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208-154
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector V-224 (PTD #2081540) risk mitigation Date:Monday, January 26, 2026 9:49:11 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, January 23, 2026 3:04 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector V-224 (PTD #2081540) risk mitigation Mr. Wallace, Injector V-224 (PTD #2081540) is being shut-in as a precautionary measure due to possible risk associated with subsidence induced wellhead tension failure based on modeling associated with the L-202 failure investigation. The associated potential failure mode is loss of OA integrity at the wellhead. The well is now classified as NOT OPERABLE and will remain shut-in until a repair can be executed. Plan forward: Ops/ FB: Shut-in/ Freeze protect SL: Secure well with TTP Please call with any questions or concerns. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 V-224 208154 500292340000 16 12/31/2023 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, January 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-224 PRUDHOE BAY UN ORIN V-224 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/26/2023 V-224 50-029-23400-00-00 208-154-0 W SPT 4521 2081540 1500 2024 2031 2021 2026 95 100 100 100 4YRTST P Austin McLeod 12/12/2022 MITIA 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-224 Inspection Date: Tubing OA Packer Depth 0 2658 2595 2583IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM221212185451 BBL Pumped:3 BBL Returned:2.6 Thursday, January 26, 2023 Page 1 of 1 • 2��- �S�Q 2-."120 2 WELL LOG TRANSMITTAL II DATA LOGGED PROACTIVE DIAGNOSTIC SERVICES, INC. r 4.-6/201C0 e iZ D K BENDER MAY ,2 3 2613 To: AOGCC ,(>> Makana Bender '" G t-; 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2— 1 900 Benson Blvd. Anchorage, AK 99508 dancpdc@bp.com and ProActive Diagnostic Services, Inc. Attn: Diane F.Williams 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Injection Profile 02-May-16 V-224 BL/CD 50-029-23400-00 2) Signed : 7 v o_eiuDate : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(d MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP_Transmit.docx • STATE OF ALASKA 4 ALASKA OIL AND GAS CONSERVATION COMMIS—UN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other MBE Treatment Elf 2. Operator Name. BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 208-154 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service m 6. API Number: 50-029-23400-00-00 7 Property Designation(Lease Number): ADL 0028240 8. Well Name and Number: ORIN V-224 9 Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,SCHRADER BLUF OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 9960 feet Plugs measured 9687 feet true vertical 5199 feet Junk measured 9569 feet AUG 1 8 2015 Effective Depth: measured 9687 feet Packer measured See Attachment feet true vertical 5033 feet Packer true vertical See Attachment feet AO 0 C C Casing: Length: Size: MD: TVD• Burst: Collapse: Structural Conductor 80 20"Conductor 30-110 30-110 0 0 Surface 5439 9-5/8"40#L-80 33-5471 33-3065 5750 3090 Intermediate 9918 7"26#L-80 30-9948 30-5192 7240 5410 Production Liner Perforation Depth: Measured depth: 8880-8912 feet 9224-9274 feet 9296-9326 feet 9486-9568 feet 9606-9648 feet True vertical depth. 4548-4567 feet 4756-4786 feet 4799-4817 feet 4913-4962 feet 4985-5010 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9 2#L-80 28-9714 28-5049 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 3-1/2"X Nipple 3906 2509 12.Stimulation or cement squeeze summary: Intervals treated(measured): 8880'-9326' Treatment descriptions including volumes used and final pressure: 249BBLS CRYSTALSEAL gsMatIpD 13. Representative Daily Average Production or Infection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments.(required per 20 AAC 25 070 25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development 0 Service RI Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O.Exempt 315-327 Contact Summerhays,Nita M(WIPRO Technologies) Email Nita.Summerhays@bp.com Printed Name Summerhays,Nita M(W; -O Technologies) Title Petrotechnical Data Manager Sig - .--_,,,--.1" �/, Phone +1 907 564-4035 Date 08/18/2015 4 HT1 A L.—. /1 i Daily Report of Well Operations ORIN V-224 ACTIVITYDATE SUMMARY ***WELL INJECTING ON ARRIVAL***(WSO-sqz). DRIFT TO 3-1/2" MCX AT 3,902' MD W/2.85" NO-GO CENT(no issues). PULL 3-1/2" MCX @ 3,902' MD (eq device, .50 bean, sn#BPX327) 7/9/2015 ***CONT ON 7/10/15 WSR*** T/I/O = 332/136/27 Assist Slickline( Load and Test for MBE Treatment) Spear in with 3 bbls meoh followed by 10 bbls diesel down TBG.. .Pre Treatment Inj. test= Spear in 2 bbls Neat MEOH at .53 bpm @ 380 psi followed by 56.7 bbls diesel up to @ 1 bpm to 1178 psi on the 7/9/2015 TBG ***Continued on 07-10-2015 WSR**** TIO= 1203/20/0 temp=S/I ***Continued from 07-09-2015 WSR**** Assist SLB Slickline, MBE Treatment,) Continue loading TBG .. , 43.3 bbls diesel pumped at— 1 bpm building up to 1350 psi on tubing to load for a total of 100 bbls of diesel pumped to load. .. Pump 2.2 bbls diese 7/10/2015 @ Minn rate Ito help set DGLV.. ***JOB CONTINUED on 07-11-2015*** ***CONT FROM 7/9/15 WSR*** (profile mod.) LRS PUMP 100 BBLS OF DIESEL DRIFT W/2.80" CENT(s/d 9,448' slm unable to pass) DRIFT W/2.80" &2.62" CENT W/S-BAILER TO 9,584' SLM (schmoo/sand recovered) DRIFT W/2.62" &2.50"CENT W/2.50" LIB TO 9,584' SLM DRIFT W/2.72" CENT, 2.77"CENT, 2.50" LIB TO 9,589' SLM (unable to pass, sticky). SET PX PLUG BODY @ 9,397' SLM (4x 3/16" ports, oal left in hole= 24") SET PX PRONG @ 9,392' SLM (86"oal left in hole, 1.75"fn, 1.75 body) SET WHIDDON (wcs-30)@ 9,385' SLM MAKE (1)ATTEMPT TO PULL STA. #8 AT 8,913' MD PULLED RK-P-15XJR FROM STA.#8 AT 8,913' MD 7/10/2015 ***CONT ON 7/11/15 WSR*** TIO =478/16/-4 **JOB CONTINUED from 07-10-15*** Assist SLB SLickline ( MBE Treatment Pump 2.78 bbls diesel to test Plug and DGLV to 2500 psi , lost 77 psi in 15 minutes-** PASS** 7/11/2015 Bled back pressure to 10 psi.Slickline in control of well upon Departure, FWHP=4/0/0 ***CONT FROM 7/10/15 WSR***(profile mod.) SET RK-DGLV IN STA.#8 AT 8,913' MD LRS PERFORM PASSING P/T OF TUBING (see log/LRS log) MAKE (2)ATTEMPTS TO PULL STA. #4 AT 9,391' MD PULLED RK-DGLV FROM STA. #5 AT 9,307' MD PULLED RK-DGLV FROM STA. #4 AT 9,391' MD PULLED RK-DGLV FROM STA. #6 AT 9,270' MD 7/11/2015 ***CONT ON 7/12/15 WSR*** T/I/O= 0+/0/0. Temp= SI. WHP's(UIC). SLB currently working on water floor regulators. Pressure reading from SLB gauges. 7/11/2015 Wellhead valves in SLB's control upon departure. 1000 hrs. TIO= 0/40/0 PRE TREATMENT INJECTIVITY TEST ( MBE Treatment) Pumped 20 bbl DSL Followed by 90 bbl 2%Kcl to Load Tbg, Reduced rate to start Injectivity Tests @ 1 bpm, 3 bpm and 5 bpm. Well remained on a vac throughout all 3 Rate tests, Positive TBG pressure annotated in Log is Pump Pressure, Pumped 35 bbll DSL for FP TBG, Hang FP Tags, RDMO SV,WV,SSV=C 7/12/2015 MV=0 IA/OA= OTG FWHP 0/28/5 ***CONT FROM 7/11/15 WSR*** PULLED RK-DGLV FROM STA. #7 AT 9,167' MD PULLED EMPTY WCS FROM 9,388' SLM ***STA. #4, STA. #5, STA. #6 &STA. #7 ALL OPEN FOR CRYSTAL SEAL TREATMENT*** 7/12/2015 ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations _ ORIN V-224 Job Scope- Place CrystalSeal into perfs. T/I/0=1027/0/0. PJSM- Discuss barriers/rates& pressures/dropped object awareness/H2S awareness. Spot and rig up HES equipment and hardline to wellsupport hardline. Rig up LEO adaptor and remote hyd panel. Cycle SSV. Test HES global trips. Low PT 330/High PT 3900- PASS Pump CrystalSeal treatment per program 2310 lbs of CrystalSeal pumped/displace CrystalSeal into perfs with 50 bbls kcl and 35 bbls 50/50 McOH. Saw pressure increase @ 249 bbls CrystalSeal away. Well to remain shut in for 24 hrs. 1400 hrs Thursday 7-16 well will be ready for injectivity test per program. Final T/I/O=675/0/0. Swab and SSV closed/Master open. IA/OA open to gauges. Final T/I/0-675/0/0 7/15/2015 Notify pad op of well status. JOB COMPLETE***** ***LRS CURRENTLY ON WELL***(wso-sqz) SWCP 4515 STANDBY FOR LRS TO COMPLETE OPEN POCKET INJECTIVITY TEST-POST CRYSTALSEAL TREATMENT. 7/16/2015 ***CONT'D ON 07/17/15 WSR*** T/I/O=0/0/0 Injectivity test(Post Crystal seal treatment) Start down tbg. w. 5 bbls methanol, 5 bbls 7/16/2015 diesel before catching fluid. Continued on 07-17-17 WSR. T/I/O=VAC/VAC/0. Temp= SI T FL(FB request). T FL @ 1050' (9 bbl). 7/16/2015 SV, SSV, WV= C. MV=0. IA/OA OTG NOVP 1145 hr. ***CONT'D FROM 07/16/15 WSR***(wso-sqz) RUN 2.73" CENT BARBELL&2.50" LIB, TOOLS FALLING SLOWLY FROM @ 2,000'SLM TO 3,400' SLM. RAN 3-1/2" BRUSH &2.50" LIB, BRUSHED TBG TO 7,700' SLM W/LRS ASSIST, TOOLS S/D @ 9,200' SLM.(unable to pass) MADE FOUR RUNS W/ 10'x 2.25" PUMP BAILER, BAILED CRYSTALSEAL FROM 9,158'SLM TO 9,315' SLM.(recovered—4.5 gallons of crystalseal) LRS ASSISTED W/BRUSH & BAILER RUNS, PUMPED 92 BBLS OF DIESEL.(see Irs log) 7/17/2015 ***CONT'D ON 07/18/15 WSR*** Continued from 07-16-15 WSR Step rate injectivity test. Brush and flush. (Post crystal seal treatment) Established injection rate of 0.25 Bpm @ 466 psi. 0.35 bpm at 460 psi, and 0.49 bpm @ 691 psi for 20 min each. Pumped total of 41 bbls diesel down tbg for injectivity test. S-Line to set DGLVs. Slickline could'nt get down hole. Pumped 92 bbls diesel down tbg while slickline worked 7/17/2015 brush. Continued from 07-17-15 WSR. Pumped an additional 216 bbls down Tbg,while S-line worked 7/18/2015 bailer and set DGLV,s. Continued on 07-19-15 WSR ***CONT'D FROM 07/17/15 WSR***(wso-sqz) MADE FIVE RUNS W/ 10'x 2.25" PUMP BAILER, BAILED FROM 9,292'SLM TO 9,321' SLM. (recovered—7.5 gallons of crystalseal/schmoo) MADE TWO RUNS W/ 12'x 2.50" PUMP BAILER TO 9,315' SLM. (recovered —2 gallons of crystalseal/schmoo) SET RK-DGLV IN ST#7 @ 9,167' MD. MADE ONE ATTEMPT TO SET RK-DGLV IN ST#6 @ 9,270' MD. (unable to s/d) LRS ASSISTED W/BAILER RUNS, PUMPED 206 BBLS OF DIESEL.(see Irs log) 7/18/2015 ***CONT'D ON 07/19/15 WSR*** ***CONT'D FROM 07/18/15 WSR***(wso-sqz) MADE TWO ATTEMPTS TO SET RK-DGLV IN ST#6 @ 9,270' MD. (unable to s/d) BRUSHED TBG/MANDRELS DOWN TO 9,316' SLM W/3-1/2" BRUSH &2.50"GAUGE RING. MADE THREE ATTEMPTS TO SET RK-DGLV IN ST#6 @ 9,270' MD. (unable to s/d) SET RK-DGLV IN ST#6 @ 9,270' MD. MADE TWO RUNS W/ 10'x 2.25" PUMP BAILER, BAILED FROM 9,326'SLM TO 9,401' SLM. (recovered —1.25 gallons of crystalseal) LRS ASSITED W/DOWNHOLE OPERATIONS, PUMPED 214 BBLS OF DIESEL& 140 BBLS OF 1% KCL. 7/19/2015 ***CONT'D ON 07/20/15 WSR*** Daily Report of Well Operations ORIN V-224 Continued from 07-18-15. Pumped 4 bbls methanol 156 bbls 1% KCL and 118 bbls diesel to assist 7/19/2015 S-Line set DGLV and brush Tbg. Continued on 07-20-15 ***CONT'D FROM 07/19/15 WSR***(wso-sqz) SET 3-1/2"WHIDDON CATCHER SUB ON PX PLUG©9,429' MD. SET RK-DGLV IN ST#5 @ 9,307' MD. SET RK-DGLV IN ST#4 @ 9,391' MD. LRS PERFORMED FAILING PRESSURE TEST ON TBG.(see Irs log) RAN PINNED RK-1 TO ST#7 @ 9,167' MD &ST#6 @ 9,270' MD .(pins sheared) RAN PINNED RK-1 TO ST#5 @ 9,307' MD.(pins not sheared) LRS ASSITED W/DOWNHOLE OPERATIONS, PUMPED 87 BBLS OF DIESEL&80 BBLS OF 1% KCL. 7/20/2015 ***CONT'D ON 07/21/15 WSR*** Continued from 07-19-15 WSR Assist S-Line, Pumped 23 bbls dsl down tbg while slickline set DGLV. Pumped 2 bbls neat methanol, followed by 75 bbls 1% kcl down tbg while slickline RIH. Slickline hung up at station#9. Pump 1 bbls neat, followed by 22 bbls diesel down tbg for freeze protection. Pumped 64 bbls of 1% kcl down tbg while slickline RIH to set DGLV in station#4. Flush line with 2 bbls neat methanol. Pump 22 bbls diesel to freeze protect tbg. Pumped 13 bbls of dsl down tbg to check set of DGLV,s. Could only reach 800 psi @ 1bpm. Slickline to RIH and tap DGLV,s pumped an additional 6 bbls diesel, 16 bbls 1% KCL, 2 bbls methanol while S-Line tapped on DGLV,s Continued on 07-21-15 7/20/2015 ***CONT'D FROM 07/20/15 WSR***(wso-sqz) RAN 1.70" LIB TO ST#5 @ 9,307' MD. (recovered impression of open pocket) PULLED 3-1/2"WHIDDON CATCHER SUB ON PX PLUG @ 9,429' MD. (recovered st#5 rk-dgiv (scrape marks up valve/pkg, marks on wobble ring) SET 3-1/2"WHIDDON CATCHER SUB ON PX PLUG @ 9,429' MD. RAN POCKET POKER/BRUSH TO ST#5 @ 9,307' MD.(tt pins sheared) SET RK-DGLV IN ST#5 @ 9,307' MD. LRS PERFORMED PASSING MIT-T TO 1,600psi. (see Irs log) PULLED RK-DGLV FROM ST#8 @ 8,913' MD. LRS PUMPED REMAINING 1% KCL& DISPLACED TBG W/80 BBLS OF DIESEL. (see Irs log) SET RK-P15.XJR (17/64" port, light spring, 395 bwpd) IN ST#8 @ 8,913' MD. LRS ASSITED W/DOWNHOLE OPERATIONS, PUMPED 80 BBLS OF DIESEL& 115 BBLS OF 1% KCL. 7/21/2015 ***CONT'D ON 07/22/15 WSR*** Continued from 07-20-15 WSR. Assist S-Line with WFR installation. MIT T***Passed to 1600 psi***Pumped 3 bbls neat methanol, followed by 25 bbls 1% kcl, followed by 5 bbls neat methanol down tbg to flush station#5. Pumped 1 bbl neat, followed by 10.4 bbls 1% kcl down tbg while slickline set DGLV in station#5. Pumped 1.2 bbls neat down tbg to reach test pressure. 15 min T lost 51 psi. 30 min T lost 13 psi. Total loss of 64 psi in 30 mins. S-Line pulled station#8. flushed w/ 95 bbls 1% KCL, 80 bbls diesel. Continued on 07-22-15 7/21/2015 T/I/O- 185/0/0 Assist Slickline w/WFR instalation. Pumped 28 bbls diesel down Tbg. to assist S- 7/22/2015 Line to set WFR. Continued on 07-23-15 WSR ***CONT'D FROM 07/21/15 WSR***(wso-sqz) LRS PREFORMED STEP RATE TEST ON ST#8. (see Irs log) PULLED& RESET RK-DGLV IN ST#9 @ 8,868' MD. LRS PREFORMED STEP RATE TEST ON ST#8. (see Irs log) PULLED RK-DGLV FROM ST#6 @ 9,270' MD. MADE ONE ATTEMPT TO SET RK-P15.XJR IN ST#6 @ 9,270' MD, TOOLS S/D IN ST#9 @ 8,868' MD. RAN PINNED RK-1 TO ST#9 @ 8,868' MD. (pins sheared) 7/22/2015 ***CONT'D ON 07/23/15 WSR*** Daily Report of Well Operations ORIN V-224 ***WSR continued from 7/21/2015*** Assist Slickline w/WFR instalation. Results from station#8 2nd Injectivity step rate test are as follows. 1000 psi. - 0.38 bpm at 5 min./0.37 bpm at 10 min. 1200 psi. -0.40 bpm at 5 min. /0.38 bpm at 10 min. 1400 psi. -0.41 bpm at 5 min. /0.40 bpm at 10 min. 1600 psi. -0.40 bpm at 5 min. /0.35 bpm at 10 min. 1800 psi. -0.37 bpm at 5 min./0.37 7/22/2015 bpm at 10 min. (66 bbls diesel pumped on 2 tests) Going on weather standby due to winds. ***CONT'D FROM 07/22/15 WSR***(wso-sqz) SET RK-P15.XJR (15/64" port, light spring, 300 bwpd) IN ST#6 @ 9,270' MD LRS PREFORMED STEP RATE TEST ON ST#8& ST#6 (see Irs log) PULLED 3-1/2"WHIDDON CATCHER SUB ON PX PLUG @ 9,429' MD (empty) PULLED P-PRONG FROM PX PLUG @ 9,429' MD PULLED 3-1/2" PX PLUG BODY FROM, 9,429' MD LRS PERFORM STEP RATE TEST, ON 1200psi THE RATE WAS TOO HIGH, SHUT DOWN RUN 2.50"CENT&2.25" LIB, INCONCLUSIVE, REMNANTS OF SAND SET 3-1/2"X-SELECTIVE TEST TOOL @ 9,580'SLM/9,597' MD LRS UNABLE TO GAIN HIGHER THAN 600 psi @ 2 bpm SET 3-1/2"X-SELECTIVE TEST TOOL @ 9,410'SLM/9,429' MD LRS PERFORMED 2 FAILING STEP RATE TESTS ON ZONES NB, OBA,AND OBB. 7/23/2015 ***WSR CONT'D ON 07/24/15*** Continued from 07-22-15 Assist S-Line w/WFR. S-Line set WFR instation#6. Estalished injection rate of 0.592 bpm @ 1000 psi, 0.602 bpm @ 1200 psi. 0.634 bpm @ 1400 psi, and 0.646 bpm @ 1600 psi. (58 bbls pumped) S-Line pulled plug .Attempted inj. test on stations 1,3,6 &8. At 1000 psi. 5 min. rate-0.948 bpm/ 10 min. rate-0.904 bpm. At 1200 psi. pumped 2 bpm to maintain pressure , stopped test. (40 bbls pumped ). S-Line set plug @ X nip 942'. Established injection rate of 0.636 bpm @ 1000 psi. 0.67 bpm @ 1200 psi, 0.58 bpm @ 1200 psi, and 0.58 bpm @ 1400 psi, 7/23/2015 and 0.57 bpm @ 1600 psi. Continued on 07-24-15. Continued from 07-23-15 Pumped 30 bbls of 1% kcl assisting Slickline w/test tool. Pumped 23 bbls of neat meth to Freeze Protect Tubing. Continued on 07-25-15 7/24/2015 ***WSR CONT'D FROM 07/23/15***(wso-sqz) SET 3-1/2"X-SELECTIVE TEST TOOL IN X-NIPPLE @ 9,274' SLM/9,295' MD RAN 3-1/2"OM-1, 1.70" LIB TO STA#3 AND S/D @ 9,641' SLM/9,475' MD(impression of rk- running neck) ATTEMPT TO SET 3-1/2"X-SELECTIVE TEST TOOL IN X-NIPPLE @ 9,274'SLM/9,295' MD(unable to hold pressure) RAN 3-1/2"OM-1, 1.75" LIB TO STA#2 @ 9,555'SLM/9,569' MD(open pocket) RAN POCKET POKER TO STA#2 @ 9,555' SLM/9,569' MD(full travel) MADE ONE ATTEMPT TO SET RK-SWELL DGLV IN STA#2 7/24/2015 ***WSR CONT'D ON 07/25/15*** ***WSR CONT'D FROM 07/24/15*** (wso-sqz) MADE ONE ATTEMPT TO SET STA#2 W/TG-SWELL DGLV MADE ONE ATTEMPT TO SET 3-1/2"X-CATCHER @ 9,597' MD(falls through nipple) RAN POCKET BRUSH TO STA#2 MADE ONE ATTEMPT TO SET STA#2 W/RK(oversized wobble ring 1.80")-SWELL DGLV SET STA#2 @ 9,555' SLM/9,569' MD W/RK(oversized wobble ring 1.80", modified wobble ring, modified latch body)-SWELL DGLV 7/25/2015 ***WSR CONT'D ON 07/26/15*** Continued from 07-24-15 WSR. Assist S-line set WFR. Pumped as directed by Slickline 171 bbls of 7/25/2015 1% KCL down the tubing . Freeze Protected tubing w/3 bbls neat meth and 17 bbls of diesel. Daily Report of Well Operations ORIN V-224 ***WSR CONT'D FROM 07/25/15***(wso-sqz) RAN 1.70" LIB TO STA#2 (impression of rk running neck) MADE 4 RUNS W/2.50"x 10'OF PUMP BAILER, WORKED BAILER FROM 9,605' SLM TO MADE 1 ATTEMPT W/2.60" BELL GUIDE AND 1-5/8"JDS TO FISH DGLV(no recovery) MADE 3 RUNS W/2.50"x 12'OF PUMP BAILER, 7/26/2015 ***WSR CONT'D ON 07/27/15*** Continued from 07-25-15 WSR. Assist S-Line Pumped an additional 6 bbls meth down Tbg. to 7/26/2015 finish FP. FWHP=20/0/0 Casing valves OTG, S-Line on location upon departure. ***WSR CONT'D FROM 07/26/15***(wso-sqz) MADE 2 RUNS W/ 12'x 2.50" PUMP BAILER MADE 1 ATTEMPT TO FISH VALVE W/2.60" BELL GUIDE, 1-5/8"JD (no recovery) RAN 2.25" LIB TO 9657' SLM(impression of rk-latch) RAN 12'x 2.50" PUMP BAILER W/FINGER CAGE(fished STA#2) FROM 9661' SLM 7/27/2015 ****WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS**** Fluids Summary BBLS Type 1027 DIESEL 68 METH 747 1% KCL 193 2% KCL 360 3% KCL 35 50/50 METH 249 CRYSTALSEAL 2679 Total ' ` 4) a) N N Y Y Y Y U U U U (0 N MI N 0- d 0- O- S 7 7 7 7 O L L L L Q H H H H -0 -0 -0 u_ uu_ u_ � (0 7 (6 7 (0 f0 7 7 0-0000 CL CO (/) (./) Ln Z LJJ W LJJ LJJ X 2 2 2 2 = N N N N N d M M M A M C.) CD co OD M rrn > ; N Tr �f Z 'a 0 CO s- 10 (O (O N CD N (O -Ng csi Off) r coN I) M O) O) O) O) a C.> YYYY �+Cn000U 0- 0- 0- 0- a) N Cl N N CO Z N N N N N > > > > > N 125 ppm WELLHEAD- FMC V-224 1 O ON -WELL REQUIRES RES A SSSV WHEN ON ACTUATOR= LEO MI""'WELL ANGLES 70 CI 4576''"' OKE_ELEV= 81.8' L J 1 BF. = 52.8' 20'COPDl1CT0R H 80' )I... KOP= 400' 650' H 9-5/8'TAM FORT COLLAR D=882' = - Max Angie= -71; 71'6 3049' 129.45#1,X-65, Datum PA)= 8771' 13=18-770' 1 r,H 3902' H 3 1/2'FES X HP,D=2.813' Datum ND=--—4400' SS GAS LFT MANDRELS 9-5/8'CSG,400,L-80 BTC,D=8.835" H 6468' x ST MD TVD DEV TYPE VLV LATCH PORT DATE 7'CSG,2611,L-80 TC11 XO TO L-80 BTC H 8948• PI 10 8791 4494 53 MG DMY RK 0 02/06/10 3-1/2"RPw/RA TAG 8800' 8819' 3-1/2"FES X NP,D=2.813' � I-1 1-- H 7'X 3-1/2'BKR DUAL FEEDTFRU PKR,D=2.965' — 8835' I j Minimum ID =2.75'@9687' I I� 8847' H3-12'FES XPP,13=2.813" 3-1/2" HES XN NIPPLE 111------1 ' H3-12"PDFGMULTI SUB,D=2.992- WATER NIECTlON MAPDFR3S 7'MARKERPPw/RATAG 8867' ST IND ND DEV TYPE VLV LATCH FORT GATE 9 8868 4541 53 1 -W DAY RK 0 07/23/15 8 8913 4568 53 MM3-W R15XJR FIK 15 07/23/15 7 X 3-1/2"FES DUAL FEED T1-RI/PKR 13=2-965' H 9126• ??1 �p M 7 9167 4721 53 AG-W DIN RK 0 0723/15 IGS 6 9270 4784 53 MMCrW R15XJR RK 0 07/23/15 15 9307 4806 53 MAY MG-W DRK 0 07/23/15 4 9391 4856 53 M AG-W DAY RK 0 0723/15 3-1/2'HMG MULTI SUB,13=2.992" H 9141' 3 9475 4907 53 MNG-W R15XJR RK 16 10/14/14 2 9569 4963 53 1U3-W 'DAY FE 0 0727/15 1 9622 4994 53 MMG-W R15XJR FE 10 10/14/14 •STA W2=SWELL FIX DIV T X 3-1/TI-ES DUAL FEED TFRU PKR D=2.965" H 9286' -X Z 9136' I-13-1/2"FES X NP,0=2.813' 1 ir—I 9295' H3-1/2'FES X PP,D=2.813- Ill----1 929T H3-1/2"NDF G MULTI SIE,D=2.992' 7-X 3-12-FES DUAL F®TFRU PK R,D=2.965" H 9420' -Zai e_i 942W H3-1/2'FES XNit D=2.813' PERFORATION SUMMARY 9435' H3-1/2'NDPG MULTI SUB,13=2.992 Fill LOG:SVS USFT ON 12/14/099�9• —I FIST t 2 EA KICK SPRINGS(3"X 5/8")FROM IVO EAT TOPPE3F:53' 8880' LI TOOL LOST DH NEAR VN ON STA#2(01/30/14) Nola:Refer to P►oduc on DB for historical pert data SIZE SPF ZONE NTE VAL Opn/Sqz SHOT SCRpI 9688" H7'X 3-1/2"FES DUAL FEEDTHIa.I PKR 13=2.965' 4-1/? 5 fib 8880-8912 0 12/13/00 dl 4-12' 5 013a 9224-9274 0 12/13/09 I rI 9507' —13-1/7 FES X PP,D=2.813" 4-1/2' 5 OBb 9296-9326 0 12/13/00 9602' H3-112' 4-1/2' 5 aid 9486-9568 0 12/13/00 MPG SINGLE SUB,D=2.992' 4-1/2' 5 OBe 9806-9648 0 12/13/09 Pi-- — 9640' H3-12'FES X PP,D=2.813' 1HI 9687' H 3-1/2"HES XN PP,D=2.750' ..J 9667' H31/2"MARX PLUG(10/11/14) 3-1/2'TBG,92N,L-80 TCU,.0087 bpf,D=2.992" f- 9710' •--------1 9710' H3-117 VVLEG,13=2.992' FWD — 965T MM...♦ 7'CSG,26N,L-80 BTC,.0383 bpf,D=6.276" H 9944' ,A14•�•�•�•�•�•�+4o+•t HELM)NOT LOGGED GATE REV BY COM AENTS DATE REV BY COMMENTS ORION UNIT 12/17/09 NIE?S ORIGINAL COMPLETION 10/14/14 GJB/PJC WFRCIO WELL: V-224 03/30/10 TVWPJC FINAL DRLG CORRECTIONS 0123/15 STT/JMD WFR GO(01/21/15) PERMIT No:t081540 01/27/14 JMA'JMD VVF R GO(01/21/14) 08/13/15 C.NIJIND_WFR GO(07/23-27/15) API No: 50-029-23400-00 02/03/14 DIS/JM)WFR GO&FISH(01/30/14) SEC 11,T11N,R11E,550'Ft&&1473'FEL 02/03/14 JM) SCHEMATIC CORRECTIONS 10/11/14 GJB/PJC SET FIFO(PLUGRP Btploratlon(Alaska) tiOF ? -. - w\ � ��� 7,-' THE STATE Alaska Oil and Gas �,,,; � OfTAsKAConservation Commission 333 West Seventh Avenue , 1 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279.1433 OFALASj" Fax. 907.276 7542 L.v. www.aogcc alaska gov Brenden Swensen L Well Interventions Engineer (�, BP Exploration(Alaska), Inc. b - 7 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool, ORIN V-224 Sundry Number: 315-327 Dear Mr. Swensen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1)))-{Ai Cathy P Foerster Chair DATED this Aay of June, 2015 Encl. RECEIVED • STATE OF ALASKA MAY 2 7 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS /9 ---i- /s��� OGCC 20 AAC 25.280 / 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing El Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well El Re-enter Susp Well ❑ Other MBE Treatment • 0 2.Operator Name: 4.Current Well Class. 5 Permit to Drill Number: BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 208-154-0 • 3.Address: Stratigraphic ❑ Service 0 - 6.API Number: P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23400-00-00 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? ORIN V-224 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028240 ' PRUDHOE BAY, SCHRADER BLUF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft)• Plugs(measured): Junk(measured): 9960 , 5199 • 9691 5036 9691 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"Conductor 30-110 30-110 Surface 5439 9-5/8"40#L-80 32.69-5471.31 32.69-3064.87 5750 3090 Intermediate 9918 7"26#L-80 30.05-9947.74 30.05-5191.78 7240 5410 Production None None None None None None Liner None None ' None None None None Perforation Depth MD(ft). Perforation Depth TVD(ft)• Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 3-1/2"9.2#L-80 L-80 27.98-9713.66 Packers and SSSV Type. See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths 3-1/2"X Nipple 3906.25',2509.1' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work. Detailed Operations Program 7 BOP Sketch n Exploratory n Stratigraphic n Development n Service n 14.Estimated Date for 15 Well Status after proposed work. Commencing Operations: (t/ISI 2-01S OIL ❑ WINJ 0 , WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date. GAS ❑ WAG 0GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brenden Swensen Email Brenden Swensen.@BP Com Printed Name Brenden Swensen Title Well Intervetions Engineer Signatur / Phone Date Prepared by Nita Summerhays 564-4035 • 564-4887 5/27/2015 COMMISSION USE ONLY Conditions of approval Notify Commission so that a representative may witness Sundry Number Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes [11 No [i Subsequent Form Required: /G.- 1r G 4 / APPROVED BY / _ _ Approved by' .e. ,� _ COMMISSIONER THE COMMISSION Date' (o S l S Q RI (; JUN 112015 s _ z . , Form 10-403 Revised 5/2015 ' AU!, ii/�TIti valid for 12 months from the date RBDM of approval. Submit Formoe'hd Attachments in Du !mateVTL 6.