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Home My WebLink About207-059MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Saturday, January 25, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-222 PRUDHOE BAY UN ORIN V-222 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/25/2025 V-222 50-029-23357-00-00 207-059-0 G SPT 4353 2070590 1500 2750 2750 2743 2742 666 669 668 667 4YRTST P Bob Noble 12/2/2024 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN ORIN V-222 Inspection Date: Tubing OA Packer Depth 46 1997 1915 1891IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN241202173003 BBL Pumped:1.2 BBL Returned:1.2 Saturday, January 25, 2025 Page 1 of 1 9 9 9 9 9 9 999 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.01.25 23:12:04 -09'00' MEMORANDUM TO: Jim Regg P.I. Supervisor,Z FROM: Matt Herrera Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, December 10, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC V-222 PRUDHOE BAY UN ORIN V-222 Src: Inspector Reviewed By P.I. Supry� Comm Well Name PRUDHOE BAY UN ORIN V-222 API Well Number 50-029-23357-00-00 Inspector Name: Matt Herrera Permit Number: 207-059-0 Inspection Date: 12/7/2020 Insp Num' mitMFH2O1208160001 Rel Insp Num: Thursday, December 10, 2020 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well v-zzz - T e In' w� - j TVD 4353 r-� -- Tubing 1203 1209 1200 1195 - PTD '!Type p Test � SPT est psi 11.4 IA 55 2017 1932 1916 - BBL Pumped:2590 1.4 BBL Ret rn Returned: 14 OA 372 I -375 375 375 Interval 4YRTST PX P --- -- - - Notes' MIT -IA Performed to 2000 PSI per Operator Thursday, December 10, 2020 Page 1 of 1 • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg �? DATE: Wednesday,December 21,2016 P.I.Supervisor IS e/-, I 2---(L61 u, SUBJECT: Mechanical Integrity Tests I BP EXPLORATION(ALASKA)INC. V-222 FROM: Chuck Scheve PRUDHOE BAY UN ORIN V-222 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry S�g----" NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-222 API Well Number 50-029-23357-00-00 Inspector Name: Chuck Scheve Permit Number: 207-059-0 Inspection Date: 12/20/2016 Insp Num: mitCS161220151217 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-222 'Type Inj W TVD 4353 Tubing 1224 - 1233 - 1243 ' 1233 ' PTD 2070590 Type Test SPT Test psi 1500 IA 3 2000 - 1925 " 1909 - Interval 4YRTST P/F P ✓ OA 367 369 ' 369 - 369 Notes: SCANNED APR p 5 201? Wednesday,December 21,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 23, 2013 TO: Jim Regg � e(( ' Z� ' 3 SUBJECT: Mechanical Integrity Tests P.I. Supervisor 1 ' BP EXPLORATION (ALASKA) INC V -222 FROM: Chuck Scheve PRUDHOE BAY UN ORIN V -222 Petroleum Inspector Src: Inspector Reviewed B P.I. Supry ) 5P- NON Comm Well Name PRUDHOE BAY UN ORIN V - 222 API Well Number 50 029 - 23357 - 00 - 00 Inspector Name: Chuck Scheve Permit Number: 207 - 059 - Inspection Date: 1/20/2013 Insp Num: mitCS130122073253 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Y J 1 Test psi 353 OA 7 z s o z 2441 2429 I — Well', V-222 IT pe In w'1TVD 4353 ' I 233 — - 2 070590 - -- Type Test SPT 277 280 280 279 I PTD YP p I –I —, -4 • 1578 1582 1582 1582 1 I Interval j - -- - -- Tubing j _i - -� – 1 -- ----- 4YRTST P P/F j Tubin (-- - -- - -- Notes: SCANNED APR 11 1 2013 Page 1 of 1 Wednesday, January 23, 2013 31-JAN -2012 2l2A Scbbimberger 5885 b ti? Alaska Data & Consulting Services �' �� 1 j , V Company: State of Alaska 2525 Gambell Street, Suite 400 � itl' ° �V Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 01 -24A BINC -00093 INJECTION PROFILE 15- Jan -12 1 1 01 -25 BBSK -00105 INJECTION PROFILE 9-Jan-12 1 1 14-44A BUTT -00054 MEMORY LEAK DETECT LOG 28- Dec -11 1 1 01 -02 BVYC -00024 CROSSFLOW CHECK 30- Dec -11 1 1 V -212 BAUJ -00106 MEMORY INJECTION PROFILE 26- Dec -11 1 1 lir S -110 BX69 -00018 USIT 7-Jan-12 1 1 01 -02 BYS4 -00015 CROSSFLOW CHECK 4-Jan-12 1 1 R -16 BG4H -00106 SBHPS 23- Dec -11 1 1 01 -30 BD88 -00189 MEMORY INJECTION PROFILE 19- Dec -11 1 1 15-47 BG4H -00105 CEMENT BOND LOG SCMT 20- Dec -11 1 1 13 -12A BVYC -00018 ISOLATION SCANNER 30- Nov -11 1 1 MPI -18 BG4H -00107 ISOLATION SCANNER 25- Dec -11 1 1 NGI -10 BBSK -00102 USIT 16- Dec -11 1 1 Z -116 BBSK -00104 ISOLATION SCANNER 22- Dec -11 1 1 V -222 BUTT -00051 MEMORY INJECTION PROFILE 26- Dec -11 1 1 V -106A BCRJ -00108 FSI 15- Aug -11 1 1 0 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 ,= PROACTIVE DAAGNOSTIC SERVICES INC. To: AOGCC • ~~L L l°A/IlS/VffT~TA:L Christine Mahnken 333 W. 7th Ave , , ; ., Suite 100 Anchorage, Alaska 99501 (907) 793-1225 ._ a.r ._ <'(J~( RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTI~ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. U ~~~ 6 ~-- ~~ Attn: Robert A. Richey 130 West International Airport Road Suite C ~ ~ ~ Anchorage, AK 99518 Fax: (907) 245-8952 1) Leak Detection - WLD 02Sep-10 V-222 BL / EDE 50-029 23 -00 1, t~._ -., ~; 2) ~ ~~, _~~ ~ ~ -,~ ,J ~_, _~, Signed : Date Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RO SUITE C, ANCHORAGE, AK 99518 PHONE: (907}245-8951 Fax: (907}245-88952 E-MAIL : r~~sanc~orageCa rra~raa®r~rl~~a.casrel WEBSITE : winnar.rraeralcar~tio~.~®m C:\DocumenLs and Settings\Diane Williams\Desktop\Tratumit_$P.docx ~:. 3 MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Nticrofilm_Mazker.doc ~ BP Exploration (Alaska) Inc. Attn: Well Integriry Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ~~ x~~'~~~~s~~~Q~~ ' i`'~' ,l ~ fY ~ (~ ~~~~ bp ~~~~~ V ~~ OCT 0 5 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, Ah~lca Oii ~ Gas Cons. ~ommi~~~n~ Anchoraqe ~o - ~~' 7 ~_ ~-~ ~- Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date V-pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al V-01 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-03 2022150 5o02s2312ao000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 V-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 V-102 2020330 50029230700000 NA 7.75 NA 9s.2 8/7l2009 V-103 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009 V-104 2021420 50029231030000 NA 1.5 NA 21.3 7/11/2009 V-1o5 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-1o6A 2041850 50029230830100 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-109 2022020 50029231200000 NA 1.2 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 NA 1.5 NA 13.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-122 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 v-20t 2012220 50029230540000 SC leak NA 4 NA 90.6 8/7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009 V-203 2051680 50029232850000 NA 2 NA 12.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061800 50029233380000 NA 1.8 NA 13.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-210 2042100 50029232310000 NA 2 NA 18.7 7/11/2009 v-211 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-212 2051500 50029232790000 NA 1.2 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 50029233510000 NA 2.8 NA 30.6 6/30/2009 V-216 2041300 50029232160000 NA 1.5 NA 13.6 6/29/2009 V-217 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7/12/2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 "~ 2080200 50029233830000 NA 1.75 NA ~5 3/9/2008 V-221 2050130 50029232460000 NA 0.8 NA 8.5 6/29/2009 V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9/7/2008 I 3 ~ w ~`~ DATA SUBMITTAL COMPLIANCE REPORT 6/22/2009 Permit to Drill 2070590 Well Name/No. PRUDHOE BAY UN ORIN V-222 Operator BP EXPLORATION (ALASK~y INC API No. 50-029-23357-00-00 MD 5278 TVD 4916 Completion Date 6/13/2007 Completion Status WAGIN Current Status WAGIN IC Y REQUIRED INFORMATION Mud log No Samples No Directional Survey DATA INFORMATI~N Types Electric or Other Logs Run: MWD DIR / GR, GR / RES / PWD, AZI-DENS / NEU, USIT Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No (data taken from Logs Portion of Master Well Data Maint Intervai OH / Start Stop CH Received Comments Log Sonic 25 Col 1 50 5150 Case 7/3/2007 USIT, GPIT, PPCX2, ~ DSLT, GR, CCL 10-Jun- 2007 D D Asc Directional Survey 0 5278 Open 7/9/2007 D C Lis 15440 Cement Evaluation 31 5067 Case 9/28/2007 LIS Veri, USIT, CCL, GR w/PGS and TIF graphics ED C Lis 15596 Induction/Resistivity 92 5275 Open 10/26/2007 LIS Veri, GR, ROP, FET, RPM, DRHO, NPHI w/PDS graphics og Induction/Resistivity 25 Blu 1 108 5278 Open 10/26/2007 MD Vision Servic 8-Jun- 2007 og Induction/Resistivity 25 Blu 1 108 5278 Open 10/26l2007 ND Vision Senric 8-Jun- 2007 og Injection Profile 5 Blu 4550 5010 Case 1l28/2009 injection Pro w/WFL, Spin, Pres, Temp, RST WFL, GR, CCL 8-Jan-2009 EO G 17534 Injection Profile 5 Blu 4550 5010 Case 1/28/2009 Injection Pro w/WFL, Spin, Pres, Temp, RST WFL, GR, CCL 8-Jan-2009 Well Cores/Samples Information: ~ ~ Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 6/22/2009 Permit to Drill 2070590 Well Name/No. PRUDHOE BAY UN ORIN V-222 Operator BP EXPLORATION (ALASK/y INC MD 5278 ND 4916 Completion Date 6/13/2007 Completion Status WAGIN Current Status WAGIN ADDITIONAL II~FORMATION Well Cored? Y /~ Chips Received? Y'Tl'0~ Analysis `~`7"IQ~ Received? Daily History Received? ~ N Formation Tops ~ N API No. 50-029-23357-00-00 UIC Y Comments: Compliance Reviewed By: ~__~" Date: ~~1~wr~ ~ti"~ q ~ ~ UPDATE: V-222 (PTD #20705~Sustained OA Pressure that does not ~eed MOASP ... Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~' ~ Sent: Friday, January 30, 2009 8:07 PM To: Regg, James B(DOA); Maunder, Thomas E(DOA); Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor Cc: NSU, ADW Well Integrity Engineer Subject: UPDATE: V-222 (PTD #2070590) Sustained OA Pressure that does not exceed MOASP due to Hydrates Attachments: MIT PBU V-222 01-21-09.x1s ~ Jim and Tom, V-222 (PTD #2070590) failed an MITOA on 01/12/09 with a LLR of 2 bpm at 1650 psi. We are currently continuing diagnostics to evaluate the wel! for an OA downsqueeze rather than an Administrative Approval. The well did pass an MITIA to 2400 psi on the same day. Please see the attached MIT form for reference. «MIT PBU V-222 01-21-09.x1s» We will continue to update the Commission with progress made on the well. Please call with any questions or concerns. Thank you, Andrea Hughes Well lntegrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 1~4r~,`, t~ ~~~ :~t~.y~~~~ u~t~, r ~ - i~. ~~ From: NSU, ADW Well Integrity Engineer Sent: Sunday, ]anuary 11, 2009 12:45 PM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad LV; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng Cc: NSU, ADW Well Integrity Engineer; Warren, Mike; Quy, Tiffany; Holt, Ryan P(ASRC) Subject: V-222 (PTD #2070590) Sustained OA Pressure that does not exceed MOASP due to Hydrates All, V-222 (PTD #2070590) has been found to have sustained OA pressure that does not exceed MOASP. The OA was bled on 12/25/08 from 780 psi to 380 psi and has shown a slow build-up since. OA gas sampling indicates a high methane content, no C02 content and low heavy end content (C2-C6), consistent with the hydrate formation at the SC shoe. Our plan forward for the well is as follows: 1. F: AOGCC MiT-IA to 2400 psi (the last test was on 08/27/07) 7/29/2009 UPDATE: V-222 (PTD #20705~Sustained OA Pressure that does not ~eed MOASP ... Page 2 of 2 2. WIC: Apply for AA A TIO plot, injection plot and gas sample analysis has been included for reference. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 7/29/2009 .~ 9 • ~ ~ Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU / V Pad DATE: 01 /21 /09 OPERATOR REP: Anna Dube AOGCC REP: Chuck Scheve STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Packer Depth Pretest Initial 15 Min. 30 Min. Well V-222 Type Inj. W TVD 4,353' Tubing 1,750 1,750 1,750 1,750 Interval O P.T.D. 2070590 Type test P Test psi 1500 Casin 670 2,400 2,340 2,330 P/F P Notes: MIT-IA to 2400 psi pre AA for OA hydrates OA 460 530 520 510 Pumped 0.5 bbls of MEOH to achieve test pressure Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R= Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU V-222 01-21-09.xis MEMORANDUM ~ To~ Jim Regg P.I. Supervisor ~ Q~? ~~3~ Zt7~~ ~ ~~ FROM: Chuck Scheve Petroleum Inspector State of Alaska ~ Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 28, 2009 SUBJECT: Mechanical Integrity Tests BP F,XPLORATION (ALASKA) INC V-222 PRUDHOE BAY UN ORIN V-222 Srr. Inspecror NON-CQNFIDENTIAL Reviewed By: P.I. Suprv ~'~~- Comm Well Name: PRUDHOE BAY UN ORIN V-222 API Well Number: 50-029-23357-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS090 1 220842 1 9 Permit Number: Z~~-os~-o Inspection Date: ~~Z~izooy R~1 Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. __ ._ .__.. _ . _._ _ __ . _ ~ _ , _ __. Wel~ V-222 ,Type Inj. ' W i TVD 4353 i j,~ 670 i 2400 `' 2340 . 2330 ~ ~ __ . _._ ~ _ . _ . ~ _ P.T. 2070590 TYPeTest i sPT ~ Test psi ~soo ~ OA _ aw ; s3o szo ~, sio . __ . ,.. . ._ __. . __ _ ._ _ _._--- . _Interval._ oTxER p~ r ~ Tubing, ~~so , i~so ~~so ~ »so NOtes' Test performed pre AA for OA hydrates. Wednesday, lanuarv 28, Z009 Page I of I 01 /23/09 1A.• t u< <- ~~hCu~berg~~ Alaska Data & Consulting Services a(" 2525 Gambell Street, Suite 400 ~~ Anchorage,AK 99503-2838 ~ a ATTN: Beth ~J QG ~ a`~~~` ~ w/ t±ll 1 O .Inh s ~ ~.... ne~...:»s:.,., N0. 5047 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 n..a.. H-35 11970840 PRODUCTION PROFILE 08/12/08 1 1r -11 12111927 IBP & CROSS-FLOW STP 1 11/24/08 1 1 MPS-41 11966291 SCMT ~ ~'ot 11/24/08 1 1 K-05C AWJB-00016 MEM PROD PROFILE p _ •~.5 1?l29/08 1 1 14-17A AXOY-00010 MEM INJECTION PROFILE ~ Q -(~ 01/15/09 1 1 F-33 ALYF-00010 CEMENT IMAGE LOG (p- ~"`` 1?J30/08 1 1 K-16AL2 AXIA-00009 MEM PROD PROFILE 0 - (~ 01/10/09 1 1 01-29 AP3~-00011 USIT - ~ ~ 01/04/09 1 1 09-30 AY1M-00007 STATIC SPINNER & IBP -- L,~ 01/15/09 1 1 N-18A AZCM-00005 JEWELRY LOG/PRESSlfEMP -- ~ 01lO6/09 1 1 R-24 AY3J-00004 USIT - 01/16/09 1 1 N-18A AWLB-00002 USIT 12/26/08 1 1 ZeS ={ S O V-212 J7 S3 AXBD-00010 MEM INJECTION PROFILE 01/16/09 1 1 d~' 0 S9 V-222 ~7's' j y ALYF-00011 INJ PROFILEJWFL 01/08/09 1 1 07-0$A AYQ~-00009 USIT - L 01/22/09 1 1 N-12 12014053 RST f - 09/30/08 1 1 E-32B AXOY-00005 MCNL 11/18/OS 1 1 P2-15A 11594511 SCMT (PDC) (REVISION 2) i l~. -(~`.~ 06/15/07 1 B-27A 11999059 RST ~~~ ~~5~ 1i/07/08 1 1 12-37 40018138 OH M D/LWD EDIT - _~L ~~' 11/07/08 2 1 N-18A 08AKA0037 OH MWD/lWD EDIT ~Q~ ~- , 12/24/08 2 1 H-38 08AKA0031 OH MWD/LWD EDIT C 1?J07/OS 2 1 ' '- l~ ~o ~- C ''~--U __"~~ ............ ~~....`. ..~..~.. . .. . ............ ..nv ~ ~~ ~ vnnu~~a v~~c aivr ~ CN\rfl ~ v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~ ~ 900 E. Benson Bivd. Anchorage,Alaska 99508 ~ Date Delivered Alaska Data & Consuiting Services 2525 Gambell Street, Swte 400 ~„,~ Anchorage, AK 9 ~~~ ~~ ~ ~, ~ ~ ~' ATTN: Beth ~, ° . , ~' i~,~, ~' ~ n ~ Received by: t ~, ~~ ° _ ~~; ~.