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209-118
Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 V-225 209118 500292341900 6 12/31/2023 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 22, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-225 PRUDHOE BAY UN ORIN V-225 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2022 V-225 50-029-23419-00-00 209-118-0 W SPT 4346 2091180 1500 1593 1595 1594 1595 194 385 381 376 4YRTST P Brian Bixby 7/3/2022 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-225 Inspection Date: Tubing OA Packer Depth 332 2505 2396 2381IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220704092137 BBL Pumped:1.2 BBL Returned:1.2 Friday, July 22, 2022 Page 1 of 1 • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 0 q - _ 1 Well History File Identifier Organizing (done) ❑ Two -sided III N 11111 11 III ❑ Rescan Needed 111 I!1I1I11II 111111 RE AN DIGITAL DATA OVERSIZED (Scannable) /G Color Items: �p ❑ . kettes, No. '(� n 1 ❑ Maps: reyscale Items: 1 ` Other, No/Type:G V o' A ❑ Other Items Scannable by ❑ Poor Quality Originals: a Large Scanner OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: a (5 1 / /s/ rrp Project Proofing Ill llllllHIlII im e BY: Maria Date: ails 11 /s/ Scanning Preparation 1 x 30 = 3 © + +� O = TOTAL PAGES `J V �� (Count does not include cover sheet) BY: Date: /s/ Production Scanning 111111111111111111 Stage 1 Page Count from Scanned File: 5 (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: % Date: a 15 1 1 /s/ vyfii Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ ill Scanning is complete at this point unless rescanning is required. 111 111111111 ReScanned 111 1111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked IIl1IIlIIIIII(IlIlI 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 2/9/2011 Permit to Drill 2091180 Well Name /No. PRUDHOE BAY UN ORIN V -225i Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 23419 -00 -00 MD 5150 TVD 4879 Completion Date 7/4/2010 Completion Status WAGIN Current Status WAGIN IC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey s DATA INFORMATION • Types Electric or Other Logs Run: MWD GR, GR, RES, NEU, AZI DENS PWD, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Typ Med /Frmt Number Name Scale Media No Start Stop CH Received Comments UZog Cement Evaluation 5 Col 20 5020 Case 7/28/2010 REPLACED USIT, GR, CCL D - C Pds 19922 moment Evaluation 20 5020 Case 7/28/2010 REPLACED by T20040 USIT, GR, CCL og Cement Evaluation 5 Col 20 5025 Case 8/30/2010 REVISED USIT, GR, CCL D C Pds 20040 dement Evaluation 20 5025 Case 8/30/2010 REVISED USIT, GR, CCL D C Lis 20188 eduction /Resistivity 63 5149 Open 10/7/2010 LIS Veri, GR, ROP, FET, RPM, RAM, NPHI -tog Induction /Resistivity 25 Blu 119 5150 Open 10/7/2010 MD Vision Service c) Induction /Resistivity 25 Blu 119 4797 Open 10/7/2010 TVD Vision Service ED C Directional Survey 0 5150 Open • 'apt Directional Survey 0 5150 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/9/2011 Permit to Drill 2091180 Well Name /No. PRUDHOE BAY UN ORIN V -2251 Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 23419 -00 -00 MD 5150 TVD 4879 Completion Date 7/4/2010 Completion Status WAGIN Current Status WAGIN UIC Y ADDITIONAL INFORMATION Well Cored? Y Daily History Received? ( / N Chips Received? -N__. Formation Tops o N Analysis �Y-/ 1Q 4 Received? Comments: Compliance Reviewed By: 9 f �l/J "^L'� Date: • • Saltmarsh, Arthur C (DOA) From: Barker, Elizabeth R (SAIC) [Elizabeth.Barker ©bp.com] Sent: Tuesday, February 01, 2011 4:41 PM To: Saltmarsh, Arthur C (DOA) Cc: Stewman, Sondra D; Hubble, Terrie L; Barker, Elizabeth R (SAIC) Subject: Well is on Production: V -225 / PTD # 209 -118 Hello Art, Well Name: PBU V -225 Permit #: 209 -118 API #: 50- 029 - 23419 -00 -00 This well began Production on August 16, 2010 Method of Operation is: Water Injector Date of Test: August 18, 2010 Hours Tested: Unavailable 24 -Hour Rate / Oil - Bbl: Unavailable 24 -Hour Rate / Gas - Mcf: Unavailable 24 -Hour Rate / Water - Bbl: Unavailable Test Rate / Oil - Bbl: Unavailable Test Rate / Gas - Mcf: Unavailable Test Rate / Water - Bbl: Unavailable Choke Size: Unavailable Gas -Oil Ratio: Unavailable Flow Tubing Pressure: 1200 Casing Pressure: 560 Inj Vol (Bbls): 449 PW Oil Gravity - API: Unavailable Thank you, Liz Barker SAIC, Projects Analyst BP, ADW Support 564 -5674 1 10/06/10 SChIumherger NO. 5623 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 8 Log Description Date BL Color CD MPF -95 BD88 -00039 MEM INJECTION PROFILE (,J - i9 If r -41 09/03/10 1 �O 1 05 -330 BAUJ -00042 MEM PROD PROFILE Q t ( 08/28/10 1 p / 1 01 -26A B9RH -00034 PRODUCTION PROFILE 1 --CS (� ■ 09/07/10 1 VCr 1 G) 1 H -07A AWJI-00111 MEM PROD PROFILE — f 09/17/10 1 ( 1 5 -110 B9RH -00035 LDL L) / T L+ 09/08/10 1 (1 / 1 18 -12B B3S0 -00090 RST GRAVEL PACK „:400 - fl 09/05/10 1 )( 1 2- 58 /5-09 6350 -00091 LDL 9 09/06/10 1 1 L -20312 10AKA0154 OH MWD/LWD EDIT 0 -- Q 05/19/10 1 ) 1 III L- 20312 -01 10AKA0154 OH MWD/LWD EDIT d ( 05/25/10 1 ��� 1 V -225 09AKA0153 OH MWD/LWD EDIT { 09 .-`j �- 06/28/10 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services • Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 s d t i . t}s .' I f I -p l 'l • 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday, September 07, 2010 Jim R per Re (I 31 P.I. Supervisor l 1 C' SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V -225i FROM: Jeff Jones PRUDHOE BAY UN ORIN V -225i Petroleum Inspector Src: Inspector Reviewed By: Pl. SuprvJ' NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN ORIN V - 225i API Well Number: 50 029 - 23419 - 00 - 00 Inspector Name: Jeff -ones Insp Num: mitJJ100906191055 Permit Number: 209 - 118 - Inspection Date: 9/6/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well V -2251 ' Type Inj. W' TVD 4346 • IA 470 2510 - 2450 2430 1 P T D 2091180 TypeTest SPT Test psi 1500 ' OA 230 410 . 380 370 P/F Interval I NITAL - P -.• Tubing 1600 1600 1600 1600 Notes: 1 well inspected, no exceptions noted. Tuesday, September 07, 2010 Page 1 of 1 08/18/10 '. Schhnnherger NO.5584 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambol! Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 9 Log Description Date 8L Color CD E -28A AZ2F -00055 MEM PROD PROFILE '- " — • 07/25/10 1 _,_ 1 F -03A AYKP -00096 SCMT REVISED '7e11a 07/22/10 _ g 1 V -225 BBKA -00039 USIT (REVISED) sm 1 ' 07/01/10 1 74 / 1 1 1/ / / H -04A BAUJ -00037 MEM PROD PROFIL E 07/20/10 1 . V -214 BBSK -00023 INJECTION PROFILE�K,�j 07/28/10 1 = DOc1Q 1 1 L•210 BGZ7 -00002 INJECTION PROFILE - [�, --(Q 08/05/10 1 ��• 1 L3 -15 11999037 OH LDWG MULTI EXPRESS IFLEX EDIT 08/18/08 1 �.I• • " 1 • N -09 BBUO -00024 �j,Z,Tj. L 07/06/10 1 _I�Zel-fIi 1 M -11 BCRC -00030 RST ) 07/02/10 1 [[„) 1 NGI -03 AYKP•00097 RST Q(p 07/24/10 1 _ , 1 18 -02B B86M -00025 RST � tr-- -- • 07/17/10 1 • - 1 L -203 B3S0.00065 CH EDIT PDC -GR USI _ ygrrj 05/02/10 ••7ATX • 1 P -28 BB6M -00018 CH EDIT PDC -GR (SCMT) _ [7� 06/14/10 • ' 1 P -28 AY1M -00047 CH EDIT PDC-GR USIT _ .� A /� 06/08/10 _.e,,L 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambol) Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 1.tJGA .; 0 2 o 1(.a Alaska OP P.,Gpim Cm %en .2ag- //g . , TD N 9 rt #t f �l r tert �a A LAS KA B P Page , of 2 r �+'�'Ql'1EE't1t111g RBpO4 Common Well Name: V -225 / OH Report No.: 1 Report Date: 6/29/2010 . Project: Prudhoe Bay Site: PB V Pad : Spud Date/Time: 6/23/2010 Event Type: COM- ONSHORE (CON) Start Date: 6/28/2010 ; End Date: 7/4 /2010 : AFE No.: Contractor: NABORS ALASKA DRILLING INC. Rig Name /No.: NABORS 9ES Rig Release: UWI: Active Datum: V -225 Actual t80.70ft (above Mean Sea Level) Generallnforntataan Job Type: Primary Cement Job Start 6/29/2010 3:43PM Job End Date/Time; 6/29/2010 5:01 PM Date/Time: Cement Company: SCHLUMBERGER Cementer: GARY GIERSDORF Cemented String: PRODUCTION CASING String Size: 7.000 (in) String Set TMD: 5,138.44 (ft) Hole Size: 8.750 (in) P ... e M e nnent Pi pe M RECIPROCATING v ft -Ibf ) 'n Torque i rUa max RPM: Rotating o ue n R R to 'n Time (Start-End): Rotate Tim 9 9 q ( � } Reciprocating Time (Start-End): 1:00:00 pm - 5:01:00 pm Recip Drag Up /Down: - (kip) SPM: 1.00 (spm) Stroke Length: 15.00 (ft) Fiutd Name BRINE ; FturdS ('1 of 1)' Slurry Type: CEMENT Purpose: PRODUCTION SLURRY Class: G -CLASS Description: TAIL SLURRY Density: 15.80 (ppg) Yield: 1.1700 (ft3 /sk94) Mix Water Ratio: 5.258 (gal /sk94) Excess' 0.00 ( %) Mix Method: BATCH Sacks Used: 264.00 (941b sacks) Water Volume: 33.1 (bbl) Excess Slurry Volume: 0.0 (bbl) Density Measured by: PRESS. BAL Other Volume: Total Vol in Well: 46.0 (bbl) Slurry Volume: 55.0 (bbl) Excess Measured From: Mud Type: SEA WATER Density: 9.40 (ppg) PV: 0.00 (cp) YP: 0.000 (Ibf /100ft Viscosity: 28.00 (s/qt) Gels 10 Sec: 0.000 (lbf /100ft Gels 10 Min: 0.000 (Ibf /100ft tives. Addi , Name Type Amount Units Concentration Concentration Unit ANTIFOAM ANTIFOAM 0.200 GAL/SX � 0 -65 DISPERSANT 0.400 % WT GASBLOK GASBLOK 2.000 GAL/SX D -186 ACCELERATOR 0.150 GAL/SX Flugcf Tests — ._ Thick Time Thick Free Water Free Water Fluid Loss Fluid Loss Fluid Loss -Comp Comp Comp Comp Comp Strength Comp Strength. (hr) Temp ( %) Temp (cc/30min) Temp Press Strength Strength Strength Strength Time Pressure 2 Temperature 2 ( °F) ( °F) ( °F) (psi) Time 1 Pressure 1 Temperature 1 2 (psi) (°F) (min) •si) ( °F (min) 5.00 69.0 0.00 80.0 20.0 69.0 1,000.0 12.5 500 82.0 14.0 1000 84.0 Printed 8/18/2010 8:34:16AM I4otth Ari AkASKA BP Page2'of2 Common Well Name: V -225 /OH ; Report No 1 Report Date: 6/29/2010 Project: Prudhoe Bay Site: PB V Pad ..... _ Spud Date/Time: 6/23/2010 Event Type: COM- ONSHORE (CON) : Start Date: 6/28/2010 End Date: 7/4/2010 AFE No.: Contractor. NABORS ALASKA DRILLING INC. Rig Name /No.: NABORS 9ES Rig Release: UWI: Active Datum: V -225 Actual ©80.70ft (above Mean Sea Level) $ple$eS l. s• Stage Stage Type Est. Top Est. Bottom Mud Circ. Mud Circ. Top Bottom Plug Pressure Float Pressure Returns Circulate Cmt Vol to Total Annular No. (ft) (ft) Rate Press. Plug Plug Bumped Bumped Held Held Prior Surface Mud Lost Flow (gpm) (psi) (psi) (min) (hr) (bbl) (bbl) After 1 PRIMARY CEMENT 2,831.00 5,150.00 295.0 530.0 Y Y Y 990.0 Y 3.00 FULL 2.00 0.0 0.0 Purtifp�ng §che�tiute • Fluid Pumped Volume Avg. Max Disp. Slurry Top Slurry Base Start Mix Cmt Start Slurry Pumping End Start Disp Foam Gas Type Gas Vol Bh Circ Bh Static Pumped Disp. Rate TMD TMD Pmp Date/Time Job Used Temp Temp (bbl) Rate ( bbVmin) (ft) (ft) (scf) (bbl/min) , s� r it t Casing Test Shoe Test Liner Top Test Test Pressure: 4,000.0 (psi) FIT /LOT: (ppg) Liner Overlap: (ft) Time: 30 (min) Tool: N Positive Test: (ppg) Positive Test Tool: N Cement Found between Shoe and Collar: N Open Hole Length: (ft) Negative Test: (ppg) Negative Test Tool: N Hours Before Start: 48.00 (hr) Time Before Test: (hr) Cmt Found on Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: Y Cement Top: 2,831.00 (ft) Under Pressure: (psi) How Determined: CEMENT BOND LOG Bond Quality: TOC Sufficient: Y CET Run: N Job Rating: GOOD �ond Quality: If Unsuccessful, Detection Indicator: Temp Survey: N Remedial Cement Required: N Hrs Prior to Log: 48.00 (hr) How Determined: Printed 8/18/2010 8:34:16AM I • p-o 0201-(1 I 'CHANICAL INTEGRITY REPORT • 1? VD v A == : Ce l ° OPER & FIELD 06f �r 5 G RELEASE: • 7/0 Val. NUMBER 1/-22 7,,--e14, DATA 7.1) 5 / .3gD.. , 87f , 'VD. ; : ETTD : $ OOS 3 � '/ iND 5 "/Casing: 9 % Shoe: .8 MD •881..TVD; "DN9 - . ,,,,_ - - 3g.10 48G /'TVD ; TOP 0 HD CD TV f � Shoe: s � D - ' '' Sc. e 4/07 Tacai. ^.g: 3 a" Packer 1.4x TVD; Set at .. /( rw cr ,Taf eke. :Iola Site and ; Perfs `IS to yBgY t•'..•CRANIC4t.1, INTEGRITY - PART 11 nnuius Press Test: _P 1Oba : 15 min ; 30 min X A Comments : {s evd lert 3 6 kn..: —.( ------- MECHANICAL INTEGRITY - PART #2 7 ` /r �6 Cement Volumes: Amt. Liner Csg 55 ; DV Cmt vol to cove= perfs 37 Neg-144 - , s . Y s-re' tft Theoretical TOO 3 5 ' /n.D %S T/c€24.rck - a c_ C .3D � o e) S0 TDC. 4.4 Yo o ` r►. u oh “S 17 • Cement Bond Log ditVP.r No) 115/7 In AOGCC File • CBL Evaluation, :.one above perfs L t ,, Q /eel - n L e r �_.. ! '`- r u e� c..Y c`L a a e_ 7� 364)° +ka, Production Log: Type Ai t ' : Evaluation CONCLUSIONS: ar_ # 2 : �u -µ- -� one ih -t-eo r 4 • STATE OF ALASKA 41 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended lb. Well Class: 20AAC25.105 20AAC25. 