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208-020
MEMORANDUM 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-220 PRUDHOE BAY UN ORIN V-220 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/15/2024 V-220 50-029-23383-00-00 208-020-0 G SPT 4400 2080200 1500 1705 1709 1703 1703 386 404 406 407 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-220 Inspection Date: Tubing OA Packer Depth 0 2510 2444 2430IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB240707131512 BBL Pumped:3.4 BBL Returned:2.4 Thursday, August 15, 2024 Page 1 of 1 9 9 9 9 9 9 99 9 9 9 99 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.08.16 15:08:35 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 8/13/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240813 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 222-24 50283201800000 22Ϭ043 8/1/2024 AK E-LINE CIBP BRU 222-26 50283201950000 224035 7/21/2024 AK E-LINE Plug BRU 232-04 50283100230000 162037 7/25/2024 AK E-LINE Perf BRU 241-26 50283201970000 224068 7/24/2024 AK E-LINE CBL BRU 241-26 50283201970000 224068 7/31/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/10/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/18/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/23/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/28/2024 AK E-LINE Hoist IRU 44-36 50283200890000 193022 8/3/2024 AK E-LINE CBL IRU 44-36 50283200890000 193022 7/31/2024 AK E-LINE CIBP IRU 44-36 50283200890000 193022 7/29/2024 AK E-LINE RCT MPU I-01 50029220650000 190090 7/20/2024 AK E-LINE CBL MRU M-02 50733203890000 187061 7/20/2024 AK E-LINE Plug PBU PTM P1-08A 50029223840100 202199 7/23/2024 AK E-LINE CBL PBU V-220 50029233830000 208020 6/28/2024 READ InjectionProfileAnalysis PTU DW-01 50089200320000 214206 7/16/2024 READ CaliperSurvey PTU DW-0ϭ 50089200320000 214206 7/17/2024 READ TemperatureSurvey Please include current contact information if different from above. T39418 T39419 T39420 T39421 T39421 T39422 T39422 T39422 T39422 T39423 T39423 T39423 T39424 T39425 T39426 T39427 T39428 T39428 PBU V-220 50029233830000 208020 6/28/2024 READ InjectionProfileAnalysis Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.13 13:58:22 -08'00' Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024V-220 208020 500292338300 4 1/1/2024 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU V-220 Patch Tubing Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-020 50-029-23383-00-00 8180 Conductor Surface Intermediate Production Liner 5114 80 4149 8147 7920 20" 9-5/8" 7" 4919 30 - 110 29 - 4178 27 - 8174 30 - 110 29 - 2853 27 - 5109 None 3090 5410 7920 5750 7240 7218 - 7858 3-1/2" 9.2# L-80 24 - 7943 4432 - 4874 Structural 3-1/2" HES Dual Feedthru Packer 7376, 4537/ 7487, 4613 / 7568, 4668 / 7720, 4775 / 7819, 4846 7169, 7376, 7487, 7568, 7720, 7819 4400, 4537, 4613, 4668, 4775, 4846 Stan Golis Sr. Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY, Schrader Bluff Oil, Orion Development Area Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028240 24 - 4936 N/A N/A 2579 1633 0 375 1047 543 322-720 13b. Pools active after work:Schrader Bluff Oil, Orion Development Area 3-1/2" HES Single Feedthru Packers 7169, 4400 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Samantha Carlisle at 10:13 am, Mar 21, 2023 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2023.03.20 18:16:58 -08'00' Stan Golis (880) Sundry Number PBU V-220 WCB 11-27-2023 Patch TubingRepair Well 322-720 PRUDHOE BAY, Schrader Bluff Oil, Orion Development Area 208-020 DSR-3/22/23 RBDMS JSB 032123 ACTIVITY DATE SUMMARY 3/3/2023 T/I/O 400/0/275 Temp S/I (TFS unit 4 assist SL with WFR changeout) Pumped 2 bbls of 60/40 for a spacer then pumped 83 bbls of DSL for a Brush and flush for SL. Pressured and Bled of TBG as needed. ********WSR Continued on 3/4/23******** 3/3/2023 ***WELL S/I ON ARRIVAL*** ENCOUNTERED HARD SCHMOO @ 7899' SLM. BRUSHED & FLUSHED / GAUGED TBG 2.74" TO 7899' SLM. BAILED SCHMOO FROM 7899' SLM TO 7904' SLM. RAN 3 1/2" GR & EQ PRONG, JAR ON RED SPYDER @ 7,920' MD. (sheared gr) GO ON WEATHER STBY -44 ***CONTINUE 3/4/23*** 3/4/2023 ***CONTINUE FROM 3.3/23*** CONTINUE WEATHER STBY -42 PULL 3 1/2" RED SYDER @ 7,920' MD BRUSH & FLUSH W/ THUNDERBIRD PUMPED 160 BBLS OF DIESEL RUN 2.50" CENT. 1-3/4" SAMPLE BAILER S/D @ 7,927' SLM (recovered 2 cups of fill) ***CONTINUE ON 3/5/23*** 3/4/2023 ***WSR Continued from 2/3/2023*** (TFS unit 4 assist SL with WFR Changeout) Pumped 161 bbls of DSL down TBG for Slick line (brush and flush). ***WSR Continued on 2/5/2023***** 3/5/2023 ***CONTINUE FROM 3/4/23*** SET 3 1/2" RMXN BODY @ 7,920' MD RAN 3 1/2" CHECK SET, S/D IN STA. # 2, UNABLE TO WORK PAST RAN KJ, 2.77" CENT. 2' X 1 7/8" STEM, 2.75" CENT. 3 1/2" CHECK SET S/D @ 7,920' MD (good set) SET RMX PRONG W/ MF-WFR IN RMXN PLUG BODY @ 7920' MD. RAN READ CALIPER FROM 7893' SLM TO SURFACE PULL RK- AL-WFR FROM STA.# 10 @ 7,327' MD SET RK-DGLV IN STA.# 10 @ 7,327' MD PUMP 1 BPM FOR 5 MINUTES, STABLE @ 950 PSI SET 3 1/2" X-SELECTIVE TEST TOOL @ 7,503' MD PUMP 1 BPM FOR 5 MINUTES, STABLE @ 1550 PSI ***CONTINUE 5/6/23*** 3/5/2023 *********WSR contunued from 3/5/2023*********** (TFS Unit 4 Assist SL with WFR changeout) Pumped 27 bbls of DSL down TBG to assist SL making target depth. Pumped 122 bbls of DSL down the TBG to assist SL with setting valves. *********WSR continued on 3/6/2023******** 3/6/2023 *******WSR continued from 3/5/2023********* (TFS unit 4 assist SL with WFR changeout) Pumped 40 bbls of DSL down TBG to assist SL with LDL. Further Pumped 164 bbls of DSL down TBG to Assist SL with Setting St#10. ***WSR Continued on 3/07/2023**** Daily Report of Well Operations PBU V-220 ( Pumped 40 bbls of DSL down TBG to assist SL with LDL Daily Report of Well Operations PBU V-220 3/6/2023 ***CONTINUE FROM 3/5/23*** MAKE 2 PASSES @ 80 FPM W/ READ LDL (SEE LOG FOR DETAILS) PULL STA.# 10 RK-DGLV @ 7,327' MD MAKE SEVERAL ATTEMPT TO SET STA.# 10 RK-WFR @ 7,327' MD SET STA.# 10 @ 7,327' MD, TG-WFR (11/64", .125 spacer, 305 BWPD) ***CONTINUE 3/7/23*** ***Note possible latch profile damage in st# 10*** 3/7/2023 ***WSR Continued from 03/06/2023*** (TFS Unit 4 Assist SL with WFR Change out) Pumped 65 bbls of DSL down TBG to Assist SL with WFR Change out. SL in control of well upon TFS Departure Final WHPS 675/0/250 3/7/2023 ***CONTINUE FROM 3/6/23*** PULL 3 1/2" X-SELECTIVE TEST TOOL @ 7,503' MD DRIFT TO 7,850' SLM W/ 20' X 2.78" PATCH DRIFT. ***WELL S/I ON DEPARTURE*** 3/12/2023 ***WELL SHUT IN ON ARRIVAL*** (PATCH SET) MIRU E-LINE PT PCE 300 PSI LOW, 2000 PSI HIGH SET OWENS X-SPAN SPC-3500-004 3.5" PATCH FROM 7463.3' - 7485'. (Min ID= 2.330") CCL TO TOP ELEMENT = 10.3', CCL STOP AT 7453.0'. RDMO E-LINE ***WELL SHUT IN ON DEPARTURE*** JOB COMPLETE (PATCH SET) MIRU E-LINE SET OWENS X-SPAN SPC-3500-004 3.5" PATCH FROM 7463.3' - 7485'. The patch is shown correctly on the new WBS, below. -WCB 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU V-220 Patch Tubing Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-020 50-029-23383-00-00 505B ADL 0028240 8180 Conductor Surface Intermediate Production Liner 5114 80 4149 8147 8089 20" 9-5/8" 7" 5045 30 - 110 29 - 4178 27 - 8174 30 - 110 29 - 2853 27 - 5109 None 3090 5410 None 5750 7240 7218 - 7858 3-1/2" 9.2# L-80 24 - 79434432 - 4874 Structural 3-1/2" HES Dual Feedthru Packer 3-1/2" HES Single Feedthru Packers 7169, 4400 7376, 4537/ 7487, 4613 / 7568, 4668 / 7720, 4775 / 7819, 4846 Date: Stan Golis Sr. Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY 1/6/2023 Current Pools: SCHRADER BLUFF OIL, ORION DEV AREA Proposed Pools: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 2030 By Anne Prysunka at 8:48 am, Dec 23, 2022 322-720 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2022.12.22 17:30:01 -09'00' Stan Golis (880) DLB 12/23/2022 2030 X 10-404 MGR27DEC22 '65GCW 01/04/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.01.04 16:11:42 -09'00' RBDMS JSB 010523 V-220 Patch St8 Well Name:V-220 Date:12-22-22 Current Status:Operable WAG Injector API Number:50-029-23383-00-00 First Call Engineer:David “Brodie” Wages 713.380.9836 (M) Second Call Engineer:Claire Mayfield 713.443.3631 PTD Number:208-020 Min ID:2.725” XN @ 7920’ MIT-IA:2082 psi on 7/3/20 Last TT tag:12/21/2022: Slickline diagnose hole BHT:~90 degF Est BHP:2480 psi (water column to last injection pressure) MPSP:2030 psi (0.1 psi/ft gas gradient to surface) Wellbore Fluids:Diesel 70 deg dev @:N/A’ Max Dev:62 deg @ 4000’ Current Inj Rates: Shut In Brief Well Summary/Discussion While working up a new WFRV design, slickline found a hole very near St8 07/01/08 pull B&R,dummy shear valve, MIT-IA, set PXN, MIT-T set live valves in 2, 4, 6, 8 w/ passing step rate test first try 06/16/09 pull prong, B&F, pull 2, 4, 6, 8 and set dummys in same, MIT-T flowsleeve in 1 (problems with 2) 06/30/09 obtain DH samples, pull 1 FS, set dummy in 1, MIT-T set test tool below 4, pull dmy from 4, set WFRV in 4 in 2 tries, move test tool up pull 6 dmy, set live WFRV, passing step rate test, move test tool up pull 8 dmy, set live WFRV, passing step rate after resetting 8 had to bail fill off x-test tool, moved test tool up pull 10 dmy, install WFRV, passing step rate, pull test tool, wellbore passing step rate 10/05/09 Eline WFL shows 23% in 10 18% into 8 40% into 6 19% into 4 0into 2 12/08/09 set MCX 05/16/10 pull MCX, B&F, IPROF, set MCX IPROF @ 3mmscfd MI: 25% into 10 10% into 8 45% into 6 15% into 4 5% into 2 similar to IPROF on water 08/26/10 Pull MCX, B&F, set dummies in 2, 4, 6, 8, 10. MIT-T fail, 8 popped out of pocket, reset 8, MIT-T pass V-220 Patch St8 set WFRV in 1, passing SRT set WFRV in 2, passing SRT set WFRVs in 4, 6, 8 with passing SRTs in between 04/01/11 lots of schmoo/asphaltenes, several days to open up B&F through St#1 FS set Reset WFRVs in 1, 10, 8, 6, 4, 2 Station Sized Rate % of total IPROF Rate% 10 320 20%11 8 160 10%15 6 450 27%59 4 160 10%15 2 445 27%0 1 105 6%0 Total 1640 100 08/03/11 Bail to 1, set flowsleeve, B&F, set dummy in 1 replace WFRVs in 10,8, 6, 4, 2, lots of bailing on pulling catcher 01/02/12 LOTS of bailing to get catcher set FS 1, B&F, reset 2 05/16/12 Set MCX 08/14/12 Pull MCX< bail runs, several tries to pull 1, dummied all valves MIT-T pass install WFRVs in 1, 2, 4, 6, 8, 10, set MCX after decent SRT 01/03/13 pull MCX 02/03/13 bailed, job canceled 06/26/13 bailed, latched up on PXN prong and parted wire, took until 11/20 to get all the wire out in spurts 11/21/13 reset 1, 2, 4, 6, 8, 10 with good step rate test 09/26/14 bailed, pull prong and, B&F w/ SBG, set RMX with prong St 1 out of pocket. Unable to pull 2 or set down in pocket pulled and dummied 10, 8, couldn't find 8, pulled catcher and found 1, dummied 1, pulled catcher and found 8 and dumy valve pulled 6, 7, 4 and set dummies in same, passing MIT-T install WFRV in 8, 1, 4, 6, 10, 2 04/04/15 bailed to RMX prong and pulled, B&F then reset prong, failed SRT, set MCX 01/31/16 pulled MCX, pulled prong without bailing, B&F set prong in RMX, pulled and reset 6, no valve in 2, set valve in 2. Pulled and reset 10, 1, 4, 8 good SRT, pulled catcher after bailing, set MCX 06/26/17 Pulled MCX, bailed to prong, pull MRX prong, B&F dummy 2 in 2 tries, dummy 1, 10, 2 (again), 6, 4, 8 MIT-T set WFRVs in 4, 6, 10, 1, 2 with passing SRT, bail to get catcher out 11/20/18 bailed to RMX prong in three days, pull prong, B&F, set prong pulled 1 and reset WFRV, pulled 2 and reset WFRV, failing SRT hole hunt with test tool, set dummy in 2, passing SRT set live WFRV in 2, failed SRT, reset again, fail SRT V-220 Patch St8 set dummy in 2, pulled 3, set live in 3, fail SRT, reset 3, passing SRT 11/18/19 pulled MCX, 5 days of baling to get to RMX prong, pull prong, B&F, set prong reset 4 to get passing SRT in stations 4 and above 08/31/22 tag @ 7865', bailed 2 days, pull RMX prong, B&F tubing clean, set dummy prong set catcher, pull 3 wfrv, set dmy in 3, pull 10 wfrv, set dmy in 10, pull 6 wfrv, set dmy in 6, pull 1 wfrv, set dmy, pull 4 wfrv, set dmy in 4 PT well to 1000 psi, pass set 305 bpd wfrv in 8, gutted in 4, 5, 1, 2, 3, attempt to pull catcher, fill, bail, day later got it out, bail to RMX prong, pull, B&F wellbore again set gutted wfrv in RMX prong, bleed pressure back, st4 and 5 didn't respond, troubleshoot for days, get holefinder stuck and fished, check or valve out of pocket above lowest packer 11/13/22 pulled and ran gutted WFRVs in lower zones per program, found hole at st8 (b/w 7453’ and 7442’) Procedure: Slickline work is complete, we only need to patch St 8 at this point Eline: 1.MU Baker one trip patch w/ 20-30’ spacer pipe 2.RIH and set patch per tubing tally to cover hole a.Slickline identify hole 7453’ – 7442’, right at the top of St 8 mandrel b.Set patch ~ 7464’ – 7484’ ME - ME 3.Perform drawdown test to confirm patch and valves are holding 4.RDMO Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Tubing Tally 4. Sundry Change form V-220 Patch St8 Current Wellbore Schematic: V-220 Patch St8 Proposed Wellbore Schematic: V-220 Patch St8 Tubing Tally: Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: December 22, 2022Subject: Changes to Approved Sundry Procedure for Well V-220Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim RDATE: Wednesday, July 29, 2020 per I , P.I. Supervisor �1 ` SUBJECT: Mechanical Integrity Tests ` Hilcorp North Slope, LLC V-220 FROM: Jeff Jones PRUDHOE BAY UN ORIN V-220 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry BP -- NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-220 API Well Number 50-029-23383-00-00 Inspector Name: Jeff Jones Permit Number: 208-020-0 Inspection Date: 7/3/2020 ✓ Insp Num: mitJJ200720110223 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-220 Type Inj I W TVD 4400 Tubing 1317 1322 - 1315 1317 PTD 2080200 Type Test SPT Test psi 1500 IA 63 2200 2104 2082 - BBL Pumped: 2 BBL Returned: 2 OA 480 - 504 507 508 " Interval 4YRTST P/F P Notes: I well inspected, no excptions noted. Wednesday, July 29, 2020 Page I of I 41/ • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,July 13,2016 TO: Jim Regg I�q 7/ 41i/1w P.I.Supervisor tSUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC, V-220 FROM: Bob Noble PRUDHOE BAY UN ORIN V-220 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry L1612- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-220 API Well Number 50-029-23383-00-00 Inspector Name: Bob Noble Permit Number: 208-020-0 Inspection Date: 7/8/2016 Insp Num: mitRCN160708160730 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-220 Type Inj W'ITVD 4400 • Tubing 1481 1490 ' 1490 - 1491 PTD 2080200 Type Test SPT Test psi 1500 IA 21 2496 . 2433 " 2416 Interval 4YRTST P/' P ✓ OA 393 418 " 410 - 400 - Notes: NOV 2 2Z016 Wednesday,July 13,2016 Page 1 of 1 04/28/11 Scldumberger 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 .y Date BL Color CD 15 -09A BBKA -00096 PRODUCTION PROFILE 1 4 1 1 3 ^ (Tf yy( 03/14/11 1 - Ro O 1 17 -06 BBKA -00094 INJECTION PROFILE O j 2 ( rS - [ a 03/10/11 1 t ' 1 , C -12B BAUJ -00064 MEM PRODUCTION PROFILE e 03/08111 1 s a , VI 1 G -238 BLPO -00079 MEM PRODUCTION PROFILE Q — (L 1 03/09/11 1 0'.. 1 16 -O8A BJGT -00022 GLS / 9 9 - f 96, 03/07/11 1 g "5` 1 02 -18B BLPO -00087 MEM CBL ' • _— 03/25/11 _ .4 '1(. 1 1 J -22A BJGT -00023 EIMIllakite MillEgirlintErlIM 1 1-210 BLP0-00086 MEM INJECTION PROFILE ' • ^ 03/23/11 1 D r e' , 1 V -105 BLP0 -00091 MEM INJECTION PROFILE y _ 03/29/11 1 �y 1 � . V -220 BBSK -00065 11�ItIX91U.71 1: ]tll>AyJdl U dt� SiJafiriV. • — • 04/11/11 1 F 1 V-212 8D88.00096 ' ' N C aN PROF LE • 04/03/11 1 " 1 • 1-214A BCRJ -00073 INJECTION PROFILE e < 1 03/18/11 1 - 1 V -223 BAUJ -00071 MEM INJECTION PROFILE ;• e� ' G�j 1 V -217 BAUJ -00077 MEM 1NJECTI•N PROFILE :7 ' :FilIilr 1 3- 05/0 -29 BG4H -00043 11311111MVk ' ' TA -i 1 1- 47A/M -20 BLPO -00092 MEM PRODUCTION PROFILE J " TIGazeY.' ' ' e+!TeTtgl, 1 1- 25A/K -22 BBSK -00057 [.1 -] " � MILVIMINENINII 1 S-01C BCUE -00113 ESIMEEIM3[:SLBLr II•111111•111•111•11•1•MiCIIIIIIINNI 1 11 -30 BD88 -00097 MEM INJECTION PROFILE ` L j �� - MIRIN ' e ME 1 04 -11A AWJI -00134 INJECTION PROFILE OY.(r n r .—j9 03/24/11 1 ` 1 P2 -41 BG4H -00044 PRODUCTION PROFILE — _.♦ •.— 03/22/11 1 !_ & 1 D -268 BM �Z,- ' SA -00009 � ' -• l TNINgim 1 02 -18B BLPO -00087 MEM PRODUCTION PROFILE - AL IIMEZIMMINNIIMPZIW -1 1 Z -20 8P50 -00010 • 03/29/11 1I.71r�1 1 Y -29A BCUE -00122 MEM LDL ` G} 6, ,— o1 / 03/20/11 1 1)." _ 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503.2838 • • '01'1 u Schlumherger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job M os/Den o N0.5538 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD E-05B V•220 E-09C D-13A 09-44A 09-44AP61 17-12A BD88-00015 BCUE-00019 A%BD-00062 BBUO-D0008 10AKA0043 10AKA0043 09AKA0079 MEM PROD PROFILE MEM INJECTION PROFI MCNL - RST OH MWDA.WD EDIT OH MWDA.WD EDIT - ~ OH MWD/LWD EDIT 05/20/10 05/16/10 11/20/09 03/09/10 03/09/10 03/08/10 03/10/10 1 1 1 1 t 2 2 1 1 1 1 1 1 1 PLEASE ACKNOWLEDGE REC EtDT Rv clr;nllu r. eun ocn inwur_ nr.,~ .•n.~.. ~...., ~... BP Exploration (Alaska) Inn. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2839 i • C /`-- c~::.y _ '~.°: ~ .~ W ~ ~~ °~~:e ~,~~~~.~ A +~r.+'T'!Fi~&R R:+A dI ~-t5 ~~~rd,A!.P~C'S:. ~A~.A1 PAr 90.Itl+~A4.#~ 1~1iC~1f9(d~i1~f DATA SUBMITTAL COMPLIANCE REPORT 1/28/2010 Permit to Drill 2080200 Well Name/No. PRUDHOE BAY UN ORIN V-220 Operator BP EXPLORATION (ALASFC/~ INC API No. 50-029-23383-00-00 MD 8180 TVD 5114 Completion Date 3/11/2008 Completion Status WAGIN Current Status WAGIN UIC Y REQUIRED INFORMATION L/y., Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, NEU, Azimuthal Density, PWD, LWD (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / r y meairrmi rvumoer ryamg al:dle a~eu~a rvo arart atop a.n rtecervea a.vmmenr D _ C Asc Directional Survey 0 800 Open 3/14/2008 t Directional Survey 0 800 Open 3/14/2008 D D Asc Directional Survey 0 8180 Open 3/17/2008 I Dir ctional Survey 0 103 8180 8020 Open C 3/17/2008 4/10/2008 LIS V i CCL USIT D C Lis 16103 onic ase er , , Log Sonic 5 Col 105 8030 Case 4/10/2008 USIT, GR, CBL, GPIT, CCL 7-Mar-2008 ED C Pds 16114' Sonic 105 8030 Case 4/10/2008 USIT, GR, CBL, GPIT, ~' CCL 7-Mar-2008 'ED C Lis 1630 Induction/Resistivity 100 8183 Open 5/23/2008 LIS Veri, GR, FET, ROP, RPM, RAM, DRHO, NPHI, TRPM og Induction/Resistivity 25 Blu 108 8139 Open 5/23/2008 TVD Vision Service Log Induction/Resistivity 25 Blu 108 8139 Open 5/23/2008 MD Vision Service Log See Notes 2 Col 0 7911 Case 7/6/2009 Fluid Interface, MPL, Pres, CCL, GR, FCAP, Temp 30- Jun-2009 ED C Las ~ ~~ 18221 ~iSee Notes 3 7912 Case 7/6/2009 Fluid Interface, Temp, GR, CCL, Pres og Injection Profile 5 Blu 7040 7868 Case 11/6/2009 Injection Pro, RST WFL 4- Oct-2009 • DATA SUBMITTAL COMPLIANCE REPORT 1 /28/2010 Permit to Drill 2080200 Well Name/No. PRUDHOE BAY UN ORIN V-220 Operator BP EXPLORATION (ALASKIy INC API No. 50-029-23383-00-00 ~MD~8180 TVD 5114 Completion Date 3/11/2008 Completion Status WAGIN Current Status WAGIN UIC Y iED C Pds 913 Injection Profile 7040 7868 Case 11/6/2009 Injection Pro, RST WFL 4- Oct-2009 WeII CoreslSamples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORM,,rA--T~~ION ~, Well Cored? YY,~yi Daily History Received? '"'~~'N Chips Received? ~Y-tid-- Formation Tops U' N Analysis.-~-- Received? i Comments: Date: Compliance Reviewed By: ~L • aiasRa vn a uas cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken A77N: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD MPI-13 AWJI-00055 SCMT 10/18/09 1 1 MPC-07 AXED-00057 MEM PROD PROFILE - 10/24/09 1 1 04-11A AWLS-00040 INJECTION PROFILE - 10/24/09 1 1 V-220 L-220 AYS4-00100 B1JJ-00035 INJECTION PROFILE T - MEM INJ PROFILE REVISED Z. .- 10/04/09 07/30/09 1 1 1 1 V-221 AXBD-00037 MEM INJ PROFILE REVISED ~C a~-.b/ ~~ 07/28/09 1 1 L-214A S-226 AP3O-00064 AYTU-00052 INJ PROFILE/RST INJECTION PROFILE - 10/06/09 10/27/09 1 1 1 1 14-07 07-OS R-28 2-OS/K-16 PSI-05 8581-00016 AYS4-00105 AWLS-00041 AZCM-00046 6148-00080 PROD PROFILE ~ SCMT USIT _ PRODUCTION PROFILE / - TEMP WARMBACK SURVEY 03 " 10/27/09 10/28/09 10/26/09 10/30/09 11/03/09 1 1 1 1 1 1 .. 1 1 1 1 C-12B 62WY-00030 MCNL ~ 09/19!09 1 1 U-05A 09AKA0074 OH MWD/LWD EDIT T -Q 08/19/09 2 1 01-18A 09AKA0151 OH MWD/LWD EDIT _ 08/27/09 4 1 H-09 ANHY-00110 RST '~ ~71a - / 09/20/09 1 PLEASE ACKNAWI Fr)[;F REC EIPT AV Clr:nllnl n euln ocTUOwuw~r nw~c rnov ~wnu T.,. BP Exploration (Alaska) Inc. Petrotechnical Data Center 1.R2-1 900 E. Benson Blvd. r~ Alaska Data & Consulting Services 2525 Gambell Street, SuAe 400 Anchorage, AK 99503-2838 ~. ,: ... , i ', f ~ ~ ~ I I ~_ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 by ~EGEIVEt~ OCT Q ~ 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, Aledca Oil & Gas Coos. CalttmiR~ion Anchorage adg-8~ ~~~_ ~~,® 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 t3.