texas 77043 7131461-3146 Fax: 713/461-0920 March 28, 2008 State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: V-Pad, Well #V-223 Prudhoe Bay, Alaska • Enclosed, please find two (2) copies, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, Rob Shoup North American Regional Manager RS:kI Serving the Wor~clwide F_nergy Industry evith Precision Survey lnstrurY~enlation CJ gyro ata Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston. Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY REPORT BP V-Pad #V-223 Prudhoe Bay, AK AK0308G_114 14 Mar 2008 • Servir~c~ the Woridwide Energy industry ~.n~ith Precision Sur~rc~,r !rl~t~l!s?~e~!tstion 1, n~ ~ ~~ A Gyrodata Directional Survey for B.P. EXPLORATION Lease: V-Pad Well: V-223, 4" Drillpipe Location: Nabors #9-ES, Prudhoe Bay, Alaska Job Number: AK0308G 114 Run Date: 14 Mar 2008 Surveyor: Henry Drew Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.327581 deg. N Longitude: 149.264916 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location CJ Horizontal Coordinates Calculated from Well Head Location A Gyrodata Directional Survey B.P. Exploration Lease: V-Pad Well: V-223, 4" Drillpipe Location: Nabors #9-ES, Prudhoe Bay, Alaska Job Number: AK0308G 114 MEASURED I N C L AZIMUTH BORE HOLE DEPTH BEARING feet deg. deg. deg. min. DOGLEG VERTICAL CLOSURE SEVERITY DEPTH DIST. AZIMUTH deg./ feet feet deg. 100 ft. 0.00 0.00 0.00 N 0 0 E 0.00 0.00 0.0 0.0 ----------------------------------------------------------------------------------------------------------------------------- 0 - 1195 FT. RATE GYROSCOPIC MULTISHOT SURVEY RUN INSIDE 4" DRILLPIPE ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO NABORS #9-ES R.K.B. ----------------------------------------------------------------------------------------------------------------------------- 100.00 0.32 165.48 S 14 31 E 0.32 200.00 0.44 145.76 S 34 14 E 0.18 300.00 0.70 151.24 S 28 45 E 0.26 400.00 0.89 150.02 S 29 59 E 0.20 500.00 1.33 166.53 S 13 28 E 0.54 600.00 3.18 156.62 S 23 23 E 1.89 700.00 5.49 139.75 S 40 15 E 2.61 800.00 7.26 135.40 S 44 36 E 1.84 900.00 8.81 129.90 S 50 6 E 1.73 1000.00 9.92 128.29 S 51 42 E 1.14 1100.00 13.52 125.49 S 54 31 E 3.64 1195.00 16.55 125.88 S S4 7 E 3.19 Final Station Closure: Distance: 101.50 ft Az: 132.75 deg. 100.00 200.00 299.99 399.98 499.96 599.88 699.59 798.97 897.99 996.65 1094.55 1186.29 0.3 165.5 0.9 157.4 1.9 153.1 3.3 152.1 5.2 154.9 9.1 156.9 16.5 152.0 27.4 146.1 41.1 141.5 57.1 137.9 77.1 135.0 101.5 132.8 HORIZONTAL COORDINATES feet 0.00 N 0.00E • -------------------------------- 0.27 S 0.86 S 1.71 S 2.92 S 4.71 S 8.38 S 14.58 S 22.73 S 32.15 S 42.40 S 54.53 S 68.90 S 0.07 E 0.36 E 0.87 E 1.55 E 2.20 E 3.57 E 7.77 E 15.30 E 25.61 E 38.25 E 54.53 E 74.53 E 2 B.P. Exploration Well: V-Pad V-223 4" Drillpipe Location: Nabors #9-ES, Prudhoe Bay, Alaska 0 -1 -20 .-. -30 z x H O -40 z -50 -60 -70 Inrun Gyrodata AK0308G_114 DEFINITIVE - --- -------- --- - ----------- --------------- --------_-- i ----------- ------------ ----- - --------- ---------- ------------------- --------- I -- --- - L M OM HOl CATED D: 1195.00 ~ ~ ~ , ~ ~ 0 1 0 2 0 3 0 4 0 5 0 6 0 ~ 0 n • FASTING (ft) B.P. Exploration Well: V-Pad V-223 4" Drillpipe - Location: Nabors #9-ES, Prudhoe Bay, Alaska 12 11 10 9 ~ 8 0 0 rn 7 a~ -a .. ~ 6 w w C~ 5 w J ~ 4 3 2 1- 0- Inrun Gyrodata _ AK03n£~G 114 r)FFTNTTT\/F ~ ~ I ~ ~ ~ ~ ~ I! ~ - -- --- - ------- -- - ----~ ------- i ---I ---- ------ I ------ -----~ --------- ~ ------------ ~ ---- --- - -----t ~----.._. ---- ----------- ------ ------ , --___- ------- ----- -- ~ ! i BOTTOM LOCATE HOLE - -- - -- - -- ------ ----- --- --- ---- ----------- ------- --- ----- --------~ MA_:~ _ QQ-- - i ~ ~ - ~ 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 MEASURED DEPTH (ft) ~ SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ..................... Orion Well ...................... V-223 API number ...............: 50-029-23384-00 Engineer .................: Minnick/Wilson 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 52.90 ft N/A Top Drive 81.40 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft Azimuth from Vsect Origin to target: 113.17 degrees '~ G ', oG 1 O ~ [(c)2008 IDEAL ID13_OC_05] 19-Mar-2008 16:42:44 Page 1 of 4 Spud date ................: 13-Mar-08 Last survey date.........: 19-Mar-08 Total accepted surveys...: 73 MD of first survey.......: 0.00 ft MD of last survey........: 6725.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2007 Magnetic date ............: 12-Mar-2008 Magnetic field strength..: 57646.32 LAMA Magnetic dec (+E/W-).....: 23.06 degrees Magnetic dip .............: 80.87 degrees ----- MWD survey Reference Reference G ............... Reference H ............... Reference Dip ............: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 meal 57646.50 LAMA 80.87 degrees (+/-) 2.50 meal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections - ----------- Magnetic dec (+E/W-).....: 23.06 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-):...: 23.06 degrees (Total az corr = magnetic dec - grid cony) 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 • t SCHLUMBERGER Survey Report Seq Measured Intl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 0.00 2 100.00 0.32 165.48 100.00 3 200.00 0.44 145.76 100.00 4 300.00 0.70 151.24 100.00 5 400.00 0.89 150.02 100.00 19-Mar-2008 16:42:44 Page 2 of 4 TVD Vertical Displ Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 100.00 0.17 -0.27 0.07 0.28 165.48 0.32 BP_GYD CT DMS 200.00 0.66 -0.86 0.36 0.93 157.46 0.18 BP_GYD CT DMS 299.99 1.47 -1.71 0.87 1.92 153.15 0.27 BP_GYD CT DMS 399.98 2.57 -2.92 1.55 3.30 152.06 0.19 BP GYD CT DMS 6 500.00 1.33 166.53 100.00 499.96 3.89 -4.72 2.21 5.21 154.95 0.54 BP_GYD CT DMS • 7 600.00 3.18 156.62 100.00 599.88 6.59 -8.40 3.58 9.13 156.92 1.88 BP _GYD CT DMS 8 700.00 5.49 139.75 100.00 699.59 12.88 -14.59 7.77 16.53 151.97 2.61 BP _GYD CT DMS 9 800.00 7.26 135.40 100.00 798.97 23.01 -22.74 15.30 27.41 146.08 1.83 BP _GYD CT DMS 10 900.00 8.81 129.90 100.00 897.99 36.20 -32.16 25.61 41.11 141.47 1.73 BP _GYD CT DMS 11 1000.00 9.92 128.29 100.00 996.65 51.85 -42.41 38.25 57.11 137.95 1.14 BP _GYD CT DMS 12 1100.00 13.52 125.49 100.00 1094.55 71.59 -54.53 54.53 77.12 135.00 3.64 BP _GYD CT DMS 13 1195.00 16.55 125.88 95.00 1186.29 95.64 -68.91 74.54 101.51 132.75 3.19 BP _GYD CT DMS 14 1228.62 17.63 125.52 33.62 1218.43 105.29 -74.68 82.56 111.33 132.13 3.23 BP _MWD+IFR+MS 15 1323.20 19.80 128.94 94.58 1308.00 134.70 -93.07 106.68 141.58 131.10 2.57 BP _MWD+IFR+MS 16 1418.80 21.63 131.18 95.60 1397.42 167.04 -114.85 132.54 175.38 130.91 2.09 BP _MWD+IFR+MS 17 1514.48 24.46 128.01 95.68 1485.46 202.97 -138.67 161.43 212.81 130.66 3.23 BP _MWD+IFR+MS 18 1609.79 28.12 129.78 95.31 1570.90 243.58 -165.20 194.25 254.99 130.38 3.93 BP _MWD+IFR+MS 19 1704.86 28.89 129.15 95.07 1654.44 287.13 -194.03 229.28 300.36 130.24 0.87 BP _MWD+IFR+MS 20 1800.46 32.91 127.98 95.60 1736.46 334.46 -224.61 267.67 349.42 130.00 4.25 BP _MWD+IFR+MS 21 1895.67 33.83 127.88 95.21 1815.97 385.10 -256.80 308.98 401.76 129.73 0.97 BP _MWD+IFR+MS 22 1991.57 36.52 124.29 95.90 1894.36 438.93 -289.27 353.64 456.88 129.28 3.54 BP _MWD+IFR+MS 23 2086.84 39.15 121.13 95.27 1969.60 496.55 -320.80 402.82 514.95 128.53 3.43 BP _MWD+IFR+MS 24 2182.31 40.87 118.82 95.47 2042.73 557.49 -351.44 455.99 575.71 127.62 2.38 BP _MWD+IFR+MS 25 2277.70 42.15 117.35 95.39 2114.16 620.47 -381.19 511.76 638.13 126.68 1.69 BP _MWD+IFR+MS 26 2373.26 43.44 117.25 95.56 2184.28 685.22 -410.97 569.45 702.26 125.82 1.35 BP _MWD+IFR+MS 27 2469.19 45.62 115.85 95.93 2252.66 752.37 -441.02 629.63 768.72 125.01 2.49 BP _MWD+IFR+MS 28 2564.16 48.24 112.75 94.97 2317.52 821.71 -469.53 692.86 836.96 124.12 3.65 BP _MWD+IFR+MS 29 2659.59 50.82 110.71 95.43 2379.46 894.28 -496.38 760.30 907.99 123.14 