~ M . ~ , /~J °~~~~~Ka'~A~9x~,~9'`:~h~s~'d~d.`~.~ !,T~Y~'a$9~hnR.ri~'`r V L ~i!3~R&ikg .~f~, ~ ~ V-222 (PTD #2070590) Sustai~OA Pressure that does not exceed MO~SP due to Hyd... Page 1 of 1 , Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~ Sent: Sunday, January 11, 2009 12:45 PM ~ To: Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad LV; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng Cc: NSU, ADW Well Integrity Engineer; Warren, Mike; Quy, Tiffany; Holt, Ryan P(ASRC) Subject: V-222 (PTD #2070590) Sustained OA Pressure that does not exceed MOASP due to Hyd rates Attachments: V-222 OA.dot; V-222 TIO and Injection Plot.doc All, V-222 (PTD #2070590) has been found to have sustained OA pressure that does not exceed MOASP. The OA was bled on 12/25/08 from 780 psi to 380 psi and has shown a slow build-up since. OA gas sampling indicates a high methane content, no C02 content and low heavy end content (C2-C6), consistent"wi e y ra e orma ion ~'' at the SC shoe. '-~' ~--' Our plan forward for the well is as follows: F: AOGCC MIT-IA to 2400 psi (the last test was on 08/27/07) 2. WIC: Apply for AA A TIO plot, injection plot and gas sample analysis has been included for reference. «V-222 OA.dot» «V-222 TIO and Injection Plot.doc» ~-- Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 6/23/2009 ~ PBU V-222 PTD 207-059 1 / 11 /2009 TIO Pressures 3,0~~o i ~~i i.am m, • -.-,~ .a . o~ oan oooa ~- o~ ti ~ ~'~'..~ ~ ~ ~~~~ ~ ^ ir ~ r ~ , ~ a ~ ~ ~ ati~w iaY 7iroe ione~ae io~zsroa ii~oiios ii~oaroe iinsroe iirzxroe iirtsroe iz~~ iznv~ izizoroe ivnioe oi;o3iu9 Injection Plot ,. 1.7 ,. 1. 1. i. 7 11 ~1. 7 1 ---- .._.._.... ... ,~ ° ~o ~ ~ 65 sao ~1 r~ ~ / 55 {00 300 ~ ~ ~ 200 d5 pp / AO D00 900 ~' 600 30 ~ ~ 600 500 p ~0p /5 ~ 10 200 ~ ~ 10/11/08 10/18/OB 10/25/OB 11/OtNB il/~/OB 11/15/OB 71/22/OB 11/29IOB 12/06/OB 72/13/OB 12/2UlOB 1U27J08 01/03/09 D1/10/09 ' g - WHIP 1~ - _ ~ - pW ~~ -- MI [; GI o OUiei ~ ~ On l 1 ) ~ ~ GPB LABORATORYANALYTICAL REPORT 907-659-5654 Email: GPBLab(~a,bp.com Sample ID PC25347 Collection Date 12/29/08 Facility V-PAD Location OA Analysis Name Analysis Unit Combination Result LINE PRES PSIG 460 METHANE-MOL% MOL% 97.613 ETHANE-MOL% MOL% 0.075 PROPANE-MOL% MOL% 0.426 I-BUTANE-MOL% MOL% 0.223 N-BUTANE-MOL% MOL% 0.272 I-PENTANE-MOL°/a MOL% 0.108 N-PENTANE-MOL% MOL% 0.159 C6P-MOL% MOL% 0.465 C02-MOL% MOL% 0.000 NITROGEN-MOL% MOL% 0.659 MOL WEIGHT 16.991 BTU GRSDRY IDEAL BTU@14.696PSIA 1049.8 BTU GRSDRY REAL BTU@14.65 PSIA 1048.8 BTU GRSSAT IDEAL BTU@14.73 PSIA 1033.9 BTU NET BTU@14.696PSIA 944.0 SPG REAL 0.5877 02 CONTAM MOL% 0.000 DISTRIBUTION ELIOT TOWNSEND Reported by: at 9:18 AM on 06/23/09 Schfam~erger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job p Log Description NO. 4454 Company: Alaska Oil B Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorege, AK 99501 Field: Polaris Orion Borealis Date B~ Color CD W-213 V•215 77667175 11594491 MEM TEMP/PRESS SURVEY CH EDIT PDC GR USI 09/29107 04/23/07 1 7 2-108 S•724 S-725PB1 11212828 40074242 40015467 OH WIRELINE PEX EDIT ' OH MWDILWD EDIT OH MWDILWD EDIT ' -d 02105/06 11/05I06 07/07/07 2 J 2 7 1 1 V-721 40075007 OH MWD/LWO EDIT 3~ 03124/07 2 1 V-222 40015319 OH MWDILWD EDIT 06/08/07 2 1 W-210 40074842 OH MWD/LWD EDIT . - 02126/07 2 1 V-278 40015066 OH MWD/LWD EDIT 04107/07 2 7 W-204 40074637 OH MWDILWD EDIT ~ 01/29/07 2 1 W-204PB1 40014637 OH MWDILWD EDIT 07/24I07 2 7 W-204L1 40014637 OH MWDILWD EDIT ' 02/07/07 7 7 W204L2 40016637 OH MWD/LWD EDIT ~ 02f20f07 1 7 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPV EACH TO: BP Explo~ation (Alaska) Inc. Petrotechnical Data Cente~..~fi,2 ;1 ~ ~ ~ 900 E Benson Blvd. ~~~ ~ F~ -„ 1';,.-r, r Anchorage AK 99508 425N ~^~ { , ~`' ~~ .+ ~~ Date Delivered: ,5^^a,P"~ ~ R~ ,~ ~pQ~ ^ d~' pi,, 7~.. : ';a ,~~~.i 1 ~ ~ (13^~' ~ '., r tt ,a.;'.: T . ;~~?u`~ .. . ~~r. Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Belh Received by. ionsro~ ~ ~ 09/25/07 . s Sc~du~~erg~ Schlumberger-DCS 2525 Gambeli St, Suite 400 Anehorege, AK 99503-2838 ATfN: Beth Well Job # Log Description NO. 4425 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99507 ~ Field: Polaris Orion Midnight Sun Date BL Color CD E-702 11637355 RST O~, ^~ / 07/27/07 7 7 W-210 11626075 CH EDIT PDC GR U51T 03/O6/07 7 V-222 11636644 CH EDIT PDC GR USIT 06N0/07 1 PLEASE ACKNOWIEDGE RECEIPT BV SIGNING AND RETURNING ONE COPY EACH TO: BP Exploretion (Alaska) Inc. ~ -~ Petrotechnical Data Center LR2-1 y~' ~ ~~a Y„ ~,{~ r{s. ~~~; 900 E Benson Blvd. ~~~ ~~'~'~' i r(~ ~ ~~ ¢'.,;: E Anchorage AK 99508-4254 ~ --~~~ Date De6vered: r~ ~y ~ ~~ ~~ ~ ~ k~~ ~ . ~, ~. {"'::,11411,;a:~~(1~~ .'~~ , ,~ . ~.~e. ~ ~ a M14~r:a FV¢:e~f ~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anehorage,AK 99503-2838 ATTN: Beth ' Received by: ~~ ~ . Saltmarsh, Arthur C (DOA) Page 1 of 1 From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, September 17, 2007 3:15 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU V-222 / PTD # 207-059 H i Art, Please reference the foflowing well: Well Name: PBU V-222 Permit #: 207-059 API #: 50-029-23357-00-00 Top Perf MD: 4724' Bottom PerF MD: 5000' This well began Injection on August 21, 2007 Methad of Operations is: Wa#er lnjection Date of Test: Injectors not Tested 9/17/2007 MEMORANDUM ~ To: Jim Regg ~~~ ~~ ~( ~' ~ 7 P.I. Supervisor J ~ i FROM: Lou Grimaldi Petroleum Inspector State of Alaska ~ Alaska Oil and Gas Conservation Commission DATE: Wednesday, September O5, 2007 SUBJECT: Mechanical Integriry Tests BP EXPLORATION (ALASKA) INC V-222 PRUDHOE BAY UN ORIN V-222 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~'` Comm Well Name• PRUDHOE BAY UN ORIN V-222 Insp Num• mitLG070831160559 Rel Insp Num: ApI Well Number• 50-029-23357-00-00 Permit Number• 207-059-0 Inspector Name~ Lou Grimaldi Inspection Date• g~Zgi2oo~ Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~'222 Type Inj. ~' TVD asas ~ ~32o iazo t~9o »so p.T, zo~os9o TypeTest SPT Test psi ~ 820 OA aoo a2o azo azo Interval ~T~- p/F P ,~ Tubing ~loo ii2o iizo >>20 NOtes• •3 bbl's pumped. Post-initial injection MIT. Good test. Wednesday, September O5, 2007 Page I of 1 ~~~ ~~~~~~~~ ~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~i~,~;~_ ~~ ~007 WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~:.~ a:~ ~ ~ ~~I;~~ ~v~r~s. G~€~miss~an 1a, Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1b. Well Class: '~~ ~`~" ~~~° zoanc2s.~oe zoa~cze.~,o ^ Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ~ WAG ^ Other No. of Completions One ~ Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aban 12. Permit to Drill Number BP Exploration (Alaska) Inc. 6/13/2007 207-059 - 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 6/4/2007 i 50-029-23357-00-00 ' 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 6/8/2007~ V-222i - FSL, 1746 FEL, SEC. 11, T11 N, R11 E, UM 4846 " Top of Productive Horizon: 8. KB (ft above MSL): 81' 15. Field / Pool(s): 1141' FSL, 1550' FEL, SEC. 02, T11 N, R11 E, UM Ground (ft MSL): 52.5' Prudhoe Bay Field / Orion Total Depth: 9. Plug Back Depth (MD+~/D) Schrader Bluff - 1363' FSL, 1538' FEL, SEC. 02, T11 N, R11 E, UM 5182 4828 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+ND) 16. Property Designation: SurFace: x- 590555 y- 5970093 Zone- ASP4 5278 4916 ADL 028240' TPI: x 590730 y- 5971670 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: Total Depth: x- 590739 y- 5971893 Zone- ASP4 None 18. Directional Survey ~ Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (ND): ' Submit electronic and rinted information er 20 AAC 25.050 N/A ft MSL (Approx.) 1764 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD DIR / GR, GR / RES / PWD, AZI-DENS / NEU, US~T ZZ. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD' SETTING DEPTH ND HOLE AM6UNT' WT. PER FT GRADE TOP BOTfOM : TOP BOTTOM SRE CEMENTING RECbRD PULLEQ 1 20" 215.5# A-53 Surface 108' Surface 108' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 29' 2967' 29' 2794' 12-1/4" 538 sxAS Lite, 281 sx 'G', 111 sx'G' 7" 26# L-80 26' S268' 26' 4906' 8-3/4" 269 sx Class 'G' 23. Open to production or inject ion? ~ Yes ^ No 24: Tuaw~ RecoRo If Yes, list each i (MD+'n/D of Top & Bottom; Pe nterval open rforation Size and Number): Size ~EPTH SET MD PACKER .SET MD 4-1/2" Gun Diameter 5 spf 3-1/2", 92#, L-80 5058' 4663', 4771', 4832', 4942' , MD TVD MD ND 4724' - 4766' 4409' - 4447' CEMEN7 S4UE~E; E~'C. FRAC7UR~ 25. ACiD 4798' - 4828' 4476' - 4504' , , 4H4Z~ - 4HBO' 4516' - 4533~ DEPTH INTERVAL MD AMOUNT 8e KIND OF MATERIAL USED 4898' - 4918' 4567' - 4586' 4958' - 5000' 4622' - 4661' 2670' Freeze Protect with 93 Bbls of Diesel ZF). PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection N/A D8t@ Of TBSt; HOUfS TBSt@C~: PRODUCTION FOR OIL-BB~: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD Flow Tubing Casing Press: C,a~cu~a,Teo OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API ~CORR~: Press. 24-HouR R,are~ Z7. CORE DATA Conventional Core(s) Acquired? ^ Yes ~ No Sidewal l Core s Ac uired? ^ Yes ~ No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submii detailed descriptions, core chips, photographs and laboratory analytical results p r 0 AAC 250.071. COMpi.ETiCN ± None ~~ JUl 2 3 2DD7 ~~ ~~~ ~ ~,,,. ~~~~~ ___ . ... .. ._ , Form 10-407 Revised 02/2007 NTINUED ON REVERSE SIDE ~^ ~~y `%~~~~~~ / G~ N A~ ; ~~~ ~,~,~~ ,- « ZS. GEOLOGIC MARKERS ~LIST ALL FORMATIONS A KERS ENCOUNTERED~: 29. FORAAATION TESTS NAME MD ND Well Tested? ^ Yes ~ No Permafrost Top 28.5' 2g 5~ ~f yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 1871' 1791' detailed test information per 20 AAC 25.071. Top Ugnu 3010' 2833' None Ugnu MA 4278' 4005' Ugnu MB1 4324' 4047' Ugnu M62 4392' 4109' Ugnu MC 4477' 4815' Schrader Bluff NA 4547' 4248' Schrader Bluff NB 4571' 4270' Schrader Bluff NC 4610' 4305' Schrader Bluff NE 4618' 4313' Schrader Bluff NF 4678' 4367' Schrader Bluff OA 4726' 4411' Schrader Bluff OBa 4799' 4477' Schrader Bluff OBb 4841' 4515' Schrader Bluff OBc 4900' 4569' Schrader Bluff OBd 4958' 4622' Schrader Biuff OBe 5028' 4686' Schrader Bluff OBf 5073' 4727' Schrader Bluff OBf Base 5123' 4773' Formation at Total Depth (Name): Colviile Mudstone 5123' 4773' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ^ ~~ Signed Terrie Hubble Title Technical Assistant Date i ~ 8/~ V-222i 207-059 Prepared By Name/Number. Terrie Hubble, 564-4628 W211 Number Drilling Engineer: grandon Peltier, 564-5912 Permit No. / A roval No. INSTRUCTIONS GeNeria~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and Ieases in Alaska. Submit a well schematic diagram with each 10-4D7 well completion report and 10-404 well sundry report when the downhole well design is changed. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). 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). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Irenn 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Onty _ ~_ ~~ E , ~ ~ ~~F ~ ; ~ ~~~F ~ ~~~~~~~r~~~ ~ ~ _ ~ ~ ~~~ ~ ~~ ~ E , ~ : ~ - ~~ ~ ~ - ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~~ ~~ ~ ~ ~ ~~~~ ~~~~~~ ~ .~ , , , ~ ~~+~~~~?~ ~~~~~~ir~iimar~ ~ ~ ~ ~ ~ ,, , ~ ..~.. , ~.E~3 ~ ~ _ _ Legal Name: V-222 Common Name: V-222 : 'Ces~ate ~ '~'~#'~pe ~ :~ Tes~ ~~~ ;~ ~~f~ ~i"~G~~ : ~~: T+ss# C~pth {"~~ l#MW Su~tac~i`Pr~ssur~ ~~ L+~ak~ F+r '~ ~N~N~~ ?~ ~ :~MW : '~ ?- r ~E.;,. . .: -- . 6/7/2007 LOT 2,967.0 (ft) 2,794.0 ft ( ) 8.80 (pp9) 997 (psi) 2,274 (psi) 15.67 (Pp9) ~ ~ Printed: 7/10/2007 11:37:57 AM ~ ~ Legal Well Name: V-222 Common Well Name: V-222 Spud Date: 6/4/2007 Event Name: DRILL+COMPLETE Start: 6/3/2007 End: 6/13/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/13/2007 Rig Name: NABORS 9ES Rig Number: 9ES 6/3/2007 00:00 - 04:30 4.50 MOB P PRE Prepare truck shop and satellite camp for move. PJSM with Peak. Move mechanic shops and satellite camp to V-pad. 04:30 - 05:30 1.00 MOB P PRE Raise pits and move off W-213. Instail jeep for move & Transport from W-Pad to V-Pad. 05:30 - 06:00 0.50 MOB P PRE Laydown derrick. 06:00 - 07:30 1.50 MOB P PRE Raise rig. Remove rig mats. Stage rig to edge of W-pad. 07:30 - 13:00 5.50 MOB P PRE Move sub base from W-pad to V-Pad. Position rig in front of V-222i. 13:00 - 17:00 4.00 DIVRTR P PRE Install surface stack on V-222i. 'Rig accepted for operations on V-222i ~ 17:00, 6/03/2007. 17:00 - 19:00 2.00 MOB P PRE Position rig over V-222i conductor. Place matting boards under rig. 19:00 - 20:00 1.00 MOB P PRE Position mud pits to sub base. Place matting boards under pits. 20:00 - 21:00 1.00 R1GU P PRE PJSM. Inspect and raise derrick. Raise pipe skate chute. 21:00 - 22:00 1.00 RIGU P PRE Make up kelly hose to topdrive. Make up lines at interconnect. 22:00 - 00:00 2.00 RIGU P PRE Unbridle from blocks. Pin blocks and torque tube. Secure bridle lines in derrick. 6/4/2007 00:00 - 04:00 4.00 RIGU P PRE Prepare celiar. NU Dresser sleeve. Level cellar area. Secure Herculite. Adjust cellar rear door to accomodate neighboring wells flowline stansions. 04:00 - 09:00 5.00 RIGU P PRE Pick up enough drill pipe to TD 8.75" hole. 141 singles, rack back 47 stands in derrick. 24 joints of 4" HWDP, rack back 8 stands in derrick. 09:00 - 10:00 1.00 RIGU P PRE Make up JAR and coliar stand, rack back in derrick. 10:00 - 10:30 0.50 DIVRTR P PRE Function test and inspect surface diverter system. Test witnessed by BP WSL Brian Buzby, NAD TP Bill Bixby and witness waived by AOGCC rep Chuck Scheve. Function test Accumulator. Test PVT's, ilow indicator. 10:30 - 14:00 3.50 RIGU P PRE Make up BHA #1: New 12.25" Reed-Hycalog Miiltooth bit, 1.5 deg PDM, NM lead DC, NM STAB, MWD, NM STAB, NM XO, orienting sub, NM DC, NM STAB, 2 ea NM DC. Hold Pre-Spud meeting. 14:00 - 14:30 0.50 RIGU P PRE Fill hole and check for leaks - OK. Pressure test high pressure mud lines and kelly hose to 3,000 psi - OK. 14:30 - 15:00 0.50 RIGU P PRE PJSM. Rig up Sperry wireline and Gyro Data. 15:00 - 16:30 1.50 RIGU P PRE MU NM DC Stand. 16:30 - 17:30 1.00 DRILL P SURF Spud V-222i surface hole ~ 16:30 hr, 6/OM2007. Drill from 108' to 361'. 550 gpm, 560 psi off, 675 psi on. 80 rpm, .6k TQ off, 1 k TQ on. PU - 52k, SO - 50k, RWT - 51 k. 10k WOB. 17:30 - 19:00 1.50 DRILL P SURF POH 1 stand to pick up JAR stand. RIH washing last stand to bottom. 19:00 - 00:00 5.00 DRILL P SURF Start kick-off and directional drill from 361' to 680'. Gyro surveying every stand. 550 gpm, 1,100 psi off, 1,200 psi on. 80 rpm, 1.2k TQ off, 2.5k TQ on. PU - 62k, SO - 59k, RWT - 58k, WOB - 20k. ART = 2.59, AST = 1.13 6/5/2007 00:00 - 03:30 3.50 DRILL P SURF Directional drill from 680' to 914'. Gyro surveying every stand. 