110 ❑ Development 0 Exploratory ❑ GINJ ❑ WINJ ® WAG ❑ WDSPL ❑ Other No. of Completions One ® Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 7/4/2010 / 209 - 118 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 6/23/2010 I 50 029 - 23419 - 00 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 6/28/2010 V -225 4638' FSL, 1832' FEL, SEC. 11, T11 N, R11E, UM g. KB (ft above MSL) 80,7' 15. Field / Pool(s): Top of Productive Horizon: 4016' FSL, 1963' FEL, SEC. 11, T11 N, R11E, UM GL (ft above MSL): 52.2' Prudhoe Bay Field / Orion Total Depth: 9. Plug Back Depth (MD +TVD): Schrader Bluff 3710' FSL, 1914' FEL, SEC. 11, T11 N, R11E, UM 5053' 4797' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 590471 y - 5969884 Zone- ASP4 5150' 4879' ADL 028240 TPI: x- 590349 y- 5969261 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 590401 y- 5968956 Zone- ASP4 None 18. Directional Survey: ® Yes ❑ No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1745' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/ VD: MWD GR, GR, RES, NEU, AZI DENS PWD, USIT N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE To BOTTOM ToP BOTTOM SIZE CEMENTING RECORD PULLED 20" 129.5# X -65 Surface 108' Surface 108' , 42" -260 sx Arctic Set 9 -5/8" 40# L -80 29' 2891' 29' 2885' 12 -1/4" 500 sx Arcticset Lite. 327 sx Class 'G' 7" 26# L -80 26' 5138' 26' 4869' , 8 -3/4" 264 sx Class 'G' 24. Open to production or injection? -4 Yes ❑ No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 4 - 1/2" Gun Diameter, 5 spf 3 - 1/2 ", 9.2 #, L - 80 4922' 4511' / 4346', 4638' / 4452' MD TVD MD TVD Additional Packers: 4700' / 4503' 4762' / 4555', 4805' / 4591' 4589' - 4631' 4411' - 4446' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 4666' - 4697' 4475' - 4501' 4712' - 4737' 4513' - 4534' COMPLETION DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED 4776' - 4800' 4567' - 4587' 2200' Freeze Protect w/ 77 Bbls of Diesel 4830' - 4884' 4611' - 4656' ® 4,-.0_ 0 R q( -m • 1 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection Yet N/A _ Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes 0 No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analyliGE el 50.071. None L \lgb 0 4 2010 RBDMS AUG 06 Et ,r7-17-? Alaska ell & Gat Cans. Commission Form 10-407 Revised 12/2009 CONTINUED ON REVERSE ,,i__ ARChdffinit Original Only 29. GEOLOGIC MARKERS (List all formations markers encountered): 30. a FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes 0 No Permafrost Top 28.5' 28,5' If yes, list intervals and formations tested, briefly summarizing test Permafrost Base 1776' 1773' results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Ugnu 2967' 2960' Ugnu MA 4109' 4015' None Ugnu MB1 4169' 4064' Ugnu MB2 4236' 4119' Ugnu MC 4329' 4196' Schrader Bluff NA 4403' 4256' Schrader Bluff NB 4433' 4281' Schrader Bluff NC 4468' 4310' Schrader Bluff NE 4476' 4317' Schrader Bluff NF 4538' 4368' Schrader Bluff OA 4590' 4412' Schrader Bluff OBa 4666' 4475' Schrader Bluff OBb 4709' 4511' Schrader Bluff OBc 4772 4563' Schrader Bluff OBd 4830' 4611' Schrader Bluff OBe 4897' 4667' Schrader Bluff OBf 4942' 4705' Base Schrader Bluff OBf 5002' 4755' Colville Mudstone 5002' 4755' Formation at Total Depth (Name): Colville Mudstone 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. I hereby certify that the foregoin is true and correct to the best of my knowledge. �� jj``�� Signed: Terrie Hubble 0AilLQ, C�� T itle: D rilling Technologist D ate: /V V - 225 209 - 118 Prepared By Name/Number. Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Trevor Hyatt, 564 -4627 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123 -00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • t z � 3rd . -6 r � Well Name: V -225 surf _ L , f T T 4st ' Test Depth Test p I MV1€ Prey a Pr e .. (TMD-Ft) �` (fig) (A. �� (�# s (p00. � 06/27/10 LOT 2,923.00 2,890.27 9.00 664.00 2,015.30 13.42 (ppg) Page 1 of 1 • 111 °l rth Ame i ALA BP = pie Operatio4OtA many Report Common Well Name: V -225 AFE No Event Type: MOBILIZATION (MOB) 1 Start Date: 6/15/2010 1 End Date: 6/23/2010 X3- 00TWZ -C (339,530.00 ) Project: Prudhoe Bay Site: PB V Pad Rig Name /No.: NABORS 9ES Spud Date/Time: 6/23/2010 6:30:OOPM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: V -225 Actual @80.7ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/20/2010 00:00 - 07:00 7.00 MOB P PRE PREPARE PIT MODULE AND MOVE PIT MODULE TO V -PAD. CLEAN OUT CELLAR. BRIDLE UP AND PREPARE DERRICK TO LOWER. MOVE RIG OFF OF WELL. 07:00 - 09:00 2.00 MOB P PRE HOLD PJSM. LOWER DERRICK. 09:00 - 12:00 3.00 MOB P PRE MOVE SUB FROM L -PAD TO L -PAD ACCESS ROAD. 12:00 - 00:00 12.00 MOB P PRE MOVE RIG TO END OF RIG MATS, DOUBLE AND TRIPLE STACK MATS BEHIND RIG, REVERSE RIG OVER MATS AND CONTINUE TO LEAP FROG MATS FROM L -PAD TO V -PAD. SIMOPS: NIPPLE UP DIVERTER AND DIVERTER FLOW LINES ON CONDUCTOR 6/21/2010 00:00 - 12:00 12.00 MOB P PRE MOVE RIG TO END OF RIG MATS, DOUBLE AND TRIPLE STACK MATS BEHIND RIG, REVERSE RIG OVER MATS AND CONTINUE TO LEAP FROG MATS FROM L -PAD TO V -PAD. 12:00 - 00:00 12.00 MOB P PRE MOVE RIG TO END OF RIG MATS, DOUBLE AND TRIPLE STACK MATS BEHIND RIG, REVERSE RIG OVER MATS AND CONTINUE TO LEAP FROG MATS FROM L -PAD TO V -PAD. 6/22/2010 00:00 - 12:00 12.00 MOB - P PRE MOVE RIG TO END OF RIG MATS, DOUBLE AND TRIPLE STACK MATS BEHIND RIG, REVERSE RIG OVER MATS AND CONTINUE TO LEAP FROG MATS FROM L -PAD TO V -PAD. 12:00 - 13:30 1.50 MOB P PRE STAGE RIG ON NORTH SIDE OF V -PAD DUE TO WIND SPEED AND DIRECTION. HOLD PJSM. RAISE AND PIN DERRICK AND CATTLE CHUTE. SPOOL WINCH LINES. 13:30 - 14:30 1.00 MOB P PRE MOVE RIG TO SOUTH SIDE OF PAD AND LINE UP TO WELL. 14:30 - 16:00 1.50 MOB P PRE LAY HERCULITE AND RIG MATS, SPOT RIG OVER WELL. 1 - 17:30 1.50 MOB P PRE SPOT PIT MODULE. HOOK UP INTERCONNECT, AIR UP FLOWLINE BOOTS. BERM RIG AND FLOWLINE AREA. 17:30 - 19:30 2.00 MOB P PRE BRIDLE DOWN. PIN BLOCKS AND TORQUE TUBE. TIE BACK AND SECURE BRIDLE LINES IN DERRICK. UNTIE SERVICE LOOP, BLOWER HOSE AND TONG HANGING LINES. HOOK UP KELLY HOSE. START LOADING AND STRAPPING 4" DP IN PIPESHED. 19:30 - 00:00 4.50 MOB P PRE SECURE CELLAR BOX AND RIG FLOOR. RIG UP 20" FLOW RISER TO SURFACE HYDRIL ► ': . HOOKUP TURNBUCKLES AND ADJUST BOP STACK. Printed 7/29/2010 3:38:29PM • N ALASKA,i BP Ngezil 2 O peration Summary Report Common Well Name: V -225 AFE No Event Type: MOBILIZATION (MOB) Start Date: 6/15/2010 End Date: 6/23/2010 X3- 00TWZ -C (339,530.00 ) Project: Prudhoe Bay Site: PB V Pad Rig Name /No.: NABORS 9ES Spud Date/Time: 6/23/2010 6:30:OOPM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: V -225 Actual @80.7ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/23/2010 00:00 - 01:30 1.50 RIGU P PRE SECURE CELLAR BOX AND RIG FLOOR. RIG UP 20" FLOW RISER TO SURFACE HYDRIL ANNULAR PREVENTER. HOOK UP TURNBUCKLES AND ADJUST BOP STACK. ACCEPT RIG AT 00:00 01:30 - 03:00 1.50 RIGU P PRE TAKE ON FLUIDS IN PITS. MW IN 8.5+ PPG DRILPLEX AR. SERVICE TOP DRIVE. CHANGE OUT SAVER SUB. CHANGE OUT PULSATION DAMPENER ON MUD PUMP #2 03:00 - 10:00 ( 7.00 RIGU P PRE PICK UP 150 JTS 4" DP AN RACK BACK 50 STANDS IN DERRICK. 10:00 - 12:00 2.00 RIGU P PRE PICKUP 21 JTS 4" HWDP AND RACK BACK 7 STANDS IN DERRICK. 12:00 - 13:00 1.00 RIGU P PRE PICK UP DRILL COLLARS AND EXPEDITE BHA COMPONENTS TO RIG FLOOR. RIG UP TONGS. 13:00 - 14:00 1.00 BOPSUR P PRE TEST DIVERTER: KNIFE VALVE OPEN - 15 SEC. - ANNULAR BAG CLOSED 40 SEC. - ACCUMULATOR TEST TO 200 PSI - 28 SEC. - ACCUMULATOR TEST TO FULL PRESSURE - 120 SEC. LOU GRIMALDI OF AOGCC WAIVED WITNESS OF DIVERTER TEST. 14:00 - 16:30 2.50 -1 RIGU P PRE PICK UP BHA #1 AS PER DD. - 12 1/4" MXL -1X BIT - 1.5DEGMUDMOTOR - MWD, UBHO, 6 3/4" COLLAS, JARS 16:30 - 18:00 1.50 RIGU P PRE RIG UP GYRO -DATA. EQUIPMENT. 18:00 - 18:30 0.50 RIGU P PRE FILL LINES AND TEST FOR LEAKS. TEST GOOD. Printed 7/29/2010 3:38:29PM • NA rth Al rt : ALASKA BP PI 18 t era i� Otithirtary Report Common Well Name: V -225 AFE No Event Type: DRL- ONSHORE (DON) Start Date: 6/23/2010 End Date: 6/28/2010 X3- 00TWZ -C (1,609,871.00 ) Project: Prudhoe Bay Site: PB V Pad Rig Name /No.: NABORS 9ES Spud Date/Time: 6/23/2010 6:30:OOPM Rig Release: INC. Contractor: NABORS ALASKA DRILLING I C . UWI: Active Datum: V -225 Actual @80.7ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/23/2010 18:30 - 21:00 2.50 DRILL P SURF DRILL AHEAD FROM BASE OF CONDUCTOR AT 108'MD TO 151'MD. - 460 GPM, 650 PSI ON, 600 PSI OFF - 50 RPM, 1K TQ ON, .5K TQ OFF - GYRO WHEN STAND DOWN. 21:00 - 22:30 1.50 DRILL N RREP 151.0 SURF TOP DRIVE BLOWER HOSE CAUGHT ON TONGS AND PARTED. REPLACE SAME. 22:30 - 00:00 1.50 DRILL P SURF DRILL AHEAD FROM 151'MD TO 281' MD. - 460 GPM, 650 PSI ON, 600 PSI OFF - 50 RPM, 1K TQ ON, .5K TQ OFF - PUW 65K, SOW 64K, ROT 64K - GYRO WHEN STAND DOWN -MW IN /OUT8.5PPG - 95 BBLS OF DRILPLEX AR LOST TODAY 6/24/2010 00:00 - 10:00 10.00 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE SECTION TO 1,209' MD. - 600 GPM, 1780 PSI ON, 1590 PSI OFF 60 RPM, 3.6K TQ ON, 1.1K TQ OFF PUW 86K, SOW 86K, ROT 85K - GYRO AS NEEDED - BACKREAM 30' ON CONNECTIONS MW IN /OUT 8.9 PPG 10:00 - 10:30 0.50 DRILL P SURF RIG DOWN GYRO DATA AND E -LINE. 10:30 - 12:00 1.50 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE SECTION FROM 1,209' MD TO 1,304' MD. - 600 GPM, 1780 PSI ON, 1590 PSI OFF - 60 RPM, 3.6K TQ ON, 1.1K TQ OFF - PUW 86K, SOW 86K, ROT 85K - BACKREAM 30' ON CONNECTIONS MW IN /OUT 9.1 PPG - 375 BBLS OF DRILPLEX AR LOST FROM 00:00 TO 12:00 12:00 - 22:00 10.00 DRILL P SURF DRILL AHEAD IN 12 1/4" HOLE SECTION FROO1\4 -, 1.304'MD TO TD AT 2.904' MD. ""A 1 J/ - 700 GPM, 3050 PSI ON, 2970 PSI OFF - 100 RPM, 4K TQ ON, 2.6K TQ OFF • - PUW 107K, SOW 104K, ROT 107K - BACKREAM 30' ON CONNECTIONS - ART 8.86 HRS, AST 1.18 HRS, ADT 10.04 HRS ENCOUNTER INTERMITTENT HYDRATES AT 2,100' MD. HYDRATES INCREASE AT 2,831' MD. 22:00 - 23:00 1.00 DRILL P SURF CIRCULATE UNTIL SHAKERS CLEAN UP, 3.5 BOTTOMS UP. RECIPROCATE PIPE IN 90' STROKES. - 700 GPM, 3050 PSI - 100 RPM, 2.6K TQ - PUW 107K, SOW 104K, ROT 107K Printed 7/29/2010 3:41:54PM • NorthAtt %tea - ALASKA BP Re Operation Summary Report Common Well Name: V -225 AFE No Event Type: DRL- ONSHORE (DON) Start Date: 6/23/2010 End Date: 6/28/2010 X3- 00TWZ -C (1,609,871.00 ) Project: Prudhoe Bay Site: PB V Pad Rig Name/No.: NABORS 9ES Spud Date/Time: 6/23/2010 6:30:OOPM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: V -225 Actual @80.7ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:00 - 00:00 1.00 DRILL P SURF MONITOR WELL - STATIC. MW IN / OUT 9.4 PPG. BACKREAM FROM 2903' MD TO 2,641' MD. - 700 GPM, 3050 PSI - 100 RPM - 265 BBLS OF DRILPLEX AR LOST FROM 12:00 TO 00:00 -735 BBLS OF DRILPLEX AR TOTAL LOST IN SURFACE HOLE 6/25/2010 00:00 - 01:00 1.00 DRILL P SURF BACKREAM FROM 2,641' MD TO BASE OF PERMAFROST AT 1,716' MD. - 700 GPM, 3050 PSI - 100RPM 01:00 - 03:30 2.50 DRILL P SURF PULL OUT OF HOLE ON ELEVATORS TO BHA AT 281' MD. CONTROL RUNNING SPEED TO PREVENT SWABBING. WORK TIGHT SPOTS FROM 1,250' MD - 1,000' MD AND 850' MD - 750' MD. 03:30 - 06:30 3.00 DRILL P SURF LAY DOWN 12 1/4" SURFACE HOLE DRILLING BHA #1. - RACK BACK JAR STAND AND COLLAR STAND - BIT GRADE: 2- 2- WT- A- E- 1 -RG -TD 06:30 - 08:00 1.50 DRILL P SURF CLEAN AND CLEAR RIG FLOOR OF ALL BHA EQUIPMENT. 08:00 - 10:30 2.50 CASING P SURF RIG UP TO RUN CASING. PERFORM DUMMY RUN WITH HANGER. CHANGE OUT TO LONG BALES. RIG UP FRANKS TOOL, 350 TON ELEVATORS, SINGLE JOINT ELEVATORS, CASING TONGS, STABBING BOARD AND ALL RELATED CASING EQUIPMENT. 10:30 - 11:00 0.50 CASING P SURF HOLD PJSM ON RUNNING 9 5/8" SURFACE CASING. 11:00 - 18:00 7.00 CASING P SURF RUN 9 5/8" 40# BTC SURFACE CASING TO 2859' MD. - BAKER -LOK ALL CONNECTIONS BELOW FLOAT COLLAR - DOPE EACH CONNECTION WITH BEST -O -LIFE 2000 DOPE - TORQUE ALL CONNECTIONS TO 10K TQ - FILL EACH JOINTS AND CIRCULATE EVERY 10TH JOINT DOWN - 25 BOW SPRING CENTRALIZERS RAN - 70 BBLS OF DRILPLEX AR LOST FROM 00:00 TO 12:00 18:00 - 19:00 1.00 CASING P SURF MAKE UP LANDING JOINT AND SET ON RING. - PUW 148K, SOW 125K RIG DOWN FRANK'S TOOL AND BLOW DOWN TOP DRIVE. RIG UP CEMENT HEAD AND CIRCULATING EQUIPMENT. _ Printed 7/29/2010 3:41:54PM • Nort America - ALASKA SP " = Page o f 8 Operation SUrbmary Report Common Well Name: V -225 AFE No Event Type: DRL- ONSHORE (DON) Start Date: 6/23/2010 End Date: 6/28/2010 X3- 00TWZ -C (1,609,871.00 ) Project: Prudhoe Bay Site: PB V Pad Rig Name /No.: NABORS 9ES Spud Date/Time: 6/23/2010 6:30:OOPM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: V -225 Actual @80.7ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:00 - 20:00 1.00 CEMT P SURF CIRCULATE AND CONDITION DRILPLEX AR FOR CEMENT JOB. BREAK CIRCULATION AND STAGE PUMPS UP FROM 84 GPM AT 235 PSI TO 336 GPM AT 402 PSI. RECIPROCATE PIPE IN 15 STROKES. - PUW 148K, SOW 144K r 20:00 - 00:00 4.00 CEMT N WAIT 2,891.0 SURF WAIT ON TRUCKS FOR CEMENT JOB WHILE CONTINUING TO CIRCULATE AND RECIPROCATE. - 61 BBLS OF DRILPLEX AR LOST FROM 12:00 TO 00:00 - 866 BBLS OF DRILPLEX AR TOTAL LOST IN SURFACE HOLE 6/26/2010 00:00 - 01:00 1.00 CEMT N WAIT 2,981.0 SURF WAIT ON TRUCKS FOR CEMENT JOB WHILE CONTINUING TO CIRCULATE AND RECIPROCATE. RECIPROCATE PIPE IN 15 STROKES. - PUW 148K, SOW 144K Printed 7/29/2010 3:41:54PM North America - ALASKA - BP Pa4 ofd8�< 4peratior Summary Report Common Well Name: V -225 AFE No Event Type: DRL- ONSHORE (DON) Start Date: 6/23/2010 End Date: 6/28/2010 X3- OOTWZ -C (1,609,871.00 ) _ I Project: Prudhoe Bay Site: PB V Pad Rig Name /No.: NABORS 9ES Spud Date/Time: 6/23/2010 6:30:OOPM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: V -225 Actual @80.7ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 04:30 3.50 CEMT P SURF PJSM WITH SLB CEMENTERS, TRUCK PUSHERS, CREWS, MUD ENGINEERS FOR CEMENT JOB. CEMENT 9 5/8" SURFACE CASING WITH RECIPROCATION IN 15' STROKES. 00:52 PUMP 10 BBLS 10.1PPG MUD PUSH II AT 3.5 BPM, TEST LINES TO 3800 PSI - TEST GOOD. 01:02 PUMP 90.1 BBL 10.1 PPG MUD PUSH II AT 6.5 BPM WITH 140 PSI 01:17 END MUD PUSH, 100.1 BBLS AWAY 01:18 DROP BOTTOM PLUG, BEGIN BATCHING UP LEAD CEMENT 01:24 START PUMPING 10.7 PPG ASL LEAD AT 6.5 BPM 01:38 89 BBL LEAD CEMENT AWAY, 6.5 BPM, 158 PSI 01:43 120 BBL LEAD CEMENT AWAY, 6.5 BPM, 157 PSI. MUD PUSH AT SHOE 01:59 224 BBL LEAD CEMENT AWAY, 6.6 BPM, 182 PSI BOTTOM PLUG SHEARED 2:00 230 BBL LEAD CEMENT AWAY,, 6.6 BPM, 209 PSI LEAD CEMENT AT SHOE, END RECIPROCATION AND LAND HANGER ON RING 02:13 318 BBL LEAD CEMENT AWAY, 6.6 BPM, 349 PSI MUD PUSH AT SURFACE 02:27 402 BBL LEAD CEMENT AWAY, END OF SLURRY BEGIN BATCHING UP 15.8 PPG TAIL CEMENT 02:36 START PUMPING 15.8 PPG TAIL AT 5 BPM, 364 PSI 02:55 48 BBL TAIL CEMENT AWAY, 5 BPM, 444 PSI 10.7 PPG ASL LEAD CEMENT AT SURFACE 02:59 68.3 BBL TAIL CEMENT AWAY, END OF SLURRY 03:02 DROP TOP PLUG AND KICK OUT WITH 10 BBL H2O. ISOLATE SLB AND DISPLACE WITH RIG PUMPS. 03:03 CHASING CEMENT WITH RIG PUMPS, 9.4 PPG DRILPLEX AR MUD SYSTEM 03:27 TAIL CEMENT AT SHOE WITH 1890 STROKES 03:51 PLUG BUMP AT 2853 STROKES, 213 BBLS DISPLACED. FINAL PUMP PRESSURE AT BUMP 1520 PSI AND HELD FOR 2 MINUTES. INCREASE PRESSURE TO 3500 PSI AND TEST CASING FOR 5 MINUTES. Printed 7/29/2010 3:41:54PM • . .. Nert{hAmerica - ALAS/01/4:1---SP Page 6 o`f Operation Sumi Report Common Well Name: V -225 AFE No Event Type: DRL- ONSHORE (DON) Start Date: 6/23/2010 I End Date: 6/28/2010 X3- 00TWZ -C (1,609,871.00 ) Project: Prudhoe Bay Site: PB V Pad Rig Name /No.: NABORS 9ES Spud Date/Time: 6/23/2010 6:30:OOPM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: V -225 Actual @80.7ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) AFTER CASING TEST BLEED PRESSURE TO ZERO. CHECK FLOATS - HOLDING. CEMENT IN PLACE AT 03:51. 