3.15 BP _MWD+IFR+MS 30 2755.07 53.52 111.95 95.48 2438.01 969.64 -523.82 830.53 981.92 122.24 3.01 BP _MWD+IFR+MS [(c)2008 IDEAL ID13_OC_05] SCHLUMBERGER Survey Report 19 -Mar-2008 16:42:44 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 2850.31 54.73 111.28 95.24 2493.82 1046.78 -552.24 902.27 1057.86 121.47 1.39 BP_MWD+IFR+MS 32 2944.47 55.30 111.57 94.16 2547.81 1123.89 -580.42 974.09 1133.90 120.79 0.66 BP_MWD+IFR+MS 33 3039.70 55.82 109.76 95.23 2601.67 1202.35 -608.13 1047.57 1211.29 120.14 1.66 BP_MWD+IFR+MS 34 3135.86 56.01 109.30 96.16 2655.56 1281.83 -634.76 1122.63 1289.65 119.48 0.44 BP_MWD+IFR+MS 35 3230.61 55.25 109.04 94.75 2709.05 1359.85 -660.44 1196.50 1366.67 118.90 0.83 BP_MWD+IFR+MS 36 3323.91 54.70 109.26 93.30 2762.60 1436.06 -685.50 1268.67 1442.03 118.38 0.62 BP_MWD+IFR+MS , 37 3373.69 53.83 108.82 49.78 2791.67 1476.36 -698.68 1306.87 1481.91 118.13 1.89 BP _MWD+IFR+MS 38 3486.94 52.66 110.54 113.25 2859.44 1566.92 -729.23 1392.30 1571.71 117.64 1.60 BP _MWD+IFR+MS 39 3581.27 53.37 110.11 94.33 2916.19 1642.18 -755.40 1462.96 1646.47 117.31 0.84 BP _MWD+IFR+MS 40 3677.04 54.84 109.11 95.77 2972.34 1719.61 -781.43 1536.04 1723.38 116.96 1.75 BP _MWD+IFR+MS 41 3770.96 54.50 107.39 93.92 3026.66 1795.94 -805.43 1608.80 1799.16 116.59 1.54 BP _MWD+IFR+MS 42 3865.61 55.85 106.20 94.65 3080.71 1873.16 -827.87 1683.19 1875.76 116.19 1.76 BP _MWD+IFR+MS 43 3959.83 55.10 107.39 94.22 3134.11 1950.30 -850.30 1757.50 1952.38 115.82 1.31 BP _MWD+IFR+MS 44 4056.11 55.94 107.18 96.28 3188.62 2029.25 -873.88 1833.28 2030.91 115.49 0.89 BP _MWD+IFR+MS 45 4151.60 56.01 106.63 95.49 3242.05 2107.91 -896.89 1909.00 2109.19 115.17 0.48 BP _MWD+IFR+MS 46 4246.80 55.10 107.46 95.20 3295.89 2185.97 -919.90 1984.06 2186.94 114.87 1.20 BP _MWD+IFR+MS 47 4341.59 54.68 108.99 94.79 3350.41 2263.22 -944.15 2057.71 2263.98 114.65 1.39 BP _MWD+IFR+MS 48 4436.73 55.25 109.14 95.14 3405.03 2340.92 -969.59 2131.34 2341.52 114.46 0.61 BP _MWD+IFR+MS 49 4532.36 54.73 109.18 95.63 3459.90 2419.06 -995.30 2205.32 2419.52 114.29 0.54 BP _MWD+IFR+MS 50 4627.29 55.95 110.26 94.93 3513.88 2497.00 -1021.65 2278.82 2497.36 114.15 1.59 BP _MWD+IFR+MS • 51 4722.80 55.24 110.28 95.51 3567.85 2575.70 -1048.95 2352.75 2575.99 114.03 0.74 BP _MWD+IFR+MS 52 4818.34 54.90 110.38 95.54 3622.55 2653.93 -1076.16 2426.19 2654.16 113.92 0.37 BP _MWD+IFR+MS 53 4914.36 54.23 110.90 96.02 3678.22 2732.09 -1103.74 2499.41 2732.27 113.83 0.83 BP _MWD+IFR+MS 54 5009.45 54.12 110.73 95.09 3733.88 2809.12 -1131.14 2571.48 2809.26 113.74 0.19 BP _MWD+IFR+MS 55 5105.19 51.71 110.50 95.74 3791.61 2885.42 -1158.03 2642.95 2885.52 113.66 2.52 BP _MWD+IFR+MS 56 5200.41 49.50 111.79 95.22 3852.04 2958.95 -1184.56 2711.58 2959.03 113.60 2.55 BP _MWD+IFR+MS 57 5295.51 46.71 112.37 95.10 3915.54 3029.72 -1211.16 2777.18 3029.79 113.56 2.97 BP _MWD+IFR+MS 58 5391.06 43.87 112.76 95.55 3982.75 3097.61 -1237.21 2839.88 3097.67 113.54 2.99 BP _MWD+IFR+MS 59 5486.75 41.88 114.02 95.69 4052.88 3162.71 -1263.04 2899.64 3162.78 113.54 2.26 BP _MWD+IFR+MS 60 5581.69 41.71 115.03 94.94 4123.66 3225.97 -1289.30 2957.20 3226.04 113.56 0.73 BP _MWD+IFR+MS [(c)2008 IDEAL ID13_OC_05] SCHLUMBERGER Survey Report 19 -Mar-2008 16:42:44 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) ------- (ft) ------ (ft) -------- (ft) -------- (ft) -------- (ft) -------- (ft) ------- (deg) -------- 100f) ----- - type (deg) ---- ------ 61 5677.00 41.92 113.05 95.31 4194.70 3289.50 - 1315.18 3015.23 3289.58 113.57 1.40 BP _MWD+IFR+MS 62 5771.93 41.78 112.86 94.93 4265.41 3352.83 - 1339.89 3073.55 3352.91 113.55 0.20 BP _MWD+IFR+MS 63 5867.70 41.59 113.39 95.77 4336.93 3416.52 - 1364.90 3132.12 3416.60 113.55 0.42 BP _MWD+IFR+MS 64 5962.90 40.97 113.01 95.20 4408.47 3479.33 - 1389.64 3189.85 3479.40 113.54 0.70 BP _MWD+IFR+MS 65 6057.57 40.22 112.90 94.67 4480.36 3540.93 - 1413.67 3246.57 3541.00 113.53 0.80 BP _MWD+IFR+MS 66 6150.62 39.80 112.99 93.05 4551.63 3600.75 - 1436.99 3301.66 3600.82 113.52 0.46 BP _MWD+IFR+MS • 67 6246.24 39.39 112.76 95.62 4625.31 3661.70 - 1460.68 3357.81 3661.76 113.51 0.46 BP _MWD+IFR+MS 68 6341.54 39.22 111.75 95.30 4699.05 3722.06 - 1483.54 3413.68 3722.11 113.49 0.69 BP _MWD+IFR+MS 69 6437.18 38.91 111.41 95.64 4773.31 3782.30 - 1505.71 3469.73 3782.35 113.46 0.39 BP _MWD+IFR+MS 70 6532.76 38.18 110.52 95.58 4848.06 3841.82 - 1527.02 3525.34 3841.85 113.42 0.96 BP _MWD+IFR+MS 71 6628.94 37.17 110.91 96.18 4924.19 3900.55 - 1547.81 3580.33 3900.57 113.38 1.08 BP _MWD+IFR+MS 72 6656.39 37.24 110.22 27.45 4946.05 3917.13 - 1553.65 3595.87 3917.15 113.37 1.54 BP _MWD+IFR+MS 73 6725.00 37.24 110.22 68.61 5000.67 3958.59 - 1568.00 3634.83 3958.61 113.33 0.00 Pro jected to TD [(c)2008 IDEAL ID13_OC_05] i +~ I er er Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Christine Mahnken Well No V-223 Date Dispatched: 24-Mar-08 Installation/Rig Nabors 9ES Dispatched By: F. Medina LWD Log Delivery V2.1, 03-06-06 Data No Of Prints No of Floppies Surveys 2 1 Received By: Please sign and return to: Drilling & Measurements LWD Division 2525 Gambell Street, Suite 400 Anchorage, Alaska 99501 fclarke3@slb.com Fax:907-561-8317 ,~ ~ ALASSA OIL A11TD GA,S C01~TSERQATIOI~T COl~'II~IISSIOIQ Robert Tirpack Engineering Team Leader BP Exploration Alaska, Inc. PO Box 196612 Anchorage, Alaska 99519-6612 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Orion Oil Pool, PBU V-223 BP Exploration Alaska, Inc. Permit No: 208-022 Surface Location: 4681' FSL, 1663' FEL, SEC . 11, T 11 N, R 11 E, UM Bottomhole Location: 3157' FSL, 1896' FWL, 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 day of February, 2008 incerely, Daniel T. Seamount, Jr. Chair cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ STATE OF ALASKA ~//D~ ~ ~~\~ ALAS~IL AND GAS CONSERVATION COMMI N ~~ PERMIT TO DRILL [~a- ~~~ ~~,N ~ ~ 2008 20 AAC 25.005 ~1859t~ III ~8~ d~(~8~~ ~ORltlllSSiai. 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 ~gppg~~r: ^ 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-223 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 6621 TVD 4961 12. Field /Pool(s): p,~p^/ Prudhoe Bay Field /f~eMrts Po I 4a. Location of Well (Governmental Section): Surface: 4681' FSL 1663' FEL 11 SEC T11 N R11 E UM 7. Property Designation: ADL 028240 , , . , , , Top of Productive Horizon: 3297' FSL, 1569' FWL, SEC. 12, T11N, R11E, UM 8. Land Use Permit: 13. Approximate Spud Date: February 24, 2008 Total Depth: 3157' FSL, 1896' FWL, SEC. 12, T11 N, R11 E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 8650' 4b. Location of Well (State Base Plane Coordinates): Surface: x-590640 y-5969930 Zone-ASP4 10. KB Elevation Plan (Height above GL): 83~ feet 15. Distance to Nearest Well Within Pool: 1187' 16. Deviated Wells: Kickoff Depth: 400 feet Maximum Hole An le: 52 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2123 Surface: 1638 18. Casin P ram: S Ica ~ s T - Settin h -Bo ttom uanti of Cement a.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 91.5# A-53 Weld 80' Surface Surface 80' 80' 260 sx Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BTC 3378' Surface Surface 3378' 2817' 607 sx Dee Crete 308 sx Class 'G' -3/4" 7" 2 L-80 TC-II 4878' Surface Surfa 4878' 3745' See Bel w 8-3/4" 7" 26# L-80 BTC-M 1743' 4787' 3745' 6621' 4961' 81 sx Crete 198 sx Class'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing Len Size ement Volume M TVD Conductor /Structural Surface Intermediate Pro i 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 Amanda Rebol, 564-5543 Printed Name Ro ert Tirpack Title Engineering Team Leader Prepared By Name/Number: Si nature ~• ~ Phone 564-4166 Date ~ .x1 d~ Terrie Hubble, 564-4628 Commission Use On Permit To Drill Number: O Gb~~O API Number: 50- C~~3.3d'~OD®D Permit Ap rov I See cover letter for Date: ~ other re uirements Conditions of Approval: ~ ~~-~ ~~5~ ~, ~~ 1~ ~I7f box is checked, well may not be us to explore o ,test, or produce coalbed me~th/ane, gas hydrates, or gas contained shales: ''1~~ ~~``~ _~7~ ~ ~feg~. Samples Req'd: ~ Yes Ly No Mud Log Req'd: ^ yes ~o ~~`~~G~'~c ~~~~ ~^ W HZS Measures: Yes ^ No Directional Survey Req'd: es ^ No © S GCVO ~Al~~.