600 gpm, 1,529 psi off, 1,670 psi on. 80 rpm, 1.4k TQ off, 4.1 k TQ on. Printed: 7/10/2007 11:38:02 AM ~ ~ Legal Well Name: V-222 Common Well Name: V-222 Spud Date: 6/4/2007 Event Name: DRILL+COMPLETE Start: 6/3/2007 End: 6/13/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/13/2007 Rig Name: NABORS 9ES Rig Number: 9ES 6/5/2007 00:00 - 03:30 3.50 DRILL P 02:00 - 09:00 7.00 DRILL P 09:00 - 09:30 I 0.501 DRILL I P 09:30 - 11:30 I 2.001 DRILL I P 11:30 - 12:30 1.00 DRILL P 12:30 - 18:00 5.50 DRILL P 18:00 - 20:00 I 2.001 DRILL I P 20:00 - 23:00 I 3.00 I DRILL I P 23:00 - 00:00 ~ 1.001 DRILL I P 6/6/2007 100:00 - 01:00 I 1.00 ~ DRILI. I P 01:00 - 04:00 I 3.00 I DRILL I P SURF PU - 69k, SO - 62k, RWT - 66k, WOB - 20k. Surveys good, RD Gyrodata & Sperry E-line. SURF Directional drill from 914'to 1,678'. 704 gpm, 2,570 psi off, 2,740 psi on. 80 rpm, 2.1 k TQ off, 42k TQ on. PU - 79k, SO - 62k, RWT - 72k, WOB - 25k. AST - 2.08 hrs, ART - 3.48 hrs. SURF Circulate 3 bottoms up. 709 gpm, 2,600 psi 80 rpm, 1.7k TQ SURF Monitor well - OK. Short trip to 268'. Pulled tight from 1,180' to 990'. Backreamed same at 560 gpm, 1,530 psi, 60 rpm, 1.8k TQ. SURF Run in hole without problem. Wash last stand to bottom. SURF Directional drill from 1,678' to TD ~ 2,978 MD, 2,804 ND'. 700 gpm, 3,225 psi off, 3,390 psi on. 80 rpm, 3.8k TQ off, 6.5k TQ on. PU - 96k, SO - 81 k, RWT - 84k, WOB - 40k. AST - 0.08 hrs, ART - 3.20 hrs. *SV1 faulted. Started losing mud ~ appx 60 bph. 'Encountered Hydrates starting ~ 2,424'. Intermittent to TD. SURF Circulate and condition mud. Monitor well - OK. 710 gpm, 3,090 psi FCP. 80 rpm, 2.2k TQ. 60 bph loss rate. 9.3 PP9 MW. SURF Short trip to 1,579'. Pulied OK to to 2,676'. Started pulling 30k over and swabbing Pump out from 2,676' to 2,245' ~ 125 gpm, 340 psi. Started steady 25k drag. Backream from 2,245' to 2,149' ~ 700 gpm, 2,880 psi, 80 rpm, 2.8k TQ Pump out from 2,149' to 1,862' ~ 125 gpm, 300 psi. Started drag. Backream from 1,862' to 1,771' ~ 695 gpm, 2,490 psi, 80 rpm, 2.3k TQ. Pump out from 1,771' to 1,675' ~ 125 gpm, 270 psi. Pull out dry from 1,675' to 1,579' - no excess drag or swabbing. SURF Run in hole without problem. Wash last stand to bottom, no fill. "Lost total of 518 bbls for the day. SURF Circulate 3 times bottoms up. Shakers clean. 700 gpm, 3,130 psi ICP, 3,040 psi FCP. 100 rpm, 2.9k TQ PU - 102k, SO - 87k, RWT - 87k. MW - 9.3 ppg. Loss rate - 60 bph. SURF POH from 2,978' to 270'. Pulled dry except ~ tight spot 1,150'. Backreamed from 1,180' to 990' ~ 595 gpm, 1,740 psi, 90 rpm, 2k TQ. Ran back in hole to 1,180 without probiem. Pulled dry from 1,180' without probiem to BHA. Printed: 7/10/2007 71:38:02 AM i C~ Legal Well Name: V-222 Common Well Name: V-222 Spud Date: 6/4/2007 Event Name: DRILL+COMPLETE Start: 6/3/2007 End: 6/13/2007 Contractor Name: NABORS ALASKA DRILLING i Rig Release: 6/13/2007 Rig Name: NABORS 9ES Rig Number: 9ES 6/6/2007 04:00 - 06:00 2.00 DRILL P SURF Laydown BHA #1. Bit grade: 3-3-WT-A-E-I-SS-TD. 06:00 - 06:30 0.50 DRILL P SURF Clear and clean rig floor. 06:30 - 08:30 2.00 CASE P SURF Rig up to run 9 5/8" surface casing. Make dummy run with hanger and landing joint. 08:30 - 12:00 3.50 CASE P SURF PJSM. Pick up and make up (Baker-Lok) 9 5/8" 40# L-80 BTC 80 ft shoe track. Check floats - OK. Run in hole with casing to 1,547'. Fiil every joint. 9,000 ft/lbs make up torque. Used Best-O-Life 2000 NM pipe dope. 'Lost 313 bbls from midnight to noon. 12:00 - 14:30 2.50 CASE P SURF Continue running in hole with 9 5/8" surface casing from 1,537' to 2,935' filling every joint. Went in hole good. Took 25k at base of permafrost. 14:30 - 15:00 0.50 CASE P SURF Rig down Franks fill-up tool, blowdown topdrive. 15:00 - 16:00 1.00 CASE N SFAL SURF Pick up and attempt to make up hanger pup joint to top joint of casing. Threads were not crossed when making up. The landing joint was wobbling around. Stopped make up of connection, backed out until threads jumped. Make back up to make up torque with landing joint acting as before. Had appx 3 inches of threads left to make up mark with torque applied. Back out hanger pup, inspect threads. Casing box threads were damaged. Hanger pup pin end appeared to have a thread milling anomaly. Change out last joint of casing, make up circulating swedge. 'Lost 180 bbls on casing run. 16:00 - 17:00 1.00 CASE P SURF Circulate and condition mud ~ 4 bpm, 400 psi. Stage up to 5.7 bpm, 460 psi. Reciprocate casing. Loss rate ~ 20 bph. 17:00 - 17:30 0.50 CASE P SURF Make up new hanger and land casing. PU - 156k, SO - 108k. Rig up cementing head. Halliburton 9 5/8" Float Shoe 2 Jts 9 5/8" 40# L-80 BTC Casing (#1- #2) Halliburton 9 5/8" Float Collar 1 Jt 9 5/8" 40# L-80 BTC Casing (#3) 3ea 9 5/8" 40# L-80 BTC Pup Jts ( 20.08', 9.68', 5.15') 1 Jt 9 5/8" 40# L-80 BTC Casing (#4- #49) 9 5/8" Tam Port Collar 1 Jt 9 5/8" 40# L-80 BTC Casing (#50- #71) 9 5/8" 40# Hanger Pup Jt Casing hanger (10-3/4" LH Acme top conn) Bowsprings Centralizers: 1 on stop ring 5-10' above shoe on jt #1 1 centralizer on collar of jt #2 1 centralizer 10' above fioat collar on jt #3 Centralizer on jts #4 thru # 25 1 centralizer with stop ring 10' above and below Tam Jts #49-#50 Total of 27ea. centralizers, 4ea. stop rings 17:30 - 19:30 2.00 CEMT P SURF Circulate and condition mud ~ 5.7 bpm, 375 psi FCP Reciprocate casing 10 ft strokes. Printed: 7/70/2007 11:38:02 AM • ~ Legal Well Name: V-222 Common Well Name: V-222 Spud Date: 6/4/2007 Event Name: DRILL+COMPLETE Start: 6/3/2007 End: 6/13/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/13/2007 Rig Name: NABORS 9ES Rig Number: 9ES 6/6/2007 17:30 - 19:30 2.00 CEMT P SURF 19:30 - 22:00 2.50 CEMT P SURF 22:00 - 23:15 125 CEMT P SURF 23:15 - 00:00 0.75 CASE P SURF 6/7/2007 00:00 - 02:00 2.00 CASE P SURF 02:00 - 04:00 2.00 DIVRTR P SURF 04:00 - 04:30 0.50 W HSUR P SURF 04:30 - 05:30 1.00 WHSUR P SURF 05:30 - 08:00 2.50 BOPSU P SURF 08:00 - 08:30 0.50 BOPSU P SURF 08:30 - 12:00 3.50 BOPSU P SURF 12:00 - 13:00 1.00 BOPSU P SURF PU - 150k, SO - 112k. Loss rate increased from 20 bph to 40 bph, then to 80 bph on last circulation. Held PJSM with Dowell while circulating. 'Lost 194 bbls from noon to end of circulation. Pump 16 bbls of water (problem with Dowell computer). Pressure test lines to 3,500 psi - OK. Pump 63 bbls of 10.5 ppg MudPush II Spacer ~ 5 bpm avg. 155 psi ICP, 110 psi FCP. Drop bottom wiper plug. Mix on the fly and pump 430 bbls of Arctic Set Lite 10.7 ppg lead cement ~ 5.4 bpm, 105 psi ICP, 300 psi FCP. 'Last 180 bbls had 2 ppb of CemNet Batch mix and pump 58 bbls of Class "G" 15.8 ppg tail cement ~ 5.3 bpm, 450 psi, ICP, 285 psi FCP. 'MudPush ~ surface with 20 bbis of tail away. Batch mix and pump 23 bbls of Class "G" 15.8 ppg tail cement with Durastone and 2 ppb Cemnet ~ 5.1 bpm, 265 psi, ICP, 225 psi FCP. Release top piug and kick out with 10 bbis of water. No indication of plug releasing. Pull cap off of head to check for plug release - OK. 'Lost 200 bbls out of 557 bbls pumped before dumping mud. Switch to rig and displace cement with 209 bbls of 9.4 ppg mud. 'Contaminated cement to surface when first bringing pump online. 1st 180 bbls ~ 5 bpm, 185 psi ICP, 675 psi FCP Next 20 bbis ~ 2 bpm, 580 psi ICP, 785 psi FCP. Land casing. PU - 120k, SO - 48k Last 9 bbis f~ 1 bpm, 770 psi ICP, 820 psi FCP. Bump plug on schedule ~ 95% pump efc with 1,350 psi. Check fioats - OK. 'Reciprocated casing 10 ft strokes. `Returned 185 bbls of sidewalk cement to surface. Pressure test casing to 3,500 psi - 30 min - Good test. `Lost 394 bbls from noon to 23:00 hr 'Lost 707 bbls for the day "Lost total of 1,225 bbls total to weli Rig down cement and casing equipment. Nipple down surface diverter. Bring wellhead into cellar. Nipple up and test metal to metal seals on welihead to 1,000 psi - 10 min - OK. Nipple up BOPE. Rig up to test BOPE. Pressure test BOPE to 250 psi low, 4,000 psi high. Tested annular preventer to 250 psi low, 3,500 psi high. All tests 5 min each. Accumulator test. W itnessing of test waived by AOGCC rep John Crisp. Test witnessed by BP WSL B. Buzby and NAD TP K. Cozby. Blow down lines. Rig down BOPE test equipment. Install wear Printed: 7/10/2007 11:38:02 AM • ~ Legal Well Name: V-222 Common Well Name: V-222 Spud Date: 6/4/2007 Event Name: DRILL+COMPLETE Start: 6/3/2007 End: 6/13/2007 'Contractor Name: NABORS ALASKA DRILLING i Rig Release: 6/13/2007 Rig Name: NABORS 9ES Rig Number: 9ES 6/7/2007 12:00 - 13:00 1.00 BOPSU P SURF 13:00 - 14:30 1.50 BOPSU P SURF , 14:30 - 16:30 2.00 DRILL P PROD1 16:30 - 17:30 I 1.00 I DRILL I P I I PROD1 17:30 - 19:00 1.50 DRILL P PROD1 19:00 - 20:00 1.00 DRILL P PROD1 20:00 - 20:30 0.50 DRILL P PROD1 20:30 - 21:00 0.50 DRILL P PROD1 21:00 - 22:15 125 DRILL P PROD1 22:15 - 22:30 ~ 0.25I DRILL I P I I PRODi 22:30 - 23:30 1.00 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 6/8/2007 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 04:30 4.00 DRILL N DFAL PROD1 04:30 - 06:00 1.50 DRILL N DFAL PROD1 06:00 - 07:00 1.00 DRILL N DFAL PROD1 07:00 - 08:00 1.00 DRILL N DFAL PROD1 08:00 - 08:30 0.50 DRILL N DFAL PRODi 08:30 - 09:00 0.50 DRILL N DFAL PROD1 09:00 - 11:00 2.00 DRILL N DFAL PROD1 11:00 - 20:30 9.50 DRILL P PROD1 bushing. Change out quill / lower IBOP. Test IBOP to 250 psi low, 4,000 psi high. Pick up drilling assembly BHA #2: Used Hycalog 8 3/4" DS70 bit, 1.15 deg PDM, NM STAB, LWD/ARC, MWD, LWD/ADN, 2ea NM DC, saver sub, 1 ea 5" HWDP, Jars, 1 ea HWDP, XO Run in hole with BHA #2 from 257' to 932'. Rotated through Tam Collar ~ 929' - OK. Shallow hole test MWD ~ 585 gpm, 1,360 psi - OK. Continue running in hole from 932' to 2,719'. Picked up ghost reamer ~ 1,180'. Cut and slip drilling line 39'. Clean out from under drawworks. Adjust brakes. Service topdrive, crown and drawworks. Run in hole from 2,719' and wash down to float collar @ 2,882' on depth. Clean out shoe track from 2,882' to 2,967'. Clean out rathole to 2,978'. 550 gpm, 1,785 psi, 60 rpm, 3.2k TQ PU - 103k, SO - 78k, RWT - 91k, WOB - 5k. Drill 20 ft of new hole from 2,978' to 2,998'. 550 gpm, 1,785 psi, 60 rpm, 4k TQ PU - 103k, SO - 78k, RWT - 91 k, WOB - 5k. Finish dispiacing 9.4 ppg mud with new 8.8 ppg LSND mud. 552 gpm, 1,235 psi, 60 rpm, 3.8k TQ. Perform LOT 2,967' MD, 2,794' TVD Leak off pressure - 997 psi MW - 8.8 PP9 EMW - 15.66 ppg Obtain benchmark ECD's and SPR's. During benchmarking, had trouble with MW D syncing. Able to get benchmarks, but data rate had switched from 24/6 to 24/3. Downlink to MWD to change data rate to 24/6. Signal sent and acknowledged by MWD. MWD would not sync at all after command was sent. Troubleshoot tool with help from shop and Anchorage without success. Observe well - OK. MW - 8.8 ppg. POH for MWD from 2,998' to BHA. PJSM on nuclear source. Change out MWD. Clear and clean rig floor. Make up BHA #3. Load source. Run in hole with BHA #3 to 990'. Shallow hole test MW D. 585 gpm, 1,425 psi. Run in hole from 990' to 2,910' - Wash last stand to bottom C~3 2,998'. Drill 8 3/4" production hole from 2,998' to TD ~ 5,278' MD, ~ 4,916' ND. 585 gpm, 2,020 psi off, 2,345 psi on. 100 rpm, 3.8k TQ off, 6.2k TQ on. PU - 134k, SO - 100k, RWT - 117k, WOB - 10/15k CECD - 9.53 ppg, AECD - 9.98 ppg Printed: 7/10/2007 71:38:02 AM . ~ Legal Well Name: V-222 Common Well Name: V-222 Spud Date: 6/4/2007 Event Name: DRILL+COMPLETE Start: 6/3/2007 End: 6h3/2007 Contractor Name: NABORS ALASKA DRILLING i Rig Release: 6/13/2007 Rig Name: NABORS 9ES Rig Number: 9ES I 6/8/2007 I 6/9/2007 11:00 - 20:30 1 9.501 DRILL I P 20:30 - 21:00 I 0.50I DRILL I P 21:00 - 23:30 I 2.501 DRILL I P 23:30 - 00:00 I 0.501 DRILL I P 00:00 - 00:30 I 0.501 DRILL I P 00:30 - 01:00 I 0.50 i DRILL I P 01:00 - 05:30 I 4.50I DRILL I P 05:30 - 06:30 I 1.001 DRILL I P 06:30 - 08:00 1.50 DRILL P 08:00 - 09:30 1.50 DRILL P 09:30 - 10:00 0.50 DRILL P 10:00 - 12:00 2.00 BOPSU P 13:30 - 15:00 1.50I CASE P 15:00 - 17:30 I 2.501 CASE I P PROD1 AST - 0.53 hrs, ART - 4.89 hrs. Pumped 50 bbl high vis sweep ~ 3,580'. No increase in cuttings when returned back to surface. PROD1 Circulate open hole volume. 585 gpm, 2,000 psi. 100 rpm, 3.8k TQ. Monitor well - OK. MW - 9.0 ppg PROD1 Backream from 5,278' to 4,728'. Adjust reaming speeds according to ECD's. 580 gpm, 2,010 psi 100 rpm, 4.1 k TQ. CECD - 9.53 ppg, AECD - 9.98 ppg / 10.5 ppg. PROD1 Circulate for ECD's. 580 gpm, 1,940 psi. 100 rpm, 4k TQ. AECD after circulating - 9.90 ppg. PROD1 Backream from 4,728' to 4,596'. Adjust reaming speeds according to ECD's. 580 gpm, 2,020 psi 100 rpm, 3.8k TQ. CECD - 9.53 ppg, AECD - 9.98 ppg / 10.56 ppg. PROD1 Circulate bottoms up for ECD's. 580 gpm, 1,975 psi. 100 rpm, 3.6k TQ. CECD - 9.53 ppg, AECD - 9.90 ppg. PROD1 Backream from 4,596' to shoe ~ 2,967'. Continued backreaming to 2,910' Adjust reaming speeds according to ECD's. Was able to increase reaming speed once ghost reamer was above shoe. 580 gpm, 1,725 psi 100 rpm, 3.2k TQ. CECD - 9.53 ppg, AECD - 9.92 ppg. PROD1 Circulate 2 bottoms up ~ 580 gpm, 1,650 psi. Still had good amount of clay after 1 st bottoms up. 100 rpm, 2.9k TQ. CECD - 9.53 ppg, AECD - 9.60 ppg. PU - 100k, SO - 75k, RWT - 86k. Monitor weli f/ 10 min 0 OK. MW - 9.1 ppg. PRODi POH from 2,910' to BHA. PRODi PJSM on nuclear source. Laydown BHA #3. Bit grade: 0-1-CT-N-X-I-NO-TD PROD1 Clear and clean rig floor. RUNPRD Change out to pipe rams from VBR's to 7". Test door seals to 250 psi low, 3,500 psi high - OK. RUNPRD Rig up to run 7" production casing. RUNPRD PJSM. Pick up and Baker Lok 80 ft shoe track. Check floats - OK. Run in hole with 7" 26# L-80 BTC-M casing to 999'. Make up TQ - 9,600 ft/Ibs with BOL 2000 pipe dope. Fill every joint. Check PU and SO weights every 10 joints. RUNPRD Make up crossover joint and run in hole from 999' to 2,962 with Printed: 7/10/2007 11:38:02 AM s • Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 6/9/2007 15:00 - 17:30 17:30 - 18:00 18:00 - 21:30 V-222 V-222 Spud Date: 6/4/2007 DRILL+COMPLETE Start: 6/3/2007 End: 6/13/2007 NABORS ALASKA DRILLING I Rig Release: 6/13/2007 NABORS 9ES Rig Number: 9ES 2.50 CASE P RUNPRD 7" 26# L-80 TCII casing. Make up TQ - 10,100 fUlbs with JetLube Seal Guard pipe dope. Fill every joint. Check PU and SO weights every 10 joints, 0.50 CASE P RUNPRD Circulate 1 1/2 times bottoms up. 5 bpm, 300 psi. PU - 111 k, SO - 88k. 3.50 CASE P RUNPRD Run in open hole from 2,967' to 5,238' without problem. Pick up hanger and landing joint. Land casing on depth @ 5,268'. PU - 165k, SO - 125k. Fill every joint. Check PU and SO weights every 10 joints. Circulated down every 10 joints for 3 minutes ~ 5 bpm. 2 minutes per joint running speed. 