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-tt9 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 ~ 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 MEM®IaAI~TDLTM ~ State of Alaska Alaska OiI and Gas Conservation Commission DATE: Wednesday, July 23, 2008 To: Jim Re gg v~i ~~~ SUBJECT: Mechanical Integrity Tests P.I. Supervisor ~ ~~y CC BP EXPLORATION (ALASKA) INC V-220 FROM: Chuck Scheve PRUDHOE BAY UN ORIN V-220 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name PRUDHOE BAY UN ORIN V-220 Insp Num: mitCS08072106123s Rel Insp Num: API Well Number: SO-029-23383-00-00 Permit Number: 208-020-o Inspector Name: Chuck Scheve Inspection Date: ~il9izoo8 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well V-z20 Type Inj. ~' TVD aaoo IA X60 2ozo 1960 1960 ~ p.T, zosozoo TypeTest SPT Test psi ~ Isoo pA I6o ~ 3zo soo sao Interval ~T~- P/F P Tubing i6so I6so I6so I6so ~ Notes: Wednesday, July 23, 2008 Page 1 of 1 Page 1 of 1 ~. Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, July 21, 2008 11:40 AM To: Saltmarsh, Arthur C (DOA) Subject: PBU V-220 / PTD # 208-020 Hi Art, Please reference the following well: We(I Name: PBU V-220 Permit #: 208-020 API #: 50-029-23383-00-00 Top Perf MD: 7214' Bottom Perf MD: 7854' This well began Injection on July 4, 2008 Method of Operations is: Produced Water Na well test data for Injection Wells 7/22/2008 RE: V-220 (PTD #2080200) Post-initial Injection MIT-IA Page 1 of 1 Regg, James B (DOA) f J !~ ~g--pZG From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, July 18, 2008 7:36 AM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA} f Cc: Engel, Harry R; NSU, ADW Well Operations Supervisor ~~~ 71 ~e ~~`~ Subject: RE: V-220 (PTD #2080200) Post-initial Injection MIT-IA Jim, Thank you for the consideration on this well. Per your request, we plan to perform the MIT-IA on Saturday morning. The AOGCC slope inspector has been notified. Thank you, Andrea Hughes From: NSU, ADW Well Integrity Engineer Sent: Thursday, July 17, 2008 2:55 PM To: 'Regg, James B (DOA)' Cc: NSU, ADW Well Integrity Engineer; Engel, Harry R; NSU, ADW Well Operations Supervisor Subject: V-220 (PTD #2080200) Post-initial Injection MIT-IA Jim, This is a follow-up request to postpone the initial MIT-IA for well V-220 (PTD #2080200). V-220 was put on produced water injection on 07/04/08 after the completion of an injectivity test. Because of the proximity of 9ES drilling grassroots well V-207, we are unable to access V-220 for the initial MIT-IA. The completion of V-207 is expected to be -3 weeks from now at which time we will gain access to V-220. We are requesting that continued injection occur until this time. I have attached a TIO plot and injection plot for your reference. In addition, 1 have attached a copy of the injectivity test job log. During the injectivity test, the tubing pressure reached 2,000 psi while the IA pressure did not exceed 220 psi. We expect that the current IA pressure is due to thermal effects given the IA fluid level is at the surface. Please contact me with questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 7/18/2008 FW: V-220 (PTD #2080200) P,gst-initial Injection MIT-IA Regg, James B (DOA) Page 1 of 1 From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, July 17, 2008 3:04 PM To: Regg, James B (DOA) ~ Subject: FW: V-220 (PTD #2080200) Post-initial Injection MIT-IA Attachments: V-220 TIO and Injection Plot.doc; V-220 Injectivity Test.tif Jim, I forgot to mention that the Operator bled the IA pressure of V-220 late yes#erday to 900 psi. It took four minutes #o bleed and was all liquid. I can send afollow-up TIO plot in a few days if you would like. ~ p~ Thank you, ~,~ ~~~ ~nc~3'ea. ~~s ~P~) G~- (Wrec~~'4~ C.%~c~lzx-. ' ~j ~~-} a,~ ~l ~~ ~ ~ (eel ~.1 Andrea Hughes Pr~ssu~es ~ ~3t-~ ~'-zee 7 ~W~,'(e ~~((a~ ~ ~~~ IB zzc`~~ (~+..e~ rn.e~- ~~ ~b --t'o P-e.~.n~ ~-~ r ~p~~j t~PS-~ From: NSU, ADW Well Integrity Engineer ~--~c1JC~i ~- (~ ~' C~7'r li~i Sent: Thursday, July 17, 2008 2:55 PM ~ ~ , BPS r a~ ~Pla-~. cvf ~leP~„~ To: 'Regg, James B (DOA)' D Cc: NSU, ADW Well Integrity Engineer; Engel, Harry R; NSU, ADW Well Operations Supervisor 1 ~"SS~~S , Subject: V-2Z0 (PTD #2080200) Post-initial Injection MIT-IA ~~'l~~ ,.~~ ~'' Y Jim, This is a follow-up request to postpone the initial MIT-IA for well V-220 (PTD #2080200). V-220 was put on produced water infection on 07/04/08 after the completion of an injectivity test. Because of the proximity of 9ES drilling grassroots well V-207, we are unable to access V-220 for the initial MIT-IA. The completion of V-207 is expected to be -3 weeks from now at which time we will gain access to V-220. We are requesting that continued injection occur until this time. I have attached a TIO plot and injection plot for your reference. In addition, 1 have attached a copy of the injectivity test job log. During the injectivity test, the tubing pressure reached 2,000 psi while the IA pressure did not exceed 220 psi. We expect that the current IA pressure is due to thermal effects given the IA fluid level is at the surface. ~j «V-220 TIO and Injection Plot.doc» «V-220 Injectivity Test.tif» tnCrN~C.~Sr~- -f"S-n ~Ra55LUp C~,,rr~ Please contact me with questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~ U' - ~'-7 d ~ yes-~r• -I~ Wit- ~ r~~ ^ s `~ ~~ ~~~~~~ b~ ~k-~ ~sc~c~- c~ kP,~, LPG ~ P 2~ ' ~~ ~~. ~ j~ ~(z~,U,~ ~n ~i2oo8 's~ ~~ • -~r Q ~ . -r-~--~. ILS -~ r a~F{i'~. f ) r 41 Page 1 of 3 WELL SERVICE REPQRT WELL JOB SCOPE UNIT V-ZZO NEW WELL POST LRS 62 DATE DAILY WORK DAY SUPV 7/2/2008 INJECTIVITY TEST SAUVAGEAU COST CODE PLUS KEY PERSON NIGHT SUPV ORD5M3635-D LRS-SCHMITT SPIELER MIN ID DEPTH TTL SIZE 0" OFT 0" "" Jab continued from 7-01-08 WSR""'x Step Rate Test (Pre Initial Inl). Pumped 85 bbls diesel down I bg to perform infectivity tests on WFRs set in GLMs #2,#4,#6 and #8 (see pump report for details). Performed Step Rate Test with all WFRs set, pumped an additional 44 bbls diesel. Injection rates are as follows:.33 bpm ~ i000 psi, .57 bprn ~ 1400 psi and 1.04 bpm C~ 1800 psi. Pressures dropped of gradually when down on the pump. Finial WHPs 120/220/160 f!A/OA casing valves open to aaupes, swab shut needle valve open to gauge at time of departure) LOG EN"f RTES !nit-> 100 120 100 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 00:00 Start ticket, 'ob in ro ress oa:a9 1 st diesel amb 450 120 100 Start down Tb with diesel 00:11 1 2 1500 120 100 00:13 1 4 1550 180 100 Pressure a ears to have stabilized 00:17 1 8 " 1550 180 100 00:18 1 10 1550 180 100 Reduce rate 00:19 .24 10.1 1220 180 100 Establish tar et rate, ressure is decreasin 00:23 .24 11 1200 180 100 Pressure a ears to have stabilized 00:25 .24 11.5 1200 180 100 SD, ressure is dro in off 00:26 950 180 100 SSL to set WFR in GLM #2 04:33 SSL has WFR set in GLM #2 04:42 .75 st/11.5 " 350 120 100 Start downTb with diesel 04:46 .75 13.5 " 550 120 100 Increase rate 04:47 1 13.7 " 800 120 100 04:48 1 15.3 1600 180 100 Reduce rate 04:49 .25 15.4 " i 700 180 100 Attemt to inject a# tar et rate of .24 BPM 04:52 .20 16.5 " 1700 180 100 Pressure continues to rise, reduce um rate 04:57 .18 17.3 1700 180 t00 Pressure a ears to have stabilized 04:59 , t 7 18.0 1700 180 100 05:02 .17 18.2 1700 180 100 SD, pressure gradually failing off. Established an injection rate of .17/ .1$ at 1700 psi, pressure fallin off 05:06 500 120 100 Contact PE with results 05:42 SSL to ull DGLV from GLM #4 06:44 C/O J Carrels for Schmitt 07:20 PJSM w/ SLB 07:33 1 18.2 100 120 100 Start down Tb with diesel 07:38 1 22.4 1700 180 100 Pressure increasin 07:40 1 24.4 1800 180 100 Pressure a ears to have stabilized 07:43 .42 27 1800 180 100 Reduce rate, Attempt to inject at target rate of 0.42 BPM 07:44 .42 27.8 1500 180 100 Pressure slowl increasin ,reduce um ra#e 07:49 .36 29.8 1500 180 100 Pressure a ears to have stabilized 07:52 _ .36 30.9 1500 180 100 SD, pressure gradually falling off. Established injection rate of .36 BPM at 1500psi, pressure fallin off 07:58 550 120 100 SSL to set WFR in GLM #4 09:29 _ SSL has WFR in GLM #4 09:30 .75 30.9/st 20 140 140 Start down Tb with diesel 09:36 .51 34 2000 140 140 Tar et ressure achieved, Reduce rate 09:39 .37 35 2000 140 140 Pressure a ears to have stabilized 09:42 .36 36.4 2000 140 140 SD, pressure gradually falling off, Established file://C:\Pto;t•am Files\AWGRS\Reports\Repoz•t.lttm 7!17/2008 P~~ge 2 of 3 injection rate of .361.37 BPM @ 2000psi, ressure fallin o#f 09:49 SSL to ull DGLV from GLM #6 11:19 SSL has DGLV from GLM#6 11:20 1 36.4/st 40 140 140 Start dawn Tb with diesel 11:25 1.5 39.6 1250 140 140 Increase rate 11:30 1,5 46.6 1750 140 140 Pressure a ears to have s#abilized 11:33 .60 51.6 1750 140 140 Reduce rate, Attempt stabilize pressure C~ .60 BPM 11:36 .60 53.2 1250 140 140 Pressure a ears to have stabilized 11:37 .60 54 1250 140 140 SD, pressure gradually falling off, Established injection rate of .60 BPM C~3 1250psi., pressure fallin aff 11:40 SSL to set WFR in GLM #6 13:14 SSL has WFR in GLM #6 13:15 1 541st 60 160 140 Start down Tb with diesel 13:19 .74 58.5 1750 160 140 Tar et ressure achieved, Reduce rate 13:24 .68 61.4 1750 160 140 Pressure a ears to have stabilized 13:26 .68 62.4 1750 160 140 5D, pressure gradually falling off, Es#ablished injection rate of .68 BPM C~ i 750psi., pressure fallin off 13:30 SSL to ull DGLV from GLM #8 14:48 SSL has DGLV from GLM # 8 14:50 1.5 62.4/st 100 160 140 Start down Tb with diesel 14:59 1.5 72.5 2000 160 140 Pressure a ears to have stabilized 15:00 .86 75.5 2000 160 140 Reduce rate, attempt to stabilize pressure ~ .86 BPM 15:04 .86 79 1600 160 140 Pressure a ears to have stabilized 15:05 .86 80 1600 160 140 SD, pressure gradually falling off, established injection rate of .86 BPM @ 1600psi., pressure fallin off 15:09 SSL to set WFR in GLM #8 16:33 SSL has WFR in GLM #8 16:34 1 80lst 160 180 160 Start down Tb with diesel 16:37 .41 82.1 1000 180 160 Target pressure achieved, attempt to stabilize rate 16:43 .33 85.6 1000 180 160 Pressure a ears to have stabilized 16:53 .33 88.3 1000 180 160 Increase rate for 2nd step of test, established injection rate of .33 BPM ~ 1000 si, 16:58 .59 91.6 1400 180 i 60 Target pressure achieved, attempt to stabilize rate 17:03 .57 95.1 1400 180 160 Pressure a ears to have stabilized 17:08 .57 97.8 1400 180 160 Increase rate for 3rd step of test, established injection rate of .57 BPM ~ i400 si 17:13 1 102.3 1800 180 160 Targe# pressure achieved, attempt to stabilize rate 17:15 .95 105.1 1800 180 160 Pressure a ears to have stabilized 17:19 .95 108.3 1800 180 160 SD, out of fluid, RD, round trip for more fluid to finish test 18:40 C/O Schmitt for J. Carrels 19:15 Start loadin diesel at COTU 19:55 Finished loadin diesel, road to location 20:53 Arrive on location, contact operator, sim-ops with SSL and Hard line 21:02 Receive permit, PJSM, RU to Tbg, install leo crossover on SSV 21:30 PT surface line to 3500 si 21:37 .75 108.6 diesel amb 250 150 100 Start down Tb with diesel 21:43 .75 111.6 1250 150 100 increase rate 21:44 .95 112 1400 150 100 21:47 .95 115.2 1650 220 140 Increase rate 21:48 i.08 116 1800 220 140 Monitor ressure 21:50 1.05 119 1800 220 140 Pressure appears to have. stabilized, attempt to estabilish in'ectivi# rate for 10 min ____ 21:55 1.03 124.5 1800 220 140 22:00 1.04 129.6 1800 220 140 SD, pressure gradually falling o#f, monitor file://C:\P;•ogram Files\AWGRS\Reports\Report.htm 7/17/2008 Page 3 of 3 ressure 22:10 400 220 160 Start RD 22:85 Finished with RD, finish a er 22:55 Finished with a er 23:59 End ticket Final-> 120 220 160 SSV is shut file:/IC:AProgram Files\AWGRS\Reports\Report.htm 7/1712008 FLUID SUMMARY _ 130 bbls diesel MECHANICAL .INTEGRITY REPORT _~-~-"b~ OPER ~ FIELD ~~ ~ ~~ -._G r :~~r~~. - ~~1 ~-©~. i.LLL NUMBER ~ '~-c~~ .N ~ LL DAT ~_ TD : ~?,~.. S (I ~ '?'VD ; ?BTD : ~S~c1 D ? ID ;SOr-) ~ '?'VD i\ Corsi^g: ~ Shoe: ~\tl~ t•ID 5~~ TVD; DV: ~~.- ?~ ~Q -T4~i, __:~e= _ 1J Q Shoe. ~ TVD ; ~'GP . }•~ ';D 3` ~ +d~ c, PGc~~~s ~u~- ~° ~_Pacicer ~~~5~ TVD; et et ~~~~ =ole S«e ~~~~ and \~A PeTfs `'1ai~-1 to~.- ~-~-:.t'~?~_C~-1r 1 NTEGR?TY - PART #? A~nuius Press Test: _~ ? 5 min ~0 min ~~R ~~~ ~. Comments : ~ ~5 ~~Q ~ ~ ~~F~, ~J~~r~c '~'CHAN F CA_s., ~ NTEGR.T'rv - PART # Z \ 1~~~~ 5 Cement Voltmm - CsQ ~ DV es :, Amt. ~~ner ~Q,r .. _ _~_ Cmt vol to cover aer~s C ~0~, `~ ~ ~~`-~ ~ ~~~ b~\S~ °~-c :_eoretical TCC ~ ~~~ ~ S S~COYI ~. __,~ 'c, I C'C~MCCd~~ ES~C~^~ ~ Ca~\ `C ~ S~1~C~_ShoCc' ~ \ ~~~ - 1(., t ~ ~ ~ ~ ~ i~-~~~ Cement Bond Log tYes or No)-~-~-; In AOGCC Fi? e - `\ t GBL Evzluation, zone zbove perfs C.~c.r~.e~~-~\~~y Ct>~~`~~o~ ~~~ ,c1 Production 'Log: Tyne ~ONCLJS?ONS: ?art i 1 _ ar~ T~ -, Evali:.ati on t t _~ ~ /a~-~ STATE OF ALASKA ~ .yI ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1b. Well Class: zoAa,c zs.,os zoaAC zs.,,o ^ Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ®WAG ^ Other No. of Completions One ®Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aban 12. Permit to Drill Number BP Exploration (Alaska) Inc. 03/11/2008 .p~ 208-020 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 2/24/2008 ~ 50-029-23383-00-00 ' 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 3/3/2008 ~ PBU V-220 - 4908 FSL, 1503 FEL, SEC. 11, T11 N, R11 E, UM ' Top of Productive Horizon: 8. KB (ft above MSL): 81.1 15. Field /Pool(s): 4097' FSL, 1182' FWL, SEC. 01, T11 N, R11 E, UM Ground (ft MSL): 52.6' Prudhoe Bay Field / Orion Total Depth: 9. Plug Back Depth (MD+TVD) Schrader Bluff 4694' FSL, 1379' FWL, SEC. 01, T11 N, R11 E, UM 8090 5046 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 590797 y- 5970158 Zone- ASP4 8180 5114 ADL 028240 - TPI: x- 593291 y- 5974658 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: Total Depth: x- 593613 y- 5975259 Zone- ASP4 N/A 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): ' Submit electronic and rinted information er 20 AAC 25.050 N/A ft MSL 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR, RES, NEU, Azimuthal Density, PWD, LWD 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD` SETTING DEPTH TVD HDLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP 'BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# A-53 Surface 109' Surfac 109' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 29' 4178' 29' 2853' 12-1/4" 730 sx Dee Crete 446 sx Class'G' 7" 26# L-80 27' 8174' 27' 5109' 8-3/4" 76 sx LiteCrete 360 sx Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24. TueING 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 3-1/2", 9.2#, L-80 7973' 7189', 7376', 748T & , MD TVD MD TVD 7568' , 7720', 7819' 7214' - 7238' ' 4429' -4445' 25; ' ACID ETC. FRACTURE CEMENT SQUEEZE 7416' - 7474' - 4564' - 4604' , , ,. 7516' - 7558' ~ 4632' - 4661' DEPTH INTERVAL MD AMOUNT He KIND OF MATERIAL USED 7580' - 7606' ~ 4677' - 4695' 7666' 7694'- 4737' 4756' 2850' Freeze Protected with 100 Bbls of Diesel - - 7738' - 7792' ~ 4788' - 4826' 7828' - 7854' 4852' - 4871' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection N/A Alaska Oil & Gas Cons. Date Of Test: HOUrS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF. WATER-BBL: CHOKE SIZ -OIL RATIO: TEST PERIOD Flow Tubing CaSing PreSS: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITV-API (CORK): PreSS. 24-HOUR RATE 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. j ~C>1ssP3.E710~ None ~~/ r~~ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE ~ e~a~ I#: NfAY ,{1 ~ ~QQQ ~~'~a/ 28. GE0.OGIC MARKERS (LIST ALL FORMATIONS AND 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 1996' 1723' detailed test information per 20 AAC 25.071. Top of Ugnu 4332' 2930' None UG_MA 6768' 4152' UG_M61 6840' 4195' UG_MB2 6954' 4265' UG_MC 7070' 4337' SB_NA 7172' 4402' SB_NB 7212' 4428' SB_NC 7263' 4462' SB_NE 7277' 4471' SB_N F 7359' 4526' SB_OA 7416' 4564' SB_OBA 7516' 4632' SB_OBB 7580' 4677' SB_OBC 7667' 4737' SB_OBD 7740' 4789' SB_OBE 7828' 4852' SB_OBF 7898' 4903' SB_OBF_BASE Top of Colville 7960' 4948' Formation at Total Depth (Name): Colville Mudstone 8180' 5114' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and aLeak-Off Test Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. /~ ~ /~ Si D t ' d _ ' ~ o"~ gne a e ~, ~~ Drilling Technologist ( V (..J Sondra tewma l PBU V-220 208-020 Prepared syName/Number. Sondra Stewman, 564-4750 Well Number Drilling Engineer: Adrienne McVey, 564-4184 Permit No. / A royal No. INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary ir- this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only TREE _ 41 /16" CMJ Vlr`EILHEAC'= A%TUAT~R = FMC Dectric KB ELEV = 81.10' BF. ELEV - KflP - ~ 54.55' 250' Max Angle = 62 deg 'Datum MD = ....... T193' _ Datum N D = ddOD' SS 3352' ~-13-1/2" HES X NIP, ID = 2.813" 7149 ~-~ 3-1/2" HES X NIP, ID = 2.813" • SAF TES: "*HES PKR ~ 6675' IS "PULL TO REL ' 8tf"t' CAN ALSQ BE REi.EASED BY PRESSURE . ~s DO NOT i:]CGES} 4304 PSI. TEST PRESSURE PKR RATING =5495 PSI.. (4332 PSI IS 8U96 OF PKR RATING}"'*" i' a-1/r xa 3-112°. ~ = 2.592" ~s-srs" cs~, 40#, L->3~, Tc_II. IIS a 8.835" I~ 4178' V 7" CSG, 26#, L-Bq, TC-II, .U383 bpf, ID = 6.276" 5,675' MA RICERJOINTwiRATAG Na7,175` MARKER JOINT w / RA TAG OA 7,417' ~ GAS LIFT MANDRELS 5T MD TVD DEV TYPE VLV LATCH PORT DATE 12 7120 4369 50 MMG DGR RKP 4 03/10/08 WATFK 1ALIFCTIQN MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT SATE 11 7201 4421 49 M M G-W DMY RFE 4 03/10108 10 7327 4504 48 M M G-IN ~~1Y RIC 0 03110!08 9 74(}7 4558 d7 FA kl G-1N QMY RK 0 03110!08 8 7469 4600 47 M M G-W DMY RK 0 03110/08 7 7519 4634 d7 M M G-UV DMY RK 0 03110108 6 7554 4656 46 MMG-W DMY RK 0 03/10108 S 7599 4690 46 Nt M G-W DMY RIE 0 03/10!08 4 7691 4754 45 MMfa-W DMY RK 0 03/10!08 3 7762 4805 44 M M G-tiIV DMY RK 0 03/10!08 2 7800 4832 44 M M G-UV DMY RK fl 03110!08 1 7871 4883 43 MMG-tN DMY RK 0 p3J14108 PERFORATION SUMMARY REF LOG: SLB Realtime LWD ANGLEATTOPPERF' 49 ~ 721 d' Rote: Refer to Production DS for h~tar~cal pert data slzE SPF IRTIFRVA~ opnisgz DATE ."3-i2" 5 Nb7,21d'-7,238" O p3106t08 d-1/2'" 5 OA 7,416'-7,474' O 03106108 +I-1I2"' S t3Ra 7,518'-7,558'. O 03f06t08 41/2"" 5 OI3b 7,58fl'-7.,606' O 03f061p8 4112" § OBc 7,666'-7,694' O 03106108 4112" S OBd 7,738'-7,782' O p3f06/08 4-112" 5 OBe 7,828'-7,854" O 0310610$ 3-1 /2" TBG, 9.2#, L-80, TGI1, .0087 bpf, ID = 2.992'•. PBTD 7" CSG, 26#, L-Bp, BTG-IUI, .0383 bpf, lD = 6.27fa ~ 8.17d' ~ 7169' ~-~ 7" HES A HR PKR w / 1/4" FEED THRU, ID = 2.920" 7183' ~MULT[ DROP SGM FOR NDPG GAUGE. 73- ~`~ 3-1 f2° HES X N{P, ID = 2.813" 7" HES A HR PKR w 11 /4" FEED THRU, = 2.92p"' ~ 7390 MULTI DROP SGM FOR NDPG GAUGE 7487' 7"' HES A HR PKR w I 1 f4" FEED THRU, ID 2.920 7502'... 3'112" HES X NIP, ID - 2.813" 7506' MULTI DROP SGM FOR NDPG GAUGE 758$'. 7" HES A HR PKR w ! 1I4" FEED THRU', ID = 2.920" 75$2' MULTI DROP SGM FOR NDPG GAUGE 7623' ~3-1l2" HES X NIP, ID = 2.813." 7720' 7"" HES AHR PKR w l 1!4" FEED THRU. ID 2 920" 7733 MULTI DROP SGM FOR NDPG GAUGE 77r~' ~ 3°i /2" HES X NIP, ID - 2.813" 7819 7" HES AHR PKR w / 1/4" FEED THRU, ID = 2.920" 7833 SINGLE SGM FOR NDPG GAUGE 7850' ' ~ 3-1/2" HES X NIP, ID = 2.813" 7SQ0' 3-:112' HES X NIP, ID ~ 2.813` 7928• 3-:112" HES XN NCP, ID = 2.75" 7947` 3-112" WLEG, 1D = 2.992" DATE REV 6Y COMMEAITS DATE REV BY COMMENTS ..113 11 1 10 8 N9ES ORIGINRL G(3NIPLETION 03f17108 /TLH GORRECTIONB (7RION UNIT UVEI.L: V-2201. PERMIT No: 2080200 APl Nn: 50-029-23383-00 4908' FSL, 1503' FEL; Sec 11, Twp 11, Rge 11 UM BP Exploration {Alaska) i aM BP EXPLORATION Page 1 of 14 Operations Summary Report Legal Well Name: V-220 Common Well Name: V-220 Spud Date: 2/24/2008 Event Name: DRILL+COMPLETE Start: 2/21/2008 End: 3/11/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/11/2008 Rig Name: NABOBS 9ES Rig Number: I Date From - To Hours' Task Code I' NPT Phase` Description of Operations 2/21/2008 18:00 - 19:00 1.00 RIGD P PRE Rig down topdrive. 19:00 - 21:00 2.00 RIGD P PRE Bridle up blocks and lower cattle chute. 21:00 - 21:30 0.50 RIGD P PRE Remove derrick pins and laydown derrick. 21:30 - 23:00 1.50 MOB P PRE Raise cellar doors and move sub off of Z-112 to pad entrance. 23:00 - 00:00 1.00 DIVRTR P PRE Remove surface hydril from cellar, load out on truck for transport to V-220. (To be nippled up before rig arrives on V-pad. 2/22/2008 00:00 - 04:00 4.00 MOB P PRE PJSM, Pre inspection of moving system. Move sub base down Z-Pad access road, left on Spine road, then right and down L&V access road. Arrive on V-Pad C~3 04:00 hr. 04:00 - 06:30 2.50 MOB P PRE Move around pad and position sub close to V-220i. Lay rig mats and herculite. Position rig over V-220i conductor. 06:30 - 08:00 1.50 MOB P PRE Raise derrick and install derrick pins. 08:00 - 09:00 1.00 MOB P PRE Remove Jeep from mud pits. Attempt to spot pits. Pits too close to cages on well house row. 09:00 - 11:00 2.00 MOB P PRE Re-position sub base over well at angle to well house row. 11:00 - 13:00 2.00 RIGU P PRE Spot mud pits, pin cattle chute, lower blocks. Remove bridal lines and pin blocks to topdrive. Level mud pits. 13:00 - 14:00 1.00 RIGU P PRE Hook up lines at interconnect. Run steam and water to mud pits. Mud pits ready to take on water for spud mud (~? 14:00 hr. *Rig acceptance rolled back 1 hour due to diverter removal on Z-112. *Rig accepted for V-220i operations at 13:00 hr, 2/22/2008. 14:00 - 16:30 2.50 RIGU P PRE iSim Ops -Rig up floor equipment. Start nipple up of surface diverter. 