`5//8- A ��8'/J`-' Perforation Attachment ADL0028240 Well Date Perf Code MD Top MD Base TVD Top TVD Base V-224 11/17/12 BPP 8880 8912 4548 4567 V-224 11/17/12 BPP 9224 9274 4756 4786 V-224 11/17/12 BPP 9296 9326 4799 4817 V-224 11/17/12 BPP 9486 9568 4913 4962 V-224 11/22/12 BPS 9606 9648 4985 5010 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF - 0 0 0 co OD CO CO J J J a) Q cp O co � rn � • ' OM O 0 V 0 c) cp N N- O r--- a)a) CO v7 m Oa 6N) CO V � O O Ln co U) Q O ~ O O co co 0 co M M N ct3Q E a) E CV w000 �- v �/� N m r c3) N w Q 0 = O) Ln O Q C J •- Q 0 I— co co M oo U 0 M co CO N OO O o a0 co o a0 J J a) -0 J 4* * N C14. O N 0 Cp � O) N N O M L CO O CO CO O N— M CO CaD O) V CO a) O O W H Q Cr) D W W O 0 Q z 0 Z U) F- Packers and SSV's Attachment ADL0028240 Well Facility Type MD Top Description TVD Top V-224 SSSV 3906 3-1/2" X Nipple 2509 V-224 PACKER 9130 3-1/2" HES Dual Feed Thru Packer 4699 V-224 PACKER 9290 3-1/2" HES Dual Feed Thru Packer 4796 V-224 PACKER 9424 3-1/2" HES Dual Feed Thru Packer 4876 V-224 PACKER 9591 3-1/2" HES Dual Feed Thru Packer 4976 bp To: AOGCC Date: May 20, 2015 From: Brenden Swensen, Orion PE 907-564-4887 Subject: V-224 MBE Treatment Step Unit Operation 1 S Set plug, dummy station 8, open stations 4, 5, 6, 7 2 FB Pre-treatment injectivity test 3 FB Bullhead polymer 4 FB Post treatment injectivity test 5 S Set new WFRV design, pull plug HISTORY V-224 is a Schrader Bluff WAG injector configured to inject into multiple zones through water flood regulator valves (WFRV's). The well was swapped from water to MI in mid-October of 2014. While on MI, it was determined that the well has a matrix bypass event (MBE) to V-207 in the OBa/OBb zones based on an instant MI response in V-207 and the down hole pressure gauges in V-224. The two zones were dummied and the MI response subsequently dissipated, also confirming the well and associated zones were the culprits for the immediate gas breakthrough. OBJECTIVE The objective of this job is to remediate the MBE from V-224 to V-207 by pumping water swelling granular cross linked synthetic polymer gel into the matrix breakthrough. CRITICAL ISSUES • Shut in offset producers and injectors to allow reservoir conditions to stabilize • High pre-treatment injectivity to minimize transit time of polymer through tubing to formation • Ensure cleanliness of pump equipment and hard line (pre and post job) • Properly dispose of remnant fluid per guidance from the Environmental Team PROCEDURE 1. Set plug at 9429' to isolate the OBd and OBe zones. 2. Pull live valve from station #8 and set dummy to isolate Nb zone. 3. Pull live valves and dummies from stations 4, 5, 6, and 7 to open the OBa/OBb. 4. Perform pre-treatment injectivity test. 5. Shut in offset producers and injectors prior to pumping treatment. 6. Bullhead polymer from surface down tubing into OBa/OBb. 7. Perform post-treatment injectivity test. 8. Set dummies and new water flood regulator valve design in stations 4-8. 9. Pull plug at 9429'. 10. Return well to injection ATTACHMENTS A. V-224 Well Bore Schematic Attachment A: V-224 Wellbore Schematic TREE= CM SAFETY WELLHEAD= FMC V-224 WHBI ON NOTES:WELL REQUIRES A SSSV WHEN ON ACTUATOR= LEO MI'"'WELL ANGLE>10e4576'- OKB ELEV= 81.8' l J KOREV 52.8' P= 400 --1- 8 20"CONDUCTOR -- 0' 1)- 650• -19-5/8"TAM PORT COLLAR,D=8.82" I KO Max Angie= 71'©3049' 129.454.X-65. Datum MD= 8771' D=18-770' , 3902 1-3-1/7 FES X MF,D=2.8171 Datum ND= 4400' SS GAS LFT MANDRELS I9-5/8"CSG,40#,L-80 BTC,D-8.835" H 5468' x1.431.43TV STI O DEV TY PE VII/ LATCH PORT DATE 17"CSG 26#,L-80 TC11 XO TO L-80 BTC F- 694$' I ^ 10 8791 4494 53 MNG OMY RK 0 02/06/10 13-12"PUP w1RA TAGH 6800' I u 11- 881W 1-3-1/2"HES XMP.D=2.813" T X 3-1/2"BKR DUAL FEED THRU PKR,D=2.965" H 8836' I Minimum D=2.75'@ 9687' 1 1 8847' -3-1/2"FES X F.D=2.613• 3-112"HES XN NIPPLE II-18863' H3-1/2"NDPG MULTI SLB,D=2.997 I Ill WATER NB T1a4 MANS r MARKER RP w/RA TAG -1 8867' r)11° El sr! IA) TV O DEV TY PE j V LV LATCH PORT DATE 9 8868 4541 53 M13-W1 DAN RK 0 12/16/09 3 8913 4568 53 1.4143-W1 P-15XlrR RK 15 10/14/14 Jr X 3-1 r2•HES DUAL FEED T1-RU PKR,D=2.965" H 9126' B 7 9167 4721 53 MNL-W* MYFE 0 12/16109 6,9270 4784 53 ANG-W DRAY FE 0 01/21/15 I 5 9307 4806 53 G-W CAW IRK 0 12/16/09 419391 4856 53 EMG-WI DIN FE 0 01/21115 3-1/2"ADM MULTI SLB,D=2.992" - 9141' I MN3 J 9475 4907 53 ANG-W P-15XJ2 RK 16 10/14/14 2 9569 4963 53 MNG-W "OW FE 0 01/30)14 © 1 9622 4994 53 1111.1G-W P-15XJR RK 10 10/14/14 STA#2=SWLL FIX MAY r X 3-I/"PIS DUAL F®THRU PKft,I)=2.965' 92116' "a p 9136' 1-13-112"FEB X NP,I) 2.613"I ' ' [ 9296' I-I3112"FES X NIP,D-2.813" • [ 9297' -3-1/7 AUG MULTI SLB,ID-2.992' 1r X 3-1/2"FES DUAL F)1)-RU FKR,D=2.985- 9420• i { 9429' I-3.117'HES X M,D=2.813" R$Y-0RATION SUMMARY ■ [ 9435' H3_lir 147G MULTI SLB,D=2.992' I REF LOG:SWS USRT ON 12/14/09 ANGLE AT TOP FERE 53°®8880' -1r RSFt 2 EA KICK ShR'NGS(3"X 5/8")FROM K/O TOOL LOST DFM NEAR WI ON STA#72(01/30/14) Note:Refer to Production DE for historical pert data SIZE SPP ZONE INTERNAL COn/Sgc SHOT SOZ I 9688• I-17"X 3-1/2"I$DUAL FTS TFRU FKR D-2.965" 4-1/2" 5 Nb 8880-8912 0 12/13109 S X 1 4-1/2" 5 OF3a 9224-9274 0 12/13/09 I I [ 9597' -I31/2"FES X NP,D=2.813' 4-1/2" 5 OBb 9296-9326 0 12/13/09 SUB,r [ 9602' I- 4-1/2" 5 OBd 9486-9568 0 12/13/09 �13112' SINGLE D=2.992" 4-1/7 5 OBe 9606-9648 0 12!13/09 tea. ' 3 t "FPS x ra.,D=7 813'1 I IBr-ILJ-I 968T H 3-1/2"FES XN NP,D=2.750" I `J 9687" I-3-12"RMK PLUG(10/11/14) /3-1/7 TBG,9.2#,L-80 TC1, 0087. bpi,D=2.992' - 9710' , -------I 9710' I-3-1/2'VVLEG,D=2.997' 9867' 44� .A.++4`6+4, / -E_MD NOT LOGGED 7"CSG,264,L-80 BTC,.038340,1D=6.276276'" - 9944' •',,Aa DATE REV BY I C0IN.1ENRS DATE REV BY COMNEMTS ORM UHT 12/17/09 IME5 IORIGIN4L COMPLETION 10/14/14 r,,B/PK_'VVFRCJO WELL V-224 03/30/10 TW/PJC FTWL DRG CORRECTIONS 0123/15 STF/JND WM C/O(01/21/15) 1 FERMT Pb:'1081540 01/27/14 JMTMJIYD WFR C/O(01/21/14) API Pb: 50-029-23400-00 02/03/14 DJS/JM)111/FR CIO&FISH(01/30/14) SEC 11.T11N,R11E 550'FN.81473'FEL. 02/03114 JED 'SCHEMATIC COF)-ECD NJS . 10/11(14 GIB/PJC SET RAA(RUG BP Exploration(Alaska) • Ima a Pro'ect Well History File Cove~age 9 J XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - ~ `rj ~. Well History File Identifier Two-sided III II'IIIIIIII IIIII ^ Rescan Needed III II~I'IIIII IIIIII Organizing (done) ^ RE AN Color Items: ^ Greyscale Items: DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ O ~s~ Pro-ect Proofin J g III 111111 IIIII II III BY: Maria Date: 0 ~s~ x 30 = ~d + =TOTAL PAGES ~" Scanning Preparation (Count does not include cover sheet) BY: Maria / Date: ~~ ~s~ Production Scanning """"""" "" Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: ~ /D ~s~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s~ Scannin is com lete at this point unless rescanning is required. II I II'I II I II II I I II. 9 P ReScanned BY: Maria Comments about this file: Date: f~'~ Quality Checked IIIIIIIIIIIIII 10!6/2005 Well History File Cover Page.doc MEMORANDUM ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 10, 2010 To: Jim Regg ~ ~ Z~~l~ P.I. Supervisor ~~~ ~ SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-224 FROM: BOU NOble PRUDHOE BAY UN ORIN V-224 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv.,~~'~--- Comm Well Name: PRUDHOE BAY UN ORIN V-224 API Well Number: 50-029-23400-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100607104415 Permit Number: 208-154-0 Inspection Date: 6/3/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well { V-224 P Inj W TVD ~_ ~ ~ -- ' 0 4521 / jA I 7240 1 ' ~ 24s0 2430 2 OS P.T.D 2os7sao fTypeTest i PS T ~ Test psi ~ --- ~ Op X20 zsoo ' ~-- s6o soo 790 Interval ~IT'~- '' p/F P Tubing ~ 7aoo_~ 7400 739o Isso i Notes: ~e r~, f ~~ -~'s~-- ~~5w~ ~ ~~i ' ~ 4 f?e ^~ #~ F ,r ' Zvi ~.,. . - ~. rl ~' ~ ," Thursday, June 10, 2010 Page 1 of 1 L J • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.pwdgoQ. ka. ov OPERATOR: BP Exploration (Alaska), Inc. ~~~~ ~(?~tu FIELD /UNIT /PAD: Prudhoe Bay /PBU / V-pad DATE: 05/21 /10 OPERATOR REP: Torin Roschinger AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well V-224 T pe In'. N i TVD 14,521' Tubin 0 0 0 0 Interval 0 P.T.D. 2081540 T pe test P Test psi .11500 Casing 2,900 X3,000 ' 3,000 ° 3,000 P/F P Notes: MIT-IA to 3000 psi to eval TxIA comm OA 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. T pe test Test psi Casin P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. T pe test Test psi Casin P/F Notes: OA Well T pe In'. TVD Tubing Interval P.T.D. Ty a test Test psi Casin P/F Notes: OA Well Type In'. TVD Tubin Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey 0 =Differential Temperature Test ~~- ~~~,ti~a.c 14~.C, INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) ~~` . MIT Report Form BFL 11/27/07 MIT PBU V-224 OS-21-10.x1s OPERABLE: Injector V-224 (PTD#2081540) Passed an AOGCC witnessed MITIA confi... Page 1 of 2 IV~aunder, Thomas E (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Saturday, June 05, 2010 8:11 PM To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); AK, OPS GC2 OSM; AK, D8~C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, RES GPB West Production Optimization Engineer; AK, RES GPB East Production Optimization Engineer; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, OPS Well Pad LV; Orlando, Margaret Cc: AK, D&C Well Integr7ty Coordinator; Holt, Ryan P (ASRC); Winslow, Jack L {ASRC); Wellman, Taylor T; Janowski, Carrie Subject: OPERABLE: Injector V-224 (PTD#2081540) Passed an AOGCC witnessed MITIA confirming Tubing Integrity Attachments: Injector V-224 (PTD #2081540) TIO 8~ Injection Plot.doc; MIT PBU V-123 V-224 06-03-10.x1s All, Injector V-224 (PTD # 2081540) passed a state witnessed MITIA to 2500 psi on 6103/2010. The passing test confirms that the well has tubing integrity. The well has been reclassified as Operable and may remain on injection as Operations sees fit. Included below are the current TIO and Injection plots and a copy of the MIT-IA form. «Injector V-224 (PTD #2081540) TIO 8~ Injection Plot.doc» «MIT PBU V-123 V-224 06-03-10.x1s» Please contact us if there are questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 From: AK, D&C Well Integrity Coordinator Sent: Tuesday, May 25, 2010 4:59 AM rs~y ~C .w`W+Y To: 'Regg, James B (DOA)'; "Schwartz, Guy (DOA'; 'Maunder, Thomas E (DOA)'; 'Brooks, Phoebe L (DOA)'; AK, OPS GC2 OSM; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, RES GPB West Production Optimization Engineer; AK, RES GPB East Production Optimization Engineer; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, OP5 Well Pad LV; Orlando, Margaret Cc: AK, D&C Well Integrity Coordinator; Clingingsmith, Mike J (CH2M Hill) Subject: UNDER EVALUATION: Injector V-224 (PTD#2081540) Place on injection for an AOGCC MITIA All, Injector V-224 (PTD #2081540) failed an MITIA on 05/08110 after the well was placed on injection. On 05/21/10, DHD performed an MITIA with the well shut-in to establish a liquid leak rate, however, the well passed an MITIA when no pressure loss was seen during the 30 minute test. The well has been reclassified as Under Evaluation 6/7/2010 OPERABLE: Injector V-224 (PTD#2081540) Passed an AOGCC witnessed MITIA confi... Page 2 of 2 so that it may be placed on injection for an AOGCC MITIA. If the MITIA fails, the plan forward is as follows: With the well injecting 1. DHD: Establish LLR 2. E-line: Run LDL The MIT form and wellbore schematic have been included for reference. Please notify Wetl Integrity when the well has been POI so that the state witnessed MITIA can be scheduled. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907} 659-5100 Ext. 1154 6/7/2010 • • STATE OF ALASKA ALASI~b4 OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg~alaska.gov; phoebe.brooks@alaska.gov; tom.maurtder@alaska.gov; doa.aogcc.prudhce.bay~alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP F~cploration (Alaska), Inc. Prudhoe Bay /PBU / V pad 06/03/10 Jerry Murphy Bob Noble Packer Pretest Initial 15 Min. 30 Min. Well V-123 T In". W TVD 6,348' Tu ' 1,560 1,560 1,540 1,540 Interval I P.T.D. 2091410 T test P Test ~ 1587 1,040 1,800 1,800 1,800 P/F P Notes: MIT-IA to 1800 psi post initial injectice OA 520 520 530 530 Well V-224 T In'. W TVD 4,521' Tu ' 1,400 1,400 1,390 1,380 Interval I P.T.D. 2081540 T test P Test 1500 1,240 2,500 2,450 2,430 P/F P Notes: MIT-IA to 2500 psi post initial injecron OA 720 860 800 790 Well T In'. TVD T Interval P.T.D. T test Test ~ P/F Notes: OA Well T In'. TVD Tu ~ Interval P.T.D. T test Test P/F Notes: OA Well T In . TVD T Interval P.T.D. T test Test P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Intemal Radioactive Tracer Survey A =Temperature Anomaly Survey D = t3ilrerential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11!27/07 MIT PBU V-123 V-224 06-03-10 (2}.xls Injector V-224 (PTD #2081540) TIO Plot Well V-22~ 4,000 3,000 ~, 2,OD0 _. 1.000 f i...+~'M 03!06/10 03!13!10 03/20/10 03/27/10 04/03/10 04/10/10 04/17/10 Od724/10 05/01/10 05/08710 05!15!10 05/22/10 05/29/10 06/05/10 Injector V-224 (PTD #2081540) Injection Plot Wefl: V-22~ -~ T6g -~- IA -~- OA OOA OOOA On 1.2i r_, 1,5Di 1 iii` ~ _ WHIP ' MI ~ - -- GI -Other D'iil~'l U G3.%~?:'Iii Od;10:'10 Ddi Ld; l li ~- OF~!uE'~;' i LI - -' --'lit ',ar.%(_15110 u P2-23 (PTD# 1940320), 04-10 (PTD# 1760420), 09-25 (PTD# 1840280), GC-lE (PTD# ... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Monday, May 31, 2010 4:43 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Cc: AK, D&C Well Integrity Coordinator Subject: P2-23 (PTD# 1940320), 04-10 (PTD# 1760420), 09-25 (PTD# 1840280), GC-1 E (PTD# 1890680), H-03 (PTD# 1710190), L-214A (PTD# 2060270), NGI-08 (PTD# 1760520), V-224 (PTD# 2081540), V-227 (PTD# 2091160), WGI-04 (PTD# 1790500) Attachments: May 2010 MIT Forms 05-31-10.zip Jim, Tom, and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: P2-23 (PTD# 1940320) 04-10 (PTD# 1760420} 09-25 (PTD# 1840280) GC-1 E (PTD# 1890680) H-03 (PTD# 1710190) L-214A (PTD# 2060270) NGI-08 (PTD# 1760520) V-224 (P D# 2081540 V-227 (PTD# 2091.160) WGI-04 (PTD# 1790500) g ~ s/? \ M ~~ ~C~~'S ~ ~'(~Civ~ L~ 'l `~ ~rr~b E~ -ice J„~\1 ~.~ «May 2010 MIT Forms 05-31-10.zip» Thank you, Toxin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 ~~ ~~~~ 6/7/2010 UNDER EVALUATION: Injector V-224 (PTD#2081540) Place on injection for an AOG... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Tuesday, May 25, 2010 4:59 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); AK, OPS GC2 OSM; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, RES GPB West Production Optimization Engineer; AK, RES GPB East Production Optimization Engineer; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, OPS Well Pad LV; Orlando, Margaret Cc: AK, D8~C Well Integrity Coordinator; Clingingsmith, Mike J (CH2M Hill) Subject: UNDER EVALUATION: Injector V-224 (PTD#2081540) Place on injection for an AOGCC MITIA Attachments: MIT PBU V-224 05-21-10.x1s; V-224.pdf All, Injector V-224 (PTD #2081540) failed an MITIA on 05/08!10 after the well was placed on injection. On 05/21/10, DHD performed an MITIA with the well shut-in to establish a liquid leak rate, however, the well passed an MITIA when no pressure loss was seen during the 30 minute test. The well has been reclassified as Under Evaluation so that it may be placed on injection for an AOGCC MITIA. If the MITIA fails, the plan forward is as follows: With the well injecting 1. DHD: Establish LLR 2. E-line: Run LDL The MIT form and wellbore schematic have been included for reference. «MIT PBU V-224 05-21-10.x1s» «V-224.pdf» Please notify Well Integrity when the well has been POI so that the state witnessed MITIA can be scheduled. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell {406) 570-9630 Pager (907) 659-5100 Ext. 1154 ~~~C~ 6/712010 ~ CJ Email to:jim.regg~alaska.gov; phcebe.brooks~alaska.gov; tom.maunder~alaska.gov; doa.aogcc.prudhce.bay~alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay /PBU ! V-pad DATE: 05/21 /10 OPERATOR REP: Torin Roschinger AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Packer D h Pretest Initial 15 Min. 30 Min. Well V-224 T In . N TVD 4,521' Tubi 0 0 0 0 Interval O P.T.D. 2081540 T test P Test ~ 1500 Ca " 2,900 3,000 3,000 3,000 P/F P Notes: MIT-IA to 3000 psi to eval TxIA Comm OA 0 0 0 0 Well T Iri. TVD Tubin Interval P.T.D. T test Test Casi P/F Notes: OA Well T In". TVD Tu ' Interval P.T.D. T test Test P/F Notes: OA Well T In . TVD T Interval P.T.D. T test Test i Casi PIF Notes: OA Well T In'. TVD Tu " Interval P.T.D. T test Test Casi P/F Nates: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radaarbve Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other {describe in notes) MIT Report Form BFL 11!27(07 MIT PBU V-224 OS-21-10.x1s NQT OPERABLE: Injector V-224 (PTD#2081540) Failed MIT-IA Page 1 of 1 • Maunder, Thomas E (DOA) From: AK, D8~C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Saturday, May 08, 2010 9:55 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); AK, OPS GC2 OSM; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, RES GPB West Production Optimization Engineer; AK, RES GPB East Production Optimization Engineer; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; Daniel, Ryan; AK, OPS Well Pad LV; Orlando, Margaret; AK, D8~C Well Integrity Coordinator Cc: Janowski, Carrie; Quy, Tiffany; Holt, Ryan P (ASRC); Winslow, Jack L (ASRC) Subject: NOT OPERABLE: Injector V-224 (PTD#2081540) Failed MIT-IA Attachments: V-224.pdf; V-224 TIO Plot.doc; V-224 Injection Plot.doc All, Injector V-224 (PTD #2081540) failed an AOGCC witnessed MIT-IA on 5/08/10. The well no longer meets AOGCC requirements to remain on injection and has been reclassified as Not Operable. The well should be shut-in as soon as it can be freeze protected. The plan forward is as follows: 1. Slickline: Set a downhole plug in tubing 2. E-Line: Perform a Leak Detect Log A wellbore schematic, TIO plot and injection plot are included for your reference. «V-224.pdf» «V-224 TIO Plot.doc» «V-224 Injection Plot.doc» Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 ~~~ ~`~ ~.~ 6/7/2010 n U Email to:jim.regg~alaska.gov; phcebe.brooks@alaska.gov; tom.maunder@alaska.gov; dce.aogcc.prudhce.bay~alaska.gov OPERATOR: BP F~cploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay! PBU / V-pad DATE: 05/08/10 OPERATOR REP: Jerry Murphy AOGCC REP: Chuck Scheve STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test n U Packer D Pretest Inifral 15 Min. 30 Min. Well V-224 T In . W TVD 4,521' Tubs 840 730 870 770 Interval I P.T.D. 2081540 T test P Test 1500 Ca " 980 2,500 2,400 2,350 P/F F Notes: MIT-IA to 2500 psi Post-initial injection OA 500 650 610 580 Pressured IA w/ 1.9 bibs MEOH 45 min 60 min 75 min Well T In". TVt3 Tubi 600 360 400 Interval P.T.D. T test Test Casi 2,300 2,240 2,190 P/F Notes: OA 550 500 480 Well T In". TVD T Interval P.T.D. T test Test P/F Notes: OA Well T In . TVD T Interval P.T.D. T test Test C P/F Notes: OA Well T In". TVD Tu " IMerwal P.T.D. T test Test Casi P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Intemal Radioactive Tracer Survey A =Temperature Anomaly Survey D = DilFererrtial Temperature Test INTERVAL Codes I = Inikal Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11 /27/07 MIT PBU V-224 05-08-10.x1s Injector V-224 (PTD #208154~1/O Plot annGl i nr~p { i 2 rs0 1 (V1[ • W~ V-714 a-- Tbg W OOA OOOA On i2/i',.n0 0J20/10 02/27710 0'/0170 03!13?10 03?2U?10 irim?70 OA.Yfj~iYO 01J1Qn0 Mit??10 09?2aJ10 u5.%01110 OSrLKi71 r~ Injector V-224 (PTD #2081540) Injection Plot Wd V-na ~m ,G ,~~ „G~, ~G ?i`4 &0R c 700 600 5[~p 400 300 i07 1 ti9 oan?no OAr_~~1a cs;nl:ut ~~a~ ~.no -WHIP SW . _.__... py/ MI - GI pMn On 100 { i o~iano m1?eno o"uz7no asmF.no n?+isno o~~zeno 03.E?7no tuJOanG asnono Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, May 17, 2010 11:49 AM To: Saltmarsh, Arthur C (DOA) Subject: PBU V-224 / PTD # 208-154 H i Art, Please reference the following well: Well Name: PBU V-224 Permit #: 208-154 API #: 50-029-23400-00-00 Top Perf MD: 8884' Bottom Perf MD: 9652' This well began Injection on Method of Operations is: April 19, 2010 Date of Test: No Test Data for Injection Wells S ~~ ~ ~ f)7~~I+ .~. _ .. ._.... _ t ~ - 5/17/2010 • MEMORANDUM TO: Jim Regg`j'CQj~ty P.I. Supervisor ~~~~{ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 12, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC V-224 PRUDHOE BAY UN ORIN V-224 Src: Inspector NON-CONFIDENTIAL • Reviewed By~:j~ P.I. Suprv ~•J,t~- Comm Well Name: PRUDHOE BAY UN ORIN V-224 API Well Number: so-o29-23400-00-0o Inspector Name: chuck Scheve Insp Num: mitCS100509080424 Permit Number: 208-154-o Inspection Date: sisi2olo Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well v-z2a Type Inj. W TVD 4521 IA 980 2500 2400 2360 2300 2240 P.T.D 2081540 TypeTest SPT Test psi 1500 ~ QA 500 650 610 580 550 500 IntervalINITAL '~ p/F F `~ Tubing 840 730 870 770 600 360 Notes: Test extended another 15 min, tubing =400 IA=2190 OA=480. }}~~qq )) }} F Wednesday, May 12, 2010 Page 1 of 1 DATA SUBMITTAL COMPLIANCE REPORT 3/3/2010 Permit to Drill 2081540 Well Name/No. PRUDHOE BAY UN POL V-224 Operator BP EXPLORATION (ALASKIy INC API No. 50-029-23400-00-00 MD 9960 TVD 5199 Completion Date 12/17/2009 Complet ion Status WAGIN Current Status WAGIN UIC Y ~ __ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATAINFORMATgN Types Electric or Other Logs Run: GR, GR / RES / NEU / AZI DENS; PWD, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty = Med/Frmt Number Name Scale Media No Start Stop CH Received Comments og Sonic , 5 Col 30 9725 Case 1/13/2010 USIT, GR, CCL , j~D'" C Pds 19191~nic 30 9725 Case 1/13/2010 USIT, GR, CCL ~' C Lis 19237 "sonic 18 9707 Case 1/26/2010 LIS Veri, USIT, CCL ~1T C Lis 19385 G mma Ray 297 2458 Open 2/24/2010 PB 1 LIS Veri, GR, ROP i ~ Gamma Ray 25 Blu 293 2392 u/Pb ~w i~ 2/24/2010 PB 1 MD GR , Gamma Ray og 25 Blu 293 2392 Open 2/24/2010 PB 1 TVD GR ~~ D C Lis 19401~fnduction/Resistivity 297 9958 Open 2/24/2010 LIS Veri, GR, ROP, FET, ~ RPM, RAM, NPHI I IJcbg Induction/Resistivity 25 Blu 293 9920 Open 2/24/2010 MD Vision Service ,f ~g~ Induction/Resistivity I--- - - -- - 25 ---- Blu --- 293 9920 Open 2/24/2010 TVD Vision service --- Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number .Comments DATA SUBMITTAL COMPLIANCE REPORT 3/312010 Permit to Drill 2081540 Well Name/No. PRUDHOE BAY UN POL V-224 Operator BP EXPLORATION (ALASKA INC API No. 50-029-23400-00-00 MD 9960 TVD 5199 Completion Date 12/17/2009 Completion Status WAGIN Current Status WAGIN UIC Y ADDITIONAL INFORMATION Well Cored? Y~ Daily History Received? ~/ N Chips Received? -~Cl l~_ Formation Tops ~~ N Analysis ~`tN`~ Received? Comments: -_ __ __ Compliance Reviewed By: ____ __ _ -___ -~~- Date: _ - -~ i 02Itfl/10 Schtumberger Alaska Data & Consulting Services 2525 Gambell Street, Sutte 400 Anchorage, AK 99503.2838 ATTN: Beth Well Job B N0.5473 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 MPC-22A F-21 BAUD-00007 AYKP-00073 MEM PROD PROFILE W/GLS - PROD PROFILE - 2/11/10 02/16/10 1 1 1 1 13-17 P2-46 AYKP-00072 AVYO-00057 INJECTION PROFILE PROD PROFILE 02/14/10 02/11/10 1 1 1 1 16-01 MPC-24A BBSK-00006 BAUJA0005 USIT - MCNL ` - 02/11/10 01/09/10 i 1 1 1 V-224PB7 09AKA0147 OH MWD/LWD EDIT 11/26/09 2 1 YLCAJC AI:RIVVYYLtUIaC MCI.CIYI of JllarvlrvV NrvV nci VnnnvV vrvc a.vr• cn~.n ,v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, SuOe 400 Anchorage, AK 99503-2939 ~ ~-) .. '.~ ,. 02!12/10 Scbb~berger Alaska Data 6 Consulting Services 2525 Gembell Street, Suite 400 Anchorage, AK 99503.2839 ATTN: Beth Well Job # N0.5468 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 13-35 BBKA-00005 CROSS FLOW CHECK 02/07/10 1 1 A-02 AWJI.00072 MEMORY PROD PROFILE - 01/31/10 1 1 M-08 AYTO-00035 CROSS FLOW CHECK 02/07/10 1 1 V-123 AWJN-00033 SCMi 01/15/10 1 1 4-38/K-34 AWJFOOD70 MEMORY PROD PROFILE 02102/10 1 1 Y-36 F-40 01-14A AYKP-00061 AZCM-00053 AWJI-00067 RST RST MCNL 01/14/10 12/29/09 01/07/10 1 1 1 1 1 1 P1-24L1-01 12034915 OH LDWG EDIT (FLEX - 08/12/08 1 1 V-224 09AKA0147 OH MWD/LWD EDIT 12/08/08 2 1 cNAC N\rn1xV Y1ILCUVC RCl.C1Y 1 Oi JlVnllnl{~ gn1U MC 1 VNIYII'1t! VryC liVYt Cgl:rl 1 V: BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services Petrotechnical Data Center LR2-1 2525 Gambell SVeet, SuAe 400 900 E. BenSOn Blvd. Anchorage, AK 99503-2838 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ 1(~i1 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ^ Oil ^ Gas ^ SPLUG ^ Other ^ Abandoned ^ Suspended zoAACZS.~os zoAACZS.iio ^ GINJ ^ WINJ ®WAG ^ WDSPL ^ Other No. of Completions One 1b. Viki»°itiliass: - .' ` '~""''' ^ Developmefit (.