'No mud losses for entire casing job. HES Float Shoe 2 Jts 7", 26#, L-80 BTC-Mod (#1-2) HES Float collar 9 Jts 7", 26#, L-80 BTC-Mod (#3-11) 7", 26#, L-80 BTC-Mod Marker Pup w/ RA in collar. 13 Jts 7", 26#, L-80 BTC-Mod (#12-23) 7" 26# L-80 TC-II X BTC-M crossover joint 104 Jis 7", 26#, L-80 TC-Il (#1 - 104) 7" 26# L-80 TC-II Pup Jt. FMC Hanger 7 1/8" x 8 1/4" Rigid Straight Blade Centralizers: Jt. # 1 2 cent. locked down next to shoe. BTC-M Jt. # 2 2 cent Floating with stop ring in the middle BTC-M Jts. # 4 thru # 23 2 ea. Floating with stop ring in the middle Cross over joint 2 ea. Floating with stop ring in the middle TC-II Jts #1 -#12 2 ea. Floating with stop ring in the middle 70 ea Total Centralizers 35 ea Total stop rings 21:30 - 22:00 22:00 - 00:00 6/10/2007 I 00:00 - 02:00 0.50 CASE P RUNPRD Rig down Frank's tool, make up 2 plug cementing head. 2.00 CEMT P RUNPRD Stage pump up to 6 bpm, 460 psi ICP. Reciprocate pipe 20 ft strokes PU - 165k, SO - 125k. Held cementing PJSM while circulating. 2.00 CEMT P RUNPRD Single stage cement job. PU - 165k, SO - 122k. Pump 5 bbls water. Pressure test lines to 4,200 psi - OK. Batch mix and pump 72 bbls MudPush II 10.3 ppg spacer C~ 5.5 bpm, 283 psi ICP, 237 psi FCP Release bottom wiper plug. Pump 56 bbls of batched mixed 15.8 ppg class "G" tail cement ~ 5.2 bpm, 223 psi ICP, 200 psi FCP. Printed: 7/10/2007 11:38:02 AM • ~ Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 6/10/2007 I 00:00 - 02:00 V-222 V-222 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Spud Date: 6/4/2007 Start: 6/3/2007 End: 6/13/2007 Rig Release: 6/13/2007 Rig Number: 9ES 2.001 CEMT I P I I RUNPRD 02:00 - 02:30 0.50 CEMT P RUNPRD 02:30 - 03:30 1.00 CEMT P RUNPRD 03:30 - 04;00 0.50 WHSUR P RUNPRD 04:00 - 05:00 1.00 BOPSU P RUNPRD 05:00 - 06:00 1.00 BOPSU P RUNPRD 06:00 - 06:30 0.50 PERFO P OTHCMP 06:30 - 08:00 1.50 PERFO P OTHCMP 08:00 - 12:00 4.00 PERFO P OTHCMP 12:00 - 13:30 1.50 PERFO P OTHCMP Clean out cement lines to Tee on rig floor. Switch over to rig. Release top plug. Pump 199 bbls of 8.6 ppg seawater. ist 170 bbls ~ 5 bpm, 133 psi ICP, 706 psi FCP. Next 20 bbls ~ 2 bpm, 480 psi ICP, 885 psi FCP. Next 9 bbls (~ 1 bpm, 885 psi, ICP, 983 psi FCP. Bump plug with 1,500 psi. Bleed off pressure, check floats - OK. CIP ~ 01:45 hr. Reciprocated casing in 20' strokes Landed casing 3 bbis prior to plug bumping. PU - 133k, SO - 98k. 'No mud losses. Pressure test casing to 4,000 psi - 30 min - OK. Rig down casing and cementing equipment Install and test pack-off to 5,000 psi - 15 min - OK. Change out top pipe rams from 7" to 3.5" x 6" VBR's Performed post cement LOT on 7" x 9 5/8" annulus. 2,794' ND 5.2 bbls ~.3 bpm to 600 psi leak off pressure 9.1 ppg MW 13.23 ppg EMW Perform annular injectivity test Additional 5 bbls ~ 3 bpm, 830 psi SIP - 500 psi Test upper 3.5" x 6" VBR's and lower 2.875" x 5" VBR's to 250 psi low, 3,500 psi high - OK. (3.5" test joint) Pick up DPC running equipment to rig fioor. Rig up to run DPC perf guns. Pick up and make up 4.5" HSD, 4505PJ, 5 spf DPC perf gun assembly and MWD. Run in hole with DPC perf assembly from 389' to Float Collar on depth @ 5,182' (PBTD) Log up and tie in perf guns, placing bottom shot ~ 5,000' and top shot ~ 4,724'. Displace well from seawater to 9.0 ppg brine. 302 gpm, 865 psi. PU - 128k, SO - 97k. 'Sim Ops Injected OA with additional 140 bbls of 9.1 ppg LSND mud. 2 bpm, 800 psi ICP, 1,000 psi FCP, 790 psi SIP. 'UCA compressive strength - 531 psi ~ 10:41 hr (6.55 hrs to strength) "UCA compressive strength - 1,097 psi ~ 11:59 hr (8.13 hrs to strength) 13:30 - 14:00 0.50 PERFO P OTHCMP PJSM. Initiate gun firing sequence and fire guns with good indication. 6 bbls loss when guns fired then static. *Perf intervals: 4,724' - 4,766', 42 ft- 210 shots 4,798' - 4,828', 30 ft- 150 shots Printed: 7/10/2007 11:38:02 AM • • Legal Well Name: V-222 Common Well Name: V-222 Spud Date: 6/4/2007 Event Name: DRILL+COMPLETE Start: 6/3/2007 End: 6/13/2007 Contractor Name: ' NABORS ALASKA DRILLING I Rig Release: 6/13/2007 Rig Name: NABORS 9ES Rig Number: 9ES 6/10/2007 I 13:30 - 14:00 I 0.50I P 14:00 - 14:30 ~ 0.50 I P 14:30 - 15:30 I 1.001 P 15:30 - 19:30 4.00 19:30 - 21:30 2.00 P P P P 21:30 - 22:00 0.50 PERFOB~ P 22:00 - 23:00 1.00 PERFOBI P 23:00 - 00:00 1.00 EVAL I P 6/11 /2007 ~ 00:00 - 01:00 01:00 - 02:30 1.00 EVAL P 1.50 EVAL P 02:30 - 03:30 03:30 - 07:00 07:00 - 08:00 08:00 - 11:00 t 1:00 - 15:30 15:30 - 20:30 20:30 - 23:00 P OTHCMP 4,842' - 4,860', 18 ft- 90 shots 4,898' - 4,918', 20 ft- 100 shots 4,958' - 5,000', 42 ft- 210 shots Total - 152 ft- 760 shots 1.00 EVAL P 3.50 EVAL P 1.00 EVAL P 3.00 RUNCO 4.501 RUNCO 5.00 RUNCO 2.50 RUNCO 'Sim Ops Freeze protected OA with 70 bbls of dead crude. 2 bpm, 800 psi ICP, 1,000 psi FCP, 790 psi SIP. OTHCMP POH above top perf with pert assembly to 4,573'. PU - 128k, SO - 97k. OTHCMP Circulate bottoms up @ 278 gpm, 810 psi. Monitor well - static. MW-9.OpP9 OTHCMP POH with DPC perf assembly laying down driilpipe. Laydown MWD assembly. OTHCMP PJSM. Rig up and laydown perf assembly. All guns fired. Rig down and clear floor. OTHCMP Run in hole with remaining drillpipe out of derrick to 1,052'. OTHCMP POH laying down drill pipe from 1,052' to surface. OTHCMP Rig up SLB E-line for junk basket J gauge ring runs. *Lost total ot 16 bbls of 9.0 ppg brine to perfs. OTHCMP WL run #1: 6.125 gauge ring / junk basket w/ CL to 5,178' and back to surface. 1/2 gallon of perf debris. OTHCMP WL run #2: 6.125 gauge ring / junk basket w/ CL to 5,105' (5 ft below bot per~ and back to surface. Junk basket empty. OTHCMP Make up USIT tools. Surface test same - OK. OTHCMP Run in hole and USIT log 7" casing from 5,150'. Logging in "Primary Depth Control" mode. *Top of solid cement ~ 3,718'. OTHCMP Rig down SLB wireline. RUNCMP PJSM. Rig up to run completion. Pull wear bushing. Make dummy run with hanger and landing joint. Bring up and rig up I-wire related equipment. RUNCMP Pick up and make up 3.5" 9.2# L-80 TCII I-wire completion to 3rd feed through packer. When making up 1st 2 jewelry assembiies, found galied pin threads. Back out connection, inspect and redress threads. Checked remainder of jewelry threads and redressed same. All connections below bottom packer were Baker Lok'd. MU TQ - 2,300 ft/Ibs. Used JetLube Seal Guard pipe dope. SFAL RUNCMP Unable to get readings from Phoenix Sensor sub. Re-splice connection without success. Trouble shoot equipment. Pull back to Sensor sub and replace 1-wire from Sensor sub, thru 2nd packer. Lower pipe to 3rd packer. Make splice, test connectivity to Sensor sub - OK. Test connections to 5,000 psi -10min-OK. RUNCMP Continue running in hole with compietion jewelry to 4th packer. Printed: 7/70/2007 11:38:02 AM . ~ Legal Well Name: V-222 Common Well Name: V-222 Spud Date: 6/4/2007 Event Name: DRILL+COMPLETE Start: 6/3/2007 End: 6/13/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/13/2007 Rig Name: NABORS 9ES Rig Number: 9ES 6/11/2007 20:30 - 23:00 2.50 RUNCO RUNCMP Make final I-wire splice, test connectivity to Sensor sub - OK. 7est connections to 5,000 psi - 10 min - OK. 23:00 - 00:00 1.00 RUNCO RUNCMP Continue running in hole with completion to 480'. Ran jewelry assemblies and 2 joints of tubing ~ end of tour. *No fluid loss for the day. 6/12/2007 00:00 - 10:00 10.00 RUNCO RUNCMP Continue running in hole with I-wire quad packer completion assembly from 480' to 3,025'. Check I-wire every 1,000 ft. Picked up space out pups and e~ra joint to place packers on depth in relation to perforations. 10:00 - 10:30 0.50 RUNCO RUNCMP PJSM. Rig up SLB E-line, pack-off and pump-in sub. 10:30 - 12:00 1.50 RUNCO RUNCMP Run in hole with E-line and log-in completion string to confirm space out. Space out good, no changes. 12:00 - 12:30 0.50 RUNCO RUNCMP Rig down SLB E-line. 12:30 - 13:00 0.50 RUNCO RUNCMP Laydown extra joint. Pick up and make up hanger and landing joint. 13:00 - 14:00 1.00 RUNCO RUNCMP Terminate I-wires to tubing hanger. Test connections to 5,000 psi - 10 min - OK. Test I-wire connectivity - OK. 14:00 - 14:30 0.50 RUNCO RUNCMP Land tubing, run in lock down screws. PU - 75k, SO - 65k. Drop 1 5/16" ball and rod. Laydown landing joint. 3.5" 92 # WLEG, 3.5" TC-II ~ 5,058' Tops: 3.5" HES 'XN' Nipple: ID 2.750 ~ 5,036' 3.5" HES'X' Nipple: 2.813" ID RHC-M Piug ~ 5,015' GLM #1 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 4,986' 3.5" HES'X' Nipple: 2.813" ID @ 4,966' 3.5" x 7" HES single feedthru Packer #1 packer @ 4,942' GLM #2 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch @ 4,924' 1 Jt 3.5" 92# L-80 TC-II Tubing (#1) GLM #3 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 4,848' 3.5" HES 'X' Nipple: 2.813" ID ~ 4,842' Phoenix Sensor sub C~2 4,839' 3.5" x 7" HES Single feedthru Packer # 2 packer ~ 4,832' GLM #4 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 4,813' GLM #5 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch C~ 4,784' 3.5" x 7" HES Dual feedthru Packer # 3 packer ~ 4,771' 3.5" HES'X' Nipple: 2.813" ID ~ 4,762' GLM #6 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 4,743' 3.5" 9.2# L-80 TC-II Pup w/ RA Tag @ 4,733' 1 jt 3.5" 9.2# L-80 TC-II Tubing (#2 ) GLM #7 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 4,682' Phoenix Sensor sub ~ 4,676' 3.5" x 7" HES Dual feedthru Packer # 4 packer ~ 4,662' 3.5" HES'X' Nipple: 2.813" ID ~ 4,641' Printed: 7/10/2007 11:38:02 AM . ~ Legal Well Name: V-222 Common Well Name: V-222 Spud Date: 6/4/2007 Event Name: DRILL+COMPLETE Start: 6/3/2007 End: 6/13/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/13/2007 Rig Name: NABORS 9ES Rig Number: 9ES 6/12/2007 14:00 - 14:30 0.50 RUNCO RUNCMP GLM #8 - 3.5" x 1.5" MMG w/ DCR-1 SHEAR VALVE & RKP latch ~ 4,593' 61 jts 3.5" 9.2# L-80 TC-II Tubing (#3- 63 ) 3.5" HES'X' Nipple: 2.813" ID @ 2,647' 81 jts 3.5" 9.2# L-80 TC-II Tubing (# 64- 144 ) 2 ea 3.5", 9.2#, L-80 TC-II Space out Pups (7.78', 5.78') 1 jt 3.5" 92# L-80 TC-II Tubing (# 145 ) 3.5", 9.2#, L-80 TC-II Pup 4.5" X 3.5" TC-II Crossover FMC Tubing Hanger w/4 1/2" TC-II Lifting Threads ~ 24.22' Ran 80 Fuil I-Wire Clamps / 18 Half I-Wire Clamps 14:30 - 16:00 1.50 RUNCO RUNCMP Pressure tubing and set packers to 4,200 psi. Hold pressure for 30 min test - Good test. Bleed pressure down to 2,500 psi. Pressure test packers annulus to 4,000 psi - 30 min - Good ~ test. 'No pressure anomalies. ~ *W itnessing of test waived by AOGCC rep Jeff Jones. Bleed off annulus pressure to 0, bleed tubing pressure to 0. Pressure up on annulus and shear out DCK valve in GLM #8. Sheared (~3 2,350 psi. Estabiish circulation both ways - OK. 16:00 - 16:30 0.50 RUNCO RUNCMP Set 2-way check valve. Test same to 1,000 psi from below - OK. 16:30 - 18:00 1.50 BOPSU P RUNCMP Pressure wash rig floor pipe racks, clean out under rotary table and drip pan and ciean out floor drains. *Pre ND to clean all fluid paths to mudpits for S-401. (Had to be done with BOP stack on) i 18:00 - 19:30 1.50 BOPSU P RUNCMP Nipple down BOPE. 19:30 - 21:30 2.00 W HSUR P RUNCMP Nipple up tree adapter flange with I-wires. Pressure test same to 5,000 psi - 10 min - OK. Nipple up and test double valve tree to 5,000 psi - OK. 21:30 - 22:00 0.50 WHSUR P RUNCMP Rig up Drili Site Maintenance and pull 2-way check valve. 22:00 - 22:30 0.50 WHSUR P RUNCMP Rig up to reverse circulate and U-tube. 22:30 - 00:00 1.50 WHSUR P RUNCMP Reverse circulate 227 bbls of clean 9.0 ppg brine with last 50 bbls containing inhibitor. 3 bpm, 400 psi. 6/13/2007 00:00 - 02:00 2.00 WHSUR P RUNCMP Rig up LRHOS. Pressure test lines to 3,000 psi - OK. Reverse in and freeze protect weil with 93 bbls of diesel, 2 bpm, 100 psi ICP, 450 psi FCP. U-tube diesel back to tubing. Freeze protected to 2,670' MD, 2,500' TVD. 02:00 - 04:00 2.00 WHSUR P RUNCMP Lubricate in BPV. Test same to 1,000 psi from below - OK. Install VR plugs in IA. Secure well. Release rig from operations on V-222i ~ 04:00 hr, 6/13/2007 'Will be pressure washing mud pits for S-401 prior to rig move. Printed: 7/10/2007 11:38:02 AM ~~ V-222 Su Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure / Slot: V-Pad / Plan V-222 (NL+15) Well: V-222 Borehole: V-222 UWI/API#: 500292335700 Survey Name / Date: V-222 / June 9, 2007 Tort / AHD / DDI / ERD ratio: 50.302° / 1811.18 ft / 4.990 / 0.368 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatlLong: N 70.32802955, W 149.26559036 Location Grid N/E Y/X: N 5970092.900 ftUS, E 590554.870 ttUS Grid Convergence Angle: +0.69155037° Reaort Survey / DLS Computation Method: Minimum Curvature / ~ubinski Vertical Section Azimuth: 7.240° Vertical Section Origin: N 0.000 ft, E 0.000 ft ND Reference Datum: Rotary Table ND Reference Elevation: 81.00 ft relative to MSL Sea Bed I Ground Level Elevation: 52.50 ft relative to MSL Magnetic Declination: 23.481 ° Total Field Strength: 57626.933 nT Magnetic Dip: 80.864° Dedination Date: June 06, 2007 Magnetic Declination Model: BGGM 2007 North Reterence: True North Total Corr Mag North -> True North: +23.481 ° • Local Coordinates Referenced To: Well Head Comments ~leasured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS li I t u.uu u.VV u.uu -t5 i.uu u.VV ~.uv u.~~ u.uu u.uu GYD GC MS 100.00 0.20 40.61 19.00 100.00 0.15 0.17 0.17 0.13 200.00 0.27 24.75 119.00 200.00 0.52 0.58 0.58 0.48 267.00 1.08 2.64 185.99 266.99 1.30 1.36 1.32 1.25 358.00 2.04 346.66 276.96 357.96 3.67 3.83 3.69 3.69 451.00 5.31 2.63 369.76 450.76 9,51 9.76 9.60 9.60 542.00 7.33 9.43 46020 541.20 19.51 19.76 19.56 19.53 636.00 9.77 11.06 553.15 634.15 33.46 33.73 33.47 33.28 728.00 12.72 10.86 643.37 724.37 51.36 51.67 51.36 50.89 Last Gyro 820.00 14.54 7.93 732.78 813.78 73.02 73.35 73.03 72.28 First MWD+IFR+MS 854.87 14.73 7.18 766.52 847.52 81.83 82.16 81.84 81.01 946.80 16.27 9.63 855.10 936.10 106.38 106.72 106.40 105.30 1041.88 16.52 11.27 946.32 1027.32 133.18 133.56 133.22 131.69 1137.86 20.18 8.10 1037.40 1118.40 163.35 163.76 163.42 161.48 1232.74 21.36 9.64 1126.12 1207.12 196.98 197.40 197.06 194.71 1328.69 23.90 6.61 1214.68 1295.68 233.88 234.31 233.96 231.26 1423.98 23.87 5.85 1301.80 1382.80 272.46 272.90 272.51 269.61 1519.59 24.03 6.40 1389.18 1470.18 311.26 311.71 311.30 308.20 1616.39 23.85 7.07 1477.66 1558.66 350.54 350.99 350.57 34721 1710.96 23.76 5.55 1564.18 1645.18 388.70 389.16 388.72 385.14 1806.68 24.32 5.59 1651.60 1732.60 427.68 428. ~ 5 427.69 423.95 1902.95 23.89 5.72 1739.47 1820.47 466.98 467.47 466.99 463.08 1998.81 23.79 4.53 1827.15 1908.15 505.70 506.21 505.70 501.67 2094.52 23.70 5.18 1914.76 1995.76 544.21 544.75 544.21 540.07 2190.11 23.66 5.45 2002.30 2083.30 582.57 583.14 582.58 578.30 2286.03 23.22 6.14 2090.31 2171.31 620.72 621.30 620.73 616.26 SurveyEditor Ver SP 2.1 Bld( doc40x_100 ) Plan V-222 (NL+15)\V-222\V-222\V-222 V.UU V.UV J~/UU~L. yV JyVJJ4.0/ IV /V.JCOVG.7JJ VV 145.GOJ:7~VJ0 0.11 0.20 5970093. 