224 BBLS OF 10.7 PPG SIDEWALK CEMENT. RETURNED TO SURFACE. FULL RETURNS DURING CEMENT JOB. CEMENT JOB VOLUME: k 402 BBLS ASL LEAD PUMPED; 500 SACKS AT 4.51 CUFT /SX 68 BBLS CLASS G TAIL PUMPED; 329 SACKS AT 1.16 CUFT /SX TAIL COMPRESSIVE STRENGTH: 500 PSI: 11 :45' HRS 1000 PSI: 17:34 HRS TOTAL FLUID LOSS FOR SURFACE: 866 BBLS DRILPLEX AR MUD SYSTEM 04:30 - 07:30 3.00 CEMT P SURF RIG DOWN CEMENTING EQUIPMENT. FLUSH FLOWLINE AND STACK. RIG DOWN CASING EQUIPMENT AND LAY DOWN LANDING JOINT. 07:30 - 12:00 4.50 BOPSUR P SURF NIPPLE DOWN DIVERTER SYSTEM. RIG DOWN SURFACE HYDRIL AND RISER. CHANGE OUT BAILS. SIMOPS: CHANGE OUT LINER AND SWABS TO 5" ON MUD PUMP #1. 12:00 - 15:30 3.50 WHSUR P SURF MAKE UP SPEED HEAD ASSEMBLY. SET BOPE STACK AND TORQUE. INSTALL FLOW NIPPLE. MAKE UP TURNBUCKLES. SIMOPS: CHANGE OUT LINER AND SWABS TO 5" ON MUD PUMP #2. 15:30 - 16:30 1.00 BOPSUR P SURF PREPARE FOR BOPE TEST. FUNCTION ALL RAMS. SET TEST PLUG WITH 4" TEST JOINT. FILL STACK. MAKE UP TESTING EQUIPMENT. 16:30 - 21:00 4.50 BOPSUR P SURF TEST BOPE WITH 4" TEST JOINT TO A LOW 250 PSI / HIGH 4000 PSI. - EACH TEST CHARTED AND HELD FOR 5 2O r MINUTES. �! - ANNULAR BAG TESTED TO A LOW 250 PSI / HIGH 3500 PSI TEST WITNESSED BY WSL BLAIR NEUFELD AND JOSHUA MALLERY, TOOLPUSHER BILL BIXBY, ROY HUNT, AND JOHN CASTLE. - AOGCC REP BOB NOBLE WAIVED WITNESS OF TEST 21:00 - 21:30 0.50 BOPSUR P SURF LAY DOWN BOP TESTING EQUIPMENT. INSTALL 9 7/16" WEAR RING. Printed 7/29/2010 3:41:54PM f North America - ALASKA Pate - of 8 Operation Summ Report Common Well Name: V -225 AFE No Event Type: DRL- ONSHORE (DON) Start Date: 6/23/2010 End Date: 6/28/2010 X3- 00TWZ -C (1,609,871.00 ) Project: Prudhoe Bay Site: PB V Pad Rig Name /No.: NABORS 9ES Spud Date/Time: 6/23/2010 6:30:OOPM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: V -225 Actual @80.7ft (above Mean Sea Level) Date ( From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:30 - 22:00 0.50 CASING P SURF EXPEDITE BHA COMPONENTS TO RIG FLOOR. 22:00 - 23:30 1.50 CASING N RREP SURF CHANGE OUT WASHPIPE ON TOP DRIVE. TEST TO 3800 PSI. 23:30 00:00 0.50 CASING P SURF PICK UP 8 3/4" PRODUCTION DRILLING BHA #2. 6/27/2010 100:00 - 02:00 2.00 CASING P SURF PICKUP BHA #2 AND RUN IN HOLE. - QD505FX HUGHES BIT - 1.5DEGMUDMOTOR - LWD, MWD, ADN - COLLAR STAND, JAR STAND 1 0 2:00 - 03:30 1.50 CASING P SURF PERFORM SHALLOW HOLE TEST. TEST - GOOD. - 425 GPM, 1165 PSI 03:30 - 04:30 1.00 CASING P SURF CONDUCT STRIPPING AND WELL CONTROL DRILL WITH RIG HANDS, WSL AND TOOL PUSHER 04:30 - 05:00 0.50 CASING P SURF RUN IN HOLE TO 2,557' MD ON 4" DP. 05:00 - 05:30 0.50 CASING P SURF PERFORM 3500 PSI 9 5/8" CASING TEST FOR 30 CHARTED MINUTES WITH 3.32 BBLS OF 9.4 PPG DRILPLEX AR MUD. - 70 PSI LOST IN FIRST 15 MINUTES - 10 PSI LOST IN SECOND 15 MINUTES - TOTAL OF 80 PSI LOST IN 30 MINUTE TEST 05:30 - 07:30 2.00 CASING P SURF WASH DOWN TO FLOAT COLLAR AND TAG ON DEPTH AT 2,805' MD. DRILL OUT FLOAT EQUIPMENT TO 2,880' MD - PU 110K, SO 100K, ROT 105K - 550 GPM WITH 2250 PSI - 40 RPM 07:30 - 09:00 1.50 CASING P 1 SURF CIRCULATE AND CONDITION MUD WHILE RECIPROCATING. - SWAP FROM 9.4 PPG DRILPLEX TO 9.0 PPG LSND MUD. - RECORD SLOW PUMP RATES. -MW IN /OUT 9.0 PPG LSND 09:00 - 09:30 0.50 CEMT P SURF DRILL OUT CASING SHOE AND 20' OF NEW FORMATION TO 2,923' MD. PULL BACK INSIDE 9 5/8" CASING SHOE AT 2,891' MD AND CONDUCT LEAK OFF TEST TO 13.43 PPG EMW. LOT: MW 9.0 PPG, 2,885' TVD, DEVIATE FROM STRAIGHT LINE AT 664 SURFACE PSI, EMW 13.43 PPG. Printed 7/29/2010 3:41:54PM North America - ALASKA = BP '-`7,7 Page 7 of # Operation Summary Report Common Well Name: V -225 AFE No Event Type: DRL- ONSHORE (DON) Start Date: 6/23/2010 End Date: 6/28/2010 X3- 00TWZ -C (1,609,871.00 ) Project: Prudhoe Bay Site: PB V Pad Rig Name /No.: NABORS 9ES Spud Date/Time: 6/23/2010 6:30:OOPM I Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: V -225 Actual @80.7ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations I (hr) (ft) 09:30 - 12:00 2 50 DRILL P PROD1 DRILL AHEAD IN 8 3/4" HOLE FROM 2905' MD' TO 3 129' MD - PU 110K, SO 105K, ROT 107K, WOB 10K - 15K LBS - PUMP AT 574 GPM WITH 1630 PSI ON, 1444 PSI OFF 60 RPM, 3.3K TQ ON, 1.2K TQ ON - AST 0.42 HRS, ART 0.53 HRS - BACKREAM 30' BEFORE CONNECTION AT 60 RPM - CAL ECD 9.66 PPG, ACT ECD 10.12 PPG - NO FLUID LOSS NOTED MW IN / OUT 9.0 PPG 12:00 - 00:00 12.00 DRILL P PROD1 DRILL AHEAD IN 8 3/4" HOLE FROM 3,129' MD' ^ TO 4562' MD. - PU 131K, SO 117K, ROT 124K, WOB 18K - 20K LBS - PUMP AT 575 GPM WITH 2140 PSI ON, 1950 PSI OFF - 100 RPM, 4.9K TQ ON, 2.7K TQ OFF - AST 2.98 HRS, ART 5.32 HRS - BACKREAM 30' BEFORE CONNECTION AT 100 RPM - CAL ECD 9.17 PPG, ACT ECD 9.48 PPG PUMP VISCOUS SWEEP AT 3,520'MD. 20% INCREASE IN SANDS AND TRACES OF CLAY OBSERVED AT SURFACE. PUMP VISCOUS SWEEP AT 4,085'MD. NO INCREASE IN CUTTINGS NOTED. - INCREASE MUD WEIGHT TO 9.4 PPG PRIOR TO ENTERING OBC SANDS - NO FLUID LOSS NOTED MW IN / OUT 9.4 PPG 6/28/2010 00:00 - 03:00 3.00 DRILL P PROD1 DRILL AHEAD IN 8 3/4" HOLE FROM 4,562' MD' e9 TO TD AT 5,150' MD. - PU 135K, SO 120K, ROT 130K, WOB 18K - 20K LBS - PUMP AT 575 GPM WITH 2460 PSI ON, 2380 PSI OFF - 100 RPM, 3.3K TQ ON, 1.2K TQ OFF - AST 0.0 HRS, ART 2.91 HRS - BACKREAM 30' BEFORE CONNECTION AT 60 RPM - CAL ECD 9.66 PPG, ACT ECD 10.40 PPG - NO FLUID LOSS NOTED MW IN / OUT 9.4 PPG Printed 7/29/2010 3:41:54PM • • North erica - ALASKA BP, - Page 8of 8 Summary Report Well Name: V -225 AFE No Event Type: DRL- ONSHORE (DON) Start Date: 6/23/2010 End Date: 6/28/2010 X3- 00TWZ -C (1,609,871.00 ) Project: Prudhoe Bay Site: PB V Pad Rig Name /No.: NABORS 9ES Spud Date/Time: 6/23/2010 6:30:00PM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: V -225 Actual @80.7ft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 03:30 0.50 DRILL P PROD1 CIRCULATE OPEN HOLE ANNULAR VOLUME AT TD. - 575 GPM, 2460 PSI MONITOR WELL - STATIC MW IN /OUT 9.4 PPG 03:30 - 12:00 8.50 DRILL P PROD1 BACKREAM TO SHOE 575 GPM, 100RPM - MANAGE ECD AT 1 PPG OVER CALCULATED - REDUCE RPM TO 60 RPM AT 4,000' MD. SIMOPS: EXPEDITE CASING TOOLS TO RIG FLOOR 12:00 - 13:00 1.00 DRILL P PROD1 CIRCULATE 3 BOTTOMS UP AT CASING SHOE. PUMP DRY JOB. - 565 GPM, 1800 PSI - 60 RPM, 2.4K TQ MONITOR WELL - STATIC. MW IN / OUT 9.4 PPG 13:00 - 14:30 1.50 DRILL P PROD1 TRIP OUT OF HOLE FROM 2,865' MD TO 933' MD WHILE RACKING BACK 4" DP STANDS. 14:30 - 15:30 1.00 DRILL P PROD1 LAY DOWN 21 JTS OF 4" HWDP 1X1. 15:30 - 18:00 2.50 DRILL P PROD1 LAY DOWN 8 3/4" PRODUCTION DRILLING BHA #2 AS PER DD. - BIT GRADE: 2- 4- WT- S- X- 1 -CT -TD 18:00 - 19:00 1.00 DRILL P PROD1 CLEAN AND CLEAR RIG FLOOR. Printed 7/29/2010 3:41:54PM • • 1 Nortb A etca F LA KA - BP , age of Op ration ' ary Report Common Well Name: V -225 AFE No Event Type: COM- ONSHORE (CON) Start Date: 6/28/2010 End Date: 7/4/2010 X3- 00TWZ -C (2,095,440.00 ) Project: Prudhoe Bay Site: PB V Pad Rig Name /No.: NABORS 9ES Spud Date/Time: 6/23/2010 6:30:OOPM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: V -225 Actual @80.7ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/28/2010 19:00 - 20:00 1.00 BOPSUR P RUNPRD FLUSH BOP STACK WITH PORTED SUB. PULL 9 1/16" WEAR RING. 20:00 - 21:00 1.00 BOPSUR P RUNPRD CHANGE UPPER RAMS FROM 3 1/2" X 6" VARIABLES TO 7 ". 21:00 - 21:30 0.50 BOPSUR P RUNPRD HOLD UNANNOUNCED RIG EVACUATION DRILL. 21:30 - 22:30 1.00 BOPSUR P RUNPRD - TEST 7" UPPER RAMS WITH 7" TEST JOINT TO A LOW 250 PSI / HIGH 4000 PSI. - TEST CHARTED AND HELD FOR 5 MINUTES. - TEST WITNESSED BY TOOL PUSHER JOHN CASTLE 22:30 - 00:00 1 1.50 CASING P RUNPRD HOLD PJSM ON RIGGING UP CASING RUNNING EQUIPMENT. MAKE DUMMY RUN WITH CASING HANGER. RIG UP CASING EQUIPMENT. 6/29/2010 00:00 - 01:00 1.00 CASING P RUNPRD RIG UP TO RUN CASING. RIG UP 350 TON ELEVATORS. RIG UP CASING TONGS. CHANGE OUT BALES. 01:00 - 06:00 5.00 CASING P RUNPRD RUN 7" 26# L -80 VAM TOP PRODUCTION CASING TO 9 5/8" CASING SHOE AT 2,836' MD. BAKER -LOK ALL CONNECTIONS BELOW FLOAT COLLAR - TORQUE TURN ALL CONNECTIONS TO 11,950K FT LBS - FILL EACH JOINT AND CIRCULATE EVERY 10TH JOINT DOWN 06:00 - 06:30 0.50 CASING P RUNPRD CIRCULATE BOTTOMS UP AT 9 5/8" CASING SHOE. - 210 GPM, 350 PSI - MW IN AND OUT 9.6 PPG 06:30 - 13:00 6.50 CASING P RUNPRD RUN 7" 26# L -80 VAM TOP PRODUCTION CASING FROM 9 5/8" CASING SHOE TO TD. - TORQUE ALL CONNECTIONS TO 11,950K FT LBS - FILL EACH JOINT AND CIRCULATE EVERY 10TH JOINT DOWN - JTS 1 AND 3 -30 RUN WITH TWO CENTRALIZERS AND ONE STOP RING LOCKED DOWN IN MIDDLE; MARKER JOINT WITH ONE CENTRALIZER AND STOP RING - TOTAL 59 CENTRALIZERS, 29 STOP RINGS RUN - MAKE UP LANDING JOINT, LAND STRING - RU FOR CEMENT JOB 13:00 - 16:00 3.00 CASING P RUNPRD CIRCULATE AND CONDITION MUD FOR CEMENT JOB. - STAGE UP FROM 2 BPM AND 330 INITIAL PSI TO 7 BPM AND 590 FINAL PSI - RECIPROCATE CASING IN 15' STROKES Printed 7/29/2010 3:42:46PM NarttiAmerica - ALASKA- - SP . Page of 6,`E OPe Summary Report Common Well Name: V -225 AFE No Event Type: COM- ONSHORE (CON) Start Date: 6/28/2010 End Date: 7/4/2010 X3- OOTWZ -C (2,095,440.00 ) Project: Prudhoe Bay Site: PB V Pad Rig Name /No.: NABORS 9ES Spud Date/Time: 6/23/2010 6:30:OOPM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: V -225 Actual @80.7ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations I � � et (hr) (ft) 16:00 - 17:00 1.00 CEMT P RUNPRD CEMENT 7" 26# L -80 VAM TOP PRODUCTION CASING - 46 BBLS OF 15.8 PPG TAIL CEMENT; YIELD 1.17 CU FT /SACK, 264 SACKS - RECIPROCATED STRING THROUGHOUT ENTIRE JOB -CEMENT IN PLACE 1701 HRS 17:00 - 18:30 1.50 CEMT P RUNPRD ATTEMPT PRESSURE TEST OF 7" CASING TO 4000 PSI; LEAK AT LANDING JOINT - TIGHTEN CONNECTION, RE- ATTEMPT TEST - NO GO ON TEST: 100 PSI BLED OFF IN FIRST 15 MIINUTES, TEST STOPPED WHEN 50 MORE PSI BLED OFF IN NEXT 10 MINUTES 1- TROUBLESHOOT SURFACE EQUIPMENT, BLEED AIR FROM ALL LINES, ISOLATE CEMENT MANIFOLD FOR TEST - RE- ATTEMPT TEST TO 4000 PSI, GOOD TEST - CONDUCT INITIAL ANNULUS INJECTIVITY TEST BY PUMPING 3 BBLS AWAY AT 2.5 BPM 18:30 - 21:00 2.50 CEMT P RUNPRD RIG DOWN FROM CEMENT JOB, FLUSH STACK 21:00 - 22:30 1.50 WHSUR P RUNCMP INSTALL 9 5/8" X 7" PACK OFF INTO WELLHEAD - PRESSURE TEST TO 5000 PSI - PUMP DOWN ANNULUS WITH 2 BBLS FLUID AT 10 SPM 22:30 - 00:00 1.50 BOPSUR P RUNCMP CHANGE OUT 7" RAMS TO 3 1/2" BY 6" VARIABLE RAMS - CONTINUE PUMPING AWAY 2 BBLS FLUID AT 10 SPM EVERY HOUR 6/30/2010 00:00 - 01:00 1.00 BOPSUR P RUNPRD CHANGE OUT UPPER 7" RAMS TO 3 1/2 "X6" VARIABLE RAMS - CONTINUE PUMPING AWAY 2 BBLS FLUID PER HOUR DOWN OA 01:00 - 02:30 1.50 BOPSUR P RUNPRD TEST UPPER AND LOWER VARIABLE RAMS AND ANNULAR PREVENTER WITH 3 1/2" TEST JOINT TO 250 PSI LOW AND 4000 PSI HIGH. TEST UPPER VARIABLE RAMS WITH 4" TEST JOINT TO sof 250 PSI LOW AND 4000 PSI HIGH. TEST 3 1/2" SAFETY VALVES. - CONTINUE PUMPING AWAY 2 BBLS FLUID PER HOUR DOWN OA 02:30 - 03:30 1.00 BOPSUR P RUNPRD CLEAR AND CLEAN RIG FLOOR OF BOP TEST EQUIPMENT INSTALL WEAR RING, RILDS 03:30 - 05:00 1.50 PERFOB P OTHCMP RIG UP TO RUN PERFORATION ASSEMBLY - PJSM ON RUNNING GUNS, HANDLING MWD TOOL - CONTINUE PUMPING AWAY 2 BBLS FLUID PER HOUR DOWN OA 05:00 - 09:00 4.00 PERFOB P OTHCMP RIH WITH PERFORATION ASSEMBLY ON 4" DP - TAG UP WITH FLOAT COLLAR AT 5053' - CONTINUE PUMPING AWAY 2 BBLS FLUID PER HOUR DOWN OA Printed 7/29/2010 3:42:46PM • • North America - ALASKA;- BP Page 3 ore Operation Summary Report Common Well Name: V -225 AFE No Event Type: COM- ONSHORE (CON) Start Date: 6/28/2010 End Date: 7/4/2010 X3- 00TWZ -C (2,095,440.00 ) Project: Prudhoe Bay Site: PB V Pad Rig Name /No.: NABORS 9ES Spud Date/Time: 6/23/2010 6:30:OOPM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: V -225 Actual @80.7ft (above Mean Sea Level) Date From - To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 12:30 3.50 EVAL P OTHCMP LOG WITH MWD FROM 5053' TO 4882'; SET GUNS ON DEPTH IN CORRELATION TO DRILLING J( . LOG p Q r - OA ZONE 4588 - 4630', OBA ZONE 4664 - 4695', 1 OBB ZONE 4710 - 4735', OBC ZONE 4774 - 4798', OBD ZONE 4828' -4882' MD SIMOPS: RU LITTLE RED HOT OIL AND FREEZE PROTECT 9 5/8 "X7" OA 12:30 - 13:00 0.50 PERFOB P OTHCMP PJSM ON FIRING 4 1/2" SCHLUMBERGER POWERJET 4505 TCP PERFORATING GUNS - FIRE GUNS, 8 BBL INITIAL LOSS - GUN CONFIGURATION: 5 SPF, 72 DEG PHASING - FLUID LEVEL DROPPED 15' IN STACK 13:00 - 13:30 0.50 PERFOB P OTHCMP POH FROM 4882' TO 4495' 13:30 - 14:30 1.00 PERFOB P OTHCMP CIRCULATE SURFACE -TO- SURFACE TIMES 2 AT 490 GPM, 1825 PSI - MONITOR WELL - STATIC - MW IN AND OUT 9.4 PPG 14:30 - 16:00 1.50 PERFOB P OTHCMP POH FROM 4495' TO 379' 16:00 - 19:00 3.00 PERFOB P OTHCMP LAY DOWN PERFORATING ASSEMBLY INSPECT GUNS; ALL SHOTS FIRED 19:00 - 19:30 0.50 PERFOB P OTHCMP CLEAN AND CLEAR RIG FLOOR 19:30 - 20:00 0.50 PERFOB P OTHCMP MOBILIZE PERFORATING CLEANOUT RUN BHA TO RIG FLOOR 20:00 22:00 2.00 PERFOB P OTHCMP MU PERFORATING CLEANOUT RUN BHA: - BIT, FULL GAUGE STRING MILL, 2 BOOT BASKETS, STRING MAGNET, JAR, 6 4 3/4" DRILL COLLARS 22:00 - 00:00 2.00 PERFOB P OTHCMP RIH WITH CLEANOUT BHA ON 4" DRILL PIPE - PUW 85K, SOW 83K - TOTAL FLUID LOSS TO PERFS 11 BBLS - MW IN AND OUT 9.4 PPG 7/1/2010 00:00 - 00:45 0.75 PERFOB OTHCMP RIH WITH CLEANOUT BHA ON 4" DRILL PIPE TO 5053' - PUW 100K, SOW 93K -MW IN AND OUT 9.4 PPG 00:45 - 02:00 1.25 PERFOB OTHCMP POH FROM 5053' TO 5000' - BACKREAM ACROSS PERF ZONE TO 4485' AT 60 RPM, 210 GPM, 560 PSI MW IN AND OUT 9.4 PPG 02:00 - 02:30 0.50 PERFOB OTHCMP CIRCULATE BOTTOMS UP AT 210 GPM, 540 PSI - MW IN AND OUT 9.4 PPG 02:30 - 03:45 1.25 PERFOB P OTHCMP POH