~. other: ~o ~`c~t~ ~`1o~c~~. c~.~~~ob~rc ~ ~l`~00~ aO ~RC~-S ~O~ ~ ~~~ 2 ~ ~ ~ APPROVED BY THE COMMISSION date ~~// ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ ~ ( ~ I\ (1 ~ Submit In Duplicate Well Name: V-2231 Drill and Complete Plan Summary T e of Wetl service / roducer / injector : Multi-Zonal Injector Surface Location: As-Built X=590640 Y=5969930 598' FNL, 1663' FEL, T11 N, R11 E, Sec. 11 Target Locations: Top OA X=593890 Y=5968585 1982' FNL, 1569' FWL, T11 N, R11 E, Sec. 12 Top OBd X=594035 Y=5968525 2044' FNL, 1713' FWL, T11 N, R11 E, Sec. 12 Bottom Hole Location: X =594218 Y =5968449 2123' FNL, 1895' FWL, T11 N, R11 E, Sec. 12 API NUMBER: TBD Estimated Start Date: 2/24/2008 Ri Nabors 9ES O eratin Da s to com lete: 14.35 MD: 6621' TVD: 4961' RT/G L: 28.5' RTE: 83.0' Well Design: Grassroots Schrader Bluff Injector 3'h" tbg, 9.2# L80, TC-II, multi-packers, zonal injection Ob'ective: Multi-zonal injector into Schrader Bluff OA, OBa, OBb and OBd sands Directional Plan: Version: Schlumberger P2 KOP: 400' MD, build 1.5/100 Maximum Hole An le: 51.78° Close Approach Wells: All wells pass major risk criteria. Reference anti-collision report Nearest well within Pool: V-223 is 1187' from V-205L2 at injection depth (top of OA sand) Distance to Nearest Property 8650' to PBU boundary Line: Comments: The slotted liner completion legs of V-205 are within'/a mile of V-223i at injection depth: L1 is 1250' from V-223i L2 is 1187' from V-2231 V-223i is intended to provide pressure support to V-205 via injection. No other wells within ~/a mile radius. V-2231 Permit Application Page 1 • Logging Program: Surface Interval Drilling, MWD: GR Open Hole: None Cased Hole: None Intermediate Interval Drilling, MWD: N/A Open Hole: N/A Cased Hole: N/A Production Interval Drilling, MWD: GR, RES, NEU, Azimuthal Density PWD Open Hole: None Cased Hole: USIT / CBL Prima De th Control Mode Mud Program: 12 1/a" Surface Hole: Fresh Water Surface Hole Mud Density Funnel Plastic Yield Point API Fluid Interval (ppg) Viscosity Viscosity (Ib/100ft) Loss pH seconds/ t c mis/30min Initial to Base Perm 8.8 - 9.2 400 - 300 55 - 30 70 - 55 NC - 8.0 9.0 - 9.5 Base PF to top SV1 9 2 - 9 5 250 - 225 55 - 30 60 - 45 8.0 9.0 - 9.5 surface hole TD . 8 3/a" Production Hole: LSND Mud Density Plastic Y d t API Interval (ppg) Viscosity lb/1 Oftn ( ) Fluid Loss pH MBT c ml/30 min SurfaceCsg. gg_9 0 12-18 18-24 <6.0 9-10 <18 Shoe to TD . Casing/Tubing Program: Hole Size Csg/ Tb O.D. WUFt Grade Connection Length Top MD/TVD Btm MDlTVD RTE 42" Insulated 20" 91.5 A-53 WLD 80' GL 80'/ 80' 12'/a" 9 /8" 40 L-80 BTC 3378' GL 3378' / 2817' 8 3/a" 7" 26 L-80 TC-II 4878' GL 4878' / 3745' 8 3/a" 7" 26 L-80 BTC-M 1743' 4878' / 3745' 6621' / 4961' Tubin 3'/z" 9.2 L-80 TC-II 6400' GL 6400' / 4785' Comments: Tb crossover to 4'/i" 'ust below tree brit Testin Test Point Depth Test Type 9 s/R" Surface Casing 20' - 50' from surface shoe LOT V-2231 Permit Application Page 2 • i Cement Calculations: Casin Size Surface Casing - 9 5/s" 40 ppf L-80 BTC -Single Stage Basis Lead: Open hole volume + 250% excess in permafrost, 40% excess below permafrost. TOC at surface Tail: O en hole volume + 40% excess + 80' shoe track. TOC is 2449' MD. Fluid Sequence and TAM port collar potentially run at 1,000' MD as a contingency for cement to surface. Volume: Wash None S acer 100 bbls of MudPush II wei hted to 10.0 Lead 417 bbls 607 sks 10.7 Dee CRETE cement - 3.85 ft /sk Tail 64 bbls 308 sks 15.8 Class G +15 bbls Durastone - 1.16 cuft/sk Temp BHST = 51 ° F from SOR In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casin Size Production Casing - 7" 26 ppf L-80 BTC-M with TC-II crossover -Single Stage Basis Lead: Open hole volume + 40% excess. TOC is 4378' MD. Tail: O en hole volume + 40% excess + 80' shoe track. TOC a rox 500' MD above MA sandstone. Fluid Sequence and TCII from surface to BTC-M crossover at 500' below TOC. Volume: S acer 40 bbls of MudPush II wei hted to 10.0 Lead 47 bbls 81 sks 11.0 CRETE - 3.27 ft /sk Tail 41 bbls 198 sks 15.8 Class G - 1.16 ft /sk Temp BHST = 90° F from SOR Formation To s TVDss and Estimated Pore Pressures Est. Formation To s Est. Formation To s Est. Formation To s Uncertaint Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. Formation MD TVD TVDss feet Yes/No Psi (pP9 EMW NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation to s are re uired from surface to TD for all new wells G1 328 328 245 +/- 50' No 110 8.7 SV6 970 968 885 +/- 50' No 398 8.7 SV5 1697 1647 1565 +/- 50' No 698 8.7 SV4 1849 1777 1695 +/- 50' Gas H drates 754 8.7 Base Permafrost 1879 1802 1720 +/- 50' No 767 8.7 SV3 2150 1977 1895 +/- 50' Gas H drates 943 8.7 SV2 2245 2092 2010 +/- 50' Gas H drates 1013 8.7 SV7 3055 2617 2535 +/- 150' MD Fault #1 (V- Pad Fault 3088 2637 2555 +/- 50' Gas H drates 1157 8.7 UG4 3507 2897 2815 +/- 50' Thin Coal 1285 8.7 UG4A 3556 2927 2845 +/- 50' Thin Coal 1303 8.7 UG3 4130 3282 3200 +/- 50' Heavy Oil 2895'-3000' 1440 8.7 V-223i Permit Application Page 3 SS) UG1 4946 3787 3705 +/- 50' Thin Coal 1672 8.7 UG Ma 5423 4082 4000 +/- 30' No wet 1800 8.7 UG Mb1 5568 4137 4055 +/- 30' No wet 1825 8.7 UG Mb2 5643 4202 4120 +/- 30' No wet 1854 8.7 UG Mc 5708 4267 4185 +/- 30' No wet 1883 8.7 SB Na 5824 4337 4255 +/- 30' No wet 1915 8.7 SB Nb 5849 4352 4270 +/- 30' No wet 1922 8.7 SB Nc 5884 4387 4305 +/- 30' No wet 1937 8.7 SB_Ne 5974 4394 4312 +/- 30' No, ti ht 1940 8.7 SB OA 6037 4497 4415 +/- 30' Yes 1880-1950 8.2-8.5 SB OBa 6112 4557 4475 +/- 30' Yes 1920-1990 8.3-8.6 SB OBb 6163 4597 4515 +/- 30' Yes 2007 8.6 SB OBc 6232 4652 4570 +/- 30' Yes 2031 8.6 SB OBd 6295 4702 4620 +/- 30' Yes 1990-2050 8.2-8.5 SB OBe 6371 4762 4680 +/- 30' Yes 2083 8.6 SB OBf 6446 4807 4725 +/- 30' Yes 2103 8.6 Base_SB_OBf 6496 4853 4770 +/- 30' No 2123 8.6 T.D. in Colville Shale 6621 4961 4878 No 8.7 Well TD Criteria T.D. is 250' M.D. deeper than the Top OBe marker for rathole (ie ??ft TVD, ??ft Rathole, etc.) Comments• SV through UG and SB N sand interval pressures are assumed based on an 8.65 ppg hydrostatic gradient, and regional pressure trends. SB OA, OBa, OBb and OBd pressure ranges are estimated and assume partial pressure depletion as a result of offset multilateral producers. V-223i Permit Application Page 4 Well Control: The 12'/a" hole will be drilled with diverter. The 8 3/a" intermediate hole will use well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Annular preventer will be tested to 2500 psi. Rams will be tested to 4000 psi. The BOP test frequency will be conducted on a 14 day frequency, with a function test every 7 days. Except for significant operational issues that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Diverter; BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- • Maximum anticipated BHP: 2123 psi C~ 4853' TVD, 8.6 ppg EMW (at base of Schrader Bluff OBf, 6496' MD) • Maximum surface pressure: 1638 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) • Planned BOP test pressure: • Annular Preventer • Rams • Planned completion fluid: 250 / 2500 psi 250 / 4000 psi 9.0 ppg brine / 6.8 ppg diesel Kick Tolerance / Integrity Testing Summary Table Casing and Casing Test Maximum Mud Weight Exp Pore LOT / Interval Pressure Influx Press FIT Volume 95/8' Surface 3500 psi 52.5 BBLS 9.0 8.7 LOT Casing (assuming 10.3 LOT'` 7" Production 4000 psi NA NA NA NA Casin * owever- a is exp e 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. 