~1~loratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. ate ., Susp., or Aband.: 12/17/2009 12. Permit to Drill Number: 208-154 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 11/26/2009 13. API Number: 50-029-23400-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached: 12/8/2009 14. Well Name and Number: ~PSX PBU V-224 FSL, 1474 FEL, SEC. 11, T11 N, R11 E, UM 4730 Top of Productive Horizon: 2280' FSL, 4460' FWL, SEC. 01, T11 N, R11 E, UM g. KB (ft above MSL): 81.8 GL (ft above MSL): 53.3' 15. Field /Pool(s): Prudhoe Bay Field / Orion Total Depth: 3134' FSL, 4525' FWL, SEC. 01, T11N, R11E, UM 9. Plug Back Depth (MD+TVD): 9857' 5136' Schrader Bluff 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 590829 y- 5969980 Zone- ASP4 10. Total Depth (MD+TVD): 9960' 5199' 16. Property Designation: ADL 028240 TPI: x- 596725 y- 5972884 Zone- ASP4 Total Depth: x- 596778 Y- 5973739 Zone- ASP4 11. SSSV Depth (MD+TVD): None 17. Land Use Permit: TVD f P f t 18. Directional Survey: ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore: N/A ft MSL ): erma ros ( 20. Thickness o 1755' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR, GR / RES / NEU / AZI DENS ; PWD, USIT 22. Re-Drill/Lateral Top Window MD/TVD: N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM .SIZE CEMENTING RECORD PULLED. 91.5# A-53 Surf ce 10 ' S rface 10 ' 42" 260 x Ar is S t A rox. -/" L- 2' 1 -1/4" 4 x Ar i i 4 x 7" 26# L-80 2 ' 9 26' 189' -3/4" 15 sx Lie re sx Clas 'G' 24. Open to production or injection? ®Yes ^ No 25. TUBING RECORD ae P If Yes, list each interval open Perforation Size and Number): (MD+TVD of To Bottom i; SIZE DEPTH SET MD KER .SET MD / TVD ; p < 4-1/2" Gun Diameter 5 spf 3-1/2", 9.2#, L-80 9710' 8835' 4520', 9126' /4696' , MD TVD MD TVD Additional Packers (5 Total): 9286' /x793' 9420' / 4874' 9588' / 4974' 8884' - 8916' 4550' - 4569' 9228' - 9278' 4758' - 4789' 26, ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9300' - 9330' 4802' - 4820' DEPTH INTERVAL (MD AMOUNT AND KIND OF MATERIAL USED 9490' - 9572' 4916' - 4965' 9652' 4987' - 5012' 9610' Freeze Protected w/ 125 Bbls Diesel - 27. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test: Hours Tested: Production For Test Period OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 28. CORE DATA Conventi onal Core(s) Acqui red? ^Yes ®No Sidewall Core(s) Acquired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presenc,~f oil~gas or water (submit separate sheets with this form, ff needed). Submit detailed descriptions, core chips, photographs and laboratory analytical res~lt~~f'gQ~50.071. ~D~~ None ; ~w~--"°~,,,,~ 4 !gyp! _ R....,, ~.... RBDMS JAN 1 ~ 1Q10 ~~ Form 10-407 Revised 12!2009 CONTINUED ON REVERSE Submit Original Only r~ 29~ GEOLOGIC MARKERS (List all formations and m ers encountered): 30. ORMATION 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 1972' 1783' detailed test information per 20 AAC 25.071. Ugnu 5392' 3036' Ugnu MA 8391' 4265' None Ugnu MB1 8471' 4310' Ugnu M62 8587 4375' Ugnu MC 8746' 4467' Schrader Bluff NA 8844' 4526' Schrader Bluff NB 8884' 4550' Schrader Bluff NC 8941' 4584' Schrader Bluff NE 8958' 4594' Schrader Bluff NF 9047' 4648' Schrader Bluff OA 9111' 4687' Schrader Bluff OBa 9228' 4758' Schrader Bluff OBb 9298' 4801' Schrader Bluff OBc 9399' 4861' Schrader Bluff OBd 9489' 4915' Schrader Bluff OBe 9608' 4986' Schrader Bluff OBf 9691' 5036' Base Schrader Bluff OBf 9775' 5086' / Top Colville Mudstone Formation at Total Depth (Name): Colville Mudstone 9775' 5086' 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. y Ol/! / ~ Title: Drilling Technologist Date: " ~ Signed: Terrie Hubble PBU V-224 208-154 Prepared ByName/Numder. Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. Drilling Engineer: Ryan Ciolkosz, 5645977 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information requin:d by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only BP AMERICA Page 1 of 1; Leak-Off Test Summary Legal Name: V-224 Common Name: V-224 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 12/7/2009 LOT 5,468.0 (ft) 3,063.2 (ft) 8.80 (ppg) 793 (psi) 2,193 (psi) 13.78 (ppg) Printed: 12/28/2009 8:46:34 AM BP AMERICA Page 1 of 27 Operations Summary Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase ' Description of Operations 11/25/2009 00:00 - 01:00 1.00 MOB P PRE PJSM W/ PEAK & RIG HANDS ON MOVING PITS. -MOVE PITS AWAY FROM RIG SUBSTRUCTURE TO THE EDGE OF V-PAD. -PULL DIVERTER SYSTEM FROM CELLAR & NU ON V-224. 02:00 - 15:00 13.00 RIGU P PRE MOVE IN & SPOT RIG SUBSTRUCTURE ON V-224. -LAY MATS & HERCULITE. -PJSM W/ PEAK & RIG CREW ON SPOTTING PITS -SPOT AND LEVEL PITS, STAGE RISER IN CELLAR. -BUTTON UP CELLAR, INSTALL WALKWAYS AND HANDRAILS, HOOK UP STEAM & H2O TO PITS. AFTER PULLING THE RIG OFF OF V-2271, A SPOT APPROXIMATELY 1.5 SQUARE FEET WAS NOTICED. NON EMERGENCY SPILL RESPONSE (5700) AND THE V-PAD OPERATOR WERE NOTIFIED. THE SPOT WAS DETERMINED TO BE LESS THAN 2 QUARTS OF HYDRAULIC FLUID. THE SPOT WAS SITUATED BELOW WHERE THE PIPE SKATE HAD BEEN LOCATED WHEN THE RIG WAS ON THE WELL. TWO WEEKS AGO, THE PIPE SKATE DEVELOPED A LEAK ONTO THE FLOOR OF THE PIPE SHED. THE HYDRAULIC FLUID WAS CLEANED UP, HOWEVER SOME OF THE FLUID APPARENTLY LEAKED PAST THE PIPE SHED FLOOR AND ONTO THE PAD BELOW. THE MATERIAL WAS CLEANED UP & PLACED IN OILY WASTE BAGS FOR DISPOSAL. IR # 2009-IR-3317145 15:00 - 17:00 2.001 RIGU P 17:00 - 20:00 3.00 I RIGU P 22:00 - 00:00 2.001 RIGU ~ P 111/26/2009 100:00 - 05:00 I 5.001 RIGU I P -RIG ACCEPT FOR OPERATIONS ON V-224 AT 12:00 HRS ON 11/25/2009.- PRE PJSM W/ PEAK & 9ES PERSONEL, ON MOVING TAYLOR CAMP. -MOVE TAYLOR CAMP TO V-PAD ENTRANCE. -TAKE ON 580 BBL OF 8.5 PPG DRILPLEX SPUD MUD TO PITS ~ 15:00 HOURS. -TOP OFF BST'S W/ COLD LAKE WATER. PRE INSTALL RISER & FLOW LINE, MAKE UP RISER TO HYDRIL. -MEASURE RKB TO GL DISTANCE. -CALIBRATE H2S ALARMS, CHANGE OUT SAVER SUB. -LOAD PIPE INTO PIPE SHED. STRAP 150 JOINT'S 4" DP IN PIPE SHED FOR TARGET TD OF 5,500' MD. PRE PJSM W/ 9ES RIG CREW ON PICKING UP DRILLPIPE FROM PIPESHED. -INSTALL SECONDARY MOUSE HOLE IN ROTARY TABLE. -PICK UP 150 JTS OF 4" DP & 18 JTS OF 4" HWDP 1 X 1 FROM PIPE SHED. -MAKE UP STANDS IN CONDUCTOR, STAND BACK IN DERRICK. PRE-SPUD MEETING PERFOMED WITH 9ES RIG NIGHT CREW f~ 23:00 HOURS 11/25/2009 PRE CONTINUE TO PICK UP 4" DP 1X1 FROM PIPE SHED. -RACK BACK 50 STANDS 4" DP, 6 STANDS 4" HWDP. Printed: 12/28/2009 8:46:39 AM w ~ BP AMERICA Page 2 of 27 Operations Sumrnary Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code 'N PT Phase Description of Operations 11/26/2009 00:00 - 05:00 5.00 RIGU P PRE -LAY DOWN MOUSE HOLE. 05:00 - 06:00 1.00 RIGU P PRE RIH W/ 4" DRILL PIPE TO 40' MD, TAG UP ON ICE. -PJSM FUNCTION TEST DIVERTER & PERFORM ACCUMULATOR DRAW DOWN TEST. -TEST WITNESSED BY: BP WSL'S SEAN HUFSTETLER, DAVE NEWLON & NABOBS TOOLPUSHER BRIAN TIEDEMEN. WITNESS OF TEST WAIVED BY AOGCC REP CHUCK SCHEVE. 06:00 - 10:30 4.50 RIGU P PRE PJSM W/ 9ES RIG CREW, SPERRY & GYRO ON PICKING UP BHA &WIRELINE TOOLS. -PULL TEST PAD EYES ~ BEAVER SLIDE, RIG UP GYRO DATA. -PICK UP BHA #1 TO DRILL OUT ICE IN CONDUCTOR. -12-1/4" BIT, 1.83 MOTOR, UBHO, XO'S, 6 JTS. HWDP. -FILL SURFACE LINES & PRESSURE TEST TO 3,000 PSI. 10:30 - 12:00 1.50 DRILL P SURF RIH W/ BHA # 1, TAG UP ON ICE ~ 40', DRILL OUT TO 100' MD. -PRE SPUD CHECKLIST COMPLETE. -PRE SPUD MEETING W/ BP WSL & ALL RIG PERSONNEL ~ 11:00 HOURS. -CONTINUE DRILLING AHEAD TO 120' MD. 12:00 - 13:00 1.001 DRILL ~ P 13:00 - 13:30 I 0.501 DRILL ~ P 13:30 - 15:30 I 2.00 DRILL P 15:30 - 17:00 I 1.501 DRILL P 17:00 - 20:00 3.001 DRILL ~ P 20:00 - 00:00 I 4.001 DRILL ~ P 111/27/2009 ~ 00:00 - 12:00 ~ 12.00 ~ DRILL ~ P SPUD WELL ~ 12:00 PM 11/26/2009 SURF CONTINUE TO DRILL AHEAD FROM 120' TO 219' MD. -PUW 52K, SOW 50K, ROT 50K. -545 GPM ~ 490 PSI OFF, 539 PSI ON. -45 RPM ~ 800 TO OFF, 2K TO ON, 25K WOB. MW IN/OUT 8.8 PPG SURF PJSM W/ 9ES RIG CREW, SPERRY & GYRO ON RIGGING WIRELINE TOOLS. -RIG UP WIRELINE & GYRO DATA, ORIENT MOTOR. SURF DRILL AHEAD FROM 219' TO 312' MD. -PUW 52K, SOW 50K, RWT 50K. -181 SPM, 545 GPM ~ 490 PSI OFF, 539 PSI ON - 45 RPM, 800 TO OFF, 2K TO ON. SURF POH FROM 312' MD, TO 28' LAY DOWN BHA # 1 UBHO & XO. -SERVICE TOP DRIVE. -MW IN /OUT 8.6 PPG SURF PICK UP BHA #2. -12 1/4" BIT, 1.83 MOTOR, NMLC, NMLC, MWD, UBHO, NM STAB, NM XO, 7" DC'S, SAVER SUB, HWDP, JARS, HWDP. -WASH DOWN FROM 282' TO 312' MD. SURF DRILL AHEAD FROM 312' TO 540' MD -PUW 65K, SOW 65K, RWT 70K. -195 SPM, 580 GPM ~ 625 PSI OFF, 725 PSI ON - 45 RPM 1.4K TO OFF, 2K TO ON. MW IN /OUT 8.6 PPG ART=0.63, AST=1.27 SURF CONTINUE TO DRILL AHEAD FROM 557' TO 1,308' MD W/ rnrneu. iucoicvva o.YU.w nm BP AMERICA Page 3 of 27 Operations Summary Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date .From - To Hours Task Code NPT Phase - Description of Operations 11/27/2009 00:00 - 12:00 12.00 DRILL P SURF BHA # 2. -12 1/4" BIT, 1.83 MOTOR, NMLC, NMLC, MWD, UBHO, NM STAB, NM XO, 7" DC'S, SAVER SUB, HWDP, JARS, HWDP. -PUW 75K, SOW 75K, RWT 80K. -195 SPM, 580 GPM ~ 1,230 PSI OFF, 1,530 PSI ON. - 45 RPM 2K TO OFF, 5K TO ON. -GYRO EVERY STAND TO 833' MD. -BACKREAM 30' ON CONNECTIONS ART=2.13 HRS, AST=5.5 ART MW IN /OUT 9.0 PPG 12:00 - 23:00 I 11.00 DRILL P 23:00 - 00:00 1.00 I DRILL ~ P 11/28/2009 100:00 - 00:30 ~ 0.501 DRILL ~ P 00:30 - 03:30 3.00 I DRILL P 03:30 - 04:00 I 0.50 ~ DRILL ~ P FLUID LOSSES TO SURFACE INTERVAL FOR TOUR = 100 BBL SURF CONTINUE TO DRILL AHEAD FROM 1 308' TO END OF BUILD SECTION ~ 2.455' MD W/ BHA # 2.__ -12 1/4" BIT, 1.83 MOTOR, NMLC, NMLC, MWD, UBHO, NM STAB, NM XO, 7" DC'S, SAVER SUB, HWDP, JARS, HWDP. -PUW 95K, SOW 65K, RWT 75K. -227 SPM, 650 GPM ~ 1,810 PSI OFF, 1,950 PSI ON. - 45 RPM 3K TO OFF, 7K TO ON. AST = 5.82 HRS, ART = 2.75 HRS MW IN 9.0 PPG /OUT 9.1 PPG H FLUID LOSSES TO SURFACE INTERVAL FOR TOUR = 40 BBL TOTAL FLUID LOSSES TO SURFACE INTERVAL =140 BBL SURF CONTINUE TO CIRCULATE 3 X BOTTOMS UP, RACKING BACK 1 STAND EVERY BU FROM 2,455 TO 2,179' MD. -PUMP OUT 2 STANDS FROM 2,179' TO 1,995' MD. -PUW 91 K, SOW 70K, ROT 79K -220 SPM, 650 GPM ~ 1980 PSI. 52 RPM 3K TO. SURF CONTINUE TO CIRCULATE 3 X BOTTOMS UP WHILE BACK REAMING FROM FROM 2,455' TO 2,179' MD. -POH WHILE PUMPING OUT 2 STANDS FROM 2,168' TO 1,995' MD. -PUW 91 K, SOW 70K, R0T79K -660 GPM ~ 1,944 PSI. 50 RPM 3.5K TO -MONITOR WELL -STATIC. -BLOW DOWN TOP DRIVE. SURF POH ON ELEVATORS FROM 1,995 TO 437' MD. -PULLED TIGHT ~ 1,870' MD. -WIPE TIGHT SPOT, OK, CONTINUE POH. -PULLED TIGHT FROM 560' TO 505' MD & 451' TO 437' MD. -UNABLE TO WIPE CLEAN, BACKREAM BOTH SECTIONS. -400 GPM ~ 434 PSI, 40 RPM ~ 1 K TO 3K TO. MW IN /OUT 9.1 PPG. SURF CONTINUE TO POH ON ELEVATORS FROM 437' TO 343' -PULLED TIGHT FROM 358' TO 343' MD. -WIPE TIGHT SECTION, OK. Pflllt8tl: 7'LI'LW1UUy tl:4ti::7y AM $P AMERICA Page 4 of 27 Operations. Summary Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date .From - To Hours Task Code NPT Phase Description of`Operations 11/28/2009 03:30 - 04:00 0.50 DRILL P SURF MW IN /OUT 9.2 PPG 04:00 - 06:30 2.50 DRILL P SURF LAY DOWN 12 1/4" BHA # 2. -STAND BACK JARS & COLLARS. -LAY DOWN XO, NM STAB, UBHO & 12 1/4" BIT. 06:30 - 07:30 1.00 DRILL P SURF MAKE UP 12 1/4" BHA # 3 -12 1/4" MXL-iX HUGHES, 9 5/8" 1.5 DEG BENT MUD MOTOR, NMLC, NM STAB, MWD, NM STAB, NMDC, NM STAB, NMDC'S, 5" HWDP, JARS, 5" HWDP, 4" HWDP. 07:30 - 08:30 1.00 DRILL P SURF CLEAN & CLEAR RIG FLOOR. -SERVICE TOP DRIVE, DRAW WORKS & CROWN. 08:30 - 15:30 7.00 DRILL P SURF PICK UP &RIH W/ 12 1/4" DRILLING BHA # 3 FROM 275' TO 650' MD -12 1/4" SMITH XR+VCR MT BIT, 9 5/8" 1.5 DEG BENT MUD MOTOR, NMLC, NM STAB, MWD, UBHO, NM STAB, UBHO, NMDC, NM STAB, NMDC'S, 5" HWDP, JARS, 5" HWDP, 4" HWDP. -STRING TOOK WEIGHT, PUW 75K, SOW 75K. -WORK PIPE W/ NO PUMP FROM 650' TO 750' MD. (v -CONTINUE TO RIH FROM 750' TO 1,052' MD. ~_,,d -STRING SAT DOWN, ~ 1,052' MD, WORK DOWN FROM 1,052 TO 1,290' MD. LL RPM 1 K 7K TO ~ ~ , - . 7 -250 GPM ~ 940 PSI, 10 RPM TO 40 -INDICATIONS WELL IS DRILLING /SIDE TRACKED RUN ~ q ~~`~ SURVEYS TO CONFIRM. p~ ~ -SURVEYS INDICATE THAT HOLE IS SIDETRACKED. Ir 7 15:30 - 17:00 1.50 STKOH N DPRB SURF POH 1 STAND & WORK PIPE TO REGAIN ORIGINAL HOLE ' SECTION ~ 30 DEGREES RIGHT. UNABLE TO SLIDE INTO HOLE. -POH TO OBTAIN SURVEYS f~ 1,200', 1,170' & 1,144' MD. -SURVEY CONFIRMED THAT BHA IS SIDETRACKED ~ 1,144' MD, RIH TO 1,290' MD. MW IN /OUT 9.2 PPG 17:00 - 00:00 7.00 DRILL N DPRB SURF DRILL AHEAD FROM 1,290' TO 1,874' MD. -PUW 90K, SOW 70K, RWT 80K, -45 RPM ~ 4-5K TO ON, 3K TO OFF. -195 SPM, 580 GPM ~ 1,220 PSI OFF, 1,400 PSI ON. ART= 4.83 HRS AST= .57 HRS MW IN /OUT 9.2 PPG FLUID LOST TO SURFACE INTERVAL FOR TODAY= 160 BBL 11/29/2009 00:00 - 03:30 3.50 DRILL N DPRB SURF CONTINUE TO DRILL AHEAD IN 12-1/4" SURFACE HOLE FROM 1,874' TO 2,445' 'MD. -PUW 98K, SOW 73K ,ROT 80K. -650 GPM ~ 2,670 PSI ON, 2510 PSI OFF. -80 RPM ~ 9K TO ON, 6K TO OFF. -BACKREAM 90' ON CONNECTIONS AND SURVEY EVERY STAND. -HYDRATES AT 2,400', 2,848', 3,266', 3,450' MD Printed: 12/28/2009 8:46:39 AM BP AMERICA Page 5 of 27 Operations Summary Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase 11/29/2009 00:00 - 03:30 3.50 DRILL N DPRB SURF 03:30 - 00:00 20.501 DRILL P 11/30/2009 100:00 - 03:00 3.001 DRILL ~ P 03:00 - 03:30 0.501 DRILL P 03:30 - 14:30 11.00 DRILL P 14:30 - 18:30 I 4.001 DRILL P 18:30 - 00:00 I 5.501 CASE SURF SURF Description of Operations MW IN /OUT 9.6 PPG AST= 3.48 HRS, ART= 2.97 HRS CONTINUE TO DRILL AHEAD IN 12-1/4" SURFACE HOLE FROM 3,595' TO 5,315' MD. -PUW 120K, SOW 75K ,ROT 90K. -650 GPM C~ 3,280 PSI ON, 3145 PSI OFF. -80 RPM ~ 11 K TO ON, 7.5K TO OFF. -BACKREAM 90' ON CONNECTIONS AND SURVEY EVERY STAND. -HYDRATES AT 4,475', 4,874', 5,012', 5,415' MD MW IN /OUT 9.6 PPG AST= 1.82 HRS, ART= 5.82 HRS LOSSES TO SURFACE INTERVAL FOR TODAY = 300 BBL. TOTAL FLUID LOSSES TO SURFACE INTERVAL = 600 BBL CONTINUE TO DRILL AHEAD IN 12-1/4" SURFACE HOLE J~ FROM 5,315' TO TD ~ 5,481' MD, 3,068' TVD. ~.r -PUW 120K, SOW 70K , 98 t g ~4 -650 GPM ~ 3,389 PSI ON, 3190 PSI OFF. -80 RPM ~ 11 K TO ON, 7.5K TO OFF. -BACKREAM 90' ON CONNECTIONS AND SURVEY EVERY STAND. -HYDRATES AT 5,415' MD. MW IN /OUT 9.5 PPG AST= 0.32, ART= 0.88 SURF CIRCULATE & RECIPROCATE 3 X BOTTOMS UP. -215 SPM, 650 GPM f~ 3,130 PSI. -100 RPM ~ 8K TO. -MONITOR WELL- OK. SURF BACK REAM OUT OF HOLE FROM 5,481' MD TO TOP OF HWDP ~ 824' MD. -ENCOUNTERED TIGHT SPOT FROM 5,481' TO 5,290' MD WITH INTERMITTENT OVERPULL FROM 20K TO 35K. -WIPED SPOT, OK, CONTINUE TO BACKREAM OUT OF HOLE. -BACK REAM OUT OF HOLE FROM 5,290' TO 2,257' MD. -ATTEMPT TO POH ON ELEVATORS W/ NO SUCCESS DUE TO SWABBING. -CONTINUE TO BACKREAM OUT OF HOLE FROM 2,257' TO TOP OF HWDP ~ 825' MD. -650 GPM ~ 3,153 PSI,35 RPM ~ 7.5K TO. MW IN /OUT 9.5 PPG SURF LAY DOWN SURFACE DRILLING BHA #3. -STAND BACK 6 STANDS OF 4" HWDP, JARS AND COLLAR -CLEAN AND CLEAR RIG FLOOR. SURF RU TO RUN 9 5/8" 40# L-80 SURFACE CASING. -RU FRANK'S FILL-UP TOOL AND 350 TON ELEVATORS. -PERFORM DUMMY RUN WITH 9 5/8" MANDREL HANGER. -CONFIRM RKB ELEVATION OF 28.8'. FLUID LOSSES TO SURFACE INTERVAL FOR TODAY = 67 rnncea: iu~w~vua o:4o:aar+m BP AMERICA Page 6 of 27 - Operations Surnrnary Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From' - To Hours Task Code NPT Phase 'Description of Operations 11/30/2009 18:30 - 00:00 5.50 CASE SURF BBL 12/1/2009 00:00 - 01:00 1.00 CASE P SURF 01:00 - 12:00 11.00 CASE P SURF 12:00 - 20:00 I 8.001 CASE P SURF 20:00 - 00:00 4.001 CASE N DPRB SURF TOTAL FLUID LOSSES TO SURFACE INTERVAL = 567 BBL FINISH RU 350 TON ELEVATORS. PJSM ON RUNNING 9 5/8" 40# L-80 SURFACE CASING. MU 9 5/8" 40# L-80 SURFACE CASING SHOE TO 8,500 FT-LBS AND BAKER-LOK. FILL PIPE AND TEST FLOATS - GOOD. RUN IN THE HOLE WITH 9 5/8" 40# L-80 TO 1480' MD, TORQUE EACH CONNECTION TO MARK WITH AN AVERAGE TORQUE OF 8,500 FT-LBS. FILLED EVERY JOINT USING THE FRANK'S TOOL AND CIRCULATE EVERY 10TH JOINT AT 4 BPM WITH 109 PSI. LOST -20K LBS DOWN WEIGHT AT 950' MD. WORK PIPE WHILE PUMPING AT 3.6 BPM WITH 120 PSI, GOOD. CONTINUE TO RUN 9 5/8" SURFACE CASING FROM 950' MD WITH STRING TAKING 15K - 20K LBS AT 997' MD, 1230' MD, 1280' MD, 1390' MD - 1420' MD. WORK SURFACE CASING THROUGH SPOTS WHILE PUMPING AT 5.8 BPM WITH 370 PSI. CONTINUE RUNNING 9 5/8" SURFACE CASING FROM 1420' MD TO 1686' MD. PUW 110K, SOW 87K. MW IN 9.2 PPG /OUT 9.6 PPG. CONTINUE TO RUN IN THE HOLE WITH 9 5/8" 40# L-80 TO 1686' MD TO 2813' MD, TORQUE EACH CONNECTION TO MARK WITH AN AVERAGE TORQUE OF 8,500 FT-LBS. FILLED EVERY JOINT USING THE FRANK'S TOOL AND CIRCULATE EVERY 10TH JOINT AT 5.6 BPM WITH 452 PSI. LOST -30K DOWN WEIGHT FROM 2813' MD TO 2896' MD. WORK PIPE WITH PUMPS ON AND OFF ADJUSTING PUMP RATE ACCORDINGLY FROM 6 BPM WITH 500 PSI TO 2 BPM WITH 467 PSI. PACKING OFF AT 2896' MD AND UNABLE TO MAKE ANY FURTHER PROGRESS. MW IN 9.2 PPG /OUT 9.6 PPG. ADD SCREENKLEEN TO 0.5% VN CONCENTRATION TO AID RESOLVE SCREEN BLINDING ISSUES. CONTACT TOWN AND DECIDE TO POH TO 2729' MD (ABOVE BENTONITE /CLAY BED LOCATED AT 2745' MD RIGHT ABOVE SV3). LD FRANKS FILL UP TOOL, BLOW DOWN TOP DRIVE. RU BACK UP TONGS. RU 3" HOSE TO SUPER SUCKER. POH AND LAY DOWN 2 JOINTS FROM 2896' MD TO 2813' MD. INTERMITTENT 40K OVERPULL NOTED WHILE POH BOTH ,JOINTS, NO ISSUES ON DOWN STROKE (75K - 80K LBS rnnteo: iuzwzwa °:vo:aa rim BP AMERICA Page 7 of 27 Operations Summary Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 12/1/2009 20:00 - 00:00 4.00 CASE N DPRB SURF 12/2/2009 ~ 00:00 - 01:30 ~ 1.50 ~ CASE ~ N ~ DPRB ~ SURF 01:30 - 05:00 3.501 CASE ~ N I DPRB ~ SURF 05:00 - 12:00 7.00 I CASE ~ N I DPRB ~ SURF DOWN WEIGHT). NOTE: PIN THREADS OF JOINT 71 AND BOX THREADS OF JOINT 70 WERE DAMAGED, REPLACED JOINTS. PUW 145K, SOW 80K. MW IN 9.2 PPG /OUT 9.6 PPG. FLUID LOSS: 392 BBLS DRILPLEX MUD LOST FOR TODAY CONTINUE TO POH FROM 2813' MD TO 2725' MD AND LAY DOWN BOTH JOINTS. THREADS ON BOTH JOINTS WERE DAMAGED, REPLACED JOINTS. NO OVERPULL GREATER THAN 40K NOTED, NO ISSUES ON DOWN STROKE. MW IN 9.2 PPG / 9.6 PPG ESTABLISH CIRCULATION BY STAGGING UP PUMPS AS FOLLOWS: 2.5 BPM WITH 322 PSI 5 BPM WITH 370 PSI 6 BPM INITIAL CIRC 431 PSI, FINAL CIRC 373 PSI 20% INCREASE IN RETURNS WITH RETURN OF 1ST BOTTOMS UP, MOSTLY SAND, GRAVEL AND SOME WOOD. SHAKERS CLEANED UP CONSIDERABLY WITH RETURN OF 2ND BOTTOMS UP CONTINUE TO CIRCULATE AT 6 BPM WITH 380 PSI WHILE MONITORING PRESSURE, DRAG AND FLUID RHEOLOGY TRENDS. NO ISSUES WITH PRESSURE STABIIiZING, CONSISTENT DOWN STROKE DRAG OF 76K LBS. RECIPROCATING PIPE IN -15' STROKES, PACKING OFF SLIGHTLY ON UPSTROKE WITH 60 PSI INCREASE IN PRESSURE AND 5% LOSS IN RETURN FLOW. MAKE CONSISTENT PROGRESS IN UPSTROKE BY WORKING PIPE WHILE CONTINUE TO CIRCULATE TO CONDITION MUD. CONSISTENT MUD PROPERTIES OBTAINED AT 04:30 HRS AS FOLLOWS: 9.4 PPG MW IN /OUT, 36 LSYP IN, 34 LSYP OUT. 128K PUW, 76K SOW WITH PUMPS ON. FLUID LOSS: -30 BBLS PER HOUR OF DRILPLEX MUD WHILE CIRCULATING RUN 9 5/8" SURFACE CASING FROM 2725' MD TO 2735' MD WHILE PUMPING AT 256 GPM WITH 346 PSI. CASING PACKED OFF AT 2735' MD, WORK PIPE FREE AND ESTABLISH CIRCULATION BY STAGGING PUMPS UP TO 497 GPM WITH 859 PSI AT 2725' MD. RIH WITH 9 5/8" CASING FROM 2725' MD TO 2727' MD WHILE PUMPING AT 414 GPM WITH 265 PSI. CASING PACKED OFF AT 2727' MD, WORK PIPE FREE AND ESTABLISH CIRCULATION BY STAGGING PUMPS UP TO 497 GPM WITH 859 PSI. rnrnea: iu~aicwa °:v°ay rm BP AMERICA Operations Summary Report Legal Well Name: V-224 Common Well Name: V-224 Event Name: DRILL+COMPLETE Start: 11/25/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT 'Phase Description of Operations 12/2/2009 05:00 - 12:00 7.00 CASE N DPRB SURF CONTINUE TO RIH FROM 2727' MD TO 2729' MD, CASING PACKED OFF AT 2729' MD. WORK PIPE FREE WITH PUMPS ON AND OFF. RUN IN THE HOLE WITH 9 5/8" 40# L-80 FROM 2729' MD TO 2896' MD WITH NO FURTHER ISSUES, TORQUE EACH CONNECTION TO MARK WITH AN AVERAGE TORQUE OF 8,500 FT-LBS. FILLED EVERY JOINT USING THE FRANK'S TOOL AND CIRCULATE EVERY 5TH JOINT AT 6 BPM WITH 550 - 600 PSI ON THE UPSTROKE DUE TO LACK OF DOWN WEIGHT WHILE PUMPING ON DOWNSTROKE. 12:00 - 17:00 5.00 CASE P SURF RUN IN THE HOLE WITH 9 5/8" 40# L-80 FROM 2896' MD TO 4230' MD. TORQUE EACH CONNECTION TO MARK WITH AN AVERAGE TORQUE OF 8,500 FT-LBS. FILLED EVERY JOINT USING THE FRANK'S TOOL AND CIRCULATE EVERY 5TH JOINT ON THE UPSTROKE AT 6 BPM WITH 550 - 600 PSI. PUW 150K, SOW 95K. MW IN 9.3 /OUT 9.4 PPG. DEVIATE FROM 1-CENTER DRAG PLOT (DEVIATION OCCURRED ON THE UP WEIGHT AT 0.4 FRICTION FACTOR). DECIDE TO CIRCULATE THREE BOTOMS UP. FLUID LOSS: TOTAL OF 165 BBLS LOST TO FORMATION UP TO THIS POINT IN TIME FOR TODAY. 17:00 - 18:30 1.50 CASE P SURF CIRCULATE WELLBORE CLEAN BY STAGE PUMPS UP AS FOLLOWS WHILE RECIPROCATING CASING IN 40' STROKES: 5 BPM WITH 554 PSI 6.3 BPM WITH 533 PSI 8.7 BPM W ITH 687 PSI 10 BPM WITH INITIAL 744 PSI, FINAL 714 PSI INITIAL PUW 136K, FINAL PUW 137K (PUMPS ON) INITIAL SOW 83K, FINAL SOW 88K (PUMPS ON) FINAL PUW 175K, FINAL SOW 105K (PUMPS OFF) SHAKERS LOOK CLEAN AT END OF THREE BOTTOMS UP. MW IN 9.3 /OUT 9.4 PPG. NO FLUID LOSS NOTED. 18:30 - 00:00 5.50 CASE P SURF RUN IN THE HOLE WITH 9 5/8" 40# L-80 FROM 4230' MD TO 4858' MD. TORQUE EACH CONNECTION TO MARK WITH AN AVERAGE TORQUE OF 8,500 FT-LBS. FILLED EVERY JOINT USING THE FRANK'S TOOL AND CIRCULATE EVERY 5TH JOINT ON THE UPSTROKE AT 6 BPM WITH 550 - 600 PSI FROM 4230' MD TO 4272' MD. ABLE TO CIRCULATE DOWN EVERY 5TH JOINT FROM 4272' MD TO 4689' MD AT 6 BPM W ITH 600 PSI. LOST -45K DOWN WEIGHT WHILE WASHING DOWN AT Page 8 of 27 Spud Date: 11 /26/2009 End: PfIf11Btl: 11JLtl/1UUy tl:4ti::ty AM i BP AMERICA Qperations Summary Report Page 9 of 27 Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From.- To Hours Task Code NPT Phase Description of Operations 12/2/2009 18:30 - 00:00 5.50 CASE P SURF 4731' MD. CIRCULATE EVERY JOINT FROM 4731' MD TO 5147' MD ON UPSTROKE AND WITH PUMPS OFF ON DOW NSTROKE. LOST -45K DOWN WEIGHT AT 5147' MD AND PACKED OFF WITH UP TO 250 PSI DIFFERENTIAL AND 15% REDUCTION IN RETURN FLOW. WORK PIPE WITH PUMPS ON AND OFF AT 6 BPM WITH INITIAL CIRC PRESSURE OF 750 PSI - 864 PSI AND FINAL CIRC PRESSURE OF 528 PSI. FULL RETURNS THROUGHOUT ENTIRE CIRCULATION AFTER PRESSURE STABILIZED. 12/3/2009 00:00 - 03:00 ~ 3.00 ~ CASE ~ P PUW 180K, SOW 115K. MW IN 9.3 /OUT 9.4 PPG. NO FLUID LOSS NOTED. SURF CONTINUE TO WORK 9 5/8" SURFACE CASING FROM X147' MD TO 5231' MD WHILE PUMPING AT 262 GPM WITH 531 PSI AND FULL RETURNS. RIH FROM 5231' MD TO 5438' MD WITHOUT PUMPING AND WITH NO ISSUES. CIRCULATE LAST JOINT ON UPSTROKE AT 6 BPM WITH 560 PSI. 03:00 - 04:00 1.00 I CASE i P 04:00 - 06:30 2.501 CEMT ~ P MW IN 9.5 PPG /OUT 9.6 PPG SURF PICK UP THE 9 5/8" MANDREL HANGER AND LANDING JOINT AND RUN TO BOTTOM AT 5470' MD. PUW 210K, SOW 100K. RD CASING RUNNING EQUIPMENT. RU CEMENT HEAD. SURF CIRCULATE FOR CEMENT JOB BY STAGGING PUMPS UP AS FOLLOWS: 3 BPM WITH 344 PSI 4 BPM WITH 413 PSI 6 BPM WITH INITIAL CIRC PRESSURE OF 516 PSI, FINAL CIRC PRESSURE OF 476 PSI 8 BPM WITH INITIAL CIRC PRESSURE OF 612 PSI, FINAL CIRC PRESSURE OF 509 PSI RECIPROCATE PIPE THROUGHOUT ENTIRE CIRCULATION IN 10' STROKES: INITIAL DRAG 176K PUW, 88K SOW FINAL DRAG 190K PUW, 94K SOW MW IN /OUT 9.4 PPG NO SIGNIFICANT FLUID LOSS NOTED ~ CIRCULATING PRIOR TO CEMENT JOB. PJSM WITH SLB CEMENTERS, TRUCK PUSHERS, CREWS AND MUD ENGINEER FOR CEMENT JOB. 06:30 - 12:30 6.00 CEMT P SURF CEMENT 9 5/8" SURFACE CASING WHILE RECIPROCATING CASING IN 10' STROKES. LAND 9 5/8" MANDREL HANGER ON LANDING RING PRIOR TO ASL LEAD CEMENT CAME OUT OF SHOE AT 412 BBLS ASL PUMPED. RESUMED RECIPROCATION. LOST ALL DOWN rnntea: tuetsiruva o:a°:~a r+rvi $P AMERICA Page 10 of 27 Operations Summary Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task ~ Code NPT Phase Description of Operations 12/3/2009 06:30 - 12:30 6.00 CEMT P SURF WEIGHT AT 525 BBLS ASL LEAD CEMENT PUMPED WITH THE 9 5/8" HANGER 2.5' ABOVE LANDING RING. UNABLE TO LAND 9 5/8" MANDREL HANGER ON LANDING RING. 06:55 PUMP 5 BBLS H2O AT 3 BPM, TEST LINES TO 4000 PSI -GOOD. 07:30 PUMP 102.7 BBL 10.0 PPG MUD PUSH II AT 5 BPM WITH 280 PSI 07:30 DROP BOTTOM PLUG; GOOD INDICATION THAT PLUG LEFT HEAD 07:35 START PUMPING 10.7 PPG ASL LEAD AT BPM WITH 149 PSI 08:53 412 BBL LEAD CEMENT AWAY, 5.5 BPM, 288 PSI 08:51 404 BBL LEAD CEMENT AWAY, 5.2 BPM, 236 PSI 08:52 412 BBL LEAD CEMENT AWAY, 2.7 BPM, 170 PSI SAW BOTTOM PLUG SHEARED AT 412.8 BBL LEAD PUMPED PARK CASING ON RING WHILE LEAD AROUND SHOE 08:55 420 BBL LEAD CEMENT AWAY, 5.5 BPM, 286 PSI 10' STROKE RECIPROCATION RESUMED PUW 220K, SOW t00K 09:05 470 BBL LEAD CEMENT AWAY, 5.5 BPM, 341 PSI PUW 220K, SOW 70K 09:15 525 BBL LEAD CEMENT AWAY, 5.5 BPM, 346 PSI PUW 240K, SOW 52K UNABLE TO LAND 9 5/8" MANDREL HANGER ON ._ RING WORK CASING BY PULLING UP TO 420K, DID NOT BREAK FREE 10:20 875.5 BBL LEAD CEMENT AWAY, 5.2 BPM, 478 PSI SWAP OVER TO 15.8 PPG TAIL 10:48 87.5 BBL TAIL CEMENT AWAY, 5.1 BPM, 291 PSI 10:52 DROPPED TOP PLUG; KICK OUT WITH 10 BBL WATER; POSITIVE INDICATION THAT PLUG LEFT HEAD. ISOLATE SLB AND DISPLACE WITH RIG PUMPS. 