16:30 - 00:00 7.50 DIVRTR P PRE Nipple up surface diverter lines. Crossover riser boot from 16" to 20". Nipple up diverter riser. Mix spud mud. Change mud pump liners from 5" to 5.5". Start loading pipeshed with 4" drill pipe. 2/23/2008 00:00 - 12:00 12.00 RIGU P PRE Continue loading out pipeshed with drill pipe and mixing spud mud. Install remaining diverter lines outside of the rig. Install 4" valves on outlets on conductor pipe. Tighten bolts on diverter riser. *Worked with 4 man crew. Motorman, Forklift driver, Pitwatcher and 1 roustabout made their flight. 2 hands from Kikoni's crew stayed over but were required to go to bed per SOP. Worked 6 hands short from midnight to noon. 12:00 - 15:00 3.00 RIGU P PRE Finish loading drill pipe and HWDP in pipe shed. Finish berming around rig 15:00 - 18:30 3.50 RIGU P PRE Change out saver sub on topdrive. Load BHA in pipeshed. Pick up BHA drilling tools to rig floor. Change out all valves and seats in mud pumps. 18:30 - 22:30 4.00 RIGU P PRE Pick up 102 joints from pipeshed, build stands and rack back in derrick. 22:30 - 00:00 1.50 RIGU P PRE Pick up 24 joints from pipeshed, build stands and rack back in derrick. 2/24/2008 00:00 - 02:00 2.00 RIGU P PRE PJSM. Pick up and make up drill collar and Jar stand and rack back in derrick. *Held Pre Spud meeting with Pat Stewart's crew during the Pre Tour Safety meeting. Printetl: 3/17/2UUS l:bli:"L/ F'M BP EXPLORATION Page 2 of 14 Operations Summary Report Legal Well Name: V-220 Common Well Name: V-220 Spud Date: 2/24/2008 Event Name: DRILL+COMPLETE Start: 2/21/2008 End: 3/11/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/11/2008 Rig Name: NABORS 9ES Rig Number: Date. From - To ~ Hours Task Code' NPT Phase Description of Operations 2/24/2008 02:00 - 03:00 1.00 DIVRTR P PRE Funtion test Diverter system and perform accumulator 03:00 - 05:00 2.001 RIGU P 05:00 - 07:00 2.00 RIGU P 07:00 - 09:00 2.00 RIGU P 09:00 - 11:00 I 2.001 DRILL I P 11:00 - 11:30 I 0.501 DRILL I P 11:30 - 12:00 I 0.501 DRILL I P 12:00 - 00:00 I 12.001 DRILL I P 12/25/2008 ~ 00:00 - 01:30 ~ 1.50 ~ DRILL ~ P 01:30 - 02:15 I 0.751 DRILL I P 02:15 - 05:00 I 2.751 DRILL I P 05:00 - 05:30 ~ 0.50 ~ DRILL ~ P drawdown test. Witnessing of test was waived by AOGCC rep Chuck Sheave. Test witnessed by BP WSL R. French and NAD TP T. Leigh. PRE Make up BHA #1: New HTC MXL-1X 12 1/4" bit, 1.5' bend PDM, NM Lead DC, NM Stab, MWD, NM Stab, NM XO, UBHO sub. PRE Rig up Sperry Sun E-line and Gyro Data equipment. PRE Pick up drill collar stand, make up topdrive, fill hole and check for leaks. Pressure test mud lines to topdrive to 3,500 psi - OK. SURF S ud V-2201 (~3 09:00 hr, 2/24/2008. Directionally drill 12 1/4" surface hole from 108' to 350' (Kick-off ~ 250') Gyro survey as needed. 575 gpm, 940 psi on, 830 psi off. 80 rpm, 3k tq on, 1 k tq off PU - 55k, SO - 55k, RWT 55k, WOB - 15k SURF POH from 350' to 175'. Pick up Jar stand and run in hole to bottom. SURF Directionally drill 12 1/4" surface hole from 350' to 454'. Gyro 575 gpm, 1,150 psi on, 1,025 psi off. 80 rpm, 3k tq on, 2k tq off. PU - 60k, SO - 60k, RWT - 60k, WOB - 20k. AST - 0.57 hrs, ART - 1.1 hrs `Held Pre Spud Meeting with Kenny Sullivan's crew during the Pre Tour Safety Meeting SURF Directionally drill 12 1/4" surface hole from 350' to 1675'. Gyro surve as needed to 914', 800' surve de th). Rigged down Gyro while sliding. 650 gpm, 2,085 psi on, 1,960 psi off. 80 rpm, 4.9k tq on, 2.1 k tq off. PU - 75k, SO - 73k, RWT - 74k, WOB - 25k. AST - 6.25 hrs, ART - 1.43 hrs SURF Directionally drill 12 1/4" surface hole from 1,675" to 1,767'. 650 gpm, 2,260 psi on, 2,140 psi off. 80 rpm, 4.9k tq on, 2.1 k tq off. PU - 75k, SO - 73k, RWT - 74k, WOB - 35k. *Note - Verv few slivers of wood came over the shaker up to now. SURF Circulate bottoms up X 3 C~ 700 gpm, 2,370 psi, 80 rpm, 2k tq. 2nd bottoms up was fairly clean, but went one more. Saw mostly clay and pea gravel on 1st bottoms up, no wood. 9.1 PP9 MW SURF Wiper trip from 1,767' to 270'. Pulled OK from 1,767' to 1,270'. Started pulling 25-50k over and swabbing. Pumped out 1 stand from 1,292'to 1,197' ~ 2 bpm, 320 psi. Had to pull slow to keep from packing off towards end of stand. Backream out from 1,197' to 917' ~ 600 gpm, 1,550 psi, 60 rpm, 3-6k tq. Pull dry OK from 917' to 270' SURF Service topdrive. Nnnteo: siurtuua i:no:zi rnn BP EXPLORATION Page 3 of 14 "Operations Summary Report Legal Well Name: V-220 Common Well Name: V-220 Spud Date: 2/24/2008 Event Name: DRILL+COMPLETE Start: 2/21/2008 End: 3/11/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/11/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/25/2008 05:30 - 06:45 1.25 DRILL P SURF Run in hole from 270' to 1,767'. Had to wash through tight spots at 1,070', and from 1,101'to 1,170'. 06:45 - 07:15 0.50 DRILL P SURF Circulate bottoms up. Stage pumps to drilling rate. 650 gpm, 2,400 psi, 80 rpm, 2.6k tq 07:15 - 12:00 4.75 DRILL P SURF Directionally drill 12 1/4" surface hole from 1,767" to 2,630'. 700 gpm, 3,075 psi on, 2,995 psi off. 80 rpm, 7k tq on, 4k tq off. PU - 80k, SO - 70k, RWT - 75k, WOB - 30k. AST - 1.70 hrs, ART - 1.23 hrs *H drates encountered at 2,370' and 2,630'. 12:00 - 17:00 5.00 DRILL P SURF Directionally drill 12 1/4" surface hole from 2,630" to 3,260'. Bit started balling up on and off starting ~ 15:00 hr, -3,140. 700 gpm, 3,005 psi on, 2,910 psi off. 80 rpm, 7.5k tq on, 4.3k tq off. PU - 90k, SO - 70k, RWT - 79k, WOB - 30k. 17:00 - 19:30 2.50 DRILL P SURF Circulate tea 35 bbls Nutplug Medium pills with bit fanning bottom. 700 gpm, 2,900 psi 80 rpm, 5-7k tq. 19:30 - 23:00 3.50 DRILL P SURF Directionally drill 12 1/4" surface hole from 3,260" to 3,426'. Slowly started putting weight on bit with ROP starting at 15 fph, then increasing to 50 fph avg with some 150 fph sections. ROP then slowed back down to 15-20 fph. Pumped 2 more nut plug pills without any ROP change. 700 gpm, 3,005 psi on, 2,910 psi off. 80 rpm, 7.5k tq on, 4.3k tq off. PU - 90k, SO - 70k, RWT - 79k, WOB - 30k. Monitor well - OK but had some h drates breakin out of mud. 9.3 ppg MW, 310 vis in, 400 vis out. 23:00 - 00:00 1.00 DRILL N DFAL SURF POH from 3,426' to 3,108' with slight hole drag without swabbing. PU - 96k, SO 75k 2/26/2008 00:00 - 02:30 2.50 DRILL N DFAL SURF Continue POH w/ BHA #1 for ROP from 3,108' to 3,013' before hole started swabbing. Backream from 3,013'to 1,750'. 700 gpm, 2,125 psi, 80 rpm, 4.4-8k tq. Drill i e was back flowing on connections. Some hydrates breakin out at surface. 02:30 - 03:00 0.50 DRILL N DFAL SURF Circulate bottoms up C~ 700 gpm, 2,205 psi to clean up backside. Shakers were not able to handle clay balls with bottoms u and had to slow um rate to gpm, psi. 03:00 - 05:30 2.50 DRILL N DFAL SURF Backream out of the hole from 1,750' to 1,550' at 350 gpm, 710 psi, 60 rpm, 3.4k tq. Connections started backflowing again. Pump out of the hole from 1,550' to 917', 2 bpm, 240 psi, no rotation. 05:30 - 07:00 1.50 DRILL N DFAL SURF POH dry from 917' to top of BHA #1 ~ 172'. 07:00 - 09:00 2.00 DRILL N DFAL SURF PJSM. LD BHA #1. MWD collar washed out. Silver dollar sized hole below turbine unit in MWD housing. After review on rig and in town of pressure data, no pressure indications found of washed out collar. MXL-1 X bit grade 1 - 2 - WT - A - E - 1 - NO - DTF. 09:00 - 12:00 3.00 DRILL N DFAL SURF MU BHA #2 -Rerun MXL-iX 12 1/4" bit, 1.5* bend PDM, NM Lead DC, NM Stab, MWD, NM Stab, NM XO, NM DC, NM Stab, tea NM DC, Jars. rnniea: aiuicu~a iao:u rm BP EXPLORATION Page 4 of 14 Operations Summary Report Legal Well Name: V-220 Common Well Name: V-220 Spud Date: 2/24/2008 Event Name: DRILL+COMPLETE Start: 2/21/2008 End: 3/11/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/11/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To '~ Hours Task Code NPT Phase Description of Operations 2/26/2008 12:00 - 14:30 2.50 DRILL N DFAL SURF RIH w/ BHA #2 from 267' - 3,426' md. Wash and ream 2 14:30 - 15:00 0.50 DRILL N DFAL SURF 15:00 - 17:30 2.50 DRILL P SURF 17:30 - 18:30 1.00 DRILL P SURF 18:30 - 22:30 4.00 DRILL P SURF 22:30 - 00:00 1.50 DRILL P SURF 2/27/2008 00:00 - 01:00 1.00 DRILL P SURF 01:00 - 02:30 1.50 DRILL P SURF 02:30 - 03:30 1.00 DRILL P SURF 03:30 - 06:30 3.00 DRILL P SURF 06:30 - 08:00 1.50 DRILL P SURF 08:00 - 09:30 1.50 DRILL P SURF 09:30 - 11:30 2.00 DRILL P SURF 11:30 - 12:30 1.00 DRILL P SURF 12:30 - 17:00 4.50 DRILL P SURF 17:00 - 20:30 3.50 DRILL P SURF 20:30 - 21:00 0.50 DRILL P SURF 21:00 - 00:00 3.00 CASE P SURF 2/28/2008 00:00 - 16:30 16.50 CASE P SURF stands to pass obstruction C~ 1,195' and 300 gpm, 575 psi, 50 RPM, 4.9k TO. Wash and ream from 3,390' to 3,426' md. Circulate 1.5 bottoms up reciprocating 35 feet. 600 gpm, 2590 psi, 73 rpm, 4.9k TO. Directionally drill 12 1/4" surface hole from 3,426' to 3,775'. 700 gpm, 3,520 psi on, 3,398 psi off. 80 rpm, 7.2k TO on, 5.1 k TO off. PU - 101 k, SO - 73k, RWT - 87k, WOB - 25k. MAD pass from 3,775' to 3,715' and for data gap on logs. Directionally drill 12 1/4" surface hole from 3,775' - TD ~ 4,189' md. 650 gpm, 3,460 psi on, 3,325 psi off. 80 rpm, 8.1 k TO on, 5.1 k TO off Hydrates breaking out at surface. PU - 101 k, SO - 73k, RWT - 87k, WOB - 25k. AST - 0.68 hrs, ART - 2.77 hrs CBU x 3. 650 gpm, 3190 psi, 80 rpm, 5.8k TQ. Shakers cleaned up to only minor cuttings returns after 2.5 bottoms up. Shut down from CBU x 3 and POH 2 stands from 4,189' and to 3,965' md. Encounter 35k+overpull with slight swabbing. PU - 110k, SO 75k. Backream 7 stands out of hole to 3,303' and (above last trip point) l~ 40 rpm, 250 gpm, 850 psi, RTW - 85k. 150 psi increase at 3,624' md. Run back through and ream back out - OK. POH 6 stands without pumps from 3,303' and to 2,789' md. Encounter 35+k overpull. PU - 105k, SO - 75k. Backream 7 stands out of hole to 2,150' and (~ 40 rpm, 250 gpm, 650 psi, PU - SOk, SO - 65k, RTW - 75k. Attempt to pull one stand at permafrost but saw overpull. Trip out of hole with pumps but no rotation from 2,150 - 727' and (Top of BHA). PU - 75k, SO - 65k, 280 gpm, 435 psi. Monitor well -static. Blow down topdrive. RIH from 727' to TD Ca? 4,189' md. Tag up TD on depth w/ no fill. PU - 110k, SO - 65k. Work pipe down with pumps through tight spots C~ 1510' - 1530', 1610', & 1910' md. CBU x 2 ~ TD, reciprocating pipe in 40' strokes. 680 gpm, 3450 psi, 80 rpm, 6.Ok TO, RTW - 85k Attempt to pull dry, but well swabbing.. Bring pumps online 400 gpm, 1530 psi initial pressure. Pump out of hole 7 stands from 4,189' - 3,488' md. Final pressure 1440 psi. PU - 108k, SO - 64k. Shut down pumps & blow down topdrive. Pull out of hole with 12.25" drilling BHA #2 from 3,488'to 1,004'' md. Pulled 20k over at 1,958' and and swabbing. Pumped that stand out to 1,863' md. PJSM. Lay down BHA #2. Stand back JAR stand. Bit #2: 1 - 1 -WT-A-E-1 -NO-TD. Clean and clear rig floor of BHA equipment. PJSM. Make dummy run with 9 5/8" casing hanger and landing joint. Rig up to run casing. PJSM. Pick up and make up 9 5/8" 80' shoe track. Baker-Lok connections. Check floats - OK. Continue running in hole with ranted: 3/z//zuua 1:SO:Z/ YM ~ ~ BP 'EXPLORATION Operations Summary Report Legal Well Name: V-220 Page 5 of 14 Common Well Name: V-220 Spud Date: 2/24/2008 Event Name: DRILL+COMPLETE Start: 2/21/2008 End: 3/11/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/11/2008 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Ili Task Code NPT Phase ' Description of Operations 2/28/2008 00:00 - 16:30 16.50 CASE P SURF 9 5/8" 40# L-80 BTC casing to -1,700' md. Filled every joint with casing fill-up tool topping off every 10 joints. Make up TQ - 8,200 ft/Ibs. Used BOL 2000 NM pipe lubricant. Work 1 joint down C~3 -3,050' md. Circulate down every 5 or 10 joints as needed ~ 2 bpm, 260 psi to keep displacement good. Halliburton 9 5/8" Float Shoe Bottom ~ 4,178'. 2 Jts 9 5/8" 40# L-80 BTC Casing (#1- #2) Halliburton 9 5/8" Float Collar C~ 4,094'. 100 Jts 9 5/8" 40# L-80 BTC Casing (#3- #102) 9 5/8" 40# Hanger Pup Jt Casing hanger (10 3/4" LH Acme top conn) 9 5/8" Landing Ring to Rotary table - 28.95' 16:30 - 17:00 0.50 CASE P SURF 17:00 - 21:30 4.50 CEMT P SURF 21:30 - 23:30 2.00 CEMT P SURF 23:30 - 00:00 0.50 CEMT P SURF 2/29/2008 00:00 - 00:30 0.50 CEMT P SURF 00:30 - 01:00 0.50 CEMT P SURF Up weight = 150K, Down Weight = 95 Baker-Lock Shoe-track Jts #1-3 Bowsprings Centralizers: 1 on stop ring 5-10' above shoe on jt #1 1 on stop ring 5-10 ft. above float collar 23 on collars on jts #3-25 25 Total Centralizers, 2 Stop Rings Laydown Frank's tool. Slowdown topdrive. Make up double plug cementing head. Stage pumps up to 300 gpm, 550 psi ICP incrementally. Continue circulating and conditioning mud to a 63 viscosity and 15 YP C~ 300 gpm, 425 psi prior to switching to Dowell. Reciprocated casing 15 ft strokes until hanger catching on surface stack. Reciprocated in 4' strokes after. PU - 190k, SO - 96k. Held cementing PJSM while circulating. Switch over to Dowell. Pump 5 bbls of water. Pressure test lines to 4,000 psi - OK. Pump 100 bbls of 10 ppg of MudPush II C~3 5.7 bpm, 175 psi ICP, 130 psi, FCP. Shut down and release bottom plug. Pumo 505 bbls of 10.7 ppq DeepCrete lead cement ~ 6.3 bpm, 247 psi ICP, 334 psi FCP. Pump 69 bbls of 15.8 ppg Class "G" tail cement ~ 5.3 bpm, 360 psi ICP, 238 psi FCP. 'Note: Spacer observed at surface at end of neat tail cement pumping. Pump 18 bbls of Class "G" tail cement with DuraSTONE,C~ 5.3 bpm, 238 psi ICP, 238 psi FCP. Drop top plug and chase with 5 bbls H2O. Full returns throughout cement pumping. Reciprocated pipe in 4' strokes until 400 bbls lead pumped. Landed casing on ring due to low slack o weight. PU - 195k, SO - 60k prior to landing casing. Switch over to rig pumps and begin displacing cement with 9.3 ppg mud C~3 6 bpm, 188 psi ICP. Continue displacing cement with total of 306 bbls of 9.3 ppg mud ~ 6 bpm, 188 psi ICP, 943 psi FCP. Slow pump to 3 bpm 10 bbls prior to bumping plug, 770 psi. Bumped plug ~ calculated strokes (95.7% efc) with 3,500 psi. CIP C~? 00:36 hr. Well defined spacer-cement interface at surface w/ 130 bbls of displacement away. Returned all of spacer. Returned 181 bbls of "Sidewalk Cement". Full returns throughout job. Hold pressure on casing for 30 minutes -good test. Nrinted:si[nzuuss i:oti:~i rm BP EXPLORATION Page 6 of 14 Operations Summary Report Legal Well Name: V-220 Common Well Name: V-220 Spud Date: 2/24/2008 Event Name: DRILL+COMPLETE Start: 2/21/2008 End: 3/11/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/11/2008 Rig Name: NABORS 9ES Rig Number: Date From - To Hours ! Task Code NPT 'i Phase. Description of Operations 2/29/2008 01:00 - 06:30 5.50 CASE P SURF Laydown landing joint. Flush flowline and riser. Rig down casing and cementing equipment. Start nipple down of diverter lines. Clean out from under rotary table. 06:30 - 09:30 3.00 DIVRTR P SURF Ni le down diverter riser and change out drilling nipple adapter from 20" to 16". Move surface hydril off of conductor and out of cellar cellar. 12:00 - 14:00 2.00 WHSUB P SURF Bring casing head and tubing spool into cellar and nipple up same. Test metal to metal seals to 1,000 psi - 10 min - OK. 14:00 - 18:30 4.50 BOPSU P SURF Nipple up BOPE. 18:30 - 21:00 2.50 BOPSU P SURF Rig up to test BOPE. 21:00 - 22:30 1.50 BOPSU P SURF PJSM. Fill stack & prepare to pressure test. Small leak from casing head -tubing spool flange. Drain stack & change out API ring. Re torque flange bolts. 22:30 - 23:30 1.00 BOPSU P SURF Finish rigging up test joint and other testing equipment. 23:30 - 00:00 0.50 BOPSU P SURF Be in Testin BOPE to 4000 si. 3/1/2008 00:00 - 04:00 4.00 BOPSU P SURF Pressure test BOPE to 250 psi/4,000 psi for 5 min each test. 250 psi/3,500 psi on annular preventer for 5 min each. Perform Accumulator test. Test witnessed by AOGCC rep Bob Noble and BP WSL M. Martyn, NAD TP T. Leigh. 04:00 - 07:00 3.00 BOPSU P SURF RD from BOP testing. LD test joint. Install 9-1/4" ID wear bushing. 07:00 - 08:00 1.00 BOPSU N MISC SURF Kelly hose frozen thaw hose. 08:00 - 10:00 2.00 DRILL P PROD1 Prepare to pick up drill pipe. Run in hole picking up drill pipe from pipe shed to 1,233' md. Continue to thaw kelly hose while tripping. 10:00 - 11:00 1.00 DRILL P PROD1 POH from 1,233' racking back stands in derrick. Continue to thaw kelly hose while tripping. 11:00 - 13:00 2.00 DRILL N MISC PROD1 Thaw kelly hose. 13:00 - 17:30 4.50 DRILL P PROD1 Clear floor and prepare to pick up BHA. PJSM with crews and contractor personnel on making up directional assembly. Pick up and make up BHA #3: Rerun 8.75" DTX619M-D2 bit, 1.15 deg XP-PDM, NM STAB, LWD/ARC, MWD, LWD/ADN, tea NM DCs, saver sub, 5" HWDP, JAR, 5" HWDP, XO to 4" HWDP. Run in hole with 8 stands of HWDP to 990'. 17:30 - 18:00 0.50 DRILL P PROD1 Shallow hole test MWD - OK. 494 gpm, 1,670 psi. 18:00 - 20:00 2.00 DRILL N MISC PROD1 Thaw kelly hose. 20:00 - 00:00 4.00 DRILL P PROD1 Pick up 33 joints of 4" drill pipe, Ghost Reamer C~3 2,046', plus 60 joints of 4" drill pipe to 3,937'. 3/2/2008 00:00 - 04:00 4.00 DRILL P PRODi Cut and slip drilling line. Inspect & Adjust draw works brakes. Service topdrive, drawworks, and crown. Calibrate blocks for epoch system. Continue to thaw kelly hose. 04:00 - 10:00 6.00 DRILL N MISC PROD1 Break kelly hose connection and thaw out inside of kelly hose and standpipe gooseneck. 10:00 - 10:30 0.50 DRILL P PROD1 Circulate & condition drilling fluid. Test MWD - OK. 10:30 - 11:00 0.50 DRILL P PROD1 Wash down from 3,937' & taa cement ~ 4,090'. 11:00 - 11:30 0.50 DRILL P PROD1 Wash and clean out cement to float collar (tagged cement 4' above collar . Drill out float collar and cement to float shoe C~3 ' 550 gpm, 2,400 psi off, 2,750 psi on, 60 rpm, 6k TO on, 5k TO off, PU - 115k, SO - 65k, RWT - 80k, WOB - 5k. 11:30 - 13:00 1.50 DRILL P PROD1 Displace well from old 9.3 ppg spud mud to new 8.8 ppg LSND drilling fluid. 550 gpm ~ 1,389 psi. 13:00 - 13:30 0.50 DRILL P PROD1 Drill out float shoe and 12.25" rat hole plus 20' to 4,209' md. Nnntea: siziiwuo 1:bb:Z/ YM BP EXPLORATION Page 7 of 14 Operations Summary Report Legal Well Name: V-220 Common Well Name: V-220 Spud Date: 2/24/2008 Event Name: DRILL+COMPLETE Start: 2/21/2008 End: 3/11/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/11/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code NPT Phase I Description of Operations ~ - -- _ 3/2/2008 __ _ 13:30 - 14:00 0.50 DRILL P PROD1 Pull up into casing. Perform 9 5/8" LOT: MD - 4,178', TVD - 2,852', MW - 8.8 ppg, LOP - 700 psi = EMW - 13.52 ppg. Obtain benchmark ECDs ~ 100 rpm - 9.23 ppg. Apply -0.04 correction. 14:00 - 17:00 3.00 DRILL P PROD1 Directionally drill from 4,209' to 4,791' md. r 585 gpm, 1,740 psi on, 1,537 psi off, 100 rpm, 7k TO on, 6k TO off, WOB - 5-20k, PU - 120k, SO - 65k, RWT - 85k, AST - 0.31 hrs, ART - 1.01 hrs, CECD - 10.44 ppg, AECD - 9.94 ppg. 17:00 - 19:00 2.00 DRILL N RREP PROD1 Loss of MWD Signal. Pulsation dampener 1 ~ 2500 psi & 2 ~ 0 psi. Backream from 4,791' and to 4,183' Qust below casing shoe). 60 rpm, 5-6k TO, 290 gpm, 1650 psi. 19:00 - 19:30 0.50 DRILL N RREP PROD1 Cirulate bottoms up at casing shoe. 290 gpm, 620 psi. No rotation. 19:30 - 23:30 4.00 DRILL N RREP PROD1 Pull one more stand up to 4,124' and (into casing shoe). Blow down topdrive. Monitor well -static. Stab TIW valve. Take pumps offline and change out both pulsation dampeners. 23:30 - 00:00 0.50 DRILL N RREP PROD1 Pumps back online. Test MWD - OK. RIH dry from 4,124' and to 4,780' md. 3/3/2008 00:00 - 06:00 6.00 DRILL P PROD1 Directionally drill from 4,791' and - 6,220'. 585 gpm, 2,410 psi on, 2,037 psi off, 100 rpm, 8.6k TO on, 8.Ok TO off, WOB - 5-20k, PU - 130k, SO - 70k, RWT - 95k, CECD - 9.86, AECD - 10.73. Pump 25 bbl hi-vis sweeps aroud at 5,300' & 6,100' md. -10% cutttings increase once sweeps back across shakers. 06:00 - 12:00 6.00 DRILL P PROD1 Directionally drill from 6,220' and - 7,367'.- 585 gpm, 2,600 psi on, 2,385 psi off, 100 rpm, 10k TO on, 9k TO off, WOB - 10-15k, PU - 146k, SO - 83k, RWT - 106k, CECD - 10.14, AECD - 10.54. 12:00 - 15:45 3.75 DRILL P PROD1 Directionally drill from 7,367' - TD C~ 8,180' md. 585 gpm, 3,425 psi on, 3,143 psi off, 100 rpm, 11 k TO on, 10k TO off, WOB - 25k, PU - 160k, SO - 90k, RWT - 115k 15:45 - 16:30 0.75 DRILL P PROD1 Circulate open hole volume ~ 585 gpm, 3,130 psi. Reciprocating pipe in 15-20' strokes. 100 rpm, 10k TO. 16:30 - 00:00 7.50 DRILL P PROD1 Backream from TD ~ 8,180' to 6,742' md. i 100-300 fph 585 gpm, 2,900 psi, 100 rpm, 8-13k TO, RTW - 95k. Adjusting pulling speeds for torque and pressure as needed. Not packing off but getting torque increases up to 13k in some areas. 3/4/2008 00:00 - 03:15 3.25 DRILL P PROD1 Continue backreaming from 6,742' and - 6,160' md. 100-500 fph 585 gpm, 2,650 psi, 100 rpm, 8k TO, RTW - 95k. Adjusting pulling speeds for torque and pressure as needed. Still not packing off. Some torque increases up to 12k in areas. 03:15 - 03:30 0.25 DRILL P PROD1 Once Ghost Reamer in casing C~? 