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. V-2231 Permit Application Page 5 C • DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Riq Work: *20" conductor already installed 1. Weld an FMC landing ring for the FMC Gen 5 wellhead on the 20" conductor. 2. if necessary, level the pad and prepare location for rig move. Riq Operations: 1. MIRU Nabors 9ES. 2. Nipple up diverter spool and function test diverter. 3. MU 12'/4" drilling assembly, 4" drill pipe, with MWD/GR and directionally drill surface hole to TD with one BHA. The surface hole TD will be approximately 400' below the top of the SV1- estimated at 3378' MD. 4. Run and cement 9 s/8" surface casing. A TAM port collar may be run at 1000' as a contingency for returning cement to surface. Use Durastone in the last 15 bbls of tail cement. Pressure test casing to 3500 psi for 30 minutes at plug bump. 5. ND diverter and NU casing /tubing head. NU ROPE and test to 4000 psi / 2500 psi annular. 6. Make up 8 3/a" drilling BHA with MWD/GR/RES/Azi-Den/NEU/PWD and RIH to float collar. Drill out shoe track and displace well to LSND drilling fluid. Drill new formation 20' - 50' below 9 s/8' shoe and perform LOT. 7. Drill ahead to production hole target TD (approx. 6621' MD, 250' below top OBe marker). Circulate one BU, back-ream out of hole until the ghost reamer is inside the surface shoe, then POOH to run casing. 8. Run and cement the 7" production casing. Displace with 8.6 ppg seawater during cementing operations. Pressure test casing to 4000 psi for 30 minutes at plug bump. Confirm 1000 psi cement compressive strength prior to freeze protecting. Freeze protect the 7" x 9 5/e" annulus. 9. PU DPC guns and RIH w/ 155' of 4.5" Power Jet 4505 5 spf, pert guns with Anadrill LWD GR for gun correlation. 10. Space out pert guns by tagging PBTD and utilizing GR and RA tags in 7" casing. Once correlated correctly, circulate over to 9.0 ppg brine. Confirm cement compressive strength is at least 1000 psi before firing. Perforate OA, OBa, OBb, and OBd. POOH and 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 loa following Primary Depth Control procedures as USIT log will be primary depth control for future well work. 13. Run the 3-'h", 9.2# completion with a 7" x 3-'/z" straddle packer assembly, I-wire, gauges, and injection mandrels. Torque turn TC-II threaded tubing. 14. Confirm that packers are on depth using E-line. 15. Run in lockdown screws and set the packers. Give AOGCC 24 hours notice, then test the production casing/tubing annulus and tubing to 4000 psi each. Shear the DCR valve and pump both ways to confirm circulation ability. 16. Install and test TWC. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 17. Freeze protect the well to 2200' TVD by first pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ Hot Oil truck, taking clean brine returns to surface. Allow diesel to u-tube into tubing. 18. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-'h" annulus valve and secure the well. Ensure that IA/OA are protected with two barriers. 19. Rig down and move off. Post-Riq Work: 1. MIRU slickline. Pull the ball and rod / RHC plug. 2. Pull shear valve from top mandrel and replace with a dummy GLV. 3. Pull dummy valves from injection mandrels and replace with injection valves. 4. Pull VR plug. V-223i Permit Application Page 6 Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control /Reservoir Pressures: A. Maximum reservoir pressures anticipated: Interval Psi EMW TVDss ft MD ft Schrader Bluff 2007-2123 4510-4770 6100-6600 Sands 8.6-8.7 SV through UG and SB N sand interval pressures are assumed based on an 8.65 ppg hydrostatic gradient, and regional pressure trends. SB OA, OBa, OBb, and OBd pressures assume partial pressure depletion as a result of offtake from up-dip Polygon 2 multilateral production wells. II. Hydrates and Shallow gas: A. Free gas and/or gas hydrates may be present in the SV5 through the SV1 surface hole below the Permafrost base. Use standard operating procedures for hydrates, if encountered. Set surface casing below deepest SV1 sand hydrate zone to isolate gas bearing intervals behind cemented pipe in surface hole from intermediate hole section. III. Running Gravels: A. Unconsolidated sand, gravel, & cobbles and thawing permafrost could impede well angle build and casing running through permafrost. Keep moderate to low build angles until out of permafrost section. Keep flow rates low. Hazards include cobbles/boulders, running gravels, wood, lost circulation and tight hole problems while drilling and running casing. See V Pad data sheet for details. IV. Lost Circulation: A. Non-fault related drilling mud losses averaging 200 bph were in countered in V-218 when drilling into the SV2 interval. Smaller loss rates were also experienced while running casing in this offset well. If mud losses occur, reference standard operating procedures, including running LCM and increasing mud viscosity. V. Kick Tolerance /Integrity Testing: A. The 9 5/$" casing will be cemented to surface. A TAM port collar run at 1000' MD in the surface casing is contingency to get cement to surface. A LOT will be performed after drilling 20-50' of new formation after drilling out the 9 s/8" casing shoe. B. The 7" casing will be cemented to 1000' MD below the 9 5/$" casing shoe. Kick Tolerance / In#egrity Testing Summary Table Casing and Casing Test Maximum Influx Mud Weight Exp Pore LOT ! Interval Pressure Volume press FIT 95/$" Surface 3500 psi 52.5 BBLS (assuming 9.0 8.7 LOT Casing 10.3 LOT 7" Production 4000 psi NA NA NA NA Casin *ttowever- a t z.5 w i is expected V-2231 Permit Application Page 7 L VI. Heavy Oil A. Heavy oil is expected in the UG4A and UG1 sand intervals which could result in plugging of shaker screens. Follow established operating practices for drilling in heavy oil zones; depths of heavy oil intervas are outlines in the Marker Tops section. VII. Hydrogen Sulfide A. All V Pad gas lift wells are expected to have H2S levels in the 10 to 300 ppm range; result of PBU gas lift gas. While no H2S is anticipated on this site, standard H2S precautions should be followed at all times. H2S Summa Table Well Name H Level m Date of Readirt #1 Closest SHL Well H2S Level V-01 75 8/20/2007 #2 Closest SHL Well H2S Level V-204 60 8/6/2007 #1 Closest BHL Well H2S Level* V-205 10 8/4/2007 Max. Recorded H2S on Pad/Facilit V-117 300 4/3/2007 *Second closest bottom hole location is in a formation that will not be penetrated by V-223i VIII. Faults A. Penetration of the V pad fault will occur during drilling the SV1 interval. Fault depth is approx. 3088' (+/_ 100'). Fault throw: southwest direction, approx. 85'. B. C. No faults are predicted in the injection interval. CONSULT THE V PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION V-2231 Permit Application Page 8 TREE = 4-1 /16" WELLHEAD= FMC ACTUATOR = Electric KB. ELEV = 28.5' BF. ELEV = KOP = 400' Max Angle =51.8• ~ 2617' ProposBD - V-2231 3-1 /2" HES X N9s, ID ®2.813" I 9-5/8" CSG, 40#, L-80, ID = 8.835" 3378' XO from TG/ to BTGM 4$'~$' WATERFLOOD/GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 5917' XXXX 40 MMG DCR-1 RKP 1.5" 7 6021' XXXX 37 MMG-W DUM RK 1.5" 6 6067' XXXX 37 MMG-W DUM RK 1.5" 5 6106' XXXX 37 M91AG-W DUM RK 1.5" 4 6135' XXXX 37 MMG-W DUM RK 1.5' 3 6184' XXXX 37 MMGW DUM RK 1.5" 2 6233' XXXX 37 MMG-W DUM RK 1.5' 1 6331' XXXX 37 MMG-W DUM RK 1.5" ~7" MARKER dONT W/ RA TAG 3-112" TBG W/ RA Tag in Centralizer _ Se Minimum ID = 2.75p 3-112" HES XN NIPPLE oa PERFORATION SUMMARY REF LOG: ANGLEAT TOP PERF: 37 deg Not®: SQE SPF ~ITERVAL Opn/Sqz DATE 4.5° 5 OA - 45' O 4.5" 5 OBa - 35' O 4.5" 5 OBb - 20' O 4.5" 5 OBd - 55' O 3-1/2" TBG, 9.2#, L-80, .0087 bpf, O = 2.992" H 6402' PBTD 6521' 7" CSG, 26ii, L-80, ®= 6.276" 6621' 5951' ~ 3-1/2" HES XNIP, O = 2.813" ~ 992' 7"X3-1/2" HES AHR Pecker, ~ 6006' ~ ~ NDPCi I=re. EWrce run Prom surface 6076' ~ 3-1/2" HE5 X N~, O = 2.813" I 6086' 7"X3-112" HES AHR Packer, ~ ~ 2.82t" 6100' NDPG