10:55 CHASING CEMENT WITH RIG PUMPS, 9.4 PPG DRILPLEX MUD PLUG BUMP AT 5655 STROKES, 409 BBLS DISPLACED. FINAL PUMP PRESSURE AT BUMP 1570 PSI AND HELD FOR 2 MINUTES. PRESSURE UP TO 3500 PSI AND HOLD FOR 5 MINUTES -GOOD. BLEED PRESSURE OFF. CHECK FLOATS -HOLDING. CEMENT IN PLACE AT 12:20 HRS 188 BBLS OF SIDEWALK CEMENT BACK TO SURFACE. FLUID LOSS: NO SIGNIFICANT FLUID LOSS NOTED. F'flfltBtl: 7%J'LW'LVU'J tl:4C::7y HM ~ • BP AMERICA Page 11 of 27 Operations Summary Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 12/3/2009 06:30 - 12:30 6.00 CEMT P SURF GOOD FLOW RETURNS THROUGHOUT JOB. CEMENT JOB VOLUME: 875.5 BBLS ASL LEAD PUMPED; 1090 SACKS AT 4.51 CUFT/SX 87.5 BBLS CLASS G TAIL PUMPED; 420 SACKS AT 1.17 CUFT/SX LEAD COMPRESSIVE STRENGTH: NOT AVAILABLE TAIL COMPRESSIVE STRENGTH: 500 PSI: 14:35 HRS 1000 PSI: 21:26 HRS 12:30 - 15:00 2.50 CEMT P SURF RD SCHLUMBERGER AND CEMENTING EQUIPMENT. RD CEMENT HEAD, RD DIVERTER LINE. FLUSH STACK. CLEAR FLOOR OF FRANKS TOOL. 15:00 - 18:00 3.00 DIVRTR P SURF PJSM ON NIPPLE DOWN DIVERTER SYSTEM. PULL RISER EXTENSION, LD RISER. MOVE SURFACE RISER OFF CONDUCTOR. 18:00 - 20:00 2.00 WHSUR N STUC SURF PREPARE CELLAR AND WELLHEAD FOR UPCOMING WELLHEAD WORK. SUCK MUD OFF OF 9 5/8" MANDREL HANGER AND 8' OF 9 5/8" X 20" CONDUCTOR ANNULUS. CONTACT TOWN ON PLAN FORWARD. MOBILIZE NABOBS AND GBR WELDER TO PREPARE AND CUT CONDUCTOR TO ADJUST LANDING RING HEIGHT. WORK WITH FMC ON HEIGHT MEASUREMENTS AND PLAN FORWARD. 20:00 - 22:00 2.00 WHSUR N STUC SURF MAKE UP LANDING JOINT TO 9 5/8" MANDREL HANGER. PULL 17.5" OF STRETCH ON 9 5/8" SURFACE CASING WITH PUW 420K LBS. PREPARE CONDUCTOR CASING FOR CUT BY CENTERING UP 9 5/8" CASING IN CONDUCTOR. CUT 19" OFF OF 20" CONDUCTOR. 22:00 - 00:00 2.00 WHSUR N STUC SURF PJSM WITH GBR ON WELDING LANDING RING TO CONDUCTOR. PREPARE CONDUCTOR AND LANDING RING FOR WELDING. 12/4/2009 00:00 - 03:30 3.50 WHSUR N STUC SURF WELD LANDING RING TO 20" CONDUCTOR. 03:30 - 05:30 2.00 WHSUR N STUC SURF PJSM WITH FMC ON INSTALLING EMERGENCY SLIPS. INSTALL EMERGENCY SLIPS ON 9 5/8" CASING WITH 390K LBS DOWN WEIGHT. PREPARE CELLAR AND CASING FOR CUT WITH WACHS CUTTER. CUT 9 5/8" CASING RIGHT BELOW COLLAR OF LAST 9 5/8" JOINT RUN. 05:30 - 08:30 3.00 WHSUR N STUC SURF RD 9 5/8" LANDING JOINT AND 350 TON ELEVATORS. CHANGE OUT TO SHORT BAILES WHILE NU SLIP-LOC CASING HEAD AND TUBING SPOOL. MAKE UP SLIP LOCK STUDS TO 350 FT-LBS. TEST THE FS SEAL IN THE SLIP-LOC HEAD TO 900 PSI FOR 15 MINUTES -GOOD TEST. 08:30 - 12:00 3.50 BOPSU P SURF SECURE BRIDGE CRANES TO BOP. REMOVE PEDESTAL rnnteo: iu~rueuua ts:ao:saHm • • BP AMERICA Page 12 of 27 Operations Summary Reporrt Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRI LLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 12/4/2009 08:30 - 12:00 3.50 BOPSU P SURF BOLTS AND PLACE BOP ON TUBING SPOOL. NEED TO ORIENT BOP ADAPTER FLANGE. BREAK CONNECTION BETWEEN BOP LOWER RAMS AND ADAPTER FLANGE, ORIENT ADAPTER FLANGE AND SET BOP ON TUBING SPOOL. 12:00 - 18:30 6.50 BOPSU P SURF MU UPPER AND LOWER WORKING VALVES, TORQUE ADAPTER FLANGE, TUBING AND SLIP-LOC CASING SPOOL. NEED TO ADD LENGTH TO RISER. SIMOPS: CHANGE OUT PUMP LINERS TO 5", LOAD 4" DP INTO PIPE SHED. 18:30 - 20:00 1.50 BOPSU P SURF PREPARE CHOKE AND BOP. MU TEST PLUG TO 4" TEST JOINT. FLUSH MUD LINE TO FILL STACK WITH WATER. SIMOPS: ADDING EXTENSION TO RISER. 20:00 - 20:30 0.50 BOPSU P SURF INSTALL RISER AND ADJUST TURNBUCKLES. 20:30 - 21:00 0.50 BOPSU P SURF FILL BOP AND CHOKE WITH WATER. 21:00 - 00:00 3.00 BOPSU P SURF TEST BOP EQUIPMENT WITH 4" TEST JOINT l 250 PSI /HIGH 4000 PSI FOR 5 MINUTES. UNABLE TO ESTABLISH INITIAL FULL BODY TEST. TROUBLESHOOT ALL SURFACE EQUIPMENT AND FOUND HCR KILL VALVE LEAKED. ISOLATE HCR KILL WITH MANUAL KILL VALVE. TEST AGAIN TO 250 PSI LOW AND 4000 PSI HIGH, GOOD. CONTINUE WITH BOP TEST. FOUND LEAK IN API RING BETWEEN VALVE #5 AND #8 IN CHOKE MANIFOLD. TIGHTEN BOLTS IN FLANGE BETWEEN VALVE #5 AND #8, TEST AGAIN TO 250 PSI LOW AND 4000 PSI HIGH, GOOD. ALL TESTS SO FAR HAVE HELD FOR 5 MINUTES TO A LOW 250 PSI /HIGH 4000 PSI. JEFF JONES OF AOGCC WAIVED WITNESS OF TEST. TEST WITNESSED BY WSLS ELI VAZQUEZ, CHRIS KOBUCK AND TOOLPUSHERS BRIAN TIEDEMANN AND SCOTT SIMONSON. 12/5/2009 00:00 - 04:00 4.00 BOPSU P SURF CONTINUE TESTING BOP EQUIPMENT TO 250 PSI LOW / 4000 PSI HIGH. UNABLE TO TEST ANNULAR PREVENTER TO 250 PSI ,~ LOW. ATTEMPT HIGHER TESTING PRESSURES: 300 PSI, 350 PSI AND 380 PSI WITH NO SUCCESS. WORK THE TEST JOINT TO ALLOW FOR BETTER PLACEMENT INSIDE THE BAG. LOW TEST SHOWING BETTER STABILIZATION TRENDS BUT NOT GOOD. ATTEMPT TO TEST ANNULAR PREVENTER TO 3500 PSI HIGH, NO SUCCESS. JEFF JONES OF AOGCC WAIVED WITNESS OF TEST. TEST WITNESSED BY WELL SITE LEADERS ELI VAZQUEZ, CHRIS KOBUCK AND TOOLPUSHERS BRIAN TIEDEMANN AND SCOTT SIMONSON. Printetl: 12/Z8/2W9 t3:4ti:;iy Ann Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 12/5/2009 04:00 - 04:30 0.50 BOPSU P SURF PULL TEST PLUG, BLOW DOWN ALL LINES AND CHOKE MANIFOLD. 04:30 - 18:30 14.00 BOPSU N WAIT SURF SHUT DOWN TO ALLOW ALL RIG PERSONNEL TO ATTEND "CHECK SIX" INTRODUCTION WORKSHOP. 18:30 - 19:00 0.50 BOPSU N WAIT SURF PRE TOUR MEETING WITH CREWS RETURNING FROM "CHECK SIX" INTRODUCTION WORKSHOP. 19:00 - 20:00 1.00 BOPSU N SFAL SURF PULL RISER, CHANGE OUT LEAKING AIR BOOT. INSTALL RISER. 20:00 - 22:30 2.50 BOPSU P SURF CONTINUE TESTING BOP EQUIPMENT AS FOLLOWS: TEST #11: ANNULAR PR_EVENTER TO 250 PSI LOW AND P I HI TEST #12: HCR KILL, CHOKE VALVES #12 & #13 SHEAR RAMS FAILED. DRAIN STACK TO RAM LOCATION, RE-TEST TO VERIFY LEAK LOCATION FOR REPAIRS. Legal Well Name: V-224 BP AMERICA Page 13 of 27 Operations Summary Report ALL BOP EQUIPMENT WAS TESTED WITH 4" TEST JOINT TO A LOW 250 PSI /HIGH 4000 PSI. ANNULAR PREVENTER TEST TO A 250 PSI LOW / 3500 PSI HIGH. EACH TEST HELD FOR 5 MINUTES EXCEPT FOR THE SHEAR RAMS. ~ > 22:30 - 23:30 1.00 23:30 - 00:00 0.50 12/6/2009 00:00 - 04:00 4.00 P SURF N SFAL SURF N (SFAL ISURF 04:00 - 05:00 1.00 BOPSU P 05:00 - 05:30 0.50 DRILL P 05:30 - 08:00 2.50 DRILL P SURF PROD1 PROD1 JEFF JONES OF AOGCC WAIVED W ITNESS OF TEST. TEST WITNESSED BY WELL SITE LEADERS ELI VAZQUEZ, CHRIS KOBUCK AND TOOLPUSHERS BRIAN TIEDEMANN AND SCOTT SIMONSON. LD 4" TEST TOOL JOINT. DRAIN STACK. BLOW DOWN CHOKE AND KILL LINES. PSJM ON CHANGING OUT RAMS. MOVE BLIND RAMS IN CELLAR. CHANGE OUT SHEAR RAMS TO BLIND RAMS. PRESSURE TEST BLIND RAMS TO 250 PSI LOW / 4000 PSI HIGH. TEST WITNESSED BY WSL CHRIS KOBUCK AND TOOLPUSHER BRIAN TIEDEMANN. JEFF JONES OF AOGCC WAIVED WITNESS OF TEST. PULL TEST PLUG AND LD 4" TEST TOOL JOINT. INSTALL 10" ID WEAR RING AND RILDS TO SECURE WEAR RING IN PLACE. EXPEDITE PRODUCTION DRILLING BHA #4 COMPONENTS UP THE BEAVER SLIDE TO THE RIG FLOOR. PJSM ON PICKING UP DRILLING BHA. MU 8 3/4" PRODUCTION DRILLING BHA #4 AS FOLLOWS: 08:00 - 18:00 10.00 DRILL I P 8 3/4" QD505X HUGHES BIT, 6 3/4" 1.5 DEG BENT MUD MOTOR, 8 5/8" STABILIZER, ARC, MWD, ADN, 7" NM DC, 8 1/2" STABILIZER, 7" NM DC, 1 JT 5" HWDP, HYDRAULIC JARS, 1 JT 5" HWDP, BAKER CIRC SUB. PRODi RIH WITH 8 3/4" DRILLING BHA #4 ON 4" DP PICKED OUT OF PIPE SHED ONE BY ONE FROM 295' MD TO 1254' MD. SHALLOW TEST MWD AT 450 GPM WITH 1004 PSI. Printed: 12/28/2009 8:46:39 AM BP AMERICA Page 14 of 27 Operations Summary Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 12/6/2009 08:00 - 18:00 10.00 DRILL P PROD1 CONTINUE TO RIH WITH 8 3/4" DRILLING BHA #4 ON 4" DP SINGLES FROM 1254' MD TO 1523' MD. PICK UP AND PLACE 8 3/4" GHOST REAMER AND PLACE AT 1530' MD BEHIND BIT. CONTINUE TO RIH FROM 1530' MDTO 4765' MD ON 4" DP SINGLES. NOTE: ROTATE BIT, BOTH STABILIZERS AND 8 3/4" GHOST WHEN EACH OF THEM PASSED THROUGH TAM PORT COLLAR AT 650' MD. PRESSURE TEST TAM PORT COLLAR TO 1000 PSI, GOOD. CONDUCT AFTER ACTION REVIEW ON RIH. 18:00 - 19:00 1.00 DRILL P PROD1 SERVICE TOP DRIVE, DRAWWORKS AND CROWN. 19:00 - 21:00 2.00 DRILL P PROD1 CUT AND SLIP 85' OF DRILL LINE. CONDUCT AFTER ACTION REVIEW ON CUT AND SLIP DRILL LINE. 21:00 - 22:30 1.50 DRILL P PROD1 PRESSURE TEST 9 5/8" SURFACE CASING TO 3500 PSI FOR 30 CHARTED MINUTES -GOOD TEST WITH ZERO BLEED OFF. 22:30 - 23:30 1.00 DRILL P PROD1 CONTINUE TO RIH WITH 8 3/4" DRILLING BHA #4 ON 4" DP FROM 4765' MD TO 5174' MD. INSTALL BLOWER HOSE. WASH DOWN FROM 5174' MD TO 5200' MD AT 452 GPM WITH 2074 PSI WHILE ROTATING AT 40 RPM WITH 8.5K FT-LBS TORQUE. MW IN /OUT 9.2 PPG DRILPLEX. 12/7/2009 00:00 - 00:30 0.50 DRILL P PROD1 CONTINUE TO WASH DOWN FROM 5200' MD TO 5383' MD AT 450 GPM WITH 2017 PSI. TAGGED FLOAT COLLAR RIGHT ON DEPTH AT 5383' MD. ROTW 85K, 8.7K FT-LBS TORQUE AND 41 RPM. MW IN /OUT 9.2 PPG DRILPLEX. 00:30 - 02:00 1.50 DRILL P PROD1 DRILL CEMENT AND SHOE TRACK FROM 5383' MD TO 5460' MD (7' ABOVE BOTTOM OF 9 5/8" FLOAT SHOE) WITH THE FOLLOWING PARAMETERS: - 450 GPM WITH 2020 PSI OFF, 2137 PSI ON -ROTATING AT 40 RPM W ITH 10.8K FT-LBS TQ ON, 9.1 K FT-LBS TQ ON - 5K WOB, ROP -150 FPH NOTE: SURFACE PRESSURE INCREASED BY -80 PSI AT 5450' MD FOLLOWED BY AN INCREASE IN TORQUE OF 7.3K FT-LBS, PULLED UP WITH -70K LBS OVERPULL. PRESSURE STARTED TO GO DOWN FROM AN INITIAL 2173 PSI (WHILE DRILLING CEMENT) TO A FINAL 1353 PSI (BEGIN OF MUD SWAP TO 8.8 PPG LSND). MW IN /OUT 9.2 PPG DRILPLEX 02:00 - 03:00 1.00 DRILL P PROD1 I PLACE WELLB RE FROM 9.2 PPG DRILPLEX TO 8.8 PPG LSND AT 450 GPM WITH 1200 PSI WHILE RECIPROCATING DRILL STRING IN 90' STROKES. MW IN /OUT 8.8 PPG LSND Printetl: 12/28/2009 8:46:39 AM • BP A'MERfCA 'Page 15 of 27 Operatiolns Summary Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of :Operations 12/7/2009 03:00 - 03:30 0.50 DRILL P PROD1 DRILL REMAINDER OF SHOE TRACK FROM 5460' MD TO 5467' MD. TAG 9 5/8" FLOAT SHOE RIGHT ON DEPTH AT 5467' MD AND CONTINUE TO DRILL CEMENT TO BOTTOM AT 5481' MD. DRILL 20' OF NEW FORMATION TO 5501' MD. - 453 GPM, 1191 PSI OFF, 1266 PSI ON - 5K WOB, 40 RPM, 7.7K TORQUE OFF, 8.1 K TORQUE ON - PUW 145K, SOW 70K, ROTW 85K 03:30 - 04:00 0.50 DRILL P PROD1 CIRCULATE ONE BOTTOMS UP AT 453 GPM WITH 1200 PSI WHILE RECIPROCATING PIPE IN 40' STROKES AND ROTATING AT 40 RPM WITH 7.4K FT-LBS TORQUE. MW IN /OUT 8.8 PPG LSND 04:00 - 04:30 0.50 DRILL P PROD1 PULL BACK INSIDE 9 5/8" CASING SHOE AT 5460' MD. CONDUCT LOT: MW 8.8 PPG 3063' TVD, DEVIATE FROM STRAIGHT LINE AT 793 SURFACE PSI EMW 13.78 PPG. 04:30 - 12:00 7.50 DRILL P PROD1 DRILL AHEAD IN 8 3/4" HOLE FROM 5501' MD TO 6607' MD. - PUMP AT 585 GPM WITH 2050 PSI OFF, 2120 PSI ON - 100 RPM, 7K-8K TORQUE OFF, 8K-9K TORQUE ON -ART 2.5 HRS, AST 0.63 HRS, ADT 3.13 HRS, BIT 3.13 HRS - PUW 135K, SOW 68K, ROTW 96K, WOB 10K - 15K -ADD H2O AT 30 BPH - MW IN /OUT 8.8 PPG - NO FLUID LOSS NOTED - BACKREAM FULL STANDS BEFORE CONNECTION AT 60 RPM, REDUCE PUMP RATE IN DOWN STROKE TO 450 GPM. - CAL ECD 9.44 PPG, ACT ECD 9.84 PPG PUMP 45 BBL HIGH VIS SWEEP (FLOWZAN AT 3 PPB) AT 6300' MD. 50% INCREASE IN CUTTINGS WITH RETURN OF SWEEP, MOSTLY SAND (80%) AND CLAY (20%). ADD LOTORO TO INCREASE LUBRICITY CONCENTRATION TO 0.5% VN. 12:00 - 00:00 12.00 DRILL P PRODi DRILL AHEAD IN 8 3/4" HOLE FROM 6607' MD TO 7946' MD. - PUMP AT 585 GPM WITH 2705 PSI OFF, 2840 PSI ON - 100 RPM, 10K TORQUE OFF, 11 K TORQUE ON -ART 3.0 HRS, AST 3.2 HRS, ADT 6.2 HRS, BIT 9.33 HRS - PUW 154K, SOW 74K, ROTW 104K, WOB 17K - 25K - ADD H2O AT 30 BPH - MW IN /OUT 8.9 PPG - NO FLUID LOSS NOTED - BACKREAM FULL STANDS BEFORE CONNECTION AT 60 RPM, REDUCE PUMP RATE IN DOWN STROKE TO 450 GPM. - CAL ECD 9.32 PPG, ACT ECD 10.04 PPG PUMP 45 BBL HIGH VIS SWEEP (FLOWZAN AT 3 PPB) AT 7050' MD. 30% INCREASE IN CUTTINGS WITH RETURN OF SWEEP. INCREASE ADD LOTORO TO INCREASE LUBRICITY CONCENTRATION TO 1.5% VN. I,6~ rnrnea: iucacu~a o.ro.ua caul BP AMERJCA Page 16 of 27 Operations Summary Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 12/8/2009 00:00 - 12:00 12.00 DRILL P PRODi DRILL AHEAD IN 8 3/4" HOLE FROM 7946' MD TO 9092' MD. - PUMP AT 585 GPM WITH 2840 PSI OFF, 3010 PSI ON - 100 RPM, 9.8K TORQUE OFF, 10.4K TORQUE ON - ART 3.73 HRS, AST 2.43 HRS, ADT 6.16 HRS, BIT 15.49 HRS - PUW 176K, SOW 76K, ROTW 111 K, WOB 7K-25K -ADD H2O AT 30 BPH - MW IN /OUT 9.0 PPG - NO FLUID LOSS NOTED - BACKREAM FULL STANDS BEFORE CONNECTION AT 60 RPM, REDUCE PUMP RATE IN DOWN STROKE TO 450 GPM. - CAL ECD 9.5 PPG, ACT ECD 10.01 PPG PUMP 3RD 4566E HIGH VIS SWEEP (FLOWZAN AT 3 PPB) AT 8090' MD, 15% INCREASE IN CUTTINGS WITH RETURN OF SWEEP. 12:00 - 19:30 7.50 DRILL P PROD1 ILL AHEAD IN 8 3/4" HOLE FROM 9092' MD TO •~ PRODUCTION HOLE TD AT 9960' MD. - PUMP AT 585 GPM WITH 3482 PSI OFF, 3570 PSI ON - 100 RPM, 9.6K TORQUE OFF, 10.2K TORQUE ON - ART 5.33 HRS, AST 0.0 HRS, ADT 5.33 HRS, BIT 20.82 HRS - PUW 180K, SOW 97K, ROTW 127K, WOB 25K - ADD H2O AT 30 BPH - MW IN /OUT 9.1 PPG - NO FLUID LOSS NOTED - BACKREAM FULL STANDS BEFORE CONNECTION AT 60 RPM, REDUCE PUMP RATE IN DOWN STROKE TO 450 GPM. - CAL ECD 9.35 PPG, ACT ECD 10.17 PPG PUMP 4RD HIGH VIS SWEEP AT 9933' MD, NO SIGNIFICANT INCREASE IN CUTTINGS WITH RETURN OF SWEEP. 19:30 - 00:00 I 4.501 DRILL I P PROD1 MONITOR WELL -STATIC. 12/9/2009 100:00 - 02:00 2.00 DRILL ~ P WITH THE FOLLOWING PARAMETERS: - 580 GPM, 3412 PSI - 100 RPM, 9.8K - 10.2K FT-LBS TORQUE - PUW 190K & SOW 102K WHILE PUMPING - ROTW 123K - MW IN /OUT 9.2 PPG - CALC ECD 9.34 PPG, ACTUAL MAX ECD NOTED WHILE BACKREAMING 10.42 PPG. ADJUST BACKREAM SPEED TO PREVENT ACTUAL ECD FROM REACHING 1.25 PPG OVER CALCULATED. PROD1 CONTINUE TO BACKREAM OUT OF THE HOLE FROM 8000' MD TO 6998' MD (8 3/4" GHOST REAMER INSIDE 9 5/8" CASING SHOE) WITH FOLLOWING PARAMETERS: - 587 GPM, 2746 PSI - 100 RPM, 7.4K FT-LBS TORQUE, ROTW 96K t'nnted: iu~w~uua °:a°:sa Nrvi BP AMERICA. Page 17 of 27 Operations Summary Report.. Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 12/9/2009 00:00 - 02:00 2.00 DRILL P PROD1 - MW IN /OUT 9.2 PPG 02:00 - 03:30 1.50 DRILL P PROD1 POH FROM 6998' MD TO 6810' MD WHILE PUMPING AT 586 GPM WITH 2683 PSI. TOTAL OF 2 BOTTOMS UP CIRCULATED, SHAKERS CLEAN UP CONSIDERABLY AFTER 2 BOTTOMS UP. - PUW 125K WHILE PUMPING OUT - MW IN /OUT 9.2 PPG - CALC ECD 9.8 PPG, ACTUAL ECD 10.0 PPG PRIOR TO POH ON ELEVATORS 03:30 - 09:00 5.50 DRILL P PROD1 BLOW DOWN TOP DRIVE AND POH ON ELEVATORS FROM 6810' MD TO 5460' MD (INSIDE 9 5/8" CASING SHOE). - PUW 137K, SOW 78 - MW IN /OUT 9.2 PPG - MONITOR WELL -STATIC PUMP DRY JOB, BLOW DOWN TOP DRIVE AND CONTINUE TO POH FROM 5460' MD TO 1544' MD. LD 8 3/4" GHOST REAMER. 8 3/4" GHOST REAMER 1/16" UNDER GAUGE. CONTINUE TO POH FROM 1544' MD TO 295' MD. MW IN /OUT 9.1 PPG. 09:00 - 13:00 4.00 DRILL P PROD1 LD PRODUCTION DRILLING BHA #4. BIT 1/8" UNDERGAUGE WITH FOLLOWING GRADE: 2-6-BT-T-X-2-CT-TD. NM 8 5/8" STABILIZER ABOVE MOTOR 3/16" UNDER GAUGE. NM 8 1/2" STABILIZER IN GAUGE. 13:00 - 13:30 0.50 DRILL P PROD1 CLEAN AND CLEAR RIG FLOOR OF BHA HANDLING EQUIPMENT. ~- 13:30 - 17:00 3.50 BOPSU P RUNPRD FLUSH BOP STACK. PULL WEAR RING. INSTALL TEST PLUG. CHANGE OUT UPPER VARIABLE RAMS FROM 3 1/2" X 6" TO 7" RAMS. PRESSURE TEST 7" RAMS TO 250 PSI LOW / 4000 PSI HIGH WITH 7" TEST JOINT FOR 5 CHARTED MINUTES EACH TEST. TEST WITNESSED BY WSL JOEY LEBLANC AND TOOL PUSHER BILL BIXBY. RD TESTING EQUIPMENT. 17:00 - 21:00 4.00 CASE P RUNPRD PJSM FOR RIGGING UP TO RUN 7" PRODUCTION MAKE DUMMY RUN WITH 7" CASING MANDREL HANGER AND CONFIRM RKB ELEVATION OF 26.40'. FILL BOP STACK. EXPEDITE CASING RUNNING EQUIPMENT AND CENTRALIZERS TO RIG FLOOR. RU TO RUN 7" 26# L-80 BTC-M / TCII PRODUCTION LONGSTRING. CHANGE OUT BAILES. MU FLOOR VALVE CROSS OVER. 21:00 - 23:00 2.00 CASE P RUNPRD PJSM FOR RUNNING 7" PRODUCTION LONGSTRING. MU 7" 26# L-80 BTC-M PRODUCTION CASING FLOAT SHOE ~~1 rnntea: iruzwzuua C:463`J HM ~ ~ BP AMERLGA Page 18 of 27 Operations Summary Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours. Task Code NPT Phase Description of Operations 12/9/2009 21:00 - 23:00 2.00 CASE P RUNPRD (JOINT #1) TO JOINT #2 WITH 8,400 FT-LBS TORQUE AND BAKER-LOK. RIH WITH JOINTS #1 AND #2, DRAWWORKS STOPPED WORKING WITH -15' OF JOINT #2 ABOVE ROTARY. THE PARKING BREAK ON THE DRAWWORKS DISK BRAKE BECAME SUDDENLY ENGAGED. 23:00 - 00:00 1.00 CASE N SFAL RUNPRD MOBILIZE RIG MECHANIC. INSPECT DRAWWORKS. FUNCTION THE PARKING BRAKE, DISENGAGE PARKING BRAKE. 12/10/2009 00:00 - 01:00 1.00 CASE P RUNPRD MU JOINT #3 (FLOAT COLLAR ON PIN END) TO JOINT #2 WITH 8,400 FT-LBS TORQUE AND BAKER-LOK. FILL PIPE IN PREPARATION TO CHECK FLOATS. PACKER CUP ASSEMBLY IN FRANKS FILL UP TOOL NOT SEALING. 01:00 - 02:00 1.00 CASE N SFAL RUNPRD STOP CIRCULATING, PICK UP FRANKS FILL UP TOOL OUT OF JOINT #3, INSPECT PACKER CUP. 02:00 - 16:00 14.001 CASE P LD FRANKS FILL UP TOOL, CHANGE OUT PACKER CUP FOR LARGER O.D. CUP. MU FRANK'S FILL UP TOOL. RUNPRD RUN IN THE HOLE WITH 73 JOINTS OF 7" 26# L-80 BTC-M FROM 127' MD TO 2955' MD. TORQUE EACH CONNECTION TO MARK WITH AN AVERAGE TORQUE OF 8400 FT-LBS. FILL EVERY JOINT USING THE FRANK'S FILL UP TOOL AND CIRCULATE EVERY 10TH JOINT AT 5 BPM WITH 337 PSI. MAKE UP TC-II X BTC-M CROSS OVER. CONTINUE TO RUN IN THE HOLE WITH 7" 26# L-80 TC-II FROM 2955' MD TO 5205' MD. TORQUE TURN EACH CONNECTION TO 10,100 FT-LBS. FILLED EVERY JOINT USING THE FRANK'S FILL UP TOOL AND CIRCULATE EVERY 10TH JOINT AT 5 BPM WITH 437 PSI. MW IN 9.1 PPG /OUT 9.2 PPG NO FLUID LOSS NOTED 16:00 - 18:30 2.50 CASE N SFAL RUNPRD LOST COMMUNICATION TO THE LOAD CELL WHILE MAKING UP JOINT #55 TO JOINT #54. BREAK OUT THE CONNECTION, COLLAR OF JOINT #54 SPUN. HOLD PJSM TO DISCUSS PLAN FORWARD. USE RIG TONGS TO HOLD COLLAR OF JOINT #54, BREAK OUT JOINT #55 WITH POWER TONGS. PUT RIG TONGS AWAY. CHANGE OUT LOAD CELL. ENERGIZE TONGS. HYDRAULIC PRESSURE PROBLEM WITH POWER TONGS (UNRELATED TO PREVIOUS PROBLEM). TROUBLE SHOOT COMPUTER SYSTEM, CHANGE OUT ENTIRE TORQUE TURN EQUIPMENT. 18:30 - 20:00 1.50 CASE P RUNPRD CONTINUE TO RUN IN THE HOLE WITH 7" 26# L-80 TC-II FROM 5205' MD TO 5446' MD (INSIDE 9 5/8" CASING SHOE), TORQUE TURN EACH CONNECTION TO 10,100 FT-LBS. FILLED EVERY JOINT USING THE FRANK'S FILL U P. 20:00 - 21:30 1.50 CASE P RUNPRD CIRCULATE TWO ANNULAR VOLUME AT 6 BPM BY STAGING UP PUMPS AS FOLLOWS: Printed: 12/28/2009 8:46:39 AM BP AMERICA Page 19 of 27 Operations Summary Report Legal Well Name: V-224 Common WeII Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 12/10/2009 120:00 - 21:30 1.501 CASE P RUNPRD 3 BPM 270 PSI 3.5 BPM 329 PSI 4 BPM 356 PSI 5 BPM 425 PSI 6 BPM 520 PSI INITIAL 6 BPM 473 PSI FINAL FULL RETURNS THROUGHOUT ENTIRE CIRCULATION AT 9 5/8" CASING SHOE. PUW 147K, SOW 81 K AT 5446' MD. MW IN /OUT 9.2 PPG. MONITOR WELL -STATIC. SIMOPS: REMOVE ICE BUILD UP FROM DERRICK. FOUND AND REMOVED CRACKED MOUNTING BRAKET FOR LIGHT IN DERRICK. 21:30 - 00:00 2.50 CASE P RUNPRD CONTINUE TO RUN 7" BTC-M /TCII PRODUCTION LONGSTRING IN OPEN HOLE FROM 5446' MD TO 6537' MD AT 3 MINUTES/JOINT SLIPS TO SLIPS. FILL EVERY JOINT USING THE FRANK'S FILL UP TOOL AND CIRCULATE DOWN EVERY 5TH JOINT AT 5 BPM WITH 525 PSI. TORQUE TURN EACH CONNECTION TO 10,100 FT-LBS. 12/11/2009 00:00 - 09:30 9.50 ~ CASE ~ P MW IN /OUT 9.2 PPG NO FLUID LOSS NOTED. RUNPRD CONTINUE TO RUN 7" BTC-M /TCII PRODUCTION LONGSTRING I 57' MD TO 8000' MD AT 3 MINUTES/JOINT SLIPS TO SLIPS. FILL EVERY JOINT USING THE FRANK'S FILL UP TOOL AND CIRCULATE DOWN EVERY 5TH JOINT FROM 6357' MD TO 8266' MD AT 5 BPM WITH 570 PSI. TORQUE TURN EACH'CONN~CTION TO 10,100 FT-LBS. .t," LATE DOWN EVERY 10TH JOINT FROM 8266' MD TO 09:30 - 10:15 I 0.751 CEMT I P 10:15 - 13:30 I 3.251 CEMT I P 8674' MD AT 5 BPM WITH 560 PSI. FILL EVERY JOINT USING THE FRANK'S FILL UP TOOL. TORQUE TURN EACH CONNECTION TO 10,100 FT-LBS. LOST 10K DOWN WEIGHT AND DEVIATE FROM I-CENTER DRAG PLOT AT 8674' MD. BEGIN TO WASH DOWN EVERY 5TH JOINT FROM 8674' MD TO 9922' MD AT 5 BPM WITH 585 PSI. MW IN /OUT 9.2 PPG NO FLUID LOSS NOTED. RUNPRD PICK UP THE 7" MANDREL HANGER AND LANDING JOINT ANI~ RI IN T(7 R(~TT~M AT 9951' MD. RD CASING RUNNING EQUIPMENT. RU CEMENT HEAD. PUW 290K, SOW 90K. RUNPRD CIRCULATE FOR CEMENT JOB BY STAGING PUMPS UP AS FOLLOWS: 2 BPM WITH 380 PSI Printstl: 1L/1tl/LUUy 1f:4ti::7y HM BP AMERICA Page 20 of 27 Operations Summary Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 12/11/2009 10:15 - 13:30 3.25 CEMT P RUNPRD 3 BPM WITH 440 PSI 4 BPM WITH 506 PSI 5 BPM WITH 597 PSI 6 BPM WITH 695 PSI 7 BPM WITH INITIAL CIRC PRESSURE OF 796 PSI, FINAL CIRC PRESSURE OF 687 PSI TOTAL OF 4 BOTTOMS UP CIRCULATED. CLEAN RETURNS WITH BOTTOMS UP. ENTIRE WHILE PUMPING AT 7 BPM WITH 720 PSI AND FULL RETURNS. 13:30 - 16:30 3.00 CEMT P RUNPRD PJSM WITH SLB CEMENTERS, TRUCK PUSHER, CREWS, MUD ENGINEER, TOOL PUSHERS AND WSL FOR CEMENT JOB. CEMENT 7" PRODUCTION CASING WHILE RECIPROCATING CASING 10' - 15' STROKES EXCEPT BRIEFLY AS EACH SLURRY WENT AROUND THE SHOE AS FOLLOWS 13:15 START BATCH MIXING TAIL CEMENT 13:24 CEMENT AT 15.8 PPG WEIGHT 13:25 PUMP 5 BBL 10.0 PPG MUD PUSH II TEST LINES TO 4500 PSI -GOOD. 13:40 PUMP 25 BBL 10.0 PPG MUD PUSH II AT 3.1 BPM WITH 215 PSI (CASING LANDED) 13:40 DROP BOTTOM PLUG; GOOD INDICATION THAT PLUG LEFT HEAD. START PUMPING 11.0 PPG LEAD CEMENT AT 5 BPM 13:49 19 BBL LEAD CEMENT AWAY, 5.0 BPM, 339 PSI 13:55 51 BBL LEAD CEMENT AWAY, 5.0 BPM, 252 PSI SWAP OVER TO 15.8 PPG TAIL 14:07 48 BBL TAIL CEMENT AWAY, 5.0 BPM, 105 PSI 14:13 74 BBL TAIL CEMENT AWAY, 5.0 BPM, 0 PSI 14:18 LAND CASING. DROP TOP PLUG; KICK OUT WITH 9.0 PPG BRINE; POSITIVE INDICATION THAT PLUG LEFT HEAD. ISOLATE SCHLUMBERGER AND DISPLACE WITH RIG PUMPS, 9.0 PPG BRINE. 14:33 36 BBL BRINE, 5 BPM, 75 PSI 14:44 117 BBL BRINE, 5 BPM, 190 PSI 14:56 175 BBL BRINE, 5 BPM, 180 PSI 15:08 233 BBL BRINE, 5 BPM, 180 PSI 15:20 292 BBL BRINE, 5 BPM, 610 PSI 15:27 321 BBL BRINE, 5 BPM, 940 PSI 15:27 SLOW DOWN TO 2 BPM 15:27 331 BBL BRINE, 2 BPM, 808 PSI 15:35 345 BBL BRINE, 2 BPM, 952 PSI rnrnea: iucac~~y o:vo.o~ruw BP AMERICA Page 21 of 27 Operations Summary Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 12/11/2009 13:30 - 16:30 3.001 CEMT ~ P ~ ~ RUNPRD LOST ALL DOWN WEIGHT (~15K LBS), WITH 7" MANDREL HANGER 7.5' ABOVE LANDING RING. WORK PIPE, APPEARS FREE ON UPSTROKE, UNABLE TO LAND.7" MANDREL HANGER ON RING. PLUG BUMP AT 6515 STROKES, 380 BBL DISPLACED. FINAL PUMP PRESSURE AT BUMP 1500 PSI AND HELD FOR 2 MINUTES. PRESSURE UP TO 4000 PSI FOR 30 CHARTED MINUTES: LOST 60 PSI DURING FIRST 15 MINTUES AND 40 PSI DURING LAST 15 MINUTES.. CEMENT IN PLACE AT 15:50 HRS. CHECK FLOATS -HOLDING. NO FLUID LOST TO FORMATION. FULL RETURNS THROUGHOUT JOB. CEMENT JOB VOLUME: 51 BBLS 11.0 PPG LITE CRETE PUMPED; 156 SACKS AT 1.83 CUFT/SX 74 BBLS 15.8 PPG CLASS G TAIL PUMPED; 356 SACKS AT 1.17 CUFT/SX _ LEAD COMPRESSIVE STRENGTH: 500 PSI: 14:35 HRS 1000 PSI: 19:34 HRS 6:30 - 17:30 17:30 - 18:00 .00 0.50 EMT CASE P P UNPRD RUNPRD TAIL COMPRESSIVE STRENGTH: 500 PSI: 11:47 HRS 1000 PSI: 13:13 HRS BLEED DOWN CEMENT LINE, CHECK FLOATS -HOLDING. ~,INE UP ON 9 5/8" X 7" OUTER ANNULUS. CLOSE ANNULAR AND PERFORM LOT TO CONFIRM ANNULAR, INJECTIVITY. FORMATION LEAK OFF AT EMW OF 15.8 PPG WITH 1060 SURFACE PSI, 3063' TVD AND 9.1 PPG LSND. INJECT 3 BBLS OF 9.1 PPG LSND AT 1060 PSI. 18:00 - 19:30 1.50 CASE P RUNPRD CONSULT WITH TOWN ON PLAN FORWARD. INJECT 15 BBLS 9.1 PPG LSND IN 9 5/8" X 7" ANNULUS WITH A MAXIMUM INJECTION PRESSURE OF 1160 PSI. BLEED OFF PRESSURE AND BEGIN TO MONITOR WELL. 19:30 - 23:30 4.00 CASE P RUNPRD MONITOR WELL FOR ESTIMATED TIME REQUIRED TO NIPPLE DOWN BOP AND INSTALL SLIPS, PACK OFF AND NU. WELL STATIC. BASED ON UCA, LEAD CEMENT REACHES 100 BC AT 20:30 HRS. SIMOPS OUT OF CRITICAL PATH: CHANGE OUT CLIPPERS SEALS AND SUCTION POD ON MUD PUMP #2. RIG DOWN CEMENT HEAD, CLEAN ALL PITS EXCEPT PIT #1 (WHICH CONTAINS LSND TO BE USED FOR OA INJECTION). 23:30 - 00:00 0.50 CASE P RUNPRD PERFORM PJSM ON SPLITTING THE STACK AND WELL HEAD WORK. PREPARE CELLAR AND RIG FLOOR TO r31. p ~ M~ r,ot ~.~„ 3~ YfIfIt00: 7L/Ltf/LUU`J C:4b:J`J HM i BP AMERICA Page 22 of 27 Operations. Summary Report -- Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date. From - To Hours Task Code NPT Phase Description of`Operations 12/11/2009 23:30 - 00:00 0.50 CASE P RUNPRD SPLIT STACK. , 12/12/2009 00:00 - 01:00 1.00 WHSUR P RUNPRD MONITOR WELL -STATIC. DRAIN THE BOP STACK AND LANDING JOINT. 01:00 - 05:30 4.50 WHSUR P RUNPRD PJSM WITH FMC ON INSTALLING EMERGENCY SLIPS. SPLIT STACK. INSTALL EMERGENCY SLIPS ON 7" CASING WITH 100K LBS DOWN WEIGHT. PREPARE CELLAR AND CASING FOR CUT WITH WACHS CUTTER. CUT 4.62' OF 7" 26# L-80 TCII CASING JOINT #171 A FMC. RKB TO TOP OF 7" TCII CASING STUMP: 26.27' MD. SIMOPS: BREAK OUT AND LD CEMENT HEAD, FINISH TO CLEAR AND CLEAN RIG FLOOR OF ALL CEMENTING AND CASING RUNNING EQUIPMENT. 05:30 - 07:00 1.50 WHSUR P RUNPRD NU BOP STACK. 07:00 - 09:00 2.00 WHSUR P RUNPRD PJSM ON INSTALLING 7" PACK OFF WITH FMC. MU LANDING JOINT TO RUNNING TOOL, INSTALL 9 5/8" X 7" PACK OFF. RILDS AND TORQUE TO 450 FT-LBS. CLEAR CELLAR AND TEST PACK OFF TO 4300 PSI FOR 30 MINUTES, GOOD TEST. 09:00 - 10:30 1.50 BOPSU P OTHCMP CHANGE UPPER RAMS FROM 7" TO 3 1/2" X 6" VARIABLES. SIMOPS: PICK UP PERF GUNS RUNNING EQUIPMENT. LOAD PERF GUNS INTO PIPE SHED. 10:30 - 11:00 0.50 BOPSU P OTHCMP PICK UP 3 1/2" AND 4" TEST JOINT ASSEMBLIES. 