03 590554.98 N 70.32802992 W 149.26558944 0.33 0.09 5970093. 38 590555.19 N 70.32803086 W 149.26558772 0.42 1.25 5970094. 16 590555.28 N 70.32803298 W 149.26558695 0.09 1.15 5970096. 59 590554.91 N 70.32803962 W 149.26558966 -0.10 3.65 5970102. 49 590554.66 N 70.32805577 W 149.26559116 1.05 2.36 5970112. 44 590555.68 N 70.32808291 W 149.26558188 3.56 2.61 5970126. 21 590558.03 N 70.32812046 W 149.26556150 6.97 3.21 5970143. 86 590561.22 N 70.32816858 W 149.26553387 10.47 2.12 5970165. 29 590564.46 N 70.32822700 W 149.26550548 11.63 0.77 5970174. 04 590565.52 N 70.32825086 W 149.26549609 15.24 1.82 5970198. 37 590568.84 N 70.32831723 W 149.2654 20.11 0.55 5970224. 81 590573.39 N 70.32838932 W 149.2654 25.11 3.95 5970254. 65 590578.03 N 70.32847069 W 149.265386 2 30.31 1.37 5970287. 95 590582.83 N 70.32856150 W 149.26534455 35.48 2.91 5970324. 55 590587.55 N 70.32866132 W 14926530267 39.66 0.32 5970362. 94 590591.27 N 70.32876611 W 14926526871 43.81 0.29 5970401. 58 590594.95 N 70.32887153 W 149.26523513 48.41 0.34 5970440. 63 590599.08 N 70.32897810 W 149.26519777 52.61 0.66 5970478. 62 590602.82 N 70.32908173 W 149.26516375 56.39 0.59 5970517. 46 590606.14 N 70.32918776 W 14926513305 60.27 0.45 5970556. 63 590609.54 N 70.32929465 W 149.26510163 63.73 0.51 5970595. 25 590612.53 N 70.32940007 W 149.26507356 66.99 0.29 5970633. 69 590615.33 N 70.32950498 W 149.26504710 70.55 0.12 5970671. 95 590618.42 N 70.32960941 W 149.26501826 74.40 0.54 5970709.95 590621.82 N 70.32971311 W 149.26498703 Generated 7/17/2007 2:07 PM Page 1 of 2 Comments Measured ~nclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de /100 ft ftUS ftUS 'L:itS1 .11 11 .y1 5.5/ Ll//.tSy "L"LStS.tS`J b525.UU b5tS. 5`J b525.UG b5;5.;i5 /iS.LV U.4U 5y/U/4/.Uy 2476 .80 22 .63 5.39 2266.02 2347.02 694.97 695. 58 695.00 690.18 81.73 0.30 5970783.95 2572 .45 22 .63 4.79 2354.31 2435.31 731.75 732. 39 731.79 726.84 85.00 0.24 5970820.64 2667 .79 24 .98 7.16 2441.53 2522.53 770.22 770. 86 770.26 765.09 89.04 2.66 5970858.94 2762 .93 25 .18 8.03 2527.70 2608.70 810.54 811. 19 810.58 805.07 94.37 0.44 5970898.97 2858. 92 24 .78 7.74 2614.71 2695.71 851.08 851. 72 851.11 845.22 99.93 0.44 5970939.19 2918. 48 24 .36 8.30 2668.88 2749.88 875.84 876. 49 875.87 869.74 103.39 0.81 5970963.75 2988. 52 24 .04 9.38 2732.76 2813.76 904.54 905 20 904.56 898.11 107.80 0.78 5970992.16 3032. 73 23 .83 8.48 2773.17 2854.17 922.46 923. 13 922.48 915.83 110.58 0.95 5971009.91 3127. 15 23 .74 8.95 2859.57 2940.57 960.53 961 21 960.54 953.47 116.35 0.22 5971047.62 3223. 62 23 .52 8.83 2947.95 3028.95 999.18 999. 88 999.19 991.67 122.33 0.23 5971085.89 3319 .53 23 .43 10.15 3035.93 3116.93 1037.36 1038. 09 1037.36 1029.35 128.63 0.56 5971123.64 3414 .50 22 .79 10.92 3123.27 3204.27 1074.57 1075. 36 1074.57 1066.00 135.44 0.75 5971160.36 3509 .41 22 .39 10.78 3210.90 3291.90 1110.96 1111. 82 1110.96 1101.81 142.30 0.43 5971196.24 3605 .49 21 .93 11.12 3299.89 3380.89 1147.12 1148. 06 1147.13 1137.39 149.18 0.50 5971231.90 3701. 83 21 .30 11.00 3389.45 3470.45 1182.53 1183. 55 1182.55 1172.22 155.99 0.66 5971266.81 3797. 51 21 .29 12.11 3478.60 3559.60 1217.18 1218. 30 1217.22 1206.26 162.95 0.42 5971300.93 3893. 89 21 .32 7.08 3568.40 3649.40 1252.14 1253. 29 1252.19 1240.76 168.78 1.90 5971335.49 3989. 31 22 .04 3.65 3657.07 3738.07 1287.35 1288. 54 1287.39 1275.84 172.06 1.53 5971370.61 4084. 87 21 .84 3.59 3745.71 3826.71 1322.99 1324 24 1323.01 1311.47 174.32 0.21 5971406.26 4180. 11 21 .74 3.57 3834.15 3915.15 1358.27 1359. 59 1358.28 1346.76 176.52 0.11 5971441.57 4276. 01 23 .69 4.43 3922.60 4003.60 1395.24 1396. 62 1395.24 1383.70 179.12 2.06 5971478.53 4371 ,26 26 .14 5.24 4008.98 4089.98 1435.33 1436. 75 1435.33 1423.68 182.51 2.60 5971518.54 4466 ,70 25 .50 4.76 4094.89 4175.89 1476.86 1478. 31 1476.86 1465.09 186.14 0.71 5971559.99 4562,24 25.22 4.37 4181.23 4262.23 1517.74 1519.23 1517,74 1505.88 189.40 0.34 5971600.81 4658.20 24.94 3.61 4268.14 4349.14 1558.35 1559.91 1558.35 1546.45 192.23 0.44 5971641.42 4753.78 24.56 3.09 4354.94 4435.94 1598.27 1599.92 1598.29 1586.40 194.57 0.46 5971681.38 4848.89 24.14 2.57 4441.59 4522.59 1637.37 1639.14 1637.40 1625.56 196.50 0.50 5971720.57 4945.16 23.97 3.35 4529.50 4610.50 1676.50 1678.38 1676.55 1664.75 198.53 0.37 5971759.77 5039.89 23.74 3.54 4616.14 4697.14 1714.73 1716.69 1714.80 1702.99 200.83 0.26 5971798.04 5136.59 23.39 3.25 4704.77 4785.77 1753.30 1755.35 1753.39 1741.59 203.12 0.38 5971836.65 Last MWD+IFR+MS 5207.65 23.21 2.67 4770.04 4851.04 1781.33 1783.46 1781.44 1769.66 204.57 0.41 5971864.73 TD ( Projected ) 5278.00 23.21 2.67 4834.69 4915.69 1808.96 1811.18 1809.10 1797.35 205.86 0.00 5971892.44 Survey Type: Definitive Survey NOTES: GYD GC MS -( Gyrodata - gyro compassing m/s -- Older G yrodata gyro multishots-plus all battery/memory tool surveys ( RGS-BT). Replaces ex-BP "Gyrodata multishot into open hole" model. Not to be run above 70 degrees inclination. ) MWD + IFR + MS -( In-field referenced MWD with mult-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Leqal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 4845 FSL 1746 FEL S11 T11 N R11 E UM 5970092.90 590554.87 BHL : 1363 FSL 1538 FEL S2 T11 N R11 E UM 5971892.44 590739.01 b`JUbLb. I/ IV /U.6L`Jt5144b VV 14`J.L04y00I / 590628.26 N 70.32991506 W 149.26492751 590631.08 N 70.33001521 W 149.26490103 590634.66 N 70.33011972 W 149.26486825 590639.51 N 70.33022893 W 149.26482501 590644.59 N 70.33033862 W 149.26477990 590647.74 N 70.33040562 W 149.26475188 590651.81 N 70.33048312 W 149.26471611 590654.38 N 70.33053152 W 149.26469353 590659.70 N 70.33063435 W 149.26464673 590665.21 N 70.33073872 W 149.26459826 590671.05 N 70.33084166 W 149.264547 590677.42 N 70.33094178 W 149.2644~ 590683.85 N 70.33103960 W 149.26443 590690.30 590696.69 590703.24 590708.65 590711.51 590713.33 590715.11 590717.26 590720.17 590723.30 N 70.33113680 W 149.26438043 N 70.33123195 W 149.26432520 N 70.33132495 W 149.26426875 N 70.33141919 W 149.26422145 N 70.33151504 W 14926419486 N 70.33161238 W 149.26417657 N 70.33170878 W 149.26415866 N 70.33180969 W 149.26413761 N 70.33191891 W 149.26411007 N 70.33203203 W 149.26408066 590726.06 N 70.33214347 W 149.26405423 590728.40 N 70.33225432 W 149.26403125 590730.26 N 70.33236345 W 149.26401227 590731.72 N 70.33247045 W 149.26399655 590733.28 N 70.33257751 W 149.26398011 590735.12 N 70.33268198 W 1492639~ 590736.94 N 70.33278741 W 1492639 590738.05 N 70.33286409 W 149.26393107 590739.01 N 70.33293975 W 149.26392058 SurveyEditor Ver SP 2.1 Bld( doc40x_100 ) Plan V-222 (NL+15)\V-222\V-222\V-222 Generated 7/17/2007 2:07 PM Page 2 of 2 :E - 4-118" C1Vti WE~~NEAL~ ~MG ACTIlATOR LEty KS, ELE~1 ~ _. ~ . ~ ~ ~ $1(~ BF E~EV - ~ e... .~ 7$ 75 . ~~. ~ e ~,. w KC?!' -- ~ ~ ~, 3IX)' Max At7gle = .___~_. 26 d~g , _ oatum PetC~ = dSXt~.2£3'. Datum TVI? - _ ~ ~~ ~i481 '~ s ~ ~J-5l$" Tam Pc~rt Goli~r, 10 = 8.8~~" 9-518'" GSG, 4{~#, L-8f1, BTG, ID = 8.E~35~~ ~2'~" (~° cs~ zc~. ~-s~. rc-~ ~ x grcaw c~o:~:~~~F .~. ~~' d~68' --._._ _- ~_~~ _ f 7" CSG, 2fi#, L 8~, BTC riNarker JT vel RA Tac~ ~~ ~1 ~1' Mini~num ID = 2. t 5" ~ 5~D3~' ~-1/2" HE~ ~~i ~IPP'i...~ (3 S` 9.z!# L-8ia Tc-~~ F'up jt, wl Ft~a Tag in collaf ~733' S~ NOTES: GLM'S @ STA #1- #7 ARE 3-1 /2'° ~~ ~~~ X 1iT11'" MMGW WHICH ARE WATER~I.OOD MANDREL.S. _.._~_.~ ~2~ 4-!!2"' XC? 3-tf2', ID = ~ 99'~'~ ~ _.~ _ ~ ___ 2~46'~ ~-,cz r~~s x r~s~ ~a~: .s~v ~ GAS LIFT MANDRELS ~ST MD ND DEV TYPE VLV LATCH PORT DATE 8 4594 4291 25 MMG FS RKP 0 06112107 WATER INJECTION MANDRELS ST MD ND DEV TYPE VLV LATCN PORT DATE 7 4683 4371 25 MMG-W DUM RK 0 06(01l07 6 4743 4427 25 MMG-W DUM RK 0 06/12I07 5 4785 4464 24 MMG-W DUM F2K 0 06/12107 4 4813 4490 24 MMG-W DUM RK 0 06l12107 3 4848 4522 24 MN1G-W DUM RK 0 06i12/07 2 4924 4591 24 MMG-W DUM RK 0 06l12/07 1 4987 4648 24 MMG-W DUM RK 0 06/12107 ~~~'~3-if2" HES X NIP, iC) = 2.813° ~ ~6S2F 7" NES AHR PKR Ck~~i Feed thns, ID = 2.965" ~675' ~~tr~~r~~x P~zES~~nnP sEr~sc~~a sue. ~Q = z.ssz• ~7~2' -(3-~~z~ ~ES x r~ap, io = z_~~s^ ~ .~. _ _._....~. ._...__ ~~~~+ 7" HES AHR PKR Duat Feed €hru, dD = 2.965" ~?" F€ES AFiF2 PKR ~i~gle F~t~t tMru, tD = 2 96~° f PERFCIf~'A~`K]NS' RY RE~ Lt)C,: SLI~ f'r~a1k~ L1JliD A E~tGLE AT T+~P F'~RF: 2~" ~ 47~6` tktte: Ftsfer fca Pt'~dUCt~tn I,~6 for t~istt>C~~{ p~rf d~fa i1~E 5P'~ ~lIFFtVAL C3pn/Sqz Lk?sTE 4-1l2" 5 A~~f6'- 472d' f3 t~6fi ~IC37 ~-112'° 5 ' ~82$". ~4?98' ' fl €l61i 2I0? 4~-112" 5' ~$6d}`- 4$4~' Gt Q6{121A7 4-1d2" 5 4918'- 48~8' t? Ofs112ti~7 ~112" 5 54af1`- 4~58' Q 46t12/tD7 ~-~~z° ~sG, ~.z~. ~-sta. ~r~-~i, .~as~ ~Pr, ~r~ = z.ssz- a~}~6" psro ~~'[82' ~~ cs~, as~. ~-a~. ~TC-~. Ea = s_z~s -{~' ~267• +~83"~~ PFiC?ENlX P~ESfTEMF" SENSO~ SUB, IC! = 2.93'"' T~~~-~3-1 d2" HES X iJEP, ~G7 = 2.81:~' ~'~~~'_ ~~7" HES RHR PKR ~iqle Peecf thru, IC1 = 2.985-~._~ ~.µ~ ~.g~~i' ^~3-1I2" HE~ ?C h~iP, IE3 - 2.SS3' ~1~t' a=~a~° ~a~s x r~iR, ~cr = z,~t~° ~}~~J' 3-1f~" NES XN N6P, I[} = 2.75" 50'S8' 3-tt2" vvt_~~, tt~= 2.~z' u~~rs +$c ~8C-'1 t~~z~~ u~~r vVEI.l.: V-222i PF~t~T IVK}: 2~I^(TS9{I J~f'! ~. SG~-iJ29-~~3 s~'-t7~-Q€# SEC '11, T91 N. f2i 1 E, ~1~` ~SL ~~` 17~' FEL E!P E;t~rlc~r~tic~n (Ala~k~a~ ` ~ :~'~C:3.a.NICAI, ~?~TEGRITY ~ r ~~..?~ _ - ~ ~ .. .-_ _ ~ ~ ~~-t `O'~ o P ~R ~ ' =.=c ..~~~._..~ . ~~~3-d`Z h~~1.I. ~UM~~~ ~ r LL DAT ~_ TD : Sr~~.~ .?-~.. ~'I~1~ Cp 'I'VD ~ 4 ~ 1~ p ~ Casi~g: ~ ~ Shoe: S~~o~ rID -- ~ ~c~~-o ~ ~.~QRT ~ ~ ~~'RO~.~.~ Q~c~ +~ ~ - a ~- ~--- _ ~TD : s ~~~ ~ ~~a~~-v-~ D; DV: ~~ ?"~ =~~i -_:,e= . ~ Shoe . '~ '?'~I~ ; _~P . '•ID _';~ r~o~ S ~ _~o'-='V ~?, fa _PzCKeT ~-1~o(c~ :'''~ T'J7i ; Set ~t ~ \ ~ _ 01 e S -~~ e ~$ ~ ~ ~-l and ~ ~ ; ~ e = ~ ~ ~-1'Z ~-- ~ t o ~f~ i rS ~ t~~~~~5 ;~:.c.r~?1=C~~ iNTEGR ~ T'Y - P 4~Z~ # ~ r_nr:ulus ~~ess Test: _? ; 15 nin ;~0 min C o~aen t s: ~..~ ~~~ S~-~~-- ~~~ ~~ ~ ya~~ ~S t~ c~ ~ a-S~C~ .~~~t.- ~' ~.j, "`s ~ ~~C~ PS ~ . r '~'CH~?~ ~ C~ ~., ~ NTEGRT'r~ _ p~T # Z . Cement Vol~es :~ ~~t. ~iner ~~ ; Csa ~ ~~~ S ; DV ~ ~ . {_ c ~ C~,~ -ro1 to cove~ ~er_s L° ~~JZ~kS 3~0 ~ll~~S T~s LD~~`~~~2C--3~'°~SC~ -=:eoretical TOC ~' '30~Zp K~ ~ ~t1~U~ - ~c -~-~ 31 ~Q '~ Lo ~ t~t-o? Cement Bond Log (Yes or No) ~c~c~ ; In AOGCC Fi~ e__~yl~- C3L ~valuation, ~one ~oove perfs ~~C~~~F-c~T K~~ ~~C _ ~ f~ Production i.og: T~ve ~UN~:;L;15 ~ ONS : ?art i 1 : ~ai ~ TL: ; Evaluation z(a~ p`'~ ~ ~ Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Christine Mahnken Well No V-222 Date Dispatched: 3-Jun-07 Installation/Rig Nabors 9ES Dispatched By: Franklin Medina LWD Log Delivery V1.1, 10-02-03 Data No Of Prints No of Flo ies Surveys 2 1 Received By: Please sign and return to: ~~~yyy Drilling & Measurements LWO Division ~/ ~ ~) ^ ( ~ ~ ~ 2525 Gambell Street, Suite 400 ~ C I 1 ~ 7 . ~ ~ ~ ~,r/ v Anchorage, Alaska 99501 nrose1 @slb.com Fax: 907-561-8317 ao~ -~rq ~J ~ J ~ ~ ~~ . chlu~~er e~ 3 ~ N0.4320 dy, ~~ I o ~~~~ Schlumberger-DCS .., ~O Company: Alaska Oil 8 Gas Cons Comm 2525 Gambell St, Suite 400 Attn: Christine Mahnken Anehorage, AK 99503-2838 ATTN B th L ° e ~ 333 West 7th Ave, Suite 700 Anchora AK 99501 e : e ~~9~ .. ~+~ ~~ ~ o ! YSfd g , y~~ ~ Field: Prudhoe Bay Orion Borealis Well Job # Log Description Date BL Color CD PLEASE ACKNOWLEOGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Cenler LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: ~~~ ~~~ ~/ <?`. SchlumbergerDCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received osizaio~ ~ ~-o -~~t~~~~T ~~ ~a~+ ~~lis.7~~~~1i~ld ~~~-7-7~~~ Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 ~ ;i.9ft.~M P~ALIiU, GOVERRl072 333 W. 7thAVENUE, SUITE 100 ANCHORAGE,ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Orion Oil Pool, V-222i BP Exploration (Alaska) Inc. Permit No: 207-059 Surface Location: 4845' FSL, 1745' FEL, SEC. 11, T 11 N, R 11 E, UM Bottomhole Location: 1380' FSL, 1514' FEL, SEC. 02, T11N, R11E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907)~3607 (pager). , DATED this ~ day of May, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. ~ STATE OF ALASKA ~"'~ . , ALAS~IL AND GAS CONSERVATION COMMI N S~t; 'rj~,~ PERMIT TO DRILL ~ 20 AAC 25.005 1 a. Type of work ~ Drill ^ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Deveiopment Gas ~ Service ~ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify i we is prop se,,~xi or: ^ Coalbed Methane ~~19~ates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ~ Blanket ^ Single Well Bond No. 6194193 . 11. Well Name and Number: V-222i 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 5292 ND 4913 12. Field / Pool(s): Prudhoe Bay Field / Orion 4a. Location of Well (Govemmental Section): Surface: 11 4845' FSL 1745' FEL SEC UM (As Planned) T11N R11E 7. Property Designation: ADL 028240 Schrader Bluff , , , . , , Top of Productive Horizon: 1136' FSL, 1540' FEL, SEC. 02, T11 N, R11 E, UM 8. Land Use Permit: 13. Approximate Spud Date: June 10, 2007 Total Depth: 1380' FSL, 1514' FEL, SEC. 02, T11N, R11E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 11,220' 4b. Location of Well (State Base Plane Coordinates): Surface: x-590555 y-5970093 Zone-ASP4 10. KB Elevation Plan (Height above GL): 82.1 feet 15. Distance to Nearest Well Within Pool: 753' 16. Deviated Wells: Kickoff Depth: 300 feet Maximum Hole An le: 26 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2222 Surface: 1732 18. Casin ``Pr ram: c~caf' ns To - Settin ` h- ` om uanti f``ment :f. r sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta e data 42" 20" 215.5# A-53 Weld 108' Surface Surface 108' 108' 260 sx Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BTC 2889' Surface Surface 2889' 2727' 474 sx AS Lite 412 sx Class'G' -3/4" 7" 26# L-8 TC-II 428 ' rfa rface 4289' 4 07' S e B I w 8-3/4" 7" 26# L-80 BTC-M 1003' 4289' 4007' 5292' 4913' 268 sx Class'G' 1 g. PRESE NT WELL CONDITION SUMMARY (To be eompleted for RedriU and Re-entry Operatians) : Total Depth MD (ft): Total Depth ND (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): asing ' Length ize Cement Volume MD D Conductor / Structural Surface Intermediate Pro i n Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ~ Filing Fee, $100 ^ BOP Sketch ~ Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ~ Drilling Fluid Program ~ 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Brandon Peltier, 564-5912 Printed Name Robert Tirpack Title Senior Drilling Engineer fi Prepared By Name/Number: Si nature ~~ ~. E~ Phone 564-4166 Date ~1 lI ~~ Terrie Hubble, 564-4628 Commission Use Onl . Permit To Drill Number: O API Number: 50-Oo19-o?3 5~0000 Permit Approval See cover letter for Da e: S 1/ D other re uirement Conditions of Approval: ~ If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ~ ~ Sam les Re 'd: M~~~ ~~~~~~~ ~_''`' ~ (~ P 4 ^ Yes ~No Mud Log Req'd: ^ Yes U/ No ~~+'~"`~'~r ~CRJ~~i ~'n ~~ ~~~t-~ ~''~~A1~ a(o ~ HZS Measures: (~ Yes ^ No D' ectional Survey Req'd: ~ Yes ^ No Other: ~(~~QO~-~-p ~~ov4~ s~ Qc,r~r~tac~~.tc~n,S ~ ~e +L~~r APPROVED BY THE COMMISSION Date ~~~ ~ ~ , COMMISSIONER ~~~~~~~~ t~PR 2 4 2007 . n Form 10-401 Revised 12/2005 O~~ w~- •~~ ~./ `~' / ~ Submit In DupliCate l7 N ~~~ • ~ Well Name: V-222i Drill and Complete Plan Summary T e of Well service / roducer / in'ector : Injector Tar et X Y Z TVDss Townshi Ran e Section FSL FEL Surface As-Staked 590554.9 5970093.2 na 11 N 11 E 11 4845 1745 T t1: To OA 590740 5971665 -4330 11 N 11 E 2 1135 1540 T t2: OBf Base 590763 5971910 -4831 11 N 11 E 2 1380 1514 AFE Number: N/A API Number: 50-029-xxxxx Estimated Start Date: June 10, 2007 O eratin da s: 13 Ri : Nabors 9ES TMD 5,292' TVD rkb: 4,913' RKB/GL 28.5'/53.6' RTE 82.1' Well Design: USH Grassroots Schrader Bluff Injector 3-'/z", L-80, TC-II, multi acker, zonal in'ection, and zonal monitorin com letion Current Status: New drill General Wetl Information: Estimated BHP: 2222 psi (8.7 ppg EMW) at 4973' TVD ~"-~~ Estimated BHT: 95 deg F at 4949' TVC~ Formation IVlarkers: Est. Est. Formation Formation Tops Tops Uncertainty Commercial Hydrocarbon Bearing Est. ~ Pore Press. -Est.