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205-150
David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250602 (IGB 25-001) Well API #PTD #Log Date Log Company Log Type Format AOGCC E-Set# KTU 43-6XRD2 50133203280200 205117 07/14/2014 POLLARD CBL PDF MPU C-15A 50029213580100 216070 07/06/2016 HALLIBURTON RCBL PDF LAS PPTX PBU L-103 50029231010000 202139 08/06/2002 SCHLUMBERGER USIT/TEMP/GR PDF PBU L-108 50029230900000 202109 06/30/2002 SCHLUMBERGER USIT/TEMP/GR PDF PBU L-111 50029230690000 202030 03/02/2002 SCHLUMBERGER USIT/TEMP/GR PDF TIF PBU S-104 50029229880000 200196 02/02/2001 SCHLUMBERGER USIT PDF PBU V-212 50029232790000 205150 12/14/2005 SCHLUMBERGER USIT PCU 04 50283201000000 201193 11/04/2001 SCHLUMBERGER USIT/CBL PDF TIF Please include current contact information if different from above. T40515 T40516 T40517 T40518 T40519 T40520 T40521 T40522 PBU V-212 50029232790000 205150 12/14/2005 SCHLUMBERGER USIT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.03 08:26:36 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/02/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230416 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPB-15 50029213740000 185121 5/16/2021 READ Caliper Survey MPC-02 50029208660000 182194 4/26/2023 READ Caliper Survey MPE-15 50029225280000 194153 4/17/2023 READ Caliper Survey MPE-15 50029225280000 194153 4/21/2023 READ Caliper Survey MPL-40 50029228550000 198010 4/18/2023 READ Caliper Survey PBU D-03A 50029200570100 200134 5/28/2023 READ MRCBL PBU L-212 50029232520000 205030 4/14/2023 READ Injection Profile PBU S-210 50029236300000 219057 4/17/2023 READ Injection Profile PBU V-212 50029232790000 205150 5/13/2023 READ Injection Profile Please include current contact information if different from above. T37721 T37722 T37723 T37723 T37724 T37725 T37726 T37727 T37728PBU V-212 50029232790000 205150 5/13/2023 READ Injection Profile Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.12 14:32:41 -08'00' • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday,March 22,2018 Jim Regg P.I.Supervisor �el I 31i z( l SUBJECT: Mechanical Integrity Tests 11l BP EXPLORATION(ALASKA)INC• . V-212 FROM: Adam Earl PRUDHOE BAY UN ORIN V-212 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-212 API Well Number 50-029-23279-00-00 Inspector Name: Adam Earl Permit Number: 205-150-0 Inspection Date: 3/13/2018 Insp Num: mitAGE180313154655 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-212 Type Inj W TVD 4383 Tubing 937 949 916 - 773 PTD 2051500 Type Test SPT Test psi 1500 IA 8 2495 - 2423 - 2398 - BBL Pumped: 2 BBL Returned: 1.8 OA 562 568 - 569 - 569 • Interval 4YRTST P/F P Notes: MIT-IA M>� cue_ Z1 Z is Web( pkceet`twte,--e tt gcA- - ds -Ls c { s ?-4- SCANNEV Thursday,March 22,2018 Page 1 of 1 Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, February 19, 2018 12:54 PM To: AK, OPS EOC Specialists;AK, OPS GC2 Facility OIL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad LV;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL;Youngmun,Alex;Zoesch, Eric;Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel,Joshua;Worthington, Aras J; Regg,James B (DOA) Subject: NOT OPERABLE: Injector V-212 (PTD#2051500)Will not be brought online before AOGCC MIT-IA is due All, Injector V-212 (PTD#2051500) is currently shut in for a WAG swap and will not be brought online before its 4 year AOGCC witnessed MIT-IA is due. At this time the well is reclassified as Not Operable for tracking purposes. Once the WAG swap pre work is complete the well will be reclassified and a state witnessed MIT-IA will be scheduled. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 «ha••+•••••4.11~4.000 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. Q~,~ ~ - ~ ~~ Well History File Identifier Organizing (done) ~.,~.,a~ iuiiiiiiiiiiuuii ae,~a~~e~e~ uiuiiiiuuiiui RE CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: DIGITAL DATA ~iskettes, No. ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Maria Date: ~ r V ^ Other:: /sl Project Proofing II I II') II I I III I I III BY: Maria Date: ~ © /s/ Scanning Preparation _~ x 30 = ~ + =TOTAL PAGES___,~ M i BY D t ~ ~ ( ~ i a S (Count does not include cover sheet) / / ar a : e: f a , . s IIIIIIIIIIIIIIIIIII Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cov r sheet) Page Count Matches Number in Scanning Preparation: _~YES NO BY: Maria Date: ~ ~ ~ ~ v /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II ~I II I II II I I III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III II~III III III I 10!6/2005 Well History File Cover Page.doc 04/28/11 Sch{umberger /10.5729 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Seth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 15 -09A BBKA -00096 PRODUCTION PROFILE 1 4113 -- 03/14/11 1 .. O0"7 1 C 17 -06 BBKA -00094 INJECTION PROFILE )'M 1 6 ,,a 03/10/11 1 - e 'r. > 1 C -12B BAUJ -00064 MEM PRODUCTION PROFILE 03/08/11 1 0 • • Sit 1 G -238 BLPO -00079 MEM PRODUCTION PROFILE — 03/09/11 1 Pa I 1 16-08A BJGT -00022 EIE1111G=i 0L9!4& LI• 1 02 -18B BLPO.00087 VIA ' [N-I>ilpt7 ,•Z+ t, T; S 1 J -22A BJGT -00023 CBL a r1+r — ' ' -- 1 L -210 BLPO -00086 MEM INJECTION PROFILE ' •. � 03/23/11 1 DMIffir 1 V -105 BLPO -00091 MEM INJECTION PROFILE _ ' 1G _ - 03/29/11 1 1 V -220 BBSK -00065 INJECTION PROFILEJWFL i�'''lricr. ♦ • ' i � '1! 1 • /*......'''"'">- V -212 B088-00096 ' ' ` • - ROE E p ..• 04/03/11 1 r'� 1 L -214A BCRJ -00073 INJECTION PROFILE 4 I /',e� 03/18/11 1 1 V -223 BAUJ -00071 MEM INJECTION PROFILE ; i i. ►��.� ' 6�PVFj 1 V -217 BAUJ -00077 " • • i �t�."