6,230' bit depth, bring a bottoms up to surface while backreaming slowly to 6,160. Run back down to kelly down ~ 6,200' md. CECD - 10.24, AECD - 10.18. Nnntea: siznzuus i:°azi rnn s ~ BP EXPLORATION Page 8 of 14 Operations Summary Report Legal Well Name: V-220 Common Well Name: V-220 Spud Date: 2/24/2008 Event Name: DRILL+COMPLETE Start: 2/21/2008 End: 3/11/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/11/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours' Task Code NPT Phase Description of Operations 3/4/2008 03:15 - 03:30 0.25 DRILL P PROD1 Shut down, Monitor well -Static. 03:30 - 08:00 4.50 DRILL P PROD1 Pull out of hole dry from 6,200' and to 995'. Monitor well at shoe for 10 minutes,static. PU - 135k, SO - 80k ~ 6,200' Occasional overpulls of up to 25k on first 3-5 stands. Rest of the hole cleaned up to 5-10k over. 08:00 - 10:00 2.00 DRILL P PROD1 PJSM. Lay down HWDP from 995' to 258'. 10:00 - 13:00 3.00 DRILL P PROD1 Lay down 8 3/4" BHA from 258'. Remove and secure radio-active sources. Flush and drain motor. Break and grade bit 3-3-WT-A-X-I-NO-TD 13:00 - 14:00 1.00 DRILL P PROD1 Clean and clear rig floor. Pull wear ring and set test plug. 14:00 - 16:00 2.00 BOPSU P RUNPRD Change upper rams from 3-1/2" x 6" variables to 7" casing s. Change bales, bring cement head and casing running equipment to floor. 16:00 - 17:00 1.00 BOPSU P RUNPRD Rig up and test 7" rams to 250 psi low, 4,000 psi hi - OK. Rig down test equipment. AOGCC rep John Crisp waived witness of test. Witnessed by NAD TP Ronnie Dalton & BP WSL Blair Neufeld. 17:00 - 20:00 3.00 CASE P RUNPRD Make dummy run with 7" hanger and landing joint. Rig up to run casing. 20:00 - 00:00 4.00 CASE P RUNPRD PJSM. Pick up and make up (Baker Lok) 7" shoe track. Check floats - OK. Continue running in hole ~ 1.5 minutes per joint with 7" 26# L-80 BTC-M casing to 2,006'. Fill each joint. Make up casing to mark with average make-up torque of 8,500 fUlbs. Used BOL-2000 M pipe lubricant. 49 total joints of BTC-M casing. 3/5/2008 00:00 - 01:00 1.00 CASE P RUNPRD Continue running in hole ~ 1.5 minutes per joint with joints 50-60 of 7" 26# L-80 BTC-M casing and crossover joint to 2,498'. Fill each joint. Make up casing to mark with average make-up torque of 8,500 ft/Ibs. Used BOL-2000 M pipe lubricant. 60 total joints of BTC-M casing. 01:00 - 01:30 0.50 CASE P RUNPRD Circulate 1.5 bottoms up while rigging up torque turn equipment for TC-II. 210 gpm, ICP - 380 psi, FCP - 320 psi. 01:30 - 04:00 2.50 CASE P RUNPRD Continue running in hole C~? 1.5 minutes per joint with 7" 26# L-80 TCII casing from 2,498' to 4,173' (just inside casing shoe). Fill each joint. Torque Turn casing to make-up torque of 10,100 Wlbs. Used JetLube Seal Guard pipe lubricant. 41 joints of TC-II casing run so far. 04:00 - 04:30 0.50 CASE P RUNPRD Circulate 1.5 bottoms up at casing shoe. 220 gpm, ICP - 500 psi, FCP - 400 psi. 04:30 - 05:00 0.50 CASE P RUNPRD Run into open hole C~ 2 minutes per joint with 7" 26# L-80 TCII casing from 4,173' to 4,250'. Fill each joint. 05:00 - 06:30 1.50 CASE N SFAL RUNPRD Trouble shoot pipe skate. 06:30 - 15:45 9.25 CASE P RUNPRD Continue running in hole @ 2 minutes per joint with 7" 26# L-80 TCII casing from 4,250' to 8,144'. Fill each joint and break circulation every 10 joints for 3 minutes. Torque Turn casing to make-up torque of 10,100 ft/Ibs. Used JetLube Seal Guard pipe lubricant. 139 total joints of TC-II casing. 15:45 - 16:00 0.25 CASE P RUNPRD Pick u 7" han er landin 'oint and land casin on 8 174' Up wt 253k Dn Wt 90k rnnteo: s¢nzuua i:oo:u rm BP EXPLORATION Page 9 of 14 Operations Summary Report Legal Well Name: V-220 Common Well Name: V-220 Spud Date: 2/24/2008 Event Name: DRILL+COMPLETE Start: 2/21/2008 End: 3/11/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/11/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code., NPT ~ Phase 3/5/2008 115:45 - 16:00 I 0.251 CASE I P 16:00 - 17:00 1.00 CEMT P 17:00 - 18:30 1.50 CEMT P 18:30 - 19:30 I 1.001 CEMT I P 19:30 - 21:00 1.501 CEMT P 21:00 - 21:30 ~ 0.50 ~ CASE P Description of Operations RUNPRD HES Float Shoe - Bottom ~ 8,174' 2 Jt 7", 26#, L-80 BTC-Mod (#1-2) HES Float Landing Collar - Top ~ 8,090' 22 Jts 7", 26#, L-80 BTC-Mod (#3-24) 7", 26#, L-80 BTC-Mod Marker Pup Jt. w/ RA ~ 7,175' 36 Jts 7", 26#, L-80 BTC-Mod (#25-60) 1 Jt 7", 26#, L-80 TC-II X BTC-M Crossover jt. @ 5,675' tea 7", 26#, L-80 TC-II Pup Joints (14.81' & 4.81') 139 Jts 7", 26#, L-80 TC-II (#1 - 139) 7" 26# L-80 TC-II Pup Jt. FMC Hanger 70ea stop rings & 143ea 7-1/8" x 8-1/4" Rigid Straight Blade Centralizers: BTC-M Joint #1 - 2 Centralizers locked down 5' from shoe, BTC-M Joint #2-24 -tea floating seperated by stop ring mid joint. BTC-M Marker Joint - 1 free floating BTC-M joints #25-60 -tea floating seperated by stop ring mid joint. XO Joint -tea floating seperated by stop ring mid joint. TC-II Pups - 1 ea free floating TC-II Joints #1-9 -tea floating seperated by stop ring mid joint. RUNPRD Rig down Frank's tool. Make up cementing head. RUNPRD Break circulation. Sta a um s u to 5 b m, 640 psi. Condition mud for cement. Held cementing PJSM while circulating. Reciprocate casing in 15 ft strokes. PU - 225k, SO - 90k. RUNPRD Switch to Dowell. Pump 5 bbls water. Pressure test lines to 4,000 psi - OK. Pump 33 bbls 10.0 ppg of MudPush II spacer ~ 5 bpm, 685 psi. Batch mix and pump 38 bbls of 11.0 ppg LiteCrete lead cement Cud 4.0 bpm avg, 488 max psi, followed by 70.0 bbls of Class "G" 15.8 ppg tail cement ~ 4.5 bpm avg, 410 psi. Shut down & wash up Ines to 'T' with water. RUNPRD Switch to rig and displace cement with 307 bbls of 9.0 ppg rine. 1st 267 bbls ~ 5 bpm, 330 psi ICP. Stopped reci rocatin and landed casin with 283 bbls awa . PU - 180k, SO - 65k. Back pumps off to 2 bpm w/ 40 bbls left to displace & back down to 1 bpm w/ 10 bbls left. Bumped plug at 5540 strokes. Final circulating pressure of 1,409 psi. CIP C~3 20:58 hr. Full returns during all of circulating, cementing, and displacement. RUNPRD Pressure up casing to 4,000 psi and hold for 30 minute test - 21:30 - 23:00 1.501 CEMT P 23:00 - 00:00 1.00 WHSUR P 3/6/2008 00:00 - 01:00 1.00 BOPSU P 01:00 - 01:30 ~ 0.501 BOPSUFjP RUNPRD Rig down cement head. Laydown landing joint and rig down casing equipment. RUNPRD Install 7" Packoff and run in lock down screws. Torque to 450 ft-Ibs. Test to 5000 psi for 30 min., Good Test. RUNPRD Change Upper Pipe Rams to 3 1/2 x 6 variables & prepare to test. RUNPRD Conduct LOT down 9-5/8" x 7" annulus to 13.82ppg. Pump total of 3 bbls during LOT. Printed: 3/27/2008 1:56:27 PM BP EXPLORATION Page 10 of 14 Operations Summary Report Legal Well Name: V-220 Common Well Name: V-220 Spud Date: 2/24/2008 Event Name: DRILL+COMPLETE Start: 2/21/2008 End: 3/11/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/11/2008 Rig Name: NABOBS 9ES Rig Number: Date. ~ From - To~ Hours Task 'Code NPT Phase Description of Operations 3/6/2008 01:30 - 02:30 1.00 BOPSU P RUNPRD Finish changing upper pipe rams to 3 1/2 x 6 variables & prepare to test w/ 3.5" and 4" test joints to 4,000 psi. 02:30 - 03:30 1.00 BOPSU P RUNPRD Test upper pipe rams w/ 3.5" and 4" test joints to 300 psi & 4,000 psi. Witness of test waived by AOGCC Rep. John Crisp. Test witnessed by BP WSL Matt Martyn & NAD TP Chris Page. 03:30 - 04:00 0.50 BOPSU P RUNPRD Clean and clear rig floor of BOPE testing equipment. 'Note: Outside of critical path, inject 2 bbls used LSND mud into OA ~ 0330 hrs. 150 psi increase in leak off pressure. 04:00 - 05:00 1.00 PERFO P OTHCMP RU equipment for DPC perforating. 'Note: Outside of critical path, inject 2 bbls used LSND mud into OA ~ 0500 hrs. Noted another 125 psi increase in leak off pressure. 05:00 - 07:30 2.50 PERFO P OTHCMP PJSM. Pick up and make up 4.5" HSD Power Jet 4505 5 SPF DPC erforatin uns 19 ea loaded or artial uns, 12 ea blanks, includin 2 ea blank unchers ,Firing head, XO, bumper sub, MWD, XO, 1-stand 4" DP, tea singles 4" DP, 10 ft pup joint. Bottom nose to 10' pup = 884'. 07:30 - 09:30 2.00 PERFO P OTHCMP RIH on 4" DP to 2,585' md. `SIMOPS -Inject 118 bbls 9.1 ppg LSND down OA to clear annulus. ICP - 1240psi, FCP - 810psi. 09:30 - 10:00 0.50 PERFO P OTHCMP Failed several attempts to shallow hole test MWD. Appears to need deeper test. 10:00 - 11:00 1.00 PERFO P OTHCMP RIH on 4" DP to 4,560' md. * SIMOPS - RU Little Red Hot Oil Services & Freeze protect OA w/ 85 bbls 40 De F dead crude. 11:00 - 11:30 0.50 PERFO P OTHCMP Shallow hole test MWD. Test good - 250 gpm 575 psi. 11:30 - 15:00 3.50 PERFO P OTHCMP Run in hole with DPC pert assembly & tag up on float collar at 8,087'. 15:00 - 17:00 2.00 PERFO P OTHCMP Log to correlate depth to reference log -MWD Realtime field print 3-Mar-2008. 280 gpm, 1050 psi. 1ft depth correction needed. Log into position & set on depth w/ Top shot C~_ 7 214' Bottom nose ~ 7 855'. DPM. 17:00 - 17:30 0.50 PERFO P OTHCMP PJSM with all hand prior to firing guns. Perforate well. Initiate firing sequence by pump and bleed. Wait 5 minutes for guns to fire. ,..Good indication of puns firing. Well initially lost 4 bbls then went on a 8-9 bph static loss rate. Perforation intervals: Nb - 7214 - 7238' - OA - 7416 - 7474' OBa - 7516 - 7558' OBb - 7580 - 7606' OBc - 7666 - 7694' OBd - 7738 - 7792' OBe - 7828 - 7854' 'Pert depths as per Realti a LWD log 17:30 - 18:00 0.50 PERFO P OTHCMP POH 7 stands to bring bottom nose above top shot at 7,214' md. 18:00 - 19:00 1.00 PERFO P OTHCMP Circulate surface to surface 280 gpm, 970 psi. Brine returns smelled of perforations, but no other debris on bottoms up. Dynamic losses during circulation started at 19 bph and slowed to 15 bph by end of circulation. Shut down, monitor well -static losses ~ 8.5 bph. Blow down top drive. Printed: 3/27/2008 1:56:27 PM ~ ~ BP EXPLORATION Page 11 of 14 Operations Summary Report Legal Well Name: V-220 Common Well Name: V-220 Spud Date: 2/24/2008 Event Name: DRILL+COMPLETE Start: 2/21/2008 End: 3/11/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/11/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To ,Hours Task Code ! NPT Phase Description of Operations 3/6/2008 19:00 - 00:00 5.00 PERFO P OTHCMP POH Laying down drillpipe to pipeshed 1x1 from 7,214' - 3,868' md. PU - 140k, SO - 80k. Static loss rate 8 bph. Total losses for da - 49 bbls. 3/7/2008 00:00 - 00:30 0.50 PERFO P OTHCMP RIH w/ remaining stands from derrick from 3,868' - 4,793' md. 00:30 - 04:30 4.00 PERFO P OTHCMP POH Laying down drillpipe to pipeshed 1x1 from 4,793' - 1,234' md. 04:30 - 05:30 1.00 PERFO P OTHCMP Cut & slip drilling line. 05:30 - 06:00 0.50 PERFO P OTHCMP Service top drive, drawwaorks,and crown. 06:00 - 07:00 1.00 PERFO P OTHCMP POH laying down drill pipe from 1225' to 718'. 07:00 - 12:00 5.00 PERFO P OTHCMP PJSM. Lay down all guns, crossovers & firing head. All shots fired er desi n. No shots seen outside of scallop. No trapped pressure in any guns. 12:00 - 13:00 1.00 PERFO P OTHCMP Clean and clear rig floor of perforating equipment. 13:00 - 14:00 1.00 EVAL P OTHCMP Service top drive, change out safety cables and service loop cooler hose. 14:00 - 15:30 1.50 EVAL P OTHCMP PJSM. Rig up Schlumberger E-Line unit and 6.16" OD Gauge ring /Junk basket tools. 15:30 - 16:30 1.00 EVAL P OTHCMP RIH w! JB/GR to 2,175' and unable to pass. POH to change out gauge ring. 16:30 - 18:00 1.50 EVAL P OTHCMP RIH w/ 5.93" OD oauae ring without trouble from surface to TD Tao ~ 8.080' md. POH. Less than 1/2 cup of debris in 18:00 - 21:00 3.00 EVAL P 21:00 - 00:00 3.00 EVAL P 3/8/2008 100:00 - 08:30 I 8.50 I EVAL I P 08:30 - 09:30 1.00 EVAL P 09:30 - 10:30 1.00 BUNCO 10:30 - 13:00 2.50 BUNCO 13:00 - 00:00 I 11.001 RU 3/9/2008 ~ 00:00 - 11:30 ~ 11.50 ~ RUN 11:30 - 00:00 ~ 12.50 ~ RUN basket. OTHCMP RIH w/ 6.16" OD gauge ring after adding a centralizer below the logging head to help centralize the tool. The guage length on this ring is 6" and eccentered tool could be causing gauge ring to hang up. Able to RIH without trouble from surface to top pert @ 7,214' before setting down and unable to fall past. 'i Work tools for 30-45 minutes. POH. OTHCMP f~IH w/ 6.125" OD cLauge ring after hot shot arrived w/ ring. RIH w/o roblems to TD to C~ 8,070' md. POH. 1 cup of soft mush debris in basket. *Note Losses C~ less than 1 bph. 27 bbls lost to formation for the da . OTHCMP _ Run in hole with USIT to in tools to 7 900'. Log Hi-Res pass from 7,982' and to 7,100' md. Log standard resolution pass from 8,030' to surface for primary depth control. Logs indicated to of channeled cement ~ -4,175', with unchanneled cement to ~ -4 328'. Note: 9-5/8" casin shoe de th OTHCMP Rig down Schlumberger E-Line unit. RUNCMP Pull wear bushing. Make dummy run w/tubing hanger. RUNCMP Rig up tubing running and I-wire equipment. * Note: Fluid losses less than 1 bph. Losses for the morning were 4 b I RUNCMP PJSM. Run in hole with completion jewelry to 419'. Baker Lok'd all 5 connections below bottom packer. Dope all other connections w/Jet Lube Seal Guard. Test line connections to 5,000 psi - OK. Test I-wire continuity - OK. Torque turn all connections to 2,300 ft-Ibs. * Note: Fluid losses for evening 1 bbl. RUNCMP Continue to make up completion jewelery (6 packers. 5 ,gauges, 8 Ni les, 12 mandrels &RIH. Current depth 832' RUNCMP PJSM. Continue running in hole with 3.5" 9.2# L-80 TCII 6 packer completion from 832'to 6,127'. Check 1-wire continuity Printed: 3/27/2008 1:56:27 PM • BP EXPLORATION Page 12 of 14 Operations Summary Report Legal Well Name: V-220 Common Well Name: V-220 Spud Date: 2/24/2008 Event Name: DRILL+COMPLETE Start: 2/21/2008 End: 3/11/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/11/2008 Rig Name: NABOBS 9ES Rig Number: Date .From - To 'Hours Task Code NPT Phase Description of Operations 3/9/2008 11:30 - 00:00 12.50 BUNCO P RUNCMP every 1,000'. Made up TCII connections to 2,300 ft/Ibs torque. Used Jet Lube Seal Guard pipe dope. PU - 80k, SO - 55k. Loss rate continues to be 1 BPH while runnin in the hole. 3/10/2008 00:00 - 04:00 4.00 BUNCO RUNCMP Continue running in hole with 3.5" 9.2# L-80 TCII 6 packer completion from 6,127' and to planned setting depth of 7,940'. Space out with extra joint in preparation for E-Line correlation log and set in slips. Check I-wire continuity every 1,000'. Made up TCII connections to 2,300 ft/Ibs torque. Used Jet Lube Seal Guard pipe dope. PU - 95k, SO - 65k. Loss rate continues to be 1 BPH while running in the hole. 04:00 - 06:00 2.00 BUNCO RUNCMP Rig up Schlumberger E-Line w/ pack-off and pump-in sub for pressure control. Make up GR/CCUPress/Temp tool. 06:00 - 09:30 3.50 BUNCO RUNCMP Run in hole with GR/CCUPresslTemp tool to correlate packers. Rlh to 7490' & log up to 7100'. Adjust for wireline 2',repeat pass. After adjustment log shows packers 2'high of required setting depth. 09:30 - 12:00 2.50 BUNCO RUNCMP Add 2.06' pup jt to bottom of #225. Make up tubing hanger and landing joint. Terminate I-wire and test connections to 5,000 psi - OK. Test I-wire continuity - OK. land tubing. Item: 3.5" 9.2 #WLEG, 3.5" TC-II set @ 7,942.5'. Tops: 3.5" 9.2 #WLEG, 3.5" TC-II C~3 7,941'. 3.5" HES 'XN' Nipple: ID 2.750 @ 7,920'. 3.5" HES 'X' Nipple: 2.813" ID RHC-M Plug ~ 7,900'. GLM #1 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch C~ 7,871'. 3.5" HES 'X' Nipple: 2.813" ID ~ 7,850'. 3.5" NDPG Single Sub Ser# BWGC-486 ~ 7,833' r #1 acker ~ 7 819' dth P k 7" HES i l f 3 " •-~ p , . ru ac e ng e ee x s .5 GLM #2 - 3.5" x 1.5" MMG-W w/ RD Dummy- R latch 7,800'. GLM #3 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch C~ 7,762'. 3.5" HES 'X' Nipple: 2.813" ID ~ 7,746'. 3.5" NDPG Multi Sub Ser# BXGC-104 C~3 7,734'. 720' 5" x 7" HES Dual feedthru Packer #2 packer ~ 7 3 , . . GLM #4 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 7,691' 1 jts 3.5" 9.2# L-80 TC-II Tubing (#1 ). 3.5" HES 'X' Nipple: 2.813" ID ~ 7,623'. GLM #5 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 7,599'. 3.5" NDPG Multi Sub Ser# BXGC-116 ~ 7,582'. #3 ack C«~ 7 568' dth P k " HES D l f " -~ er , . ru ac er p ua ee 3.5 x 7 GLM #6 - 3.5" x 1.5" MMG w/ RD Dummy- RK latch ~ 7,550'. GLM #7 - 3.5" x 1.5" MMG w/ RD Dummy- RK latch ~ 7,519'. 3.5" NDPG Multi Sub Ser# BBXGC-103 ~ 7,506'. 3.5" HES 'X' Nipple: 2.813" ID ~ 7,503'. -~' 3.5" x 7" HES Dual feedthru Packer #4 packer ~ 7,487'. GLM #8 - 3.5" x 1.5" MMG w/ RD Dummy- RK latch @ 7,469'. 1 jts 3.5" 9.2# L-80 TC-II Tubing (#2). Printed: 3/27/2008 1:56:27 PM BP EXPLORATION Page 13 of 14 Operations Summary Report Legal Well Name: V-220 Common Well Name: V-220 Spud Date: 2/24/2008 Event Name: DRILL+COMPLETE Start: 2/21/2008 End: 3/11/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/11/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To I Hours Task '.Code NPT Phase Description of Operations 3/10/2008 09:30 - 12:00 2.50 BUNCO RUNCMP 3.5" 9.2# L-80 TC-II Pup (Centralizer w/PIP tag) C~ 7,417'. GLM #9 - 3.5" x 1.5" MMG w/ RD Dummy- RK latch ~ 7,407'. 3.5" NDPG Multi Sub Ser# BXGC-105 ~ 7,390'. ---~,• 3.5" x 7" HES Dual feedthru Packer #5 packer C«~ 7,376'. 3.5" HES 'X' Nipple: 2.813" ID ~ 7,355'. GLM #10 - 3.5" x 1.5" MMG w/ RD Dummy- RK latch ~ 7,327'. 3 jts 3.5" 9.2# L-80 TC-II Tubing (#3 - 5 ). GLM #11 - 3.5" x 1.5" MMG w/ RD Dummy- RK latch ~ 7,201'. 3.5" NDPG Multi Sub Ser# BXGC-117 ~ 7,183'. „~ --~' 3.5" x 7" HES Dual feedthru Packer #6 packer C~ 7,169'. ~ PG 3.5" HES 'X' Nipple: 2.813" ID ~ 7,149'. GLM #12 - 3.5" x 1.5" MMG w/ DCR-1 Shear- RKP latch ~ 7,120'. 117 jts 3.5" 9.2# L-80 TC-II Tubing (#6 - 122 ). 3.5" HES 'X' Nipple: 2.813" ID ~ 3,352'. 102 jts 3.5" 9.2# L-80 TC-II Tubing (# 123- 224 ). 2 ea 3.5", 9.2#, L-80 TC-II Space out Pups 1 jt 3.5" 9.2# L-80 TC-II Tubing (# 225 ) 3.5" 9.2# L-80 TC-II Hanger Pup 4.5" X 3.5" TC-I I Crossover FMC Tubing Hanger w/4 1/2" TC-II Lifting Threads Up wt = 98k, Dn wt = 60k 130 full Cannon clamps, 32 Half clamps 12:00 - 14:30 2.50 BUNCO RUNCMP Drop 1 5/16" ball and rod down tubing. Pressure up to 4000 nsi to set packers record and chart tuhinn test 30 minutes. Bleed tubing to 2500 psi and pressure annulus to 4000 psi. hold for 30 minutes an c a Test witness waive y rep John Crisp. Test witnessed by BP rep Blair Neufeld and Nabors Drilling rep Ronnie Dalton. Bleed of annulus and tubing to 0 psi. Pressure up annulus,Shear DCK-1 at 2250 psi. Pump 2 bbls in each direction. 14:30 - 15:30 1.00 BOPSU P RUNCMP Set TWC and test from below to 1000psi. Blow down surface equipment 15:30 - 18:00 2.50 BOPSU P RUNCMP Nipple Down BOP. 18:00 - 22:00 4.00 WHSUR P RUNCMP PJSM. Nipple up tree adaptor. Test same to 5,000 psi - OK. 22:00 - 23:30 1.50 WHSUR P RUNCMP Terminate I-wires on tree adaptor. Test connections to 5,000 psi - OK. Test I-wire continuity - OK. 23:30 - 00:00 0.50 WHSUR P RUNCMP Nipple up double master valve dry hole tree. 3/11/2008 00:00 - 00:30 0.50 WHSUR P RUNCMP Nipple up double master valve dry hole tree. 00:30 - 01:30 1.00 WHSUR P RUNCMP PJSM. Rig up, fill tree with diesel and test to 250 psi low, 5,000 psi high - OK. 01:30 - 04:00 2.50 WHSUR N WAIT RUNCMP Wait on Drill Site Maint. to show up and lubricate out TWC valve. Lubricator is tied pup on a job at Doyon 14. Perform misc. tasks while preparing for rig move. 04:00 - 05:30 1.50 WHSUR P RUNCMP PJSM. Ri u DSM lubricator. Test same to 500 si - OK. Pull 2-way check valve. Rig down lubricator. 05:30 - 06:00 0.50 WHSUR P RUNCMP PJSM. Rig up to circulate clean and corrosion inhibited brine. 06:00 - 07:00 1.00 WHSUR P RUNCMP Reverse circulate 62 bbls of clean 9.0 ppg brine, followed by 113 bbls of clean brine treated with corrosion inhibitor. rnntea: ~iznzuua ~:oo:u rnn ~1 BP EXPLORATION Page 14 of 14 Operations Summary Report Legal Well Name: V-220 Common Well Name: V-220 Spud Date: 2/24/2008 Event Name: DRILL+COMPLETE Start: 2/21/2008 End: 3/11/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/11/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/11/2008 06:00 - 07:00 1.00 WHSUR P RUNCMP 3 bpm, 379 psi. 07:00 - 08:00 1.00 WHSUR P RUNCMP PJSM. Rig up and test LRHOS lines to 3,500 psi - OK. Reverse 100 bbls of 50"` diesel for tubing and IA freeze protection to 2,850' MD, 2,200' TVD. 2.2 bpm, 275 psi ICP, 525 psi FCP. 08:00 - 09:30 1.50 WHSUR P RUNCMP U-tube diesel back to tubing. 09:30 - 10:30 1.00 WHSUR P RUNCMP Rig up DSM lubricator. Install BPV. Test to 1,000 psi from below - OK. 10:30 - 12:00 1.50 WHSUR P RUNCMP Install VR plugs in IA and OA. Secure tree and cellar. 