~ Pore Press. Formation (MD) (TVDss) (feet) (Yes/No) (Psi) EM 9 G1 327 -245 +/-25 No 110 8.7 SV6 973 -885 +/-25 No 398 8.7 SV5 1691 -1550 +/-25 No 698 8.7 SV4 1833 -1680 +/-25 No 756 8.7 Base Permafrost 1855 -1700 +/-25 Gas hydrates 765 8.7 SV3 2276 -2085 +/-25 Gas hydrates 938 8.7 SV2 2473 -2265 +/-25 Gas hydrates 1019 8.7 SV1 2823 -2585 +/-25 Gas hydrates 1163 8.7 Fault 1(V-Pad Fault) 2829 -2590 f/- 100' M.D. - See fault detail section UG4 2976 -2725 +/-25 Thin coal 1226 8.7 UG4A 3009 -2755 +/-25 Heavy Oil (2820 - 2970' SS) 1240 8.7 UG3 3419 -3130 +/-25 Thin coals 1409 8.7 UG1 3977 -3640 +/-25 Heavy Oil (3720 - 3910' SS) ~ 638 8.7 V-222i Permit to Drill Page 1 ~ ~ UG Ma 4289 -3925 +/-25 Heavy Oil (3930 - 1766 8 7 - 3960' SS) . UG_Mb1 4344 -3975 +/-25 No (wet) 1789 8.7 UG Mb2 4410 -4035 +/-25 Heavy Oil (4040 - 1816 7 8 - 4070' SS) , UG_Mc 4481 -4100 +/-25 No (wet) 1845 8.7 SB_Na 4552 -4165 +/-25 No (wet) 1874 8.7 SB_Nb 4579 -4190 +/-25 No (wet) 1886 8.7 SB_Nc 4617 -4225 +/-25 No (wet) 1901 8.7 SB_Ne 4626 -4233 +/-25 No (wet) 1905 8.7 SB OA 4733 -4330 +/-25 Yes 1680 7 5-8 0 - 1800 . . SB OBa 4811 -4400 +/-25 Yes 182~ 8 0-8 5 - 1950 . . SB OBb 4856 -4440 +/-25 Yes 1850 8 0-8 5 - 1970 . . SB OBc 4917 -4495 +/-25 Yes 1900 8.1 SB OBd 4973 -4545 +/-25 Yes 1730 7 3-8 0 - 1880 . . SB OBe 5045 -4610 +/-25 Yes 2050 8.6 SB OBf 5089 -4650 +/-25 Yes 2070 8.6 Base SB OBf 5140 -4695 +/-25 No 2090 8.6 T.D. in Colville 5292 -4831 No Shale (wp01) 2180 8.7 Wells within a'/a mile of this in'ection well, scanned from the to of the reservoir to TD Well Name Dist, Ft. Annulus Integrity Comments V-202, L1, L2 712' @ Top of Pool Offset producer. For V-201 A injection intervals, closest approach is (Top Na) 855' C«~OA (V-202L2), 944' C«~OBa (V-202L1), 1232'C~OBd (V-202). Top of cement calculated to be in the UG3 interval (3685' MD). Good cement isolation. V-201 794' @ Top of Pool Original hole for V-201 A- will be cemented, P&A'd. Top of cement (Top Na) calculated to be in the UG3 interval. Bond log shows good quality of cement along and above Schrader Bluff with top at 3488' MD. Good cement isolation. V-105 873' @ Top OBb Dual SB/Kuparuk injector. Top of cement calculated to be in the UG3 interval. Bond log shows good quality of cement along and above Schrader Bluff with TOC at 4406' MD. Good cement isolation. V-204, L1, L2, 940' @ OBa Offset producer. For V-201 A injection intervals, closest approach is L3 960' C~OA (V-204L3), 940' C~OBa (V-204L2), 1070'C«306b (V- 204L1), 1050' C OBd (V-204). Top of cement calculated to be in the UG3 interval (3480' MD). Good cement isolation. V-106A 1299' C~3 Top of Pool V-106A is greater than 1/4 mile distant from all V-222i injection zones (Top Na) (OA-OBd). Full returns noted during cementing. Top of cement calculated to be at 3696, in the UG3 interval. V-107 1270' @ Top of Pool Top of cement calculated to be in the UG3 interval (3440' MD). To Na Good cement isolation. V-03 1294' C~ Top of Pool Top of cement calculated to be in the UG3 interval (3591' MD). To Na Good cement isolation. ~~~~ ~ ~ ~~~~ ~ V-222i Permit to Drill ~~~ ~~~,~,~" ~ Page 2 k~`~5 • ~ Casing/Tubing Program: Hole Size Csg/ Tbg O.D. WUFt Grade Connection Length (ft) Top MD/TVD RTE ft Btm MD/TVD RTE ft 42" Insulated 20" 215.5 A-53 WLD 108 GL 108/108 12-Ya" 9-5/8" 40 L-80 BTC 2889 GL 2889/2727 8-3/a" 7" 26 L-80 TC-II 4289 GL 4289/4007 8-3/a" 7" 26 L-80 BTC-M 1003 4289/4007 5292/4913 Tubin 3-'/2" 9.2 L-80 TC-II 5076 GL 5076/4720 Note: To roduction acker within 200' MD of to erforation Directional: Directional Plan: Schlumber er Feasibilit Stud P1 b Ref Elev: 82.1' MD KOP: 300' MD, be in 1.5/100 build Close A roach Wells: All Wells ass Ma~or Risk Scan, reference anti-collision re ort Surve Pro ram: GYD-GC-SS 800' , MWD 2200' , MWD + IFR + MS 5292' Maximum Hole An le: 26.13 de rees Distance to Nearest Pro ert Line: 11,220' from PBU bounda Distance to Nearest Well in Pool: 753' from V-202 at to Na Mud Program: 12-~/a" Surface Hole Mud Pro erties Spud - Freshwater Mud Interval Density PV YP PH Funn Vis FL 0-1855' BPRF 8.8-9.2 30-55 50 - 70 9.0 - 9.5 300-400 NC - 8 1855'-2889' SV1 9.2-9.5 30-55 45 - 60 9.0 - 9.5 250-300 < 8.0 8-3/a" Intermediate Hole Mud Pro erties Freshwater Mud (LSND) Interval Density PV YP PH API Filtrate MBT 2889'-5292' OBf Base 8.8-9.0 8-14 18-24 9.0-9.5 4- 7 < 15 Survev and Loqqinq Proqram: 12-'/a" Hole Section: Surface Gyro until MWD surveys are clean. MWD / LWD: Dir/GR O en Hole: None Cased hole: None 8-3/a" Hole Section: Sample as required by well site Geologist MWD / LWD: GR/RES/PWD reai time and Azi-Dens/Neu recorded O en Hole: None Cased Hole: USIT in primary depth control mode. Log from PBTD to surface. V-222i Permit to Drill Page 3 ~ ~ Cement Calculations: Casin Size Surface Casing - 9 5/e" 40 Ib/ft L-80 BTC - Single Stage Basis Lead: Open hole volume + 250% excess in permafrost and 40% excess below permafrost. TOC at surface Tail: O en hole volume + 40% excess + 80' shoe track. TOC 1004' MD above shoe 1885' MD . Fluid Sequence and A Tam Port collar may be located at 1,000' as a contingency for cement to surface Volume: JVash None ~ acer 70 bbls of MudPush II wei hted to 10.3 Lead 375 bbls 474 sks 10.7 Ib/ al Arctic Set Lite cement - 4.44 Tail 85 bbls (412 sks) 15.8 Ib/qal Class G+ Durastone - 1.15 c I Temp I BHST ~ 50° F from SOR I Casin Size Intermediate Casing - 7" 26 Ib/ft L-80 BTC-M x TC-II - Single Stage Basis Lead: None Tail: O en hole volume + 30% excess + 80' shoe track. TOC at 3789' MD, which is 500' above the Ma. Fluid Sequence and This cement job is planned for one stage. If two stages are required, 12.5 ppg Lite Volume: Crete will be used as the lead and the TOC will be at the same depth as for one stage. 1S Sta e Wash None S acer 70 bbl of MUDPUSH XL S acer wei hted to 10.3-Ib/ al Lead none Tail 55 bbl (268 sksl 15.8 ppa Class G cement + Latex - 1.16 cuft/sk 1 Temp I BHST ~ 95° F from SOR I Surface and Anti-Collision Issues: • Surface Shut-in Wells: The closest existing surface wells are V-102 (15' away), V-201 (30' away), and V- 221 (30' away). • Close Approach Shut-in Wells: All wells have passed the major risk scan. No wells will require subsurface shut-in during drilling operations. Reference the Anti-collision report in the directional plan for a full list of offset well paths. V-222i Permit to Drill Page 4 ~ ~ Well Control Surface hole will be drilled with a diverter. The production hole section will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer. This equipment is capable of handling maximum potential surface pressures. BOP equipment will be tested to 4,000 psi. Anticipated surface pressures will not exceed 3,OOOpsi, therefore it will not be necessary to have two sets of pipe rams installed at all times. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Surface Section • BOPE: • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 9-5/8" Casing Test: • Kick Tolerance: Hydril GK, 21-1/4", 2000 psi 1,234 psi - SV1 (8.7 ppg EMW @ 2727' TVD) 960 psi - Based on a full column of gas C~ 0.10 psi/ft Function Test 3,500 psi surface pressure test NA Variance Request To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is ~ requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line. To mitigate any risk involved with no flow paddle, the following steps will be taken while the flow paddle is removed from the flow line. Ensure PVT alarms are used and the pit levels are accurately monitored for any pit gain. Visually look down the riser during connections to ensure the well is not flowing. Intermediate Section Kick Tolerance and Intearitv Testin • BOPE: Hydril, 13-5/8", 5000 psi • Maximum anticipated BHP: 2,222 psi - OBf Base (8.7 ppg EMW C 4913' TVD) • Maximum surface pressure: 1,732 psi - Based on a full column of gas @ 0.10 psi/ft • Planned BOP test pressure: 4,000 psi/250 psi Rams and 2,500 psi/250 psi Annular • 7" Casing Test: 4,000 psi surface pressure test • Integrity Test - 8-3/4" hole: LOT 20' - 50' from 9 5/" shoe • Kick Tolerance: 25.8 bbl KT with a 9.0 ppg mud and a 10.9 ppg LOT • Planned completion fluid: Estimated 9.0 ppg Brine / 6.8 ppg Diesel Disposal • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. V-222i Permit to Drill Page 5 ~ ~ Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control / Reservoir Pressures: The Schrader Bluff sands are expected to be pressured at 7.3-8.7 ppg EMW. II. Hydrates and Shallow gas: Gas Hydrates are expected at V-pad near the base of the permafrost. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Occasionally hydrates are encountered below the SV1. III. Lost Circulation / Breathing: Lost circulation is considered low at the faults in the production hole section. Seepage losses could occur in the Schrader O-sands. IV. Kick Tolerance / Integrity Testing: Production Section Kick Tolerance and Integrity Testing • Integrity Test - 8-3/4" hole: LOT 20' - 50' from 9 g/8" shoe • Kick Tolerance: 25.8 bbl KT with a 9.0 ppg mud and a 10.9 ppg LOT V. Stuck Pipe There could be slight differential sticking across the open hole while running the 7" casing. Keep the casing moving as much as possible and follow the centralizer program to help with standoff. VI. Hydrogen Sulfide V Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. H2S levels across the pad are typically in the 10 ppm range based on the latest samples taken. Well Name H2S Level Date of Readin #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility V-102 20 m 11/5/2006 V-107 60 m 12/19/2006 V-202 25 m 12/20/2006 V-204 100 m 9/30/2006 V-117 180 m 12/26/2005 VII. Faults There is a low risk of losses incurred when crossin the fault. Formation Where Encounter Fault MD Intersect tvdss Est. Throw Throw Direction Uncertaint Fault #1 - Lower SV2 V Pad fault 2829 -2590 -125' Southwest +/- 100' M.D. CONSULT THE V PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION V-222i Permit to Drill Page 6 ~ ~ V-222i Drill and Complete Procedure Summary Pre-Rig Work: 1. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the 20" conductor. 2. Prepare pad and neighboring wells for the rig move and sim-ops production. Shut in nearby wells, bleed off process lines, and remove well houses as necessary. Rig Operations: 1. MIRU Nabors 9ES. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. 2. MU 12-~/a" drilling assembly with MWD/GR and directionally drill surface hole to TD with one BHA. Conduct a short trip at the BPRF. The actual surface hole TD will be below the hydrates in the SVi . CBU, short trip to previous ST point, RIH to TD, CBS, then POOH and lay down BHA. 3. Run and cement the 9 5/8", 40.0 Ib/ft. surface casing back to surface. A TAM Port Collar may be run at 1000' MD as a contingency. Use Durastone in the last 15 bbls of tail cement. 4. ND diverter spool and NU and test casing/tubing head. NU BOPE and test to 4,000 psi / 2500 psi annular. PU 4" DP as needed. 5. MU 8-3/a" drilling assembly with MWD/GR/Res/Azi-Den/Neu/PWD and RIH to float collar. Confirm 1,000 psi cement compressive strength prior to testing casing. Test the 9 5/8' casing to 3,500 psi for 30 minutes. 6. Drill shoe track and displace over to new 8.8 ppg LSND mud. Drill new formation to 20' below 9 5/8" shoe and perform LOT. 7. Drill ahead to Production hole Target TD (base OBf). 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", 26#, L-80, BTC-M x TC-II production casing. Displace the casing with seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. Freeze protect the 7" x 9 5/8" annulus. 9. PU DPC guns and RIH w/ ~160' of 4.5" Power Jet 4505 5 spf, perf guns with Anadrill LWD GR/CCL for gun correlation. 10. Space out perf guns by tagging PBTD and utilizing GR/CCL and RA tags in 7" casing. Once correlated correctly, circulate over to 9.0 ppg brine. Confirm cement compressive strength is at least 1,000 psi before firing. Perforate OA, OBa, OBb, OBc, and OBd. POOH LD DP and guns. Make Clean-out Run. 11. RU Schlumberger E-line. RIH with gauge ring and junk basket to recover any perf debris. Repeat until clean to at least 50' below the bottom perforation. 12. Run USIT log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. 13. Run the 3-~/2", 9.2#, L-80, TCII completion with a 7" x 3-'/z" straddle packer assembly, I-wire, gauges, and injection mandrels. Torque turn TC-II threaded tubing. Top packer must be within 200' of OA perfs. 14. Run in the lockdown screws and set the packers. Give AOGCC 24 hours notice, then test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCR shear valve and pump both ways to confirm circulation ability. 15. Install and test FMC TWC. Nipple down the BOPE. Nipple up and test the double master to 5,000 psi. 16. Freeze protect the well to 2,500' TVD by first pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ Hot Oil truck, taking clean brine returns to surface. Allow diesel to u-tube into tubing. 17. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-'h" annulus valve and secure the well. Assure that IA/OA are protected with two barriers. 18. Rig down and move off. Post-Rig Work: 1. Install Tree with LEO. 2. R/U Slickline and pull ball and rod / RHC from the tailpipe. 3. Replace the DCR shear valve with a dummy GLV. 4. Pull dummy valves in injection mandrels and replace with injection valves. 