� I OTZR4 1 3 - 05/0 -29 BG4H -00043 LDL ( , °' / - U ' ' p •D 1 1-47A/M -20 BLPO -00092 MEM PRODUCTION PROFILE az5'7 tier.gt •i 1 1- 25A/K -22 BBSK -00057 CBL r - U 7 ke!Z`� 1 S -01C BCUE -00113 MEM CBL - b — 144 03/17/11 .» • - i 1 1 11 -30 BD88 -00097 MEM INJECTION PROFILE l'9 U'1 -' - 04/18/11 1 tne:i 1 04 -11A AWJI.00134 INJECTION PROFILE 01 O —j /d' 03/24/11 1 Oj ; 1 P2-41 BG4H -00044 PRODUCTION PROFILE ( --'a -t 5 03/22/11 1 /�6S U1 , 0 -268 BMSA -00009 SCMT aA(A —()4'd 03/24/11 AU g$ _ 02 -18B BLPO -00087 MEM PRODUCTION PROFILE d-(TGe ;L 03/24/11 1 . • 1 Z -20 BP5G -00010 GLS 1 lr *--(p 0 03/29/11 1 r 11 1 7-29A BCUE -00122 MEM LDL / GD4, -- ( 03/20/11 1 Jog 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 Gemhell Street, Suite 400 900 E. Benson Blvd Anchorage, AK 99503 -2838 • . n,I STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ~ convert to Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ MI Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^ Exploratory ^ 205-1500 3. Address: P.O. Box 196612 Stratigraphic^ Service 0 6. API Number: Anchorage, AK 99519-6612 ~ 50-029-23279-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ` ADLO-028240 V-212 10. Field/Pool(s): °^~ PRUDHOE BAY FIELD / SCHRADER BLUFF POOL 11. Present Well Condition Summary: Total Depth measured 6150 feet Plugs (measured) 5824' 1/15/06 feet true vertical 5047.93 feet Junk (measured) None feet Effective Depth measured 6055 feet Packer (measured) 5485 5654 5763 true vertical 4953 feet (true vertical) 4383 4552 4661 Casing Length Size MD ND Burst Collapse Structural Conductor 106 20" 215.5# A-53 SURFACE - 106 SURFACE - 106 Surface 3233 9-5/8"40# L-80 28 - 3233 28 - 2689 5750 3090 Intermediate 6140 7" 26# L-80 25 - 6140 25 - 5038 7240 5410 Production Liner Liner Perforation depth: Measured depth: O 5608 - 5642 O 5672 - 5698 O 5711 - 5733 O 5820 - 5872 _ True Vertical depth: 4505.96 - 4539.94 4569.94 - 4595.94 4608.94 - 4630.94 4717.94 - 4769.93 Tubing: (size, grade, measured and true vertical depth) 3-1/2" 9.3# L-80 SURFACE - 5846 SURFACE - 4744 Packers and SSSV (type, measured and true vertical depth) 7"X3-1 /2" BKR PREM BKR 54 4383 7"X3-1 /2" BKR PREM BKR 5654 4552 7"X3-1 /2" BKR PREM BKR 5763 4661 ~~~ 12. Stimulation or cement squeeze summary: Intervals treated (measured): : ~ ~ ~ :+ =i `1' ~ (~ ~ J ice` ~ ~ Treatment descriptions including volumes used and final pressure: ~~~~5~~ a~~ :~. ~=~ ~'~ ~ #~+!>"'t'~iA4flaaEtlii 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 683 1301 Subsequent to operation: 14. Attachments: 15. Well Class after work: ,1 Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^~ Daily Report of Well Operations X 16. Well Status after work: Oil ;Gas WDSPL GSTOR ^ WAG ~] GINJ ^ WIN SPLUG ^ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. ~• Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature q ~ Phone 564-4944 Date 8/27/2010 VIIII IU-YV't RCVfBCU I/GVV~ J~~ ~ ~ ~/~O ~~ ~+~~~'7 ~~w1~j ~ 0 u ~J v-Zi2 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 8/24/2010}***WELL INJECTING ON ARRIVAL***(WAG swap) CURRENTLY RIH W/ 3-1/2" WHIDDON C-SUB TO SET ON P-PRONG @ X5,824' MD. ~ ~ ,***JOB IN PROGRESS, CONTINUED ON 8/25/10 WSR*** 8/25/2010{***CONTINUED FROM 8/24/10 WSR***(WAG swap) PPERFORM MAN DOWN DRILL W/ BP REP ON LOCATION. €SET 3-1/2" WHIDDON CATCHER SUB @ 5,798' SLM. PULLED RK-P15 WFR FROM ST #1`E5,785' MD). SET RKP-FLOW SLV @ ST #1 (5,785' MD). ;BRUSH & FLUSH TBG FROM SURFACE TO 5824' MD W/ 3-1/2" BLB, 2.50" ~G-AUGE RING (no issues). LRS PUMPED TOTAL OF 75 BBLS DIESEL (hot). 'PULLED RKP-FLOW SLV FROM ST #1 (5,785' MD) SET RK-P15 WFR @ ST #1 (5,785' MD). LRS PERFORMED 3 FAILED INJECTIVITY SRT's. (see log for details). j MADE TWO ATTEMPTS TO PULL STA# 1, 'RAN 1.75" LIB TO STA# 1 AT 5,774'SLM.(lib shows empty pocket). CURRENTLY RIH W/ 4-1/2" GR. "**CONT WSR ON 8/26/10*** .~,.~ _ ~...~.~ ~ ~.,~~ o.~ 8/25/2010 T/I/0=800/0/380 Inj Test (WFR) Pump 58 bbls diesel down tbg at various Epressures to determine Inj rate of WFR..18 bpm @ 1000 psi .28 bpm @ 1200 psi .4 bpm @ 1400 psi. @ lowest pressures failed to meet the minimum rate for WFR that was set. FWHP's= 1000/0/380 S-line in control of well at dep. 8/25/2010 T/I/0=450/0/400 Assist Slick Line; Brush and Flush (WFR) Pump 75 bbls 180* 'diesel down tbg. FWHP's=ssv/0/400 S-line in control of well at dep. m~.~.~ ~~.......~.~. -~...-..._.._~~_~ n =_ _ _~ ~_ 8/26/20101***CONT WSR FROM 8/25/10***(wag swap) PULLED W HIDDON FROM 5,798'SLM (recovered wfr from sta #1) RE-SET 3-1/2" WHIDDON AT 5,798'SLM. SET RK-P15 XJR IN STA# 1 AT 5,774' SLM. LRS PERFORM PASSING INJECTIVITY SRT. PULLED EMPTY 3-1/2" WHIDDON CATCHER. SET 3 1/2" MCX (.875" bean, ser# BP3-03, 35" oal) IN X NIP @ 2484' SLM (2506' MD) DRAWDOWN TEST PASSED. ***WELL S/I ON DEPARTURE, PAD OP NOTIFIED TO SWAP TO MI & POI ~*** FLUIDS PUMPED BBLS 170 DIESEL 170 Total TREE = 4-1 /16" CMJ WELLHEAD = FMC GEN 5 ACTUATOR = • LEO KB. ELEV = 80' BF. ELEV = 52.6' KOP = 354' Max Angle = 54 @ 2868 Datum MD = 5577' Datum TV D = 4400' 20" CONDUCTOR ~-) 101' 9-518" CSG, 40#, L-80 BTC, ID = 8.835" 3233' Minimum ID,,_,,,,2,.$.,,-~--~--,,,,_.,,,,,,,,,,,,, 13" @ 2506' 3-1 /2" HES X NIPPLE SA~FE'T~}TES: --- V -212 ____ 26' 4-1/2" X 3-112" XO, ID = 2.992" 63' 7" SHORT JOINT w / RA TAG 2506' I-I3-1/2" HES X NIP, ID = 2.813" 5183' ~ 7" SHORT JOINT w / RA TAG GAS LIFT MANDRELS MD TVD DEV TYPE ~VLV LATCH POR 5440 4338 8 MMG DMY RK 0 5469' 3-1/2" HES X NIP, ID = 2.813" 5485' 7" X 3-112" BKR PREM PKR, ID = 2.875" WATER INJECT~N MANDRELS ~i ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 5606 4504 2 MMG-W DMY RK 0 12/14/05 4 5630 4528 2 MMG-W P-15 RK 9 10!06/09 3 5711 4609 0 MMG-W DMY RK 0 12114!05 2 5740 4638 0 MMG-W P-15 RK 8 10/06!09 1 5785 4683 0 MMG-W P-15 RK 10 10/06!09 PERFORATION SUMMARY REF LOG: USIT ON 12/12/05 ANGLE AT TOP PERF: 2° @ 5610' Note: Refer to Production DB for historical perf data SQE SPF ZONE INTERVAL Opn/Sqz DATE 3-1/2" 5 OA 5608 - 5642 O 12/12/05 3-1/2" 5 Oi3a 5672 - 5698 O 12/12/05 3-1/2" 5 Ot3b 5711 - 5733 O 12/12/05 3-1/2" 5 OBd 5820 - 5872 O 12112!05 1 3-1/2" TBG, 9.3#, L-80 TCII, .0087 bpf, ID = 2.992" I u 7" CSG, 26#, L-80 BTGM, ID = 6.276" 8-3/4" TD I 5846' I I 6055' I 5644' H 3-1/2" PUP w !RA MARKER 5654' 7" X 3-112" BKR PREMIER PKR, ID = 2.875" 5690' 3-112" HES X NIP, ID = 2.813" 17" X 3-1/2" BKR PREM PKR, ID = 2.875" I 5808' ~-{ 3-1/2" HES X NIP, ID = 2.813" 5824' 3-1/2" HES X NIP, ID = 2.813" 5824' 3-112" PX PLUG (01/15/06} 5846' 3-1/2" WLEG, ID = 2.992" DATE REV BY COMMENTS DATE REV BY COMMENTS 12/16/05 D16 ORIGINAL COMPLETION 10/08/09 MBM/SV GLV GO (10/06109) 01/04/06 MCZ/TLH DRLGDRAFTCORRECTIONS 01/10/06 DAV/TLH GLV GO 01/15/06 WTS/TLH WFV C/O & PX PLUG SET 11/30/07 TW/PJC GLV / PERF CORRECTIONS 03/13/08 TVN/PJC PERF CORRECTIONS ORION UNff WELL: V-212 PERMfT No: "2051500 API No: 50-029-23279-00 SEC 11 T11 N, R11 E, 405' FNL& 1634' FEL BP Exploration (Alaska) C~ MEMORANDUM TO: Jim Regg 2 P.I. Supervisor ~~~~ "~~~~~ l~ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, March 10, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC V-212 PRUDHOE BAY iJN ORIN V-212 Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UN ORIN V-212 Insp Num: mitCS100305144412 Rel Insp Num: API Well Number: 50-029-23279-00-00 Permit Number: 20s-150-0 Inspector Name: Chuck Scheve Inspection Date: 3/4/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well v-zlz ~ Type Inj. ~' ` TVD 4383 '~ IA 370 zsoo ~ zalo zaoo P.T.D 20s1s00 TypeTest SPT Test psi lsoo OA sso sso sso sso Interval aYRTST p~ P ~ Tubing 900 900 900 900 Notes: Wednesday, March 10, 2010 Page 1 of 1 • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~:.