11:00 - 13:00 2.00 BOPSU P OTHCMP 1/2" X 6" VARIABLE RAMS TO 250 PSI LOW / 4000 PSI HIGH WITH 3 1/2" AND 4" TEST JOINT. EACH TEST HELD FOR 5 MINUTES. TEST WITNESSED BY TOOL PUSHER BILL BIXBY AND WSL DICK MASKELL. RD TEST EQUIPMENT. 13:00 - 14:00 1.00 WHSUR P RUNPRD INSTALL 9 1/16" I.D. WEAR BUSHING. PJSM WITH LRS ON FREEZE PROTECTING OUTER ANNULUS. BULLHEAD 130 BBL OF 9.1 PPG LSND AT 3 BPM WITH 1100 PSI. RU LRHOS TO FREEZE PROTECT OUTER ANNULUS WHILE BULLHEADING DOWN LSND. PRESSURE TEST LINES TO 3500 PSI. PUMP 120 BBLS OF 100 DEG F DEAD CRUDE TO FREEZE PROTECT ~_ 2596' TVD (4251' MD) AS FOLLOWS: START AT 2 BPM WITH INITIAL CIRCULATING PRESSURE OF 1150 PSI 80 BBLS AWAY, 2 BPM, 1300 PSI 120 BBLS AWAY, 2 BPM, 1400 PSI FINAL OUTER ANNULUS: PRESSURE 1400 PSI. RD LRHOS. 14:00 - 15:00 1.00 PERFO P OTHCMP REMOVE ICE BUILD UP FROM DERRICK. 15:00 - 18:00 3.00 PERFO P OTHCMP RU TO RUN PERF GUNS. PJSM WITH SLB PERF CREW. PICK UP 782' OF 4 1/2" 5 SPF 4505PJ PERFORATING Printetl: 12/29/2009 8:46:39 AM Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations BP AMERICA Page 23 of 27 Operations Summary Report 18:00 - 18:30 0.50 PERFO P OTHCMP RIH WITH 782' OF PERFORATING ASSEMBLY ON 4" DP STANDS FROM 782' MD TO 1580' MD. ATTEMPT TO SHALLOW TEST MWD AT 225 GPM WITH 280 PSI - NO GOOD. 18:30 - 19:00 0.50 PERFO P OTHCMP RIH WITH PERFORATING ASSEMBLY ON 4" DP STANDS FROM 1580' MD TO 2180' MD. 19:00 - 19:30 0.50 PERFO P OTHCMP SHALLOW TEST MWD WITH 232 GPM WITH 361 PSI - GOOD. 19:30 - 00:00 4.50 PERFO P OTHCMP RIH WITH PERFORATING ASSEMBLY ON 4" DP STANDS FROM 2180' MD TO 9442' MD. PUW 180K, SOW 80K. 12/13/2009 00:00 - 00:30 0.50 PERFO P OTHCMP CONTINUE TO RIH FROM 9442' MD AND TAGGED FLOAT COLLAR AT 9856' MD (RIGHT ON DEPTH) WITH 10K LBS. PUW 180K, SOW 80K. MW IN /OUT 9.0 PPG BRINE. 00:30 - 03:30 3.00 PERFO P OTHCMP WITH PERFORATING ASSEMBLY ALREADY DEEPER THEN THE DESIRED PERFORATING DEPTH, CORRELATE WITH GAMMA RAY ON MWD TO REAL-TIME DATA ACQUIRED WHILE DRILLING. LOG GUNS ON DEPTH. 03:30 - 04:30 1.00 PERFO P OTHCMP 4 1/2" SCHLUMBERGER POWERJET 4505 5-SPF, 72 DEG PHASING GUNS ON DEPTH AS FOLLOWS WITH REFERENCE TO REAL TIME LWD LOG. TOP (MD) BOTTOM (MD) 8884' 8916' D 9228' 9278' it t ~'~ 9300' 9330' 9490' 9572' 9610' 9652' PJSM WITH SLB PERFORATING CREW. PERFORM A DRY RUN WITH DRILLER AND SLB TO ESTABLISH PUMP RATES. INITIATE FIRING SEQUENCE AS PER SLB PERF SPECIALIST. GOOD INDICATION ON SURFACE THAT GUNS WERE FIRED. LOST 17 BBL OF 9.0 PPG BRINE IMMEDIATELY AFTER GUNS FIRED. 04:30 - 05:00 0.50 PERFO P OTHCMP POH FROM 9652' MD TO 8820' MD (64' ABOVE TOP PERF) TO CLEAR THE BOTTOM OF THE GUNS ABOVE THE UPPERMOST SET OF PERFS. PUW 170K. FLUID LOSS: 28 BBLS OF 9.0 PPG LOST DURING THE FIRST 30 MINUTES AFTER PERFORATING. MW IN /OUT 9.0 PPG BRINE. 05:00 - 06:00 1.00 PERFO P OTHCMP CIRCULATE 1.5 BOTTOMS UP AT 257 GPM WITH 920 PSI. PUW 170K, SOW 70K. FLUID LOSS: 27 BBLS OF 9.0 PPG BRINE LOST WHILE CIRCULATING MW IN /OUT 9.0 PPG BRINE. 06:00 - 16:00 10.00 PERFO P OTHCMP POH WITH PERFORATING ASSEMBLY FROM 8220' MD TO 842' MD WHILE LAYING DOWN 4" DRILL PIPE ONE BY ONE. 12/12/2009 15:00 - 18:00 3.00 PERFO P OTHCMP ASSEMBLY (236' LOADED, 546' BLANK). Printed: 12/28/2009 8:46:39 AM C1 BP AMERICA Page 24 of 27 Operations Summary Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES .Date From - To Hours Task Code ` NPT Phase "`Description of Operations 12/13/2009 06:00 - 16:00 10.00 PERFO P OTHCMP FLUID LOSS: 10 BPH OF 9.0 PPG BRINE. TOTAL FLUID LOSS FOR TOH 139 BBLS BRINE. MW IN /OUT 9.0 PPG BRINE. 16:00 - 21:30 5.50 PERFO P OTHCMP PJSM WITH SLB ON LAYING DOWN PERFORATING ASSEMBLY. 21:30 - 23:00 I 1.50 I EVAL I P 23:00 - 00:00 I 1.00 EVAL P 12/14/2009 00:00 - 01:30 1.501 EVAL P LD PERF GUNS AND CONFIRMED ALL SHOTS FIRED. RD POWER TONGS AND REMOVE SCHLUMBERGER EQUIPMENT FROM RIG FLOOR. CLEAN RIG FLOOR OF GUN RESIDUE. FLUID LOSS: 3 BPH OF 9.0 PPG BRINE. MW IN /OUT 9.0 PPG BRINE. OTHCMP PJSM WITH E-LINE SCHLUMBERGER CREW. RIG UP SCHLUMBERGER E-LINE AND GR/JB ASSEMBLY FLUID LOSS RATE: 3 BPM OF 9.0 PPG BRINE. OTHCMP SLB E-LINE RIH WITH 5.91" GAUGE RING, 5"JUNK BASKET AND ROLLER STEM TO 3000' MD W ITH NO RESTRICTIONS NOTED (FIRST RUN). TOTAL OF 241 BBLS OF 9.0 PPG BRINE LOST TO FORMATION TODAY. OTHCMP CONTINUE TO RIH WITH 5.91" GAUGE RING, 5" JUNK BASKET AND ROLLER STEM ON SLB E-LINE FROM 3000' MD TO 9750' MD (98' BELOW BOTTOM PERF) WITH NO RESTRICTIONS (FIRST RUN). POH. JUNK BASKET RETURNED 1/4 CUP OF SAND, CEMENT AND GUN POWDER RESIDUE, NO METAL RETURNS. FLUID LOSS RATE: 5 BPH 9.0 PPG BRINE 01:30 - 03:30 2.00 EVAL P OTHCMP RIH WITH 6.045" GAUGE RING, 5" JUNK BASKET AND ROLLER STEM ON SLB E-LINE FROM SURFACE TO 9750' MD (98' BELOW BOTTOM PERF) WITH NO RESTRICTIONS (SECOND RUN). POH. JUNK BASKET RETURNED 3/4 CUP OF CEMENT, GUN POWDER RESIDUE, 10% METAL RETURNS. FLUID LOSS RATE: 5 BPH 9.0 PPG BRINE 03:30 - 07:00 3.50 EVAL P OTHCMP RIH WITH 6.125" GAUGE RING, 5" JUNK BASKET AND ROLLER STEM ON SLB E-LINE FROM SURFACE TO 9750' MD (98' BELOW BOTTOM MOST PERF WITH NO RESTRICITONS (THIRD RUN). POH AND ENCOUNTERED OBSTRUCTION AT 9720' MD, PULL FREE BY SLIGHTLY PULLING ON E-LINE TO A MAXIMUM OVERPULL OF 1800 LBS. JUNK BASKET RETURNED 3/4 CUP OF MOSTLY PIECES OF CEMENT. FLUID LOSS RATE: 5 BPH 9.0 PPG BRINE 07:00 - 09:30 2.50 EVAL P OTHCMP RIH WITH 6.125" GAUGE RING, 5" JUNK BASKET AND ROLLER STEM ON SLB E-LINE FROM SURFACE TO 9750' MD (98' BELOW BOTTOM PERF WITH NO RESTRICTIONS (FOURTH RUN). POH. JUNK BASKET RETURNED 1/4 CUP OF DEBRIS, MOSTLY CEMENT. Nnnted: iu[ai'[uua a:aa:~a Hnn BP AMERICA Page 25 of 27 Operations Summary Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 12/14/2009 07:00 - 09:30 2.50) EVAL ~ P ~ ~ OTHCMP FLUID LOSS RATE: 5 BPH 9.0 PPG BRINE 09:30 - 10:30 1.00 EVAL P OTHCMP PJSM WITH SLB E-LINE ON RIGGING DOWN GAUGE RING AND RIGGING UP USIT TOOL. RD 6.125" GAUGE RING, 5" JUNK BASKET AND ROLLER STEM. RU USIT TOOL. 10:30 - 12:30 2.00 EVAL P OTHCMP RIH W ITH USIT ON SLB E-LINE TO 2150' MD. NO GO AT 2150' MD. SUSPECT WELLBORE GEOMETRY MAY BE PREVENTING TOOL FROM GOING DOWN FURTHER. POH WITH USIT, REMOVE STRAIGHT BLADE CENTRALIZERS AND REPLACE WITH TWO 4-ARM SPRING LOADED CENTRALIZERS AND ADD A KNUCKLE JOINT. 12:30 - 20:30 8.00 EVAL P OTHCMP RIH WITH USIT TO 9722' MD. 5 DEG 1.5" HI RESOLUTION PASS FROM 9722' MD TO 8280', AND 5 DEG 6" CEMENT EVALUATION MODE FROM 8280 TO SURFACE. USIT RESULTS: TOP OF 11.0 PPG LEAD CEMENT AT 5542' MD 20:30 - 21:00 0.50 EVAL P 21:00 - 22:00 1.00 BUNCO 22:00 - 00:00 I 2.00 12/15/2009 ~ 00:00 - 02:00 ~ 2.00 02:00 - 12:00 10.00 OTHCMP RD SLB E-LINE. RUNCMP DRAIN STACK. PULL WEAR RING. PU 3 1/2" LANDING JOINT, MAKE DUMMY RUN WITH 11" X 4 1/2" FMC TUBING HANGER AND CONFIRM RKB ELEVATION OF 24.20'. FILL STACK. RUNCMP RU TO RUN 3 1/2" 9.2# 1-80 TCII 5 PACKER COMPLETION. FLUID LOSS: 3 BPH 9.0 PPG BRINE. TOTAL OF 89 BBLS OF 9.0 PPG BRINE LOST TO PERFS TODAY. RUNCMP PJSM W/SLB I-WIRE, BAKER, HALLIBURTON & 9ES RIG PERSONEL ON RIGGING UP TO RUN COMPLETION. -PULL WEAR RING, STAGE I-WIRE SPOOLS & TOOLS ON RIG FLOOR. -RIG UP 4 1/2" CASING EQUIPMENT, STAGE LANDING JT & PUP JTS. ON RIG FLOOR. RUNCMP PJSM W/ SLB I-WIRE, BAKER, HALLIBURTON & 9ES RIG PERSONEL ON RUNNING COMPLETION. -RIH W/ 3 1/2" 12.6# L-80 TCII TUBING JEWELRY AS PER RUNNING ORDER. -BAKERLOC FIRST 4 JTS. MU TO 2,300 FT / LBS -PICK UP AND FEED I-WIRE THROUGH FIRST PACKER, INSTALL NDPG IN CARRIER. -TEST PACKER VOID TO 5,000 PSI. -MW IN /OUT 9.0 FLUID LOST TO PERFS FOR TOUR = 40 BBL 12:00 - 00:00 12.00 BUNCO RUNCMP CONTINUE RIH W/ 3 1/2", 12.6#, L-80, TCII TUBING & JEWELRY AS PER RUNNING ORDER. -FEED I-WIRE THROUGH EACH PACKER, INSTALL NDPG IN CARRIER. -INSTALL FULL CANNON CLAMP OVER EVERY OTHER JT & HALF CLAMP OVER EACH MANDREL. -TEST ALL PACKER VOIDS TO 5,000 PSI / 10 MIN. -TEST I WIRE CONTINUITY EVERY 20 JTS OR 2 HOURS. rnrnea: iucaicvva a:vo:oa.,m • $P AMERICA Page 26 of 27 Operations Summary Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 end: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase ' Description of Operations ,12/15/2009 12:00 - 00:00 12.00 BUNCO RUNCMP -MU TO 2,300 FT /LBS -MW IN /OUT 9.0 FLUID LOST TO PERFS FOR TOUR = 30 BBL TOTAL FLUID LOSSES TO PERFS = 400 BBL 12/16/2009 00:00 - 12:00 12.00 BUNCO RUNCMP CONTINUE RIH W/ 3 1/2", 12.6#, L-80, TCII TUBING FROM 4,395' TO 9,710' MD. -INSTALL FULL CANNON CLAMP OVER EVERY OTHER JT & HALF CLAMP OVER EACH MANDREL. -TEST I WIRE CONTINUITY EVERY 20 JTS OR 2 HOURS. -PUW 112K, SOW 62K, MU TO 2,300 FT /LBS -MW IN /OUT 9.0 FLUID LOST TO PERFS FOR TOUR = 40 BBL TOTAL FLUID LOSSES TO PERFS = 440 BBL 12:00 - 12:30 0.50 BUNCO RUNCMP PJSM W/ SLB E-LINE AND RIG CREWS ON RUNNING WIRELINE. 12:30 - 15:00 15:00 - 17:00 2.50 2.00 BUNCO BUNCO RUNCMP RUNCMP RIH WITH GR/CCL LOGGING TOOL TO 9,640 ELM. -LOG UP FROM 9,640' TO 8,675" ELM. -RIG DOWN SLB E-LINE MAKE UP HANGER & LANDING JT, TERMINATE I-WIRE, PRESSURE TEST TO 5,000 PSI. -LAY DOWN TUBING JOINTS FOR SPACE OUT. -$PAGE OUT TUBIN ~ IOINTS USING A 19.79' & A 9.70' PUP JOINTS. -LAND TUBING W/ WLEG ~ 9,710' MD, PUW 115K, SOW 63K, RILDS. -INSTALLED 192 FULL CLAMPS. -DROP 1-5/16" BALL AND ROD W/ ROLLER STEM. 17:00 - 20:00 3.00 BUNCO RUNCMP PRESSURE UP TUBING TO 4,500 PSI TO SET PACKERS. - BLEED DOWN TO 4,000 PSI / 30 MIN, FOR TUBING TEST. -PRESSURE LOSS FIRST 15 MIN. 0 PSI, 2ND 15 MN 0 PSI. TEST GOOD. -BLEED OFF TUBING TO 2,500 PSI. -CIRCULATE FLUID THROUGH SURFACE EQUIPMENT TO REMOVE AIR. M ~'r -PRESSURE UP ON ANNULUS 4 000 PSI / 30 MIN. f - , -PRESSURE LOSS FIRST 15 MIN. 10 PSI, 2ND 15 MN 10 PSI. TEST GOOD. -BLEED OFF TUBING PRESSURE TO SHEAR DCR SHEAR VALVE. -ESTABLISH CIRCULATION /REVERSE CIRCULATION THROUGH SHEAR VALVE. -WITNESS OF TEST WAIVED BY AOGCC REPRESENTATIVE LOU GRIMALDI, TEST WITNESSED BY BP WSL SEAN HUFSTETLER & ROB O'NEAL, NABOBS TOOL PUSHER ROY HUNT. 20:00 - 22:30 2.50 BUNCO RUNCMP CLEAN & CLEAR RIG FLOOR. -DRAIN STACK. -ICJI iv ~.uuu roi rnvm ocwvv i v rvw., J,JVV ~ V, ABOVE / 10 MIN. OK. 22:30 - 00:00 1.50 BOPSU N SFAL RUNCMP PJSM, CHANGE OUT BLIND RAMS TO SHEAR RAMS. Printed: 12/28/2009 8:46:39 AM ~ M BP AMERICA Page 27 of 27 Operations Summary. Report Legal Well Name: V-224 Common Well Name: V-224 Spud Date: 11/26/2009 Event Name: DRILL+COMPLETE Start: 11/25/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/17/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code- NPT Phase 'Description of Operations 12/16/2009 22:30 - 00:00 1.50 BOPSU N SFAL RUNCMP FLUID LOST TO PERFS FOR TOUR = 7 BBL TOTAL FLUID LOSSES TO PERFS = 447 BBL 12/17/2009 00:00 - 01:00 1.00 BOPSU N SFAL RUNCMP CHANGEOUT BLIND RAMS TO SHEAR RAMS -PULL MOUSE HOLE & RISER 00:00 - 03:30 3.50 BOPSU P RUNCMP PJSM WITH SLB & RIG HANDS ON ND BOP STACK. -PULL RISER, PULL TURN BUCKLES, PULL AND SECURE BOPE. -MOVE TREE & ADAPTER FLANGE INTO CELLAR. -SLB PERFORM CONTINUITY TEST ON I-WIRE. -INSTALL ADAPTER FLANGE AND DOUBLE MASTER VALVES. 03:30 - 06:30 3.00 WHSUR P RUNCMP MOVE TREE & ADAPTER FLANGE INTO CELLAR. -SLB PERFORM CONTINUITY TEST ON I-WIRE. -INSTALL ADAPTER FLANGE AND DOUBLE MASTER VALVES. -SLB TERMINATE I-WIRE THROUGH ADAPTER FLANGE. -FMC INSTALL AND TORQUE ADAPTER FLANGE AND TREE. -ENERGIZE SEALS, TEST TO 5,000 PSI FOR 30 MINUTES. -FILL TREE W/ DIESEL. PRESSURE TEST TO 5,000 PSI. OK. °` 06:30 - 07:00 0.50 WHSUR P RUNCMP PJSM W/ DSM AND 9ES RIG PERSONEL ON PULLING '~ TWC. -RIG UP DSM LUBRICATOR. -PRESSURE TEST TO 500 PSI, PULL TWC. 07:00 - 09:00 2.00 WHSUR P RUNCMP CIRCULATE 77 BBL CLEAN BRINE FOLLOWED BY 129 BBLOF CLEAN BRINE W/ CORROSION INHIBIT R. -3 BBL / MIN ~ 400 PSI. 09:00 - 10:30 1.50 WHSUR P RUNCMP PJSM W/ RIG &LRS HANDS ON PUMPING DIESEL. -RU LRS TO TUBING SPOOL ANNULAR VALVE. -PRESSURE TEST LINES TO 3,000 PSI. -PUMP 125 BBL, 70 DEGREE DIESEL DOWN IA, 2 BPM ~ 300 PSI. 10:30 - 12:00 1.50 WHSUR P RUNCMP -ALLOW DIESEL TO U-TUBE INTO TUBING STRING. 12:00 - 18:00 6.00 WHSUR P RUNCMP DSM INSTALL BPV, LRS PRESSURE TEST FROM BELOW 1,000 PSI. -DSM INSTALL VR PLUGS IN ALL 3 ANNULUS VALVES. -T/ IA/ OA PRESSURE 0 / 0 / 0 -RELEASE RIG TO V-123 ~ 18:00 HOURS rnncea: iueweuua o:go:aar+m by ~'"'~ .. __ . __ . _ _ Schlumher~er ~- v-~~4r~s-i ~u Report Date: 28-NOV-09 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA SWcture 1 Slot: V-Pad I Plan V Slot (S-Z) Well: V-224 Borehole: V-224PB1 UWIIAPI#: 500292340070 Survey Name 1 Date: V-227PB1 I November 28, 2009 Tort IAHD I DDI / ERD ratio: 74.955° 11115.09 ft 15.015 / 0.563 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatlLong: N 70.32771235, W 149.26338218 Location Grid N/E YIX: N 5969980.100 ftUS, E 590828.540 ftUS Grid Convergence Angie: +0.69362834° rcepvrt Survey 1 DLS Computation Method: Minimum Curvature / LI Vertical Section Azimuth: 59.080° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Dawm: Rotary Table TVD Reference Elevation: 81.80 ft relative to MSL Sea Bed 1 Ground Level Elevation: 53.30 ft relatroe to MSL Magnetic Declination: 22.145° Total Field Strength: 57660.289 nT Magnetic Dip: 80.889° Declination Date: November 30, 2009 Magnetic Declination Model: BGGM 2009 North Reference: True North Total Corz Mag North •> True North: +22.145° Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth 7Ne Section Departure True North True North it de de k ft ft R ft ft n nn ft n nn de 1100 ft n nn itUS cncnnon ~n ftUS cnnoeo ew ~i ~n ~no•~a oac ~ni awn ecooon~o K I t V.VU u.vu u. w -o i.ov V. vv v. w v. w v .w v. vv v. vv ~.w .,ov~~w . ~ ~ ..uw~~. ..+ ~. , v ..," , ~w., .. ~t~. ~~„w~ ~v i NSG SSHOT 84.00 0.14 51. 34 2. 20 84. 00 0. 10 0. 10 0 .10 0. 06 0. 08 0.17 5969980 .17 590828. 62 N 70 .32771253 W 149. 26338153 175.00 0.81 37. 03 93. 20 175. 00 0. 81 0. 85 0 .85 0. 65 0. 55 0.74 5969980 .75 590829. 09 N 70 .32771412 W 149. 26337768 189.00 1.40 37. 58 107. 19 188. 99 1. 06 1. 12 1 .12 0. 86 0. 72 4.21 5969980 .97 590829. 25 N 70 .32771470 W 149. 26337635 280.00 3.30 34. 52 198. 11 279. 91 4. 48 4. 86 4 .85 3. 90 2. 88 2.09 5969984 .04 590831. 37 N 70 .32772301 W 149. 26335882 374.00 5.90 35. 41 291. 80 373. 60 11. 36 12. 39 12 .39 10. 07 7. 21 2.77 5969990 .25 590835. 63 N 70 .32773986 W 149. 26332368 ', 463.00 7.92 38. 75 380. 15 461. 95 21. 30 23. 10 23 .09 18. 58 13. 70 2.31 5969998 .84 590842. 02 N 70 .32776311 W 149. 26327106 556.00 8.75 43. 21 472. 17 553. 97 34. 12 36. 57 36 .53 28. 73 22. 56 1.13 5970009 .10 590850. 75 N 70 .32779085 W 149. 26319926 648.00 9.24 56. 79 563. 05 644. 85. 48. 23 50. 89 50 .59 37. 88 33 .53 2.36 5970018 .38 590861. 61 N 70 .32781583 W 149. 26311029 MWD+GMAG 672.50 9.43 64 .74 587. 22 669. 02 52. 19 54. 86 54 .35 39. 81 36 .99 5.32 5970020 .35 590865. 04 N 70 .32782112 W 149. 26308222 762.59 11.13 73 .52 675. 87 757. 67 67. 96 70. 90 69 .05 45. 43 52 .00 2.56 5970026 .15 590879 .99 N 70 .32783646 W 149. 26296047 858.52 13.22 76 .89 769. 64 851. 44 87. 37 91. 13 87 .62 50. 55 71 .57 2.30 5970031 .50 590899 .49 N 70 .32785044 W 149. 26280182 953.75 15.48 75 .91 861. 89 943. 69. 109. 90 114. 73 109 .91 56. 11 94 .50 2.39 5970037 .34 590922 .35 N 70 .32786564 W 149. 262 84 1049.41 S~L1- ~~ 18.44 73 .77 953. 38 1035 .18 136. 76 142. 63 137 .00 63. 45 121 .42 3.16 5970045 .01 590949 .17 N 70 .32788568 W 149. 26 9 1145.46 22.35 73 .37 1043. 39 1125 .19 169. 17 176. 09 169 .95 72. 92 153 .51 4.07 5970054 .87 590981 .15 N 70 .32791157 W 149. 262 2 S/`T 1240.56 26.76 72 .61 1129. 87 1211 .67 207. 53 215. 60 209 .12 84. 50 191 .29 4.65 5970066 .90 591018 .77 N 70 .32794320 W 149. 26183100 1336.86 30.38 72 .60 1214. 43 1296 .23 252. 29 261. 65 254 .93 98. 27 235 .23 3.76 5970081 .20 591062 .54 N 70 .32798080 W 149. 26147468 1432.07 34.02 73 .00 1294. 98 1376 .78 301. 57 312. 38 305 .46 113. 26 283 .69 3.83 5970096 .78 591110 .81 N 70 .32802175 W 149. 26108171 6 1527.38 37.58 73 .24 1372. 27 1454 .07 355. 65 368. 12 361 .04 129. 44 337 .03 3.74 5970113 .60 591163 .95 N 70 .32806595 W 149. 26064914 P 1623.23 42.13 74 .40 1445. 84 1527 .64 415. 03 429 .53 422 .25 146. 52 396 .02 4.81 5970131 .39 591222 .72 N 70 .32811262 W 149. 26017083 Sc~f`~" 1719.10 46.76 74 .31 1514. 26 1596 .06 479. 77 496 .64 489 .17 164. 63 460 .64 4.83 5970150 .27 591287 .11 N 70 .32816205 W 149. 25964677 y 1813.56 47.96 72 .14 1578. 25 1660 .05 547. 14 566 .12 558 .58 184. 69 527 .16 2.11 5970171 .14 591353 .38 N 70 .32821686 W 149. 25910735 1908.57 49.12 73 .83 1641. 16 1722 .96 616. 25 637 .32 629 .72 205. 51 595 .24 1.81 5970192 .79 591421 .19 N 70 .32827373 W 149. 25855525 2004.36 53.91 72 .24 1700. 75 1782 .55 689. 00 712 .28 704 .63 227. 42. 666 .92 5.17 5970215 .55 591492 .60 N 70 .32833356 W 149. 25797393 2100.92 59.49 71 .40 1753. 75 1835 .55 767. 69 792 .95 785 .30 252. 61 743 .56 5.82 5970241 .67 591568 .92 N 70 .32840235 W 149. 25735243 SurveyEditor Ver SP 2.1 Bld( users) Plan V Slot (S-Z)\V-224\V-224P61\V-227P61 Generated 1/7/2010 1:57 PM Page 1 of 2 Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Tnre Section Departure True North True North ft de de ft ft ft ft ft ft ft de 1100 ft ftUS ftUS 2196.79 62.61 70.95 1800.15 1881.95 849.71 876.83 869.18 279.68 822.96 3.28 5970269.69 2292.17 67.60 70.15 1840.29 1922.09 934.48 963.32 955.66 308.49 904.50 5.29 5970299.49 Last Survey 2387.41 69.25 70.84 1875.31 1957.11 1021.29 1051.89 1044.22 338.06 987.99 1.86 5970330.06 TD (Projected) 2455.00 69.25 70.84 1899.25 1981.05 1083.17 1115.09 1107.43 358.80 1047.69 0.00 5970351.52 Survey Type: Definitive Survey NOTES: SLB NSG+SSHOT - (NorthSeeking Gyro Singleshots -- Northseeking gyro in gyrocompassing or stationing mode with larger misalignment errors as a result of landing in a UBHO sub. Not to be run above 70 degrees inclination.) MWD+GMAG - (MWD + IFR +SLB Multi-station correction + Sag correction -- Standard SLB MWD error model where the surveys have been geomagnetically reference (declination) corrected using a local crustal magnetic model and the SLB multistation drillstring magnetic interference correction GMAG (GeoMAGnetic Correction) under survey specialist supervision -and where the inclinations have then been corrected for BHA sag.) Survev Error Model: SLB ISCWSA version 24 *** 3-D 95.00% Confidence 2.7955 sigma Surveying Prog: MD From I ft 1 MD To 1 ft 1 EOU Freg Survev Tool Tvoe Borehole -> Survev 0.00 27.80 Act-Stns SLB_NSG+SSHOT-Depth Only V-224P61 -> V-227PB1 27.80 648.00 Act-Stns SLB_NSG+SSHOT V-224P61 -> V-227P61 648.00 2387.41 Act-Stns SLB MWD+GMAG^^1 V-224PB1 -> V-227PB1 2387.41 2455.00 Act-Stns SLB BLIND^^1 V-224PB1 -> V-227P61 Legal Description: Surface : 4729 FSL 1474 FEL S11 T11 N R11 E UM BHL : 5088 FSL 426 FEL S11 T11 N R11 E UM Northing IYI fftUSl Easting 1X1 fftUSl 5969980.10 590828.54 5970351.52 591871.71 i 591647.97 N 70.32847628 W 149.25670860 591729.16 N 70.32855497 W 149.25604727 591812.27 N 70.32863571 W 149.25537025 591871.71 N 70.32869236 W 149.25488606 SurveyEditor Ver SP 2.1 Bld( users) Plan V Slot (S-Z)\V-224\V-224PB1\V-227PB1 Generated 1/7/2010 1:57 PM Page 2 of 2 by .. ~~. ~ ~ Schlumberger ~ v-~c4 ~u Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: V-Pad / Plan V Slot (S-Z) We11: V-224 Borehole: V-224 UWIIAPI#: 500292340000 Survey Name 1 Date: V-224 /December 09, 2009 Tort 1 AHD 1 DDI 1 ERD ratio: 195.093° / 7820.72 ft / 6.466 11.504 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaULong: N 70.32771235, W 149.26338218 Location Grid NIE YIX: N 5969980.100 ftUS, E 590828.540 ftUS Grid Convergence Angle: +0.69362834° Grid Scale Factor. 0.99990937 r~e~vri Vertical Section Azimuth: 59.080° Vertical Section Origin: N 0.000 ft, E 0.000 ft ND Reference Datum: Rotary Table ND Reference Elevation: 81.80 ft relative to MSL Sea Bed 1 Ground Level Elevation: 53.30 ft relative to MSL Magnetic Declination: 22.145° Total Field Strength: 57660.289 nT Magnetic Dip: 80.889° Declination Date: November 30, 2009 Magnetic Declination Model: BGGM 2009 North Reference: True North Total Corr Mag North •> True North: +22.145° Local Coordinates Referenced To: Well Head L Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Eaeting Latitude Longitude Depth True Section Departure True North True North R de de R ft R R R R R de 1100 R RUS RUS KIt U. W U.VV V .UV -ai.au u .u~ ~. ~u u .vu u. ~u u. uu u. uu ~.uv oao~~ov. iv a~uoco av rvrv. ~criic~a vv wy. cooaocio NSG SSHOT 84. 00 0.14 51 .34 2. 20 84 .00 0. 10 0 .10 0. 10 0. 06 0. 08 0.17 5969980. 17 590828. 62 N 70. 32771253 W 149. 26338153 175. 00 0.81 37 .03 93. 20 175 .00 0. 81 0 .85 0. 85 0. 65 0. 55 0.74 5969980. 75 590829. 09 N 70. 32771412 W 149. 26337768 189. 00 1.40 37 .58 107. 19 188 .99 1. 06 1 .12 1. 12 0. 86 0. 72 4.21 5969980. 97 590829. 25 N 70. 32771470 W 149. 26337635 280. 00 3.30 34 .52 198. 11 279 .91 4. 48 4 .86 4. 85 3. 90 2. 88 2.09 5969984. 04 590831. 37 N 70. 32772301 W 149. 26335882 374. 00 5.90 35 .41 291. 80 373 .60 11. 36 12 .39 12. 39 10. 07 7. 21 2.77 5969990. 25 590835. 63 N 70. 32773986 W 149. 26332368 463. 00 7.92 38 .75 380. 15 461 .95 21. 30 23 .10 23. 09 18. 58 13. 70 2.31 5969998. 84 590842. 02 N 70. 32776311 W 149. 26327106 556. 00 8.75 43 .21 472. 17 553 .97 34. 12 36 .57 36. 53 28 .73 22. 56 1.13 5970009. 10 590850. 75 N 70. 32779085 W 149. 26319926 648. 00 9.24 56 .79 563. 05 644 .85 48. 23 50 .89 50. 59 37 .88 33. 53 2.36 5970018. 38 590861. 61 N 70. 32781583 W 149. 26311029 MWD+GMAG 672. 50 9.43 64 .74 587. 22 669 .02 52. 19 54 .86 54. 35 39 .81 36. 99 5.32 5970020. 35 590865. 04 N 70. 32782112 W 149. 26308222 762. 59 11.13 73 .52 675. 87 757 .67 67. 96 70 .90 69. 05 45 .43 52. 00 2.56 5970026. 15 590879. 99 N 70. 32783646 W 149. 26296047 858. 52 13.22 76 .89 769. 64 851 .44 87. 37 91 .13 87. 62 50 .55 71. 57 2.30 5970031. 50 590899. 49 N 70. 32785044 W 149. 26280182 953. 75 15.48 75 .91 861. 89 943 .69 109. 90 114 .73 109. 91 56 .11 94. 50 2.39 5970037. 34 590922. 35 N 70. 32786564 W 149. 262 84 Tie-In Survey 1049. 41 18.44 73 .77 953. 38 1035 .18 136. 76 142 .63 137. 00 63 .45 121. 42 3.16 5970045. 01 590949. 17 N 70. 32788568 W 149. 269 MWD+GMAG `'1144. 79 21,.57 73 .25. 1043. 00 1124 .80 168. 36 175 .25 169. 13 72 .72 152. 70 3.29 5970054. 66 590980. 33 N 70. 32791101 W 149. 262 4 1169. 74 22.72 73 .58 1066. 11 1147 91 177. 48 184 .66 178. 43 75 .40 161. 71 4.64 5970057. 45 590989. 31 N 70. 32791834 W 149. 26207084 1199. 97 24.30 73 .01 1093. 83 1175 .63 189. 17 196 .72 190. 37 78 .87 173. 26 5.28 5970061. 06 591000. 82 N 70. 32792781 W 149. 26197719 1238. 80 .25.92 71 .05 1128. 98 1210 .78 205. 22 213 .19 206. 75 83 .96 188. 93 4.69 5970066. 33 591016. 42 N 70. 32794172 W 149. 26185013 1314. 64 27.21 71 .93 1196. 82 1278 .62 238. 34 247 .11 240. 53 94 .72 221. 09 1.78 5970077. 48 591048. 45 N 70. 32797112 W 149. 26158932 1334. 18 28.08 73 .98 1214. 13 1295 .93 247. 14 256 .17 249. 54 97 .38 229. 76 6.60 5970080. 24 591057. 08 N 70. 32797837 W 149. 26151903 1429. 19 30.89 75 .21 1296 .82 1378 .62 292. 19 302 .93 295. 96 109 .78 274. 84 3.03 5970093. 19 591102. 01 N 70. 32801224 W 149. 26115345 1525. 67 34.10 74 .81 1378 .19 1459 .99 342. 03 354 .76 347. 47 123 .19 324. 90 3.33 5970107. 20 591151. 90 N 70. 32804888 W 149. 26074751 1620. 58 37.68 74 .15 1455 .07 1536 .87 395. 66 410 .39 402. 90 138 .09 378. 50 3.79 5970122. 75 591205. 30 N 70. 32808957 W 149. 26031288 1715. 56 44.49 73 .75 1526 .61 1608 .41 455. 96 472 .77 465. 15 155 .35 438. 44 7.18 5970140. 73 591265. 03 N 70. 32813672 W 149. 25982676 1810. 92 45.85 73 .46 1593 .84 1675 .64 521. 43 540 .40 532. 69 174 .44 503. 32 1.44 5970160. 60 591329. 67 N 70. 32818886 W 149. 25930065 SurveyEditor Ver SP 2.1 Bld( users) Plan V Slot (S-Z)\V-224\V-224\V-224 Generated 1/7/2010 1:57 PM Page 1 of 4 Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Dept Tnre Section Departure True North True North ft de de ft ft ft ft ft ft ft de H00 ft ftUS ftUS 1906. 92 48.52 73. 23 1659 .08 1740. 88 589 .67 610. 81 603 .05 194. 62 570. 78 2.79 5970181 .60 591396. 87 N 70 .32824399 W 149 .25875360 2000. 84 52.77 74. 53 1718 .63 1800. 43 659 .86 683. 41 675 .58 214. 76 640. 54 4.65 5970202 .58 591466. 37 N 70 .32829898 W 149 .25818793 2098. 79 55.86 75. 36 1775 .76 1857. 56 736 .37 762. 96 755 .00 235. 41 717. 36 3.23 5970224 .15 591542. 93 N 70 .32835538 W 149 .25756496 2193. 94 62.12 74. 24 1824 .75 1906. 55 814 .84 844. 47 836 .41 256. 81 796. 01 6.66 5970246. 50 591621. 31 N 70 .32841381 W 149 .25692715 2290. 10 67.26 73. 68 1865 .85 1947. 65 898 .83 931. 37 923 .27 280. 83 879. 52 5.37 5970271 .53 591704. 52 N 70 .32847940 W 149 .25624989 2385. 68 67.65 73. 13 1902 .50 1984. 30 984 .36 1019. 65 1011 .53 306. 04 964. 12 0.67 5970297. 76 591788. 79 N 70 .32854825 W 149 .25556384 2481. 68 71.44 73. 02 1936 .04 2017. 84 1071 .62 1109. 58 1101 .45 332. 22 1050. 15 3.95 5970324. 98 591874. 50 N 70 .32861974 W 149 .25486612 2576. 