'Rig released from V-220i operations ~ 12:00 hr, 3/11/2008 Printetl: 3/27/2008 1:56:'L/ PM BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: V-220 Common Name: V-220 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 3/2/2008 LOT 4,209.0 (ft) 2,852.0 (ft) 8.80 (ppg) 700 (psi) 2,004 (psi) 13.52 (ppg) • Printed: 3/27/2008 1:56:20 PM p ~_-= r ~: ~_~_~_}. V-220 Su Report Date: March 3, 2006 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure/Slot: V-Pad / Plan V Slot (N-Z+1) Well: V-220 Borehole: V-220 UWI/API#: 500292338300 Survey Name /Date: V-220 /February 26, 2008 Tort /AHD / DDI / ERD ratio: 133.538° / 5836.98 ft / 6.096 / 1.141 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaULong: N 7019 41.515, W 14915 49.043 Location Grid NIE Y/X: N 5970157.670 ftUS, E 590796.670 ftUS Grid Convergence Angle: +0.69340350° Grid Scale Factor: 0.99990937 c umberger Report Survey /DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 29.870° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 81.10 ft relative to MSL Sea Bed /Ground Level Elevation: 52.60 ft relative to MSL Magnetic Declination: 23.086° Total Field Strength: 57645.060 nT Magnetic Dip: 80.873° Declination Date: February 26, 2008 Magnetic Declination Model: BGGM 2007 North Reference: True North Total Corr Mag North -> True North: +23.086° Comments Measured Inclination Azimuth SulrSea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft tt ft ft de 00 tt ftUS ttUS Hlt 0.UU U.UU U.UU -tit .lU U.UU U.UU U.UU U.UV U.UU U.UU U.VV by/Ul5/.tl/ byV /yt). t)/ N /U 1y 41.blb W 14y 154y.V4J GYD CT DMS 100.00 0.54 18.30 18.90 100.00 0.46 0.47 0.47 0.45 0.15 0.54 5970158.12 590796.81 N 70 19 41.519 W 149 15 49.039 200.00 0.86 15.32 118.89 199.99 1.65 1.69 1.69 1.62 0.49 0.32 5970159.29 590797.14 N 70 19 41.531 W 149 15 49.029 300.00 3.05 21.15 218.83 299.93 5.01 5.10 5.10 4.82 1.65 2.20 5970162.51 590798.26 N 70 19 41.562 W 149 15 48.995 400.00 3.38 20.54 318.67 399.77 10.54 10.71 10.71 10.07 3.65 0.33 5970167.78 590800.19 N 70 19 41.614 W 149 15 48.937 500.00 4.94 22.37 418.40 499.50 17.72 17.96 17.96 16.81 6.32 1.57 5970174.55 590802.79 N 70 19 41.680 W 149 15 48.859 600.00 7.03 23.22 517.85 598.95 28.07 28.39 28.38 26.41 10.37 2.09 5970184.21 590806.72 N 70 19 41.774 W 149 15 48.741 700.00 9.24 25.70 616.84 697.94 42.16 42.54 42.51 39.27 16.27 2.24 5970197.13 590812.46 N 70 19 41.901 W 149 15 48.569 800.00 12.26 29.12 715.07 796.17 60.79 61.18 61.10 55.79 24.92 3.09 5970213.75 590820.91 N 70 19 42.063 W 149 15 48.316 MWD+IFR+MS 854.79 13.74 23.38 768.46 849.56 73.07 73.50 73.40 66.84 30.33 3.58 5970224.87 590826.19 N 70 19 42.172 W 149 15 48.158 945.77 15.41 28.91 856.51 937.61 95.89 96.37 96.26 87.34 40.46 2.39 5970245.49 590836.07 N 70 19 42.374 W 149 15 47. 1040.33 18.22 34.21 947.03 1028.13 123.20 123.71 123.43 110.57 54.85 3.38 5970268.89 590850.17 N 70 19 42.602 W 149 15 47 1134.73 20.52 35.41 1036.08 1117.18 154.39 155.01 154.47 136.27 72.74 2.47 5970294.79 590867.75 N 70 19 42.855 W 149 15 46.9 1229.74 23.66 31.35 1124.11 1205.21 190.03 190.73 190.05 166.13 92.31 3.67 5970324.89 590886.96 N 70 19 43.149 W 149 15 46.349 1324.60 27.21 27.61 1209.77 1290.87 230.75 231.45 230.77 201.62 112.27 4.11 5970360.61 590906.48 N 70 19 43.498 W 149 15 45.766 1419.52 29.91 25.56 1293.13 1374.23 276.04 276.82 276.10 242.20 132.55 3.03 5970401.44 590926.26 N 70 19 43.897 W 149 15 45.174 1513.75 33.69 22.83 1373.21 1454.31 325.43 326.46 325.60 287.50 152.83 4.29 5970446.98 590946.00 N 70 19 44.342 W 149 15 44.582 1612.31 38.19 23.57 1452.98 1534.08 382.87 384.29 383.26 340.65 175.63 4.59 5970500.39 590968.15 N 70 19 44.865 W 149 15 43.916 1705.80 43.41 23.73 1523.73 1604.83 443.58 445.36 444.22 396.59 200.13 5.58 5970556.61 590991.97 N 70 19 45.415 W 149 15 43.201 1804.51 44.74 23.05 1594.64 1675.74 511.80 514.02 512.78 459.61 227.39 1.43 5970619.95 591018.46 N 70 19 46.035 W 149 15 42.405 1900.56 47.45 21.36 1661.25 1742.35 580.37 583.22 581.81 523.68 253.51 3.09 5970684.33 591043.80 N 70 19 46.665 W 149 15 41.642 1997.49 52.93 21.45 1723.28 1804.38 653.99 657.65 656.05 592.97 280.68 5.65 5970753.94 591070.13 N 70 19 47.346 W 149 15 40.849 2091.69 56.57 21.21 1777.64 1858.74 730.05 734.56 732.79 664.62 308.65 3.87 5970825.91 591097.23 N 70 19 48.051 W 149 15 40.032 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V Slot (N-Z+1)\V-220\V-220\V-220 Generated 4/3/2008 1:53 PM Page 1 of 3 Comments Measured Inclination Azimuth SutrSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft it it ft de 00 ft ftUS ftUS 2187.53 61.04 Z4.U5 182/.LS 1908.38 811.35 818.52 814.89 /4U.L4 340.23 5.31 59/V9U1.91 59112/.89 N /U 1948. /95 W 1491539.110 2283.91 61.73 23.96 1873.43 1954.53 895.52 901.13 899.29 817.53 374.65 0.72 5970979.60 591161.36 N 70 19 49.555 W 149 15 38.105 2379.04 61.40 24.01 1918.73 1999.83 978.73 984.78 982.94 893.96 408.65 0.35 5971056.43 591194.44 N 70 19 50.307 W 149 15 37.112 2475.02 61.98 26.45 1964.26 2045.36 1062.94 1069.28 1067.42 970.39 444.67 2.32 5971133.28 591229.53 N 70 19 51.058 W 149 15 36.060 2570.59 62.34 29.11 2008.89 2089.99 1147.38 1153.78 1151.80 1045.15 484.06 2.49 5971208.50 591268.00 N 70 19 51.793 W 149 15 34.910 2666.97 61.76 28.97 2054.07 2135.17 1232.51 1238.92 1236.73 1119.58 525.39 0.62 5971283.42 591308.42 N 70 19 52.525 W 149 15 33.704 2763.02 62.41 30.98 2099.04 2180.14 1317.38 1323.79 1321.31 1193.09 567.79 1.97 5971357.44 591349.93 N 70 19 53.248 W 149 15 32.465 2858.54 61.70 30.96 2143.80 2224.90 1401.75 1408.17 1405.32 1265.45 611.21 0.74 5971430.30 591392.47 N 70 19 53.960 W 149 15 31.197 2953.97 60.95 31.41 2189.59 2270.69 1485.45 1491.90 1488.70 1337.07 654.56 0.89 5971502.44 591434.95 N 70 19 54.664 W 149 15 29.931 3049.34 62.20 32.90 2234.99 2316.09 1569.25 1575.77 1572.12 1408.07 699.21 1.90 5971573.97 591478.72 N 70 19 55.363 W 149 15 28.628 3144.42 62.05 32.82 2279.44 2360.54 1653.18 1659.81 1655.66 1478.67 744.81 0.17 5971645.11 591523.46 N 70 19 56.057 W 149 15 27. 3239.46 62.02 33.05 2324.01 2405.11 1737.00 1743.76 1739.14 1549.12 790.45 0.22 5971716.10 591568.24 N 70 19 56.750 W 149 15 25 ~ 3335.15 61.30 32.70 2369.43 2450.53 1821.11 1827.98 1822.94 1619.86 836.16 0.82 5971787.38 591613.09 N 70 19 57.445 W 149 15 24.628 3427.80 60.77 31.94 2414.30 2495.40 1902.09 1909.04 1903.70 1688.36 879.50 0.92 5971856.39 591655.60 N 70 19 58.119 W 149 15 23.362 3523.31 60.43 31.75 2461.19 2542.29 1985.25 1992.25 1986.68 1759.04 923.41 0.40 5971927.59 591698.64 N 70 19 58.814 W 149 15 22.080 3618.85 62.61 32.73 2506.74 2587.84 2069.15 2076.22 2070.40 1830.06 968.21 2.45 5971999.15 591742.57 N 70 19 59.513 W 149 15 20.772 3714.53 62.03 32.99 2551.19 2632.29 2153.77 2160.95 2154.82 1901.24 1014.18 0.65 5972070.86 591787.68 N 70 20 0.212 W 149 15 19.429 3810.53 61.26 33.00 2596.78 2677.88 2238.12 2245.43 2239.01 1972.09 1060.19 0.80 5972142.26 591832.82 N 70 20 0.909 W 149 15 18.085 3905.48 60.63 32.38 2642.90 2724.00 2321.02 2328.43 2321.77 2041.95 1105.02 0.88 5972212.65 591876.79 N 70 20 1.596 W 149 15 16.776 4001.40 62.04 32.41 2688.91 2770.01 2405.10 2412.59 2405.73 2113.01 1150.11 1.47 5972284.25 591921.02 N 70 20 2.295 W 149 15 15.459 4097.69 62.10 32.00 2734.01 2815.11 2490.11 2497.67 2490.64 2184.99 1195.45 0.38 5972356.77 591965.48 N 70 20 3.003 W 149 15 14.135 4128.14 61.80 32.16 2748.33 2829.43 2516.96 2524.54 2517.47 2207.76 1209.72 1.09 5972379.71 591979.47 N 70 20 3.227 W 149 15 13.718 9-5/8" Csg C~ 4178'md 4206.25 60.25 31.29 2786.17 2867.27 2585.25 2592.87 2585.71 2265.88 1245.65 2.21 5972438.25 592014.70 N 70 20 3.798 W 149 15 12.668 4249.58 59.78 32.09 2807.82 2888.92 2622.77 2630.40 2623.19 2297.82 1265.37 1.93 5972470.42 592034.02 N 70 20 4.112 W 149 15 12.092 4344.71 60.72 32.28 2855.03 2936.13 2705.29 2712.99 2705.64 2367.72 1309.36 1.00 5972540.84 592077.16 N 70 20 4.800 W 149 15 10.807 4437.58 60.50 32.12 2900.60 2981.70 2786.14 2793.91 2786.43 2436.19 1352.48 0.28 5972609.82 592119.45 N 70 20 5.473 W 149 15 9.548 4530.80 59.30 31.70 2947.35 3028.45 2866.74 2874.56 2866.98 2504.65 1395.11 1.34 5972678.78 592161.24 N 70 20 6.146 W 149 15 8.302 4625.58 60.07 31.53 2995.19 3076.29 2948.52 2956.38 2948.73 2574.32 1438.00 0.83 5972748.97 592203.28 N 70 20 6.831 W 149 15 7.049 4721.39 60.62 32.27 3042.60 3123.70 3031.72 3039.64 3031.90 2645.01 1482.00 0.88 5972820.17 592246.42 N 70 20 7.527 W 149 15 5~ 4816.94 58.57 33.20 3090.95 3172.05 3114.03 3122.04 3114.15 2714.33 1526.55 2.30 5972890.02 592290.12 N 70 20 8.208 W 149 15 4. 4912.23 58.49 33.11 3140.70 3221.80 3195.17 3203.32 3195.25 2782.37 1571.00 0.12 5972958.59 592333.74 N 70 20 8.877 W 149 15 3.164 5006.26 60.75 34.24 3188.25 3269.35 3276.10 3284.43 3276.15 2849.87 1615.98 2.62 5973026.62 592377.90 N 70 20 9.541 W 149 15 1.850 5099.52 60.10 33.98 3234.28 3315.38 3356.98 3365.54 3357.01 2917.02 1661.47 0.74 5973094.31 592422.57 N 70 20 10.201 W 149 15 0.521 5195.20 60.40 33.04 3281.76 3362.86 3439.88 3448.61 3439.89 2986.28 1707.33 0.91 5973164.12 592467.58 N 70 20 10.882 W 149 14 59.182 5290.93 60.87 31.88 3328.70 3409.80 3523.23 3532.03 3523.23 3056.68 1752.10 1.16 5973235.04 592511.50 N 70 20 11.575 W 149 14 57.873 5386.16 60.83 30.41 3375.09 3456.19 3606.37 3615.20 3606.37 3127.85 1795.12 1.35 5973306.73 592553.64 N 70 20 12.275 W 149 14 56.617 5481.69 63.01 29.06 3420.06 3501.16 3690.65 3699.48 3690.65 3201.04 1836.91 2.60 5973380.41 592594.54 N 70 20 12.994 W 149 14 55.396 5577.32 61.60 29.08 3464.50 3545.60 3775.31 3784.15 3775.31 3275.05 1878.05 1.47 5973454.90 592634.78 N 70 20 13.722 W 149 14 54.194 5673.11 60.46 29.87 3510.90 3592.00 3859.11 3867.96 3859.11 3348.00 1919.28 1.39 5973528.34 592675.12 N 70 20 14.439 W 149 14 52.989 5769.20 61.08 29.33 3557.82 3638.92 3942.97 3951.81 3942.97 3420.91 1960.70 0.81 5973601.74 592715.65 N 70 20 15.156 W 149 14 51.779 5864.37 60.10 30.22 3604.55 3685.65 4025.87 4034.71 4025.87 3492.87 2001.87 1.31 5973674.19 592755.94 N 70 20 15.864 W 149 14 50.576 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V Slot (N-Z+1)\V-220\V-220\V-220 Generated 4/3/2008 1:53 PM Page 2 of 3 Comments Measured Inclination Azimuth Sub-Sea ND TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude 'i Longitude Depth Section Departure tt de de ft tt tt ft ft ft ft de 100ft ftUS ftUS J`JJ`J.~.125 bU.b l ~7V.U 1 JOJ I.OJ 3/JG. yJ 41 VO.yO 41 1 /.01 41 V0. ~0 JV04./ V LV4J. JV V.J/ J~/J/'fV. JV 6055.90 61.27 29.92 3698.44 3779. 54 4192.81 4201.65 4192. 81 3637.39 2085. 43 0.69 5973819. 69 6151.38 60.12 29.35 3745.17 3826. 27 4276.07 4284.91 4276. 07 3709.76 2126. 61 1.31 5973892. 54 6246.41 60.40 28.79 3792.31 3873. 41 4358.57 4367.43 4358. 57 3781.87 2166. 70 0.59 5973965. 14 6342.59 61.21 28.49 3839.23 3920. 33 4442.51 4451.39 4442. 52 3855.56 2206. 94 0.89 5974039. 30 6437.96 60.67 28.88 3885.55 3966. 65 4525.86 4534.75 4525. 86 3928.70 2246. 95 0.67 5974112. 90 6532.87 58.44 28.36 3933.64 4014. 74 4607.66 4616.57 4607. 67 4000.52 2286. 15 2.40 5974185. 19 6628.61 53.83 28.70 3986.97 4068. 07 4687.11 4696.04 4687. 12 4070.34 2324. 10 4.82 5974255. 46 6724.06 52.88 29.50 4043.94 4125. 04 4763.69 4772.63 4763. 70 4137.26 2361. 34 1.20 5974322. 82 6819.75 52.52 29.88 4101.93 4183. 03 4839.80 4848.75 4839. 82 4203.39 2399. 04 0.49 5974389. 39 6916.20 52.72 29.40 4160.49 4241. 59 4916.44 4925.39 4916. 46 4270.00 2436. 95 0.45 5974456. 45 7012.07 51.43 29.36 4219.41 4300. 51 4992.06 5001.01 4992. 08 4335.90 2474. 05 1.35 5974522. 78 7107.33 50.42 29.37 4279.45 4360. 55 5066.01 5074.96 5066. 03 4400.34 2510. 31 1.06 5974587. 66 7202.84 49.37 29.98 4340.98 4422. 08 5139.06 5148.01 5139. 08 4463.82 2546. 47 1.20 5974651. 56 7297.70 48.31 29.40 4403.41 4484. 51 5210.48 5219.43 5210. 50 4525.86 2581. 85 1.21 5974714. 02 7393.24 47.30 29.27 4467.58 4548. 68 5281.26 5290.21 5281. 28 4587.56 2616 .53 1.06 5974776. 13 7488.11 46.85 29.11 4532.19 4613. 29 5350.72 5359.68 5350. 74 4648.21 2650 .41 0.49 5974837. 18 7583.92 46.15 28.62 4598.14 4679. 24 5420.21 5429.18 5420. 23 4709.07 2683 .96 0.82 5974898. 43 7679.37 44.95 28.60 4664.98 4746. 08 5488.33 5497.31 5488. 36 4768.88 2716 .58 1.26 5974958. 64 7776.85 44.41 28.63 4734.30 4815. 40 5556.85 5565.85 5556. 89 4829.06 2749 .41 0.55 5975019. 19 7871.06 43.46 28.91 4802.14 4883. 24 5622.21 5631.22 5622 .25 4886.35 2780 .87 1.03 5975076. 86 7966.72 42.16 28.28 4872.32 4953. 42 5687.20 5696.23 5687 .24 4943.43 2811 .99 1.43 5975134. 30 8061.47 41.24 28.11 4943.06 5024. 16 5750.20 5759.26 5750 .25 4998.98 2841 .77 0.98 5975190. 21 Last Survey 8109.55 40.91 27.92 4979.30 5060. 40 5781.77 5790.85 5781 .83 5026.87 2856 .61 0.73 5975218 .27 TD (Projected) 8180.00 40.91 27.92 5032.55 5113. 65 5827.88 5836.98 5827 .95 5067.63 2878 .21 0.00 5975259 .29 Survey Type: Definitive Survey NOTES: GYD CT DMS - (Gyrodata -cont. drillpipe m/s -- Gyrodata pump-down multishot surveys with continuous tool (RGS-CT) in dril l-pipe.) MWD + IFR + MS - (In-field referenced MWD with mull-station analysis and correction appli ed in post-processi ng. Assumes a BHA sag correction is app lied to enhance inclination accuracy. ) Legal Descrip tion: Northing (Y) fftUSl Easting (X) fftUSl Surface : 4907 FSL 1503 FEL S11 T11 N R11 E UM 5970157.67 590796.67 BHL : 4694 FSL 3900 FEL S1 T11 N R11 E UM 5975259.29 593613.08 JJG/JV./J IV /V LV IV.J/ I YY IYJ IY'4J.JJ/ 592837.74 N 70 20 17.285 W 149 14 48.134 592878.03 N 70 20 17.997 W 149 14 46.931 592917.24 N 70 20 18.706 W 149 14 45.759 592956.59 N 70 20 19.430 W 149 14 44.583 592995.71 N 70 20 20.150 W 149 14 43.414 593034.03 N 70 20 20.856 W 149 14 42.268 593071.13 N 70 20 21.542 W 149 14 41.159 593107.56 N 70 20 22.200 W 149 14 40.071 593144.45 N 70 20 22.851 W 149 14 38.969 593181.54 N 70 20 23.506 W 149 14 37 593217.84 N 70 20 24.154 W 149 14 36. 593253.32 N 70 20 24.787 W 149 14 35.717 593288.71 N 70 20 25.412 W 149 14 34.660 593323.32 N 70 20 26.022 W 149 14 33.626 593357.25 N 70 20 26.628 W 149 14 32.612 593390.39 N 70 20 27.225 W 149 14 31.622 593423.20 N 70 20 27.823 W 149 14 30.641 593455.10 N 70 20 28.411 W 149 14 29.688 593487.19 N 70 20 29.003 W 149 14 28.728 593517.95 N 70 20 29.566 W 149 14 27.809 593548.37 N 70 20 30.128 W 149 14 26.899 593577.47 N 70 20 30.674 W 149 14 26.028 593591.97 N 70 20 30.948 W 149 14 25.595 593613.08 N 70 20 31.349 W 149 14 24.963 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V Slot (N-Z+1)\V-220\V-220\V-220 Generated 4/3/2008 1:53 PM Page 3 of 3 05/20/08 ~chlumherr~er Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh dk N0.4712 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 .... r1e~w ..a:.. MPB-04A 12021150 MEM PROD PROFILE _ ~y 04/17/08 1 it MPG-13 12021151 MEM INJECTION PROFILE ~C 04/18/08 1 1 Z-26A 11978454 MEM GLS ~(p -p 04/23/08 1 1 Z-29 11978453 MEM GLS - 04/22/08 1 1 Y-36 12005204 MEM GLS y _ 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 - J /p 05/10/08 1 1 X-16A 11975771 USIT L~ L 05/14/08 1 1 07-26 12061688 USIT - 05/16/08 1 1 05-34 11966251 USIT - 04/13/08 1 1 OS-23A 118966257 USIT ~ 05/13/08 1 1 S-33 11962596 USIT 04/15/08 i 1 V-223 12061688 CH EDIT PDC GR (USIT `~ - / 03/23/08 1 V-220 40016600 OH MWD/LWD EDIT a(~ _ 03/03/08 2 1 4-14A/S-37 40016545 OH MWD/LWD EDIT p~.-U ( / 02/18/08 2 1 05-22B 11628800 MCNL 10/22/07 1 1 05-13B 12021140 MCNL ~ 01/31!08 1 1 Z-10 12066520 RST ~ 04/10/08 1 1 D-10 11975766 RST 04/25/08 1 1 rya-e~.~G eyv nwvvrGCV~aG nGV G:r': 0: A:Vrv11YV HrvV rSCI URIV IIVV VIVC liVYi GHV11 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 "` ~ ' Date Delivered: ~,,,~ ~~ "~; '1~~.1; , Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~\ ~clumber~~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~, ........... / 4 !~ NO. 4645 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Endicott,Borealis 03/28/08 Well Job # Lo Descri lion Date BL Color co V-220 12031459 USIT ( 03/07!08 1 1 N-14A 12066514 RST 03/15/08 1 1 Z-112P61 40016350 OH MWD/LWD EDIT ~(~~_ j~-^,,,i ~~(l, 3 _ 01/29/08 2 1 r PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Servic 2525 Gambell Street, Suite 4 Anchorage, AK 5 3-2838 ATTN: Beth Received by: 2 J 04/09/08 ~~i y ~~~~~m~l~~~~~' 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 n~.e RI Cnlnr rtn 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 V - ~ (p C O 04/01/08 1 1 18-13B 12061689 PRODUCTION PROFILE '~_'-~ ~ 03/27/08 1 1 E-10A 11998994 USIT (~ '~ 03/28/08 1 1 02-12B 11628789 MCNL ,~ / ! U '- 08/21/07 1 1 15-45B 11963079 MCNL (~~- _ 02/14/08 1 1 V-220 12031459 CH EDIT PDC GR (USIT)~~j~ ((p ,d 03/07/08 1 V-214 40016214 OH MWD /LWD 04/01/08 2 1 -~ .. 1 ~ PLEASE AGKIVUWLEUIit F{tla1Y 1 tST JIUrv11VU r+rvu rsc i urovmu yrvc wr r cw~.n ~ v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ' ~~~.i Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 .~ ATTN: Beth \ Received b `r' ! gyro ata Gyrodata incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713,461-0920 March 6, 2008 State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: V-Pad, #V-220 Prudhoe Bay, Alaska i 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, {.~,9 fi `Ly ~, ~ l~J~f ~ Rob Shoup North American Regional Manager RSaf Serving the VVorl~wid2 ~ r-'CU'y i ~.a°~,~ t4~lih ~rec~s~~ai ~;;~r~P; ' ~'~~ ~~[atic~n ! 1 gyrodata ~yrodata incorporated 1682 W. Sam Houston Pkwy. N Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY REPORT BP V-Pad #V-220 Prudhoe Bay, AK AK0208G_108 25 Feb 2008 Servinythe;/V~ ~_, ~ut~ ~E 'i~ci~~ . t~ "~ec~5 ~ ~u;~ t~ e.;~.~,~r, ti `v' a~g_~~,o A Gyrodata Directional Survey for B.P. EXPLORATION Lease: V-Pad Well: V-220, Location: Nabors #9ES, Prudhoe Bay, Alaska Job Number: AK0208G 108 Run Date: 25 Feb 2008 Surveyor: Steve Thompson Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.328199 deg. N Longitude: 149.263623 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location • Horizontal Coordinates Calculated from Well Head Location B.P. Exploration Lease: V-Pad Well: V-220 Location: Nabors #9ES, Prudhoe Bay, Alaska Job Number: AK0208G 108 A Gyrodata Directional Survey MEASURED I N C L AZIMUTH BORE HOLE DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg. min. deg./ feet feet deg. feet 100 ft. 0.00 0.00 0.00 N 0 0 E 0.00 0.00 0.0 0.0 0.00 N 0.00 E -------------------- 0 - 800 FT. RAT --------------- E GYROSC ----------------------------------------------- OPIC MULTISHOT SURVEY ---------------------- --------------------- --------------- ----------------- ----------------------- ------------- ALL MEASURED DEPTHS AND COORDINATES REFERENCED FROM NABORS #9ES ROTAR ----------------------------------------------------------------------------------------------------------------------------- Y TABLE AT 81.10 FT. AMSL ------------------------------------------------------- ------------- 100.00 0.54 18.30 N 18 18 E 0.54 100.00 0.5 18.3 0.45 N 0.15 E 200.00 0.86 15.32 N 15 19 E 0.32 199.99 1.7 17.0 1.62 N 0.49 E 300.00 3.05 21.15 N 21 9 E 2.20 299.93 5.1 18.9 4.82 N 1.65 E 400.00 3.38 20.54 N 20 33 E 0.34 399.77 10.7 19.9 10.07 N 3.65 E 500.00 4.94 22.37 N 22 23 E 1.56 499.50 18.0 20.6 16.82 N 6.32 E 600.00 7.03 23.22 N 23 13 E 2.09 598.95 28.4 21.4 26.42 N 10.38 E 700.00 9.24 25.70 N 25 42 E 2.24 697.94 42.5 22.5 39.28 N 16.27 E 800.00 12.26 29.12 N 29 7 E 3.09 796.18 61.1 24.1 55.78 N 24.92 E Final Station Closure: Distance: 61.10 ft Az: 24.07 deg. • • 2 B.P. Exploration _ Well: V-Pad V-220 Location: Nabors #9ES, Prudhoe Bay, Alaska 55 50 45 40 35 .. 30 z 25 20 15 10- 5- 0- 0 Inrun Gyrodata _ AK0208G_108 DEFINITIVE I I ~ ~ ~ j i ~ ' i BOTTOM H E ~ I ~ ------- ------ - _ _ ~ ------ - --- -----LAC MD: 800.0 ~- --_------- -- -------------1 _ --- - i ~ i i -- ~, I ~ I _ -- --------- --- -- - - - -- - _---- ------ -------- ----- I I - -- --------- i i I I --------------- i I ----- - - I ~ -t i ------ ----- i 5 10 15 20 2~5 • • FASTING (ft) B.P. Exploration Well: V-Pad V-220 Location: Nabors #9ES, Prudhoe Bay, Alaska 10 9- 8- 7- w 0 0 ~ 6- rn a~ }~_ ~ 5- w w C~ J 4- 0 3- 2- 1- o- Inrun Gyrodata AK0208G 108 DEFINITIVE I ~ 'I - -- ---- ---- - --- --- -- ~ ----- ----- ------- t-- 7 ------- -------~- __ -- - --~ - }- I - - -- i I -~ - ----- ---- ------ ~ -- i r------- -!- ~ i -} -- I ------------ ---- --- - --- ------ _ _._.- ----- r-- _-- - -- - -- -- ___ _._. . -- ---- -~ __ - i I --- ----------- --------------- ------- ---~ - - ------- ------ - ' - - - ~O LO ---OM_HOLE-------I--- ATED MD : 800.00 - ~ ~ ~ i I -- - ----- -------- I ~ -------) I -----------------~ • 100 200 300 400 500 600 700 800 900 MEASURED DEPTH (ft) B.P. Exploration ..Well: V-Pad V-220 Location: Nabors #9ES, Prudhoe Bay, Alaska 12 11 10 9 8 z o ~ Q z J 6 U Z 5 4 3 2 1 0 Inrun Gyrodata AK0208G 108 DEFINITIVE I _ ~ - -------------- ~ ~ ~ I ~ ' 1 --. __ ___----I ~ ~ ---- _-- _ ___ ~, i ----- ---- - ' - B~TT4~M--H L-~, O ~ I. (LOCATED _- _._---_____ ~ .. _._ __--___- ._ _._-_.._-_-_ _.___-l --____.._ .__-__ _-. I I i _._._.. _. .-._.._-_. __.-__.___ ! .__._.____._-_ -__ __..__ -- ~_.__. . _.-_..__._._ _.-.-...__.. MD: 800.00 A -_ . _..___._ .. _--.__...... ~ ~, _ "~ --_- L _-_--___._-____._-__- ~ -.__._-_-____-._ .-._ __._ _. ......_,.-_..____._ -_- ._.-._ --._._..---.. .._--~ _ --__ _-- ._ ._ ~ __- I+ ~ ______----__-_ --_-._--___ _- _-_._._._-____ _-__-._-..-__-.._--L_-. - - ---- ----- ----- ------r - i -~ ---- --- -------- -- - - ---- - I i - I I I ~ i t i ~ i ii ---.. - - ~ ~ ----- - I ~ I ~ __ ~ ~ -- ~ ~- I i i i i i ~ i ~ I 100 200 300 400 500 600 700 800 900 MEASURED DEPTH (ft) • s a SCHLUMBERGER Survey report Client .................... BP Exploration (Alaska) Inc. Field ..................... Orion Well ...................... V-220 API number ................ 50-029-23383-00 Engineer .................. T.Kallestad Rig :...................... Nabors 9ES STATE :.................... Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS............ Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 52.60 ft KB above permanent.......: 81.10 ft DF above permanent.......: 81.10 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: 29.87 degrees 3-Mar-2008 17:41:19 Page 1 of 4 Spud date ................. 24-Feb-08 Last survey date.........: 03-Mar-08 Total accepted surveys...: 89 MD of first survey.......: 0.00 ft MD of last survey........: 8180.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2007 Magnetic date ............. 