LAYING DOWN 4" DRILL PIPE ONE BY ONE 03:45 - 05:00 1.25 PERFOB P OTHCMP SLIP AND CUT DRILLING LINE - SERVICE TOP DRIVE, INSPECT AND ADJUST BRAKES, ADJUST CROWN -O- MATIC, INSPECT I DERRICK 05:00 - 07:30 2.50 PERFOB P OTHCMP CONTINUE POH LAYING DOWN 4" DRILL PIPE ONE BY ONE 07:30 - 09:00 1.50 PERFOB P OTHCMP LAY DOWN CLEANOUT BHA - MONITOR WELL - STATIC - MW 9.4 PPG Printed 7/29/2010 3:42:46PM • N©rtt America - ALASKA -- B#' of e Operation Summery Report Common Well Name: V -225 AFE No Event Type: COM- ONSHORE (CON) Start Date: 6/28/2010 End Date: 7/4/2010 X3- 00TWZ -C (2,095,440.00 ) Project: Prudhoe Bay Site: PB V Pad Rig Name /No.: NABORS 9ES Spud Date/Time: 6/23/2010 6:30:OOPM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: V -225 Actual @80.7ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 10:00 1.00 PERFOB P OTHCMP CLEAR AND CLEAN RIG FLOOR OF CLEANOUT BHA, HANDLING TOOLS 10:00 - 12:00 2.00 EVAL P OTHCMP MOBILIZE SCHLUMBERGER E -LINE UNIT EQUIPMENT TO RIG FLOOR - RU E -LINE 12:00 - 13:00 1.00 EVAL P OTHCMP RIH WITH 6.125" GAUGE RING AND JUNK BASKET TO 5046' - POH WITH ASSEMBLY; 1/2 CUP DEBRIS RETRIEVED 13:00 - 16:30 3.50 EVAL P OTHCMP ' RU USIT LOGGING TOOL - RIH WITH USIT TOOL TO 5023' AND LOG FOR CEMENT BOND LOG 16:30 - 17:00 0.50 j EVAL P OTHCMP RD SLB E -LINE UNIT AND EQUIPMENT 17:00 - 21:00 4.00 RUNCOM P RUNCMP RIG UP COMPLETION RUNNING EQUIPMENT - RU CASING TOOLS - RU ;I -WIRE SPOOL AND RUNNING EQUIPMENT - PULL WEAR RING, MAKE DUMMY RUN WITH HANGER 21:00 - 00:00 3.00 RUNCOM P RUNCMP MU, RIH WITH 3 1/2" 9.2# L -80 TCII COMPLETION STRING PER RUNNING ORDER (SEE COMPLETION TALLY IN WELLBORE EQUIPMENT SUMMARY) - PRESSURE TEST I -WIRE LINE TO 5000 PSI - BAKER -LOK ALL CONNECTIONS BELOW FIRST PACKER ASSEMBLY 7/2/2010 00:00 - 21:00 21.00 RUNCOM P RUNCMP MU, RIH WITH 3 1/2" 9.2# L -80 TCII COMPLETION STRING PER RUNNING ORDER - TEST I -WIRE CONNECTIONS TO 5000 PSI - MU 3 1/2" 9.2# L -80 TCII TUBING TO 2300 FT /LBS - PU ONE JOINT OUT OF RUNNING ORDER, SET STRING INTO SLIPS FOR LOGGING - TOTAL OF 77 FULL CLAMPS, 24 HALF CLAMPS AND 101 PINS USED TO SECURE I -WIRE - PUW 88K, SOW 78K 21:00 - 23:00 2.00 I RUNCOM P RUNCMP MOBILIZE WIRELINE EQUIPMENT TO FLOOR - RU SCHLUMBERGER WIRELINE UNIT - MU GREASE LINE PACKOFF, PUMP IN UNIT 23:00 - 00:00 1.00 RUNCOM P RUNCMP RIH WITH CCL TOOL AND LOG TO CORRELATE STRING TO GAMMA RAY LOG - VERIFY PACKER ASSEMBLY 3 SET ON DEPTH AT 4700' - CORRELATE, CALCULATE SPACE OUT 7/3/2010 I 00:00 - 02:00 2.00 RUNCOM P RUNCMP POH WITH WIRELINE TOOL - RD WIRELINE EQUIPMENT, UNIT - I 02:00 - 03:30 1.50 RUNCOM P RUNCMP MU JOINTS TO STRING - MU TUBING HANGEk LAND STRING RUN IN LOCK DOWN SCREWS, TEST PACKOFF TO 5000 PSI- PUW 88K, SOW 78K Printed 7/29/2010 3:42:46PM North Americas ALASKA - BP Page 5 Operation Summary Report ' Common Well Name: V -225 AFE No Event Type: COM- ONSHORE (CON) Start Date: 6/28/2010 End Date: 7/4/2010 X3- 00TWZ -C (2,095,440.00 ) Project: Prudhoe Bay Site: PB V Pad Rig Name /No.: NABORS 9ES Spud Date/Time: 6/23/2010 6:30:OOPM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: V -225 Actual @80.7ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 05:30 2.00 RUNCOM P RUNCMP DROP BALL AND ROD - PRESSURE UP TUBING TO 4700 PSI TO SET PACKERS - HOLD PRESSURE FOR 30 MINUTES - BLEED TUBING TO 2500 PSI, PRESSURE ANNULUS TO 4000 PSI - HOLD PRESSURE FOR 30 MINUTES — BLEED TUBING TO 0 PSI TO SHEAR DCK SHEAR VALVE IN GLM #9 - BLEED OFF ANNULUS TO 0 PSI CIRCULATE BOTH WAYS TO VERIFY DCK SHEAR - WITNESS OF SETTING AND TESTING PACKERS WAIVED BY AOGCC REP JOHN CRISP 05:30 - 07:00 1.50 WHSUR P RUNCMP DRAIN STACK, INSTALL TWC - TEST FROM BELOW TO 1000 PSI, FROM ABOVE TO 3500 PSI 07:00 - 08:00 1.00 WHSUR P RUNCMP CLEAR FLOOR OF SLB IWIRE SPOOL, MATERIAL 08:00 - 12:30 4.50 BOPSUR P RUNCMP NIPPLE DOWN BOP 12:30 - 14:30 2.00 WHSUR P RUNCMP _NU DOUBLE MASTER VALVE DRY HOLE TREE 14:30 - 16:00 1.50 WHSUR P RUNCMP PRESSURE TEST ADAPTER FLANGE TO 5000 PSI - TERMINATE AND TEST IWIRE - TEST TREE TO 5000 PSI 16:00 - 17:00 1.00 WHSUR P RUNCMP RU DSM LUBRICATOR - LUBRICATE OUT TWC - RD LUBRICATOR 17:00 - 19:30 2.50 WHSUR P RUNCMP PUMP 160 BBLS CLEAN BRINE FOLLOWED BY 60 BBLS OF CORROSION INHIBITED BRINE AT 110 GPM, 250 PSI 19:30 - 23:00 3.50 WHSUR P RUNCMP RU LITTLE RED HOT OIL SERVICES - PUMP 77 BBLS OF DIESEL FREEZE PROTECT AT 35 GPM TO FREEZE PROTECT DOWN TO 2200'TVD - ALLOW TO U -TUBE - RD LRHOS 23:00 - 00:00 1.00 WHSUR P RUNCMP RU DSM LUBRICATOR - LUBRICATE IN BPV - TEST BPV TO 1000 PSI FROM BELOW 7/4/2010 00:00 - 05:00 5.00 RIGD P WHDTRE SECURE WELL, PREPARE RIG TO MOVE OFF WELL - INSTALL VR PLUG - FLUSH LINES WITH FRESH WATER TO CLEAR OF BRINE - CLEAN PITS - VACUUM CELLAR, UNDER ROTARY TABLE - CLEAN, VACUUM CUTTINGS BOX - RIG RELEASED AT 0500 HRS Printed 7/29/2010 3:42:46PM Nora America - ALA XA BP Page' °6 out Operation Summary Report Common Well Name: V -225 AFE No Event Type: COM- ONSHORE (CON) Start Date: 6/28/2010 End Date: 7/4/2010 X3- 00TWZ -C (2,095,440.00 ) Project: Prudhoe Bay Site: PB V Pad Rig Name /No.: NABORS 9ES Spud Date/Time: 6/23/2010 6:30:OOPM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: V -225 Actual @80.7ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:00 - 00:00 19.00 DEMOB P SURE C CONTINUE CLEANING RIG AND PREPARING FOR MOVE TO END OF PAD - BREAK APART BOP, REMOVE FROM CELLAR - RD INTERCONNECT, MOVE PITS AWAY FROM SUB - PULL SUB OFF OF WELL DRAIN FLUIDS, SECURE WIRING - DROP DERRICK - POSITION AND BUILD HERCULITE BERM - MOVE RIG ONTO BERMED AREA 7/5/2010 00:00 - 06:00 6.00 DEMOB P SURE SPOT RIG ON HERCULITE BERM AREA - PEPARE RIG FOR COLD STORAGE Printed 7/29/2010 3:42:46PM by 0 V -225 Survey Report Schlumberger (DO Survey) Report Date: June 30, 2010 - 09:43 AM Survey / DLS Computation: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 185.500 ° (True North) Field: Prudhoe Bay Unit - WOA Vertical Section Origin: 0.000 ft, 0.000 ft Structure / Slot: V -Pad / V -225 TVD Reference Datum: Rotary Table Well: V -225 TVD Reference Elevation: 80.700 ft above MSL Borehole: V -225 Seabed / Ground Elevation: 52.200 ft above MSL UWI / API #: 500292341900 Magnetic Declination: 21.798 ° Survey Name: V -225 Total Field Strength: 57643.211 nT Survey Date: 28- Jun -10 Magnetic Dip Angle: 80.926 ° Tort / AHD I DDI / ERD Ratio: 51.728 ° / 1147.325 ft / 4.797 / 0.235 Declination Date: June 24, 2010 Grid Coordinate System: NAD27 Alaska State Plane, Zone 04, US Feet Magnetic Declination Model: BGGM 2010 Location Let I Long: N 70° 19' 38.86385 ", W 149° 15' 58.64372" North Reference: True North Location Grid NIE Y/X: N 5969884.210 BUS, E 590471.120 BUS Grid Correction: 0.000 ° Grid Convergence Angle: 0.69088918 ° Total Corr Mag North->True North: 21.798 ° Grid Scale Factor: 0.9999093 Local Coord Referenced To: Well Head Comments MD Inc' Azim True TVDSS TVD VSEC AHD Closure NS EW DLS Northing Easting Latitude Longitude (ft) ( (°) (ft) (ft) (ft) (ft) (ft) (ft) (ft) 0100ft) (ftUS) (ftUS) (a) (a) RTE 0.00 0.00 0.00 -80.70 0.00 0.00 0.00 0.00 0.00 0.00 N/A 5969884.21 590471.12 70.32746218 - 149.26628992 186.00 0.39 280.02 105.30 186.00 -0.05 0.63 0.63 0.11 -0.62 0.21 5969884.31 590470.50 70.32746248 - 149.26629498 277.00 0.49 313.23 196.30 277.00 -0.31 1.31 1.29 0.43 -1.21 0.30 5969884.63 590469.90 70.32746336 - 149.26629975 365.00 0.43 316.74 284.29 364.99 -0.76 2.02 1.95 0.93 -1.71 0.08 5969885.12 590469.40 70.32746472 - 149.26630381 461.00 0.56 312.83 380.29 460.99 -1.28 2.85 2.75 1.51 -2.30 0.14 5969885.69 590468.80 70.32746631 - 149.26630860 553.00 0.61 310.83 472.28 552.98 -1.84 3.79 3.69 2.14 -3.00 0.06 5969886.31 590468.09 70.32746802 - 149.26631428 645.00 1.40 295.46 564.27 644.97 -2.51 5.39 5.28 2.94 -4.39 0.90 5969887.10 590466.70 70.32747021 - 149.26632551 716.00 1.97 289.27 635.24 715.94 -3.09 7.48 7.33 3.71 -6.32 0.84 5969887.85 590464.75 70.32747233 - 149.26634120 736.00 2.56 285.80 655.22 735.92 -3.25 8.27 8.11 3.95 -7.08 3.03 5969888.07 590464.00 70.32747297 - 149.26634732 816.00 2.88 275.06 735.13 815.83 -3.56 12.05 11.74 4.81 -10.80 0.75 5969888.69 590460.27 70.32747478 - 149.26637749 916.00 3.00 272.55 835.00 915.70 -3.40 17.18 16.67 4.95 -15.92 0.18 5969888.97 590455.15 70.32747571 - 149.26641898 1016.00 3.55 270.12 934.84 1015.54 -2.98 22.89 22.21 5.07 -21.63 0.57 5969889.02 590449.44 70.32747604 - 149.26646529 1116.00 4.30 275.14 1034.60 1115.30 -2.66 29.73 28.97 5.42 -28.46 0.82 5969889.28 590442.60 70.32747698 - 149.26652067 1144.60 4.45 279.16 1063.12 1143.82 -2.73 31.92 31.14 5.69 -30.62 1.19 5969889.53 590440.44 70.32747772 - 149.26653821 1240.36 4.44 276.65 1158.59 1239.29 -3.04 39.34 38.56 6.71 -37.97 0.20 5969890.46 590433.08 70.32748051 - 149.26659781 1336.76 4.35 277.40 1254.71 1335.41 -3.24 46.72 45.94 7.61 -45.30 0.11 5969891.28 590425.74 70.32748298 - 149.266657 1431.96 4.32 278.74 1349.64 1430.34 -3.56 53.92 53.13 8.62 -52.42 0.11 5969892.20 590418.60 70.32748574 - 149.266715 1528.14 3.93 279.69 1445.57 1526.27 -4.00 60.84 60.05 9.73 -59.25 0.41 5969893.22 590411.76 70.32748876 - 149.2667704 1623.67 3.59 280.40 1540.89 1621.59 -4.50 67.10 66.31 10.82 -65.42 0.36 5969894.24 590405.58 70.32749174 - 149.26682043 1718.77 4.60 278.37 1635.75 1716.45 -4.94 73.89 73.10 11.91 -72.12 1.07 5969895.25 590398.86 70.32749472 - 149.26687477 1814.74 4.64 275.83 1731.41 1812.11 -5.16 81.62 80.82 12.87 -79.79 0.22 5969896.11 590391.18 70.32749733 - 149.26693696 1909.43 4.84 275.01 1825.77 1906.47 -5.15 89.45 88.63 13.60 -87.58 0.22 5969896.76 590383.39 70.32749934 - 149.26700012 2005.97 4.81 275.45 1921.97 2002.67 -5.11 97.57 96.74 14.34 -95.67 0.05 5969897.40 590375.29 70.32750137 - 149.26706570 2100.85 4.86 275.81 2016.51 2097.21 -5.13 105.56 104.73 15.13 - 103.63 0.06 5969898.09 590367.33 70.32750351 - 149.26713023 2194.91 4.82 274.46 2110.24 2190.94 -5.08 113.50 112.65 15.84 - 111.53 0.13 5969898.70 590359.42 70.32750545 - 149.26719432 2290.87 4.80 274.92 2205.86 2286.56 -4.96 121.54 120.68 16.50 - 119.55 0.05 5969899.26 590351.39 70.32750725 - 149.26725935 2386.98 4.62 272.65 2301.64 2382.34 -4.73 129.44 128.56 17.02 - 127.42 0.27 5969899.69 590343.51 70.32750868 - 149.26732319 2482.29 4.73 271.77 2396.64 2477.34 -4.28 137.20 136.29 17.32 - 135.19 0.14 5969899.90 590335.75 70.32750949 - 149.26738613 2578.00 4.64 271.93 2492.03 2572.73 -3.79 145.02 144.07 17.57 - 143.00 0.10 5969900.06 590327.93 70.32751018 - 149.26744949 2673.35 4.52 270.11 2587.07 2667.77 -3.19 152.63 151.65 17.71 - 150.61 0.20 5969900.10 590320.32 70.32751056 - 149.26751121 2767.70 4.58 270.34 2681.13 2761.83 -2.50 160.12 159.09 17.74 - 158.10 0.07 5969900.04 590312.84 70.32751064 - 149.26757190 2840.93 4.77 271.26 2754.11 2834.81 -2.02 166.09 165.03 17.82 - 164.06 0.28 5969900.05 590306.87 70.32751087 - 149.26762030 9 -5/8" Csg 2891.00 5.02 270.73 2804.00 2884.70 -1.68 170.36 169.28 17.90 - 168.34 0.51 5969900.07 590302.60 70.32751107 - 149.26765494 2964.76 5.39 270.04 2877.45 2958.15 -1.08 177.05 175.94 17.94 - 175.03 0.51 5969900.04 590295.91 70.32751119 - 149.26770920 3060.58 6.31 250.59 2972.78 3053.48 1.56 186.73 185.20 16.19 - 184.49 2.27 5969898.18 590286.46 70.32750641 - 149.26778597 Pilling Olf 2009.1.726.0 Prudhoe Bay Unit - WOA\V- Pad\V- 225/v- 225 \V -225 7129/2010 3:30 PM Page 1 002 • Comments MD Inc! Azim True TVDSS ND VSEC AHD Closure NS EW DLS Northing Easting Latitude Longitude (ft) ( °) (1 (ft) (ft) (ft) (ft) (ft) (ft) (R) ( °1100ft) (ftUS) (ftUS) ( °) ( °) , 3156.34 7.60 222.99 3067.86 3148.56 8.81 198.10 194.03 9.81 - 193.78 3.70 5969891.68 590277.26 70.32748898 - 149.26786125 3252.03 9.53 204.61 3162.50 3243.20 21.32 212.24 201.40 -2.02 - 201.39 3.48 5969879.76 590269.78 70.32745665 - 149.26792301 3347.67 12.65 185.31 3256.37 3337.07 39.28 230.47 206.60 -19.66 - 205.66 5.03 5969862.07 590265.73 70.32740847 - 149.26795762 3443.88 17.55 181.24 3349.24 3429.94 64.30 255.51 211.72 -44.67 - 206.95 5.21 5969837.06 590264.74 70.32734015 - 149.26796807 3539.91 20.91 175.23 3439.90 3520.60 95.61 287.11 219.50 -76.23 - 205.84 4.06 5969805.51 590266.23 70.32725392 - 149.26795904 3634.92 24.33 172.49 3527.60 3608.30 131.37 323.64 231.12 - 112.54 - 201.87 3.77 5969769.25 590270.64 70.32715472 - 149.26792685 3730.70 28.27 170.68 3613.45 3694.15 172.54 366.07 249.27 - 154.50 - 195.62 4.20 5969727.37 590277.40 70.32704008 - 149.26787613 3825.78 30.65 170.03 3696.23 3776.93 217.67 412.82 274.77 - 200.60 - 187.77 2.53 5969681.38 590285.80 70.32691416 - 149.26781251 3920.96 33.05 171.28 3777.07 3857.77 266.22 463.05 307.97 - 250.15 - 179.63 2.61 5969631.93 590294.54 70.32677878 - 149.26774646 4017.03 33.59 171.28 3857.35 3938.05 317.37 515.82 347.63 - 302.31 - 171.62 0.56 5969579.88 590303.18 70.32663628 - 149.26768150 4112.17 33.87 172.12 3936.47 4017.17 368.68 568.65 390.68 - 354.59 - 163.99 0.57 5969527.70 590311.43 70.32649347 - 149.26761967 4207.79 34.77 172.69 4015.44 4096.14 421.19 622.56 437.14 - 408.03 - 156.87 1.00 5969474.36 590319.19 70.32634748 - 149.26756190 4302.96 35.07 173.06 4093.48 4174.18 474.35 677.04 485.86 - 462.09 - 150.11 0.39 5969420.39 590326.60 70.32619980 - 149.26750711 4398.14 34.85 173.01 4171.48 4252.18 527.60 731.57 535.80 - 516.22 - 143.50 0.23 5969366.34 590333.87 70.32605190 - 149.26745348 - 4331.04 579.67 784.94 585.39 - 569.17 -136.86 1.62 596 9313.49 590341.14 70.32590726 - 149.26739 4493.36 33.32 172.69 4250.34 4589.50 33.50 171.76 4330.60 4411.30 631.19 837.87 635.00 - 621.62 - 129.70 0.56 5969261.13 590348.94 70.32576397 - 149.26734156 4683.97 33.69 171.99 4409.29 4489.99 681.99 890.15 684.38 - 673.36 - 122.31 0.24 5969209.48 590356.95 70.32562260 - 149.26728165 4779.74 33.74 171.45 4488.95 4569.65 733.62 943.30 734.97 - 725.97 - 114.66 0.32 5969156.98 590365.23 70.32547889 - 149.26721957 4874.86 33.66 170.91 4568.09 4648.79 784.75 996.08 785.38 - 778.12 - 106.57 0.33 5969104.93 590373.95 70.32533642 - 149.26715396 4971.11 33.55 170.51 4648.25 4728.95 836.26 1049.35 836.45 - 830.69 -97.97 0.26 5969052.47 590383.19 70.32519280 - 149.26708423 5066.22 33.16 170.42 4727.69 4808.39 886.76 1101.64 886.77 - 882.26 -89.30 0.41 5969001.01 590392.47 70.32505191 - 149.26701399 5081.41 33.03 169.69 4740.42 4821.12 894.76 1109.94 894.76 - 890.43 -87.87 2.76 5968992.86 590394.00 70.32502959 - 149.26700238 5150.00 33.03 169.69 4797.92 4878.62 930.73 1147.33 930.76 - 927.22 -81.18 0.00 5968956.17 590401.13 70.32492910 - 149.26694812 Survey Error Model: ISCWSA Rev 0 ° °° 3 -D 95.000% Confidence 2.7955 sigma Survey Program: MD From MD To EOU Freq (ft) Survey Tool Type Borehole / Survey (ft) (ft) 0.000 553.000 Act Stns SLB_NSG+SSHOT V -2251 V -225 553.000 2840.930 Act Stns SLB_MWD +GMAG V -225 / V -225 2840.930 5150.000 Act Sins SLB_MWD+GMAG V -225 / V -225 Legal Description: Northing (V) Easting (X) Surface: 4637.6 FSL 1832.4 FEL S11 T11N R11E UM 5969884.210 590471.120 BHL: 3710 FSL 1914 FEL 11 T11N R11EUM 5968956.170 590401.130 Italisized marker stations are not part of the calculation for definitive survey. Final Definitive Survey Verify and Sign -off I have checked to the best of my ability that the following data is correct: Surface Coordinates and Reference Elevations Declination Information Survey Tool Codes SLB DE: Client Representative: Date: Drilling Office 2009.1.726.0 Prudhoe Bay Unit - WOA \V- Pad \V- 2251V -2251V -225 7129/2010 3:30 PM Page 2 of 2 TREE= 4- 1 /16 "CIW • WELLHEAD = FMC M ACTUATOR = Electric V -2 2 5 CUT -TO- RELEASE DESIGNS. BOTH THE BOT AND HES PKR KB. ELEV = 80.5' HAVE A 7" CUT WINDOW. BOT PKR PRESSURE RATING = BF. ELEV = 54.8' 7500 PSI. HES PKR PRESSURE RATING = 5000 PSI (4000 PSI 14.5" X 3.5" XO, ID= 2.992" I / I L ) I IS 80% OF PKR RATING). DO NOT EXCEED 4,000 PSI.