97 70.49 73. 66 1967 .12 2048. 92 1158 .92 1199. 66 1191 .52 358. 05 1136. 45 1.18 5970351. 84 591960. 47 N 70 .32869026 W 149 .25416628 2673. 24 69.54 73. 46 2000 .02 2081. 82 1246 .52 1290. 13 1281 .98 383. 65 1223. 22 1.01 5970378 .49 592046. 92 N 70 .32876017 W 149 .25346257 2768. 59 69.34 72. 35 2033 .51 2115. 31 1333 .21 1379. 40 1371 .25 409. 89 1308. 55 1.11 5970405. 76 592131. 92 N 70 .32883183 W 149 .25277056 2863. 69 68.17 73. 16 2067 .97 2149. 77 1419 .33 1468. 04 1459 .88 436. 17 1393. 20 1.46 5970433 .06 592216. 23 N 70 .32890358 W 149 .25208406 2958. 89 70.83 72. 84 2101 .30 2183. 10 1505 .88 1557. 20 1549 .04 462. 24 1478. 47 2.81 5970460 .16 592301. 17 N 70 .32897476 W 149 .2 6 3054. 71 70.73 72. 48. 2132 .85 2214. 65 1593 .83 1647. 68 1639 .52 489. 21 1564. 84 0.37 5970488 .17 592387. 20 N 70 .32904838 W 149 5 .25 2 3150. 22 69.62 72. 36 2165 .24 2247. 04 1681 .25 1737. 53 1729 .37 516. 34 1650. 49 1.17 5970516 .34 592472. 50 N 70 .32912246 W 149 .249 48 3245. 91 69.71 73. 17 2198 .49 2280. 29 1768 .43 1827. 26 1819 .10 542. 93 1736. 19 0.80 5970543 .96 592557. 87 N 70 .32919504 W 149 .24930247 3341. 63 69.03 72. 21 2232 .22 2314. 02 1855 .49 1916. 84 1908 .68 569. 58 1821. 71 1.18 5970571 .64 592643. 05 N 70 .32926779 W 149 .24860886 3437. 04 70.18 72. 87 2265 .47 2347. 27 1942 .46 2006. 26 1998 .10 596. 41 1907. 02 1.37 5970599 .50 592728. 02 N 70 .32934103 W 149 .24791699 3532. 48 70.64 72. 21 2297 .47 2379. 27 2029 .91 2096. 18 2088 .02 623. 39 1992. 79 0.81 5970627 .51 592813. 45 N 70 .32941468 W 149 .24722136 3628. 24 70.16 72. 32 2329 .59 2411. 39 2117 .74 2186. 39 2178 .23 650. 87 2078. 71 0.51 5970656 .02 592899. 03 N 70 .32948968 W 149 .24652448 3724. 04 69.58 72. 13 2362 .56 2444. 36 2205 .33 2276. 34 2268 .17 678. 33 2164. 37 0.63 5970684 .52 592984. 34 N 70 .32956463 W 149 .24582979 3818. 80 68.89 73. 12 2396 .16 2477. 96 2291 .47 2364. 94 2356 .78 704. 79 2248. 92 1.22 5970712 .00 593068. 56 N 70 .32963685 W 149 .24514398 3914. 74 69.43 73. 28 2430 .29 2512. 09 2378 .42 2454. 61 2446 .43 730. 70 2334. 76 0.58 5970738 .95 593154. 07 N 70 .32970758 W 149 .24444780 4010. 08 69.18 72. 37 2463 .98 2545. 78 2465 .06 2543. 79 2535 .62 757. 04 2419. 97 0.93 5970766 .31 593238. 95 N 70 .32977945 W 149 .24375670 4105. 24 68.55 72. 29 2498 .29 2580. 09 2551 .45 2632. 55 2624 .38 783. 98 2504. 54 0.67 5970794 .27 593323. 18 N 70 .32985298 W 149 .24307077 4200. 94 69.13 72. 94 2532 .84 2614. 64 2638 .22 2721. 80 2713 .62 810. 65 2589. 71 0.88 5970821 .96 593408. 01 N 70 .32992575 W 149 .24237999 4296. 32 68.17 72. 84 2567 .56 2649. 36 2724 .48 2810. 63 2802 .46 836. 78 2674 .61 1.01 5970849 .12 593492. 58 N 70 .32999706 W 149 .24169137 4391 .96 69.31 73. 53 2602 .24 2684. 04 2810 .93 2899. 76 2891 .58 862. 56 2759 .93 1.37 5970875 .93 593577. 57 N 70 .33006741 W 149 .24099937 4487 .96 69.98 73. 40 2635 .63 2717. 43 2898 .11 2989. 77 2981 .58 888. 18 2846 .21 0.71 5970902 .58 593663. 53 N 70 .33013730 W 149 :24029955 4583 .17 69.62 72. 54 2668 .51 2750. 31 2984 .85 3079. 12 3070 .93 914. 35 2931 .65 0.93 5970929 .78 593748. 64 N 70 .33020870 W 149 .23960659 4678 .46 68.48 72. 38 2702 .58 2784. 38 3071 .42 3168. 11 3159 .92 941. 17 3016 .50 1.21 5970957 .62 593833. 15 N 70 .33028188 W 149 .23891836 4774 .31 69.31 73. 29 2737 .09 2818. 89 3158 .28 3257. 53 3249 .34 967. 55 3101 .94 1.24 5970985 .04 593918 .25 N 70 .33035387 W 149 .238 4869 .59 70.04 72. 89 2770 .19 2851. 99 3244 .97 3346. 88 3338 .68 993. 54 3187 .42 0.86 5971012 .06 594003 .41 N 70 .33042477 W 149 .237 02 4965 .56 69.09 73 .45 2803 .70 2885. 50 3332 .19 3436. 80 3428 .61 1019. 58 3273 .50 1.13 5971039 .14 594089 .15 N 70 .33049581 W 149 .23683384 5060 .85 69.52 73. 63 2837 .37 2919. 17 3418 .51 3525. 95 3517 .74 1044. 84 3358 .99 0.48 5971065 .42 594174 .32 N 70 .33056470 W 149 .23614043 5156 .55 69.80 72 .54 2870 .64 2952. 44 3505 .57 3615. 68 3607 .47 1070. 95 3444 .84 1.11 5971092 .57 594259 .84 N 70 .33063592 W 149 .23544409 5252 .55 69.39 72 .34 2904 .11 2985. 91 3593 .11 3705. 65 3697 .44 1098. 09 3530 .62 0.47 5971120 .75 594345 .28 N 70 .33070997 W 149 .23474828 5348 .68 68.48 72 .54 2938 .66 3020. 46 3680 .39 3795. 36 3787 .15 1125. 16 3616 .14 0.97 5971148 .84 594430 .46 N 70 .33078380 W 149 .23405455 5420 .76 69.12 73 .16 2964 .72 3046 .52 3745 .66 3862. 56 3854 .35 1144. 97 3680 .36 1.20 5971169 .43 594494 .43 N 70 .33083785 W 149 .23353369 5519 .44 67.55 72 .43 3001 .15 3082 .95 3834 .75 3954. 27 3946 .05 1172. 10 3767 .96 1.73 5971197 .61 594581 .69 N 70 .33091183 W 149 .23282310 5584 .36 68.46 74 .43 3025 .47 3107 .27 3893 .06 4014. 46 4006 .24 1189. 26 3825 .65 3.18 5971215 .47 594639 .16 N 70 .33095863 W 149 .23235514 5679 .76 67.49 74 .15 3061 .25 3143 .05 3978 .40 4102. 90 4094 .64 1213. 20 3910 .78 1.05 5971240 .44 594723 .99 N 70 .33102393 W 149 .23166459 5774 .10 67.86 74 .78 3097 .08 3178 .88 4062 .54 4190 .17 4181 .87 1236. 57 3994 .86 0.73. 5971264 .83 594807 .77 N 70 .33108766 W 149 .23098257 SurveyEditor Ver SP 2.1 Bld( users) Plan V Slot (S-Z)\V-224\V-224\V-224 Generated 1/7/2010 1:57 PM Page 2 of 4 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS btfby.`J~l /U. 43 /b.-Iy 31J~. 1`J Jcic. aa ~f140.V1 YL/y. 0~ YL/I.JV ILJA. VV YVVI. JJ J.VI JJ/1 - - -. - 5965. 89 71. 13 75.86 3162. 79 3244. 59 4235.11 4370. 32 4361 .79 1280. 89 4169. 48 0.80 5971311 .25 594981. 82 N 70 .33120846 W 149.22956619 6061. 85 69. 73 73.97 3194. 93 3276. 73 4322.09 4460. 73 4452 .15 1304. 41 4256. 77 .2.36 5971335 .82 595068. 82 N 70 .33127259 W 149.22885809 6157. 40 69. 52 74.29 3228. 20 3310. 00 4408.59 4550. 30 4541 .70 1328. 91 4342. 93 0.38 5971361 .36 595154. 67 N 70 :33133937 W 149.22815920 6252. 61 69. 37 74.47 3261. 63 3343. 43 4494.57 4639. 45 4630 .82 1352. 91 4428. 79 0.24 5971386 .40 595240. 22 N 70 .33140481 W 149.22746276 6348. 19 68. 85 74.65 3295. 71 3377. 51 4580.63 4728. 75 4720 .09 1376. 68 4514. 86 0.57 5971411 .21. 595325. 99 N 70 .33146962 W 149.22676454 6443. 59 70. 04 74.73 3329. 20 3411. 00 4666.66 4818. 08 4809 .38 1400. 27 4601. 02 1.25 5971435 .83 595411. 84 N 70 .33153391 W 149.22606567 6539. 89 69. 88 74.95 3362. 20 3444. 00 4753.73 4908. 54 4899 .80 1423. 93 4688. 34 0.27 5971460 .54 595498. 86 N 70 .33159840 W 149.22535734 6636. 30 69. 46 74.70 3395. 70 3477. 50 4840.74 4998. 95 4990 .17 1447. 59 4775. 59 0.50 5971485 .26 595585. 81. N 70 .33166290 W 149.22464956 6732. 12 69. 34 74.70 3429. 41 3511. 21 4927.12 5088. 64 5079 .83 1471. 26 4862. 10 0.13 5971509 .97 595672. 03 N 70 .33172740 W 149.22394776 6826. 93 69. 19 74.38 3462. 98 3544. 78 5012.58 5177. 31 5168 .47 1494. 90 4947. 56 0.35 5971534 .64 595757. 19 N 70 .33179182 W 149.22325450 6921 .45 68. 51 71.04 3497. 09 3578. 89 5098.24 5265. 46 5256 .61 1521. 09 5031 .72 3.37 5971561 .84 595841. 01 N 70 .33186321 W 149.22257180 7017 .37 68. 20 66.55 3532. 49 3614. 29 5186.09 5354. 61 5345 .48 1553. 32 5114. 81 4.36 5971595 .08 595923. 70 N 70 .33195112 W 149.2218 7113 .32 67. 12 61.32 3568. 98 3650. 78 5274.47 5443. 35 5433 .07 1592. 28 5194 .51 5.17 5971635 .00 596002. 91 N 70 .33205742 W 149.221 10 7209 .13 66. 82 60.76 3606. 46 3688. 26 5362.59 5531. 52 5519 .37 1634. 98 5271 .65 0.62 5971678 .62 596079 .53 N 70 .33217390 W 149.22062514 7304 .41 66. 56 57.56 3644. 17 3725. 97 5450.08 5619. 02 5604 .44 1679. 83 5346 .77 3.10 5971724 .37 596154 .09 N 70 .33229628 W 149.22001561 7400 .54 65. 68 53.65. 3683. 10 3764. 90 5537.80 5706. 92 5688 .56 1729. 46 5419 .29 3.83 5971774 .87 596226 .00 N 70 .33243173 W 149.21942713 7495 .58 64. 30 49.69 3723. 29 3805. 09 5623.19 5793. 04 5769 .23 1782. 85 5486 .85 4.05 5971829 .07 596292 .90 N 70 .33257744 W 149.21887889 7591 .51 62. 72 45.12 3766. 10 3847. 90 5707.24 5878. 88 5847 .39 1840. 91 5550 .04 4.57 5971887 .89 596355 .38 N 70 .33273596 W 149.21836597 7687 .42 60. 80 40.45 3811. 50 3893. 30 5788.31 5963. 36 5921 .51 1902. 88 5607 .43 4.73 5971950 .54 596412 .01 N 70 .33290511 W 149.21790011 7783 .07 57. 57 35.70 3860. 51 3942. 31 5864.98 6045. 49 5990 .42 1967. 47 5658 .11 5.44 5972015 .73 596461 .89 N 70 .33308148 W 149.21748869 7878 .65 57. 37 31.54 3911. 92 3993. 72 5937.71 6126. 06 6054 .78 2034. 55 5702 .71 3.68 5972083 .34 596505 .68 N 70 .33326464 W 149.21712647 7973 .05 57. 67 29.03 3962. 62 4044. 42 6007.49 6205. 69 6115 .91 2103. 31 5742 .86 2.27 5972152 .58 596544 .99 N 70 .33345240 W 149.21680037 8068 .85 57. 27 26.15 4014. 14 4095 .94 6076.35 6286. 46 6175 .89 2174. 88 5780 .27 2.57 5972224 .59 596581 .52 N 70 .33364785 W 149.21649651 8164 .44 59. 27 22.59 4064. 43 4146 .23 6143.15 6367. 75 6233 .60 2248. 93 5813 .78 3.80 5972299 .03 596614 .14 N 70 .33385007 W 149.21622422 8259 .78 59. 28 17.65 4113. 16 4194 .96 6206.85 6449. 69 6287 .93 2325. 85 5841 .96 4.45 5972376 .28 596641 .38 N 70 .33406014 W 149.21599516 8354 .87 57. 33 13.66 4163. 13 4244 .93 6265.61 6530 .59 6337 .36 2403. 72 5863 .81 4.12 5972454 .40 596662 .29 N 70 .33427283 W 149.21581740 8450 .31 55. 34 10.15 4216. 05 4297 .85 6319.61 6610 .01 6382 .35 2481. 41 5880 .22 3.70 5972532 .28 596677 .75 N 70 .33448505 W 149.21568381 8545 .55 56. 00 8.67 4269. 76 4351 .56 6370.51 6688 .66 6424 .71 2559. 00 5893 .08 1.46 5972610 .01 596689 .66 N 70 .33469699 W 149.21557904 8642 .10 55. 41 8.24 4324. 16 4405 .96 6421.11 6768 .42 6467 .24 2637. 90 5904 .81 0.71 5972689 .04 596700 .44 N 70 .33491250 W 149.21548340 8737 .52 52. 87 8.64 4380. 05 4461 .85 6470.15 6845 .75 6509 .13 2714. 39 5916 .15 2.68 5972765 .65 596710 .85 N 70 .33512144 W 149.2158 8833 .39 53. 14 8.59 4437. 74 4519 .54 6518.89 6922 .32 6551 .44 2790. 09 5927 .62 0.28 5972841 .48 596721 .41 N 70 .33532824 W 149.21 8928 .66 53. 04 8.75 4494. 96 4576 .76 6567.43 6998 .49 6594 .20 2865. 40 5939 .11 0.17 5972916 .92 596731 .97 N 70 .33553394 W 149.215 2 9023 .81 52. 69 8.12 4552. 40 4634 .20 6615.53 7074 .35 6637 .12 2940 .43. 5950 .23 0.64 5972992 .07 596742 .19 N 70 .33573890 W 149.21511296 9121 .01 52 .26 6.56 4611. 61 4693 .41 6663.27 7151 .43 6680 .13 3016 .89 5960 .08 1.35 5973068 .63 596751 .12 N 70 .33594774 W 149.21503256 9216 .00 52 .84 5.98 4669. 37 4751 .17 6708.85 7226 .84 6721 .63 3091 .84 5968 .32 0.78 5973143 .68 596758 .44 N 70 .33615251 W 149.21496527 9311 .32 53 .20 5.14 4726 .71 4808 .51 6754.12 7302 .99 6763 .34 3167 .63 5975 .69 0.80 5973219 .54 596764 .90 N 70 .33635953 W 149.21490494 9402 .53 53 .09 4.33 4781 .41 4863 .21 6796.66 7375 .97 6803 .01 3240 .36 5981 .72 0.72 5973292 .33 596770 .04 N 70 .33655822 W 149.21485560 9494 .27 53 .11 3.31 4836 .50 4918 .30 6838.47 7449 .33 6842 .45 3313 .56 5986 .61 0.89 5973365 .58 596774 .04 N 70 .33675817 W 149.21481548 9586.13 53 .49 2.49 4891 .40 4973 .20 6879.46 7522 .98 6881 .62 3387 .12 5990 .33 0.83 5973439 .17 596776 .88 N 70 .33695911 W 149.21478478 9676 .91 53 .28 2.15 4945 .54 5027 .34 6919.40 7595 .85 6920 .30 3459 .92 5993 .28 0.38 5973512 .00 596778 .95 N 70 .33715801 W 149.21476038 9768 .89 52 .84 1.41 5000 .82 5082 .62 6959.12 7669 .36 6959 .29 3533 .40 5995 .57 0.80 5973585 .49 596780 .34 N 70 .33735874 W 149.21474136 9860 .33 52 .33 0.96 5056 .38 5138 .18 6997.72 7741 .99 6997 .73 3606 .01 5997 .07 0.68 5973658 .11 596780 .96 N 70 .33755710 W 149.21472870 SurveyEditor Ver SP 2.1 Bld( users) Plan V Slot (S-Z)\V-224\V-224\V-224 Generated 1/7/2010 1:57 PM Page 3 of 4 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude D®pth True Section Departure True North True North 8 de de ft k ft ft ft ft ft de 1100 ft ftUS ftUS Last Survey 9894.83 52.14 0.48 5077.51 5159.31 7012.02 776926 7012.11 3633.28 5997.41 1.23 5973685.38 596780.98 N 70.33763161 W 149.21472574 TD (Projected) 9960.00 52.14 0.48 5117.50 5199.30 7038.83 7820.72 7039.28 3684.74 5997.84 0.00 5973736.83 596780.79 N 70.33777216 W 149.21472191 Survey Type: Definitive Survey NOTES: SLB NSG+SSHOT - (NorthSeeking Gyro Singleshots -- Northseeking gyro in gyrocomgassing or stationing mode with larger misalignment errors as a result of landing in a UBHO sub. Not to be run above 70 degrees inclination.) MWD+GMAG - (MWD + IFR +SLB Multi-station correction + Sag correction -- Standard SLB MWD error model where the surveys have been geomagneticailly reference (declination) corrected using a local crustal magnetic model and the SLB multistation drillstring magnetic interference correction GMAG (GeoMAGnetic Correction) under survey specialist supervision -and where the inclinations have then been corrected for BHA sag.) Survev Error Model: SLB ISCWSA version 24 *** 3-D 85.00% Confidence 2.7955 sigma Surveying Proa: MD From I ft 1 MD To 1 ft 1 EOU Frea Survev Tool Tvae Borehole -> Survev 0.00 27.80 Act-Stns SLB_NSG+SSHOT-Depth Only V-224P61 -> V-227P61 27.80 648.00 Act-Stns SLB_NSG+SSHOT V-224P81 -> V-227P61 648.00 1049.41 Act-Stns SLB_MWD+GMAG^^1 V-224PB1 -> V-227P61 1049.41 5420.76 Act-Stns SLB_MWD+GMAG^^1 V-224 -> V-224 5420.76 9894.83 Act-Stns SLB_MWD+GMAG^"2 V-224 -> V-224 9894.83 9960.00 Act-Stns SLB_BLIND V-224 -> V-224 Legal Description: Surface : 4729 FSL 1474 FEL S11 T11 N R11 E UM BHL : 3132 FSL 753 FEL S1 T11 N R11 E UM Northing IYI [ftUSI Easting 1X1 [ftUSI 5969980.10 590828.54 5973736.83 596780.79 u SurveyEditor Ver SP 2.1 Bld( users) Plan V Slot (S-Z)\V-224\V-224\V-224 Generated 1 /7/2010 1:57 PM Page 4 of 4 TREE _ 4-1 /16" CNV WELLHEAD = FM ACTUATOR = ~ectric KB. ELEV = 81.8 BF. ELEV - 53.3 KOP - 250 Max Angle= 71° @ 2482' Datum MD = 8771' Datum TV D = 4400 SS F~ ~20" CONDUCTOR -I- ~ 9-5/8" CSG, 40#, L-80, BTGM, IO = 8.835" ~ V-224 ES: 108' 24' 4-1/2" X 3-1/2" XO, ID = 2.992" 3902 3-1/2" HES X NIP, ID = 2.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 468' 10 8791 4494 53 MMG DCR RKP 0 12/16/09 WATER INJECTION MANDRELS 7" CSG, 26#, L-80 TCII XO TO L-80 BTGM ~ 6948 Minimum ID = 2.75"@ 9687' 3-1 /2" HES XN NIPPLE 3-1 /2" RA PIP TA G I-1 8800' 7' MARKER JOINT w /RA PIP TAG ~~ 8866 ST MD TVD DEV TYPE VLV LATCH PORT DATE 9 8868 4541 53 MMG-W DMY RK 0 12/16/09 8 8913 4567 53 MMG-W DMY RK 0 12/16/09 7 9167 4721 53 MMG-W DMY RK 0 12/16/09 6 9270 4784 53 MMG-W DMY RK 0 12/16/09 5 9307 4806 53 MMG-W DMY RK 0 12/16/09 4 9391 4856 53 MMG-W DMY RK 0 12/16/09 3 9475 4907 53 MMG-W DMY RK 0 12/16/09 2 9569 4963 53 MMG-W DMY RK 0 12/16/09 1 9622 4994 53 MMG-W DMY RK 0 12/16/09 8819' - ~ 3-1/2" HES X NIP, ID = 2.813" 8835' 7" X 3-1/2" BAKER, DUAL FEED PKR, ID = 2.965" 8847' 3-1/2" HES X NIP, ID = 2.813" 8853' 3-1/2" NDPG MULTI-SENSOR SUB , ID = 2.992" 9126 7" X 3-1/2" HES, DUAL FEED PKR, ID = 2.965" 9135 3-1/2" HES X NIP, ID = 2.813" 9141 ~ 3-1 /2" NDPG MULT~SENSOR SUB , ID = 2.992" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 53° @ 8884' Note: Ref er to Production DB for historical pert data SIZE SPF ZONE INTERVAL Opn/Sqz DATE 4-1/2" 5 Nb 8884-8916 O 12/11/09 4-1/2" 5 OBa 9228-9278 O 12/11/09 4-1/2" 5 OBb 9300-9330 O 12/11/09 4-1/2" 5 OBd 9490-9572 O 12/11/09 4-1/2" 5 Obe 9610-9652 O 12/11/09 L-1/2" TBG, 9.2#, L-80 TCII, .0087 bpf, ID = 2.992" H 9710' PBTD 9857' 7" CSG, 26#, L-80 BTGM, ID = 6.276" 9944 9286 --I7" X 3-1/2" HES, DUAL FEED PKR, ID = 2.965" 9295 3-1/2" HES X NIP, ID = 2.813" 9296' 3-1/2" NDPG MULTI-SENSOR SUB , ID = 2.992" 9419 -17" X 3-1/2" HES, DUAL FEED PKR, ID = 2.965" 9429' 3-1/2" HES X NIP, ID = 2.813" 1 9435' 3-1/2" NDPG MULTI-SENSOR SUB , ID = 2.992" 9588 --~ 7" X 3-1/2" HES,DUAL FEED PKR, ID = 2.965" 9597 3-1 /2" HES X NIP, ID = 2.813" 9602' 3-1/2" NDPG MULTI-SENSOR SUB , ID = 2.992" 9640 3-1/2" HES X NIP, ID = 2.813" 96$7' 3-1/2" HES XN NIP, ID = 2.750" 9710 3-1/2" WLEG, ID = 2.992" DATE REV BY COMMENTS DATE REV BY COMMENTS 12/17/09 N9ES ORIGINAL COMPLETION 12/18/09 SV DRLG HO CORRECTIONS OFtION UNff WELL: V-224 PERMfI' No: 2081540 API No: 50-029-2340-00 SEC 11, T11 N, R11 E, 4730' FSL & 1474' FEL BP Exploration (Alaska) ~ ~D zoJ'-/sy 1~EC~3ATlICAL INTEGRITY RL'PORT FUD v:.='. - l ~ ZG Zoa OPEA ~ FIELD ~ / `-- ~r~'a'ti ~a ~_ ;G ~ct,slc~; Z / zoo +.~LI.L NIJt'IDER V ~Zz~ ALL DATA TD s ~~;~~ D .3~.. S~~l ~ '3'V'D. ; : BTD : g57 ?~ID ~TVD ~''~ Casing : R ~ Shoa : `S~iID 3"c~ Y TvD ; Lv : -~ _:.~___ ~'-~-n `` ':'CP 2~ID ""'D i :cbi.^.g: ~ ~Z~` ~ Packer 8P~3,~M~~ ._ ___r_.__- Set ~t ale Site'" I Z. Z~ ~~ and ~ 7S ~~ Perfs ~ ~0 _~.__ 7 ' 1uQ / 0~ 5/'FN AS ' ~ ~~~ i CF.L iNTEGR3TY - ~' ART # ? ' t~.xinuius Press Tests :.'~ C?~ : ].5 mine; ?,0 mia~J~ ~-~'f ~~~'Sc. C ottttaen t s : ~ oa M ~~- o ~ 2-v sc; " '~SIE CHAN I C?Z TNTEGRII'Y -PART # 2 C l ~.s s ~ ~.. ~• ~- << t Ca.s;n. _ Cezuenc Volumes r ~.mt. 3.:~aer /~ S /3l3LGeg ~ DVS. ~ - - ~~ Ctat vol to coven ver~.s U2G bbt ~c tU® Theflretical TOC ~C~ ~. ~ ~~ ~~crts_ 5Z Z~ ~ ~ . ~ ~..,, T s~ ~. ~ i 'cx.~ ~~ bbl,, r~X. J Cement Bond Log es or No) C~C___S (~s In AOGCC F'iie C8L :,valuation, zone above perfs ~e»-,e.~ ~~~ r',S. 4'-.Xc~.~~`~ ~ Foss ~.er ~ ~~ ~ ~'~ ~'-t ~- ~ `~ ~ ~~ '~ ~-~5 ~ `te.v~., ~,~ e ~0 e-r`~5 . FroduCtion Log: TypE ~f t Evaluation l~ • coNCZ~vs~oNS : . e~ (T- ~ [A ~-X C~ bra ~~ ~ - ~l~ ,~~~Z~ ~- ~~ Schlum~erger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~~ ,~ ,~ Y ~-=i`"~'~d 3 ~•~ LOQ DesCfiotinn NO. 5447 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 -•• ~~~~a~ vaid venter LH2-1 Alaska Data & Consulting Services 900 E. Benson Blvd. 2525 Gambell street, suite 400 Anchorage, AK 99503-2838 Schfumher~er aska Data & Consulting Services ?5 Gambell Street, Suite 400 chorage,AK 99503-2838 TN: Beth Welt Job # NO. 5385 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 02-31A 17-09 12-30 17-09 13-27A JX-02A MPJ-19A L-103 W-217 12-05AL1 V-224 D-14A 11-27 3-27/M-33 8146-00087 B3S(~-00042 B9RH-00003 AWJB-00047 BALL-00009 AWJI-00065 AP3~-00075 BALL-00010 AYKP-00056 B2NJ-00025 AYKP-00059 AWJI-00060 AP3Q-00068 68K5-00012 SCMT ~ ~ TBG. CUT/FLOW DETECTION _ LDL ~ G MEM LDL USIT MEM LDL - USIT - RST/WFL - C CH EDIT PDC USIT _ MCNL _ CH EDIT PDC USI MCNL - C + RST ~j - ~ RST 12/24/09 01/05!10 12/26/09 01/03/10 12/31/09 12/29!09 12/29109 01/06/10 11/27/09 09/29/09 12/14/09 1111 rr/09 11/OW09 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 11/18/09 1 1 ACKNOWLEDGE REC EIPT BY SIGNIN G AND RETURNING ONE COPY EACH TO: :xploration (Alaska) Inc. technical Data Center LR2-1 E. Benson Blvd. r Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~" W-217i inadvertent surface hole~etrack • Page 1 of 2 .~ Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, November 30, 2009 9:19 AM To: 'Coolidge, Robert B' Cc: Davies, Stephen F (DOA) Subject: RE: Inadvertent surface hole sidetrad~ Permit # ZO&-~t54 tNelt: V-224 Robert, Thanks for the heads up on the inadvertent sidetrack. You are correct in calling the lost wellbore V-224PB1 . It should be assigned the PTD API number plus the prefix -70 The new wellbore will keep the original API number (50-029-23400-00) permitted for the well and will continue to keep the original well name V-224 . Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Coolidge, Robert B [mailto:coolrb@bp.com] Sent: Sunday, November 29, 2009 1:44 PM To: Schwartz, Guy L (DOA) Cc: Tirpack, Robert B; Hobbs, Greg S (ANC); NSU, ADW Drlg Rig 9es Subject: Inadvertent surface hole sidetrack Permit # 208-154 Welt: V-224 Guy, Yesterday, we had an inadvertant sidetrack of the surface hole in this well. Summary is as follows: Drilled to 2455' MD per plan, TOH to change Bit/BHA. TIH, STRING SAT DOWN @ 1,052' MD, WORK DOWN FROM 1,052 TO 1,303' MD. INDICATIONS WELL IS DRILLING new hale TAKE SURVEYS. SURVEYS INDICATE THAT HOLE IS SIDETRACKED. DRILL ONWARD TO 1874' AS OF 24:00 HOURS 11/28. CONTINUING TO DRILL NEW HOLE TO PLANNED CASING POINT. THE ORIGINAL HOLE WHICH WAS LOST HAS BEEN CALLED V-224PB1. The directional plan and targets have not changed . I would welcome your guidance to confirm API number and well name for old and new holes. Bob Bob Coolidge BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling Robert.Coolidge@bp.com Office: 907-564-5776 11/30/2009 W-217i inadvertent surface hole~etrack ~ Page 2 of 2 Cell: 907-980-7183 Fax: 907-564-4040 Home:345-1991 11/30/2009 • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 08, 2008 1:37 PM To: 'Tirpack, Robert B'; Ciolkosz, Ryan R Cc: Peltier, Brandon Subject: RE: V-224 Ryan, Thanks for the call. You are correct, sorry I missed that informa#ion. My question is answered. Tom Maunder, PE AOGCC From: Tirpack, Robert B [mailto:Robert.Tirpack@bp.com] Sent: Wednesday, October 08, 2008 11:09 AM To: Ciolkosz, Ryan R Cc: Peltier, Brandon; Maunder, Thomas E (DOA) Subject: FVV: V-224 Ryan -please take a look at Tom's question and respond. Thanks, Rob From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, October 08, 2008 10:46 AM To: Tirpack, Robert B Cc: Saltmarsh, Arthur C (DOA) Subject: V-224 Rob, Please pass to Ryan. 1 don't have his email. I am reviewing the permit application for this injection well. I do not find any statement regarding any wells that might exist within a % mile radius of V-224 beginning at the top of the SB and continuing to TD along the well trajectory. There is spider plot included in the directional section that appears to show all wells in the area. Based on the SB tvd interval given on page 7, it would appear that there is likely only 1 well, V-121, that is proximate. Would you please confirm that and include a statement regarding the effectiveness of the cement isolation through the SB sands? Call or message with any questions. Tom Maunder, PE AOGCC 10/8/2008 k .fir gd ~ ~ ~' ~, ALASSA OIL A1~TD GAS COI~TSERQATIOI~T CODIl~IISSIOIQ Robert Tirpack Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Orion/Schrader Bluff Oil Pool, PBU V-224 BP Exploration Alaska Inc. Permit No: 208-154 Surface Location: 4730' FSL, 1474' FEL, SEC. 11, T11N, R11E, UM Bottomhole Location: 3085' FSL, 4603' FWL, SEC. O1, T11N, R11E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced service well. Beginnings 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 iri the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659--3607 (pager). Sincerely, Daniel T. Searriount, Jr. Chair DATED this ~ day of October, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. b ~ STATE OF ALASKA ~ ~' `°"°" ':r /p.6-d~ ~ ,/~~~ ~ ~~~~ ALAS~IL AND GAS CONSERVATION COMMI~N ~ ~-~a ~; PERMIT TO DRILL to `~" 20 AAC 25.005 °`~ ~ ~ ~~~~ 1 a. Type of work ® Drill ^Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ StratigraphicTest ^ Development Oil ^ Single Zone 1 c. Specify if wqN 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: PBU V-224 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 9908' TVD 5169' 12. Field /Pool(s): Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): Surface: ~ ' ' 7. Property Designation: ADL 028240 Schrader Bluff FSL, 1474 FEL, SEC. 11, T11 N, R11 E, UM 4730 Top of Productive Horizon: ~ ~ 2261' FSL, 4445' FWL, SEC. 01, T11N, R11E, UM ~ 8. Land Use Permit: 13. Approximate Spud Date: November 15, 2008 Total Depth: ~~ ~ 3085' FSL, 4603' FWL, SEC. 01, T11 N, R11 E, U 9. Acres in Property: 2560 14. Distance to Nearest Property: 12,655' 4b. Location of Well (State Base Plane C ordi es): Surface: x-590829 y- 0 Zone-ASP4 10. KB Elevation Plan (Height above GL): 81.8 feet 15. Distance to Nearest Well Within Pool: 292' 16. Deviated Wells: Kickoff Depth. 250 feet Maximum Hole An le: 70 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2264 Surface: 1755 18. Casin Pro. ram: S cifi do s T - Se in De th -Bottom uanti of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 91.5# A-53 Weld 80' Surface Surface 80' 80' 260 sx Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BTC 5108' Surface Surface 5108' 2926' 814 sx Dee Crete 407 sx Class'G' 8-3/4" 7" 26# L-80 TCII /BTC-M g 7' urface Surface 9907' 5169' 103 sx Crete 54 sx lass 'G' 1 g. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 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 Ryan Ciolkosz, 564-5977 Printed Name Robert Tirpack Title Engineering Team Leader Prepared By Name/Number: Si nature Phone 564-4166 Date /fT Terrie Hubble, 564-4628 Commission Use'Onl Permit To Drill Number: v?