23-Feb-2008 Magnetic field strength..: 57644.98 GAMA Magnetic dec (+E/W-).....: 23.09 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 57645.00 GAMA 80.87 degrees (+/-) 2.50 meal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.09 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.09 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 • SCHLUMBERGER Survey Report 3-Mar-2008 17:41:19 Page 2 of 4 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical -------- -------- Displ -------- -------- Displ -------- -------- Total ------- ------- At ----- ----- DLS - - ---- ---- Srvy # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type I 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 100.00 0.54 18.30 100.00 100.00 0.45 0.45 0.15 0.47 18.30 0.54 BP _GYD CT DMS 3 200.00 0.86 15.32 100.00 199.99 1.62 1.62 0.49 1.69 16.98 0.32 BP _GYD CT DMS 4 300.00 3.05 21.15 100.00 299.93 4.82 4.82 1.65 5.10 18.91 2.20 BP _GYD CT DMS 5 400.00 3.38 20.54 100.00 399.77 10.07 10.07 3.65 10.71 19.92 0.33 BP GYD CT DMS 6 500.00 4.94 22.37 100.00 499.50 16.81 16.81 6.32 17.96 20.61 1.57 BP _GYD CT DMS 7 600.00 7.03 23.22 100.00 598.95 26.41 26.41 10.37 28.38 21.44 2.09 BP _GYD CT DMS • 8 700.00 9.24 25.70 100.00 697.94 39.27 39.27 16.27 42.51 22.50 2.24 BP _GYD CT DMS 9 800.00 12.26 29.12 100.00 796.17 55.79 55.79 24.92 61.10 24.07 3.09 BP _GYD CT DMS IO 854.79 13.74 23.38 54.79 849.56 66.84 66.84 30.33 73.40 24.41 3.58 BP MWD+IFR+MS 11 945.77 15.41 28.91 90.98 937.61 87.34 87.34 40.46 96.26 24.86 2.39 BP _MWD+IFR+MS 12 1040.33 18.22 34.21 94.56 1028.13 110.57 110.57 54.85 123.43 26.38 3.38 BP _MWD+IFR+MS 13 1134.73 20.52 35.41 94.40 1117.18 136.27 136.27 72.74 154.47 28.09 2.47 BP _MWD+IFR+MS 14 .1229.74 23.66 31.35 95.01 1205.21 166.13 166.13 92.31 190.05 29.06 3.67 BP _MWD+IFR+MS 15 1324.60 27.21 27.61 94.86 1290.87 201.62 201.62 112.27 230.77 29.11 4.11 BP MWD+IFR+MS 16 1419.52 29.91 25.56 94.92 1374.23 242.20 242.20 132.55 276.10 28.69 3.03 BP _MWD+IFR+MS 17 1513.75 33.69 22.83 94.23 1454.31 287.50 287.50 152.83 325.60 27.99 4.29 BP _MWD+IFR+MS 18 1612.31 38.19 23.57 98.56 1534.08 340.65 340.65 175.63 383.26 27.27 4.59 BP _MWD+IFR+MS 19 1705.80 43.41 23.73 93.49 1604.83 396.59 396.59 200.13 444.22 26.78 5.58 BP _MWD+IFR+MS 20 1804.51 44.74 23.05 98.71 1675.74 459.61 459.61 227.39 512.78 26.32 1.43 BP MWD+IFR+MS 21 1900.56 47.45 21.36 96.05 1742.35 523.68 523.68 253.51 581.81 25.83 3.09 BP _MWD+IFR+MS 22 1997.49 52.93 21.45 96.93 1804.38 592.97 592.97 280.68 656.05 25.33 5.65 BP _MWD+IFR+MS 23 2091.69 56.57 21.21 94.20 1858.74 664.62 664.62 308.65 732.79 24.91 3.87 BP _MWD+IFR+MS 24 2187.53 61.04 24.05 95.84 1908.38 740.24 740.24 340.23 814.69 24.68 5.31 BP _MWD+IFR+MS 25 2283.91 61.73 23.96 96.38 1954.54 817.53 817.53 374.65 899.29 24.62 0.72 BP MWD+IFR+MS 26 2379.04 61.40 24.01 95.13 1999.83 893.96 893.96 408.65 982.94 24.57 0.35 BP _MWD+IFR+MS 27 2475.02 61.98 26.45 95.98 2045.36 970.39 970.39 444.67 1067.42 24.62 2.32 BP _MWD+IFR+MS 28 2570.59 62.34 29.11 95.57 2089.99 1045.15 1045.15 484.06 1151.80 24.85 2.49 BP _MWD+IFR+MS 29 2666.97 61.76 28.97 96.38 2135.17 1119.58 1119.58 525.39 1236.73 25.14 0.62 BP _MWD+IFR+MS 30 2763.02 62.41 30.98 96.05 2180.14 1193.09 1193.09 567.79 1321.31 25.45 1.97 BP MWD+IFR+MS SCHLUMBERGER Survey Report 3-Mar-2008 17:41:19 Page 3 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type 31 2858.54 61.70 30.96 95.52 2224.90 1265.45 1265.45 611.21 1405.32 25.78 0.74 BP _MWD+IFR+MS 32 2953.97 60.95 31.41 95.43 2270.69 1337.07 1337.07 654.56 1488.70 26.08 0.89 BP _MWD+IFR+MS 33 3049.34 62.20 32.90 95.37 2316.09 1408.07 1408.07 699.21 1572.12 26.41 1.90 BP _MWD+IFR+MS 34 3144.42 62.05 32.82 95.08 2360.54 1478.67 1478.67 744.81 1655.66 26.73 0.17 BP _MWD+IFR+MS 35 3239.46 62.02 33.05 95.04 2405.11 1549.12 1549.12 790.45 1739.14 27.03 0.22 BP MWD+IFR+MS 36 3335.15 61.30 32.70 95.69 2450.53 1619.86 1619.86 836.16 1822.94 27.30 0.82 BP MWD+IFR+MS 37 3427.80 60.77 31.94 92.65 2495.40 1688.36 1688.36 879.50 1903.70 27.52 0.92 BP _MWD+IFR+MS • 38 3523.31 60.43 31.75 95.51 2542.29 1759.04 1759.04 923.41 1986.68 27.70 0.40 BP _MWD+IFR+MS 39 3618.85 62.61 32.73 95.54 2587.84 1830.06 1830.06 968.21 2070.40 27.88 2.45 BP _MWD+IFR+MS 40 3714.53 62.03 32.99 95.68 2632.29 1901.24 1901.24 1014.18 2154.82 28.08 0.65 BP MWD+IFR+MS 41 3810.53 61.26 33.00 96.00 2677.88 1972.09 1972.09 1060.19 2239.01 28.26 0.80 BP _MWD+IFR+MS 42 3905.48 60.63 32.38 94.95 2724.00 2041.95 2041.95 1105.02 2321.77 28.42 0.88 BP _MWD+IFR+MS 43 4001.40 62..04 32.41 95.92 2770.01 2113.01 2113.01 1150.11 2405.73 28.56 1.47 BP _MWD+IFR+MS 44 4097.69 62.10 32.00 96.29 2815.11 2184.99 2184.99 1195.45 2490.64 28.68 0.38 BP _MWD+IFR+MS 45 4128.14 61.80 32.16 30.45 2829.43 2207.76 2207.76 1209.72 2517.47 28.72 1.09 BP MWD+IFR+MS 46 4206.25 60.25 31.29 78.11 2867.27 2265.88 2265.88 1245.65 2585.71 28.80 2.21 BP _MWD+IFR+MS 47 4249.58 59.78 32.09 43.33 2888.92 2297.82 2297.82 1265.37 2623.19 28.84 1.93 BP _MWD+IFR+MS 48 4344.71 60.72 32.28 95.13 2936.13 2367.72 2367.72 . 1309.36 2705.64 28.94 1.00 BP _MWD+IFR+MS 49 4437.58 60.50 32.12 92.87 2981.70 2436.19 2436.19 1352.48 2786.43 29.04 0.28 BP _MWD+IFR+MS 50 4530.80 59.30 31.70 93.22 3028.45 2504.65 2504.65 1395.11 2866.98 29.12 1.35 BP MWD+IFR+MS 51 4625.58 60.07 31.53 94.78 3076.29 2574.32 2574.32 1438.00 2948.73 29.19 0.83 BP _MWD+IFR+MS • 52 4721.39 60.62 32.27 95.81 3123.70 2645.01 2645.01 1482.00 3031.90 29.26 0.88 BP _MWD+IFR+MS 53 4816.94 58.57 33.20 95.55 3172.05 2714.33 2714.33 1526.55 3114.15 29.35 2.30 BP _MWD+IFR+MS 54 4912.23 58.49 33.11 95.29 3221.80 2782.37 2782.37 1571.00 3195.25 29.45 0.12 BP _MWD+IFR+MS 55 5006.26 60.75 34.24 94.03 3269.35 2849.87 2849.87 1615.98 3276.15 29.55 2.62 BP MWD+IFR+MS 56 5099.52 60.10 33.98 93.26 3315.38 2917.02 2917.02 1661.47 3357.01 29.66 0.74 BP _MWD+IFR+MS 57 5195.20 -60.40 33.04 95.68 3362.86 2986.28 2986.28 1707.33 3439.89 29.76 0.91 BP _MWD+IFR+MS 58 5290.93 60.87 31.88 95.73 3409.80 3056.68 3056.68 1752.10 3523.23 29.82 1.16 BP _MWD+IFR+MS 59 5386.16 60.83 30.41 95.23 3456.19 3127.85 3127.85 1795.12 3606.37 29.85 1.35 BP _MWD+IFR+MS 60 5481.69 63.01 29.06 95.53 3501.16 3201.04 3201.04 1836.91 3690.65 29.85 2.60 BP MWD+IFR+MS 1 SCHLUMBERGER Survey Report 3-Mar-2008 17:41:19 Page 4 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type 61 5577.32 61.60 29.08 95.63 3545.60 3275.05 3275.05 1878.05 3775.31 29.83 1.47 BP _MWD+IFR+MS 62 5673.11 60.46 29.87 95.79 3592.00 3348.00 3348.00 1919.28 3859.11 29.82 1.39 BP _MWD+IFR+MS 63 5769.20 61.08 29.33 96.09 3638.92 3420.91 3420.91 1960.70 3942.97 29.82 0.81 BP _MWD+IFR+MS 64 5864.37 60.10 30.22 95.17 3685.65 3492.87 3492.87 2001.87 4025.87 29.82 1.31 BP _MWD+IFR+MS 65 5959.98 60.61 30.01 95.61 3732.95 3564.75 3564.75 2043.56 4108.96 29.82 0.57 BP MWD+IFR+MS 66 6055.90 61.27 29.92 95.92 3779.54 3637.39 3637.39 2085.43 4192.81 29.83 0.69 BP _MWD+IFR+MS 67 6151.38 60.12 29.35 95.48 3826.27 3709.76 3709.76 2126.61 4276.07 29.82 1.31 BP _MWD+IFR+MS 68 6246.41 60.40 28.79 95.03 3873.41 3781.88 3781.88 2166.70 4358.57 29.81 0.59 BP _MWD+IFR+MS 69 6342.59 61.21 28.49 96.18 3920.32 3855.56 3855.56 2206.94 4442.52 29.79 0.89 BP _MWD+IFR+MS 70 6437.96 60.67 28.88 95.37 3966.65 3928.70 3928.70 2246.95 4525.86 29.77 0.67 BP MWD+IFR+MS 71 6532.87 58.44 28.36 94.91 4014.74 4000.52 4000.52 2286.15 4607.67 29.75 2.40 BP _MWD+IFR+MS 72 6628.61 53.83 28.70 95.74 4068.07 4070.34 4070.34 2324.10 4687.12 29.73 4.82 BP _MWD+IFR+MS 73 6724.06 52.88 29.50 95.45 4125.04 4137.26 4137.26 2361.34 4763.70 29.72 1.20 BP _MWD+IFR+MS 74 6819.75 52.52 29.88 95.69 4183.03 4203.39 4203.39 2399.04 4839.82 29.72 0.49 BP _MWD+IFR+MS 75 6916.20 52.72 29.40 96.45 4241.59 4270.00 4270.00 2436.95 4916.46 29.71 0.45 BP MWD+IFR+MS 76 7012.07 51.43 29.36 95.87 4300.51 4335.90 4335.90 2474.05 4992.08 29.71 1.35 BP _MWD+IFR+MS 77 7107.33 50.42 29.37 95.26 4360.55 4400.34 4400.34 2510.31 5066.03 29.70 1.06 BP _MWD+IFR+MS 78 7202.84 49.37 29.98 95.51 4422.08 4463.82 4463.82 2546.47 5139.08 29.70 1.20 BP _MWD+IFR+MS 79 7297.70 48.31 29.40 94.86 4484.51 4525.85 4525.85 2581.85 5210.50 29.70 1.21 BP _MWD+IFR+MS 80 7393.24 47.30 29.27 95.54 4548.68 4587.56 4587.56 2616.53 5281.28 29.70 1.06 BP MWD+IFR+MS 81 7488.11 46.85 29.11 94.87 4613.29 4648.21 4648.21 2650.41 5350.74 29.69 0.49 BP _MWD+IFR+MS • 82 7583.92 46.15 28.62 95.81 4679.24 4709.07 4709.07 2683.96 5420.23 29.68 0.82 BP _MWD+IFR+MS 83 7679.37 44.95 28.60 95.45 4746.08 4768.88 4768.88 2716.58 5488.36 29.67 1.26 BP _MWD+IFR+MS 84 7776.85 44.41 28.63 97.48 4815.40 4829.06 4829.06 2749.41 5556.89 29.65 0.55 BP _MWD+IFR+MS 85 7871.06 43.46 28.91 94.21 4883.24 4886.35 4886.35 2780.87 5622.25 29.64 1.03 BP MWD+IFR+MS 86 7966.72 42.16 28.28 95.66 4953.42 4943.43 4943.43 2811.99 5687.24 29.63 1.43 BP _MWD+IFR+MS 87 8061.47 41.24 28.11 94.75 5024.16 4998.98 4998.98 2841.77 5750.25 29.62 0.98 BP MWD+IFR+MS 88 8109.55 40.91 27.92 48.08 5060.40 5026.87 5026.87 2856.61 5781.83 29.61 0.73 BP MWD+IFR+MS 89 8180.00 40.91 27.92 70.45 5113.65 5067.63 5067.63 2878.21 5827.95 29.59 0.00 Pr ojected to TD [(c)2008 IDEAL ID13 OC 05] Schlumberger Drilling ~ Measurements MWD/LWD Log Product Delivery Customer Well No Installation/Rig BP Exploration (Alaska) Inc V-220 9ES Dispatched To: Christine Mahnken Date Dispatched: 21-Feb-08 Dispatched By: Franklin Medina Data No Of Prints No of Flo ies Surveys 2 1 Received By: Please sign and return to: Drilling & Measurements LWD Division / ~ ~ Qv~ ~ ~ Q ~ 2525 Gambell Street, Suite 400 Anchorage, Alaska 99501 fclarke3@slb.com Fax: 907-561-8317 LWU LOg Uellvery VL.'I , U3-U(i-U(i ~~8-d~.~ a~ ~~ ~~ ~~ ~~ ~ ^~ ~~ ~-~ ~ ~ ~' SARAH PAL/N, GOVERNOR ~~ OII/ ~`~ ~ 333 W. 7th AVENUE, SUITE 100 COI~TSERQATIOI~T CO1rII~IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Orion Schrader Bluff, V-220 BP Exploration Alaska Inc. Permit No: 208-020 Surface Location:. 4908' FSL, 1 3' FEL, SEC. 11, T11N, R11E, UM Bottomhole Location: 4674' FSL, 1400' FWL, SEC. O1, 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 an required test, contact the Commission's petroleum field inspector at (907-3607 (pager). DATED this day of February, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~~~~~c~ STATE OF ALASKA ~~~ ~~~ o ~ ~~~~ ALASK~IL AND GAS CONSERVATION COMMIN PERMIT TO DRILL ~ ~~~ 20 AAC 25.005 Alaska Oil & Gays ~Un~~ ~I)ftlrl~i;~xior~ 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 proposed for: ^ 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: ~~'~ "P~iBa(-220 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 8098 TVD 5018 12. Field /Pool(s): Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028240 Schrader Bluff FEL, SEC. 11, T11 N, R11 E, UM FSL, 1503 4908 Top of Productive Horizon: T11 N R11 E UM 1145' FWL SEC. 01 4238' FSL 8. Land Use Permit: 13. Approximate Spud Date: February 16, 2008 , , , , , Total Depth: 4674' FSL, 1400' FWL, SEC. 01, T11N, R11E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 11,150' 4b. Location of Well (State Base Plane Coordinates): Surface: x-590797 y-5970158 Zone-ASP4 10. KB Elevation Plan (Height above GL): 81.1 feet 15. Distance to Nearest Well Within Pool: 544' 16. Deviated Wells: Kickoff Depth: 250 feet Maximum Hole An le: 61 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2242 Surface: 1740 1 Ca in Pr .ram: S ifi tio n T - in D h - B m nti of C ment c.f. or sa s 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 109' 109' 260 sx Arctic Set A rox. 12-1/4" 9-5/ " 40# L-80 BTC 4097' Surface Surface 4126' 2851' 728 sx Dee Crete 84 sx Class 'G' 8-3/4" 7" 26# L- T -II 5600' Surf a Surfa 5629' 77' Below 8-3/4" 7" 26# L-80 BTC-M 2469' 5629' 3577' 8098' 5018' 60 sx LiteCrete 332 sx Class'G' 1 g. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): asing Length ize ement Volume MD TVD Conductor /Structural Surface Intermediate Production 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 Adrienne McVey, 564-4184 Printed Name Robert Tirpack Title Engineering Team Leader d Prepared By Name/Number: Si nature ~ Phone 564-4166 Date ~~-~~Y Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill API Number: Permit Approval See cover letter for Number: d'O~?DO 50-lpo?9~,3~0~~ date: (~2-° C~~ ~ O other re uirements Conditions of Approval: pG~~~ ~~,~~~~L~~~ ~ `'~C~I. ~~ ~La-~a ~~j'~(~> , ~..( If box is checked, well may not be used toe plore for, test, or produce coalbed met ne, gas/hydrates, or g contained shales: LVJ 11`1\T'~ Cfc~~~ CVVCt~~~ ~ Samples Req'd: es ~No Mud Log Req'd: Yes [~No ~ to~ S` Z®.~ ~~ ~ `' HZS Measures: Yes ^ No ctional Survey Req'd: Yes ^ No Other:~`.~~~~ J~ p~~~"'TTTic~~~Yi~G.CCtJt~~ ~~~0~~ f '~. / PPROVED BY THE COMMISSION Date ~^ ~~ ~ ,COMMISSIONER Form 10-401 Revised 12/2005 Submit In Duplicate Well Name: V-220i Drill and Complete Plan Summary T e of Well service / roducer / in'ector : Injector Surface Location: 4907' FSL, 1503' FEL, Sec. 11, T11 N, R11 E, Umiat Slot NZ+1 As Built X = 590,797 Y = 5,970,158 Target 1 (Top OA): 4238' FSL, 4135' FEL, Sec. 1, T11 N, R11 E, Umiat X = 593,385 Y = 5,974,800 Z = 4475' TVDss Target 2 (Top OBd): 4456' FSL, 4007' FEL, Sec. 1, T11 N, R11 E, Umiat X = 593,510 Y = 5,975,020 Z = 4700' TVDss BHL: 4673' FSL, 3880' FEL, Sec. 1, T11 N, R11 E, Umiat X = 593,634 Y = 5,975,239 Z = 4937' TVDss API NUMBER: TBD Estimated Start Date: February 16, 2008 Ri Nabors 9ES O eratin Da s to com lete: 16.1 MD: 8098' TVD: 5018' RT/GL: 28.5' RTE: 81.1' Well Design: USH Grassroots Schrader Bluff Injector 3 Y2" TC-II com letion, 5 ackers for zonal isolation. Ob'ective: Multi-zonal injector into Schrader Bluff Nb, OA, OBa, OBb/OBc and OBd sands Directional Plan Version: Schlumberger P7 KOP: 250' MD Maximum Hole An le: 61 ° Close A roach Wells: All wells pass Major Risk criteria. Reference anti-collision report. Distance to Nearest Property Line• 11,150' to PBU boundary. Nearest well within Pool: 544' from V-120 at top Na sand. V-2201 Drilling Permit Application • ~/a Mile Wellbore Mechanical Integrity Summary Well Name Dist. ft Annulus Inte rit Comments Distance from V-220i at 7025' MD (Top Na sand; closest approach). ,C~ ~5 On cement job, pumped 186 bbl 12.5 ppg Microlite lead, 39 bbl 15.8 ~U~ _ ppg `G' tail. Full returns throughout job. Based on 30% excess, estimated TOC=5999' MD, approximately 1000' above Schrader. V-103 1034 USIT (10/5/2002) shows spotty lead cement, with ~10' of good cement above Schrader. Entire USIT was run with a 2.6 MRAY impedance threshold, which is optimized for the 15.8 ppg tail cement; should have been set lower for 12.5 Microlite. ,,, ei _ Distance from V-220i at 7561' MD (Top Na sand; closest approach). l ~tJ` r ` On cement job, pumped 129 bbls 12.0 ppg `G' extended lead, 34 bbl 15.8 ppg `G' tail. Full returns throughout job. Based on 30% excess, V-120i 544 estimated TOC=5212' MD, approximately 2400' above Schrader. USIT (12/5/2004) shows fair cement across Schrader, with good cement from 7380'-7390', and 7778'-7816'. V-204 L1 1227 Distance to TD of slotted liner lateral. V-204 L2 1127 " V-204 L3 1107 " L-204 1286 " L-204 L1 1250 " L-204 L2 1305 " L-204 L3 1249 " Lo in Pro ram Surface Interval Drilling, MWD: GR Open Hole: None Cased Hole• None Production Interval Drilling, MWD: GR/RES/NEU/Azimuthal Density/PWD Open Hole: None Cased Hole: USIT Prima De th Control mode Mud Program 12 ~/a" Surface Hole: Fresh Water Spud Mud Interval Density Funnel Vis seconds Yield Point_ Ib/100ft2 API FL mU30 min pH Surface to BPRF 8.8 - 9.2 300 - 400 55 -70 NC - 8.0 9.0 - 9.5 BPRF to TD 9.2-9.5 225-250 45-60 8.0 9.0-9.5 8 3/a" Production Hole: LSND Interval Density (ppg) PV (cP) YP (Ib/100ft2) API FL (mV30 min) HTHP FL (mU30 min) pH MBT Cs Shoe to TD 8.8-9.0 12-18 18-24 <6.0 N/C 9-10 <18 V-2201 Drilling Permit Application 2 CasinalTubina Prearam • Hole Size Csg/ Tb O.D. WUFt Grade Connection Length Top MDlTVD RTE Btm MDlTVD RTE 42" Insulated 20" 91.5 A-53 Weld 80' Surface 109'/ 109' 12 ~/a" 9 /8" 40 L-80 BTC 4097' Surface 4126'/2851' 8 3/a" 7" 26 L-80 TC-II 5600' Surface 5629' / 3577' 8 3/a" 7" 26 L-80 BTC-M 2469' 5629' / 3577' 8098' / 5018' Tubin 3'h" 9.2 L-80 TC-II 7833' Surface 7862' / 4850' ~ Comments: ~ Tubing crossover to 4 ~/2" just below tree. ~ Test Point I Depth I Test Type 9 s/8" Surface Casing 20' - 50' from surface shoe LOT Cement Calculations Surface Casin Casin Size 9 /8" Basis: Lead: Based on 3126' 12-1/4" open hole with 250% excess above BPRF (1980') and 30% excess below BPRF. TAM port collar used if necessary. Lead TOC: Surface Tail: Based on 85' shoe track volume and 1000' of 12'/a" open hole with 30% excess. DuraSTONE in last 15 bbl. Tail TOC: 1000' MD above the Casin shoe Total Cement Volume: Lead 482.5 bbl / 2707 ft / 728 sks of DeepCrete at 10.7 ppg and 3.72 ft3/sk Tail 67.9 bbl / 381 ft / 84 sks of Class `G' at 15.8 ppg and 4.56 ft /sk DuraSTONE: 15 bbl / 84.2 ft3 / 73 sks at 16.3 ooa and 1.16 ft3/sk Production Casin Casina Size 7" Basis: Lead: Based on 1072' of 8-3/4" open hole with 30% excess. TOC: 1000' from surface shoe Tail: Based on 85' shoe track volume and 1900' of 83/a" open hole with 30% excess. TOC at 6198' MD, 500' MD above UG_Ma. Total Cement Volume: Lead 35.9 bbl / 201 ft / 60 sks of LiteCRETE at 11.0 ppg and 3.37 ft3/sk Tail 69.2 bbl / 388 ft / 332 sks of Class `G' at 15.8 ppg and 1.17 ft3/sk. V-220i Drilling Permit Application 3 Estimated Formation Tops (TVDss) and Pore Pressures Formation Top TVDss Uncertaint ft Commercial Hydrocarbon- Bearin ? Est. Pore Pressure si Est. Pore Pressure EMW G1 -240 +/-50' No 108 8.7 SV6 -900 +/-50' No 405 8.7 SV5 -1580 +/-50' No 711 8.7 Base Permafrost -1700 +/-50' No 765 8.7 SV4 -1710 +/-50' Gash drates 770 8.7 Fault 1 V-Pad Fault -1795 +/- 100' M.D. SV3 -2020 +/-50' Gash drates 909 8.7 SV2 -2195 +/-50' Gas h drates 988 8.7 SV1 -2545 +/-50' Gash drates 1145 8.7 UG4 -2850 +/-50' Thin Coal 1283 8.7 UG4A -2890 +/-50' Heavy Oil 2870'- 2920' SS 1301 8.7 UG3 -3250 +/-50' Thin Coals 1463 8.7 UG1 -3785 +/-50' Heavy Oil 3830'- 3900' SS 1703 8.7 UG_Ma -3900 +/- 150' M.D. Possible Fault #2 -4025 +/- 30' No wet 1811 8.7 UG_Mb1 -4125 +/- 30' No wet 1856 8.7 UG_Mb2 -4190 +/- 30' No wet 1886 8.7 UG_Mc -4260 +/- 30' No wet 1917 8.7 SB_Na -4325 +/- 30' No 1946 8.7 SB_Nb -4345 +/- 30' Yes 1955 8.7 SB_Nc -4380 +/- 30' Yes 1971 8.7 SB_Ne -4390 +/- 30' Yes 1976 8.7 SB_OA -4480 +/- 30' Yes 1890-1960 8.1-8.4 SB_OBa -4550 +/- 30' Yes 1890-1960 8.0-8.3 SB_OBb -4590 +/- 30' Yes 1960-2020 8.2-8.5 SB_OBc -4650 +/- 30' Yes 2040-2070 8.4-8.5 SB_OBd -4700 +/- 30' Yes 1990-2050 8.1-8.4 SB_OBe -4765 +/- 30' Yes 2120 8.6 SB_OBf -4810 +/- 30' Yes 2140 8.6 Base _SB_OBf -4855 +/- 30' No 2160 8.6 T.D. in Colville Shale -4937 No 2197 8.6 Comments: SV through UG and SB N-sand interval pressures are assumed based on a .45 ppg hydrostatic gradient, and regional pressure trends. SB OA, OBa, OBb, OBc, and OBd pressure ranges are estimated and assume partial pressure depletion as a result of offtake from updip Polygon 2A multilateral production wells. V-220i Drilling Permit Application 4 Well Control 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. 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 affect 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 are on file with the AOGCC. Production Interval: • Maximum anticipated BHP: 2242 psi @ 5012' TVD, 8.6 ppg EMW (at TD in Colville Shale, 8108' MD) • Maximum surface pressure: 1740 psi C surface (based on BHP and a full column of gas from TD Cc~ 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 98 bbl 9.5 8.7 LOT Casing (assuming 12.5 LOT 7" Production 4000 psi NA NA NA NA Casin 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-2201 Drilling Permit Application 5 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: 1. Weld an FMC landing ring for the FMC Gen 5 wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up and function test diverter. 3. MU 12'/4" drilling assembly with MWD/GR and directionally drill surface hole to TD with one BHA. The surface hole TD will be approximately 470' below the top of the SV1. 4. Run and cement 9 e/e" surface casing. A TAM port collar may be run at 1000' as a contingency. 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. 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 20' - 50' of new formation and perform LOT. 7. Drill ahead to production hole target TD (approx. 8108' MD, 250' below OBe). 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. Pressure test casing to 4000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. Freeze protect the 7" x 9-5/8" annulus. 9. PU DPC guns and RIH w/ -265' 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 tying into GR. Once correlated correctly, circulate over to 9.0 ppg brine. Confirm cement compressive strength is at least 1000 psi before firing. Perforate Nb, OA, OBa, OBb, OBc, and OBd. POOH LD DP and guns. 11. RU Schlumberger E-line. RIH with gauge ring and junk basket to recover any pert debris. Repeat until clean to at least 50' below the bottom perforation. 12. Run USIT log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. 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. Top packer must be within 200' of Nb perfs. 