Ress/Terrp Sensor Sub 6153' 7" X 3-1/2" HES AHR Packer, ID = 2.921 6167' NDPG Ress/Temp Sensor Sub 3-1/2" HES X NIP, ~ = 2.813" 6271' u 7" X 3-1/2" HES AHR Pecker, ~ = 2.921" 62$5' NDPG Ress/Temp Sensor Sub ~' 3-1l2" HES X N~ ~ ®2.813' 6359' 3-112" HES X NIP, K1 m 2.813" w/RHGm pIW 637g' 3-1/2" HES XN N~, ~ = 2.75" I 6400' I DATE REV BY COMMENTS DAATE REV BY COMMENTS ORION UNIT 12/04/07 AER Roposed Conpletion Ver. 1.0 WELL: V-2231 PERMIT No: API No: Sec 11 T11 N R11 E 8P dcplaration (Alaska) by V-223 (P2 Report Date: October 4, 2007 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure 1 Slot: V-Pad / Plan V Slot (S-M) ~~ Well: ~~~~' Plan V-223 (S-M) Borehole: ~~~ Plan V-223 UWIIAPI#: 50029 Survey Name 1 Date: V-223 (P2) I October 4, 2007 Tort 1 AND 1 DDI 1 ERD ratio: 70.574° / 3894.33 ft / 5.564 / 0.785 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatlLong: N 70.32758088, W 149.26491439 Location Grid NIE YIX: N 5969929.700 ftUS, E 590640.200 ftUS Grid Convergence Angle: +0.69218497° osa~ Schlumberger Vertical Section Azimuth: 113.171 ° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 83.00 ft relative to MSL Sea Bed 1 Ground Level Elevation: 54.50 ft relative to MSL Magnetic Declination: 23.058° Total Field Strength: 57646.140 nT Magnetic Dip: 80.873° Declination Date: March 15, 2008 Magnetic Declination Model: BGGM 2007 North Reference: True North Total Corr Mag North -> True North: +23.058° Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Subsea TVD TVD Vertical NS EW Gravity DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 100 ft Index ftUS ftUS rcrr_ u.uu u.w rab.uv -ac .bu V.UU U .UU U .UU U.UV -- U.UU U.UU bybyyYy./U b`JVb4U.ZV N /U.3Z/5t7Vt52f VV 74y.Zb4y143y KOP Bld 1.5/100 400.00 0.00 185.00 317 .50 400.00 0 .00 0 .00 0.00 HS 0.00 0.00 5969929.70 590640.20 N 70.32758088 W 149.26491439 Bld 2/100 500.00 1.50 185.00 417 .49 499.99 0 .41 -1 .30 -0.11 70.00E 1.50 0.29 5969928.39 590640.10 N 70.32757732 W 149.26491532 600.00 2.88 144.27 517 .42 599.92 2 .97 -4 .65 1.24 29.30E 2.00 1.24 5969925.07 590641.50 N 70.32756818 W 149.26490434 700.00 4.73 132.32 617 .20 699.70 9 .01 -9 .46 5.75 17.36E 2.00 1.80 5969920.31 590646.07 N 70.32755503 W 149.26486773 Crv 2.5/100 783.19 6.34 127.81 700 .00 782.50 16 .69 -14 .59 11.92 HS 2.00 2.15 5969915.26 590652.29 N 70.32754103 W 149.26481776 800.00 6.76 127.81 716 .70 799.20 18 .55 -15 .76 13.43 HS 2.50 2.21 5969914.10 590653.82 N 70.32753783 W 149.26480549 900.00 9.26 127.81 815 .71 898.21 32 .02 -24 .30 24.43 HS 2.50 2.55 5969905.70 590664.92 N 70.32751450 W 149.26471628 1000.00 11.76 127.81 914 .03 996.53 49 .66 -35 .47 38.84 HS 2.50 2.83 5969894.70 590679.46 N 70.32748397 W 149.26459948 1100.00 14.26 127.81 1011 .46 1093.96 71 .43 X9 .27 56.61 HS 2.50 3.06 5969881.12 590697.40 N 70.32744628 W 149.26445532 1200.00 16.76 127.81 1107 .81 1190.31 97 .30 -65 .66 77.73 HS 2.50 3.26 5969864.99 590718.71 N 70.32740151 W 149.2642 1300.00 19.26 127.81 1202 .90 1285.40 127 .20 -84 .61 102.15 HS 2.50 3.43 5969846.34 590743.35 N 70.32734975 W 149.2640 8 1400.00 21.76 127.81 1296 .56 1379.06 161 .09 -106 .08 129.82 HS 2.50 3.59 5969825.21 590771.28 N 70.32729108 W 149.26386169 1500.00 24.26 127.81 1388 .60 1471.10 198 .90 -130 .04 160.70 HS 2.50 3.73 5969801.63 590802.44 N 70.32722563 W 149.26361134 1600.00 26.76 127.81 1478 .85 1561.35 240 .56 -156 .43 194.71 HS 2.50 3.85 5969775.65 590836.77 N 70.32715352 W 149.26333552 SV5 1697.56 29.19 127.81 1565. 00 1647.50 284. 83 -184. 49 230.86 HS 2.50 3.96 5969748.03 590873.25 N 70.32707687 W 149.26304239 1700.00 29.26 127.81 1567 .13 1649.63 285 .98 -185 .22 231.80 HS 2.50 3.97 5969747.31 590874.20 N 70.32707488 W 149.26303475 1800.00 31.76 127.81 1653 .28 1735.78 335 .09 -216 .33 271.91 HS 2.50 4.07 5969716.69 590914.67 N 70.32698986 W 149.26270959 SV4 1849.39 32.99 127.81 1695. 00 1777.50 360. 68 -232. 55 292.80 HS 2.50 4.12 5969700.73 590935.76 N 70.32694557 W 149.26254017 End Crv 1867.32 33.44 127.81 1710 .00 1792.50 370 .18 -238 .57 300.56 -- 2.50 4.14 5969694.80 590943.59 N 70.32692912 W 149.26247726 Base Perm 1879.31 33.44 127.81 1720 1802.5 376. 57 -242. 62 305.78 --- 0 4.15 5969690.82 590948.86 N 70.32691806 W 149.26243496 Crv 3/100 1891.29 33.44 127.81 1730 .00 1812.50 382 .96 -246 .66 310.99 40.29E 0.00 4.15 5969686.83 590954.12 N 70.32690700 W 149.26239266 WeIlDesign Ver SP 2.1 Bld(doc40x_100) Plan V Slot (S-M)\Plan V-223 (S-M)\Plan V-223\V-223 (P2) Generated 10/4/2007 3:30 PM Page 1 of 2 Measured Vertical Gravity Directional Comments Inclination Azimuth Subsea TVD TVD NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 100 ft Index ftUS ftUS 1`JUU.UU 33.64 1Z/.51 1/3/.26 1iSly./6 :Sts/.6Z -Z4y.6U 314.tSU 4U.U3L 3.UU 4.16 by6y62f3.y4 byUyb/.y6 N /U.3'L6tSytSy/ W 14y.'Lti'L3tS1// 2000.00 35.98 124.22 1819.37 1901.87 443.30 -283.00 361.07 37.34E 3.00 4.26 5969651.11 591004.63 N 70.32680774 W 149.26198658 2100.00 38.40 121.29 1899.03 1981.53 502.89 -315.66 411.92 35.00E 3.00 4.35 5969619.07 591055.86 N 70.32671850 W 149.26157432 2200.00 40.89 118.66 1976.03 2058.53 566.24 -347.50 467.19 32.98E 3.00 4.43 5969587.90 591111.51 N 70.32663151 W 149.26112615 SV2 2245.34 42.04 117.56 2010.00 2092.50 596.14 -361.64 493.67 32.15E 3.00 4.47 5969574.09 591138.16 N 70.32659287 W 149.26091145 2300.00 43.43 116.29 2050.15 2132.65 633.16 -378.43 526.74 31.22E 3.00 4.51 5969557.70 591171.43 N 70.32654700 W 149.26064327 2400.00 46.02 114.13 2121.20 2203.70 703.47 -408.37 590.41 29.68E 3.00 4.59 5969528.53 591235.45 N 70.32646519 W 149.26012702 2500.00 48.64 112.15 2188.97 2271.47 776.99 -437.23 658.03 28.34E 3.00 4.66 5969500.49 591303.40 N 70.32638632 W 149.25957881 2600.00 51.30 110.33 2253.28 2335.78 853.50 -464.94 729.39 27.17E 3.00 4.73 5969473.64 591375.09 N 70.32631060 W 149.25900014 End Crv 2617.91 51.78 110.01 2264.42 2346.92 867.51 -469.78 742.56 -- 3.00 4.74 5969468.97 591388.31 N 70.32629738 W 149.2588 SV1 3055.23 51.78 110.01 2535.00 2617.50 1210.55 -587.36 1065.38 --- 0.00 4.91 5969355.30 591712.49 N 70.32597605 W 149.2562 9-5/8" Csg Pt 3378.48 51.78 110.01 2735.00 2817.50 1464.11 -674.28 1303.99 --- D.00 5.00 5969271.28 591952.12 N 70.32573850 W 149.2543 UG4 3507.78 51.78 110.01 2815.00 2897.50 1565.54 -709.04 1399.43 -- 0.00 5.03 5969237.68 592047.97 N 70.32564348 W 149.25356756 UG4A 3556.27 51.78 110.01 2845.00 2927.50 1603.57 -722.08 1435.23 --- 0.00 5.04 5969225.08 592083.91 N 70.32560784 W 149.25327737 UG3 4130.03 51.78 110.01 3200.00 3282.50 2053.65 -876.35 1858.76 --- 0.00 5.17 5969075.95 592509.24 N 70.32518613 W 149.24984357 UG1 4946.24 51.78 110.01 3705.00 3787.50 2693.90 -1095.81 2461.26 --- 0.00 5.30 5968863.80 593114.29 N 70.32458612 W 149.24495912 Ma 5423.03 51.78 110.01 4000.00 4082.50 3067.90 -1224.01 2813.21 --- 0.00 5.36 5968739.88 593467.73 N 70.32423556 W 149.24210595 Crv 4/100 5664.62 51.78 110.01 4149.47 4231.97 3257.41 -1288.96 2991.55 172.32R 0.00 5.39 5968677.09 593646.82 N 70.32405792 W 149.24066031 5700.00 50.38 110.26 4171.70 4254.20 3284.90 -1298.44 3017.39 172.16R 4.00 5.41 5968667.93 593672.78 N 70.32403200 W 149.24045082 5800.00 46.41 111.01 4238.09 4320.59 3359.58 -1324.77 3087.36 171.66R 4.00 5.45 5968642.44 593743.05 N 70.32395999 W 149.23988365 Na 5824.31 45.45 111.21 4255.00 4337.50 3377.04 -1331.06 3103.66 171.53R 4.00 5.45 5968636.35 593759.42 N 70.32394278 W 149.23975154 5900.00 42.46 111.87 4309.48 4391.98 3429.55 -1350.34 3152.52 171.05R 4.00 5.48 5968617.66 593808.51 N 70.32389006 W 149.23935545 6000.00 38.51 112.87 4385.52 4468.02 3494.45 -1375.02 3212.55 170.29R 4.00 5.52 5968593.71 593868.83 N 70.32382256 W 149.23886879 End Crv 6027.33 37.44 113.17 4407.06 4489.56 3511.27 -1381.60 3228.03 --- 4.00 5.52 5968587.32 593884.38 N 70.32380458 W 149.23874335 V-223 Tgt 1 OA 6037.33 37.44 113.17 4415.00 4497.50 3517.34 -1383.99 3233.62 --- 0.00 5.53 5968585.00 593890.00 N 70.32379804 