~~ w~'La~u~ . ; ~~ . ~ w ~` V G;~ August 14, 2009 ~ bp ~~~`~~~~ OCT A 5 20Q9 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, ~~(8 0l) $t G83 CODS. C(#It1mi~R~inn Anchor~p~ a~s- ~ ~D U~ ~... ~ ~.- Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date V-pad S/13/2009 Well Name PTD # API # initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al V-01 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-o3 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 V-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 V-102 2020330 50029230700000 NA 7.75 NA 98z 8/7/2009 V-103 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009 V-104 2021420 50029231030000 NA 1.5 NA 21.3 7/11/2009 V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-106A 2041850 50029230830100 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-109 2022020 50029231200000 NA 12 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 206Q200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 NA 1.5 NA t3.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-t20 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-t22 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 V-2o1 2012220 50029230540000 SC leak NA 4 NA 90.6 8/7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009 V-203 2051680 50029232850000 NA 2 NA 12.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061800 50029233380000 NA 1.8 NA 13.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 v-210 2042100 50029232310000 NA 2 NA 18.7 7/11/2009 V-211 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-212 2051500 50029232790000 NA 1.2 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 50029233510000 NA 2.8 NA 30.6 6/30/2009 V-216 2041300 50029232160000 NA 1.5 NA 13.6 6/29/2009 V-217 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7/12/2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 ",-'~^ 2080200 50029233830000 NA 1.75 NA ~b 3/9/2008 V-221 2050130 50029232460000 NA 0.8 NA 8.5 6/29/2009 V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9/7/2008 01 /23/09 ~~~~~~pih~~s Alaska Data & Consulting Services a(`~ 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 QJ a ATTN: Beth P~J QG ~~~~k ` W/ ell l o .Inh !k N0.5047 Company: State of Alaska Alaska Oil & Gas Cons Comm k.,,~,-,,,~,; ~b1r,_ ~~,~, 'i ) ~' !.,~ ~. ~J ; ~ Attn: Christine Mahnken 333 West 7th Ave, Suite 100 ®~ ' ~ Anchorage, AK 99501 ;~.' ~ i 1 .... nes., wa:..w H-35 11970840 PRODUCTION PROFILE 08/12/08 1 1 -11 12111927 IBP & CROSS-FLOW STP ~ j 11/24/08 1 1 MPS-41 11966291 SCMT - ~~ 11/24/08 1 1 K-O5C AWJB-00016 MEM PROD PROFILE p _ ~.5 12/29/08 1 1 14-17A AXOY-00010 MEM INJECTION PROFILE O -~ 01/15/09 1 1 F-33 ALYF-00010 CEMENT IMAGE LOG (p- ~"' 12/30/08 1 1 K-16AL2 AXIA-00009 MEM PROD PROFILE 0 b J 01/10/09 1 1 01-29 AP30-00011 USIT $ - '- ~ 01/04/09 1 1 09-30 AY1M-00007 STATIC SPINNER &IBP ~-- L( 01/15/09 1 1 N-18A AZCM-00005 JEWELRY LOG/PRESSITEMP - ~ 01/06/09 1 1 R-24 AY3J-00004 USIT ~ 01/16/09 1 1 N-18A AWLB-00002 USIT 12/26/08 1 1 V-212 - XBD-00010 MEM INJECTION PROFILE ~ 01/16/09 1 1 V-222 LYF-00011 INJ PROFILEIWFL .~ ~~"~ 01/08/09 1 1 07-OVA AYOO-00009 USIT '`~ - L 01/22/09 1 1 N-12 12014053 RST J - 09/30/08 1 1 E-32B AXOY-00005 MCNL 11/18/08 1 1 P2-15A 11594511 SCMT (PDC) (REVISION 2) t )~,~ 06/15/07 1 B-27A 11999059 RST ~- D~ ~ ~~' + 11/07/08 1 1 12-37 40018138 OHM D/LWD EDIT _~ ~,~- 11/07/08 2 1 N-18A 08AKA0037 OH MWD/LWD EDIT O~f - '~ 12/24/08 2 1 H-38 08AKA0031 OH MWD/LWD EDIT - C 12/07/08 2 1 -~ ~ G ~~ ~ -~,~ DI CAeC Af~VI.IA\IIII cn/-r nr n r~e~T w~i ~.~~ ...... ...w w~~...w...-.~ .-.~ ~~~... _ ~_. __ _-___-_-_-_.-__.__~-.~..~~~.. ~. ~......... v. r+.-r ..r. v... ~..~V VIAL. VVf 1 LnV11 IV. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~ /t 900 E. Benson Blvd. II/ I Anchorage, Alaska 99508 n Date Delivered Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ~ ~,~y Anchorage, AK 9~~0~ ~85: o ~, la , ,„ f°- ATTN: Beth ~., Received by: ~ ~,- t ~ ~, ~~ ~t .,,. .. . 1. i ls` J~ ~c~o~ DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051500 Well Name/No. PRUDHOE BAY UN ORIN V-212 Operator BP EXPLORATION (ALASKA) INC MD 6150 TVD 5048 Completion Date 12/15/2005 Completion Status WAGIN Current Status WAGIN REQUIRED INFORMATION Mud Log No Samples No Directional Survey(_ Yes j - DATA INFORMATION Types Electric or Other Logs Run: MWD GR, MWD / GR / RES /DEN / NEU / PWD, USIT Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No I ~I~ D A i l S sc ona urvey Direct ~,~g Sonic 5 Col 1 s~ Injection Profile Blu 1 E C Lis 14515 Induction/Resistivity ', Rpt 14515 LIS Verification ~C Lis ~°'~ Gamma Ray %.S ~~~ Well Cores/Samples Information: Name ADDITIONRL INFORMATION WeIlCored? YYTi ) Chips Received? 