*** KOP = 600' Max Angle = 35 ° @ 4303' (20" CONDUCTOR H 108' I I 2504' 1 HES X NIP, ID = 2.813" I Datum MD = 4673' Datum TVD = 4400 SS I 2891' H 9 -5/8" CSG, 40 #, L -80 BTC, ID = 8.835" DRLS DRAFT ST MD D DEV TYPE VLV LATCH PORT DATE 9 1 TV 4483 4323 33 I MMG DCR RK I 0 07/04/10 WATER INJECTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 4550 4378 33 MMG -W DMY RK 0 07/04/10 7 4619 4436 34 MMG -W DMY RK 0 07/04/10 Minimum ID = 2.75" @ 4899' 6 4654 4465 34 MMG -W DMY RK 0 07/04/10 5 4683 4489 34 MMG -W DMY RK 0 07/04/10 3 -1/2" HES XN NIPPLE 4 4716 4517 34 MMG -W DMY RK 0 07/04/10 3 4745 4541 34 MMG -W DMY RK 0 07/04/10 2 4787 4576 34 MMG -W DMY RK 0 07/04/10 17' MARKER JOINT w /RA PIP TAG H 4579' I * 1 4840 4620 34 MMG -W DMY RK 0 07/04/10 17" X 3-1/2" BOT Premier FEEDTHRU PKR, ID = 2.87" H 4512' ( — ZI ki t I I I 4524' H3-1/2" HES X NIP, ID = 2.813" I 13-1/2" RA PIP TAG H 4492' I - I • I 4530' H3 -1/2" NDPG MULTI - SENSOR SUB , ID =2.992 I MI I 'NIP, M 4638' — 7" HES MFA SINGLE FEEDTHRU PKR, ID = 2.90" I I I 4647' — 3 -1/2" HES X NIP, ID = 2.813" I F I 4648' H3 -1/2" NDPG MULTI - SENSOR SUB , ID = 2.992 I I t 4700' H 7" HES MFA SINGLE FFFnTHRU PKR, ID = 2.90" I PERFORATION SUMMARY I I I 4709' H3-1/2" HES X NIP, ID = 2.813" I REF LOG: ? ?? ■ 1 4711' H3-1/2" NDPG MULTI - SENSOR SUB , ID = 2.992 I ANGLE AT TOP PERF: 34° @ 4588' L I Note: Refer to Production DB for historical perf data SIZE SPF ZONE INTERVAL Opn /Sqz DATE a.11.Z I 4762' H7" HES MFA SINGLE FEEDTHRU PKR, ID = 2.90" I 4 -1/2" 5 OA 4588 -4630 0 06/30/10 4 -1/2" 5 OBa 4664 -4695 0 06/30/10 I I 4771' -13 -1/2" HES X NIP, ID = 2.813" I 4 -1/2" 5 OBb 4710 -4735 0 06/30/10 4 -1/2" 5 OBc 4774 -4798 0 06/30/10 MW [1 4 -1/2" 5 OBd 4828 -4882 0 06/30/10 L I 4805' H 7" HES MFA SINGLE FEEDTHRU PKR, ID = 2.90" 4814' H3-1/2" HES X NIP, ID = 2.813" I II"' I 4820' H3-1/2" NDPG SINGLE - SENSOR SUB , ID = 2.992 I —Ti ' I I 4878' H3-1/2" HES X NIP, ID = 2.813" I ' ' 4$99' —1 3 -1/2" HES XN NIP, ID = 2.750" I 13-1/2" TBG, 9.2 #, L -80 TCII, .0087 bpf, ID = 2.992" I—I 4922' �.�.�.�.�.�.�.�.�.�. 4922' H3 -1/2" WLEG, ID= 2.905" I PBTD H 5053' I 17" CSG, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" I—I 5138' I 0.0.0.0.0.4 DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 07/04/10 N9ES ORIGINAL COMPLETION WELL: V -225i 07/09/10 SV DRLG HO CORRECTIONS PERMIT No: # 209118 API No: 50- 029 - 23419 -00 SEC 11, T11 N, R11 E, 4638' FSL & 1832' FEL BP Exploration (Alaska) Page 1 of 1 Schwartz, Guy L (DOA) From: Winfree, Michael Alex (Jr.) [ Michael .A.Winfree @conocophillips.com] Sent: Monday, August 16, 2010 12:45 PM To: Schwartz, Guy L (DOA) Subject: RE: CD3 -302A and CD3 -301A Attachments: CD3 -302A Drilling Report 04- 02- 2010.pdf p -7 Z ,' -- O 3 Guy, Testing of the BPV from below, before nippling down the tree, was only requested on the CD3 -302A well. After reviewing the daily drilling reports for CD3 -302A, it is apparent there was an oversight documenting the pressure test from below on the BPV before nippling down the tree. Per your request for the pressure test, the procedure change was forwarded to the rig as an addendum to the drilling program. I have verified with the Company Man that the BPV was pressure tested from below. The Wellview data base has been updated and a copy of the report has been attached for your records. Thanks, -Mike Mike A. Winfree 907.265.6820 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Friday, August 06, 2010 9:24 AM To: Winfree, Michael Alex (Jr.) Subject: CD3 -302A and CD3 -301A Mike, As per our conversation yesterday can you verify that the BPVs or TWC were tested from below before the tree was pulled and BOP nippled up (on both CD3 -302 and CD3 -301) . The drilling reports were not clear on whether this was done or not. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 8/16/2010 Security Level: AK Development Daily Drilling Report £; CD3 -302 Conacc�Ptzi[ lips Report Number: 1 Rig: DOYON 141 Report Date: 4/2/2010 AFEzypa x. _ ;;:' 'letNvrlwo .. _ 10274272 7,825,000.00 7,825,000.00 Weilbore 'Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3 -302 Development FIORD KUPARUK -5.02 1.0 0.0 0.0 Daily Mud Cost Cumulative Mud Cost Dairy Cost Total Cumulative Cost 26,422.92 26,422.92 201,273.92 201,273.92 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 4/2/2010 4/8/2010 20.91 21.03 - 0.12 4/23/2010 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) SURFACE, 2,678.5ftKB Ops and Depth cl Morning Report 24hr Forecast Test BOPE N/U BOPE, Test BOPE, POOH w/ 4 -1/2" Tbg, Run Cmt retainer to 5782' on 4" DP. Last 24hr Summary Move rig f/ CD3 -301A to CD3 -302A, Rig up, Accept rig @ 1600: hrs 4/2/10, Pull BPV, Rig pump lines to kill well, Pump 50 bbls fresh water down ann. taking returns out tbg to recover diesel out tbg, Switch & Pump 250 bbls at 3 bpm 11.2 ppg kill mud down tbg holding back pressure according to kill schedule, Monitor well - Static, Blow down pump lines, Set BPV, N/D Tree, Install Blanking plug, N/U BOPE. General Remarks Weather Head Count No Accidents - No Spills Temp 6 WC -12 / Overcast / Wind N @ 15 38.0 mph Larry Hill, Rig Supervisor Rig Supervisor Mike Thornton, Rig Supervisor Rig Supervisor Mike Winfree Jr, Drilling Engineer Drilling Engineer Time Lbg` ;Star{ Ertl Our z Tl Depth Start Depth End Time. Tina '(hrs) _ Phase . , . Op Caia A�tM y Co i 1 17,19(i Ttk(G�de . Trbt Ci Ss ". ° {11KB) tR�} . W , flperatian ti 00 :00 06:00 6.00 MIRU MOVE DMOB P Rigged down and moved modules off well. Sub off well @ 0600. 06:00 12:00 6.00 MIRU MOVE MOB P Prepared location and laid rig matts, Spot Sub over CD3 -302. 12:00 13 :30 1.50 M1RU MOVE MOB P Spot Pits, Pump room, Motor room, Boiler room. 13:30 14:45 1.25 MIRU MOVE MOB P Spot Rock Washer & Pipe shed. 14:45 16:00 1.25 MIRU MOVE RURD , P Rig up & work on rig acceptance check list. Accepted Rig @ 16:00 hrs 4/2/10. 16:00 17:45 1.75 SLOT DRILL RURD P Pull BPV, Rig pump lines to kill well to well & tiger tanks.. 17:45 21:30 3.75 SLOT DRILL CIRC P PJSM, Test lines to 2000 psi, Pump 50 bbls fresh water down annulus at rate of 3 bpm holding 900 psi on choke to recover diesel out tubing, Switch and pump 250 bbls 11.2 ppg kill mud at rate of 3 bpm hold back pressure according to kilt sheet, Monitor well - Static. 21:30 22:00 0.50 SLOT DRILL RURD P Blow do line b4igg nk, Rig down • mp lines. 22:00 22:30 0.50 SLOT WHDBOP NUND p Set BPV and test from below. 22:30 23:30 1.00 SLOT WHDBOP NUND P PJSM, Nipple down Tree, In - blanking • • • Plu• contro • •p - up Adapter flange. 23:30 00:00 0.50 SLOT WHDBOP NUND P PJSM, Nipple up BOPE. Mud CtreckkData 43 rN ,�� �._ --,., Y F € al¢ z (30m} tiTHP Fifl Dersslt]{ Sefli Solids Cart Dens (ilga1)' Vw AilVk €alr(dj) , (Ibf11OOfL' E00110fO . , g ff40 ) -^ (ibfliOO MBT (9Kbbl)- tmL/3Or pH 16pAltylw. LSND 5,865.0 11.20 48 19.0 22.0 9.0 13.0 14.000 0.0 0.0 9.2 68.0 11.8 Latest BOP Test Data 3/12/2007 Tested Hydril to 250 & 3500 -All other componets to 250 & 5000 psi AOGCC waived witnessing of test Page 1/2 ' Report Printed: 8/16/2010 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, August 12, 2010 9:36 AM To: 'Johnson, Vern' Subject: RE: ODSN -16 Packer test pressure (PTD 210 -053) Vern, Pressure testing the inner annulus to 2500 psi after running the completion is acceptable to the Commission. I believe this well has the 7" casing run back (tie back liner) to the surface and will have been tested to a higher pressure (3500 psi ) before drilling out the horizontal 6" OH section. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Johnson, Vern [mailto:Vern.Johnson @pxd.com] Sent: Wednesday, August 11, 2010 10:29 PM To: Schwartz, Guy L (DOA) Subject: ODSN -16 Packer test pressure Guy As discussed this afternoon, we are planning to reduce the planned annulus test pressure on our production packer from 3500 psi (as described in the permit to drill) to 2500 psi. The reasons we would like to reduce the test pressure are that 1) there is no technical need to test to more than 2500 psi, and 2) some of the electrical connectors for the ESP completion are rated to 5000 psia; and the hydrostatic pressure combined with the test pressure approaches the pressure rating. Let me know if you have any questions or need further information. Vern Johnson Drilling Superintendent Pioneer Natural Resources Alaska 907 - 343 -2111 office 907 - 575 -9430 cell Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 8/12/2010 07/27/10 SchlumYener NO. 5567 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambill Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job 8 Log Description Date BL Color CD P2 -16 BB6M- 00027, LDL ` .. — .. 2 .. » 07/20/10 1 1 F -03A AYKP -00096 Ma NM A •• ■ 3 - 1 IIICMCIIIIIMIIIIIIIIMIIIIIUIIMIMIIIIEMMIIIIIIMIIIIIIIIIMIIIIII V -225 BBKA -00039 MEIMIPYZItd Z+ 07/01/10 -00 == S -100 BCZ2 -00014 USIT : ♦ • '. " - 07/14/10 1 1 2- 58/S -09 BCZ2 -00016 LDL ^ /j ' 1f! Wt ' X16" 07/17/10 1 1 1- 15/P -25 AYKP -00094 LDL . KQIAPVjIYrAINIIMtl�' 0 -0 -- BCRD -00036 1111511111116:f 111:11iM7/li`%lI'i IIEMEMIIIIIIIIMINIUMIMMINIIIIIIIIINIMIIIMIll 01-22B AZ2F -00042 MCNL r1 A �Lj 05/ 1 1 -- lc B -20 AY1M -00042 RST ) L 05/07/10 1 1 04 -20 BCRJ -00020 RST 05/30/10 1 1 AYKP -00082 IMIEri rr ♦fis'LL 06/02/10 0 -IMEIIIIIII-- 05-32A B8K5 -00040 . _ ♦ -• 0— �� 05/19/10 1 H -25 BCRD -00017 if,,a LL1e 05 /10/10 0_ 1 AVYO -00063 - '' ' 0 -0- E IMMIIIIIMIIIIMIIMIMIIIIMMIIIIIMMII - =MIMI - - - -- 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 JUL. 2 2010 Anthorage ib all a , _ -__, ,,,--- ,----) ri ' - r li 'r E k\r /Ay i 1 1 /A\ H / \ (,,, it 0 'i 1 r UT /. EL if .tu u\,, SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W, 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. Robert Tirpack Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519 Re: Prudhoe Bay Field, Orion Schrader Bluff V -225 BP Exploration (Alaska), Inc. Permit No: 209 -118 Surface Location: 4638' FSL, 1832' FEL, SEC. 11, T11N, R i 1 E, UM (As staked) Bottomhole Location: 3733' FSL, 1921' FEL, SEC. 11, 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) 659 -3607 (pager). Sincerely, CP /1/<'' Daniel T. Seamount, Jr. Chair DATED this day of October, 2009 cc: Department of Fish 85 Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA C � IVED4 ALASI�IL AND GAS CONSERVATION COMM 141110N /O - / -d9 PERMIT TO DRILL SE P 2 9 2009 20 AAC 25.005 1a. Type of work: lb. Proposed Well Class: ❑ Development Oil ❑ Service - Winj ❑ Single Zone 41 $ f essiConsabansissw ' ® Drill ❑ Redrill ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ® Multiple Zone ❑ Coalbed 9 Hydrates ❑ Re -Entry ❑ Exploratory ® Service - WAG ❑ Service - Disp Wile Gas 2. Operator Name: 5. Bond: ® Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 V -225 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 - 6612 MD 5142' TVD 4866' Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Schrader Bluff Surface: ADL 028240 4638' FSL, 1832' FEL, SEC. 11, T11N, R11 E, UM (As Staked) Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4065' FSL, 1961' FEL, SEC. 11, T11N, R11 E, UM December 20, 2009 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 3733' FSL, 1921' FEL, SEC. 11, T11N, R11E, UM 2560 9,180' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: —82' feet 15. Distance to Nearest Well Open Surface: x- 590471 y- 5969884 Zone ASP4 GL Elevation above MSL: — feet to Same Pool: 597' 16. Deviated Wells: Kickoff Depth: 600 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 35 degrees Downhole: 2115 Surface: 1660 18. Casing Program: Specifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD TVD (including stage data) 42" 20" 129.5# X - 65 Weld 80' Surface Surface 80' 80' —260 sx Arctic Set 12 -1/4" 9 -5/8" 40# L -80 BTC 2869' Surface Surface 2869' 2862' 460 sx Arcticset Lite. 40 sx Class 'G' 8 -3/4" 7" 26# L -80 TC -II 4061' urface Surface. 