5. Pull VR plug. 6. Install wellhouse and flowlines. V-222i Permit to Drill Page 7 TREE = 41 /8" CNV WELLHEAD = FMC ACTUATOR = LEO KB. ELEV = BF. ELEI/ _ KOP = 3~0' Max Angle = 26 deg Datum MD = Datum ND = ~ a ~~v ~ ca. nra rnn ~a. oo i a ~a r~~~ ~ v V~~ ~~! REL E" BUT CAN ALSO BE RELEASm BY PRESSURE DO NOT IXC~ 4300 PSI. TEST PRESSURE PKR pAT11Ul~ = r.d~4 DCI /dA97 DCI IC flfleL AF DIl17 DATIIUl~\~ 29' 4-1/2" XO 3-1 /2", ID = 2.992" / 4-1/2" TBG, 12.6#, L-80, ~ TG11, .0152 bpf, ID = 3.958" 9-5/8" CSG, 40#, L-80, TG 11, ID = 8.835" 2889' 7" CSG, 26#, L-80, TG11, .0383 bpf, ID= 6.276" 4289' MARKERJOINTw/ RA TAG Obb 4811 Minimum ID = 2.66" ~ xxxx' 3-1/2" HES XN NIPPLE REF LOG: ?? ANGLE AT TOP PERF: Note: Refer to Roduction DB for historical perf data SQE SPF INTERVAL OpNSqz DWTE 41 /2" 5 OA O 41 /2" 5 Oba O 41/2" 5 Obb O 41 /2" 5 Obc O 41 i2" ~ 5 rJbd O ~ 2627' 3-1 /2" HES X NIP, ID = 2.813" 8 4608 M1AG DI1AY RK WATER INJECTION M+4NDRELS ST 7 6 5 4 3 2 7 ND ND DEV NPE VLV LATCH PORT DiATE 4708 M1A~W RK 4769 M1AG-W RK 4822 MVIG-W RK 4866 M1AGW RK 4912 AMIGW RK 4947 NNIGW RK 5004 M1AGW RK 4668' 3-1/2" HES X NIP, ID= 2.813" ~ 4688~ 7" HES A HR PKR w/ 1/4" FEED THRU, ID = 2.920' NOTE: DC} AIOT ~CGEED 4300 PS! 4701' PHEONDC PRES(TEMP SENSOR SUB, ID = 2.992" 4788~ 3-1/2" HES X NIP, ID= 2.813" 4799' 7" HES A HR PKR w! 1/4" FEED THRU, ID = 2.920' I 4885~ H3-1/2" HE,~ X NIP, if3 = 2.813" 4891' T' HES AHI~ F~ECR w/ `!;4" F~ED 711RU, ID =~.920' 3-1/2" TBG, 9.2#, L-80, TGII, .0087 bpf, ID= 2.992" ~ XXXX PBTD 6212' 7" CSG, 26#, L-80, BTGM, .0383 bpf, ID = 6.276 6292' 4904' f--~ PHEONDC PRESIfEMP SENSOR SUB, ID = 2.992" I 4961' 7" HES AHR PKR w/ 1/4" FEED THRU, ID = 2.920' I 4984~ -I3-~~2" HES X NIP, ID = 2.813" 5034~ 3-1/2" HES X NIP, ID = 2.813" 5054~ 3-1/2" HES XN NIP, ID = 2.813" 5076' 3-1/2" WLEG, ID = 2.992" DATE ~ REV BY ~ CONMENTS ~ DATE REV 04/O6/07 BJP Proposed WBD BP Exploration (Alaska) bp V-222 (P1 b) P Schlumberger osa~ Survey 1 DLS Compucafion Method: Minimum Curvalure 1 Lubinski Vertical Section Azimuth: 7240° ~~ Vertical Section Origin: N 0.000 ft, E 0.000 ft ND Reference Datum: Rotary Table TVD Reference Elevation: 82.10 ft ~elative to MSL Sea Bed 1 Ground Level Elevation: 53.60 ft relaGve to MSL Magnetic Declination: 23.651° Total Field Strength: 57637.916 nT Magnetic Dip: 80.899° Declination Date: June 04, 2007 Magnetic Declination Model: BGGM 2006 ~ North Reference: True Norfh ToWI Corr Mag North •> True North: +23.651 ° I ncal Cnerdinates ReferenCed T0: W21~ H88d ~ RepoR Date: April 4, 2007 Client: BP Explorabon Alaska Field: StructurelSlot: Prudhoe Bay Unit - WOA ~'~~ V-Pad/PlanV-222(NL+15) Well: ~~~ Plan V-222 (NL+15) ~ Borehole: ~g Plan V-222 uwuaPi#: 5oozs Survey Name 1 Date: V-222 (P1 b)1 April 4, 2007 ToR 1 AHD 1 DDI I ERD ratio: 26201 ° I 1828.83 ft 14.713 I 0.37i Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Location Wtllong: N 70.32803037, W 149.26559009 Location Grid wE YIX: N 5970093200 ftUS, E 590554.900 ftUS Grid Convergence Angle: +0.69155063° Grid Scale Factor. 0.99990932 Comments Measured Inclination Azimuth Depth ft d de Klt KOP Bid 1.5/100 G1 Bld 2.25/100 S V6 Bld 3/100 End Bld SV5 SV4 Base Perm SV3 SV2 SV1 Fault Crossing 9-5/8" Csg Pt Vertical NS EW Gravity DLS Build Rate Walk Rate Northin EasGn Latitude I Longitude Sub-Sea ND ND Tool Face 9 9 Section ~g~ ~ ~g) ~ (g) ~ (R) (ft) (deg) (degH00ft) (degH00ft) (deg1100ft) (ftUS) (ftUS) ononon~-~ ~n~ ~n~ 9aFSi ~.00 300.00 327.10 400.00 500.00 ~.~0 0.00 0.41 1.50 3.75 ~.42 7.42 7.42 7.42 7.42 -$2.~~ 217.90 245.00 317.89 417.78 ~.~~ 300.00 327.10 399.99 499.88 ~.~~ 0.00 0.10 1.31 5.89 V.VU 0.00 0.10 1.30 5.84 U.UV 0.00 0.01 0.17 0.76 --- HS HS HS HS v.vv 0.00 1.50 1.50 225 ....... 0.00 1.50 1.50 2.25 -•-- 0.00 0.00 0.00 0.00 -- -- 5970093.20 5970093.30 5970094.50 5970099.05 590554.90 590554.91 590555.05 590555.59 N 70.32803037 W 149.26559009 N 70.32803063 W 149.26558999 N 70.32803392 W 149.26558872 N 70.32804633 W 149.26558393 600.00 700.00 800.00 900.00 973.83 6.00 8.25 10.50 12.75 14.41 7.42 7.42 7.42 7.42 7.42 517.41 616.63 715.29 813.23 884.99 599.51 698.73 797.39 895.33 967.09 14.39 26.79 43.08 6323 80.56 14.27 26.56 42.72 62.70 79.89 1.86 3.46 5.56 8.17 ?0.40 HS HS HS HS HS 2.25 2.25 2.25 2.25 2.25 2.25 2.25 2.25 2.25 2.25 0.00 0.00 0.00 0.00 0.00 5970107.49 5970119.80 5970135.98 5970155.99 5970173.20 590556.59 590558.04 590559.95 590562.31 590564.34 N 70.32806935 W 149.26557503 N 70.32810295 W 149.26556204 N 70.32814707 W 149.26554498 N 70.32820166 W 149.26552388 N 70.32824862 W 149.26550573 973.84 1000.00 1100.00 1200.00 1291.45 14.41 15.20 18.20 21.20 23.94 7.42 7.42 7.42 7.42 7.42 885.00 910.30 1006.07 1100.21 1184.65 967.10 992.40 1088.17 1182.31 1266.75 80.56 87.25 115.97 149.67 184.77 79.89 86.52 115.00 148.42 183.22 10.40 11.27 14.98 19.33 23.86 HS HS HS HS --- 2.25 3.00 3.00 3.00 3.00 2.25 3.00 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 5970173.20 5970179.84 5970208.37 5970241.83 5970276.68 590564.34 590565.12 590568.49 590572.44 590576.55 N 70.32824862 W 149.26550572 N 70.32826673 W 149.26549 2 N 70.32834455 W 149.265 N 70.32843585 W 149.265 N 70.32853092 W 149.26539658 1691.19 1833.43 1855.31 2276.55 2473,49 23.94 23.94 23.94 23.94 23.94 7.42 7.42 7.42 7.42 7.42 1550.00 1680.00 1700.00 2085.00 2265.00 1632.10 1762.10 1782.10 2167.10 2347.10 346.97 404.69 413.57 584.49 664.41 344.07 401.30 410.11 579.60 658.85 44.82 52.27 53.42 75.50 85.82 --- --- -- --- - 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5970437.75 5970495.06 5970503.88 5970673.62 5970752.97 590595.56 590602.32 590603.36 590623.39 590632.76 N 70.32897034 W 149.26522666 N 70.32912669 W 149.26516620 N 70.32915074 W 149.26515689 N 70.32961379 W 149.26497783 N 70.32983028 W 149.26489410 2823.61 2829.08 2889.26 23.94 23.94 23.94 7.42 7.42 7.42 2585.00 2590.00 2645.00 2667.10 2672.10 2727.10 806.48 808.70 833.12 799.73 801.93 826.14 104.17 104.46 107.61 - --- --- 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5970894.05 5970896.26 5970920.50 590649.40 590649.66 590652.53 N 70.33021515 W 149.26474526 N 70.33022117 W 149.26474293 N 70.33028732 W 149.26471735 WeIlDesign Ver SP 2.1 Bld( doc40x_100 ) Plan V-222 (NL+15)\Plan V-222 (NL+15)\Plan V-222\V-222 (P1b) Generated 4/4/2007 12:00 PM Page 1 of 2 Comments Measured Inclination Azimuth Sub•Sea TVD 7~/p Vertical NS EW Gravi ~ lFace To DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Secfion o ft de de R k ft R ft de de 100 k de 100 ft de 1100 ft ftUS ftUS o~, ~~ „o ~n ___ n nn n 00 0.00 5970955.77 590656.69 N 70.33038354 W 149.26468014 UG4 UG4A 29/6./y 3009.61 'L3.`J4 23.94 i.wc 7.42 c~co.vv 2755.00 ~o~~.~~ 2837.10 ~~~.~~ 881.95 ~~~.~~ 874.57 ~.~.-~ 113.92 --- -~-- 0.00 - 0.00 0.00 5970969.00 590658.25 N 70.33041962 W 149.26466618 UG3 UG1 Ma Mb1 Mb2 3419.91 3977.91 4289.74 4344.45 4410.09 23.94 23.94 23.94 23.94 23.94 7.42 7.42 7.42 7.42 7.42 3130.00 3640.00 3925.00 3975.00 4035.00 3212.10 3722.10 4007.10 4057.10 4117.10 1048.44 1274.86 1401.39 1423.59 1450.23 1039.66 1264.19 1389.66 1411.67 1438.09 135.43 164.68 181.Q2 183.89 187.33 --- --- -- -- --- 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5971134.32 5971359.17 5971484.82 5971506.86 5971533.31 590677.76 590704.29 590719.12 590721.72 590724.84 N 70.33087064 W 149.26449174 N 70.33148403 W 149.26425450 N 70.33182680 W 149.26412191 N 70.33188694 W 149.26409865 N 70.33195910 W 149.26407074 Mc Na /~p Nc Ne 4481.21 4552.33 4579.68 4617.98 4626.73 23.94 23.94 23.94 23.94 23.94 7.42 7.42 7.42 7.42 7.42 4100.00 4165.00 4190.00 4225.00 4233.00 4182.10 4247.10 4272.10 4307.10 4315.10 1479.09 1507.95 1519.05 1534.59 1538.14 1466.71 1495.32 1506.33 1521.74 1525.26 191.06 194.78 196.22 198.22 198.68 --- --- --- --- --- 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5971561.97 5971590.62 5971601.65 5971617.08 5971620.60 590728.22 590731.61 590732.91 590734.73 590735.14 N 70.33203728 W 149.26404050 N 70.33211546 W 149.26401025 N 70.33214552 W 149.26399862 N 70.33218762 W 149.26398234 N 70.33219724 W 149.2639~ Crv 4/100 End Crv V-201A Tgt OA OA 4667.01 4700.00 4723.53 4733.53 4733.54 23.94 25.22 26.13 26.13 26.13 7.42 6.64 6.13 6.13 6.13 4269.82 4299.82 4321.02 4330.00 4330.01 4351.92 4381.92 4403.12 4412.10 4412.11 1554.48 1568.20 1578.40 1582.80 1582.81 1541.47 1555.09 1565.22 1569.60 1569.60 200.79 202.47 203.61 204.08 204.08 14.56L 13.85L --- --- -- ~.~~ 4.00 4.00 0.00 0.00 0.00 3.88 3.89 0.00 0.00 0.00 -2.36 -2.17 0.00 0.00 5971636.83 5971650.47 5971660.62 5971665.00 5971665.00 590737.06 590738.57 590739.58 590740.00 590740.00 N 70.33224152 W 149.26396149 N 70.33227872 W 149.26394788 N 70.33230640 W 149.26393868 N 70.33231837 W 149.26393487 N 70.33231838 W 149.26393486 OBa OBb OBc V-201A Tgt OBd OBd 4811.50 4856.06 4917.32 4973.01 4973.02 26.13 26.13 26.13 26.13 26.13 6.13 6.13 6.13 6.13 6.13 4400.00 4440.00 4495.00 4545.00 4545.09 4482.10 4522.10 4577.10 4627.10 4627.11 1617.14 1636.76 1663.74 1688.27 1688.27 1603.74 1623.26 1650.09 1674.48 1674.48 207.74 209.84 212.72 215.34 215.34 -- --- --- --- --- 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5971699.19 5971718.72 5971745.58 5971770.00 5971770.00 590743.26 590745.12 590747.67 590750.00 590750.00 N 70.33241166 W 149.26390510 N 70.33246496 W 149.26388810 N 70.33253826 W 149.26386471 N 70.33260489 W 149.26384345 N 70.33260491 W 149.26384345 OBe OBf OBf Base TD / 7" Csg 5042.07 5045.42 5089.97 5140.09 5292.07 26.13 26.13 26.13 26.13 26.13 6.13 6.13 6.13 6.13 6.13 4607.00 4610.00 4650.00 4695.00 4831.44 4689.10 4692.10 4732.10 4777.10 4913.54 1718.68 1720.15 1739.77 1761.85 1828.78 1704.72 1706.19 1725.70 1747.65 1814.21 218.59 218.75 220.85 223.21 230.36 --- --- --- --- --- 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5971800.28 5971801.74 5971821.28 5971843.26 5971909.89 590752.88 590753.02 590754.88 590756.98 590763.32 N 70.33268752 W 149.26381709 N 70.33269152 W 149.26381582 N 70.33274483 W 149.26379881 N 70.33280480 W 149.26377967 N 70.33298663 W 149.26372166 ~ WeIlDesign Ver SP 2.1 Bld( doc40x_100 ) Plan V-222 (NL+15)\Pian V-222 (NL+15)\Plan V-222\V-222 (P1b) Generated 4/4/2007 12:00 PM Page 2 of 2 . b ~ ~ P Schlumberger WELL FIELD STqUCTURE V-222 (P1 b) Prudhoe Bay Unit - WOA V-Pad Magne~icParamalers SurlaceLocalbn NAD]]Naska5lalnPlanxS.ZonnM USFnx~ Miuellaneous MoEel~ BGGM2~6 OiV- BOB99° Oa~e Jure00.1001 l'e~~. N)01900909 Nor1M~g' S91009J.]OIIUS G~NCOnv bd9!5508J' Sbl~ PIanV~122~NL~15~ N~Ret. RolaryTabla~B].'OflaboveMSL~ MagOec: ~2J651" FS-. 5)fi]]9nT Lon. W1491556.1]< Eaa~ing'. 590551.901RI5 SraleFac1:0.999909]t53 Plan~. V-223~Pip) SrvyDa~e: Ap~i106.300] O 60~ ~200 ~VO~ 24~~ ~ 600 1200 1800 `o 0 ~ c _ 2400 a~ m U ~ ~ ~ ~ 3000 3600 4200 ....................... :..................................j................... .............i. ._.._.._.._.._ _ _..~..~..~..~..~..~..~ ~ ._.._..~.._.._.. .~3~ .._.._.._.._.._..~.._.._.._.._.._.._.._.._.r ._.._.._.._.._.._.._.._.. Tgt OA _.._.._..~..~..~ aRnn C.._.._.._.._.._.._.._.._.._.._.._.._.._.._._.._.._.._.._.._.._ i r• cs9 2 (P i b) 0 6~~ 1200 1800 2400 3000 3600 4200 48~~ 0 600 1200 1800 2400 Vertical Section (ft) Azim = 7.24°, Scale = 1(in):600(ft) Origin = 0 N/-S, 0 E!-V ~ ~ bp Schlumberger WELL FIELD SiRUCTURE V-222 (P1b) Prudhoe Bay Unit - WOA V-Pad Mag~~icPUamnlera Surlacala~'alm NR02)FLakaSlMeMSro~.InneOd USFeM MiSCeWreous M1lodel BGGMI006 Dip B0899' Oa~a: JuneW.300] Lal N)Ot9G0909 No~tlirtg 59)009J30IIU5 GrMCOnv ~Ofi9'SS(~l' SW ManV~112~NL•15~ TVDReI~. M115L~OOOIIaEOVeMSL~ MagDec~. ~13.851' FS~. 5I6]]9nT Lon~. Wt.19t556~2< Eaalirv~ 59055690!RIS SukFac1.09999p1]~53 PWn- V-111(Ptp~ SrvyDala Pyn16f.300] -500 -250 0 250 500 1750 1500 1250 n n n Z ~ 1000 0 ~ N C N fa U ~ ~ 750 v v v 500 250 0 -500 -250 0 250 500 c« W Scale = 1(in):250(ft) E»> 1750 1500 1250 1000 750 500 250 0 ~ BP Alaska Anticollision Report ~ Company: ' BP AmoCO Date: 4/24(2007 Time: 09:36:17 Page: 1 j Field: Prudhoe Bay ~~eference SiCe: PB V Pad Co-ordinAte(NE) Refeeence: Well: Pl~n U-222 (NL+15), True North i Referenee VVeII: . Rlan V-222 (~1L+15) Vertical ('~Vp) Reference: V~222 Plan 82.1 I Reference WellpatB:_ Pian V-222 _ ~ ` `> _ Db: ,~racle =1 ~ ~ ~ ~_ ~~ _ __ ~ - _ ~ ----- - -_ - -- i GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of -- - __ _ _____ _ ~ .~ ______ ._ _ ~ ~:__ _ -- _ . _ -- - -- - -- --- - reference - There are II@H~6aRells in this~pal Plan & PLANNED PROGRA~~ InterpolaHon Method: MD IntervaL• 5.00 ft Error Model: ISCWSA EllipSe ' Depth Range: 28.50 to 5292.07 ft Scan Method: Trav Cylinder North Maximum Radius:10000.00 ft Error Surface: Ellipse + CaSing _ ____ ___ -- _ . _ __ ____ -- --- ----- I Survey Program for Definitive Wellpath I Date: 3/15/2007 Validated: No ~ Planned From To Survey , ft ft Version: Toolcode 2 Tool Name I i, ~--- 28.50 800,00 Planned: Pla n #1 V2 _ - --- GYD-GC-SS Gyrodata gyro single shots ~~ i j 800.00 2200.00 Planned: Pla n #1 V2 MWD MWD - Standard ', 800.00 2950.00 I Planned: Pla n #1 V2 MWD+IFR +MS MWD + IFR + Mu lti Station I 2950.00 5292.07 Planned: Pla n #1 V2 MWD+IFR+MS MWD + IFR + Mu lti Station f Casing Points _ . _ _ _ -r _-. _ _ ~ _ _ _. _ ~~ MD -~ 1"VA~ Diameter ~~ , Hole Si~e ~ Name~~ , l ft R ; _ .