1T7'fi-- Analysis C~LLPd'~ Received? API No. 50-029-23279-00-00 UIC Y (data taken from Logs Portion of Master Well Data Maint Interval Start Stop OH / CH Received Comments 0 0 1/17/2006 DEFINITIVE SURVEY 0 5900 Case 3/26/2006 ASIT/GR/CCL 14-Dec-2005 , 5400 5824 Open 7/25/2006 Injection Profile/Water Flow Log RST-C Inverted, PRES, TEMP, SPIN O8- Apr-2006 65 6067 Open 3/16/2007 LIS Veri, GR, ROP, FET, NPHI, NCNT, DRHO i 65 6067 Open 3/16/2007 LIS Veri, GR, ROP, FET, NPHI, NCNT, DRHO 65 6067 Open 8!3/2007 LIS Veri, GR, ROP, FET, NPHI, NCNT, DRHO w/Graphics EMF and PDF "COPY OF DISK FROM 3/16/07** Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~/ N Formation Tops 1'/ N DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051500 Well Name/No. PRUDHOE BAY UN ORIN V-212 Operator BP EXPLORATION (ALASKA) INC MD 6150 ND 5048 Completion Date 12!1512005 Completion Status WAGIN Current Status WAGIN Comments: Compliance Reviewed By: _ API No. 50-029-23279-00-00 UIC Y -- ~ .. _ -- Date: - _~__ e vr' _P~ (~- - • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : V-212 V-212: Digital Log Images: 50-029-23279-00 June 25, 2007 AK-MW-4084736 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd: Anchorage, Alaska 995 ,~ Date: ~~~ ~ ~~~~ BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ate; ~,s~~~~ u=G aas - ~'S° ~ 153~~ ~r • WELL LOG TRANSMITTAL To: State of Alaska February 5, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: V-212, AK-'VIW-4084736 1 LDWG formatted CD rom with verification listing. API#: 50-029-23279-00 PLEASE ACK'V"OWLEDGE RECEIPT BY SIGNING AND RETU'R.NING A COPY OF THE TRA:~TSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish ~ Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 - ~ ~ ~ 1~: , ~~~ ,~ 0 Date: ~~'~' ~ `~~ ~`~3°'3 Signed: ;; f , i` ;'ice.. Scblumberger Schlumberger-DCS 2525 Gambeli St, Suke 400 Anchorage, AK 99503-2838 ATTN: Beth Welt Job # Log Description NO. 3873 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suhe 100 Anchorage, AK 99501 Field: Orion, Aurora, Borealis, Polaris Date BL Color CD V-212 11225953 INJECTION PROFILElWFL 04I08lO6 1 L-212 11217240 INJECTION PROFILE 04!16/06 1 L-216 11217241 INJECTION PROFILE 04I17/O6 1 L-215 11217242 INJECTION PROFILE 04118/06 1 V-213 REDO 11076450 INJECTION PROFILE 07/01/05 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. PeVOtechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: ~,~ S /~j~-, Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 A ATTN: Beth ~ Received by: ^ -~~ o6rzafo6 • • STATE OF ALASKA ALASK~IL AND GAS CONSERVATION COM SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG 20AAC25.105 2oAAC2s.~~o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: An a ^ Development ~~x~r ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 12/15/2005 12. Permit to Drill Number 205-150 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/2/2005 13. API Number 50-029-23279-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 12/10/2005 14. Well Name and Number: PBU V-212 4874 FSL, 1634 FEL, SEC. 11, T11 N, R11 E, UM Top of Productive Horizon: 998' FSL, 775' FW L, SEC. 01, T11 N, R11 E, UM g, KB Elevation (ft): 80' 15. Field /Pool(s): Prudhoe Bay Field / Orion Schrader Bluff Total Depth: 996' FSL, 775' FW L, SEC. 01, Ti 1 N, R11 E, UM 9. Plug Back Depth (MD+TVD) 6055 + 4953 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 590666 70123 y- 59 Zone- ASP4 10. Total Depth (MD+TVD) 6150 + 5048 Ft 16. Property Designation: ADL 028240 _ __ _ TPI: x- 593057 _ y- 5971555 Zone- ASP4) Total Depth: x- 593057 Y- 5971554 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: -~------------- ------------ ---------~--~ Thi k f P f 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL ness o erma rost c 20. 1900' (Approx.) 21. Logs Run: MWD / GR, MWD / GR / RES /DEN / NEU / PWD, USIT 2. ASING, LINER AND EMENTING ECORD CASING INO EPTH MD ETTINO EPTH TVD HOLE MOUNT SIZE WT. PER FT. - GRADE OP TTOM OP TTOM $IZE CEMENTING RECORD PULLED; 20" 215.5# A-53 Surtace 106' Surtace 106' 42" 60 sx Arctic Set A rox. 9-5/8" 40# L-80 28' 3233' 28' 2689' 12-1/4" 597 sx AS Lite, 379 sx Class 'G' 7" 26# L-80 25' 6140' 25' 5038' 8-3/4" 80 sx LiteCrete 216 sx Class 'G' 23. Pertorations open to Produc tion (MD + TV D of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" Gun Diameter, 5 spf 3-1/2", 9.2#, L-80 5846' 5485', 5654', 5763' MD TVD MD TVD 5610' - 5644' 4508' - 4542' 5674' - 5700' 4572' - 4598' 25, ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5714' - 5736' 4612' - 4634' 74' 472 ' ' ' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 5822 - 58 0 - 4772 Freeze Protect with 90 Bbls Diesel 26. PRODUCTION TEST Date First Production: January 2, 2006 Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submi~cbie chips;`if none, state "none". None ~~ 1- t•_ _ ~ ~ ~~Q~ ~t" 13~,~ ORlG!l~~L. ~E~~~V~~ FE~3 1 6 2006 Ala ~ ' n Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 213. GEOLOGIC MARKER 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 3575' 2904' None Ugnu MA 5208' 4112' Ugnu MB1 5253' 4155' Ungu MB2 5318' 4218' Ugnu MC 5399' 4298' Schrader Bluff NA 5447 4345' Schrader Bluff NB 5471' 4369' Schrader Bluff NC 5505' 4403' Schrader Bluff OA 5609' 4507' Schrader Bluff OBa 5673' 4571' Schrader Bluff OBb 5713' 4611' Schrader Bluff OBc 5770' 4668' Schrader Bluff OBd 5821' 4719' Schrader Bluff OBe 5888' 4786' Schrader Bluff OBf 5928' 4826' Base Schrader Bluff OBf 5977' 4875' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si d 0~~ ~ / gne ~ ~ Title Technical Assistant Date Terrie Rubble PBU V-212 205-150 Prepared By Narne/Number.• Te/rie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Matt Marryn, 564-4101 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. 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 elevation in feet above mean low low water. 