4061' 3982' fSee Below) 8 -3/4" 7" 26# L -80 BTC -M 1081' 4061' 3982' 5142' 4866' 281 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured): Casing Length, Size Cement Volume MD ND Conductor / Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: ❑ Property Plat ❑ BOP Sketch ® Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report C ■ ∎ 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 Mark Staudinger, 564 -4337 Printed Name Robert Tirpack Title Engineering Team Leader / Prepared By Name/Number Signature /` � Phone 564 -4161 Date 712 t� // f' Terrie Hubble, 564 -4628 Commission Use Only Permit To Drill API Number: Permit A 7?s t S ee cover letter for Number: .01709/jr 50 Oa9a3dIi9oo� / � ' other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coal. • methane, gas hydrates, or gas contained shales: V Other: y000 Psi g D feS1 Samples Req'd: ❑�es "No Mud Log Req'd: 0 Yes g Z Soo / 15.6 G Ahn..A4.r (es - Con ." ) H Measures: I Yes ❑ No Directional Survey R I Yes ❑ No — n L U. (-1'i/4,I- 0 Per-.e.?'le‘. rh wccorJ 14-V AIOZGIA M Z oh Ap�Ora dK &o[�h q- re ,,„ . , cc�1oi�w�r < /doc G I (Z 6 AA ZS. o 33C;J ) / Grl �) > - -• • VED BY THE COMMISSION �� M �+ v r Date w / COMMISSIONER Form 10-401 Revised 07/200 ,q This perm IRdiftinNithAt the date of approval (20 AAC 25.005(g)) Submit In Duplicate • Well Name: V -225i Drill and Complete Plan Summary Name Position Office Home Cell Mark Staudinger Drilling Engineer 5733 929 -5850 440 -7403 Priya Maraj Geologist 4181 522 -0353 748 -6895 Bob Dawson Ops Geologist 5264 345 -3359 242 -2391 Mike Warren Pad Engineer 4306 258 -5537 250 -1652 Type of Well (service / producer / injector): 1 Injector Surface Northing Easting Offsets TRS Location 5,969,884 590,471 642' FNL / 1832' FEL 11N, 11E, 11 Northing Easting TVDss Offsets TRS Target 5,969,310 590,350 -4310 1215' FNL / 1961' FEL 11 N, 11 E, 11 Locations 5,969,160 590,370 -4525 1365' FNL / 1943' FEL 11N, 11E, 11 Bottom Northing Easting TVDss Offsets TRS Location 5,968,979 590,394 -4784 1546' FNL / 1921' FEL 11 N, 11 E, 11 API NUMBER: I TBD I ( Rig: 1Nabors 9ES I Estimated Start Date: 1 12/20/2009 I Operating Days to complete: 1 12 I MD: 1 5142' 1 ( TVD: 1 4866' I 1 RT /GL: 1 28.5'/53.5' 1 RTE: 1 82.0' Well Design: Grassroots Schrader Bluff Injector 3 1 /2" tbg, 9.2# L80, TC -II, multi - packers, zonal injection I Objective: 1 Multi -zonal injector into Schrader Bluff OA, OBa, OBb, OBc and OBd sands I Directional Plan: Version: Schlumberger P3 KOP: 600' MD, build 1.5/100 Maximum Hole Angle: 35° Close Approach Wells: All wells pass major risk criteria. Reference anti - collision report Nearest well within Pool V -225i is 597' from V -02. Distance to Nearest Property 9,180' to PBU boundary Line: V -225i Permit Application Page 1 S • Wells within 1 /4 mile of this injection well: Well Name Dist, Ft. Annulus Integrity Comments V -02 597' 2nd stage cmt. 4903- 3440ss calculated with 30% excess. 700'ss above top Na, and 231'ss below base OBf. No annular p communication. A °? . V -111 PB1 772' Plug from 3892 to 4913 ss. Calculated TOC 250'ss above top Na with 30% excess. Base plug 240'ss below base OBf. V -111 898' Calculated TOC 660' ss above top Na with 30% excess. No annular communication V -204 937' Calc TOC with 30% excess is 850ss above top Na sand. No annular communication. Distance cited is that to cemented heel section of well at top of pool (SB_Na) V -205 1132' 60 bbl losses while cementing - monitoring recommended. No annular communication. Distance to cemented heel section of well at top of pool (SB_Na) V -03 1152' 2nd stage from 4890 to 3506'ss. Calculated TOC 660 ss above Na sand. Base 190' ss below base OBf. No annular communication. Logging Program: Surface Interval Drilling, MWD: GR Open Hole: None Cased Hole: None Intermediate Interval Drilling, MWD: N/A Open Hole: N/A Cased Hole: N/A Production Interval Drilling, MWD: GR, RES, NEU, Azimuthal Density PWD Open Hole: None Cased Hole: USIT (Primary Depth Control mode) Mud Program: 12 1/4" Surface Hole: Fresh Water Drilplex Mud Density Funnel Viscosity LSYP Yield Point API FL 2H (PPM (seconds) (2x3 -6 rpm) (Ib /100ft) (mis /30min) Spud to Base 8.5 — 9.5 60 -120 (for reference 40 -60 50 - 70 NC 10.8 -11 PF only. Fluid should be run off LSYP) Base PF to 8.5 - 9.5 Same 30 -50 55 -60 NC 10.8 -11 TD 8 3 /4" Production Hole: LSND Interval Density YP PV pH API (ppg) Fluid Loss Csg Shoe to TD 9.4 -9.6 18 -24 8 -18 9 -10 <6.0 V -225i Permit Application Page 2 • • Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Connection Length Top Btm Tbg O.D. MD/TVD MD/TVD RTE 42" 20" 129.5 X -65 WLD 80' GL 80'/80' 12 1 /4" 9' /8 40 L -80 BTC 2869' GL 2869' / 2862' 8 3/4' 7" 26 L -80 TC -II 4061' GL 4061' / 3982' 8 3 /d' 7" 26 L -80 BTC -M 1081' 4061' / 3982' 5142' / 4866' Tubing 3 9.2 L -80 TC -Il 4954' GL 4954' / 4713' Comments: I Tbg crossover to 4 just below tree Integrity Testing: Test Point Depth Test Type 9 5 /8 ' Surface Casing 20' — 50' from surface shoe LOT Cement Calculations: Surface Casing: Casing Size 19'/ Basis: Lead: Open hole volume +250% excess in permafrost and 40% excess below permafrost. Port collar used if necessary. Lead TOC: Surface Tail: Open hole volume + 40% excess + 80' shoe track. Tail TOC: 1000' MD above the casing shoe (1869' MD) Total Cement Volume: Lead 365 bbl / 2047 ft' / 460 sks of Arctic Set Lite at 10.7 ppg and 4.45 cf /sk Tail 84 bbl / 472 ft / 407 sks of Class 'G' at 15.8 ppg and 1.16 cf /sk Production Casing: Casing Size I 7 " Basis: Lead: None Planned Lead TOC: N/A Tail: Open hole volume with 30% excess and 80' shoe track volume, ID 6.276" Tail TOC: 4061' (500' MD above Ma) Total Cement Volume: Lead None Planned Tail 58 bbl / 326 ft° / 281 sks of Class 'G' at 15.8 ppg and 1.16 cf /sk V -225i Permit Application Page 3 • • Formation Markers: Est. Commercial Formation Hydrocarbon Est. Pore Tops Uncertainty Bearing Press. Est. Pore Press. Formation (TVDss) (feet) (Yes /No) (Psi) (ppg EMW) G1 -240 +1 -50' No 108 8.7 SV6 -880 +1 -50' No 396 8.7 SV5 -1540 +/ -50' No 693 8.7 SV4 -1670 +/ -50' No 752 8.7 Base Permafrost -1700 +/ -50' No 765 8.7 SV3 -2055 +/ -50' Gas hydrates 925 8.7 SV2 -2230 +/ -50' Gas hydrates 1004 8.7 SV1 -2555 +/ -50' Gas hydrates 1150 8.7 Surf Casing Pt - 2780 UG4 -2850 +/ -50' Thin Coal 1283 8.7 UG4A -2880 +/ -50' Heavy Oil 1296 8.7 Thin Coals; Heavy UG3 -3225 +/ -50' Oil 1451 8.7 UG1 -3720 +/ -50' Heavy Oil 1674 8.7 Fault #1 - V Pad +/ 150' Fault - 3870 M.D. UG_Ma -3890 +/- 30' No, Wet 1751 8.7 UG_Mb1 -3935 +/- 30' No, Wet 1771 8.7 UG_Mb2 -4015 +/- 30' Yes, Heavy Oil 1807 8.7 UG_Mc -4065 +/- 30' No, Wet 1829 8.7 SB_Na -4150 +/- 30' No 1868 8.7 SB_Nb -4172 +/- 30' No 1877 8.7 SB_Nc -4205 +/- 30' Yes 1892 8.7 SB_Ne -4211 +/- 30' Yes 1895 8.7 SB_OA -4310 +/- 30' Yes 1610 -1650 7.2 -7.4 SB_OBa (upper lobe) - 4375 +/ 30' Yes 1540 - 1620 6.8 - 7.1 SB_OBa (lower lobe) -4390 +/- 30' Yes 1650 -1740 7.4 -7.6 SB_OBb -4415 +/- 30' Yes 1815 -1885 7.9 -8.2 SB_OBc -4470 +/- 30' Yes 2085 -2115 9.0 -9.1 SB_OBd -4520 +/- 30' Yes 1885 -1940 8.0 -8.3 SB_OBe -4585 +/- 30' Yes 2063 8.7 SB_OBf -4625 +/- 30' Yes 2081 8.7 Base _ SB -4675 +/- 30' No 2104 8.7 T.D. in Colville Shale -4784 No 2153 8.7 V -225i Permit Application Page 4 • Well Control: 12 1 /4" holes will be drilled with diverter. The 8 3 A" intermediate hole will use well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Annular preventer will be tested to 2500 psi. Rams will be tested to 4000 psi. The BOP test frequency will be conducted on a 14 day frequency, with a function test every 7 days. Except for significant operational issues that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- • Maximum anticipated BHP: 2115 psi @ 4552' TVD, 9.1g EMW • Maximum surface pressure: 1660 psi CO surface (based on BHP and a full column of gas from TD @ 0.10 psi /ft) • Planned BOP test pressure: • Annular Preventer 250 / 2500 psi • Rams 250 / 4000 psi • Planned completion fluid: 9.6 ppg brine / 6.8 ppg diesel (5142' MD, also TD) Kick Tolerance / Integrity Testing Summary Table I Casing and Casing Test Maximum Mud Weight Exp Pore LOT/ Interval Pressure Influx Press FIT Volume 9 Surface 3500 psi 50 BBLS 9.4 9.1 LOT Casing (assuming 12.6 LOT) 7" Production 4000 psi NA NA NA NA Casing Disposal: • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS -04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. Variance Request: To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling / surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line. V -225i Permit Application Page 5 • • V -225i - Drill and Complete Procedure Summary Pre -Rig Work: 1. Install Cellar Box and set 20" Conductor to +/- 108'. 2. Weld an FMC landing ring for the FMC Gen 5 wellhead on the conductor. 3. Level the pad and prepare location for rig move. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up and function test diverter. 3. Build Spud Mud or Drillplex and pick up enough 4" drillpipe to TD surface hole. 4. MU 12 - drilling assembly with MWD /GR and directionally drill surface hole to the base of the permafrost. Perform wiper trip, then drill to TD. The surface hole TD will be approximately 80' TVD below the top of the UG4. 5. CBU as needed, then POH for casing. 6. Run and cement 9- surface casing. A TAM port collar may be run at 1000' as a contingency. 7. ND diverter and NU casing / tubing head. NU BOPF and test to 4n0nps, Give the AOGCC 24 hrs notice prior to testing. 8. Make up 8 -3/4' drilling BHA with MWD /GR /Res /Azi- Den /Neu and RIH to float collar. Test 9 -5/8" casing to 3500 psi for 30 minutes (ensure cement has reached at least 500 psi compressive strength prior to testing). 9. Drill out shoe track and displace well to LSND drilling fluid. Drill 20' of new formation and perform LOT. 10. Drill ahead to production hole target TD ( -250' below OBe). CBU, back - ream /MAD Pass until inside surface casing, then POH to run casing. 11. Change to 7" rams and test prior to running casing. 12. Run and cement the 7" production casing. Displace with brine. Pressure test casing to 4000 psi for 30 minutes at plug bump. 13. Install and test 9 5/8 x 7" pack -off. Establish injection rate in the 7" x 9 -5/8" annulus. Change 7" rams back to Variable Bore Rams. 14. Freeze protect the 7" x 9-%" annulus. Confirm 500 psi cement compressive strength prior to freeze protecting. 15. PU DPC perf guns and RIH w/ -147' of 4.5" Power Jet 4505 5 -spf perf guns with Anadrill LWD GR for gun correlation. 16. Space out perf guns by utilizing GR and LWD log. Confirm cement compressive strength is at least 1000 psi before firing. Perforate OA, OBa, OBb, OBc, and OBd. POH, laying down DP and guns. 17. RU Schlumberger E -line. RIH with gauge ring and junk basket to recover any pert debris. Repeat until clean to at least 50' below the bottom perforation. 18. Ru n USIT log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. 19. Run the 3 -'h ", 9.2# completion with a 7" x 3 -1" straddle packer assembly, I -wire, gauges, and injection mandrels. Torque turn TC -II threaded tubing. Top packer must be within 200' of OA perfs. 20. RU E -line and run GR /CCL to space out completion. Correlate GR /CCL to SLB real -time LWD logs. 21. Run in lockdown screws and pressure up the tubing to 4000 psi to set packers and test for 30 minutes. Bleed tubing to 2500 psi, then test IA to 4000 psi for 30 minutes. Bleed down IA, then tubing. Notify AOGCC 24 hrs prior to testing tubing and IA. 22. Shear the DC valve and pump both ways to confirm circulation ability. 23. Install and test TWC. Nipple down the BOPE. Nipple up and test double master valves to 5000 psi. RU DSM and pull TWC. 24. Freeze protect the well to 2200' TVD by first pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ Hot Oil truck, taking clean brine returns to surface. Allow diesel to u -tube into tubing. 25. Install BPV in tubing hanger. Install all annulus valves and secure the well. Ensure that T /IA/OA are protected with two barriers. 26. RDMO. Post -Rig Work: V -225i Permit Application Page 6 • • 1. Install tree with electric SSV actuator. 2. Pull BPV. 3. MIRU slickline. Pull the ball and rod / RHC plug. 4. Pull shear valve from top mandrel and replace with a dummy GLV. 5. Pull dummy valves from injection mandrels and replace with injection valves. 