W 149.23869805 OA 6037.34 37.44 113.17 4415.01 4497.51 3517.35 -1383.99 3233.62 --- 0.00 5.53 5968585.00 593890.01 N 70.32379803 W 149.23869800 OBa 6112.89 37.44 113.17 4475.00 4557.50 3563.28 -1402.06 3275.85 --- 0.00 5.53 5968567.44 593932.44 N 70.32374861 W 149.23835576 OBb 6163.26 37.44 113.17 4515.00 4597.50 3593.90 -1414.11 3304.00 --- 0.00 5.53 5968555.73 593960.73 N 70.32371566 W 149.23812757 8 OBc 6232.53 37.44 113.17 4570.00 4652.50 3636.00 -1430.68 3342.71 --- 0.00 5.54 5968539.63 593999.63 N 70.32367035 W 149.237 V-223 Tgt 2 OBd 6295.50 37.44 113.17 4620.00 4702.50 3674.28 -1445.74 3377.90 --- 0.00 5.54 5968525.00 594035.00 N 70.32362916 W 149.23752856 OBd 6295.51 37.44 113.17 4620.01 4702.51 3674.29 -1445.75 3377.90 --- 0.00 5.54 5968525.00 594035.01 N 70.32362915 W 149.23752850 6371.06 37.44 113.17 4680.00 4762.50 3720.22 -1463.82 3420.12 --- 0.00 5.55 5968507.44 594077.44 N 70.32357973 W 149.23718627 OBe 6371.08 37.44 113.17 4680.01 4762.51 3720.22 -1463.82 3420.13 --- 0.00 5.55 5968507.44 594077.45 N 70.32357972 W 149.23718621 TD / 7" Csg 6621.06 37.44 113.17 4878.51 4961.01 3872.18 -1523.61 3559.83 --- 0.00 5.56 5968449.34 594217.85 N 70.32341619 W 149.23605383 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Plan V Slot (S-M)\Plan V-223 (S-M)\Plan V-223\V-223 (P2) Generated 10/4/2007 3:30 PM Page 2 of 2 by • • Schlumberger WELL V-223 (P2) FIELD Prudhoe Bay Unit - WOA STRUCTURE V-Pad Magrele Parameters Sutla ce Location NA02] Alaska Slala Planes. Zore M, US Feel Miscella neous Motlel: BGGM 2001 Dip: 00.0]J° Dale'. Mdlcn 15.2008 Lal: N]0 t9 J9.29t NoMmg. 5969929 ]O INS Gritl Conv: ~0 fi921049]° Slol: PWn V SIO115-MI TVD Re!. olary Table 182 50 fl above MSL) Mag Dec'. .23050° FS'. 5]fi4fi.t nT Lan'. W1491553.692 Easling: 591164020 ftt15 Scale F.xl. 09999093320 Plan: V-22J (P21 Snry Dale'. GctMer 04. 2D0] 0 800 1600 2400 3200 0 800 1600 O O ~_ 2400 C 0) f6 U D H 3200 4000 4800 Perm ~ ~ ~ - ~~- Crv 3F,700 _.._.._.._. _.-_.._.._.._.._ . ~..i. _.._.._.._.._.._.._.._ ._.._.._.._.._.._.._.._.i_ ._.._.._.._.._.._.._.._y_.._.._.._.._.._.._.._ .. End Crv 9-SIB" Csg Pt -..-..-.._.. ~.._.._..-.._.._.._.._.._..i.. _.._.._.._.._.._.._.._..L.._.. _.. _.._.._.. _.._.._.{ crv anon `~ .. •. .End crv a Tgt z oea TD l 7" Csg V-223 0 800 1600 2400 3200 4000 4800 0 800 1600 2400 3200 Vertical Section (ft) Azim = 113.17°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-V by Schlumberger ALL V-223 (P2) PIELD Prudhoe Bay Unit - WOA STRUCTURE V-Pad Magne0c Parameters Surtaca Location NAD2] to Planes. Zone IW. US Feet Miscellaneous Matlel: BGGM 2001 Dip. 80.8)3° Dale. c 15.2008 Lal: N]0 (939.291 NMhing S9fi9929110 flU5~ GrN Dunv: +0 fi921849]° Slot PIanV SIW fS-M1 NDRei: Rotary Tahle f8250flahove MSLf Mag Dec: +23058° FS'. 1nT Lon. W1491553.692 EasOng: 590fi40.20 ftU5 Scale Fact 0.9999093328 Plan: 23fP31 srvy Date: onohe. oa. 209] 0 500 1000 1500 2000 2500 3000 3500 0 n n n Z -500 0 0 c m -1000 v v v -1500 0 500 1000 1500 2000 2500 3000 3500 «< W Scale = 1(in):500(ft) E »> 0 -500 -1000 -1500 • i BP Alaska Anticollision Report Company: BP Amoco Date: 10/4!2007 'time: 15:36:12 Page: I Field: Prudhoe Bay Reference Site: PB V Pad Co-ordinate(NE) Reference: Well: Plan V-223 (S-M), True North Reference Well: Plan V-223 (S-M) Vertical (TVD) Reference: V-223 Plan 82.5 Reference Wellpath: Plan V-223 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are Itl@IiHoeells in thisRlildlpal Plan & PI..ANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 6621.06 ft Scan Method: Trav Cylinder North Maximum Radius: 859.26 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath - - -_ _. ~ Date: 10!3/2007 Validated: No Version: 2 ' Planned From To Survey Toolcode Tool Name ft ft 28.50 500.00 Planned: Plan #2-5 V2 GYD-GC-SS Gyrodata gyro single shots 500.00 1900.00 Planned: Plan #2-5 V2 MWD MWD - Standard 500.00 3320.00 Planned: Plan #2-5 V2 MWD+IFR +MS MWD +IFR + Multi Station 3320.00 6621.06 Planned: Plan #2-5 V2 MWD+IFR+MS MWD +IFR + Multi Station Casiug Points - -- - MD 'CVD - - Diameter Hole Size Name - ft ft in in 3378.48 2817.50 ~ 9.625 12.250 9 5/8" ~ 6621.06 4961.00 7.000 8.750 7" Summary <--------- Ot'fset Wellpath ------ -----> Keference Otl'set Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning tt ft- ft ft ft ~ ~, PB V Pad Plan V-07 (NM-15) Plan V-07 V14 Plan: PI 376.50 375.00 181.22 7.15 174.07 Pass: Major Risk PB V Pad Plan V-220 (N-P) Plan V-220 V4 Plan: PI 994.00 1020.00 126.09 15.82 110.27 Pass: Major Risk ', PB V Pad V-01 V-01 V15 404.90 405.00 16.08 7.30 8.77 Pass: Major Risk I~ PB V Pad V-02 V-02 V12 661.32 675.00 204.76 10.87 193.90 Pass: Major Risk '~ PB V Pad V-03 V-03 V7 425.99 345.00 235.57 6.76 228.80 Pass: Major Risk I, PB V Pad V-04 V-04 V7 458.33 460.00 184.00 8.41 175.58 Pass: Major Risk j PB V Pad V-100 V-100 V7 1185.67 1180.00 104.05 18.15 85.90 Pass: Major Risk PB V Pad V-101 V-101 V7 380.17 380.00 250.13 6.56 243.57 Pass: Major Risk ~, PB V Pad V-102 V-102 V5 414.79 415.00 184.64 8.26 176.38 Pass: Major Risk ', PB V Pad V-103 V-103 V6 274.99 275.00 202.95 4.84 198.11 Pass: Major Risk PB V Pad V-104 V-104 V13 429.16 430.00 216.35 7.25 209.10 Pass: Major Risk ~ PB V Pad V-105 V-105 V13 747.15 760.00 172.87 12.21 160.66 Pass: Major Risk PB V Pad V-106 V-106 V10 399.67 400.00 189.57 6.46 183.12 Pass: Major Risk PB V Pad V-106 V-106A V9 119.70 120.00 189.87 2.30 187.56 Pass: Major Risk ~ ~, PB V Pad V-106 V-106APB1 V6 119.70 120.00 189.87 2.30 187.56 I Pass: Major Risk PB V Pad V-106 V-106AP62 V2 119.70 120.00 189.87 2.30 187.56 Pass: Major Risk li PB V Pad V-106 V-106AP63 V2 119.70 120.00 189.87 2.30 187.56 Pass: Major Risk 'i PB V Pad V-107 V-107 V5 671.21 685.00 189.28 10.66 178.62 Pass: Major Risk li PB V Pad V-109 V-109 V2 564.41 565.00 162.06 9.36 152.70 Pass: Major Risk PB V Pad V-109 V-109P61 V5 564.41 565.00 162.06 9.36 152.70 Pass: Major Risk PB V Pad V-109 V-109P62 V2 564.41 565.00 162.06 9.36 152.70 Pass: Major Risk PB V Pad V-111 V-111 V25 457.51 460.00 217.99 8.62 209.38 Pass: Major Risk I, PB V Pad V-111 V-111 PB1 V8 457.51 460.00 217.99 8.62 209.38 Pass: Major Risk i, PB V Pad V-111 V-111 P62 V2 457.51 460.00 217.99 8.62 209.38 Pass: Major Risk PB V Pad V-111 V-111 P63 V6 457.51 460.00 217.99 8.62 209.38 Pass: Major Risk !~ PB V Pad V-112 V-112 V7 330.99 330.00 221.51 6.14 215.37 Pass: Major Risk ', ', PB V Pad V-113 V-113 V6 511.52 510.00 192.18 8.12 184.06 Pass: Major Risk PB V Pad ~ V-114 V-114 V5 340.68 340.00 131.21 5.89 125.32 Pass: Major Risk PB V Pad ~ V-114 V-114A V4 340.68 340.00 131.21 5.89 125.32 Pass: Major Risk ! PB V Pad V-114 V-114AP61 V4 340.68 340.00 131.21 5.89 125.32 Pass: Major Risk PB V Pad V-114 V-114APB2 V2 340.68 340.00 131.21 5.89 125.32 Pass: Major Risk PB V Pad V-115 V-115 V5 329.49 330.00 167.38 5.59 161.78 Pass: Major Risk PB V Pad V-115 V-115PB1 V4 329.49 330.00 167.37 5.59 161.78 Pass: Major Risk PB V Pad V-117 V-117 V9 393.68 395.00 104,59 6.90 97.68 Pass: Major Risk PB V Pad V-117 V-117P61 V6 393.68 395.00 104.59 6.90 97.68 Pass: Major Risk PB V Pad V-117 V-117PB2 V6 393.68 395.00 104.59 6.90 97.68 Pass: Major Risk PB V Pad V-119 V-119 V13 583.35 585.00 145.44 10.21 135.23 Pass: Major Risk PB V Pad V-120 V-120 V5 250.39 250.00 244.81 4.61 240.20 Pass: Major Risk PB V Pad V-121 V-121 V5 554.13 555.00 72.89 10.69 62.20 Pass: Major Risk PB V Pad V-122 V-122 V10 294.64 295.00 121.54 5.27 116.27 Pass: Major Risk PB V Pad V-122 V-122P61 V10 294.64 295.00 121.54 5.27 116.27 Pass: Major Risk BP Alaska Anticollision Report Company: BP Amooo Field: Prudhoe Bay Reference Site: PB V Pad Reference Well: Plan V-223 (S-M) Reference Wellpath: Plan V-223 Summary ~< ----_ pffset Wellpath > Site Well Wellpath PB V Pad V-122 V-122P62 V5 PB V Pad V-201 Plan V-201A V1 Plan: P PB V Pad V-201 V-201 V10 ', PB V Pad V-202 V-202 V9 ', PB V Pad V-202 V-202L1 V5 PB V Pad V-202 V-202L2 