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: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 12/21/2005 1:52:13 PM BP EXPLORATION Operations Summary Report Legal Well Name: V-212 Common Well Name: V-2121 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To 'Hours Task Code NPT 12/1 /2005 ~ 01:30 - 03:30 ~ r 2.001 MOB ~ P 03:30 - 04:30 1.00 MOB P 04:30 - 07:00 2.50 MOB P 07:00 - 07:30 0.50 MOB P 07:30 - 12:00 I 4.50 I MOB I P 12:00 - 17:30 I 5.501 MOB I P 17:30 - 20:30 3.00 RIGU P 20:30 - 00:00 3.50 RIGU P 12/2/2005 00:00 - 02:30 2.50 RIGU P Start: 12!212005 Rig Release: 12/15/2005 Rig Number: Phase PRE PRE PRE PRE PRE PRE PRE PRE PRE Page 1 of 12 Spud Date: 12/2/2005 End: 12/15/2005 Description of Operations Held PJSM, Moved Motor Complex, Moved Pump Room, Moved Pit Complex, Rigged Down Floor and Secured Top Drive. Laid Mats Around Well V-2121. Held PJSM, Pulled Rig Off of V-2141. Moved Rig Down Well Row to V-2121. Held PJSM. Pad Operator Shut In V-103 and V-106. Set Diverter on V-2121 Conductor. Lined Up and Moved Rig Over V-2121. Leveled, Shimmed and Set Rig. Spotted, and Set Pump #2 Module, Pit Module and Power Module. Nipple Up Diverter System R / U #2 Mud Pump and Mud Pits. Accepted Rig at 0000 hrs. Continued to Rig Up Pump and Pit Modules. Checked Lines, Took on Spud Mud. Held Pre-Spud Meeting w/ Rig Crews, Toolpusher and Drilling Supervisor. Tested Surface Diverter System. Witness of Test Waived by AOGCC Rep John Crisp. P / U and Stood Back 18 Joints of 4" HWDP, 90 Joints of 4" DP. Held PJSM. R / U Gyrodata Equipment. Repaired Top Drive Control Valve Block System. P / U and Stood Back Non-Mag Flex Drill Collars. M / U BHA #1, Orient Motor and MWD, 85.92 Degree Offset. Orient UBHO Sub. Upload MWD. Fill Riser and Check for Leaks. Tag at 106' Drill 12 1/4" Surface Hole from 106' to 169' Up Weight 55,000 lbs. Down Weight 55,000 lbs. Rotating Weight 55,000 lbs. 40 rpm with 2,000 fUlbs Torque on and off Bottom. Weight on Bit 3,000 lbs. Pump Pressure 800 psi on Bottom, 760 psi off Bottom at 450 gpm. ART-1.08 hrs. 02:30 - 03:00 0.50 RIGU P PRE 03:00 - 03:30 0.50 RIGU P PRE 03:30 - 09:00 5.50 RIGU P PRE 09:00 - 11:00 2.00 RIGU P PRE 11:00 - i7:00 6.00 RIGU N RREP PRE 17:00 - 18:00 1.00 RIGU P PRE 18:00 - 21:00 3.00 RIGU P PRE 21:00 - 22:00 1.00 RIGU P PRE 22:00 - 00:00 2.00 DRILL P SURF 12/3/2005 00:00 - 05:00 5.00 DRILL ~ P 05:00 - 00:00 I 19.001 DRILL I P 12/4/2005 100:00 - 12:00 I 12.001 DRILL I P At 155' the Well Took 90 bbls. Checked all Wells on Location for Fluid. Found None SURF Drill 12 1/4" Surface Hole from 169' to 300'. WOB 10,000#, rpm 40, Torque 3,000 ft /Ibs, Pump Rate 425 gpm, 900 psi. String Weight Up 60,000#, String Weight Down 60,000#, String Weight Rotating 60,000#. SURF Drilled 12-1/4" Directional Hole by Rotating and Sliding from 300' to 1,002'. WOB Sliding 10,000# - 15,000#, WOB Rotating 15,000# - 20,000#, RPM 40, Motor RPM 130, Torque Off Bottom 2,000 ft /Ibs - On Bottom 4,000 ft /Ibs, Pump Rate 500 gpm, SPP Off Bottom 1,400 psi, On Bottom 1,540 psi. String Weight Up 75,000#, String Weight Down 75,000#, String Weight Rotating 75,000#. Ran Gyrodata Every Connection 350' - 1,002'. 5.18 Hours AST, 5.23 Hours ART SURF Drilled 12-1/4" Directional Hole by Rotating and Sliding from 1,002' to 1,758'. WOB Sliding 15,000# - 20,000#, WOB Rotating 15,000# - 20,000#, RPM 40, Motor RPM 156, Torque Off Bottom 2,500 ft /Ibs - On Bottom 4,000 ft /Ibs, Pump Rate 600 gpm, SPP Off Bottom 2,200 psi, On Bottom 2,300 psi. String Weight Up 80,000#, String Weight Down 85,000#, String Printed: 12/21/2005 1:52:21 PM BP EXPLORATION Page 2 of 12 Operations Summary Report Legal Well Name: V-212 Common W ell Name: V-2121 Event Nam e: DRILL+C OMPLE TE Contractor Name: DOYON DRILLIN G INC . Rig Name: DOYON 16 Date 'I From - To Hours Task I Code NPT 12/4/2005 00:00 - 12:00 12.00 DRILL P 12:00 - 14:30 2.50 DRILL P 14:30 - 15:00 0.50 DRILL P 15:00 - 16:00 1.00 DRILL P 16:00 - 18:00 2.00 DRILL P 18:00 - 19:30 1.50 DRILL P I 19:30 - 22:00 2.50 DRILL P 22:00 - 00:00 2.00 DRILL P 12/5/2005 00:00 - 12:00 12.00 DRILL P 12:00 - 16:00 4.00 DRILL P 16:00 - 18:00 2.00 DRILL P 18:00 - 19:30 1.50 DRILL P 19:30 - 22:00 2.50 DRILL P 22:00 - 00:00 2.00 DRILL P 12/6/2005 00:00 - 02:00 2.00 DRILL P Spud Date: 12/2/2005 Start: 12/2/2005 End: 12/15/2005 Rig Release: 12/15/2005 Rig Number: Phase Description of Operations SURF Weight Rotating 83,000#. Rigged Down Gyrodata. SURF Drilled 12-1/4" Directional Hole by Rotating and Sliding from 1,758' to 1,886'. WOB Sliding 20,000#, WOB Rotating 20,000#, RPM 40, Motor RPM 156, Torque Off Bottom 2,500 ft /Ibs - On Bottom 4,000 ft /Ibs, Pump Rate 600 gpm, SPP Off Bottom 2,480 psi, On Bottom 2,600 psi. String Weight Up 82,000#, String Weight Down 85,000#, String Weight Rotating 85,000#. SURF Pumped and Circulated Around 40 bbl Weighted Sweep, 600 gpm, 2,500 psi. Reciprocated and Rotated Drill String 80 rpm. SURF Blew Down Top Drive. POOH w/ 4" DP. Average Drag 15,000#, 40,000# Overpull - 1,620', 75,000# Overpull - 1,030'. SURF POOH w/ BHA, B / O and L / D UBHO Sub. Download Data and Inialize MW D. C / O Bit. SURF RIH with BHA #2, Bit (MXC-1 ), 8" Sperrydril Lobe 4/5, Sleeve Type Stablizer, 8" NPT Gam / Res MWD, Non Mag Float Sub, 3 x Non Mag Flex Drill Collars, XO, Drilling Jar, XO, 20 x 4" HW DP. Total BHA Lenght = 808.17' SURF RIH with 4" Drillpipe to 1,886'. No Problems. Break Circulation at 1,000' SURF Drilled 12-1/4" Directional Hole by Rotating and Sliding from 1,886' to 1994'. WOB Sliding 20,000#, WOB Rotating 20,000#, RPM 40, Motor RPM 156, Torque Off Bottom 3,000 ft /Ibs - On Bottom 4,500 ft /Ibs, Pump Rate 600 gpm, SPP Off Bottom 2,670 psi, On Bottom 2,750 psi. String Weight Up 87,000#, String Weight Down 75,000#, String Weight Rotating 77,000#. SURF Drilled 12-1/4" Directional Hole by Rotating and Sliding from 1,994' to 3,021'. WOB Sliding 20,000#, WOB Rotating 15,000# - 20,000#, RPM 80, Motor RPM 156, Torque Off Bottom 5,000 ft /Ibs - On Bottom 7,000 ft /Ibs, Pump Rate 600 gpm, SPP Off Bottom 2,850 psi, On Bottom 2,980 psi. String Weight Up 90,000#, String Weight Down 75,000#, String Weight Rotating 85,000#. Encountered Hydrates at 2,550', Gas broke out at surface, caused drilling mud to splash on rotary table. Notified 5700 at 07:45 hrs. SURF Drilled 12-1/4" Directional Hole by Rotating and Sliding from 3,021' to 3,239'. WOB Sliding 5,000# - 8,000#, WOB Rotating 5,000# - 10,000#, RPM 80, Motor RPM 104, Torque Off Bottom 5,000 ft /Ibs - On Bottom 7,000 ft /Ibs, Pump Rate 400 gpm, SPP Off Bottom 1,850 psi, On Bottom 1,980 psi. String Weight Up 97,000#, String Weight Down 75,000#, String Weight Rotating 90,000#. Reduced Pump Rate to 400 gpm and Control Drilled from 3,021' to 3,239' to Clean Up MWD Signal. SURF Circulated 3 x Bottoms Up, Pump Rate 600 gpm, 2,660 psi. Stand Back 1 Stand of Drillpipe Every 30 minutes SURF Monitor Well, (Mud Weight 9.3 ppg). POOH to 808'. Overpulled 25,000# at 2,902', 2,335', 2,130'. Overpulled 40,000# at 2,800'. SURF RIH from 808' to 3,239'. Took 25,000# Drag at 1,660', 2,130', 2,285', 2,319', M / U Top Drive and Work Hole at 2,450'. Wash from 3,202' to 3,239' SURF Pump 40 bbl Weighted Sweep Around. Pump Rate 620 gpm, 2,880 psi. Stand Back 1 Stand of Drillpipe Every 30 minutes. SURF Monitor Well, (Mud Weight 9.3 ppg). POOH with 4" Drillpipe and 4" HWDP to 198'. No Problems. Printed: 12/21/2005 1:52:21 PM BP EXPLORATfON Operations Summary Report Legal Well Name: V-212 Common Well Name: V-2121 Event Name: DRILL+COMPLETE Start: 12/2/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/15/2005 Rig Name: DOYON 16 Rig Number: Date .From - To ~ Hours Task Code I NPT Phase 12/6/2005 02:00 - 04:00 2.00 DRILL P SURF 04:00 - 04:30 0.50 DRILL P SURF 04:30 - 07:00 2.50 CASE P SURF 07:00 - 13:00 6.001 CASE P SURF 13:00 - 14:00 1.001 CEMT P SURF 14:00 - 16:30 I 2.501 CEMT I P I I SURF 16:30 - 19:30 I 3.001 CEMT I P I I SURF Page 3 of 12 Spud Date: 12/2/2005 End: 12/15/2005 Description of Operations Hold PJSM, Lay Down BHA #2 Clear Rig Floor Hold PJSM, Rig Up 9 5/8" Casing Handling Equipment. Remove Short Bails, Install Long Bails. Held PJSM, RIH with Float Shoe, Jts. #1 and #2 9-5/8" L-80 40# BTC-M Casing, Float Collar and Jt #3. Check Float Equipment, OK. Continue to RIH with Jts. #4- #77 9-5/8" Casing, Breaking Circulation Every 20 Jts at 400 gpm for 5 Minutes. B / O and L / D Franks Fill Up Tool. M / U 9-5/8" Fluted Hanger. P / U and M / U Landing Jt. Remove Casing Slips. Install Cement Head and M / U Cementing Hose. Break Circulation at 4 bpm at 380 psi. Stage Up to 10 bpm at 950 psi. Reciprocated Pipe During Circulation, String Weight Up 175,000#, String Weight Down 105,000#. SIMOPS: Held PJSM for Upcoming Cement Job with Rig Crew, Toolpusher, BP Supervisor, Schlumberger Cementing Crew, Veco Truck Drivers'and MI Mud Man. Switched to Dowell, Pumped 5 bbls Water, 3 bpm, 100 psi. Shut in Cement Manifold, Tested Lines to 3,500 psi, OK, Bled Down Pressure. Dropped Bottom Plug, Pumped 70 bbls 10 ppg Mudpush 5 bpm / 150 psi. Mixed and Pumped 472 bbls (480 sks) 10.6 ppg ArcticSet Lite Cement, Followed by 79 bbls (660 sxs) 15.8 ppg Premium Class G Cement w/ 0.300 %bwoc Dispersant, 0.600 %bwoc Accelerator, 0.200 gal / sk Antifoam, 0.40 %bwoc Fluid Loss. Durastone 15# per/bbl Last 20 bbls in Tail Slurry. Pumped Cement at the Following Rates: Pumped Rate Pressure 50.0 bbls 7.75 bpm 810 psi 100.0 bbls 7.75 bpm 810 psi 150.0 bbls 7.75 bpm 810 psi 200.0 bbls 7.75 bpm 810 psi 250.0 bbls 7.75 bpm 810 psi 300.0 bbls 7.75 bpm 900 psi 350.0 bbls 7.75 bpm 920 psi 400.0 bbls 7.75 bpm 950 psi 450.0 bbls 7.75 bpm 1,000 psi 470.0 bbls 7.75 bpm 1,000 psi Tail Cement 25.0 bbls 5.75 bpm 1,150 psi 50.0 bbls 5.75 bpm 1,100 psi 79.0 bbls 5.75 bpm 1,100 psi Dropped Top Wiper Plug, Pumped 5.0 bbls Water 5.50 bpm, 140 psi. Switched to Rig Pumps and Displaced Cement with 234 bbls of Mud at the Following Rates: Pumped Rate Pressure 25.0 bbls 8.0 bpm 950 psi 50.0 bbls 10.0 bpm 960 psi 75.0 bbls 10.0 bpm 990 psi 100.0 bbls 8.0 bpm 730 psi 125.0 bbls 8.0 bpm 780 psi 150.0 bbls 8.0 bpm 820 psi 175.0 bbls 8.0 bpm 910 psi Printed: 12/21/2005 1:52:21 PM BP EXPLORATION Page 4 of 12 Operations Summary Report Legal Well Name: V-212 Common Well Name: V-2121 Spud Date: 12/2/2005 Event Name: DRILL+COMPLETE Start: 12/2/2005 End: 12/15/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/15/2005 Rig Name: DOYON 16 Rig Number: Date ;From - To ~ Hours ~! Task ~ Code =~NPT Phase 12/6/2005 ~ 16:30 - 19:30 ~ 3.001 CEMT P ~ ~ SURF 19:30 - 23:00 I 3.501 CEMT I P I I SURF 23:00 - 00:00 1.00 CASE P SURF 12/7/2005 00:00 - 02:30 2.50 CEMT P SURF 02:30 - 04:00 1.50 WHSUR P SURF 04:00 - 06:00 2.00 BOPSU P SURF 06:00 - 07:00 1.00 BOPSU P SURF 07:00 - 11:30 4.50 BOPSU P SURF 11:30 - 12:30 1.00 BOPSU P SURF 12:30 - 16:30 4.00 ~ BOPSUF#N ~ RREP SURF 16:30 - 17:30 1.00 BOPSU P SURF 17:30 - 22:30 5.00 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P PROD1 12/8/2005 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 02:00 1.50 DRILL P PROD1 02:00 - 03:30 I 1.501 DRILL I P I I PROD1 03:30 - 06:00 ~ 2.501 CASE P ~ PROD1 Description of Operations 200.0 bbls 8.0 bpm 1,000 psi 220.0 bbls 3.0 bpm 620 psi 234.0 bbls 3.0 bpm 650 psi 234.0 bbls Total Displacement Pumped. Pressured up to 1,500 psi to Bump Plug. Bled Down Pressure and Checked Floats, Floats Held. Cement In Place at 1915 hrs. 165 bbls Cement Back to Surface Flushed Riser and Diverter, R / D Cement Head. B / O and L / D Landing Joint. R / D and Cleared 9 5/8" Handling Equipment Off Rig Floor. Held PJSM, N / D Diverter Line and Knife Valve N / D 20" Drilling Riser, 20" Annular and Diverter Spool, Removed 4" Annulus Valves. N / U FMC Wellhead and Tubing Spool, Tested to 1,000 psi f/ 30 minutes. Held PJSM, N / U BOPE: 13-5/8" 5M GK Annular Preventer, 13-5/8" 5M Upper Rams w/ 3-1/2" x 6" Variable Rams, 13-5/8" 5M Blind Shear Rams, Mud Cross w/ Kill /Choke Lines, 13-5/8" Lower Pipe Rams with 2-7/8" x 5" Variable Rams, 13-5/8" x 11" DSA, N / U Secondary Annulus Valve. Function Tested BOPE, R / U BOPE Test Equipment. Tested BOPE to 250 psi / 4,000 psi. Test #1, Hydril, Upper IBOP, Dart Valve, Kill HCR, Choke Valves 1, 12, 13, 14. Test #2, Upper Rams, Lower IBOP, Manual Kill, Choke Valves 9,11. Test #3, Choke Valves 5, 8,10, TIW. Test # 4, Choke Valves 4, 6, 7. Test #5, Choke Valve 2. Circulated Bottoms Up at 1,800', 6 bpm, 200 psi RIH with 8-3/4" Directional BHA on 4" DP. P / U DP 1 x 1 from Pipeshed M / U Top Drive, Established Parameters, String Weight Up 95,000#, String Weight Down 90,000#, Rotating String Weight 92,000#, Pump 6.5 bpm, 710 psi. Rotary 25 rpm, Torque 5,000 ft/Ibs. Washed Down from 3,134' to 9-5/8" Float Collar at 3,145'. No Cement. Circulated and Conditioned Mud for Casing Test. Monitored Well, Static. Blew Down Top Drive. M / U Circulating Head, R / U Test Equipment and Chart Recorder. C{osed Upper Pipe Rams and Opened Kill Line. Pumped Down Drill Pipe and Kill Line Simultaneously at 1/2 bpm with the Following Strokes and Pressure. Strokes Pressure 3 stks 300 psi 6 stks 610 psi 9 stks 920 psi 12 stks 1,170 psi 15 stks 1,450 psi 18 stks 1,630 psi 21 stks 1,900 psi 24 stks 2,080 psi 27 stks 2,450 psi 30 stks 2,760 psi Printed: 12/21/2005 1:52:21 PM BP EXPLORATION