-~ ~ _ -' in _, _ in ' ~. _ _ `~ .. -- -~_~ _ _ ~ :: _ _- ~ .. _ - _..: i _~ _ . ~~--~ ; ~-- _~ ,, __ . - _ 3017.27 2844.10 9.625 _ 12.250 9 5/8" ' S291.80 4913.30 ~ __ - 7.000 -- -_ ____ _ 8.750 7" .. _. __ -- - -- --- - -- - _-- - -___- ---- _- -- Summary m ~' '~ <------ `------------- Offset Wellpath - ---- ~ ~ Reference Z)ffset ' Ctr-Ctr No-Go Al~owahle" ~ Site ` W~l[ ~~~ Wellpath ~ MD NID ~ Distance Area ~ Deviation Warning ~ ~~ ~ - ~ - ` - ft ft - ft .: ft ~ ft; ~ _ , --- PB V Pad ~ - - Plan V-219 (N-P) _ - _.. Plan V-219 V3 Plan: PI 815.94 815.00 _ ~ 80~.37 15.39 64.98 Pass: Major Risk ~e V ~ad ~lan V-220 (NM-15) ~lan V-220 V5 ~lan: ~I 5a9.62 590.00 23.65 11.21 12.44 Pass: Major Risk PB V Pad V-01 V-01 V15 264.60 265.00 189.09 4.80 184.28 Pass: Major Risk ! PB V Pad V-02 V-02 V12 270.49 270.00 61.28 4.94 56.33 Pass: Major Risk ', PB V Pad V-03 V-03 V7 942.61 855.00 186.62 14.94 171.68 Pass: Major Risk PB V Pad V-04 V-04 V7 1002.11 1005.00 33.26 18.01 15.25 Pass: Major Risk I PB V Pad V-100 V-100 V7 361.79 365.00 252.48 6.21 246.27 Pass: Major Risk ~I PB V Pad V-101 V-101 V7 418.17 420.00 132J1 7.12 125.59 Pass: Major Risk ' PB V Pad V-102 V-102 V5 379.79 380.00 14.30 7.67 6.62 Pass: Major Risk ', PB V Pad V-103 V-103 V6 844.90 835.00 123.47 14.70 108.77 Pass: Major Risk I PB V Pad V-104 V-104 V13 374.27 375.00 75.82 6.40 69.43 Pass: Major Risk ~I PB V Pad V-105 V-105 V13 540.16 540.00 5570 9.29 46.41 Pass: Major Risk I PB V Pad V-106 V-106 V10 1125.96 1125.00 79.52 18.96 60.55 Pass: Major Risk ! PB V Pad V-106 V-106A V9 1821.51 1805.00 79.84 40.04 39.81 Pass: Major Risk ' PB V Pad V-106 V-106AP61 V6 1821.51 1805.00 79.84 40.04 39.81 Pass: Major Risk ' PB V Pad V-106 V-106APB2 V2 1821.51 1805.00 79.84 40.04 39.81 Pass: Major Risk j PB V Pad V-106 V-106APB3 V2 1821.51 1805.00 79.84 40.04 39.81 Pass: Major Risk PB V Pad I V-107 V-107 V5 424.05 425.00 45.28 6.65 38.63 Pass: Major Risk , PB V Pad V-108 V-108 V7 254J8 255.00 167.40 4.50 162.90 Pass: Major Risk ! PB V Pad V-109 V-109 V2 371.80 375.00 21770 6.59 211.10 Pass: Major Risk ' PB V Pad V-109 V-109PB1 V5 371.80 375.00 217J0 6.59 211.10 Pass: Major Risk , PB V Pad V-109 V-109P62 V2 371.80 375.00 217.70 6.59 211.10 Pass: Major Risk PB V Pad V-111 V-111 V25 805.53 800.00 164.42 14.90 149.53 Pass: Major Risk ' PB V Pad V-111 V-111 P61 VS 805.53 800.00 164.42 14.90 149.53 Pass: Major Risk PB V Pad V-111 V-111 PB2 V2 805.53 800.00 164.42 14.90 149.53 Pass: Major Risk ', PB V Pad V-111 V-111 P63 V6 805.53 800.00 164.42 14.90 149.53 Pass: Major Risk ' PB V Pad V-113 V-113 V6 337.89 340.00 234.90 5.37 229.53 Pass: Major Risk PB V Pad V-114 V-114 V5 300.28 300.00 203.41 5.18 198.22 Pass: Major Risk I PB V Pad V-114 V-114A V4 300.28 300.00 203.41 5.18 198.22 Pass: Major Risk ' PB V Pad V-114 V-114AP61 V4 300.28 300.00 203.41 5.18 198.22 Pass: Major Risk PB V Pad V-114 V-114APB2 V2 300.28 300.00 203.41 5.18 198.22 Pass: Major Risk , PB V Pad V-117 V-117 V9 327.47 330.00 231.75 5.83 225.92 Pass: Major Risk ~~ PB V Pad V-117 V-117PB1 V6 327.47 330.00 231.75 5.83 225.92 Pass: Major Risk I PB V Pad V-117 V-117P62 V6 327.47 330.00 231.75 5.83 225.92 Pass: Major Risk j PB V Pad V-119 V-119 V13 418.49 425.00 209.44 7.50 201.94 Pass: Major Risk I PB V Pad V-120 V-120 V5 294.98 295.00 205.00 5.37 199.63 Pass: Major Risk ~~ PB V Pad V-121 V-121 V5 419.12 425.00 213.58 8.89 204.69 Pass: Major Risk ! PB V Pad V-122 V-122 V10 627.07 640.00 242.86 11.26 231.60 Pass: Major Risk i PB V Pad V-122 V-122PB1 V10 627.07 640.00 242.86 11.26 231.60 Pass: Major Risk ~ PB V Pad V-122 V-122PB2 V5 627.07 640.00 242.86 11.26 231.60 Pass: Major Risk I PB V Pad '___ _- ---- V-201 _-- - Plan V-201A V1 Plan: P ___ _ _- 364.80 _ _ -- 365.00 - ---- 31.30 --- - 6.15 -- 25.16 --- - Pass: Major Risk - ~~ BP Alaska Anticollision Report ~ Company: $P Arnoco Date: 4/24(2007 Time: 49:36:17 ` Page: ` 2 Field: , Prutlhoe Bay ` ' Reference Site: PB V Pad Cu-urdinate(NE) Reference: ,; Well: Pl~n V-222.(NL+15}; True Narth ` Reference Wellt Plan V 222 (NL+15) Ve-~ica1(TVD) Reference: V-222 ~lan 82.1 , Reference Wellpath: Plan V-222 --f` ~,_ Db: Oracle Summary <---- - -- Offset Wellpath -- ------~ Reference ` Offset Ctr-Ctt r Site Well WeUpath MB 1VtD Distance ft ft, ft PB V Pad V-201 ~ V-201 V10 364.80 365.00~ 31.30 PB V Pad V-202 V-202 V9 423.22 425.00 105.73 PB V Pad V-202 V-202L1 V5 423.22 425.00 105.73 PB V Pad V-202 V-202L2 V5 423.22 425.00 105.73 PB V Pad V-203 V-203 V18 461.49 465.00 176.33 PB V Pad V-203 V-203L1 V6 461.49 465.00 176.33 PB V Pad V-203 V-203L2 V4 5175.41 6965.00 3886.73 PB V Pad V-203 V-203L3 V3 5134.87 6915.00 3874.98 PB V Pad V-203 V-203L4 V3 461.49 465.00 176.33 PB V Pad V-204 V-204 V2 652.03 675.00 170.83 PB V Pad V-204 V-204L1 V2 652.03 675.00 170.83 PB V Pad V-204 V-204L1 P61 V6 652.03 675.00 170.83 PB V Pad V-204 V-204L2 V2 652.03 675.00 170.83 PB V Pad V-204 V-204L2P61 V5 652.03 675.00 170.83 PB V Pad V-204 V-204L3 V3 652.03 675.00 170.83 PB V Pad V-204 V-204PB1 V9 652.03 675.00 170.83 PB V Pad V-204 V-204PB2 V2 652.03 675.00 170.83 PB V Pad V-205 V-205 V14 386.14 390.00 199.22 PB V Pad V-205 V-205L1 V9 4298.49 8770.00 3130.99 PB V Pad V-205 V-205L2 V8 4099.52 8340.00 3079.36 PB V Pad V-210 V-210 V9 444.40 445.00 89.74 PB V Pad V-211 V-211 V5 311.00 310.00 150.66 PB V Pad V-212 V-212 V7 555.58 550.00 114.56 PB V Pad V-213 V-213 V5 971.44 990.00 227.50 PB V Pad V-213 V-213PB1 V5 971.44 990.00 227.50 PB V Pad V-214 V-214 V3 813.58 820.00 113.97 PB V Pad V-214 V-214PB1 V2 980.46 990.00 124.68 PB V Pad V-214 V-214PB2 V3 811.49 815.00 114.08 PB V Pad V-214 V-214PB3 V5 811.49 815.00 114.08 ! PB V Pad V-214 V-214P64 V2 811.49 815.00 114.08 I PB V Pad V-215 V-215 V6 357.81 360.00 190.50 , I PB V Pad V-216 V-216 V8 437.76 435.00 150.34 '~ PB V Pad V-217 V-217 V5 357.21 360.00 204.36 i PB V Pad V-218 V-218 V6 417.19 415.00 176.85 I PB V Pad V-221 V-221 V6 657.95_ 655.00 47.96 ~. .rE. ft ft 6.14 25.16 7.73 98.00 7.68 98.05 7.68 98.05 9.32 167.01 9.32 167.01 9.32 11.70 11.70 11.70 11.70 11.70 11.70 11.70 11.70 6.91 167.01 159.13 159.13 159.13 159.13 159.13 159.13 159.13 159.13 192.31 7.96 5.44 9.55 16.99 16.99 14.60 21.15 14.73 14.73 14.73 7.59 8.05 7.35 7.11 13.93 81.78 145.22 105.01 210.51 210.51 99.37 103.53 99.35 99.35 99.35 182.91 142.29 197.02 169.74 34.03 Warning Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk No Offset Errors No Offset Errors Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk No Offset Errors No Offset Errors Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk ~ ~ FieldPrudhoe Bay Site PB V Pad Well:Plan V-222 (NL+15) WellpathElan V-222 -3 1 3 300 200 100 0 2 100 200 300 313 0 Travelling Cylinder Azimuth (TFO+AZI) [degJ vs Centre t ~ Site: PB V Pad Drilling Target Conf.; 99% Description: Map Northing: 5971665.00 ft Map Easting : 590740.00 ft Latitude: 70° 19'S6.346N Shape: Circle Target: V-222 Tgt OA ~.~ _ __ _ _ _ __ __ _ ~ Well: Plan V-222 (NL+15),V-201 Based on: Planned Program Vertical Depth: 4330.00 ft below Mean Sea Level Local +N/-S: 1569.59 ft Local +E/-W: 204.08 ft Longitude: 149° 15'S0.166W _ - --- -- --- Radius: 50 ft ; _ ~ I650 I ~i ' -- __ _ _ __ _ _ --__ __-_ -- -. ___-' I ~+50 , / % o 0 0 0 0 0 0 0 ~n o ~n o ~n o~ i ~ - cv c~i m m 0 ~ ~ ~ ~pt ~t ) ~ Site: PB V Pad Drilling Target Conf.: 99% Descriprion: Map Northing: 5971665.00 R Map Easting : 590740.00 ft Latitude: 70° 19'S6.346N Shape: Circle Target: V-222 Tgt OA r~ LJ Well: Plan V-222 (NL+15),V-201 Based on: Planned Program Vertical Depth: 4330.00 ft below Mean Sea Level Local +N/-S: 1569.59 ft Local +E/-W: 204.08 ft Lon~itude: 149° 15'S0.166W Radius: 50 ft ~~0 1650 600 1550 1500 4-50 0 0 0 0 0 0 0 9 ~n o ~n o ~n O~ p j - 0 ~ ~ ~ ~~t ~t 1 c~v c~ m m ~ Tar et: V-222 T t OBd g g Site: PB V Pad Drilling Target Conf.: 95% Description: Map Northing: 5971770.00 ft Map Easting : 590750.00 ft Latitude: 70° 19'S7.378N Shape: Circle ; ; ~ i ~ i I i, , ; ~ ,, -_ ;. ~ , ; , ~ _ __ _ _____ - - ~ _ - __ _ __ ; j ~ -_ -- _. 0 0 0 0 o ~' o ~ 0 a 0 0 d 1 0 0 ~ 1 ~pl ~} ) cv c v ~ Well: Plan V-222 (NL+15),V-201 Based on: Planned Program Vertical Depth: 4545.00 ft below Mean Sea Level Local +N/-S: 1674.47 ft Local +E/-W: 215.34 ft Lon ig tude: 149° 15'49.836W - - __ _ _ __ Radius: 50 ft -! I800 ~, I ~15 0 _ ~~ -- __ _ 0 0 m 0 ~ m ~00 1650 600 RE: V-222--additional Tom You are correct, all of the 1/4 mile proximity wells, except V-106A, had been previously submitted with the V-201A permit application. Brandon Peltier BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling (907) 564-5912 (Direct) (907) 748-7838 (Mobile) 13:~ant~~n. :-~el.tiex~.,~%u~. com Original Message----- From: Thomas Maunder [mailt~~:,,c~:r: ~:~a;zr:_der~~admin.st;ate,a::.us Sent: Thursday, May 10, 2007 11:12 AM To: Peltier, Brandon Cc: Tirpack, Robert B; Art Saltmarsh Subject: Re: V-222--additional Brandon, In checking the 1/4 mile proximity information, it became apparent that this information was submitted previously. It appears that the V-222 penetration is replacing or being substituted for the proposed ~A V•-~,~ penetration. Is that correct? I remember that problems were encountered in the preparation/decompletion phase of ~ and I believe that operation was halted. In the future, it will be appreciated if you would provide some sort of comment or statement describing changes such as this. Since BP doesn't include a transmittal letter, we are left reading between the lines on some applications. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 5/10/2007 10:57 AM: Brandon, I am reviewing the permit application and have a question. l. On page 4, the possibility of a 2 stage job on the 7" is mentioned. The cement volume given looks to only be for the tail slurry of a 2 stage job. Would you have a look at this and reconcile? Thanks, Tom Maunder, PE AOGCC 1 of 1 5/10/2007 2:06 PM ~ • ~: v-aaa Tom On these Orion Injectors we like to use only the 15.8 G tail slurry for the entire cement job, but this depends upon the cement modeling results. Typically, the modeling shows that we can do these cement jobs in one stage with just the 15.8 slurry, and that is how I presented it in the permit application. However, I usually add verbiage towards a two stage in case the modeling results are different than expected. The modeling is being done now and should be finished by next week. Given the relatively short production section, I fully expect to complete the cement job with one stage and one slurry, the 15.8 G. Brandon Peltier BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling (907) 564-5912 (Direct) (907} 748-7838 (Mobile) Bran~:ox~ . ~elti.er:=~:;:; . cotn -----Original Message----- From: Thomas Maunder [~nailto:~o:r maurder:~~d-~:in.~tate.ak.us] _....._..__...._...__ ....................._...__..._......._......._..._.__.__...._ ._......_......_........._...__.............._....................._........_._... Sent: Thursday, May 10, 2007 10:57 AM To: Peltier, Brandon Cc: Tirpack, Robert B Subject: V-222 Brandon, I am reviewing the permit application and have a question. 1. On page 4, the possibility of a 2 stage job on the 7" is mentioned. The cement volume given looks to only be for the tail slurry of a 2 stage job. would you have a look at this and reconcile? Thanks, Tom Maunder, PE AOGCC 1 of 1 5/10/2007 2:07 PM ~ ~ 6050000 n u 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000 ~ , Alaska Department of Natura~sources Land Administration System Page 1 of 4 ~ ° ~ ~~ ~~~~ ~~, , ~~ ,,., .. ...~~ ~ : ~`~~~~ ~,~~~~~~~~ ~~~rch Sta#e Cabins N~t!!!~~ ' ~DU 5 ~ .~~., , ~ ;,, , : ~ ~ ~f ,, ~c ~ ~a ry File Type: ADL = File Number: ?$?40 „; ~ Prin.table C.ase File_Summary See Township, Range, Section and Acreage? ~~;^ ,~ ~, ~~ ~ Yes ~ No ~~~ ,~~+ ~~,, http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28240&... 5/8/2007 • , Alaska Department of Natura~sources Land Administration System Page 2 of 4 I~ . http://www.dnr. state. ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=28240&... 5/8/2007 ~ ~ ^ Alaska Department of Natura~sources Land Administration System Page 3 of 4 ~ http://www. dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28240&... 5/8/2007 . Terri L. Hubble BP Exploration AK inc. PO Box 196612 MB 7-5 Anchorage, AK 99519 PAY TO THE ORDER OF "Mastercard Check" Fi t Nationai Bank Alaska Anchorage, AK 99501 11•,~~~. MEMO ~ 89-B11252 334 DATEC~I • Zy-~7 -$ ~~ E~ ~ ` ~;L25200060~:99L46227L556~~' 0334 ~ • T'RA~SIO~IT"I'AI, LE'I"~'E1Z CH[~CKLIS'I' `v~~,~, ~~N~E .~,~~ 1~"~~ ~~D# v2o~oS9o Devetopment / Service Exploratory Stratigraphsc 1'est Non-Conventionat Welt C'ircie 4ppropriate Letter / Paragraphs to be Included in Transmittal Letter ~ i CE{ECK I ADD-ONS ~ ! T'EXT FOR APPROVAL LETTER ; VVHAT ~ (OPTIONS) i ~ APPL[ES ~ i ! ~ I MliLTI LATERAL ~ The permit is for a new wellbore segment of exi;tino ; i ~ we(t ' ~(IF last two digits in ~ permit No. API No. ~0- - - ~ ' ~ i API number are ; i ', between 60-69) Production shou(d continue to 6e reported as a function of the i i ; original AP[ number stated above. ~ ~ ~ ~ P[LOT E{OLE ~ ~[n accordance with 20 A.4C 2~.00~(~, ali records, data and logs ; ; ; acquired for the pilot ho(e must be clearly differentiated in both ~ i ; well name ( PI~ and API reumber ~ i '(~0- - -_) from records, da.ta and logs ~ ~ ~ acquired for well ~ ~ ~ SPACING The permit is approved subject to fu1l compliance with 20 AAC ~ ' EXCEPTION ~ 2~.0>j. Approval to perforate and ~roduce ! inject is contingent ~ i I upo~ issuance of a conservation order approving a spacing j i l exception. assumes the ~ ~ 1 i liability of any protest to the spacing exception that may occur. I ~ i DRY D[TCH ; ~ A1[ dcy ditch sample sets submitted to the Commission must 6e in ; i SAMPLE i no greater than 30' samp(e intervals &om betow the permafrost or i ! I from where samples are first caught and 10' samp(e intervals j ; ~ through target zones. ; ~ ; Please note the following special condition of this permi*: ~ ; Non-Conventionai ~ production or production testing of coal bed methane is not allowed i j Well ~ for (name of we(1) until after (Companv Name) has designed and ! ~ ' implemented a water we(! testing program to provide base(ine data I j ,' on water quality and quantity. fCom~anv Name) must contact the i ~ Commission to obtain advance approval of such water well testing ! ~ program. ~ Rev: 12~r06 C ^ jody~transmittal_checklis[ ~ ~ ^^ ~ N ~ , , , , , , , , , ~ o a~ o- , , , , , N y , a~ 0 , ~ ~ , ~ ~ ~ ~ , ~ 'i . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~o ~ ~ , , ~ ~ ~ ~ , ~ ~ , , ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~ _ ~ ~ Q ~ ~ , ~ ~ . ~ ~ , . , ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , , ~ , , ~ , ~ , ~ ~ ~ , . ~ ~ ~ , , , , ~ ~ ~ ~ ~ ~ ~ , ~ ~ , ~ ~ , ~ ~ ~ N~ ~ _, ~ , ~ ~ , ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ , , , ~ ~ ~ ~ ~ ~ ~ , ~ , ~ , ~ ~ ~ , ~ ~ ~ ~ ~ ~ ~~ ~ ~°~~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~~ ~, 3, ~ , ~ , ~ , , , , ~ , , , , , , , , 3 ~ y N ~, .m , O , ~ , , , , , , y, ~',, N, E ` ~ ~ m , , ~ , , , , , ~ , , a ~ fl` ~ ~ m ~ >, Q. ~ t , ~ , , ~ ~~ ~ ~~ , , ~ , ~~ . ~~ ~~ , v ~ ~~ ~ ~ c, ~vi~ ~ -a~ ~~ o~ ~ , ~~ W(~ ~ , ~ ~ , ~ ~ , ~ , ~ , , ~ , ~ ~ ~ a~ ~ ~~ N~ ~ oi a ~ c~i' °' ~' r~ ~ , ~ O , , ~ ~ ~ , , , , , , >' °' °: oS ~ O . ai v' , C E O ~ ~ ~ . ~ , ~ ~ , ~ ~ , ~ ~ , ~ , ~ , : ~ . , ~ ~ ~ , 4 ~ ~ O ~ °' C ~ N, ~ ~ ~ ~ ~~ ~ °' m ` , ~ ~ ~ ~ , ~ , , ~ , ~ ~ , ~ T C9 ~~~ ~ ~ ~ ~~ , d, ~ ~ ~ p~ o , ~ , ~ $ , ~ ~ ° ~n ~ a, c~ I o a , , , ~ ~ , ~ ~ , ~ , , ~ ~ ~ y, ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ , ~ ~, ~ ~ , ~ ~ ~ ~ ~ ~ . , ~ , ~ ~ , 3~ ~6 ~ ~ ~ ° ~ ~ ~ ~ ~ V~ ~ ~ ~~ ~ ~ ~ ~ a ~ ~ ~ , ~ N~ >, ~, ~ ~ ~ , , ~ LL, , ~ ~ , , , , ~ , ~ , , ~ ~ ~ ~ ~ : ~ ~ ~ ~, ~ ~~~ , c~ , , p, ~ y ~, ~, o, ~ , . , , , , _ , ~ , , ~ , ~ ~ ~ ~ , ~ ~ , , ~ , ~ C ~ ~, a ~ ~ ~ Q , , ~~ , N, ~~ , , N ~ m o ~' ~ ~~ I ~ ~' , , ~ ~ ~ , ~ W; ~ ~ ~ ~ . ~ ~ ~ ~ ~ , ~ , ~ ~ M~ ~ ~ , ~ ~ r •Q ~ c~ ~ W'~ , ~, , ~ ~ . ~ _~ ~ ~ ~ ~' , ~ ~ , , , , ~ ~ ~ a Q a z ~ ~ ~ , , ~ ~ , ~ ~ ~ , ~, ~ ~ ~ ~~ , ~~ , m~ ~ , ~ ~,~ , ~, -~, ~ ,n, p~ ~ ; ; O , , _, , , , , a, ~ , ~ ~ ' ~ , y , ~ . 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