~~/S API Number: 50-Oo?foZ~~00000a Permit A proval See cover letter for Date: ~ other re uirements Conditions of Approval: ~~~~~~`'~G`uC:\e~'f~dr~4~L1`~ L ~,~~~ ~©F't*"sW-~t~~~`~. If box is chec ed, well``may not be us o exp a or, test, or produce Coalbed r~net~h/ane, gas hydrates, or gas con ained shales: ,-,/ 1" l rT ~ ~~~ ~C~~~la ~ Samples Req'd: ^ Yes L~J No Mud Log Req'd: ^ Yes L-~ ~o ~.,~ ©®~ ` S ~ ~~ ~ ~~S ~ GS ~ G^~~ HZS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No Other: ~ ~;~ v`~C>;R ~F ~'~'~~~ Q (~-`~ \ ~C~LCb~ Cl~~ ~s~~ ~~o ~ ~/~ # GI/~G / APPROVED BY THE COMMISSION Date ,COMMISSIONER Form 10-401 Revised (2/2005 ~ J Submit In Duplicate tr ~'~t~~~~~ Well Name: V-2241 Drill and Complete Plan Summary T e of Well service / roducer / injector : WAG Injector Surface Location: As-Built X=590828.54 Y=5969980.1 4730' FSL, 1474' FEL, T11 N, R11 E, Sec. 11 Target Locations: Top Nb X=596710 Y=5972865 Z=4440 2261' FSL, 835' FEL, Ti 1 N, R11 E, Sec. 1 Top OBe X=596810 Y=5973425 Z=4865 2819' FSL, 727' FEL, T11 N, R11 E, Sec. 1 Bottom Hole Location: X =596857.51 Y =5973691.1 Z=5087 3085' FSL, 676' FEL, T11 N, R11 E, Sec. 1 Gre Bernaski Geolo ist 564-5464 Mike Warren Prod. En ineer 564-4306 R an Ciolkosz Drillin En ineer 564-5977 API NUMBER: TBD Estimated Start Date: 11 /15/2008 MD: 9908' TVD: 5169' Ri Nabors 9ES Operatin Days to complete: 18.5 RT/GL: 28.5'/53.3 RTE: 81.8' Well Design: Grassroots Schrader Bluff Injector 3'/z" tbg, 9.2# L80, TC-II, multi-packers, WAG Ob•ective: WAG injector into Schrader Bluff Nb, OBa, OBb, OBd and OBe sands Directional Plan: Version: Schlumberger P7b KOP: 250' MD, build 1.5/100 Maximum Hole An le: 69.56° Close Approach Wells: Nearest well within Pool: All wells pass major risk criteria. Reference anti-collision report V-121, 292' Distance to Nearest Property Line• 12,655' to PBU boundary Wells Within'/a mi. V-121, 292' TOC logged at 7710' MD, 584' MD above top sand. No anncomm anomalies. V-2241 Permit Application Page 1 Loaaina Proaram: Surface Interval Drilling, MWD: GR Open Hole: None Cased Hole: None Production Interval Drilling, MWD: GR, RES, NEU, Azimuthal Density, PWD (Realtime and Recorded Mode) Open Hole: None Cased Hole: USIT Prima De th Control Mode Mud Program: 12 ~/a" Surface Hole: Fresh Water Surface Hole Mud Density Funnel Plastic Yield Point API Fluid Interval (ppg) Viscosity Viscosity (Ib/100ft) Loss pH seconds/ t c mis/30min Initial to Base Perm 8.8 - 9.2 400 - 300 55 - 30 70 - 55 NC - 8.0 9.0 - 9.5 Base PF to top SV1 2 - 9 9 5 250 - 225 55 - 30 60 - 45 8.0 9.0 - 9.5 surface hole TD . . 8 3/a" Production Hole: LSND Mud Density Plastic Yield Point API Interval (ppg) Viscosity (Ib/100ft2) Fluid Loss pH MBT c ml/30 min SurfaceCsg. 88-92 12-18 18-24 <6.0 9-10 <18 Shoe to TD Casina/Tubina Proaram: Hole Size Csg/ Tb O.D. Wt/Ft Grade Connection Length Top MD/TVD Btm MDlTVD RTE 42" Insulated 20" 91.5 A-53 WLD 80' GL 80'/ 80' 12'/a" 9 / " 40 L-80 BTC 5108' GL 5108' / 2926' 8 3/a" 7" 26 L-80 TC-II 6608' GL 6608' / 3449' 8 3/a" 7" 26 L-80 BTC-M 3299' 6608' / 3449' 9907' / 5169' Tubin 3'/i" 9.2 L-80 TC-II 9727' GL 9727' / 5063' ~ Comments: ~ Tbg crossover to 4 ~/z" just below tree ~ Integrit Testin Test Point Depth Test Type 9 s/R" Surface Casina 20' - 50' from surface shoe LOT Cement Calculations: Casin Size Surface Casin - 9 5/8" 40 ppf L-80 BTC -Single Sta e Basis Lead: Open hole volume + 250% excess in permafrost, 40% excess below permafrost. TOC at surface. Tail: O en hole volume + 40% excess + 80' shoe track. TOC is 1000' ft above Surface Casin Shoe. Fluid Sequence and TAM port collar potentially run at 1,000' MD as a contingency for cement to surface. Volume: Wash None S acer 50 bbls of MudPush II wei hted to 10.0 Lead 558 bbls 814 sks 10.7 Dee CRETE cement - 3.85 ft /sk Tail 84 bbls 407 sks 15.8 Class G - 1.16 cuft/sk Temp BHST = 50° F from SOR V-2241 Permit Application Page 2 In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casin Size Production Casin - 7" 26 f L-80 BTC-M with TC-II crossover -Sin le Sta e Basis Lead: Open hole volume + 30% excess. TOC is 1000' MD below surface casing shoe. Tail: O en hole volume + 30% excess + 80' shoe track. TOC 500' MD above MA sandstone. Wash None S acer 30 bbls of MudPush II wei hted to 10.0 Lead 62 bbls 103 sks 12.5 CRETE - 3.27 ft /sk Tail 73 bbls 354 sks 15.8 Class G -1.16 ft /sk w/latex Temp BHST = 90° F from SOR Est. Formation To s Est. Formation To s Est. Formation To s Uncertaint Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. Formation MD TVD TVDss feet Yes/No Psi EMW G1 326.81 326.8 245 +/-50' No 110 8.7 SV6 995.37 986.8 900 +/-50' No 405 8.7 SV5 1804.1 1666.8 1585 +/-50' No 713 8.7 Base Permafrost 1979.64 1776.8 1690 +/-50' No 761 8.7 SV4 2030.5 1806.8 1720 +/-50' Gash drates 774 8.7 Fault 1 (V- Pad Fault 1895 +/- 100' M.D. n/a SV3 2903.66 2156.8 2070 +/-50' Gas h drates 932 8.7 SV2 3361.74 2316.8 2215 +/-50' Gas h drates 997 8.7 SV1 4406.72 2681.8 2570 +/-50' Gash drates 1157 8.7 Surf Casing Pt 5108.14 2926.8 2845 Fault #2 ossible 2920 +/- 100' M.D. n/a UG4 5337.18 3006.8 2925 +/-50' Thin Coal 1316 8.7 UG4A 5423.07 3036.8 2960 +/-50' Heavy Oil 2960'- 3010' SS 1332 8.7 UG3 3390 +/-50' Thin Coals; Heavy Oil 3850'- 3935' 1526 8.7 UG1 7952.81 4031.8 3935 +/-50' Heavy Oil 3770'- 3835' SS 1771 8.7 UG Ma 8389.13 4266.8 4185 +/- 30' No wet 1883 8.7 UG_Mb1 8465.86 4306.8 4225 +/- 30' No wet 1901 8.7 UG Mb2 8581.14 4371.8 4290 +/- 30' No wet 1931 8.7 UG_Mc 8697.61 4436.8 4355 +/- 30' No wet 1960 8.7 SB_Na 8821.11 4506.8 4425 +/- 30' No 1991 8.7 SB_Nb 8847.34 4521.81 4440 +/- 30' Yes 1998 8.7 SB_Nc 8908.16 4556.8 4475 +/- 30' No 2014 8.7 SB_Ne 8925.46 4566.8 4485 +/- 30' No 2018 8.7 SB OA 9096.43 4666.8 4585 +/- 30' No wet 1990- 8.4-8.6 V-224i Permit Application Page 3 2040 1980- SB_OBa 9205.7 4731.8 4650 +/- 30' Yes 2040 8.2-8.4 2020- SB_OBb 9280.54 4776.8 4695 +/- 30' Yes 2070 8.3-8.5 2050- SB_OBc 9379.31 4836.8 4755 +/- 30' No 2090 8.3-8.5 2080- SB_OBd 9468.89 4891.8 4810 +/- 30' Yes 2130 8.3-8.5 SB_OBe 9557.58 4946.81 4865 +/- 30' Yes 2165 8.6 SB_OBf 9637.44 4996.8 4915 +/- 30' Yes 2187 8.6 Base SB OBf 9700.85 5036.8 4955 +/- 30' No 2205 8.6 T.D. in Colville Shale 9907.57 5170 5087 No 2264 8.6 Well Control: The 12'/4" hole will be drilled with diverter. The 8 3/a" intermediate hole will use well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Annular preventer will be tested to 2500 psi. Rams will be tested to 4000 psi. The BOP test frequency will be conducted on a 14 day frequency, with a function test every 7 days. Except for significant operational issues that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- • Maximum anticipated BHP: 2264 psi C 5070' TVD, 8.6 ppg EMW (at Colville Shale, 9907' MD) • Maximum surface pressure: 1755 psi C surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) • Planned BOP test pressure: • Annular Preventer • Rams • Planned completion fluid: 250 / 2500 psi 250 / 4000 psi 9.0 ppg brine / 6.8 ppg diesel Kick Tolerance /Integrity Testing Summary Table Casing and Casing Test Maximum Mud Weight Exp Pore LOT / Interval Pressure` influx Press FIT Volume 95/8" Surface 3500 psi 51.3 BBLS 8.8 8.6 LOT Casing (assuming 10.8 LOT 7" Production 4000 psi NA NA NA NA Casin V-224i Permit Application Page 4 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-2241-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 700' below the top of the SV1. 4. Run and cement 9 5/8" surface casing. A TAM port collar may be run at 1000' as a contingency. Pressure test casing to 3500 psi for 30 minutes at plug bump. 5. ND diverter and NU casing /tubing head. NU BOPE 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. 9907' MD, 350' 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/ 245' of 4.5" Power Jet 4505 5 spf, pert guns with Anadrill LWD GR for gun correlation. "Before picking up guns, confirm with Asset Team to perforate OBe zone. 10. Space out pert guns by tagging PBTD and utilizing GR and RA tags in 7" casing. Once correlated correctly, circulate over to 9.0 ppg brine. Confirm cement compressive strength is at least 1000 psi before firing. Perforate Nb, OBa, OBb, OBd, and OBe. 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 from PBTD to surface casing shoe following Primary Depth Control procedures as USIT log will be primary depth control for future well work. 13. Run the 3-'/z", 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 OA 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 circulation ability. 16. Install and test TWC. Nipple down the BOPE. Nipple up and test double master valves 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-'/z" annulus valve and secure the well. Ensure that IA/OA are protected with two barriers. 19. RDMO. V-2241 Permit Application Page 5 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-224i Permit Application Page 6 • Drilling Critical Issues ..J POST THIS NOTICE IN THE DOGHOUSE 1. Well Control /Reservoir Pressures: A. Maximum reservoir pressures anticipated: Interval Psi EMW Tdl)ss ft MD ft Schrader Bluff 2040-2264 4585-5087 6100-6600 Sands 8.3-8.6 II. Hydrates and Shallow gas: A. Free gas and/or gas hydrates may be present in the SV5 through the SV1 surface hole below the Permafrost base. Use standard operating procedures for hydrates, if encountered. Set surface casing below deepest SVi sand hydrate zone to isolate gas bearing intervals behind cemented pipe in surface hole from intermediate hole section. III. Running Gravels: A. Unconsolidated sand, gravel, & cobbles and thawing permafrost could impede well angle build and casing running through permafrost. Keep moderate to low build angles until out of permafrost section. Keep flow rates low. Hazards include cobbles/boulders, running gravels, wood, lost circulation and tight hole problems while drilling and running casing. See V Pad data sheet for details. IV. Lost Circulation: A. Non-fault related drilling mud losses averaging 200 bph were in countered in V-218 when drilling into the SV2 interval. Smaller loss rates were also experienced while running casing in this offset well. If mud losses occur, reference standard operating procedures, including running LCM and increasing mud viscosity. V. Kick Tolerance /Integrity Testing: A. The 9 5/8" casing will be cemented to surface. A TAM port collar run at 1000' MD in the surface casing is contingency to get cement to surface. A LOT will be performed after drilling 20-50' of new formation after drilling out the 9 s/$" casing shoe. B. The 7" casing will be cemented to 1000' MD below the 9 5/g" casing shoe. Kick Tolerance /Integrity Testing Summary Table Casing and Casing Test Maximum Influx Mud Weight Exp Pore LOT / Interval Pressure Volume Press FIT 95/$" Surface 3500 psi 51.3 BBLS (assuming 8.8 8.7 LOT Casing 10.8 LOT 7" Production 4000 psi NA NA NA NA Casin V-2241 Permit Application Page 7 VI. Heavy Oil A. Heavy oil is expected in the UG4A and UG1 sand intervals which could result in plugging of shaker screens. Follow established operating practices for drilling in heavy oil zones; depths of heavy oil intervas are outlines in the Marker Tops section. VII. Hydrogen Sulfide A. All V Pad gas lift wells are expected to have H2S levels in the 10 to 300 ppm range; result of PBU gas lift gas. While no H2S is anticipated on this site, standard H2S precautions should be followed at all times. H2S Summa Table Well Name H S Level m Date of Readin #1 Closest SHL Well H2S Level V-100 No data. #2 Closest SHL Well H2S Level V-213 NA #1 Closest BHL Well H2S Level V-205 20 m 5/24/2008 #2 Closest BHL Well H2S Level V-01 10 m 11/11/2007 Max. Recorded H2S on Pad/Facilit V-117 300 m 4/3/2007 VIII. Faults A. Penetration of the V pad fault will occur during between drilling of the SV4 and the SV3 intervals. Fault depth is approx. 1895' (+/.100') TVDSS. Fault throw: southwest direction, approx. 85' -110'. B. Possible penetration of second fault in lower SVi interval. Fault depth is approx. 2920 (+/- 100') TVDSS. Fault throw: Northeast direction, approx 85' -110'. C. No faults are predicted in the injection interval. CONSULT THE V PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION V-2241 Permit Application Page 8 by V-224 (P7b) Proposal Schlumberger Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure 1 Slot: V-Pad / Plan V Slot (S-Z) well: Plan V-224 (SZ) ro e Borehole: ppp Plan V-224 UWIIAPI#: 50029 Survey Name 1 Date: V-224 (P7b) /August 18, 2008 Tort 1 AHD I DDI 1 ERD ratio: 136.167° 17756.02 ft / 6.306 11.500 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaVLong: N 70.32771235, W 149.26338218 Location Grid NIE YIX: N 5969980.100 ftUS, E 590828.540 ftUS Grid Convergence Angle: +0.69362834° 8 Vertical Section Azimuth: 81O Vertical Section Origin: 59.080° N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 81.80 ft relative to MSL Sea Bed I Ground Level Elevation: 53.30 ft relative to MSL Magnetic Declination: 22.697° Total Field Strength: 57671.373 nT Magnetic Dip: 80.870° Declination Date: November 18, 2008 Magnetic Declination Model: BGGM 2008 North Reference: TNe Norlh Total Corr Mag North -> True North: +22.697° Local Coordinates Referenced To: Well Head CJ Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ff de de ff ff ff ff ft de de 1100 ft Index ffUS ffUS RIC WRP Bld 1.5/100 G1 Bld 2.5/100 Crv 2.5/100 S V6 Bld 4/100 U.UU 28.50 250.00 300.00 326.81 350.00 400.00 500.00 550.00 600.00 700.00 800.00 900.00 990.18 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 U.VV 0.00 0.00 0.75 1.15 1.50 2.75 5.25 6.50 7.15 8.88 10.95 13.21 15.33 15.57 19.57 23.57 27.57 31.57 35.57 1600.00 1700.00 39.57 43.57 WeIlDesign Ver SP 2.1 Bld( doc40x_100 ) JV.UU 30.00 30.00 30.00 30.00 30.00 30.00 30.00 30.00 39.48 53.45 62.54 68.67 72.64 73.01 -61.8U U .UU U.UU V.VV V.UU --- U.UU U.UU Uy0yyr5V.lV -53.30 28. 50 0.00 0.00 0.00 --- 0.00 0.00 5969980.10 168.20 250 .00 0.00 0.00 0.00 30.OOM 0.00 0.00 5969980.10 218.20 300 .00 0.29 0.28 0.16 30.OOM 1.50 0.00 5969980.39 245.00 326. 80 0.67 0.67 0.39 30.OOM 1.50 0.00 5969980.77 268.19 349.99 1.14 1.13 0.65 30.OOM 1.50 0.29 318.15 399.95 2.76 2.74 1.58 30.OOM 2.50 0.94 417.90 499.70 8.86 8.78 5.07 HS 2.50 1.73 467.64 549.44 13.33 13.21 7.63 64.85R 2.50 2.00 517.29 599.09 18.74 18.06 11.02 55.44R 2.59 2.22 616.31 698.11 32.28 27.46 21.18 41.60R 2.59 2.56 714.82 796.62 49.44 36.44 35.81 32.64R 2.59 2.83 812.60 894.40 70.19 44.98 54.88 26.64R 2.59 3.06 900.00 981.80 91.95 52.28 75.87 22.80R 2.59 3.24 909.46 991.26 94.49 53.06 78.37 HS 2.59 3.25 73.01 1004.78 1086.58 123.78 61.87 107.23 HS 4.00 3.46 73.01 1097.76 1179.56 159.46 72.61 142.38 HS 4.00 3.64 73.01 1187.94 1269.74 201.34 85.22 183.65 HS 4.00 3.81 73.01 1274.90 1356.70 249.23 99.64 230.84 HS 4.00 3.96 73.01 1358.21 1440.01 302.89 115.80 283.71 HS 4.00 4.09 73.01 1437.45 1519.25 362.06 133.61 342.01 HS 4.00 4.22 73.01 1512.25 1594.05 426.45 152.99 405.45 HS 4.00 4.34 Plan V Slot (S-Z)\Plan V-224 (SZ)\Plan V-224\V-224 (P7b) 5969981.24 5969982.86 5969988.94 5969993.40 5969998.29 5970007.82 5970016.97 5970025.73 5970033.29 5970034.10 5970043.26 5970054.43 5970067.53 5970082.52 5970099.31 5970117.83 5970137.98 OyUifZi5.04 N /U.SZ//1Z3b VV 14`J.Yb33i5Yltf 590828.54 N 70.32771235 W 149.26338218 590828.54 N 70.32771235 W 149.26338218 590828.70 N 70.32771312 W 149.26338085 590828.92 N 70.32771418 W 149.26337905 590829.18 N 70.32771545 W 149.26337687 590830.09 N 70.32771983 W 149.26336935 590833.50 N 70.32773634 W 149.26334107 590836.01 N 70.32774844 W 149.26332032 590839.34 N 70.32776170 W 149.26329281 590849.38 N 70.32778738 W 149.246 590863.90 N 70.32781190 W 149.2 181 590882.87 N 70.32783522 W 149.26293713 590903.76 N 70.32785518 W 149.26276697 590906.25 N 70.32785729 W 149.26274671 590935.00 N 70.32788138 W 149.26251265 590970.02 N 70.32791072 W 149.26222760 591011.13 N 70.32794517 W 149.26189294 591058.13 N 70.32798455 W 149.26151031 591110.80 N 70.32802868 W 149.26108156 591168.87 N 70.32807734 W 149.26060879 591232.07 N 70.32813028 W 149.26009431 Generated 8/18/2008 12:00 PM Page 1 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 725UU.VV 4/.5/ /J.VI 15i5L.L4 lbb4.U4 4`JD./4 "I/3.t5b 4/3./3 r1J 4.UU 4.44 D`J/Ulb`J.bb b`J 13UU.U`J IV /U .3LtSltS/L/ VV l4y.Lbyb4UbV SV5 1804.10 47.73 73.01 1585.00 1666.80 498.68 174.74 476.63 HS 4.00 4.45 5970160.58 591302.97 N 70. 32818968 W 149.25951712 1900.00 51.57 73.01 1647.08 1728.88 569.61 196.09 546.52 HS 4.00 4.54 5970182.78 591372.59 N 70. 32824801 W 149.25895038 End Crv 1954.27 53.74 73.01 1680.00 1761.80 611.49 208.70 587.78 -- 4.00 4.60 5970195.88 591413.69 N 70. 32828244 W 149.25861576 Base Perm 1971.18 53.74 73.01 1690.00 1771.80 624.72 212.68 600.82 --- 0.00 4.61 5970200.02 591426,68 N 70. 32829332 W 149.25851003 Bld 4/100 2013.45 53.74 73.01 1715.00 1796.80 657.80 222.64 633.41 HS 0.00 4.63 5970210.37 591459.15 N 70. 32832052 W 149.25824569 SV4 2021.94 54.08 73.01 1720.00 1801.80 664.46 224.65 639.97 HS 4.00 4.64 5970212.46 591465.69 N 70. 32832600 W 149.25819249 2100.00 57.20 73.01 1764.05 1845.85 726.99 243.48 701.59 HS 4.00 4.71 5970232.03 591527.07 N 70. 32837742 W 149.25769279 2200.00 61.20 73.01 1815.24 1897.04 810.35 268.57 783.73 HS 4.00 4.79 5970258.12 591608.88 N 70. 32844596 W 149.25702673 2300.00 65.20 73.01 1860.31 1942.11 896.97 294.65 869.07 HS 4.00 4.87 5970285.22 591693.90 N 70. 32851718 W 149.25633461 Fault Crossing 2388.71 68.75 73.01 1895.00 1976.80 976.20 318.51 947.14 HS 4.00 4.94 5970310.02 591771.66 N 70. 32858233 W 149.25 154 2400.00 69.20 73.01 1899.05 1980.85 986.43 321.59 957.22 HS 4.00 4.95 5970313.22 591781.71 N 70. 32859074 W 149. 78 End Bld 2408.83 69.56 73.01 1902.16 1983.96 994.45 324.01 965.12 --- 4.00 4.95 5970315.73 591789.58 N 70. 32859734 W 149.2 567 SV3 2889.35 69.56 73.01 2070.00 2151.80 1431.47 455.59 1395.71 --- 0.00 5.16 5970452.51 592218.51 N 70. 32895664 W 149.25206367 SV2 3304.48 69.56 73.01 2215.00 2296.80 1809.01 569.28 1767.71 --- 0.00 5.29 5970570.68 592589.07 N 70. 32926700 W 149.24904673 SV1 4320.83 69.56 73.01 2570.00 2651.80 2733.36 847.60 2678.47 --- 0.00 5.52 5970859.99 593496.31 N 70. 33002663 W 149.24166005 9-5/8" Csg Pt 5108.14 69.56 73.01 2845.00 2926.80 3449.40 1063.21 3383.99 --- 0.00 5.65 5971084.10 594199.10 N 70. 33061486 W 149.23593760 UG4 5337.18 69.56 73.01 2925.00 3006.80 3657.70 1125.93 3589.23 --- 0.00 5.68 5971149.29 594403.54 N 70. 33078595 W 149.23427283 UG4A 5437.38 69.56 73.01 2960.00 3041.80 3748.83 1153.37 3679.02 --- 0.00 5.70 5971177.82 594492.99 N 70. 33086080 W 149.23354448 UG3 6668.46 69.56 73.01 3390.00 3471.80 4868.45 1490.50 4782.19 --- 0.00 5.84 5971528.24 595591.90 N 70. 33178011 W 149.22459578 Crv 4/100 6948.37 69.56 73.01 3487.77 3569.57 5123.02 1567.16 5033.02 116. 12E 0.00 5.87 5971607.92 595841.76 N 70. 33198907 W 149.22256100 7000.00 68.66 71.02 3506.18 3587.98 5170.04 1582.05 5078.90 115. 41 L 4.00 5.89 5971623.37 595887.45 N 70. 33202967 W 149.22218881 7100.00 66.99 67.09 3543.94 3625.74 5261.21 1615.13 5165.36 113. 93E 4.00 5.92 5971657.48 595973.50 N 70. 33211988 W 149.22148734 7200.00 65.42 63.07 3584.31 3666.11 5352.18 1653.65 5248.33 112. 31 L 4.00 5.95 5971697.01 596055.98 N 70. 33222496 W 149.22081424 7300.00 63.95 58.95 3627.08 3708.88 5442.49 1697.43 5327.38 110. 55E 4.00 5.98 5971741.73 596134.49 N 70. 33234441 W 149.22017279 7400.00 62.61 54.73 3672.05 3753.85 5531.72 1746.25 5402.15 108. 65E 4.00 6.01 5971791.45 596208.65 N 70. 33247765 W 149.21956611 7500.00 61.40 50.41 3719.01 3800.81 5619.42 1799.88 5472.25 106. 62E 4.00 6.03 5971845.92 596278.10 N 70. 33262402 W 149.21899715 7600.00 60.33 46.00 3767.71 3849.51 5705.17 1858.06 5537.36 104. 47E 4.00 6.06 5971904.88 596342.49 N 70. 33278281 W 149.21846870 7700.00 59.40 41.50 3817.94 3899.74 5788.55 1920.49 5597.16 102. 21 L 4.00 6.08 5971968.02 596401.52 N 70. 33295326 W 149.232 7800.00 58.64 36.92 3869.43 3951.23 5869.15 1986.88 5651.35 99. 85E 4.00 6.10 5972035.06 596454.90 N 70. 33313452 W 149.2 337 7900.00 58.04 32.28 3921.94 4003.74 5946.59 2056.91 5699.67 97. 41 L 4.00 6.12 5972105.66 596502.37 N 70. 33332573 W 149.21715101 UG1 7924.63 57.91 31.12 3935.00 4016.80 5965.13 2074.67 5710.64 96.80E 4.00 6.13 5972123.55 596513.12 N 70. 33337423 W 149.21706191 8000.00 57.61 27.58 3975.22 4057.02 6020.48 2130.23 5741.88 94. 9'1 L 4.00 6.15 5972179.48 596543.69 N 70. 33352594 W 149.21680815 8100.00 57.35 22.84 4029.00 4110.80 6090.46 2206.48 5777.79 92. 36E 4.00 6.17 5972256.15 596578.66 N 70. 33373418 W 149.21651645 8200.00 57.28 18.09 4083.02 4164.82 6156.20 2285.30 5807.21 89. 80E 4.00 6.19 5972335.31 596607.12 N 70. 33394944 W 149.21627734 8300.00 57.38 13.34 4137.02 4218.82 6217.37 2366.29 5829.99 87. 23E 4.00 6.21 5972416.57 596628.92 N 70. 33417066 W 149.21609198 Drp 0.5/100 8353.28 57.51 10.82 4165.69 4247.49 6247.99 2410.20 5839.39 --- 4.00 6.22 5972460.59 596637.79 N 70. 33429060 W 149.21601550 8353.29 57.51 10.82 4165.70 4247.50 6247.99 2410.21 5839.39 LS 0.00 6.22 5972460.59 596637.79 N 70. 33429062 W 149.21601549 Ma 8389.13 57.33 10.82 4185.00 4266.80 6268.10 2439.88 5845.06 LS 0.50 6.22 5972490.32 596643.09 N 70. 33437165 W 149.21596933 8400.00 57.28 10.82 4190.87 4272.67 6274.19 2448.86 5846.77 LS 0.50 6.22 5972499.33 596644.70 N 70. 33439619 W 149.21595534 We1lDesign Ver SP 2.1 Bld( doc40x_100) Plan V Slot (S-Z)\Plan V-224 (SZ)\Plan V-224\V-224 (P7b) Generated 8/18/2008 12:00 PM Page 2 of 3 Measured Vertical Mag 1 Grav Directional Comments Inclination Azimuth Sub-Sea ND ND 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 M07 C46Z.Ctl 06.Yb 7U.tlZ 4ZZb.VU 43UO.t3U OJUy.JJ ZSUU. /7 OtfDO.OG LJ U.DV O.ZZ OJ/ZO07.Z`J Oy0003.ytl /V /U.3J4~J/CJ W 74y.Y1~tt/465 8500.00 56.77 10.82 4245.30 4327.10 6330.03 2531 .26 5862.52 LS 0.50 6.23 5972581.90 596659.45 N 70.33462126 W 149.21582712 Mb2 8581.14 56.37 10.82 4290.00 4371.80 6375.11 2597. 77 5875.23 LS 0.50 6.23 5972648.56 596671.35 N 70.33480295 W 149.21572360 8600.00 56.27 10.82 4300.46 4382.26 6385.56 2613 .19 5878.17 LS 0.50 6.23 5972664.01 596674.11 N 70.33484505 W 149.21569961 Mc 8697.61 55.78 10.82 4355.00 4436.80 6439.45 2692. 69 5893.37 LS 0.50 6.24 5972743.68 596688.33 N 70.33506222 W 149.21557586 8700.00 55.77 10.82 4356.35 4438.15 6440.77 2694 .64 5893.74 LS 0.50 6.24 5972745.63 596688.68 N 70.33506753 W 149.21557283 8800.00 55.27 10.82 4412.96 4494.76 6495.65 2775 .61 5909.21 LS 0.50 6.25 5972826.77 596703.17 N 70.33528870 W 149.21544680 Na 8821.11 55.16 10.82 4425.00 4506.80 6507.19 2792. 63 5912.46 LS 0.50 6.25 5972843.84 596706.22 N 70.33533520 W 149.21542029 V-224 Tgt 1 Nb 8847.32 55.03 10.82 4440.00 4521.80 6521.50 2813 .75 5916.50 HS 0.50 6.25 5972865.00 596710.00 N 70.33539289 W 149.21538742 Nb 8847.34 55.03 10.82 4440.01 4521.81 6521.51 2813. 76 5916.50 180.00E 0.50 6.25 5972865.01 596710.00 N 70.33539293 W 149.21538740 8900.00 54.77 10.82 4470.29 4552.09 6550.19 2856 .08 5924.59 180.00E 0.50 6.25 5972907.42 596717.58 N 70.33550852 W 149.2 52 Nc 8908.16 54.72 10.82 4475.00 4556.80 6554.63 2862. 62 5925.84 180.00E 0.50 6.25 5972913.98 596718.75 N 70.33552639 W 149.2 33 Ne 8925.46 54.64 10.82 4485.00 4566.80 6564.02 2876. 49 5928.49 180.00E 0.50 6.25 5972927.87 596721.23 N 70.33556425 W 149.21528975 9000.00 54.26 10.82 4528.34 4610.14 6604.40 2936 .06 5939.87 180.00E 0.50 6.26 5972987.57 596731.89 N 70.33572697 W 149.21519702 OA 9096.43 53.77 10.82 4585.00 4666.80 6656.35 3012. 70 5954.52 180.00E 0.50 6.26 5973064.38 596745.61 N 70.33593633 W 149.21507771 9100.00 53.76 10.82 4587.11 4668.91 6658.26 3015 .53 5955.06 180.00E 0.50 6.26 5973067.21 596746.11 N 70.33594405 W 149.21507331 9200.00 53.25 10.82 4646.59 4728.39 6711.78 3094 .49 5970.15 180.00E 0.50 6.27 5973146.34 596760.24 N 70.33615973 W 149.21495039 OBa 9205.70 53.22 10.82 4650.00 4731.80 6714.82 3098. 98 5971.01 180.00E 0.50 6.27 5973150.84 596761.05 N 70.33617199 W 149.21494341 OBb 9280.54 52.84 10.82 4695.00 4776.80 6754.63 3157. 71 5982.23 180.00E 0.50 6.27 5973209.70 596771.55 N 70.33633240 W 149.21485199 9300.00 52.75 10.82 4706.77 4788.57 6764.95 3172 .93 5985.14 180.00E 0.50 6.27 5973224.96 596774.28 N 70.33637399 W 149.21482829 OBc 9379.31 52.35 10.82 4755.00 4836.80 6806.86 3234. 77 5996.96 180.00E 0.50 6.28 5973286.93 596785.35 N 70.33654291 W 149.21473203 9400.00 52.24 10.82 4767.65 4849.45 6817.76 3250 .85 6000.03 180.00E 0.50 6.28 5973303.04 596788.22 N 70.33658683 W 149.21470700 OBd 9468.89 51.89 10.82 4810.00 4891.80 6853.93 3304. 22 6010.22 180.00E 0.50 6.28 5973356.52 596797.77 N 70.33673260 W 149.21462393 9500.00 51.74 10.82 4829.23 4911.03 6870.21 3328 .24 6014.81 180.00E 0.50 6.29 5973380.60 596802.07 N 70.33679822 W 149.21458654 V-224 Tgt 2 OBe 9557.57 51.45 10.82 4865.00 4946.80 6900.24 3372 .55 6023.28 LS 0.50 6.29 5973425.00 596810.00 N 70.33691925 W 149.21451758 OBe 9557.58 51.45 10.82 4865.01 4946.81 6900.25 3372. 56 6023.28 LS 0.50 6.29 5973425.01 596810.00 N 70.33691928 W 149.21451756 9600.00 51.23 10.82 4891.51 4973.31 6922.30 3405 .09 6029.50 LS 0.50 6.29 5973457.62 596815.82 N 70.33700814 W 149.21446692 OBf 9637.44 51.05 10.82 4915.00 4996.80 6941.71 3433. 73 6034.97 LS 0.50 6.29 5973486.32 596820.94 N 70.33708637 W 149.21442235 9700.00 50.73 10.82 4954.46 5036.26 6974.02 3481 .41 6044.08 LS 0.50 6.30 5973534.10 596829.47 N 70.33721660 W 149.214 OBf Base 9700.85 50.73 10.82 4955.00 5036.80 6974.46 3482. 