6. Pull VR plug. 7. Install wellhouse and flowlines. V -225i Permit Application Page 7 • 1 Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures: Interval Psi (EMW) TVDss MD Schrader Bluff 1540 -2153 4310- 4562 - Sands (6.8 -9.1) 4625 4947 II. Hydrates and Shallow gas: A. Free gas and /or gas hydrates may likely be present in the SV4 through the SV1 surface hole below the Permafrost base. Use standard operating procedures for hydrates, if encountered. Set surface casing below deepest SV1 sand hydrate zone to isolate gas bearing intervals behind cemented pipe in surface hole from intermediate hole section. III. Running Gravels: A. Unconsolidated sand, gravel, & cobbles and thawing permafrost could impede well angle build and casing running through permafrost. Keep moderate to low build angles until out of permafrost section. Keep flow rates low. Hazards include wood and cobbles, lost circulation, and tight hole problems while drilling and running casing. See V Pad Data Sheet for details. IV. Faults Formation Where MD Throw Encounter Fault Intersect tvdss Est. Throw Direction Uncertainty Fault #1 - V -Pad Fault in Ugnu M Sand Interval 4,025 -3870 80' to 120' Southwest +/- 150' M.D. V. Lost Circulation / Breathing: A. The V -Pad Fault has been penetrated by nearly all wells drilled from V -Pad. Lost circulation is not expected from this fault. VI. Kick Tolerance / Integrity Testing: A. The 9 5 /8 " casing will be cemented to surface using a port collar at 1000' if necessary. The 7" casing will be cemented 500' MD above the Ma (692' below 9 -5/8" surface shoe). Kick Tolerance / Integrity Testing Summary Table Casing and Casing Test Maximum Mud Weight Exp Pore LOT / Interval Pressure influx Press FIT Volume 9 Surface 3500 psi 50 BBLS 9.4 9.1 LOT Casing (assuming 12.6 LOT) 7" Production 4000 psi NA NA NA NA Casing VII. Heavy Oil A. Heavy oil is expected in the UG4A, UG3, UG1, and UG_Mb2 intervals which could result in plugging of shaker screens. Follow established operating practices for drilling in heavy oil zones. V -225i Permit Application Page 8 • I VIII Hydrogen Sulfide A. All V Pad gas lift wells are expected to have H levels in the 20 to 300 ppm range; result of PBU gas lift gas. This site should be treated as an H site with all the required precautions. Date of Well Name H2S Level Reading #1 Closest SHL Well H2S Level V -119 NA #2 Closest SHL Well H2S Level V -113 30 ppm 3/11/2008 #1 Closest BHL Well H2S Level V -02 20 ppm 12/5/2008 #2 Closest BHL Well H2S Level V -205 40 ppm 12/4/2008 Max. Recorded H2S on Pad /Facility V -117 300 ppm 4/3/2007 Other Relevant H2S Data: V-119 is an injector. (H2S alarms from rigs, etc.) V - 117 last reading 150 ppm 1/25/09. CONSULT THE V PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION V -225i Permit Application Page 9 ■ TREE = 4-1/16" CIW SAFETY NOTES: *** HES PKR @ 4472' IS "PULL TO WELLHEAD = FMC RELEASE' BUT CAN BE RELEASED BY PRESSURE DO ACTUATOR = Bectric V -2 5 i Proposed GEED 4 300 PSI. TEST PRESSURE PKR RATING _ K B. ELEV = = 5 PSI (4332 PSI IS 80% OF PKR RATING)*** BF. ELEV = KOP 600' 120" CONDUCTOR H 108' I ) N 27' I - - 1/2" X 3 -1/2" XO, ID = 2.992" I Max Angle = 35 deg Datum MD = , I xxxx' H3 -1/2" HES X NIP, ID = 2.813" I Datum ND = I 2869' 1-19-5/8" CSG, 40 #, L -80 BTC, ID = 8.835" I GAS LIFT MANDRELS H I - STI MD I ND DEV TYPE I VLV 1LATCH1PORT1 DATE 7" CSG, 26 #, L -80 TCII XO TO L -80 BTGM 4062' �-c 10 MMG WATER INJECTION MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 9 MMG -W 8 MMG -W Minimum ID = 2.75" @ 4932' N 7 MMG-W 3 -1/2" HES XN NIPPLE 6 MMG -W 5 MMG -W 4 MMG -W 3 MMG -W 2 MMG -W 17" X 3 -1/2" HES SINGLE FEEDTHRU PKR, ID = 2.965" H 4472' I — ■ E, 1 MMG -W 13-1/2" RA PIP TAG H xxxx' I__ . _ I 4486' H 3 -1/2" NDPG MULTI - SENSOR SUB , ID = 2.992 I IT MARKER JOINT w /RA PIP TAG H xxxx' I- -* 1- -- I 4506' H3-1/2" HES X NIP, ID = 2.813" I — I M1 `3 1 4616' — 7" X 3 -1/2" SINGLE FEEDTHRU PKR, ID = 2.965" MR I 4620' — 3 -1/2" HES X NIP, ID = 2.813" - - I 4626' 1-13-1 /2" NDPG MULTI - SENSOR SUB , ID = 2.992 I �� :3 I 4680' I--17" X 3 -1/2" SINGLE FEEDTHRU PKR, ID = 2.965" I I 4684' I-1 - 1 /2" HES X NIP, ID = 2.813" I I 4690' H3 -1/2" NDPG MULTI - SENSOR SUB , ID = 2.992 I IMIP PERFORATION SUMMARY IL M. - I 4744' H7" X 3-1/2" SINGLE FEEDTHRU PKR, ID = 2.965" I g - I 4748' H3-1/2" HES X NIP, ID = 2.813" I SIZE SPF ZONE INTERVAL Opn /Sqz DATE L I 4 -1/2" 5 OA 4 -1/2" 5 OBa M/ : II -I 4808' I- I 7" X 3 -1/2" SINGLE FEEDTHRU PKR, ID = 2.965" I 4 -1/2" 5 OBb - I 4821' H3 -1/2" NDPG SINGLE-SENSOR SUB , ID = 2.992 I 4 -1/2" 5 OBc 4 -1/2" 5 OBd I -- - -I 4851' 1-13-1/2" HES X NIP, ID = 2.813" I Mr 11- __ _ I 4911' H3 -1/2" HES X NIP, ID = 2.813" I I- - -- 1 4932' H3-1/2" HES XN NIP, ID = 2.750" I 13-1/2" TBG, 9.2 #, L -80 TCII, .0087 bpf, ID = 2.992" H 4954' I -- -__ __ ■ I 4953' H3 -1/2" WLEG, ID = 2.992" I PBTD H 5059' ( v i ■ 17" CSG, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" H 5142' I - DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 06/25/09 MIS PROPOSED COM PLEFION WELL: V -225i PERMIT No: API No: 50-029 - SEC 11, T11 N, R11 E, xxxx' FSL & xxxx' FEL BP Exploration (Alaska) • bp 4) V -225 (P3) Proposal Schiumberger Report Date: June 26, 2009 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 188.270° Field: Prudhoe Bay Unit - WOA /� Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: V -Pad I Plan V Slot (S -D) • • stU y ND Reference Datum: Rotary Table F S ea Bed Well: Plan V -225 (SD) eas ND Reference Elevation: 82.00 ft relative to MSL Borehole: Plan V -225 1 Ground Level Elevation: 53.50 ft relative to MSL UWIIAPI #: 50029 Magnetic Declination: 22.401° Survey Name 1 Date: V -225 (P3) / June 22, 2009 Total Field Strength: 57694.530 nT Tort I AHD 1 DDI 1 ERD ratio: 42.213°11152.29 ft / 4.711 10.237 Magnetic Dip: 80.872° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: June 22, 2009 Location Lat!Long: N 7019 38.86571985, W 14915 58.64424189 Magnetic Declination Model: BGGM 2008 • Location Grid NIE YIX: N 5969884.400 ftUS, E 590471.100 ftUS North Reference: True North Grid Convergence Angle: +0.69088905 Total Corr Mag North -> True North: +22.401° Grid Scale Factor: 0.99990930 Local Coordinates Referenced To: Well Head Measured Azimuth Vertical NS EW Mag I Gray Directional Comments Inclination Sub -Sea ND ND DLS Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty (ft) I (deg) I (deg) I (ft) (ft) (ft ) (ft ) (ft) (deg) I (deg /100 ft) Index I (ftUS) (ftUS) RTE 0.00 0.00 287.90 -82.00 0.00 0.00 0.00 0.00 - -- 0.00 0.00 5969884.40 590471.10 0 19 38.86571985 9 15 58.64424189 WRP 28.50 0.00 287.90 -53.50 28.50 0.00 0.00 0.00 - -- 0.00 0.00 5969884.40 590471.10 0 19 38.86571985 9 15 58.64424189 G1 327.00 0.00 287.90 245.00 327.00 0.00 0.00 0.00 - -- 0.00 0.00 5969884.40 590471.10 0 19 38.86571985 9 15 58.64424189 KOP Bld 1.5/100 600.00 0.00 287.90 518.00 600.00 0.00 0.00 0.00 287.90M 0.00 0.00 5969884.40 590471.10 0 19 38.86571985 9 15 58.64424189 Cry 2/100 700.00 1.50 287.90 617.99 699.99 -0.22 0.40 -1.25 290.62M 1.50 0.29 5969884.79 590469.85 0 19 38.86967648 9 15 58.68060234 800.00 3.50 290.62 717.89 799.89 -1.09 1.88 -5.35 291.13M 2.00 1.30 5969886.21 590465.73 0 19 38.88419608 9 15 58.80030242 End Cry 858.77 4.67 291.13 776.50 858.50 -2.01 3.37 -9.26 - -- 2.00 1.66 5969887.66 590461.80 0 19 38.89888809 9 15 58.91444265 SV6 967.62 4.67 291.13 885.00 967.00 -3.98 6.57 -17.53 - -- 0.00 1.94 5969890.76 590453.50 0 19 38.93032136 9 15 59.15586369 EOCU 1529.49 4.67 291.13 1445.00 1527.00 -14.16 23.07 -60.21 - -- 0.00 2.48 5969906.74 590410.62 0 19 39.09256364 49 16 0.40196838 SV5 1624.81 4.67 291.13 1540.00 1622.00 -15.89 25.86 -67.45 - -- 0.00 2.53 5969909.45 590403.35 0 19 39.12008665 49 16 0.61336169 SV4 1755.24 4.67 291.13 1670.00 1752.00 -18.26 29.69 -77.36 - -- 0.00 2.59 5969913.16 590393.39 0 19 39.15774960 49 16 0. 99 SV3 2151.56 4.67 291.13 2065.00 2147.00 -25.44 41.33 - 107.47 - -- 0.00 2.73 5969924.43 590363.15 0 19 39.27218624 49 16 1.7 070 SV2 2327.14 4.67 291.13 2240.00 2322.00 -28.62 46.49 - 120.81 - -- 0.00 2.78 5969929.42 590349.75 0 19 39.32288564 49 16 2.17100144 SV1 2648.21 4.67 291.13 2560.00 2642.00 -34.44 55.91 - 145.20 - -- 0.00 2.86 5969938.55 590325.25 0 19 39.41559251 49 16 2.88306818 Cry 3/100 2815.54 4.67 291.13 2726.78 2808.78 -37.48 60.82 - 157.92 271.70M 0.00 2.90 5969943.31 590312.48 0 19 39.46390860 49 16 3.25417949 9 -5/8" Csg Pt 2868.91 4.02 271.70 2780.00 2862.00 -37.75 61.66 - 161.81 258.26M 3.00 3.04 5969944.10 590308.57 0 19 39.47215925 49 16 3.36790587 2900.00 3.89 258.26 2811.01 2893.01 -37.26 61.48 - 163.93 237.43M 3.00 3.10 5969943.89 590306.45 0 19 39.47036361 49 16 3.42983449 UG4 2949.11 4.15 237.43 2860.00 2942.00 -35.53 60.19 - 167.06 226.64M 3.00 3.19 5969942.56 590303.34 0 19 39.45762837 49 16 3.52115271 UG4A 2979.19 4.53 226.64 2890.00 2972.00 -33.89 58.78 - 168.84 220.33M 3.00 3.24 5969941.14 590301.58 0 19 39.44383976 49 16 3.57314193 3000.00 4.88 220.33 2910.74 2992.74 -32.49 57.54 - 170.01 200.61M 3.00 3.27 5969939.89 590300.42 0 19 39.43164408 49 16 3.60733172 3100.00 7.11 200.61 3010.20 3092.20 -22.84 48.51 - 174.95 33.29L 3.00 3.41 5969930.79 590295.60 0 19 39.34276270 49 16 3.75132983 3200.00 9.75 190.85 3109.11 3191.11 -8.33 34.39 - 178.72 23.63L 3.00 3.53 5969916.63 590292.00 0 19 39.20396313 49 16 3.86143395 WellDesign Ver SP 2.1 Bld( users) Plan V Slot (S -D) \Plan V -225 (SD) \Plan V- 225 \V -225 (P3) Generated 6/26/2009 1:46 PM Page 1 of 2 Measured Azimuth Vertical NS EW Mag 1 Gray Directional Comments Inclination Sub -Sea TVD TVD DLS Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty (ft) (deg) I (deg) I (ft) (ft) (ft) I (ft) I (ft) I (deg) (deg /100ft ) Index (ftUS) (ftUS) 3300.00 12.56 185.31 3207.21 3289.21 10.99 15.24 - 181.32 18.20L 3.00 3.64 5969897.46 590289.63 0 19 39.01562582 49 16 3.93734226 UG3 3323.37 13.23 184.35 3230.00 3312.00 16.20 10.05 - 181.76 17.26L 3.00 3.67 5969892.25 590289.25 0 19 38.96451202 49 16 3.95013061 3400.00 15.44 181.79 3304.24 3386.24 35.08 -8.89 - 182.74 14.78L 3.00 3.75 5969873.31 590288.50 0 19 38.77826700 49 16 3.97884682 3500.00 18.35 179.36 3399.91 3481.91 63.87 -37.94 - 182.98 12.45L 3.00 3.85 5969844.26 590288.61 0 19 38.49253726 49 16 3.98583411 3600.00 21.29 177.58 3493.98 3575.98 97.27 -71.83 - 182.04 10.78L 3.00 3.95 5969810.38 590289.96 0 19 38.15921977 49 16 3.95828537 V Pad Fault 3606.47 21.48 177.48 3500.00 3582.00 99.59 -74.19 - 181.94 10.69L 3.00 3.96 5969808.03 590290.09 0 19 38.13603685 49 16 3.95531483 3700.00 24.25 176.21 3586.17 3668.17 135.20 - 110.47 - 179.92 9.52L 3.00 4.05 5969771.78 590292.55 0 19 37.77922811 49 16 3.89627662 UG1 3742.80 25.51 175.72 3625.00 3707.00 152.79 - 128.43 - 178.65 9.07L 3.00 4.09 5969753.84 590294.03 0 19 37.60258376 49 16 3.85924551 3800.00 27.21 175.13 3676.25 3758.25 177.55 - 153.75 - 176.62 8.54L 3.00 4.14 5969728.55 590296.36 0 19 37.35360381 49 16 3.79997846 3900.00 30.18 174.24 3763.96 3845.96 224.21 - 201.55 - 172.16 7.76L 3.00 4.22 5969680.81 590301.40 0 19 36.88351347 49 16 3.66965560 4000.00 33.15 173.50 3849.06 3931.06 275.05 - 253.73 - 166.54 7.13L 3.00 4.31 5969628.70 590307.65 0 19 36.37024553 49 16 3.5 13 Ma 4061.49 34.98 173.10 3900.00 3982.00 308.33 - 287.95 - 162.52 6.80L 3.00 4.36 5969594.54 590312.08 0 19 36.03379040 49 16 3.3 98 End Cry 4062.01 35.00 173.10 3900.42 3982.42 308.61 - 288.24 - 162.48 - -- 3.00 4.36 5969594.25 590312.12 0 19 36.03089130 49 16 3.38725874 Mb1 4116.43 35.00 173.10 3945.00 4027.00 338.74 - 319.23 - 158.73 - -- 0.00 4.38 5969563.31 590316.24 0 19 35.72614542 49 16 3.27778121 Mb2 4201.88 35.00 173.10 4015.00 4097.00 386.05 - 367.89 - 152.84 - -- 0.00 4.42 5969514.73 590322.72 0 19 35.24758524 49 16 3.10586411 Mc 4262.92 35.00 173.10 4065.00 4147.00 419.84 - 402.64 - 148.64 - -- 0.00 4.45 5969480.03 590327.34 0 19 34.90575651 49 16 2.98306754 Na 4354.48 35.00 173.10 4140.00 4222.00 470.52 - 454.78 - 142.33 - -- 0.00 4.48 5969427.98 590334.28 0 19 34.39301337 49 16 2.79887481 Nb 4378.89 35.00 173.10 4160.00 4242.00 484.04 - 468.68 - 140.65 - -- 0.00 4.49 5969414.10 590336.13 0 19 34.25628185 49 16 2.74975717 Nc 4427.72 35.00 173.10 4200.00 4282.00 511.07 - 496.49 - 137.28 - -- 0.00 4.51 5969386.34 590339.83 0 19 33.98281881 49 16 2.65152245 Ne 4433.83 35.00 173.10 4205.00 4287.00 514.45 - 499.96 - 136.86 - -- 0.00 4.51 5969382.87 590340.29 0 19 33.94863593 49 16 2.63924316 Cry 3/100 4562.00 35.00 173.10 4309.99 4391.99 585.40 - 572.94 - 128.03 - -- 0.00 4.55 5969310.01 590350.00 0 19 33.23086212 49 16 2.38140467 V -225 Tgt OA 4562.01 35.00 173.10 4310.00 4392.00 585.41 - 572.95 - 128.03 0.87L 0.00 4.55 5969310.00 590350.00 0 19 33.23079535 49 16 2.38138068 End Cry 4566.80 35.14 173.10 4313.92 4395.92 588.06 - 575.68 - 127.70 - -- 3.00 4.56 5969307.27 590350.36 0 19 33.20394624 49 16 2.37173337 OBa 4641.50 35.14 173.10 4375.00 4457.00 629.56 - 618.37 - 122.53 - -- 0.00 4.58 5969264.66 590356.05 0 19 32.78411896 49 16 2.22084190 OBb 4684.30 35.14 173.10 4410.00 4492.00 653.34 - 642.83 - 119.57 - -- 0.00 4.59 5969240.24 590359.30 0 19 32.54356240 49 16 2.13438347 OBc 4757.67 35.14 173.10 4470.00 4552.00 694.11 - 684.76 - 114.49 - -- 0.00 4.61 5969198.37 590364.88 0 19 32.13117969 49 16 1.98617032 V -225 Tgt OBd 4824.93 35.14 173.10 4525.00 4607.00 731.47 - 723.20 - 109.84 - -- 0.00 4.63 5969160.00 590370.00 0 19 31.75316217 49 16 1.85030972 OBe 4892.20 35.14 173.10 4580.00 4662.00 768.84 - 761.63 - 105.18 -- 0.00 4.65 5969121.63 590375.12 0 19 31.37514462 49 16 1.71445049 TD 5142.20 35.14 173.10 4784.43 4866.43 907.73 - 904.50 -87.89 - -- 0.00 4.71 5968978.99 590394.13 0 19 29.97010061 49 16 1.2 195 Legal Description: Northing (Y) fftUSl Eastinq (X) tftUSI Surface : 4638 FSL 1832 FEL S11 T11N R11E UM 5969884.40 590471.10 V -225 Tgt OA : 4065 FSL 1961 FEL S11 T11N R11 E UM 5969310.00 590350.00 V -225 Tgt OBd : 3915 FSL 1943 FEL S11 T11N R11 E UM 5969160.00 590370.00 BHL : 3733 FSL 1921 FEL S11 T11N R11E UM 5968978.99 590394.13 WellDesign Ver SP 2.1 Bld( users) Plan V Slot (S -D) \Plan V -225 (SD) \Plan V- 225 \V -225 (P3) Generated 6/26/2009 1:46 PM Page 2 of 2 Schlumberger • • WELL Plan V -225 (P3) FIELD Prudhoe Bay Unit - WOA I STRUCTURE V -Pad Magnetic Parameters Surface Loca on NAD27 Alaska State Planes, bane 06, US Feet lascellaneous Modal: BGGM 2008 Dip: 80.8)2° Date: June 22, 2009 Lat . N701938.866 NMNng: 598988440!MS God Cony: .069088905° Slot: Plan V SIBS -D) TVD Ref Ratan, Table (82.008 above MSL) Mag Dec: •22401° FS: 57694.5 nT Lon W149 15 58 644 Eating: 590471.108US Scale Fact 0.999909298 Pia): V-225 (P3) St, Date: June 22. 2009 -600 0 600 1200 1800 2400 0 RTE 0 600 KOP Bid 1.5/100 600 Cry 21100 End Cry 1200 • 1200 1800 = 1 1800 4 3 0 0 (O _. ._..K.._.._.._.._.._.._.._.._.. 2 ._.._.._.._.._.._.._.._..,.._.. _.._.._.._.._.._.._.._ ._.._.._..«._.._. ._.._.._.i_.._.._.._.._.._.._. _.._..y.. _.. _.._.._.. _.._.._.. E 2400 2400 u a> 0 Cry 31100 I- .1. L 9 -98` Cag Pt 3000 +'�' "' 3000 3600 3600 V Pad Fault _..- .. ... ._.._.._.._.._.._.._.._.._. _.._... � i ..._.._.._.. __.._.._.._.._.._.._.._.._.._ ._.._.._.._.._.._.._.._.._._.._.._.._.._.._.._.. _.._..___.._ .._.._.._.._... 4200 _.,_ .. _.._.._.._.._.._.._. _.. ._.._.._.._.._.._.._.._.._. .._.._.._.._.._.._. ._.._..:.._.._.._.._.._.._.._.. 4200 re 0 B V -225 Tgt OBd 4800 OBe 4800 -225 (P3) TD -600 0 600 1200 1800 2400 Vertical Section (ft) Azim = 188.270, Scale = 1(i n):600(ft) Origin = 0 NI-S, 0 E / -W Schlumberger WELL Plan V -225 (P3) I FIELD Prudhoe Bay Unit - WOA I STRUCTURE V -Pad Magnetic Pa nWets Surface Location NA027 Alaska State Plate, Zane 04. US Feat Miuellaneous Model: 8GGM 2008 Dip'. 