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 ability to circulate. 16. Install and test TWC. Nipple down the BOPE. Nipple up and test the double master to 5000 psi. 17. Freeze protect the well to 2500' 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. RDMO. Post-Rig Work: 1. Install tree with electric SSV actuator. 2. MIRU slickline. Pull the ball and rod / RHC plug. 3. Pull shear valve from top mandrel and replace with a dummy GLV. 4. Pull dummy valves from injection mandrels and replace with injection valves. 5. Pull VR plug. 6. Install wellhouse and flowlines. V-220i Drilling Permit Application 6 Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE Well Control The Schrader in the Polygon 2A fault block is expected to be normal to sub-normally pressured at 8.0-8.7 ppg EMW. Hydrates and Shallow Gas Gas hydrates and/or free gas may be present in the SV5 through SVi below BPRF. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole. Occasionally hydrates are encountered below the SV1. III. Faults/Lost Circulation/Breathing A. Fault #1: "V-pad Fault". V-220i will penetrate this fault in the SV4 interval at a high angle and move quickly away from the fault. Fault #2: Separates Orion Polygon 2 from Polygon 2A. V-220i will pass over from the upthrown side of the fault to the downthrown side; a slight repeat of the Ugnu M-sand interval may be seen. No faults are exoected in the reservoir interval. B. Lost circulation is not anticipated while drilling V-2201 (several previously-drilled V-pad wells have intersected both faults without experiencing losses). If LC does occur, follow LCM decision tree. C. Breathing is not expected on this well. IV. Kick Tolerance/Integrity Testing A. The 9 5/8" casing will be cemented to surface. B. The Kick Tolerance for the surface casing is 98 bbl with 9.5 ppg mud, 12.5 ppg LOT, and an 8.7 ppg pore pressure. C. Integrity Testing Test Point Test D th Test a EMW 9 s/a" shoe 20-50' from shoe LOT >12.5 ex ected V. Hydrogen Sulfide V Pad is not designated as an H2S site, but Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time; however, all V Pad gas lift wells will likely have H2S levels in the 10-180 ppm range as a result of using PBU lift gas. Well Name H2S Level Date of Readin #1 Closest SHL Well H2S Level V-03 10 m 7/15/2007 #2 Closest SHL Well H2S Level V-111 10 m 10/15/2007 #1 Closest BHL Well H2S Level V-103 60 m 9/2/2007 #2 Closest BHL Well H2S Level V-204 60 m 8/4/2007 VI. Anti-Collision Issues All wells pass Major Risk criteria. The following wells are less than 100' center-to-center from V-220 P7: Well Name Ctr-Ctr Distance (ft) Reference MD (ft) Allowable Deviation (ft) Comment V-03 59.75 364.84 53.87 Use traveling cylinder V-111 88.45 411.20 80.68 Use traveling cylinder V-111 PB1 88.75 425.80 79.25 Use traveling cylinder V-120 28.03 912.71 8.60 Use traveling cylinder V-218 43.37 1065.90 24.15 Use traveling cylinder CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. V-2201 Drilling Permit Application 7 TREE= 41/16"C WELLHEAD'= ACTUATOR = Electric KB. ELEV = BF. ELEV = KOP = 250' Max Angle = 62 deg Datum MD = Oratum ND = V-22~i Propose ~4-1 /2" TBG, 12.6#, L-80, TC-II, .0152 bpf, ID=3.958" ~-1 29' r 9-518" CSG, 40#, L-80, TGN, ID = 8.835" 4126' T' CSG, 26#, L-80, TGN, .0383 bpf, ~ = 6.276" 5626' Minimum ID = 2.75" ~ xxxx' 3-1/2" HES XN NIPPLE MARKER JOINT w! RA TAG Na 7181 MARKER JOINT w / RA TAG 7566' GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 10 7140 MMG DCR RK WATER INLIF[`TIC)N MA NIIRFI C ST MD ND DEV TYPE VLV LATCH PORT DATE 9 7220 MMG-W DMY RK 8 7279 MMG-W DMY RK 7 7423 MMG-W DMY RK 6 7472 MMG-W DMY RK 5 7528 MMG-W DMY RK 4 7557 MMG-W DMY RK 3 7612 MMG-W DMY RK 2 7701 MMG-W DMY RK 1 7781 MMG-W DMY RK PERFORATION SUMMARY REF LOG: SLB ReaRinmie LWD ANGLE AT TOP PERF: Note: Refer to Reduction DB for historical perf data SQE SPF INTERVAL OpNSgz DATE 4-1/2" 5 Nb xxxx'-xxxx' O 4-1/2" 5 OA xxxx'-xxxx' O 4-1/2" 5 OBa xxxx'-xxxx' O 4-1/2" 5 OBb xxxx'-xxxx' O 4-1/2" 5 OBc xxxx'-xxxx' O 4-1/2" 5 OBd xxxx'-xxxx' ~3-1/2" TBG, 92#, L-80, TG~, CSG, 26#, L-80, D087 bpf, ID = 2.992" ~ 7852' PBTD 8018' .0383 bpf, ID = 6.276 8098' 29' ~-~4-1 /2" XO 3-1/2". O = 2.992" 3370' ~~3-1/2" HES X NIP, ID = 2.813" 7169' ~-- ~ 3-1 /2" HES X NIP, ID = 2.813" 7189' 7" HES A HR PKR w / 1 /4" FEED THRU, ID = 2.920" 7203' NDPG PRES/TEMP SENSOR SUB 7308' 3-112" HES X NIP, ID = 2.813" 7392' T' HES A HR PKR w / 1!4" FEED THRU, ID = 2.920" 7406' NDPG PRESIfEMP SENSOR SUB 7491' 3-1/2" HES X NIP, ID = 2.813" 7502' T' HES A HR PKR wl 1/4" FEED THRU, ID = 2.920" 7516' NDPG PRES/TEMP SENSOR SUB 7510' T' HES A HR PKR w / 1 /4" FEED THRU, ID = 2.920" 7584' NDPG PRES/TEMP SENSOR SUB 7596' ~-i3-1/2" HES X NIP, ID = 2.813" 7730' 7" HES A HR PKR w / 1 /4" FEED THRU, ID = 2.920" 7743' NDPG PRES/TEMP SENSOR SUB 7760' 3-112" HES X NIP, ID = 2.813" 7810' 3-1/2" HES X NIP, ID = 2.813" 7830' 3-112" HES XN NIP, ID = 2.75" 785Z' 3-112" WLEG, ID = 2.992" DATE REV BY COMMENTS DATE REV BY COMMENTS 11/13/07 ALM Proposed WBD 11/19/07 ALM Added 2nd I-wire 01/15/08 ALM Updated w! P6 depths 01/25/08 ALM Updated w/ P7 depths ORION UNIT WELL: V-220i PERMff No: xxxxx API No: 50-029-xxxxx Sec, Tw p, Rge BP Exploration (Alaska) w ~ ~r - o~ , ~, ~ I V_PAD ~ - ~ L PAD' ~ ~~ ~ `" 35 ~ ~-36 e ~ -4P' 1 ~ -- T ARID '~ : ~~ ~ 15°00'00" I ~Z { ~ wpESr - ., KSTA DK ~ ~ " PLANT ~ - 03- `' ., ~ E ~ ~ "~~ ,ROJECT V-220i ~ _ ' AREA- , ~ ~ V. ~ V-120 ^ ^ V-115 . V-PAD I - ~ ~~ ~ V-03 ^ ^ V-213i ` 1D`" ~~ ~~ ~ ~ ` ~' V-2181 v-t,t ^ ^ ^ V-100 ^ v-tz2 -- ~TM S'°~He ~~k " 1 " 1~'i" V-216i ^ ^ V-117 ~ . ~ ~ '~ ~ : RO g ', ' 7=:J - - i , V-103 ^ . o ~ ' ~ V-212 ^ ^ V-121 ~,' e' .. ~ 3, i ~` _ V-106 ^ ^ V-205 ^ V-217f VICINITY MAP V-04 ^ v-tosi ^ v-ot N.T.S. v-22r ^ ~V-2231 v-o7 ^ v-zzzi ^ V-102 ^ ^ V-SPARE (sLOr s-L) V-201 ^ V-107 V-02 ^ ^ ^ SLOT S-J ^ V-21 Si ` 0 ryL A V-104i ^ ^ ^ V-204 ° °°° t~~ .`C'° ° ° ° ° °'° ~' ° v-2toi ^ v-tta / ~ °° °° 9 v-2oz ^ ^ v-tts ° ° ° ,v-2, 4i ^ ^ v-,D9 ~ ~~ °° ~ 49 ~ v-tot ^ o V-211i ^ ^ V-113 °°° ~°°°°°„°°°°°°°°°°°°°°°°o°°° V-108 ^ V-203 ^ ^ V-112 °°°°~°°°°°~°°°°°°°°°°°°°°°°°°°° ~~,`~° Richard F. Allison ~s ° 10608 °° ssla~n~ `' -- TO SPINE ROAD - I SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM ~ PPD PROPERLY REGISTERED AND LICENSED Wop, ~, ~ TO PRACTICE LAND SURVEYING IN / -~o ~ THE STATE OF ALASKA AND THAT ~ 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 HORfZONTAL CONTROL IS V-PAD OPERATOR MONUMENTATION. LEGEND 3. BASIS OF ELEVATION IS V-PAD OPERATOR MONUMENTATION. BUILT CONDUCTOR -~ AS 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 V-220i Y=5,970,157.67 N 10,179.83 70°19'41.515" ' " 70.328199' 52 6' 4,908'FSL ' X= 590,796.67 E 5,060.28 149'15 49.044 149.2636233' 1,503 FEL V-223i Y=5,969,929.57 N 10,000.03 70'19'39.290" ' " 70.3275806' 52 9, 4,681'FSL ' X= 590,640.02 E 4,849.91 149'15 53.697 149.2649158' 1,663 FEL r . i~u uct ~ M. GRIM O CHECKED: ALLISON ~p O ~ ,~ Dnre 1/05/08 ~'~ I- DRAWING - FRB08WOV 01-00 sr+EEr: ~~~~D~a ~oBNO, GREAASR BUILTH~ NDUCTOR-PAD waitrons SCALE: 1 OF 1 0 ISSUED FOR INFORMATION MLG TFB WELLS V-2201 AND V-2231 N0. DATE REVISION BY CHK 1"=150 by V-220 (P7) Proposal Schlumberger Report Date: 25-Jan-08 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: Field: Structure I Slot: BP Exploration Alaska Prudhoe Bay Unit - WOA V-Pad I Plan V Slot (N-Z+1) d O~ Vertical Section Azimuth: O~ Vertical Section Origin: 5' TVD Reference Datum: 29.870° N 0.000 ft, E 0.000 ft Rotary Table Well: Plan V-220 (NZ+1) ~~ TVD Reference Elevation: 81.10 ft relative to MSL Borehole: Plan V-220 ~p Sea Bed 1 Ground Level Elevation: 52.60 ft relative to MSL UWOAPI#: 50029 Magnetic Declination: 23.098° Survey Name 1 Date: V-220 (P7) /January 18, 2008 Total Field Strength: 57644.531 nT Tort I AHD 1 DDI 1 ERD ratio: 77.476° / 5823.45 ft / 5.862 / 1.160 Magnetic Dip: 80.873° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: February 18, 2008 Location LatlLong: N 70.32819852, W 149.26362319 Magnetic Declination Model: BGGM 2007 Location Grid NIE YIX: N 5970157.670 ftUS, E 590796.670 ftUS North Reference: True North Grid Convergence Angle: +0.69340350° Total Corc Mag North a True North: +23.098° Grid Scale Factor. 0.99990937 Local Coordinates Referenced To: Well Head Measured Vertical Mag I Grav Directional Comments Inclination Azimuth Sub-Sea TVD TVD NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS RIC U.UU U.UU LO.VU -81.IU U.UU U.UU U.VV V.VV -- U.UU U.UU b`J/Ulb/.b/ b`JU/`Jb.b/ IV /U .3Li31`JBbL VV l4`J.LbJbZS"I `J KOP Bld 1.5/100 250.00 0.00 25.00 168.90 250.00 0.00 0.00 0.00 25 .OOM 0.00 0.00 5970157.67 590796.67 N 70 .32819852 W 149.26362319 300.00 0.75 25.00 218.90 300.00 0.33 0.30 0.14 25 .OOM 1.50 0.00 5970157.97 590796.80 N 70 .32819933 W 149.26362207 G1 321.10 1.07 25.00 240.00 321.10 0.66 0.60 0.28 25. OOM 1.50 0.00 5970158.27 590796.94 N 70. 32820016 W 149.26362092 Bld 2.5/100 350.00 1.50 25.00 268.89 349.99 1.30 1.19 0.55 25 .OOM 1.50 0.29 5970158.86 590797.21 N 70 .32820176 W 149.26361870 400.00 2.75 25.00 318.85 399.95 3.15 2.87 1.34 25 .OOM 2.50 0.94 5970160.55 590797.97 N 70 .32820635 W 149.26361235 500.00 5.25 25.00 418.60 499.70 10.10 9.19 4.28 HS 2.50 1.73 5970166.91 590800.84 N 70 .32822362 W 149.26358844 600.00 7.75 25.00 517.95 599.05 21.38 19.45 9.07 HS 2.50 2.22 5970177.22 590805.50 N 70 .32825165 W 149.26354965 700.00 10.25 25.00 616.71 697.81 36.97 33.62 15.68 HS 2.50 2.58 5970191.48 590811.94 N 70 .32829038 W 149.26349604 800.00 12.75 25.00 714.70 795.80 56.83 51.69 24.10 HS 2.50 2.86 5970209.64 590820.14 N 70 .32833974 W 149.26342772 900.00 15.25 25.00 811.72 892.82 80.93 73.61 34.33 HS 2.50 3.10 5970231.69 590830.10 N 70 .32839963 W 149.263 SV6 992.03 17.55 25.00 900.00 981.10 106.82 97.16 45.31 HS 2.50 3.28 5970255.37 590840.79 N 70. 32846396 W 149.263 Bld 3.5/100 1000.00 17.75 25.00 907.59 988.69 109.23 99.35 46.33 HS 2.50 3.29 5970257.57 590841.79 N 70 .32846994 W 149.26324749 1100.00 21.25 25.00 1001.84 1082.94 142.48 129.60 60.43 HS 3.50 3.49 5970287.98 590855.53 N 70 .32855258 W 149.26313311 1200.00 24.75 25.00 1093.88 1174.98 181.41 165.01 76.94 HS 3.50 3.66 5970323.58 590871.61 N 70 .32864931 W 149.26299922 1300.00 28.25 25.00 1183.36 1264.46 225.86 205.44 95.80 HS 3.50 3.82 5970364.24 590889.97 N 70 .32875977 W 149.26284632 1400.00 31.75 25.00 1269.95 1351.05 275.67 250.75 116.93 HS 3.50 3.96 5970409.79 590910.54 N 70 .32888354 W 149.26267498 1500.00 35.25 25.00 1353.32 1434.42 330.66 300.76 140.25 HS 3.50 4.09 5970460.08 590933.26 N 70 .32902018 W 149.26248584 1600.00 38.75 25.00 1433.17 1514.27 390.61 355.30 165.68 HS 3.50 4.21 5970514.92 590958.02 N 70 .32916916 W 149.26227961 1700.00 42.25 25.00 1509.20 1590.30 455.31 414.15 193.12 HS 3.50 4.31 5970574.09 590984.75 N 70 .32932994 W 149.26205705 SV5 1798.39 45.69 25.00 1580.00 1661.10 523.37 476.05 221.99 HS 3.50 4.41 5970636.33 591012.86 N 70. 32949904 W 149.26182295 1800.00 45.75 25.00 1581.13 1662.23 524.52 477.10 222.47 HS 3.50 4.42 5970637.38 591013.33 N 70 .32950190 W 149.26181899 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Plan V Slot (N-Z+1)\Plan V-220 (NZ+1)\Plan V-220\V-220 (P7) Generated 1/25/2008 9:04 AM Page 1 of 3 Measured Vertical Mag I Grav Directional Comments Inclination Azimuth Sub-Sea TVD TVD NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS IyVU.UU 4y.Z5 ZS.UU 164tf.6/ 1/Z`J.// 5y/.y/ 543.y1 253.63 ti5 3.5U 4.51 5y/U/U4.5ti 5y1U43.ti/ N /U.3Zytiti44L W 14y.1615663Z End Bld 1933.06 50.41 25.00 1670.00 1751.10 623.14 566.80 264.30 --- 3.50 4.54 5970727.58 591054.07 N 70.32974696 W 149.26147974 Base Perm 1980.13 50.41 25.00 1700.00 1781.10 659.28 599.68 279.63 --- 0.00 4.57 5970760.63 591069.00 N 70.32983677 W 149.26135541 SV4 1995.82 50.41 25.00 1710.00 1791.10 671.33 610.63 284.74 - 0.00 4.58 5970771.65 591073.98 N 70.32986671 W 149.26131396 Bld 3.5/100 2027.20 50.41 25.00 1730.00 1811.10 695.42 632.55 294.96 25.71 R 0.00 4.60 5970793.69 591083.93 N 70.32992658 W 149.26123108 2100.00 52.71 26.39 1775.26 1856.36 752.28 683.92 319.69 24.84R 3.50 4.66 5970845.35 591108.03 N 70.33006691 W 149.26103051 Fault Crossing 2132.99 53.76 26.99 1795.00 1876.10 778.67 707.53 331.56 24.48R 3.50 4.68 5970869.09 591119.62 N 70.33013141 W 149.26093424 2200.00 55.90 28.16 1833.60 1914.70 833.40 756.08 356.93 23.81 R 3.50 4.73 5970917.94 591144.39 N 70.33026404 W 149.26072852 2300.00 59.11 29.81 1887.31 1968.41 917.72 829.83 397.81 22.92R 3.50 4.81 5970992.18 591184.37 N 70.33046553 W 149.26039690 End Bld 2362.34 61.13 30.78 1918.37 1999.47 971.77 876.50 425.08 --- 3.50 4.85 5971039.17 591211.07 N 70.33059301 W 149.26017573 SV3 2572.82 61.13 30.78 2020.00 2101.10 1156.06 1034.85 519.40 --- 0.00 4.95 5971198.64 591303.46 N 70.33102560 W 149.259 SV2 2935.23 61.13 30.78 2195.00 2276.10 1473.39 1307.52 681.81 --- 0.00 5.07 5971473.22 591462.55 N 70.33177045 W 149.258 SV1 3660.07 61.13 30.78 2545.00 2626.10 2108.04 1852.84 1006.63 -- 0.00 5.26 5972022.39 591780.71 N 70.33326014 W 149.25545824 9-5/8" Csg Pt 4126.04 61.13 30.78 2770.00 2851.10 2516.03 2203.41 1215.44 --- 0.00 5.36 5972375.42 591985.25 N 70.33421777 W 149.25376407 UG4 4291.71 61.13 30.78 2850.00 2931.10 2661.10 2328.06 1289.68 -- 0.00 5.38 5972500.95 592057.97 N 70.33455826 W 149.25316166 UG4A 4374.55 61.13 30.78 2890.00 2971.10 2733.63 2390.38 1326.81 -- 0.00 5.40 5972563.71 592094.33 N 70.33472851 W 149.25286045 UG3 5120.10 61.13 30.78 3250.00 3331.10 3386.42 2951.29 1660.90 --- 0.00 5.51 5973128.57 592421.59 N 70.33626067 W 149.25014932 UG1 6228.06 61.13 30.78 3785.00 3866.10 4356.53 3784.86 2157.41 --- 0.00 5.64 5973968.01 592907.93 N 70.33853757 W 149.24611951 Possible Flt Crossing 6466.22 61.13 30.78 3900 3981.1 4565.06 3964.04 2264.14 --- 0 5.66 5974148.45 593012.47 N 70.33902698 W 149.24525318 Drp 4/100 6489.21 61.13 30.78 3911.10 3992.20 4585.19 3981.33 2274.44 178.30E 0.00 5.67 5974165.86 593022.55 N 70.33907421 W 149.24516957 6500.00 60.70 30.77 3916.34 3997.44 4594.62 3989.43 2279.26 178.30E 4.00 5.67 5974174.02 593027.28 N 70.33909635 W 149.24513041 6600.00 56.70 30.62 3968.29 4049.39 4680.03 4062.89 2322.87 178.22E 4.00 5.71 5974247.99 593069.99 N 70.33929699 W 149.24477641 Drp 0.5/100 6698.24 52.77 30.47 4025.00 4106.10 4760.22 4131.95 2363.63 HS 4.00 5.74 5974317.54 593109.91 N 70.33948562 W 149.24444553 Ma 6698.25 52.77 30.47 4025.01 4106.11 4760.23 4131.96 2363.64 HS 0.50 5.74 5974317.55 593109.91 N 70.33948565 W 149.24444548 6700.00 52.76 30.47 4026.07 4107.17 4761.62 4133.16 2364.34 177.94E 0.50 5.74 5974318.75 593110.60 N 70.33948893 W 149.24443975 6800.00 52.26 30.45 4086.93 4168.03 4840.96 4201.56 2404.56 177.92E 0.50 5.75 5974387.63 593149.99 N 70.33967575 W 149.24411323 Mbl 6861.99 51.95 30.43 4125.00 4206.10 4889.88 4243.73 2429.35 177.91E 0.50 5.76 5974430.09 593174.26 N 70.33979094 W 149.24391204 6900.00 51.76 30.42 4148.48 4229.58 4919.77 4269.51 2444.49 177.91 L 0.50 5.76 5974456.05 593189.09 N 70.33986135 W 149.24378913 Mb2 6966.83 51.43 30.41 4190.00 4271.10 4972.14 4314.67 2471.00 177.90E 0.50 5.77 5974501.53 593215.05 N 70.33998471 W 149.243 7000.00 51.26 30.40 4210.72 4291.82 4998.04 4337.01 2484.11 177.89E 0.50 5.77 5974524.02 593227.88 N 70.34004572 W 149.2434 46 7057.53 50.97 30.39 4246.83 4327.93 5042.82 4375.64 2506.76 -- 0.50 5.77 5974562.91 593250.07 N 70.34015123 W 149.24328352 7059.38 50.97 30.39 4248.00 4329.10 5044.26 4376.88 2507.49 177.81 L 0.00 5.77 5974564.16 593250.78 N 70.34015461 W 149.24327762 Mc 7078.42 50.88 30.38 4260.00 4341.10 5059.04 4389.63 2514.97 177.80E 0.50 5.78 5974577.00 593258.10 N 70.34018944 W 149.24321692 7100.00 50.77 30.38 4273.63 4354.73 5075.77 4404.06 2523.43 177.80E 0.50 5.78 5974591.53 593266.39 N 70.34022886 W 149.24314824 Na 7180.87 50.36 30.36 4325.00 4406.10 5138.22 4457.95 2555.00 177.79E 0.50 5.79 5974645.80 593297.30 N 70.34037605 W 149.24289190 7200.00 50.27 30.35 4337.22 4418.32 5152.94 4470.65 2562.44 177.78E 0.50 5.79 5974658.59 593304.59 N 70.34041075 W 149.24283150 Nb 7212.17 50.21 30.35 4345.00 4426.10 5162.30 4478.73 2567.17 177.78E 0.50 5.79 5974666.72 593309.22 N 70.34043280 W 149.24279312 Nc 7266.70 49.93 30.33 4380.00 4461.10 5204.11 4514.81 2588.29 177.77E 0.50 5.79 5974703.05 593329.90 N 70.34053137 W 149.24262163 Ne 7282.22 49.86 30.33 4390.00 4471.10 5215.98 4525.06 2594.29 177.77E 0.50 5.80 5974713.37 593335.77 N 70.34055936 W 149.24257295 7300.00 49.77 30.33 4401.47 4482.57 5229.56 4536.78 2601.15 177.77E 0.50 5.80 5974725.18 593342.49 N 70.34059138 W 149.24251727 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Plan V Slot (N-Z+1)\Plan V-220 (NZ+1)\Plan V-220\V-220 (P7) Generated 1/25/2008 9:04 AM Page 2 of 3 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS /4uu.w 4`J.L/ JU.3U 44Ut7.4U 454/.5U 53U5.tlZ 46UZ.44 2b39.53 1 //./5L U.SU 5.tf1 59/4/91.29 5933tiU .U/ N 7U.34U7707Z W 149.24220559 7413.17 49.20 30.30 4474.99 4556.09 5315.59 4611.05 2644.57 -- 0.50 5.81 5974799.96 593385 .00 N 70.34079423 W 149.24216474 V-220 Tgt 1 OA 7413.18 49.20 30.30 4475.00 4556.10 5315.60 4611.06 2644.57 180.00E 0.00 5.81 5974799.97 593385 .00 N 70.34079425 W 149.24216471 OA 7420.83 49.16 30.30 4480.00 4561.10 5321.39 4616.06 2647.49 180.00E 0.50 5.81 5974805.00 593387. 86 N 70.34080790 W 149.24214100 7500.00 48.77 30.30 4531.98 4613.08 5381.11 4667.62 2677.62 180.00E 0.50 5.81 5974856.92 593417 .36 N 70.34094875 W 149.24189639 OBa 7527.31 48.63 30.29 4550.00 4631.10 5401.63 4685.34 2687.97 180.00E 0.50 5.82 5974874.76 593427. 50 N 70.34099713 W 149.24181236 OBb 7587.66 48.34 30.29 4590.00 4671.10 5446.81 4724.36 2710.76 180.00E 0.50 5.82 5974914.05 593449. 81 N 70.34110370 W 149.24162728 7600.00 48.28 30.29 4598.21 4679.31 5456.03 4732.31 2715.41 180.00E 0.50 5.82 5974922.06 593454 .37 N 70.34112544 W 149.24158954 Oec 7677.52 47.89 30.29 4650.00 4731.10 5513.71 4782.13 2744.51 180.00E 0.50 5.83 5974972.21 593482. 86 N 70.34126149 W 149.24135328 7700.00 47.78 30.29 4665.09 4746.19 5530.37 4796.51 2752.91 180.00E 0.50 5.83 5974986.70 593491 .08 N 70.34130078 W 149.24128505 V-220 Tgt 2 OBd 7751.83 47.52 30.29 4700.00 4781.10 5568.68 4829.58 2772.23 LS 0.50 5.84 5975020.00 593510 .00 N 70.34139112 W 149.241 OBd 7751.84 47.52 30.29 4700.01 4781.11 5568.69 4829.59 2772.24 LS 0.50 5.84 5975020.01 593510. 01 N 70.34139114 W 149.2411 7800.00 47.28 30.29 4732.60 4813.70 5604.14 4860.21 2790.12 LS 0.50 5.84 5975050.83 593527 .51 N 70.34147475 W 149.24098297 7847.65 47.04 30.29 4765.00 4846.10 5639.07 4890.37 2807.74 LS 0.50 5.84 5975081.21 593544 .77 N 70.34155715 W 149.24083988 OBe 7847.66 47.04 30.29 4765.01 4846.11 5639.08 4890.38 2807.74 LS 0.50 5.84 5975081.22 593544. 77 N 70.34155718 W 149.24083984 7900.00 46.78 30.29 4800.76 4881.86 5677.31 4923.39 2827.02 LS 0.50 5.85 5975114.45 593563. 65 N 70.34164733 W 149.24068330 OBf 7913.48 46.72 30.29 4810.00 4891.10 5687.13 4931.87 2831.98 LS 0.50 5.85 5975122.99 593568. 50 N 70.34167048 W 149.24064308 OBf Base 7978.92 46.39 30.29 4855.00 4936.10 5734.63 4972.89 2855.94 LS 0.50 5.85 5975164.29 593591. 96 N 70.34178252 W 149.24044853 8000.00 46.28 30.29 4869.56 4950.66 5749.88 4986.06 2863.63 LS 0.50 5.85 5975177.55 593599. 49 N 70.34181849 W 149.24038607 TD ! 7" Csg 8097.65 45.79 30.29 4937.34 5018.44 5820.17 5046.75 2899.08 -- 0.50 5.86 5975238.66 593634. 20 N 70.34198426 W 149.24009821 Legal Description: Northi ng (Y) [ftUS] Easting (X) [ftUS] Surface : 4907 FSL 1503 FEL S11 T11N R11E UM 5970157.67 590796.67 V-220 Tgt 1 OA : 4238 FSL 4135 FEL S1 T11N R11E UM 5974799.97 593385.00 V-220 Tgt 2 OBd : 4456 FSL 4007 FEL S1 T11 N R11 E UM 5975020.00 593510.00 BHL : 4673 FSL 3880 FEL S1 T11N R11E UM 5975238.66 593634.20 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Plan V Slot (N-Z+1)\Plan V-220 (NZ+1)\Plan V-220\V-220 (P7) Generated 1/25/2008 9:04 AM Page 3 of 3 by Schlumherger WELL FIELD STRUCTURE V-220 (P7) Prudhoe Bay Unit - WOA V-Pad MagneOC Parameiars Surface Lwdllaf NAU2]Alaska 9pte Planas_ZOne 04, US Fee[ Mluelkne°us MoCel: BGGM 2001 Dp: BO B]3" Date: FeMUary 18. 2008 Lat N]0 t941S15 nM1ny. 59]015]e]flUS Grb Gonv: •069340350' Slot. PIanV SIW iN-Z•11 NU Ref: Rotary Tack 181.10 ftaGOVe M8L1 Mag Dec •23.098° FS 5]644.5 nT Lon W149 1549.043 Easuny. 590'l9fi fi/ ftt15 Scale Fact 0999909366 Plan V 2201P)1 Srvy Oate. Janwry 25, 2008 -1000 0 1000 2000 3000 4000 5000 6000 0 1000 ~ 2000 C 0) N ~ 3000 D H 4000 5000 .........:................................. ' RTE.................:...................................;..................................;..................................:...................................:..................................j........................ KOP Bld 1.5/100 .. _..-;.._.._.._.._.._.._.._.. _.. .. _. ._.._.._.._.._..~.._.._.._.._.._.._.._.._.i-.._.._.._.._.._.._.._.._.i_.._.._.._.._.._.._.._.._i._.._.._.._.._.._.._.._..y.._.._.._.. _.. _.._.._.._..i.._.._.. _.._.._.._ Bld 2.51100 Bld 3.5/100 .::..:: =•: -::.t: vr::.tr..t::.t::.e::.t::.T •: •r::.e:: a::~::s::.•r::,;r::.t::.t::.r::.r::.t::.t::.•r::.t :yt: :.t::.t::t::e ::t::e::.t::~.'t~::.t::.t: •.r:: trartnt::•r::.r=:.t::.•r::.t::t::t::r::t:: e::.4:.t::.t::t: nt:: w::.t::T::•r::.T::.T::-::.~::a::e::~ v€"' End ~Id BId3.51100 ' Fault Crossing End Bld r-.. K.. ....................