06 6044.20 LS 0.50 6.30 5973534.74 596829.59 N 70.33721837 W 149.21434713 9800.00 50.23 10.82 5018.09 5099.89 7025.37 3557 .18 6058.56 LS 0.50 6.30 5973610.03 596843.03 N 70.33742357 W 149.21423019 9900.00 49.73 10.82 5082.39 5164.19 7076.36 3632 .41 6072.93 LS 0.50 6.31 5973685.42 596856.49 N 70.33762905 W 149.21411310 TD / 7" Csg 9907.57 49.70 10.82 5087.28 5169.08 7080.20 3638 .08 6074.01 --- 0.50 6.31 5973691.10 596857.51 N 70.33764454 W 149.21410427 Legal Description: Northing IY1 fftUSl Easting fX- fftUSl Surface : 4729 FSL 1474 FEL S11 T11N R11E U M 5969980.10 590828.54 V-224 Tgt 1 Nb : 2261 FSL 835 FEL S1 T11 N R11 E UM 5972865.00 596710.00 V-224 Tgt 2 OBe : 2819 FSL 727 FEL S1 T11N R11E UM 5973425.00 596810.00 BHL : 3085 FSL 676 FEL S1 T11 N R11 E UM 5973691.10 596857.51 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Plan V Slot (S-Z)\Plan V-224 (SZ)\Plan V-224\V-224 (P7b) Generated 8/18/2008 12:00 PM Page 3 of 3 by Schlumberger yyELL FIELD STRUCTURE V-224 (P7b) Prudhoe Bay Unit - WOA V-Pad Magnetic Parameters SuRace Location NAD2] AMSka SIa1e Plarres. Zme 04. US Feet Miscellaneous Mo°el'. BGGM 2008 Dip: BO BIO° Dale: Novambe118. 2008 Lal'. N10 t9 39.164 Natbm9: 5969960.10 XUS Gritl Conv: b 693fi2fi34° Slol'. PNn V Slol (5-Z) ND Rel'. Rotary Table (81.80 ft above MSL( Mag Dec. •2269]° PS'. 4nT Lon. W149 1548.116 Easling: 59082654 flUS Srale Fact'.0.999093116 Plan: V-224 (P]b) Srvy Dale. August 18, 2008 0 1000 2000 3000 4000 5000 6000 7000 0 1000 ~ 2000 O O O C N N in 3000 H 4000 5000 .....................' 7.~.............................................................................................................. WRP Bld 1.51100 ._.. _.. _.. _. _.._. _ .._.._.._.. _.._.._.._..y. _..-.._.._.._.._.._.. .F. _..-..-..-.._, eid zs~ioo crv z.s/ioo B(d aioo End Crv; ' B1d 4110_0 ._.._.._.._.. _.. _..:.._. End Bld ......................i................................. ............................... z..... ._.. _.. _.._.. _j. ..-..-..-..-..-.. -..-. ..-..-..-..-.._.. _.._ ..j.. -. ._.._.. _.._.._i._.._.._..-..-..-..-.._...a. .._ ...... .............................. ............................. ............................. .............. 0 .. _.. _. i-..-..-..-..-..-.._.. _..-.i-..-.._..-..-.._..-..-..-i._.._..-..-.._..-..-..-..K..-..-.. _.. _.. ...............i...................................j..................................j..................................~...................................j..................Z -.. _..~.._.. _.._..-..T-518"~s .' ._..-..-..-..-..-.._.i_..-..-.._..-..-.._.._.._1.-..-..-..-..-..-.._..-.. i.. _.._.._.._ 9 P~ .._. crv anoo 000 )00 )00 000 000 0 1000 2000 3000 4000 5000 6000 7000 Vertical Section (ft) Azim = 59.08°, Scale = 1(in):1000(ft) Origin = 0 N/-S, 0 E/-V by Schlumherger WELL FIELD STRUCTURE V-224 (P7b) Prudhoe Bay Unit - WOA V-Pad Magnetic Parameters Surrace LOCalbn NAD2]Alaska Slate Planes, ZOna 04. US Feel Miscellaneous Model: BGGM 2038 Dip: 80.810° OMe: November 18. 2008 Lat: N]01939.]64 NonMng: 5969980.10 hUS Grit D011V: •069362634° SbL PIan V Sld (527 TVO ReI: Rotary TaEle (81.BOfl above MSLI Mag Dec: •22.69]° FS: 5]6]1inT Lon: Wt49 1546.1 ]6 Easting: 5906 28 54 110 5 Style Fad:09999093]ifi PIan: V-224 (P]8) Srvy Date: August 18, 2008 0 800 1600 2400 3200 4000 4800 5600 6400 4000 3200 n n n Z 2400 0 0 c a~ ~ 1600 v v v 800 0 4000 3200 4580ss 2400 1600 800 0 0 800 1600 2400 3200 4000 4800 5600 6400 «< W Scale = 1(in):800(ft) E »> Field: Prudhoe Bay Site: PB V Pad Well: Plan V-224 (S-G) Wellpath: Plan V-224 i ~'1an -224 (S-Z},/PIan~V-22 --- -!_ __ ~ - Y --_-- ~- ~~ ~ !i ~ ,'I i ~ ~~ ~~I~ I ~I Oilfield Services, Alaska Schlumberger Drilling & Measurements 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8367 Monday, August 18, 2008 Ryan Ciolkosz BP Exploration (Alaska) Inc. Sehlumberger Prudhoe Bay V-224 (P7b) Nabors 9ES Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analysis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two hundred feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey Program: Instrument Type Start Depth End Depth GYD GC SS 28.50' and 600.00' and MWD 600.00' and 2000.00' and MWD + IFR + MS 600.00' and 9907.57' and Close Approach Analysis results: Under method (2), note. All drilled wells pass major risk. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drilling Aids to be provided: A drilling map and traveling cylinder will be provided. Checked by: Scott DeLapp 08/18/2008 _ __. - - - -- --- - -_ BP Alaska Company: BP Amoco Date: 8/18/2008 Time: 12:18:44 Page: 1 Field: Prudhoe Bay ReferenceSitc: PB V Pad Co-ordinatc (NE) Rete rence: WeIL' Plan True North V-224 (S-Z) , Reference Well: Plan V-224 (S-Z) Vertical ('CVD) Refere nce: V-224 Pla n SZ 81.8 Reference ~i ellpath : Plan V-224 Db: Oracle GLOBAL SCAN A PPLIED: All wellpaths within 200'+ 100/1000 of reference -There are «i~li~ells in thisi3iadlttlpal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse -- Depth Range: - 0 7:57- ft- _ -- - -- - - - - - - Sa:an Method: ~7av C ylinderNortlr- _ -- Maximum Radius: 1187.91 ft Error Surface: Ellipse + Casing -- - - __ - --- -- - - Survey Program for Definitive Wellpath _- __ I Date: 10/10/200 7 Validated: No Version: 16 _----- . __~--P-lanwed-From--To c•••~•,e3~ T~~Icode- T-0olName- --.. ft ft ~~ 28.50 600_ 00 _. _Planned;_Pla n #7 V-224 V1__ -__-- GYD-GC-S$ __ Gyrodata gKro single-shots _ 600.00 2000. 00 Planned: Pla n #7 V-224 V1 MWD MWD - Standard ~', 600.00 5050. 00 Planned: Pla n #7 V-224 V1 MWD+IFR +MS MWD +IFR + Mu lti Station - ---- 50-50-0~s399~ 57 WaRned:-PFa n~7 `~ 224 ~~'~ n~~nm~~ro ~r,~c ~YIWD-+-IFR +-Mu lti-Station -_----- i --_._ Casing Points MD "fV D Diameter Hole Size Name ft ft in in 5108.14 2926. 80 9.625 12.250 9 5/8" 9907.57 5169. 09 7.000 8.750 7" Summary - - -- -- G-----~-------------- Ofi'set Wellpath --- - ---> Reference Offset Ctr-Ctr No-Go - Allowable - Site Well Wellpath MD I~ID Distance Area Deviation Warning - _.-- ft ft ft ft ft PB V Pad Plan V-123 (NP) Plan V-123 V3 Plan: PI 425.61 425.00 235.27 8.02 227.24 Pass Major Risk PB V Pad Plan V-219 (S-Y) Plan V-219 V3 Plan: PI 403.62 405.00 15.93 7.62 8.30 Pass Major Risk - -RB~Pad- °lar `~ o-~"a(N-`F) PIan~27~3~IerrP~ 734:66 -~30~E~ 1602- -1-39- 1-5553- -Kass. h9ajorRisk - --- - PB VPad Plan V-228 (S-S) Plan V-228 V2 Plan: PI 357.11 360.00 105.97 6.76 99.21 Pass: Major Risk I~ PB V Pad V-01 V-01 V15 336.36 340.00 180.69 6.09 174.59 Pass: Major Risk PB V Pad V-03 V-03 V7 754.93 675.00 171.44 12.00 159.44 Pass: Major Risk PB V Pad V-04 V-04 V7 550.67 550.00 246.48 10.12 236.36 Pass: Major Risk I PB V Pad V-100 V-100 V7 332.24 -335.00 61.21 5.75 55.46-_ Pass; Major Risk PB V Pad _ _ _ _ V-103 _ V-103 V6 355.93 _ 355.00 210.68 6.24 204.44 Pass: Ma or Risk i j PB V Pad V-105 V-105 V13 637.32 650.00 246.76 10.96 235.80 Pass: Major Risk - - - ~ B-V P-ad ~ !-406- - - - ~1-106~F'FO 52~~ 529.0~ 22~5-5- ---€~2~ - 214:33 ~as~ ~~- - PB V Pad V-106 V-106A V9 148.99 150.00 225.66 3.17 222.49 Pass: Major Risk '~ PB V Pad V-106 V-106AP61 V7 148.99 150.00 225.66 3.17 222.49 Pass: Major Risk rt ~SVFa~ _ 17=i06 _ -V-fiU6APB2 V2 - _ -T48:99-- -~5~00 ZZ~66 -3:17 22:49 _ asps: IVlalor iR`s c~ i --- PB V Pad V-106 V-106AP63 V2 148.99 150.00 225.66 3.17 222.49 Pass: Major Risk ~, PB V Pad V-111 V-111 V25 735.07 740.00 179.09 13.32 165.77 Pass: Major Risk ~ PB V Pad V-111 V-111 PB1 V9 739.72 745.00 179.17 15.66 163.50 Pass: Major Risk PB V Pad V-111 V-111 P62 V2 739.72 745.00 179.17 15.66 163.50 Pass: Major Risk - !~ ~B~F R,ad -~14 - -_ - af-4~1fzB3V6 7~58T ~40~OA ~a~09 13:32- 1657 Pass: Major Risk__.---- -- ------ --- ', PB V Pad V-115 V-115 V5 437.34 440.00 28.87 7.34 21.52 Pass: Major Risk PB V Pad V-115 V-115L1 V1 437.34 440.00 28.87 7.04 21.82 Pass: Major Risk _ ` PB VFad _-- - - ~T'f5L7V0 X37:34- X40:00 _- 287- -x:34 Tr52- - Pass: Major- iR`s c~~ - PB VPad V-115 V-115L2P61 V3 437.34 440.00 28.87 7.04 21.82 Pass: Major Risk __ PB V _Pad -_ V-115- ______ V-115PB1 _V4 437.34 __ -_440.00 28.87 7.34 21.52_ Pass: Maa~or Risk--__. I PB V Pad V-117 V-117 V9 558.25 570.00 94.34 9.55 84.79 Pass: Major Risk '~ PB V Pad V-117 V-117PB1 V6 558.25 570.00 94.34 9.55 84.79 Pass: Major Risk -RB ~/ Pad---- _-V-14~ - V=F47P132 V6 _ _ 558.25 570~ ~94.34 9=5-5- 84.79 P-ass:-Major Risk- - PB V Pad V-120 V-120 V6 547.11 535.00 188.45 11.22 177.23 Pass: Major Risk ', PB V Pad V-121 V-121 V5 9677.43 9215.00 189.24 184.35 4.89 Pass: Major Risk i PB V Pad V-122 V-122 V10 435.67 440.00 73.26 7.78 65.48 t Pass: Major Risk PB V Pad V-122 V-122P61 V10 435.67 440.00 73.26 7.78 65.48 Pass: Major Risk PB V Pad _ V_-1.22. _ _ __- __V-122P62 V7 -_ - 435.67 440.00_ _ 73.26__ .._-7.78_ 65.48 _ Pass: Major Risk PB V Pad V-205 V-205 V14 326.79 330.00 150.91 6.02 144.88 Pass: Major Risk PB V Pad V-205 V-205L1 V9 326.79 330.00 150.91 6.02 144.88 Pass: Major Risk _ - _PB-VPad- - ~F-2~}5 aF-205E-2~F8 - 326.79. 33E1.00 ~SE~sJ'~ ~'r.02-.. .144.88 ~as~Major Risk _ ~ - - - PB V Pad V-207 drilling Plan V-207L3 OBa V2 PI 1249.28 1265.00 115.23 23.21 92.02 Pass: Major Risk 'I PB V Pad V-207 drilling Plan V-207L4 Nb V2 Pla 1249.28 1265.00 115.23 23.32 91.91 Pass: Major Risk I~ pB V-Peer ~T-2DTdrilling ~=707 V5 - ~'19~45 TZ0500 - - 103~T -2T:06 8'L~81 - ass: alor is - I - . _ _. i PB V Pad V-207 drilling V-207L1 V2 1195.45 1205.00 103.87 21.11 82.76 Pass: Major Risk ', ~, PB V Pa d V-207 drilling V-207L2 V3 7463.48 9365.00 1133.0 2 _ No Offset_Errors I ---- -- ____ __ _ __ - _ ', PB V Pad _ _ V-207 drilling -- _ ---__ -_ V-207P61 V5 1195.45 1205.00 . _- . 103.87 _ 21.11 - _ 82.76 Pass: Major Risk ---- - - -- - ~~AZaska -__- z~nte~~isicrrri a trr~ - -_ - - - I! Company: BP Amoco Date: 8 /4 8120 0 8 Time: 12:18:44 Page: 2 Field: Prudhoe Bay Reference Site: PBV-Pad Co-ordinate(NF) Refer ence: Well: Plan V-224 (S-Z~ True North Reference Well: Plan V-224 (S-Z) Verfical (T~"D) Reference: V-224 Plan SZ 81.8 i Reference Wellpa th: Plan V-224 Db: Ofaole Summary <-- -- .Offset Wellpath --- ----> Reference Offset Ctr-Ctr No-Co Allowable Site Well _ - - Wellpath . MD MD Distance Area __ Deviation Warning ft ft ft ft ft PB V Pad V-212 V-212 V7 625.06 625.00 215.32 10.69 204.64 Pass: Major Risk ', PB V Pad V-213 V-213 V5 343.13 345.00 44.21 6.39 37.81 Pass: Major Risk pR ~i pa.~ - . _ _ V-21-3 ~ i-~l3P-B1 V5 _ ~43.1~- ~a~ nn s14.2~~,39 _ Aainr Rie ~.8~ _Pass:Ji,ao_-...ok ', PB V Pad V-216 V-216 V8 265.44 265.00 202.70 4.94 197.76 Pass: Major Risk PB V Pad 1 1 -V=2t8---- V~'Y8-V7-- --_ 199G23- 20SfY.OfJ_ .118:35 _.56:57 -. -.79 ~ass:lvtajori2isk -- 6 PB VPad PB V Pad V-220 V-223 V-220 V10 V-223 V8 610.81 595.00 370.49 375.00 187.87 13.52 195.97 8.06 174.35 Pass Major Risk 187.91 Pass Major Risk FieldPrudhoe Bay SitePB V Pad We11:Plan V-224 (S-Z) WellpathElan V-224 From KOP to TD -Scan interval 100 ft Scale 1:50 -1 5 6 150 100 50 V-121 0 2 V1-2172 2( VV 2H6 50 V- 1op1a 1so 0 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre -- -_ _ - - - -. _- _-. -- arget~ - gt _--- - -- -- 3rte: a an - - - =- -- - -- ~n'Iling Trarget Conf~ g - on: anne rogram esenphon: ertica ept a ow can ea eve ap No mg: Local+Nl=S: ~ff 13 74 __ ____ _- - - st~ttg-s - : '9L0 e rr 71:0 7600 _ - - - -- ite: ~ Ian V-~2~ (S-Zj --- -- -- - --UrilIing'IargetConf.9 - _ - - - on:~lannedProgram escnphon: ertica ept : e ow can ea eve -- -- ap o mg: . ~ it _ __ _ - ocaI+~~S:~~7~3 ap ast~ng :- osa + - ahtu e: ongitu e: i tL0 I ;~(i(i 4rri I 33f]L 15°00'Op~~ ARID PLAN~Z - A - ~~~ ;I P D L s ~~ ~~" i ~ ~ )) i a ~ i r ` KSTATREDK ',I-~ a I '~ 03-11 ~-' , 2 ° ~ ,,, . ~,~ C ~ ~a ~ ~~ "-, ~ ~ ) ~ V-PAD ~` I ~- ~TO~ ~~ t Sp °~ >#1~ ~N y~~~ I ~ '~ , F An " 1 ~ ~36 ~' V-2201 ^ v-zo7 ^ V-224i V-2191 v-12o ^ v-Its V-03 ^ ^ V-213i v-2181 ^ ^ V-too V-111 ^ ^ V-122 V-2161 ^ ^ V-117 V-103 ^ V-212 ^ ^ V-121 V-106 ^ ^ V-2171 ^ v-2os v-o4 ^ V-105i ^ ^ V-01 V-221i ^ ^ V-223i V-07 ^ V-222i ^ V-102 ^ ^ V-SPARE (s~or s-L) v-zo1 ^ V-107 ^ ^ SLOT S-J v-oz ^ ^ v-2151 v-to4i ^ ^ v-zoa V-210i ^ ^ V-114 V-202 ^ ^ V-119 V-214i ^ ^ V-109 V-101 ^ V-211i ^ ^ V-113 V-108 ^ ^ V-05 V-203 ^ ^ V-112 , I TO SPINE RR=AD -_ P p0 ~ / wOP ~~ ~ ZD / V-PAD VICINITY MAP N.T.S. ~P° 0 `~ ° °°~ `S ~°°49~ °~ °a°°°°°°°°°°°°°°°°°°°°°°°°°°° °°°°°°°°°°°°°°°°°°°°°°°°°°°°°° °°° Richard F. Allison ~s ° 10608 °° $$ I ~~' ° ° °°°~~ SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN 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 CORRECT AS OF JUNE 3, 2008. NOTES 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD-27. 2. BASIS OF HORIZONTAL CONTROL IS V-PAD OPERATOR MONUMENTATION. LEGEND 3. BASIS OF ELEVATION IS V-PAD OPERATOR MONUMENTATION. AS-BUILT CONDUCTOR ELEVATIONS ARE BP MEAN SEA LEVEL DATUM. 4. THE MEAN SCALE FACTOR FOR V-PAD IS 0.999909334. ^ EXISTING CONDUCTOR 5. REFERENCE FIELD BOOK: W008-01 PGS. 53-57. 6. DATE OF SURVEY: JUNE 3, 2008. LOCATED WITHIN PROTRACTED SEC. 11, T. 11 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR BOX SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) ELEV. OFFSETS Y=5,969,976.03 N 9,999.91 70'19'39.726" 70.3277025° 53 5' 4,726' FSL V-219i X= 590,813.86 E 5029.87 149'15'48.606" 149.2635017° . 1,488' FEL Y=5,969,980.10 N 10,000.04 70'19'39.764" 70.3277122° 53 3' 4,730'FSL V-2241 X= 590,828.54 E 5,045.11 149'15'48.176" 149.2633822' . 1,474'FEL F. Robert °""`"" BARNHART -~ cRECKEO: 0 r ~ FURRER DATE: 0 t ~ a s/s/os ~' DRAWING FRSOS wov oa-oo SHEET: oa N~ GREATER PRUDHOE BAY V-PAD ~ ~~~D~o SCALE AS-BUILT CONDUCTOR 0 6 5 08 ISSUED FOR INFORMA710N TFB MSF : " WELLS V-2191 & V-2241 1 OF 1 N0. DArE REVISION BY CHK 1 =150 l~ 1 T ~T ~1 ~\ ~ ; __ ,`„ ° 1J _ - P~ROJEA CT ~, ~. r• j a f ~~ ti 1 ~kr +.., _,NE TREE _ V1fELLHEAD = ' ACTUATOR = KB. ELEV = BF. ELEV = kna= Max Angle = 69.6 deg Datum MD = Datum ND = 41/2" TBG, 12.6#, L-80, 1' TG11, .0152 bpf, ~ = 3.958" 9-5/8" CSG, 40#, L-80, TC-11, ~ = 8.835" 5108' X10 7" TGII to 7" BTGM 6608' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 10 xxxx MMG DCR RK WATER INJECTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 9 xxxx MMG-W DMY RK 8 xxxx MMG-W DMY RK 7 xxxx MMG-W DMY RK 6 xxxx MMG-W DMY RK 5 xxxx MMG-W DMY RK 4 xxxx MMG-W DMY RK 3 xxxx MMG-W DMY RK 2 xxxx MMG-W DMY RK 1 xxxx MMG-W DMY RK PERFORATION SUMMARY REF LOG: SLB Realtime LWD A NGLE AT TOP PERF: Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" 5 Nb 30' O 4-1/2" 5 OBa 55' O 4-1/2" 5 OBb 30' O 4-1/2" 5 OBd 85' O 4-1/2" 5 OBe 45' O PBTD = 9827' 41V-22~ PROPOSED MinimumlD=2.75"@ xxxx' Electric 3-1/2" HES XN NIPPLE 4 29' I 9727' ,~_ 3887' I"13-1/2" HES X Nom. ~ = 2.813" 8770' 1~3-1 /2" HES X NIP. ~ = 2.813" 8801' 7a HES A HR PKR w / 114" FEED THRU, ~ = 2.920" NOTE DO NOT EXCEED 4300 PSI 8814' MULTI DROP SGM FOR NDPG GAUGE 8897' 3-112" HES X NIP, ID = 2.813" 7" Csg. MARKER JOWTw/ 8847' / RA TAG MARKER JO~1T w / RA TAG H 8897' 8918' 7" HES AHR PKR w / 1 /4" FEED THRU, ID = 2.920" ~' I~ ~-~ 9254' 3-1 /2" HES X NIP, O = 2.813" 9255' 7" HES A HR PKR w / 1 /4" FEED THRU, ~ = 2.920" '~ 9264' i-iMULTI DROP SGM FOR NDPG GAUGE 928 3-112" HES X Nom, O = 2.813" 9323' 7" HES A HR PKR w / 1 /4" FEED THRU, ID = 2.920" (MULTI DROP SGM FOR NDPG GAUGE I ~} 9550' H3-1/2" HES X NIP, ID = 2.813" I 9556' 7" HES AHR PKR w / 1 /4" FEED THRU, ID = 2.920" g~1 3-1/2" HES X NIP, ID = 2.813" 579' I~ MULTI DROP SGM FOR NDPG GAUG 9654' 3-1/2" HES X NIP, ID = 2.813" 9674' 3-1 /2" HES XN Nom, ID = 2.75" ~ 9727' 3-1/2" WLEG, ID = 2.992" 7" CSG, 26#, L-80, BTC-M, .0383 bpf, ID = 6.276 9907' T~ DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 07/06/08 AER Proposed WBD WELL: V-2241 PERMff No: xxxxx API No: 50-029-xxxxx Sec, Tw p, Rge BP 6cploration (Alaska) Alaska Department of Natural Resources Land Administration System Page I offs ~ ,,,. .:. ;.. - !~~;c~rc~Ys S~arci~ State Cabins !l~1~t~ ~ ~ ~ S i_A €~n€~ i Case Abstract ~ Case ©etail ~ Land Abstract ., File: ,~DL 282-411 Search for Status Flat Upd<~t~~s ~~ nl~ 10~(1~:`'(iO8 Custon~e~°: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 1 966 1 2/900 E. BENSON BL ATTN: LAND MANAGER- ALASKf1 ANCHORAGE AK 995 1 966 1 2 Case Typc OIL & GAS LEASE COMP D~VR Unit: 780 OIL AND GAS File Location: DOG :DIV OIL AND GAS Case Status: 35 ISSUED Status Dute: 09/1.4/1965 Ti~tal Acres: 2560.000 Dale Initiated : 05/28/1965 Office ofPri~nar-v Respofasihiliiv: DOG DIV OIL AND GAS I ast Transaction Date: 12/04/2006 Case Subtti~e : t~~~:- NORTH SLOPE Last Transaction: AA-NRB f1SSIGNMF,NT APPROVED 1~IL'7"Idla77.' ~ ~ TOti1'TZS~71I7: OI ~ ~'~ ~~i111'~~'.~ ~) ~ I E SPCtlo77: OI 1C~L ~/Qn 11C1'~'S: ~>-~~) ~°1t'C~F ~' i~t5 ltiIC7'li~/c/I1. I ~~ TObP2~~11~).~ O~ ~ ~ J~cln~i'.~ (1 ~ ~ L Sect7~~11: (1 ~ S~'C//03'11~~'I'C'~': ~) ~1) ME~ridi~rrr.~ I_~ To~~n~/trj~.~ Ill IN Ran;~c~.~ 111E Sectrnri.~ I I S~~~lronllrf~c~.~~: (rl(? ll~~ridiuir~ U 7~nrn~F~r~~~ OI I~~ Raftae.°' (11 1 f-: ,~'~~c~~tnn~ I ' :~~~~c°tinn .1<~i~<~c 64l) Legal DescriPii~~n 0~-?~Y-196 R**S:~1LE.~~OIIC'EI,F_CTAL DF'SCRIPTIOi'~"`~' C'I-~-19OIIN-011E-U~111,2,11,1? 260.00 0-1-01-19?7 'k * UNITIZED. LE_A~SE A ND P~1RIICTPfl TING _ARE.4 I_EG~1 L DESCRIPTION* LEASE CO~LIRIITTED INENl11ZI~TY TO PRUDHOE BAY UNIT ,4ND OIL RINI GAS CAP PA PR UDHOF 13,~Y UN7T http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28240&... 10/6/2008 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 6000000 5950000 5900000 5850000 400000 i $ooooo i 500000 600000 700000 TRANSMITTAL LETTER CHECKLIST WELL NAME _ ~ G/ ~o~o?yL PTD# ~o~ /~-~ _ Development r/ Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~~l1/.J,~oE ~y POOL: _ O,~io,~'~ f'_~~.~D~ ~~s.~'. ~-~ Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) ~~ FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing (If last two digits API number well in permit No. . AP[ No. SO- 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 togs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API cumber (50• - _) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with ZO AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingept upon issuance of a conservation order approving a spacing exception. assumes the liability of any pu~otest 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 ] 0' sample intervals tlubu tar et zones. Non-Conventional WeU please note the following special condition of this permit: production or production testing of coal bed mejhane is not allowed for (name of well) until after (Comoanv Name,) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. _(Com4anv Name) must contact the Commission to obtain advance approve! of such water welt testing ro Rev: 1/! !/2008 ^ WELL PERMIT C Field & Pool PRUDHOE BAY, ORION SCHR BL OIL -640135 HECKLIST: Well Name: PRUDHOE BAY UNIT V-224 Program SER Well bore seg PTD#:2081540 Co . mpany BP EXPLORATION~ALASKAI INC Initial ClasslType SER ! PEND GeoArea Ag0 Unit 11650 On108 Shore 2n__ Annular Disposal ^ Administration 1 Pe[mitfeeattached- - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - 2 Lease number appropriate- - - - - - - - - - - - - - - Yes . - - - - - - - - - - - - - - - - - - - - - - - 3 Unique well name andmumber - -- -- - -- - - - -- -- Yes-- - - -- - - -- --- -- -- ---- - -- - - - - -- ---- 4 WQlllocatedina_definedp9ol------------------------- -----------Yes----- --QtiontSchraderBluff Pool-------------------------------------- -- ------ - 5 Well located properdtstanceftomdrillingunit_boundary------------ ------------Y~----- ---- -- -- - - --- -- ----- -- -- -- -- - - -- 6 Well located proper distance f[om other wells- - - - - - - - ~ - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7 Sufficient acreage aveihsble in drilling unit- - - - - - - - - - Yes - - 25ti0 acrQg• - - - - - - - - - - - - - - - - - - - - - - - - 8 If deviated, is-wellborePlat_included---------------------- ----- - -- Y~ - --------------------------------- -- - - - --- -- 9 OpsratoronlyaffesisdParty-------------------------- Yes----- -- - -- -------- -- - -- -- -- -- -- -- -- - - -- -- -- --- 10 Ope[atorhas_appropriatebondinforce--------------------- ------------Yes----- --QlanketBOnd#6194193.----------------------------------- -- ~-- -- --- 11 Pe[miteanbetssuedwifhoutconserrationorder---------------- -------._--Yes.---- -------------------------- -- -- --- -- - --- - -- -- --- -- - Appr Date 12 Permitoenbeissuedwithouiadministrative_approval------------- ------------Yes-_..- -.------------------------- --- --- ---- - -- - - - --- 13 Can permit be apRroved before 15•gay-wait - - ~ - - - - - - - - - - - -Yes - - - - - - - ~ - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - ACS 10!6!2008 14 Well located within area and strata auihorued kylmjectiom Order# (putlQ# in-comments)-(For_ Yes _ _ . _ _ . - AIQ_26, - _ _ _ _ _ _ - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 • Allwells-+Hdhi~ t(4_roile area of teyiew kleMifiBd (FOr seNlee we119n1y) _ - - Yes -- - - - - - - - - - - - - ---- - -- - - --- -- -- - - - - - - - - - - - - - - - - - - - - - - - - 16 Pre-produced injector duration of pre production less than 3 months- (Forservice welt only) - _ Ko- - - - - - - - - - - - - - - - - - - - - 17 -tyOrBOrven.gas_conforn8 to AS31,05,03QQ.1.A)~U.2.A-D) - - - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 Conductofstring-provided- --- - -- -- --- ----- - - - Yes---- - -- - ------ -- -- - --- --- -- ------ - - - -- ----- 19 Su[facecasingproteotsallknownUSDWg____--_--------- ------------NA_____ _._Altaquifers8xempted,40CFR-147.1Q3(bk(3)andAEQ1.____-_____--._--._---_----------- 20 CMT-voladequaie tocirculate_onconductor&surf-csg____-_---- --_-_---_--Yes--- ----------------------- ------ -- -- - - -- - ------ 21 CMT-vatadequate-to tie-in long stringtasyrfcsg_---__--------- ------------No----- -------------------------------------------------------- ----------- - 22 CMT-willoover all known-productivehorixons____------------- ----------Yes---- -------------------- - - -- - -- - - - -- - - - - 23 Casing desgns adequate for C~ T B & permafrost - - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate tankage_or reserve pit - - - - - - - - - - - - - - - - . - - - - - -Yes - _ - - _ - -Rig equipped with steel pits, No reserve pit planned,- Alt waste-t4 ;approved disposal well(s). _ - - - - - - - - - - - - 25 a 10.403 for abandonment keen aRP-roved------.-- Ifare-drill,has -----------NA----- -------------------------------- -- - - ---- -- -- -- ---- 26 - Adequate_wellkore separationproposed- - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - -Yes - - . - - - . Praxim~! analysis performed, Traveling cylinder path calculated: Gyros likely-in surface hole, _ - - - _ - - _ - - _ 27 1f diveder.requiJed, does it meet regulations - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 28 DrilliDgf!uid-program schematic & equip IistadQquate- - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - - - - -Maximum expected formation prgsst~re 8.6_EMW._ MVy planned up to 9,2_ppg in_zone. _ _ - - - - - - - - _ _ - - - . - TEM 101812008 29 BOPEs,-do iheym~tregulation - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 30 BOPE-Press rating appropriate; test fo_(put prig in comments)- - - - - - - - - - - - - - - - - - Yes _ - - - _ - - MASP calculated at 1755psi, 4000_psi_I30P test_planned, - - - - - - - - - - - - - . - - - - - - - - - - 31 Choke-manifoklcomplieswlAPl_RP-53 (May $4)--- -- -- -- ---- ---Ye$ --- -- -- - - -- - ---- - -- -- - -- --- ---- - -- --- 32 VYorkwill9ccu[withoutoperatlanshutdown------------------- -----------Yes---- ----.--------------- -- -- - ----- -- -- -- - -- - - --- --- 33 - Is presence of N2S gas probable- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - - _ - - - H2S is reported-at Vpad. _Mud_should preclude H2$ onrig._ Rig has Sensors and_alarms,. - _ - - - - - .. - - - _ 34 -Mechanical-c9nditionofv~ellswiihinAQRyerified(ForservlceweNpnly)_ _---__---_-_Yes-_-- -._V-1~1_inAOR,NO issues,_-_-____-__--._---__-------------------------- -- Geology 35 Permit can be issued w!o hydrogan_sulfidemeaaures - - - - - - - - - - - - - - - - - - No- _ _ - - - ..Max level HZ$ yell V-2052Qppm_(5l24lQ6);-Maxon Pad 3QOppm ~4l3147)._ _ - _ - - - _ - - - - - - - - - - - - - - - - 36 Data presented onpoientialoverpressurezones--__-__--_--_ ------------~- - --- ---- - ---- - --- -- -- - -- -- - -- - - --- - Appr Date 37 Seismic anaysis of shallow gas_~omes - - - - - - - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - ACS 10(6!2008 36 Beaked-conditiomsurvey_(if off-shore)__________________-_ -------------NA---- ------------------------------------ - ------ - ------------------------ - 39 Contact namelphone for weekiy_R ogress re ds [exploratory onl r Ao Y7 - Yes - - _ - - ----- - . _ Ryan Ciolkosz --564-5977- - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ - - - - - - - - - - - - - - - - - - - Geologic Engineering Date P Date Called for confirmation of State Plan Coordinates. 10.6.08. Commissioner: Date: Commissioner: o ner /D-~~~~ L`