Page 5 of 12 Operations Summary Report Legal Wefl Name: V-212 Common Well Name: V-2121 Spud Date: 12/2/2005 Event Name: DRILL+COMPLETE Start: 12/2/2005 End: i 2!15/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/15/2005 Rig Name: DOYON 16 Rig Number: Date From - To j Hours I Task Code I NPT PhaseI Description of Operations 12/8/2005 03:30 - 06:00 2.50 CASE P PROD1 33 stks 3,050 psi 36 stks 3,360 psi 39 stks 3,500 psi Shut In Low Torque Valve at Head Pin to Isolate and Monitor for Pressure Loss Minutes Pressure 1 min. 3,490 psi 2 min. 3,480 psi 3 min 3,470 psi 4 min 3,460 psi 5 min 3,450 psi 10 min 3,440 psi 15 min 3,430 psi At +/- 16 minutes Observed Steady Pressure Loss of 100 psi Per Minute. Bled Down Pressure and Checked Circulating System for Leaks. No Leaks or Pressure Loss. Repressured Casing to 3,500 psi and Observed Pressure Loss of 150 psi Per Minute. Bled Down Pressure. Opened Top Pipe Rams and Closed Bottom Pipe Rams and Repressured Casing to 3,500 psi. Observed 150 psi Pressure Loss Per Minute. Bled Down Pressure, Opened Pipe Rams. R / D Testing Lines and M / U Top Drive, Closed Top Pipe Rams and and Retested to 3,500 psi with Same Results. Consulted with Anchorage, Decision Made to Run RTTS. 06:00 - 07:30 07:30 - 10:00 10:00 - 11:00 11:00 - 12:00 12:00 - 15:00 1.50 CASE N DFAL PROD1 POOH w/ 4" DP. 2.50 CASE N DFAL PROD1 POOH w/ BHA, Cleared Floor, Removed Radioactive Sources. B / O and L / D Directional Tools. Cleared and Cleaned Rig Floor. 1.00 CASE N DFAL PRODi Held PJSM. M / U 9-5/8" RTTS. 1.00 CASE N DFAL PROD1 RIH w/ RTTS on 4" DP to 1,606' 3.00 CASE N DFAL PROD1 M / U Top Drive, Established Parameters, String Weight Up 67,000#, String Weight Down 67,000#. Circulated 10 bbls to Clear RTTS. Set RTTS at 1,606'. Pressure Tested Below RTTS to 3,500 psi, Lost 1,600 psi in 4 min, Bled Down Pressure. Closed Pipe Rams and Test Above RTTS to 3,500 psi, OK, Bled Down Pressure and Released RTTS RIH w/ RTTS to 2,470', Set RTTS and Pressure Tested Below to 3,500 psi, Lost 2,000 psi in 4 min, Bled Down Pressure and Released RTTS. RIH w/ RTTS to 3,135' Set RTTS and Pressure Tested Below to 3,500 psi, Bled Down to 1,500 psi in 2 min - 500 psi, 5 Min - 350 psi, 10 min - 340 psi, 20 min - 340 psi, 25 min - 340 psi, 30 min. 15:00 - 16:00 1.00 CASE N DFAL PROD1 Closed Pipe Rams and Test Above RTTS to 4,000 psi f/ 30 Min, Pumped 2 bpm with the Following Strokes and Pressures. Strokes Pressure 5 stks 400 psi 10 stks 1,100 psi 15 stks 1,750 psi 20 stks 2,350 psi 25 stks 2,900 psi 30 stks 3,500 psi 34 stks 4,000 psi Shut In and Monitored for Pressure Loss Printed: 12/21/2005 1:52:21 PM BP EXPLORATION Operations Summary Report Page 6 of 12 Legal Well Name: V-212 Common W ell Name: V-2121 Spud Date: 12/2/2005 Event Nam e: DRILL+C OMPLE TE Start : 12/2/2005 End: 12/15/2005 Contractor Name: DOYON DRILLIN G INC . Rig Release: 12/15/2005 Rig Name: DOYON 16 Rig Number: Date " i From - To ' ~ Hours Task Code NPT Phase Description of Operations 12/8/2005 15:00 - 16:00 1.00 CASE N DFAL PROD1 Minutes Pressure 0 min. 3,980 psi 5 min. 3,980 psi 10 min 3,970 psi 15 min 3,950 psi 20 min 3,950 psi 25 min 3,950 psi 30 min 3,950 psi Bled Down Pressures and Released RTTS. 16:00 - 17:30 1.50 CASE N DFAL PROD1 POOH w/ 4" DP. 17:30 - 18:00 0.50 CASE N DFAL PROD1 POH w/ 4" HW DP, B / O and L / D Halliburton RTTS 18:00 - 20:30 2.50 CASE N DFAL PROD1 M / U 8-3/4" HTC HMC506Z PDC Bit Ser# 7109704, w/ 4 x 14 Jets, 2 x 13 Jets to 7" SperryDrill Lobe 7/8 6.0 Stg Mud Motor w/ 1.5 deg Bend, Integral Blade Stablizer, NM Hang-off Collar. M / U MWD Hung Off in Rotary Table. Initialized MWD. Pulse Test MWD. Load Nukes. Continue to M / U BHA, NM Hang-off Collar, 3 x NM Flex Collars, XO, 15 x 4" HW DP, XO, Drilling Jar, XO, 5 x 4" HWDP, Ghost Reamer. BHA Length 854.02'. 20:30 - 21:30 1.00 CASE N DFAL PROD1 RIH w/ 4." DP to 3,067' 21:30 - 22:30 1.00 DRILL P PROD1 M / U Top Drive, Established Parameters, String Weight Up 104,000#, String Weight Down 79,000#, Rotating String Weight 90,000#, Pump 5 bpm, 700 psi. Rotary 40 rpm, Torque 5,000 fUlbs. Washed Down from 3,067' to 3,145'. Drill Float Equipment, Cement and Clean Out 12-1/4" Rathole to 3,239. Dri11 20' of New 8-3/4" Hole to 3,259'. WOB 5,000# - 7,000#. Rotary 40 rpm, Torque 6,000 ft/Ibs. Pump 10 bpm, 1,670 psi. 22:30 - 23:30 1.00 DRILL P PROD1 Circulate and Condition LSND Mud for FloPro NT Mud Displacement. Pump 8 bpm, 1,100 psi 23:30 - 00:00 0.50 DRILL P PROD1 Pump 75 bbl Water Spacer, 40 bbl Hi-Vis Sweep Followed by FloPro NT Mud 12/9/2005 00:00 - 00:30 0.50 DRILL P PROD1 Displaced Wellbore with 8.8 ppg FloPro Nt Mud at 10 bpm, 1,275 psi. Monitor Well, Static. B / O Top Drive and Blew Down Same. 00:30 - 01:30 1.00 DRILL P PROD1 R / U Circulating Head Pin, Hi-Torque Valve, Test Hose. and Chart Recorder. Opened Kill Line and Closed Pipe Rams. Performed LOT at 3,259' MD. at 1/2 bpm with the Following Strokes and Pressures. Strokes Pressure 1 stk 75 psi 2 stks 150 psi 3 stks 225 psi 4 stks 300 psi 5 stks 375 psi 6 stks 450 psi 7 stks 525 psi 8 stks 575 psi 9 stks 615 psi 10 stks 650 psi 11 stks 680 psi Shut In and Monitored for Pressure Loss. Minutes Pressure 1 min 530 psi 2 min 490 psi Printed: 12/21/2005 7:52:27 PM BP EXPLORATION Page 7 of 12 Operations Summary Report Legal Well Name: V-212 Common Well Name: V-212i Spud Date: 12/2/2005 Event Name: DRILL+COMPLETE Start: 12/2/2005 End: 12/15/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/15/2005 Rig Name: DOYON 16 Rig Number: Date From - To ~I Hours Task ~ Code' NPT ' Phase Description of Operations 12/9/2005 00:30 - 01:30 1.00 DRILL P PRODi 3 min 460 psi 4 min 440 psi 5 min 430 psi 6 min 420 psi 7 min 420 psi 8 min 420 psi 9 min 420 psi 10 min 420 psi Surface Pressure 525 psi Shoe TVD 2,692' MW 8.8 ppg LOT = 12.55 ppg Bled Down Pressure. Opened Pipe Rams. R / D Circulating Head Pin and Lines. 