V5 ~~ PB V Pad V-204 V-204 V2 PB V Pad V-204 V-204L1 V2 'i PB V Pad V-204 V-204L1 PB1 V6 PB V Pad V-204 V-204L2 V2 PB V Pad ~ V-204 V-204L2P61 V5 ! PB V Pad V-204 V-204L3 V3 PB V Pad V-204 V-204PB1 V9 PB V Pad V-204 V-204P62 V2 PB V Pad V-205 V-205 V14 ', PB V Pad V-205 V-205L1 V9 PB V Pad V-205 V-205L2 V8 PB V Pad V-210 V-210 V9 ', PB V Pad V-212 V-212 V7 PB V Pad V-213 V-213 V5 PB V Pad V-213 V-213P61 V5 PB V Pad V-214 V-214 V3 PB V Pad V-214 V-214PB1 V2 PB V Pad V-214 V-214P62 V3 PB V Pad V-214 V-214P63 V5 PB V Pad V-214 V-214PB4 V2 PB V Pad V-215 V-215 V7 PB V Pad V-216 V-216 V8 PB V Pad V-217 V-217 V5 PB V Pad V-218 V-218 V6 PB V Pad V-221 V-221 V6 ', PB V Pad V-222 V-222 V6 Date: 10/4/2007 'l'ime: 15:36:12 Page: 2 Co-ordinate(NE) Reference: Well: Plan V-223 (S-M), True North Vertical ('I'VD) Keference: V-223 Plan 82.5 Db: Oracle Reference Offset Ctr-Ctr No-Go Allowable MD MD Distance Area Deviation Warning ft - ft ft ft ft _ 294.64 295.00 121.54 5.27 116.27 Pass: Major Risk 320.40 320.00 193.77 5.51 188.27 Pass: Major Risk 320.40 320.00 193.78 5.51 188.27 Pass: Major Risk 590.04 600.00 225.48 10.48 215.00 Pass: Major Risk 590.04 600.00 225.48 10.43 215.05 Pass: Major Risk 590.04 600.00 225.48 10.43 215.05 Pass: Major Risk 513.98 515.00 115.13 9.21 105.92 Pass: Major Risk 513.98 515.00 115.13 9.21 105.92 Pass: Major Risk 513.98 515.00 115.13 9.21 105.92 Pass: Major Risk 513.98 515.00 115.13 9.21 105.92 Pass: Major Risk 513.98 515.00 115.13 9.21 105.92 Pass: Major Risk 513.98 515.00 115.13 9.21 105.92 Pass: Major Risk 513.98 515.00 115.13 9.21 105.92 Pass: Major Risk 513.98 515.00 115.13 9.21 105.92 Pass: Major Risk 944.52 945.00 36.56 15.38 21.18 Pass: Major Risk 5110.79 7850.00 851.53 No Offset Errors 5084.78 7715.00 786.07 No Offset Errors 226.39 225.00 222.58 4.03 218.55 Pass: Major Risk 411.89 410.00 195.95 7.18 188.77 Pass: Major Risk 279.59 280.00 151.60 5.21 146.38 Pass: Major Risk 279.59 280.00 151.60 5.21 146.38 Pass: Major Risk 275.90 275.00 241.60 5.65 235.95 Pass: Major Risk 451.95 450.00 243.53 9.63 233.90 Pass: Major Risk 293.68 290.00 242.35 5.82 236.53 Pass: Major Risk 293.68 290.00 242.35 5.82 236.53 Pass: Major Risk 293.68 290.00 242.35 5.82 236.53 Pass: Major Risk 667.80 670.00 92.44 13.78 78.66 Pass: Major Risk 210.88 210.00 210.33 3.95 206.38 Pass: Major Risk 1549.12 1535.00 44.84 30.47 14.37 Pass: Major Risk 315.50 315.00 225.08 5.62 219.47 Pass: Major Risk 315.85 315.00 180.79 6.45 174.34 Pass: Major Risk 276.49 275.00 185.23 5.17 180.05 Pass: Major Risk FieldPrudhoe Bay SitePB V Pad We11:Plan V-223 (S-M) WellpathElan V-223 313 300 200 100 0 2 100 200 300 313 0 Travelling Cylinder Azimuth (TfO+AZI) [degj vs Centre t ~ e' 1 V-PAD ,~ L-PAD ~~' ~ ) ~ ~+ ~ : ' 35 . 3~ ~ ~ ,~ ~ ~ ~ ~ GRID i t' ` ~ I 15°00'00'~Z - WppESppT~~ / K~TAZEDK ~ {~~ ~~ o3-11 ~ PLANT I ~ I 1^ ' '" ~ , ~~ ~ ~ _ F ROJECT V-2201 ~ , ~ ~ ~ - AREA~- ,. ~~~ In ~ -- ~~ k V-PAD , ~ . . ~~ ~ V-120 ^ ^ V-115 ~'~ { ~ V-03 ^ ^ V-213i V-2181 ^ ^ V-100 ~ ~V - TO ~~ C1 v~ ~ V-111 ^ ^ V-122 NF _ { R~ ~ ~ V-216i ^ ^ V-117 S ~ I" t, - ~~- ~ ~ V-103 ^ V-212 ^ ^ V-121 ~ _ _ I"~" ~ ~ ° ° -'°~ ^ ^ V-211 VICINITY MAP ^ V-205 v-oa ^ N.T.S. v-1 osi ^ v-o1 v-zzr ^ V-2231 v-o7 ^ v-zz2i ^ V-102 ^ ^ V-SPARE (sEOr s-E) V-201 ^ V_107 ^ ^ SLOT S-J ^ V-2,51 ~~ 0 F q ~ q V-02 ^ s ° v-zloi ^ ^ v-11a Gj °° ~ °°°-9 v-zoz ^ ^ v-11s 2, a1 ^ ^ v-, D9 ,~ o °4 9 TH °°° ~ - V-101 ^ °°°a°°°°°°°°°°°°°°°°°°°°°°°o°°° V-211( ^ ^ V-113 V-108 ^ ~ ^ V-112 V-203 ^ °°°°°°°°°°°°°°°°°°°°°°°°°°°°°°° '?~~,°°° Richard F. Alliso n ~sr 10608 `~D °°°°°° °°°°~ ~ ~ 1 ' ESS I ONAL TO SPINE ROAD - SURVEYOR'S CERTIFICATE I _ M C ~ ICENSED REGISTERED AND PROPERLY _ PPO R IN D P WoP ~" / ~ THAT AND ASKA STATE OF AN T~E to / i THIS AS-BUILT REPRESENTS A SURVEY ~ ~ MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE NOTES CORRECT AS OF JAN. 04, 2008. 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD-27. 2. BASIS OF HORIZONTAL CONTROL IS V-PAD OPERATOR MONUMENTATION. LEGEND 3. BASIS OF ELEVATION IS V-PAD OPERATOR MONUMENTATION. -~- AS-BUILT CONDUCTOR ELEVATIONS ARE BP MEAN SEA LEVEL DATUM. 4. THE MEAN SCALE FACTOR FOR V-PAD IS 0.999909334. ^ EXISTING CONDUCTOR 5. REFERENCE FIELD BOOK: W008-01 PGS. 05-10. 6. DATE OF SURVEY: JANUARY 04, 2008. LOCATED WITHIN PROTRACTED SEC. 11, T. 11 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR BOX SECTION N0. COORDINATES COORDINATES POSITION DMS) POSITION(D.DD) ELEV. OFFSETS Y=5,970,157.67 N 10,179.83 70'19'41.515" 70.328199' 526' 4,908'FSL ' V-220i X= 590,796.67 E 5,060.28 149'15'49.044" 149.2636233' FEL 1,503 Y=5,969,929.57 N 10,000.03 70'19'39.290" 70.3275806' 529' 4,681'FSL ' V-223i X= 590,640.02 E 4,849.91 149'15'53.697" 149.2649158' FEL 1,663 CHECKEI (~ I J DATE: O ~ r 1 DRAwiN( U FR808' ~ ~(\N~\, ~~o ~ J08 NO: ~ lll SCALE: M. GRIM ALLISON 1/O5/OS ov o1-0o GREATER PRUDHOE BAY V-PAO SHEET: AS-BUILT CONDUCTOR 1 of 1 1~=1so~ .WELLS V-2201 AND V-2231 ` ~ Alaska Department of Natural Resources Land Administration System Page 1 of 4 • See Township, Range, Section and Acreage? New Search 1 '` Yes ~` No ______ _ ._. _ _.-- t_ ?~ Mar~c~ (Case Abstract (Case I~etaii I Land Abstract File: ~U1, ?8240 Search for St,~t~3 s Plat Updates 1~ ~~f 02'I l ~(u)ti Custornec•: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 1 966 1 2/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 99~ 196612 Case Type: ;~~ OIL & GAS LF,ASE COMP DNR U~tit: 780 OIL AND GAS File Location: DOG DN OIL AN D GAS Case Statics: 35 ISSUED Status Dcrte: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Prirnac,h Responsibility: DOG D[V OlL AND GAS Last Ti°ccnsaction Date: (2/04/2006 Case Subtype : ~~ NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED tvleridian: U Township: O1 1 N l~crn,rr: [l ] 1 I ,5~ection: 01 S~ctinn Acc°es: 640 ~ 5oarct~ Plats Mt~l•rdian: U 7ownslti/~: O1 I N Ran,~c~: l) I ~ E 5'c~crr~ur~ 02 Secti~~n .I~~rc~~: 640 1L1~~ri~Ii~i~r: t' %uivcts/~i/~~ 01 I V` Rccn,~c: Ol lE 5'c~cJiuu~ ll Sectirnr :Ic~rt'e: 640 111E'rl(~~Ian: ~~ ~UlilL~'{7L~7: O ~ IN ~~cOl.~rE'.' ~) I LE .~~'~"llOn: 12 ,~eCt1UF1 : (CI"E'S: 64© Legal Description 0~ -28-196 * * *SALE NOTICE LEGA L DESCRIPTION* C1=1-19 DI1N-0IIE-UM1,2.11,122560.00 0~1-01-19?7 **UNITIZED,LEASEAND PARTICIPATING AREA LEGAL DESCRIPTION'~`* LEASE COMMITIF_D IN ENTIRETY TO PRUDHU~BA~UNITAND OTL RIRI ..GAS CAP PA PRUDHOE I3:4Y UNIT http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28240&... 2/11 /2008 ' Alaska Department of Natural Resources Land Administration System Page 2 of 4 • TIZc(CT S0 OIL RIR~I:9 ND GAS CAP PARTICIPATING ARE.-tS 7: 11 ~:. R. 11 E.. U.11/ f T aIERIDIA.~'. ALASK-~ SECTION 1: ALL, 6=I0.00 ACRES; SECTION ?: ALL, 6-J0.00 ACRES; SF_CTIO;'~' I I: ALL„ 6-J0.00 ACRES: SECTION I Z:.ALL. 6=10.00 ACRES; CONTAINING A PPRO_XI117ATELY 2, 560.00 AC RES, ~LIORE OR LESS. ;k#'Fx ~T:k>;:--;~x:kx~x x>;<~:k ~>,~~ <~c*x~#~k=k*~~kx~x*r,.*~Mx>;:#~k *>;:~;<*i: <;k ~k=k >k ~=~~k*~x;;~x ~ «~ 11-01-2001 * *FOR1LLtTION OF BORE11 LIS PARTICIPATING AREA I EGAL DESCRIPTION LEASE INCORPORATED IN PART INTO THE BPA ** PRUDHOE Bf1F UNIT BOREALIS PARI7CIPATING AREA TRACT ~ 0 (PARTI4L) T.11 _N. , R.11 E. , UMIA T MERIDIAN, ALAShA SECTION 1: TtJ2, tiV2E2. =180.00 ACRES; SEC.'TIO.~' Z: II I_, 6-10.00 ACRES; SECTION I I: N2, N2S2. -180. DO ACRES; SECTION 12: NWT, W2NE=1, 2=#0.00 ACRES; THIS TRACT CONTAINS 1.8=10.00 ACRES. MORE OR LESS. *> =k>k*~xy*T:*-*:~k#~..;k>g~;k~:*xxv*~k**=kxx~;k*~*=k##~k.k*~*x~~=k~~*x:k ~:~x;k~k~k=k~Y=kM~kx*A~k 02-01-200-1 ~ `kF'ORItiZATION OF ORLON PARTICIPATING AREA LEGAL DESCRIPTION* LEASE COM~1~fITTED IN PART TO ORLON PARTICIPATING AREA PIZUDHOE BAY' Li;VIT TRACT SD ORIOIV PARTICIPATING AREA T, II1V; R. II E., LIt7IAT1~IERIDIAN, AL:9SKA http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28240&... 2/11 /2008 " ~ Alaska Department of Natural Resources Land Administration System Page 3 of 4 • S'~CMON 1: ALL, 60.00 ACRES: SI'C'TIO;V ?::-ALL, 6-10.00 ACRES: SECTIO.