80.872° Date: June 22, 2009 La N701938.866 Northing'. 596988440 [US GM Cons +069088905 SIG'. Plan V Slot (S-D) TM Ref. Ratay Table (82 ft above MSL) Mag Dec. +22.401 FS: 57694 5 nT Lan: W149 15 58.644 Eastit9 590471 10 SUS Scale Fact'. 0 999909298 Plat: V -225 (73) Sr, Data: June 22, 2009 -450 -300 -150 0 150 300 150 150 N 9-19' Csg Pt AL4 �►.. End Cry Cry 2/100 KOP Bid 1.5/100 Cry 3/ 00 • 0 0 RTE V Pad Fault -150 -150 A A A Z -300 End•Cry -300 0 c it m -450 -450 • V V V V -225 Tgt OA -600 -600 V -225 Tgt O8d -750 080 -750 -900 TD -900 -225 (P3) -450 -300 -150 0 150 300 «< W Scale = 1(in):150(ft) E »> . • Anticollision Report • Company: North America - ALASKA - BP Local Co-ordinate Reference: Well Plan V -225 (S -D) Project :. Prudhoe Bay TVD Reference: V -225 Plan SD @ 82.00ft (Nabors 9ES) Reference Site PB V Pad MD Reference: V -225 Plan SD @ 82.00ft (Nabors 9ES) S ite E rror : 0.00ft North Reference: True Reference Well: Plan V -225 (S -D) ; Survey !Calculation Method: Minimum Curvature W Error: 0.00ft Output errors are at 1.00 sigma Reference Welibore! Plan V -225 Database: EDM .16 - Anc Prod - WH24P Reference Design Plan #3 V -225 (jwpb) Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation w arn i ng Site Name Depth Depth Distance (ft) from Plan Offset Well - Wettbore - Design (ft) (ft) (ft) (ft) PB V Pad Plan V -206 (S -K) - Plan V -206 - Plan #1 642.25 645.00 103.20 11.75 91.47 Pass - Major Risk Plan V -225 (S -D) - Plan V -225 - Plan #1 V -225 4,735.84 4,595.00 18.74 / 63.02 -44.07 FAIL - Major Risk Plan V -225 (S -D) - Plan V -225 - Plan #2 V -225 4,735.84 4,595.00 18.74 / 63.02 -44.06 FAIL - Major Risk Plan V -226 (S -L) - Plan V -226 - Plan #1 543.82 545.00 121.29 10.28 111.03 Pass - Major Risk V -01 - V -01 - V -01 670.23 675.00 190.43 12.07 178.36 Pass - Major Risk V -02 - V -02 - V -02 1,440.76 1,445.00 123.24 22.38 100.93 Pass - Major Risk V -03 - V -03 - V -03 599.96 600.00 376.64 9.93 366.70 Pass - Major Risk V -04 - V -04 - V -04 625.07 625.00 273.03 11.48 261.56 Pass - Major Risk V -05 - V -05 - StressCheck V -05 (WPSCK), v2 434.47 435.00 30.62 6.58 24.04 Pass - Major Risk V -05 - V -05 - V -05 220.79 220.00 31.56 4.17 27.39 Pass - Major Risk V -07 - V -07 - V -07 321.33 320.00 242.31 6.14 236.16 Pass - Major Risk V -100 - V -100 - V -100 668.60 675.00 309.51 10.77 298.74 Pass - Major Risk V -101 - V -101 - V -101 344.68 345.00 180.89 6.11 174.79 Pass - Major Risk V -102 - V -102 - V -102 479.85 480.00 215.00 9.45 205.55 Pass - Major Risk V -104 - V -104 - V -104 1,054.57 1,050.00 187.07 17.92 169.16 Pass - Major Risk V -105 - V -105 - V -105 1,021.88 1,030.00 246.59 16.90 229.74 Pass - Major Risk V-107-V-107-V-107 1,218.23 1,220.00 170.03 19.27 150.79 Pass - Major Risk V -108 - V -108 - V -108 389.64 390.00 186.36 6.89 179.47 Pass - Major Risk V -109 - V -109 - V -109 550.63 550.00 13.56 9.31 4.28 Pass - Major Risk V -109 - V- 109PB1 - V- 109PB1 550.63 550.00 13.56 ' 9.31 4.28 Pass - Major Risk V -109 - V- 109PB2 - V- 109PB2 550.63 550.00 13.56 9.31 4.28 Pass - Major Risk V -111 - V -111 - V -111 2,425.23 2,440.00 344.06 33.63 310.75 Pass - Major Risk V -111 - V -111 PB1 - V -111 PB1 2,425.23 2,440.00 344.06 33.63 310.75 Pass - Major Risk V -111 - V -111 PB2 - V -111 PB2 2,425.23 2,440.00 344.06 33.63 310.75 Pass - Major Risk V -111 - V -111 PB3 - V -111 PB3 2,425.23 2,440.00 344.06 33.63 310.75 Pass - Major Risk V-112-V-112-V-112 340.48 340.00 46.68 7.50 39.18 Pass - Major Risk V -113 - V -113 - V -113 499.99 500.00 17.48 8.04 9.40 Pass - Major Risk V -114 - V -114 - delete me 28.70 28.50 45.13 0.91 44.21 Pass - Major Risk V-114-V-114-V-114 657.69 660.00 32.75 11.66 21.10 Pass - Major Risk V -114 - V -114A - delete me 28.70 28.50 45.13 0.91 44.21 Pass - Major Risk V -114 - V -114A - V -114A 657.69 660.00 32.75 11.66 21.10 Pass - Major Risk V -114 - V- 114APB1 - delete me 28.70 28.50 45.13 0.91 44.21 Pass - Major Risk V -114 - V- 114APB1 - V- 114APB1 657.69 660.00 32.75 11.66 21.10 Pass - Major Risk V -114 - V- 114APB2 - V- 114APB2 657.69 660.00 32.75 11.66 21.10 Pass - Major Risk V -119 - V -119 - V -119 630.04 630.00 30.94 11.15 19.79 Pass - Major Risk V -121 - V -121 -V-121 548.29 550.00 247.32 10.69 236.64 Pass - Major Risk V -201 - V -201 - V -201 364.89 365.00 208.81 6.15 202.66 Pass - Major Risk V -202 - V -202 - delete me 28.50 28.50 182.30 0.96 181.34 Pass - Major Risk V -202 - V -202 - V -202 1,083.93 1,080.00 155.98 17.38 138.61 Pass - Major Risk V -202 - V -202L1 - delete me 28.50 28.50 182.30 0.91 181.39 Pass - Major Risk V -202 - V -202L1 - V -202L1 1,083.93 1,080.00 155.98 17.38 138.61 Pass - Major Risk V -202 - V -202L2 - delete me 28.50 28.50 182.30 0.91 181.39 Pass - Major Risk V -202 - V -202L2 - V -202L2 1,083.93 1,080.00 155.98 17.38 138.61 Pass - Major Risk V -203 - V -203 - delete me 29.30 28.50 185.53 0.97 184.56 Pass - Major Risk V -203 - V -203 - V -203 960.56 950.00 163.19 17.04 146.21 Pass - Major Risk V -203 - V -203L1 - V -203L1 960.56 950.00 163.19 17.04 146.21 Pass - Major Risk V -203 - V -203L2 - delete me again 960.56 950.00 163.19 17.09 146.17 Pass - Major Risk V -203 - V -203L2 - V -203L2 960.56 950.00 163.19 17.04 146.21 Pass - Major Risk V -203 - V -203L3 - V -203L3 960.56 950.00 163.19 17.04 146.21 Pass - Major Risk V -203 - V -203L4 - V -203L4 960.56 950.00 163.19 17.04 146.21 Pass - Major Risk V -204 - V -204 - V -204 339.78 340.00 61.29 5.99 55.30 Pass - Major Risk V -204 - V -204L1 - V -204L1 339.78 340.00 61.29 5.99 55.30 Pass - Major Risk V -204 - V -204L1 PB1 - V -204L1 PB1 339.78 340.00 61.29 5.94 55.35 Pass - Major Risk 6/23/2009 9 :24:48AM Page 3 of 5 COMPASS 2003.16 Build 70 Anticollision Report Company: North America - ALASKA - BP Local Co- ordinate Reference: Well Plan V -225 (S -D) Project ` Prudhoe Bay TVD Reference: V -225 Plan SD @ 82.00ft (Nabors 9ES) Reference Site: PB V Pad MD Reference: ; V -225 Plan SD @ 82.00ft (Nabors 9ES) Site Error: 0.00ft North Reference: True Reference Welt: Plan V -225 (S -D) Survey Calculation Method: Minimum Curvature Weft Error: ; 0.00ft Output errors are at 1.00 sigma Reference Wel lbore Plan V -225 Database: EDM .16 - Anc Prod - WH24P Reference Design: Plan #3 V -225 (jwpb) Offset TVD Reference: Offset Datum Summary ,. Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) : from. Pfan Offset Well - Wellbore - Design (ft) . (ft) (ft) (ft) ` . . PBVPad V -204 - V -204L2 - V -204L2 339.78 340.00 61.29 5.94 55.35 Pass - Major Risk V -204 - V- 204L2PB1 - V- 204L2PB1 339.78 340.00 61.29 5.94 55.35 Pass - Major Risk V -204 - V -204L3 - delete me 339.78 340.00 61.29 5.99 55.30 Pass - Major Risk V -204 - V -204L3 - V -204L3 339.78 340.00 61.29 5.94 55.35 Pass - Major Risk V -204 - V- 204PB1 - delete me 339.78 340.00 61.29 5.99 55.30 Pass - Major Risk V -204 - V- 204PB1 - V- 204PB1 339.78 340.00 61.29 5.94 55.35 Pass - Major Risk V -204 - V- 204PB2 - V- 204PB2 339.78 340.00 61.29 5.94 55.35 Pass - Major Risk V -205 - V -205 - V -205 700.00 705.00 220.05 12.21 207.84 Pass - Major Risk V -205 - V -205L1 - V -205L1 700.00 705.00 220.05 12.21 207.84 Pass - Major Risk V -205 - V -205L2 - V -205L2 700.00 705.00 220.05 12.21 207.84 Pass - Major Risk V -210 - V -210 - V -210 210.90 210.00 185.84 3.77 182.07 Pass - Major Risk V -211 - V -211 - V -211 231.09 230.00 181.79 4.04 177.75 Pass - Major Risk V -214 - V -214 - delete me 28.90 28.50 180.23 0.92 179.32 Pass - Major Risk V -214 - V -214 - V -214 260.39 260.00 181.46 5.19 176.27 Pass - Major Risk V -214 - V- 214PB1 - V- 214PB1 338.19 335.00 182.14 7.02 175.12 Pass - Major Risk V -214 - V- 214PB2 - V- 214PB2 258.19 255.00 181.42 5.15 176.27 Pass - Major Risk V -214 - V- 214PB3 - V- 214PB3 258.19 255.00 181.42 5.15 176.27 Pass - Major Risk V -214 - V- 214PB4 - V- 214PB4 258.19 255.00 181.42 5.15 176.27 Pass - Major Risk V -215 - V -215 - V -215 470.55 470.00 79.63 10.10 69.53 Pass - Major Risk V -217 - V -217 - V -217 444.03 445.00 234.62 8.21 226.42 Pass - Major Risk V -222 - V -222 - V -222 270.99 270.00 226.04 5.08 220.97 Pass - Major Risk V -223 - V -223 - V -223 614.86 615.00 176.73 13.36 163.37 Pass - Major Risk 6/23/2009 9:24 :48AM Page 4 of 5 COMPASS 2003.16 Build 70 • Project: Prudhoe Bay Site: PB V Pad Well: Plan V -225 (S -D) Wellbore: Plan V -225 Design: Plan #3 V -225 ANTI - COLLISION SETTINGS Interpolation Method: MD, interval: 100.0C Depth Range From: 28.50 To 5142.20 Results Limited By: Centre Distance: 711.37 0 V 14N /� \ V-202/V-202L2 V -222N -222 V -211/V -21 1 98" 330 V -0 ,,,neck V -0 4, • 1 .. y 19. 30 / 1962 � V -101N -101 100 �� �� tji r -94 V- 02N -02 / ✓ i -_ V- 203N- 203L8e aaaZ6` C pl* - 1 , H , 1 . P (: — ,_. 3 0005N - 105 1581, a' 18-05 : T, T�1 , i y V 7. 600 �p� 17 v 1406 1208 ?' 9 401 Np a a ; ' { ` . h QC �gt01 Dui b89 599 1 80 , 1 • : in ° 1 u i , , , , / *z 1403 -9684 03 1 � ! � aft ' �� 58� cu ,�,' -_- �r � ` 3 V- 111N- 111P1I 300 4 ®T 4 � to 40 8C $i av 1% - Ak - IN V- 108/V1Q$ 10 t..'..01 1d 179 V -113N -113 / 1396 1206 /- `� 1. + i't∎ ' ia�W • p 15 `� Hi'� 5: 0' ----------. 1954j�" 1394 ����� ` kV-121N- 121 P SI �� A. '` �� / 1775 / 1293 - — — ��� ra_' A �� k A A /______„ 11 7 157,2,, 138: 119 . At . , . � ® � ► ��� ®� _ , 96• 1587 1198 �� ?�I� � '� � ✓ � + 57 / 1395 1098 , ����ri i I; � � � V . f $ Vicki "J f f� �,7 4 � , 1 % "V via � 1 .� �i � of `®t ' � I 275 i -� 1002 51 ,._ � ` °� e... 5 E , �� � -1► s��� V -100 /V -100 120 �a d� � a7 _ 1,0► 1 2350 4 V 109/V 109PB2 - a �.. , <� : ��'�• _..� 1001 � t /,� ,. S � \ �h��� q , '�d �.I. 270 - `8 7- 60 8 ,0 J(f g 'yc. lik :: � G.yV Tw 90 -±4 599 l wa 6 : V4 1'_, Etnt, 5 � / 10�1 6 / �� t' , 1 k t; 10 7 793 ��n �`� /� �� i i ® V -217N -217 N ' :' ® , V -223N -223 I ins 0 983 4 \�r �. ®: 240 1166 11 5 . ���* 120 200 � �a \ V- 01 /V -01 ■ i 250 ‘'V'-215/V-215(9-L)/Plan 1344 #1 , 300 la V- 205N -205L2 210 / ..•"" gm •Ian V -206 (S-K) /Plan #1 V- 114/V- 114APBa 350 180 Travelling Cylinder Azimuth (TFO +AZI) [1 vs Centre to Centre Separation [100 ft/in] EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 / • AEO 2 • 6000000 1 Z, 1 / - 7 i AEO 1 5950000 -� V -225 (surface) 5900000 40 CFR 147.102 (b)(3) • 5850000 400000 500000 600000 700000 800000 Alaska Department of Naturallsources Land Administration System Page 1 of 4 Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28240 Printable Case File Summary See Township, Range, Section and Acreage? Yes No [ New Search LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28240 Search for Status Plat Updates As of 10/01/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: O11N Range: 011E Section: 01 Section Acres: 640 Search Plats Meridian: U Township: O11N Range: 011E Section: 02 Section Acres: 640 Meridian: U Township: 011N Range: 011E Section: 11 Section Acres: 640 Meridian: U Township: O11N Range: 011E Section: 12 Section Acres: 640 Legal Description 05 -28 -1965 * * *SALE NOTICE LEGAL DESCRIPTION* * * C14 -19 011N- 011E -UM 1,2,11,12 2560.00 04 -01 -1977 * *UNITIZED,LEASE AND PARTICIPATING AREA LEGAL DESCRIPTION ** LEASE COMMITTED IN ENTIRETY TO PR UDHOE BAY UNIT AND OIL RIM GAS CAP PA PRUDHOE BAY UNIT http://dnr.alaska.gov/projects/las/Case Summary.cfm?FileType=ADL&FileNumber=2824... 10/1/2009 • • TRANSMITTAL LETTER CHECKLIST WELL NAME PEI,/ 1/4:PUS • PTD# o?a 9//7 Development ✓ Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: ./ 23:45' POOL: a•P. /O/$ ,� 44 0407 Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - . API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 WELL PER T CHEC Field & Pool PRUDHOE BAY, ORION SCHR BL OIL - 640135 Well Name: PRUDHOE BAY UN ORIN V -2251 Program SER Well bore se PTD #: 2091180 Company BP EXPLORATION (ALASKA) INC Initial Class/Type SER / PEND GeoArea 890 Unit 11650 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a definedpool Yes Orion - Schrader Bluff. 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 2560 acres. 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Blanket Bond #6194193. 11 Permit can be issued without conservation order Yes Appr Date 1 12 Permit can be issued without administrative approval Yes ACS 10/1/2009 1 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For Yes AIO 026.000 li 15 All wells within 1/4 mile area of review identified (For service well only) Yes 16 Pre- produced injector: duration of pre production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(y2.A -D) NA 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs NA Within area AEO no.1 ( 40 CFR) 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg No TOC planned 1000' below surface shoe. 22 CMT will cover all knownproductive horizons Yes 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequatetankage_or reserve pit Yes Rig has steel pits. All waste to approved disposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved NA '26 Adequate wellbore separation proposed Yes Proximity analysis performed. All drilled wells pass major risk criteria . 27 If diverter required, does it meet regulations Yes Paddle removal approved <1000' Appr Date 28 Drilling fluid program schematic & equip list adequate Yes 2115 psi (9.1 ppg) will drill with 9.4 ppg LSND GLS 10/5/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 1660 psi will test BOP's to 4000psi • 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S on V pad. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) Yes _ AOR complete. V -02 closest at597' 35 Permit can be issued w/o hydrogen sulfide measures No Max level H2S on Pad for well V -117 was 300ppm (4/3/07). Geology 36 Data presented on potential overpressure zones NA Appr Date 37 Seismic analysis of shallow gas zones NA ACS 10/1/2009 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] No Geologic Engineering III. .11 Commissioner: Date: C mmissio r: Date 67 rer Date