~~Se7err7t'~SV4 t.- ..r.. ....................i........................o........................i.........................i.. .......................i................. .........:..................................:................................ ...................................:..................................j..................................:.....................................................................:........................ .. _.. ~.. _.. _.._.._.. _.._.._.._.. j.. _.._.. _.._.._.. _.. _.. _.. j... .._.._.._.. _.. _.._.j_.. _.. _.. _.. _.. _.._.._.. _.. _.. _.. _.. _.. _.. _.. _.. _.. _j. _.. _.._.._.._.._.._.._..y..•.._.. _.. _.._.._.. _.._.. j.. _.._.. _.. _.._.. _ 9-518" Cig Pt ... ..............................•.t .• ........................... ....... ....... ... ~:. Possible FIt Crossing Drp 41100 Drp 0.51100 .......j ..................................j..............-.......-...........~.................-.................j..................................j.................................. ~.-................ ................................1........................ .. _.. ~.. _.._.._.._.._.._.._.._.. s.._.._.._.._.._.._.._.._..... _.._.._.._.._.._.._.._._.._.._.._.._.._.._.._.._•i _.._.._.._.._.._.._.._.._i. _.. _.. _.. _.. _.. _.. _.. . ~.._.._.._..Y 22I1 S6R i Da..i.._. ~_.._.~_.. _.._ ._..K.._.._.._.._.._.._.._.._.. i.._.._.. _.._.. _. ~.._.. _..f.._.._.._.._.._. ~.. _.. _.1_.._ ._. ~.._.. _.._.. _.._ j_.._.._.._.._.._.._.._.._/._.. _.. _.. _.._.. _. ~.._. .. _.._.._.._.._.. •.._.._.._.. _.._.._ tt.txrRStart-tt-tt-tt:ttat[^tt^ttttstst[.tt.t[ut^tt.ttatttt[/ttattat[.tt.tr~tt~rt~t[.tt.tti:tiff:itiiiitt=ix-titriatt-tt-t[-tt-tt.tx.tta[t.t[^[t.[t.tt^tt.'t.il-tl.ts R: :t :at:st:at:.ttsstjtt~tt-t~-xt-tt-tti .. .r.ro.. .r n ...u..w.u...u...........ato.........._........ .. . .. . ........ . . . . ..«.u .. .r r. r. u.....r......... ..... . . . . «.. ... . rr .. u . _...j.. ..-..-..-..-..-..-.._.. j. _.._.._.._.._.._.._.._ .j... _.._.. _.._.._.. _.._.._.j_ ._.._.._.._.._.._.._.. ..-.._..-..-..•..-.._. _i._.._.._.._.._.._.._.._..i.. .. ._. T7.G.T~tRil9A._.._.._.. - .._..~.._.._.._.._.._.._.._.._. ~.._.._.._.._.._.._.._.._..r.._.._.._.._.._.._.._.._.1_.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._.._/._.._.._.. _.. _.. _.._.._..y.._.._.. _.._.._ ._.._.. .T: ._.. _.._ .........:..................................:..................................:...................................:..................................:............................... ~..:......................................................... ~ aae....................... _ZZQ (p7) 0 1000 2000 3000 4000 5000 •I • -1000 0 1000 2000 3000 4000 5000 6000 Vertical Section (ft) Azim = 29.87°, Scale = 1(in):1000(ft) Origin = 0 N/-S, 0 E/-V 5250 4500 3750 n n n Z 3000 0 ti c a~ v 2250 v v v 1500 750 0 by ~ • ° Schlumherger WELL V-220 (P7) FIELp Prudhoe Bay Unit - WOA BTRUpTURE V-Pad Magretk Parameters Surtace LOCafion Ng03] glaska 51a1e Planes. Zone Od. US Fael Mlscallan eous ' MoEel. BGGM 200] pip. BO 6]3° Dale. February 18.300H Laf. N]01961.515 Nortbirg'. 59 ]015]fi]MIS GnE panv: ~069340J50° PIanV SIOf 1N-Z~11 NDRei'. Rotary Table 161.19fl above MSL~ Mag Dec. X23096' FS'. 5]666.5 nT Lan'. W169 15 69 063 EasOng'. 590]9fi fi]M1S Scale Fact: 0.999909365 Plan'. V-3201P]) Srvy Dale: January 25. 3005 0 750 1500 2250 3000 5250 4500 3750 3000 2250 1500 750 0 0 750 1500 2250 300( c« W Scale = 1(in):750(ft) E »> 0 G Field: Prudhoe Ba~• Site: PB V Pad Nell: Plan V-220 (N-Z+1) Wellpath: Plan V-220 N"GStI-Y~Laal-1 j800tGin~ -800 0 800 1600 ?iW }'_00 Jfi00 18W Plan V-220 (N-Z+l )/Plan V-220 BP Alaska Anticollision Report Company: BP Amoca Date: 1/18/2008 'l'ime: 12:54:09 Page: 1 Ficw: Prudhoe Bay Keference Site: PB V Pad Co-~irdinate(NE) Reference: Well: Plan V-220 (N-Z+1 ), True North Reference Well: Plan V-220 (N-Z+1) Vertical-(TVD)Reference: V-220 Plan NZ+1 81.1 Reference Wellparh: Plan V-220 - Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of - - reference -There are 1[NPIi~Iiseells in thisRtiidlpal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 8097.65 ft Scan Method: Trav Cylinder North ~ Maximum Radius: 1006.91 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath 'I Date: 10!5/2007 Validated: No Planned From To Survey ft ft 28.50 800.00 Planned: Plan #7 V1 ', 800.00 2200.00 Planned: Plan #7 V1 800.00 4100.00 Planned: Plan #7 V1 4100.00 8097.65 Planned: Plan #7 V1 Casing Points MD TVD Diameter ft ft in -- 4126.04 2851.10 9.625 ', 8097.65 5018.44 7.000 Summary Version: 7 Toolcode Tool Name J GYD-GC-SS Gyrodata gyro single shots MWD MWD -Standard MWD+IFR+MS MWD +IFR + Multi Station MWD+IFR+MS MWD +IFR + Multi Station Hole Size Name in 12.250 9 5/8" 8.750 7" ~' <------------- Offset Wellpath ----- ------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpat4 MD MD Distance Area- Deviation Warning ft' ft ft ft tt PB V Pad Plan V-207 (S-Z) Plan V-207 V3 Plan: PI 335.26 340.00 181.23 6.62 174.61 Pass: Major Risk ', PB V Pad Plan V-219 (S-Z+1) Plan V-219 V7 Plan: PI 351.26 355.00 180.42 6.65 173.77 Pass: Major Risk ' PB V Pad Plan V-224 (N-Z) Plan V-224 V2 Plan: PI 666.08 670.00 16.62 12.67 3.94 Pass: Major Risk ', PB V Pad Plan V-227 (N-Y) Plan V-227 V3 Plan: PI 353.05 355.00 31.54 6.79 24.76 Pass: Major Risk ', PB V Pad Plan V-228 (S-Y) Plan V-228 V2 Plan: PI 300.98 305.00 182.91 5.82 177.09 Pass: Major Risk '~ PB V Pad V-03 V-03 V7 364.84 285.00 59.75 5.88 53.87 Pass: Major Risk ', PB V Pad V-04 V-04 V7 327.39 330.00 181.37 6.09 175.28 Pass: Major Risk ~, PB V Pad V-07 V-07 V15 384.58 390.00 225.77 7.46 218.31 Pass: Major Risk ', PB V Pad V-100 V-100 V7 271.44 275.00 196.02 4.78 191.24 Pass: Major Risk ', PB V Pad V-103 V-103 V6 356.43 360.00 120.28 6.26 114.02 Pass: Major Risk ', PB V Pad V-105 V-105 V13 355.19 360.00 196.38 6.10 190.28 Pass: Major Risk PB V Pad V-106 V-106 V10 374.74 380.00 148.77 6.12 142.65 Pass: Major Risk PB V Pad V-106 V-106A V9 446.88 455.00 149.56 9.96 139.61 Pass: Major Risk ', PB V Pad V-106 V-106APB1 V7 446.88 455.00 149.56 9.96 139.61 Pass: Major Risk ', PB V Pad V-106 V-106AP62 V2 446.88 455.00 149.56 9.96 139.61 Pass: Major Risk ', PB V Pad V-106 V-106AP63 V2 446.88 455.00 149.56 9.96 139.61 Pass: Major Risk ', PB V Pad V-111 V-111 V25 411.20 415.00 88.45 7.76 80.68 Pass: Major Risk ', PB V Pad V-111 V-111 PB1 V9 425.80 430.00 88.75 9.50 79.25 Pass: Major Risk ', PB V Pad V-111 V-111 P62 V2 425.80 430.00 88.75 9.50 79.25 Pass: Major Risk ', PB V Pad V-111 V-111 P63 V6 411.20 415.00 88.45 7.76 80.68 Pass: Major Risk PB V Pad ~ V-115 V-115 V5 315.25 320.00 184.78 5.38 179.40 Pass: Major Risk PB V Pad V-115 V-115P61 V4 315.25 320.00 184.78 5.38 179.40 Pass: Major Risk ', PB V Pad V-117 V-117 V9 280.64 285.00 209.48 5.05 204.43 Pass: Major Risk ', PB V Pad V-117 V-117PB1 V6 280.64 285.00 209.48 5.05 204.43 Pass: Major Risk PB V Pad V-117 V-117PB2 V6 280.64 285.00 209.48 5.05 204.43 Pass: Major Risk PB V Pad V-120 V-120 V6 912.71 920.00 28.03 19.43 8.60 Pass: Major Risk ', PB V Pad V-121 V-121 V5 313.63 320.00 226.42 6.74 219.68 Pass: Major Risk PB V Pad V-122 V-122 V10 615.31 645.00 202.78 11.07 191.71 Pass: Major Risk PB V Pad V-122 V-122PB1 V10 615.31 645.00 202.78 11.07 191.71 Pass: Major Risk PB V Pad V-122 V-122P62 V7 615.31 645.00 202.78 11.07 191.71 Pass: Major Risk PB V Pad V-204 V-204 V2 515.37 550.00 365.77 9.39 356.38 Pass: Major Risk PB V Pad V-204 V-204L1 V2 515.37 550.00 365.77 9.39 356.38 Pass: Major Risk PB V Pad V-204 V-204L2 V2 6470.16 9220.00 696.63 No Offset Errors PB V Pad V-204 V-204L3 V4 515.37 550.00 365.77 9.39 356.38 Pass: Major Risk PB V Pad V-204 V-204P62 V2 515.37 550.00 365.77 9.39 356.38 Pass: Major Risk PB V Pad V-212 V-212 V7 339.10 340.00 136.08 5.95 130.13 Pass: Major Risk PB V Pad V-213 V-213 V5 1269.27 1345.00 137.28 20.32 116.96 Pass: Major Risk ', PB V Pad V-213 V-213P61 V5 1269.27 1345.00 137.28 20.32 116.96 Pass: Major Risk PB V Pad V-216 V-216 V8 484.20 490.00 104.00 8.95 95.05 Pass: Major Risk PB V Pad V-217 V-217 V5 314.21 320.00 233.93 6.74 227.19 Pass: Major Risk ~~ PB V Pad V-218 V-218 V7 1065.90 1085.00 43.37 19.22 24.15 Pass: Major Risk BP Alaska Anticollision Report __- - - - -- Compan~: BP Amoco Dater 1/18/2008 Time: 12:54:09 Page: 2 " Field: Prudhoe Bay Reference Site: PB V Pad Co-ordinate(NF.) Reference: Well: Plan V-220 (N-Z+1), True North Reference Well: Plan V-220 (N-Z+1) Vertical (TVD) Reference: V-220 Plan NZ~1 81.1 Reference Wellpath: Plan V-220 Db: Oracle Summary <------- -- Offset Wellpath ---- ---> Reference Offset Ctr-Ctr No-Co Allowable '.Site Nell Wellpath Ml) MD Distance Area Deviation ft ft ft ft ft PB V Pad V-221 V-221 V8 2160.09 2260.00 258.18 68.95 189.22 ', PB V Pad V-222 V-222 V6 627.05 650.00 255.03 11.86 243.17 Warning Pass: Major Risk ', Pass: Major Risk ', FieldPrudhoe Bay Site PB V Pad We11:Plan V-220 (N-Z+1) WellpathElan V-220 -3 1 3 300 200 100 0 2 100 200 300 -3 1 3 0 Travelling Cylinder Azimuth (TFO+AZI) [degJ vs Centre t Site: PB V Pad Drilling Target Conf.: 95% Description: Map Northing: 5974800.00 ft Map Easting :593385.00 ft Latitude: 70°20'26.860N Shape: Circle Target: V-220 Tgt OA ell: Plan V-219 (S-Z+1),Plan V-220 (N-Z+1) Based on: Planned Program Vertical Depth: 4475.00 ft below Mean Sea Level Local +N/-S: 4611.08 ft Local +E/-W: 2644.56 ft Longitude: 149° 14'31.793 W Radius: 100 ft 4 ~i i[i h'3i~0 6 loll 4hL~~' 4-r~ i.4 00 0 0 0 0 0 0 Site: PB V Pad • Drilling Target Conf.: 95% Description: Map Northing: 5975020.00 ft Map Easting :593510.00 ft Latitude: 70°20'29.008N Shape: Circle Target: V-220 Tgt OBd . Plan V-219 (S-Z+1),Plan V-220 (N-Z+1) Based on: Planned Program Vertical Depth: 4700.00 ft below Mean Sea Level Local +N/-S: 4829.57 ft Local +E/-W: 2772.23 ft Longitude: 149° 14'28.061 W Radius: 100 ft =i0 ;_ _. __ . _ - - - , ~, D o 0 0 0 DD o 0 0 0 Q 0 ~ ~ oo ~ o ~ ~ ~ ~ c~ D~} ~} c~ c~ m 4 i ~r; 4 i "10 4~1f1 -,10 0 0 m Alaska Department of Natural: ources Land Administration System Page 1 of 4 • .,~._ U~;c~- > u~~;r;~h Sfate Cabins :`I~.f~rh'~~~s~~ S -~ i..AS illtenu I Case Abstract 1 Case Detail I Land Abstract /~~ile: :1llL ?8210 ~ Search for Status Plat Updates 1~ ~~f O210~ ~'U08 Customer: 000107377 BP EXPLORATION (ALASKA) INU PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA. ANCHORAGE AK 995196612 Case 7ihe: %~=~ OIL R GAS LEASE COIvIP DNR Unit:. 780 OIL AND GAS File Location: DOG UTV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Totes! Acres: 2560.000 Date Initiated: 05/28/1965 Office of Prima~~y Responsibility: DOG DIV OIL AND GAS Last Trarrsacti~~n Date: 12/04/2006 Case Subtype : ~~~ NORTH SLOPE Last Transaclio~~r: AA-NRB ASSIGNMENT APPROVED Mcrrr~~iu~i ~ U Toivftsfup: U I IN 2~m-~~: 01 I E Section: Ol .5'ectinn _lrr~~s: 6-1(1 Search Plats l~e'7"h11~U1.~ ~~ ~iT1171S'~11~1; Of ~ ~' ~~Clil,;~c'.' OIIE ~~c'C'/It)/1: O2 _S~c'~'l/(~il.'~~'PC~~: ~~~I} l~r'IYc~lilfl.~ (-~ ~Utt'il.~'~Ilj?: UI i~~ IiUR,~'C." 011E .~~NCIl~~l7: i I SC'~'l/UU.-~CI"C.C: (1-~(~ Mc°ricliart tJ %inrns{lrj~: U I 1 ~ R~irr,c~.~ 0I IE Se~~tru~~.~ I ? S'~~ctiuir -Icr~~: (,-((} Legal Description 0~-25'-1965 * ~ *SALE NOTICE LEGAL DESCRIPTION* CIS-19 OIIN-011E-UM 1,2,17,12 260.00 0=~-01-1977 *'~`UMTIZED,LEASE AND P:~RTICIPATING AREA LEGAL DESCRIPTION* LEASE COlt'IMITTED IN ENTIRETY TO PR UDHOE 13AY UNIT AND OIL RI~%t GAS CAP PA PRUDHOE I3AY UNIT http://www.dnr. state.ak.us/less/Case_Summary.cfm?FileType=ADL&FileNumber=28240&... 2/7/2008 Alaska Department of Natural ~ ources Land Administration System Page 2 of 4 TIZ~4 CT ~ ~ OIL RIl'~iAND GAS CAP PARTICIPATING _ACEAS T. 11 N . K. I1 E. , UMIAT MERIDIAN, ALASKA SECTION 1: ALL. 6-10.00 ACRES; SECTION 2: ALL, 640.00 ACRES; SECTION I I: ALL, 640.00 ACRES; SECTION 1?: ALL. 640. DO ACRES: CONTAINING APPROXIMATELY 2, ~ 60.00 ACRES, MORE OR LESS. ~~*+~k~*~r*>,<ic:k*;~:~~~~*##=k~~~;6 :k*~*~k~~>;<~k~~*;;<#~k :t~~ =~x~~k:t**=k~~k ~=;tx~k ~k*#x**~x~-:~~ l I -01-?001 * `kFORNIATION OF BOREALIS PARTICIPATING AREA LEGAL DESCRIPTION LEASE /NCORPORATED IN PART INTO THE BPA PR UDHOE BA F UNIT BORE 4LIS PARIICIP 9 TING AREA TRACT ~0 (PARTIAL) T.11 N. , R. I 1 E. , UMIAT MERIDIAN, ALASKA SECTION 1: W?, YV2E2, 480.00 ACRES, SEC TION Z: ALL, 6=10.00 ACRES, SECTION 11: N2, N2S2, 480.00 ACRES; SECTION 12: Nb~4, W?NE4, 2-10.00 ACRES; THIS TRACT CONTAINS 1, 8-10.00 ACRES, MORE OR L ESS. =k~~~~:;i:~;kx~:x;k~*~k*x#~**~k*~ex;k ~kx~*~k*~=T;k~>;<x#~:*,k ~e ~k~~k r>,<*x*~xx~F>;: ;e ~k ~;;<~e ~c ~e :k ;g ,e x;k~# 02-01-2004 '~ `F'ORMATION OF ORLON PARTICIPATING AREA LEGAL DESCRIPTION* LEASE, COMMITTED IN PART TO ORLON PARTICIPATING AREA PRUDNOE BAY UNIT TRACT ~ 0 ORLON PARTICIPATING AREA T 11 f~%., R. 11 E., UMIAT MERIDIAN, <?LASKA http://www.dnr. state. ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28240&... 2/7/2008 "Alaska Department of Natural Resources Land Administration System • S'EC'TION` I:.4LL, 6-)O.OOACKZ;~S'; :SEC'TIOV ?: ALL. 60.00 ACRES; SECTION 11: EI/2, EI/ZNWl,~~, -X00.00 ACRES, SECTION 1?: ALL, 6~0. DO ACRES: CONTAINING APPROXI~lI4TELY 2, 320.00 ACRES, MIORE' OR LESS. . x:~'<~Y~:x„~#~;k~xx;e ~: ;k *:~;:: ~:~~;gt~~ ~ ;~x:~;<~#**=kph*xx:k=k~~x~:<:Ya*:<~:~~:*:k ;;~~;~ <~ <:g+~xx 1?-01-200-1 ~~ ` * `BOREALIS PA E_~PANDED, LEASE INCORPORATED IN PART LEGAL DESCRIP"LION LS AS FOLLOi~S: PR UDHOE I3AY UNIT 130REALIS P ~RTICIPATING ARF_A ZRACT ~0 (PARTIAL) T TIN., R. TIE., U~~IIATMERIDL~N, ALASKA S'E'CT ION 1: E2E2, 160.00 ACRES; SECTION 11: S2SE~1. 50.00 ACRES; SECTION' 12: S2, F_ZNE4, 400. DO ACRES; THIS TRACT CONTAINS 6-10.00 ACRES, MORE OR LESS. Page 3 of 4 ~~THE ACKI'AGE NOW INCORPORATED INTO THE BPA LS DESCRIBED AS FOLLOWS: PRUDHOE I3AY UNIT BOREALIS' PARTICIPATING AREA TR.~1Ca' ~ 0 (PARTI~IL) T. II1V., T. 11 E. , U~IIl 4 T ~YIERIDIAN, ALASKfi SLGTION I: ALL, 6.10. DO ACRES; SECTIOiV 2: ALL, 60.00 ACRES: SEC'T~QN 11: N2, SE=1. N2St~-1, X60 ACRES; S~eTlON12: ALL. 6~IO.OOACRI'S; http://www. dnr.state. ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=28240&... 2/7/2008 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 6000000 5950000 5900000 5850000 400000 500000 600000 700000 800000 i • r~ L TRANSMITTAL LETTER CHECKLIST WELL NAME ~,~`/- J~.~aO PTD# a?O~Ov~ Up Development / Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~.~~D.yDE"~y~EZd POOL: .E'/off ~~.~.~AD~ .UL!!«" 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 (If last two digits in API number well permit No. ,API No. 50- - - 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 i SAMPLE n 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 Well Please note the following special condition of this permit: production or production testing of coat bed methane is not allowed for (name of well) until after (Company 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 testin g ro ram. Rev: 1/i 1/2008 WELL. PERMIT CHECKLIST F~kf & Pool PRUDHOE BAY, ORION SCHR BL OIL - 640135 WeH Name: PRUDHOE BAY UN GRIN V•220 Rrogram SER Well bore seg ^ PTD#:2060200 Company 8P E7(PLOR TION (ALASI(A~INC initial Classllype SER ! P END GeoArea 890 Unit 11650 On10if Shore _4n Annular Disposal ^ Administration 1 Pem~itfeeattached- --------- ---- -- - ----- --- - -~----- - - -- --- ---- ----- - -- --- ---- - - - ~ 2 Lease numberapPropriate -------- --- - -- - - - ----Yes -- -- -- - -- -- ------ ------ - --- -- - ----- 3 UnigoaweAnameet~number- - ------- ~ - ----- - --- - - Yes--- - -- --- --- - - ------- - -- --- - ---- -- 4 _1ryalUccatedin-adefinedp~l------ --- --- - -- - --- Y~ - --- -- -- --- - - --- ---- - ----- - ----- -- ------- 5 WallJxatadpropardistaticefromdr'ilin9unr!-boundary---------------- -----Yes------ ------------------------------------------------------------------- 6 WeNlccatedproparQistancefromotherwells------------------------- -- --Yes------ ------------------------------------------------ ----- 7 SuffrGiantacrsa9e_availablein_driklipgunii----- ------ -- --- ----Yes --- -------- - --- -- -- --- -- -- - ----- - ----- 8 If_deviated,is-wellbQrsplat_included_---_-_---------------------- -----Yes------ -------------------_ _---- ------------------------------------------ 9 Oper~atoroalyaf(ectedPe~V---- - ----- -- -- - -- --- ---Yes - ------ - -- -- - ------ -- --- - -- -- - ---- 10 Ope[atorbas_aAPmprlaiebondmfcrce--------------------------- -----Yes_----- -9lanketSond#6194193----------------------------------------------------- 11 Pe[mitr~nba[aauedwithQUtconsarvatlonorder--------------------- -----Yes------ -------------------------------------------------.--------------- Appr Date 12 Permit can be issuedwlthoutadministraiive_approval-------------------- - ---Yes--.--- --------------------------------------------------.--------------- ACS 2f112008 13 Canpermlt-beapPravedbafors15•dayvtaN------ - -- ----- --- -- Yes------ - -- --- ~ ------ - ----- --- -- - ---- --- 14 -Wflll Iccated wNhin area and strata authorized by Injection Drder # (put 10# in_comments)_ (For- Yes _ _ - _ _ - - AIO.26A_ _ - _ _ . - _ - - - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 -All wells_with~l(4_mike~ataaof[eviewidentifa[d(Forse_rvir~wehooly)---------- -----Yea.----- ---------------------------------------------.--------------------- 16 Pte-producedinjecior. duration ofpra-production~ssthan3montha_(Forservkcawailonly)---NA------ -------------------------------------------------------------------- 17 Nonconven,gas:conformstcAS31.0~.030Q.1.A),U.2.A-D) --- -- - --- NA ------ -- -- - - ---- --- - -------- -- --- - - - ------ Engineering i 18 Conductor sidng.ptovided---- ------ -- -- ------- - ---Y~ -- ---- -- --- ~- ---------- - ---- - -- -- - -------- 9 Surfacecasln~protectsallknownUSDVYs-------------------------- -----NA------- -Alla4ukfersexempted,40CFR-147.102(b)(3)and-AE01.--------------------_------------ 20 CMT-voladequate_tocirculate_onconducior~surf-csg___________________ _---Yes----- ---------------------------------------------------------------- 21 CMT_voladequate_tofia~Ulongstringtosyrfcsg- --- -- -- -- - - - -- N0 --- --- - -- - - ---- --- -- ------- - --- -- - ------ 22 CMT-willcoyer_alikna+an_ptoductivebarizcns----------------------- -----Yes------ ------------------------------------------------------------------ 23 CasingdeslgnsadequateforC,?68~_pennafmst-- - - -- -- --- ----Yes- --- - -- ---------- - ------- -- -- - -- -- -- 24 -Adequate tankage_or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - _ - - _ -Yes - - _ _ _ . _ Rig equipped with steel pits. No rase[ve pN planned,- All waste-to aRprQved disposal weN(s). _ - - _ . _ _ _ _ . - _ - 25 Ida-re'dril[alias.at0~403fQrebandonmentbeenapPraved---------------- -----NA------ -------------------------------------------------------------------- 26 Adequete_welibota separationproposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - _ - - - _ Pcoximkty analysis performed. Traveling cylinder path calculated. Gyros likely_in surface hole-. - - - - - - _ . - _ - 27 If-divertarta~uited,dcesitmeetregrllations--- -- ----- - -- -- -Yes--- - -- --- ------ -- --- --- -- -- - -- ---- --- Appr Date 28 Driling iluld_program schematlc_& equip fist-adequate- - - - - - - - - - - - - - - - - - - - - - -Yes - _ _ - - -Maximum expected formation Pressute6.6_EMW.- Planned MrN up to-9.0 ppg, _ - _ - - - - - - _ . _ _ _ - - - _ - - TEM 21612008 29 BOPEs,_dotheymeetregulation---- ------ - -- -- - -- Yes --- - - ----- -- ---- ------ - -- - ----- -- -- ~ 30 BOPI*_ptflss rating appropriate; fast to_(put psig in comments)- - - - - - - - - - - - - - - - - - -Yes - _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ - _ - MASP calculated at 1749 psi, 4000 psi_SOP tastplanned, ~ 31 Chcke_manlfolds~mRliasw/APLRP-53(MayQ4)--------------------- -----Yes-----. _ _ = = _ = ------- .' 32 WQrkwilloccurwithouiaparationshutdown_-_________------------ -----Yes---.-. ------_-------------------------------------------------------------- 33 as presende of H2S gas Probable- _ - - _ _ _ . - - - - - - -- - - - - - - - - - - - - - - - - - - - -Yes - - - - _ - _ H2S is teported_a1 Vpad• -Mud_sh9uld preclude on rig.- Rig has senscrs and_alarms.- . _ . _ _ - - - _ - _ .. - _ _ 34 -Mechanical condikion of yells wkthin AQR_ verified (Foraervice well only - - - - - - - - - - - - - - Yes _ - - _ - _ _ 2 walls in AOR.- Sufficient volume_pumpad_te covet SQ. - IntegrNy is probable. - - _ _ _ - - - _ - - _ _ _ _ - _ _ _ _ Geology 35 Pe[mitcan ba issued w1o hydroganaulfide measu[as- - - - - - - - - - - - - - - - - - - - - - - - No_ _ _ _ _ N1eN y-103=60Ppm- H2S_ (912!07); V,204=_69ppm (6!4!07. - - - - - - - - - - - - . - - - - - - - - - - - . - - - - - 36 DataptasentedonPotential9va~Presaurezones- -- --- -------- ------'~ - - ------ - -- -------- ---- - ------ - -- -- - -- -- Appr Date 37 SeismicanaryalsQfshallorygas_zonas________________________--_ ---__-NA_---_-- -____---_---_- --- --------- ----------------------------------- - --- ACS 21712008 36 Seabed.condltionsunrey_(ttoffshore)---------------------------- -----t~A----__ __---- 39 ConteCinamalphoneforweakq+.plQgressrepode(explotateryonly]------------ -----Yes------ -AdrkenneMcVey-564.4134------------------------------------------------- geologic Pu Engineering D i Commissionee Date Date: C (ssionec ~ ~ ~ Co a e ~~, 0~