~' 11: EL'2, Eli'',Vi~'L'-1, -100.00:-~C'RF_,S; SECTION 12: ALL, 6-10.00.~tCRES; CONT.9INING APPR(LYLL~1 TELY 2, 320.00 ACRES, ILIORE OR LESS'. ~~fi* <: >;<xxkm*:;<:kx~~M>; ~~**xx~~;k,:~~x~k ~k**x#~*fixx*=k**~*=k ;g ~kx~k ,: ~: x;ky* < <;g ~:<x:k ;: :k~ 12-01-200=1 ~ ~~ * *BOREALIS P_A EYPANDED, LEASE INCORPORATED IN PART'k * * * ~ ~` * ~` LEGAL DESCRIPTION IS AS FOLLOT~S.~ PRUDHOE 13AY UNIT 13OREALhS PARTKIPATING _AREA TIZ~ICT ~0 (P,=IRTIAL) T 11 N . R.11 E.. (JMIAT NIERIDI ~ N, .ALASKA SECTION 1: E ZE2, 160.00 _ACRES; SECTION U: SZSE=I. 80.00 ACRES: SECTION I2: S2, E2NEI, 100.00 ACRES, THIS' TRACT CONTAINS 6-10.00 ACRES. MORE OR LESS. *'~`THE ACREAGE NOW INCORPOI~~TED INTO THE I3PA IS DESCRIBED AS FOLLOWS: PR UDHOE BA Y UNIT BORF,ALIS PARTICIPATING ~I RF_A TRACT ~0 PARTIAL) T.11,~'., T.11E., UMIATNIERIDI.9N; ALASKA SECTION 1: ALL, 610.00 ACRES, SECTION ?: ALL, 6-10.00 ACRES: SECTION 11: N2, SE4, N2.SW'-1, X60 ACRES: SECTION 12::1I_L, 640.00 ACRES; http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28240&... 2/11 /2008 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) i 6050000 6000000 5950000 5900000 5850000 400000 500000 600000 700000 800000 • TRANSMITTAL LETTER CHECKLIST WELL NAME ~.e~~ Y~~3 PTD# o?D~'Oo?~?O Development / Service Exploratory Stratigraphic Test Non-Conventional Well a ~~ FIELD: ~~~,~ ~ ~ POOL: ~ D.~/D~ ~ODL . Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and .API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Companv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Companv Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 / 11 /2008 WELL PERMIT CHECKLIST Field & Pooi PRUDHOE BAY, ORION SCHR BLOIL -640135 Well Name: PRUDHOE BAY UN GRIN V-223 Program SER Well bore sag ^ PTD#:2080220 Company BP EXPLORATION (_ALASKA) IN Initial ClasslType SER ! PEND GeoArea 890 Unit 11650 OnlOff Share .~_ Annular Disposal ^ Administration 1 Petroitfeeattached --- -- --- --- - -- --- --- --- ~ -------- --- - - - -------- ---- --- --- - -- -- - --- 2 Lease number appropriate - ---- ---- ---- -- - - ---- -Yes --- - -- - --- -- --- ---- - - -- -- - -- - - 3 Uniqueweilnameandnumber---- ---- - -- -- - - -- --_ Yes- -- --- -- -- - -- -- ----- -- - - - - -- 4 -Wfllll°catadina_definad~ool------ ---- --- -- --- -- Yes --- --- -- --- --- ---- ---- ----- --- -- ---- --- ! 5 _Welllacatedproperdistan4etromdrillingunitboundary------------- ---------Yes- ---------------.-------------------------- -- -- - - ---- - -- 6 Well located proper distance iromotherWells- - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 SufFiciQnt acreage available in-dtiU- - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 8 ffdeviated,is.Wellboreplatincluded-------- -- - -- -- - ---- Yes- --- ---- ----- -- - ---- ---- --- --- -- ----- -- --------- 9 Oper-atoronlyaf[eciedDarU'---~ -- -- --- - -- -- - -- ---- Yea- - ---- ---- --- - --- --- ----- -- -- - -- -- ------- ~~ 10 0peratorbaa-appropriate bond in force_---____--_---------- ---------Yes- ------Blanket@ond#619415$--_---------------------------------------- ---- 11 Permitcanbeiasuedwithoutconservatlonorder__________________ _____ ___Yes- -------------------------------------------- - - -- ----- -- - ---- Appr Date 12 Petmitcanbeiasuedwlthouladministrativa_approval---------------- ---------Yes- ------------------------------,------------- --- --- - ------- 13 Cen permit-be apRroveti before 15-day-Wait- - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ACS 2111!2008 14 _WelUocated Within area and_strata authorized by Injection p_rder # (put IQ# in-commend)-(For_ Yes _ - _ _ _ _ _ AIO-26A- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 All wells_within 1(4_mile atea_of review kkntified (for service wep only) - - - - - - - - - - - - - - Yes - _ - _ . - _ _ - - - _ _ _ - _ - - - - - 18 Ple•producedin)actor. duration ofpraproductionlessthan3montha-(For service vrelioniy).-_NA- --------------_---.----__----.---__.-_--._---_-----------.------------- 17 _Nonconven,gas-rAnfortna to AS31,05A30Q,1,A),(l•2•A-C) - - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 Conductorsttlng-pravJded--- ----- -- - ------- ---- ----- vas. ----- -- -- -- ---- ---- ---- --- --- -- -- - --- ----- -- 19 SurfacecasingprotectgallknoWnUSD1Ns-_-_----._--__------ ----------N~- ----__Allaquifersexempked,40CFR-147,102(b)(3)andAEQ1.--------------------------------- 20 CMTvoladequate_tocitcul~teon_conductcr8,surf-csg--------------- ---------Yes- -.-----------------.-------------------- ---- -- - - --- - --- --- 21 CMTvoladequate_totie•inlongsiringtosurfcsg -- -- --- --No --- -- -- - -- --- ----- -------- --- ----- -- --- 22 CMT_Willcover-all knawn~roductiveborizons____--___----_---- _-_------Yes- ------------------------------------- ---- -- - - -- - -- -- - 23 CasingdesgnsadequateforC,LB&permafrost----------------- -----__--Yes- ----------------------------------------- -- - -- -- - -- ----- 24 Adequate iankaga_or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - - _ - - -Rig equipped with steel pits. No.reserve pit planned.- All waste_to approved disposal well(s), - _ - _ _ - - - _ - _ _ 25 Ifa_re•ddlGhas_a10~40~farabandonmentbeenaRRroved------------- ---------~-- ----------------- - - --- ---- ---- --- - - -- ---- -- - -- 26 Adaquete_Welibote separatlonl~roposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ - - - _ - _ Proximity analysis performed, Traveling cylinder path calculated, Gyros likely_in surface hole, _ _ _ _ _ - _ - - - 27 Ifidiverter_requited,doesRmeetregulations- -- - --- -- - - -- ---- Yes- -- --- -- ---- - ---- -- --- --- -- -- ----- - -- -- Appr Date 28 Drilling fluid-program schematic & equip list adaquate- - - - - - - - - - - - - - - - - -- - - - - - - Yes - - _ _ - - -Maximum expected formation pressure 8.6_- 8,7 EMW, Planned MVy 9.2 - 9,5.PPG in zone. - - _ _ - _ - _ - _ - _ - M 2!1112008 TE 29 BOPEs,.dotheymeetregulation._-_--__---__---_------ ---------Yes- ---------------------------------------- ---- -- --- - - --- - d ~[D ,~IV~ 30 BOP):_prsss rating appropriate; test to-(put psig in comments)- - - - - - - - - - - - - - - - - - --Yes _ _ . _ _ _ _ MASP calculated at 1fl3Qpsi, 4000_psi_BOP testptoposed.. _ - _ - _ - _ - - - _ - - - _ - - - - - - - _ - - - - _ - - - - Y ` 31 Choke_roanifoldcomRliesWlAPI-RP•53fMay334) -- -- --- --- ---Yes --- --- - -- - - --- ---- - - ----- -- - --- ---- -- --- 32 .Vt~QrkWIl19QC9rWIth9UtQperatlOn9hlltdQWn---- --- --- ---- ---- - YBS ----- -- - - -- -- - --- ---- --- ---- -- --- --- 33 Is presence of H2S gas probable- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Ko_ _ _ _ _ _ - . H2S not expected in_SB, but-is presenton V pad. Mud shauld_preclude H2S on rig. Riq has sens9rs & alarms,_ _ 34 -Mecbanicalcondldon of Walls Within AQR verified (For seNice well onlya _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - - _ - _ No penetrations Info SB_Witbin 114 mile._ Soma weil.segmenis exsi in reservoir within-1!4 milfl. _No_ issues. _ - _ - - Geology A 35 Permitcan be issued wlo hydrogen subida meassrres - - - - - -- - - - - - - - - - - - - - - - - - - ~-o- - - - - - - - H2S ~vels: Y-01=75_ppm; V-204=60 ppm; V-117=300ppm. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - U' 36 _D~ka-p~sentedonRofential°verpressurezenes- --- ---- -- - ---- ---~ ---- - - -- --- -- ----- --- ---- - - --- --- -- - - --- Appr Date 37 SeismlcanalysisoPshallowgas_zonas------------------------- ----------~- --------------- .-- ACS 2111!2008 38 Seabed_conditionsurvey-(ifoR-shore)------------------------ ----------hLA-- ------------------- - 39 ContactnamelphoneforWeeidy-Prrtgressreports_~exploratoryonry]-------- ----- ---Yes- ------AmandaRebol~554~5543__---_--_---_-_---------------------- --- --- Geologic Engineering P Date Date: ' Daie Commissioner: miss ssioner• Co ~'~. z-,z-~ a -~z • o ~