01:30 - 02:00 0.50 DRILL P PROD1 M / U Top Drive, Established Parameters, String Weight Up 105,000#, String Weight Down 75,000#, Rotating String Weight 87,000#, Pump 15 bpm 2,490 psi. Rotary 100 rpm, Torque 6,500 ft/Ibs. Obtained Clean Hole ECD of 9.44 ppg at 550 gpm, 100 rpm, Calculated ECD 9.50 ppg. 02:00 - 12:00 10.00 DRILL P PROD1 Drilled 8-3/4" Directional Hole by Rotating and Sliding from 3,259' to 4,370'. WOB Rotating 12,000#, WOB Sliding 15,000#, Motor RPM 174, Rotary RPM 100, Torque Off Bottom 8,000 fVlbs, Torque On Bottom 9,000 ft/Ibs, Pump Rate 610 gpm, SPP Off Bottom 2,950 psi, On Bottom 3,100 psi, String Weight Up 118,000#, String Weight Down 83,000#, Rotating Weight 95,000#. Calculated ECD 9.87 ppg, Actual ECD 10.1 ppg. Pumped 20 bbl Hi-Vis Weighted Sweeps Every 400'. 12:00 - 00:00 12.00 DRILL P PROD1 Drilled 8-3/4" Directional Hole by Rotating and Sliding from 4,370' to 5,410'. WOB Rotating 10,000#, WOB Sliding 10,000#, Motor RPM 174, Rotary RPM 100, Torque Off Bottom 9,000 ft/Ibs, Torque On Bottom 8,500 fUlbs, Pump Rate 613 gpm, SPP Off Bottom 3,350 psi, On Bottom 3,520 psi, String Weight Up 140,000#, String Weight Down 95,000#, Rotating Weight 115,000#. Calculated ECD 9.64 ppg. Actual ECD 9.80 ppg. AST 4.92 hrs. ART 5.35 hrs. Pumped 20 bbl Hi-Vis Weighted Sweeps Every 400'. 12/10/2005 00:00 - 08:30 8.50 DRILL P PROD1 Drilled 8-3/4" Directional Hole by Rotating and Sliding from 5,410' to 6,150'. WOB Rotating 15,000#, WOB Sliding 5,000#, Motor RPM 174, Rotary RPM 100, Torque Off Bottom 8,000 ft/Ibs, Torque On Bottom 9,000 fUlbs, Pump Rate 610 gpm, SPP Off Bottom 3,850 psi, On Bottom 4,000 psi, String Weight Up 150,000#, String Weight Down 115,000#, Rotating Weight 135,000#. Calculated ECD 9.71 ppg. Actual ECD 9.85 ppg. Pumped 20 bbl Hi-Vis Weighted Sweeps Every 400'. AST - 1.55 hrs, ART - 3.28 hrs. 08:30 - 11:00 2.50 DRILL P PROD1 Pumped and Circulated Around 40 bbl Hi-Vis Weighted Sweep, 3 x Bottoms Up. Pump Rate 610 gpm, 3,710 psi. Reciprocated and Rotated Drill String 110 rpm. 11:00 - 16:00 5.00 DRILL P PROD1 Performed MAD Pass from 6,140' - 5,400'. 100 rpm, 600 gpm, 3,700 psi. Trip Speed 250' / hr. Printed: 12/21/2005 1:52:21 PM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date I From - To 12/10/2005 ~ 16:00 - 18:00 18:00 - 00:00 12/11/2005 ~ 00:00 - 01:00 01:00 - 02:30 02:30 - 04:30 04:30 - 07:30 07:30 - 09:00 09:00 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 18:30 18:30 - 19:30 19:30 - 20:00 V-212 V-212i DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Hours i Task Code ~ NPT 2.001 DRILL P Page 8 of 12 Spud Date: 12/2/2005 Start: 1212/2005 End: 12!15/2005 Rig Release: 12/15/2005 Rig Number: Phase I Description of Operations PROD1 Pumped and Backed Reamed Out of the Hole from 5,400' - 4,320'. 100 rpm, 600 gpm, 3,450 psi. 6.00 DRILL P PROD1 Performed MAD Pass from 4,320' - 3,400'. Pumped and Back Reamed from 3,400' - 3,233'. 100 rpm, 600 gpm, 3,170 psi. String Weight Up 102,000#, String Weight Down 83,000#, Rotating String Weight 91,000#, String Rotary 100 RPM, Torque 5,000 ft/Ibs. MAD Pass Trip Speed 250' ! hr. 1.001 DRILL I P 1.50 DRILL P 2.00 DRILL P 3.00 DRILL P 1.50 DRILL P 3.00 DRILL P 1.00 DRILL P 1.00 EVAL N 4.50 EVAL N 1.00 EVAL N 0.50 BOPSU P 20:00 - 21:00 1.00 BOPSU~ P 21:00 - 21:30 0.50 BOPSU P 21:30 - 22:00 I 0.501 CASE I P 22:00 - 23:00 I 1.001 CASE I P 23:00 - 00:00 ~ 1.00 CASE ~ P PROD1 Pumped and Circulated 20 bbl Hi-Vis Weighted Sweep at 3,230', 610 gpm, 2,700 psi. PRODi RIH w/ 4" DP to 6,055'. No Hole Problems. PROD1 M / U Top Drive, Established Parameters, String Weight Up 155,000#, String Weight Down 110,000#, Rotating String Weight 133,000#, Pump 625 gpm 3,700 psi. Rotary 100 rpm, Torque 8,000 ft/Ibs. Precautionary Wash and Ream from 6,055' to 6,150'. Recriprocated and Rotated While Pumping 40 bbl Hi-Vis 2# Over Mud Weight Sweep Around. Total Circulation 3 Bottoms Up. Actual ECD 9.6 ppg, Calculated ECD 9.71 ppg, Monitored Well, Static. Pumped Dry Job. Blew Down Top Drive. MW 9.0+ ppg. PROD1 POOH w/ 4" DP. PROD1 POOH, B / O and L / D 20 Jts 4" HWDP. PROD1 POOH, B / O and L / D BHA Components. Cleared Rig Floor, Removed Radioactive Sources. Downloaded MWD Data. B / O and L / D MW D, Motor and Bit. PROD1 Cleared and Cleaned Rig Floor. DFAL PROD1 Held PJSM. R / U Schlumberger E-Line Equipment. DFAL PROD1 P / U and M / U USIT Logging Tools. Test E-Line Connection and Tools at Surface with CET Plug, Good Test. RIH with USI-CE Tool to 3,300'. Activated Tool at 500' Going In. Logged Up from 3,300', Unable to Get Good Data, Pull Up to 3,100' and Run Dianostic Check on DH Tools. Data Quality Improved. RIH to 3,300' and Log Up. Unable to Get Good Data. POH with USIT Tools. Inspected Tools at Surface, Shale and Sand in USIT Sub. B / O and L / D Tools. DFAL PROD1 Held PJSM. R / D Schlumberger E-Line Equipment PROD1 P / U Test Joint and M / U Wear Ring Pulling Tool. Pull Wear Ring, Install Test Plug. PRODi C / O Lower Pipe Rams to 7" PROD1 R / U Test Equipment. Test Lower Ram Door Seals to 250 psi low / 4,000 psi high for 5 min Each. Witness of Test was Wavied by AOGCC Rep. Jeff Jones. Test Witnessed by BP Drilling Supervisor. R / D Test Equipment and Pull Test Plug. RUNPRD P/U Landing Joint with 7" Hanger Installed. Make Dummy Run and Land in Wellhead. Mark Joint. Pull and L / D Hanger and Joint RUNPRD Held PJSM. Remove Elevators and Bails, Install Franks Fill Up Tool, R / U Long Bails and Casing Elevators, Hang Pickup Sling, R / U Casing Equipment. RUNPRD Held PJSM. RIH with 7" 26# L-80 BTM Casing Joints #1,2 & 3, Bakerloc All Connections Through Float Collar, Fill Shoe Joints and Check Floats. RIH with Joints #4 & #5. Make Up to Base Printed: 12/21/2005 1:52:21 PM BP EXPLORATION Operations Summary Report Legal Well Name: V-212 Common Well Name: V-212i Event Name: DRILL+COMPLETE Start: 12/2/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/15/2005 Rig Name: DOYON 16 Rig Number: Date From - To Hours I' Task CodeL 12/11/2005 23:00 - 00:00 1.00 CASE P 12/12/2005 00:00 - 04:00 4.00 CASE P 04:00 - 04:30 I 0.501 CASE I P 04:30 - 10:00 I 5.501 CASE I P 10:00 - 12:00 2.001 CEMT ~ P 12:00 - 13:00 I 1.001 CEMT I P 13:00 - 14:00 I 1.001 CEMT I P NPT Phase Page 9 of 12 Spud Date: 12/2/2005 End: 12/15/2005 Description of Operations RUNPRD of Triangle, Average Make Up Torque 8,000 ft/Ibs. Utilizing Best-O-Life 2000 NM Thread Dope on All Other Connections RUNPRD RIH with 7" 26# L-80 BTM Casing P / U Joints #6 - #77. Make Up to Base of Triangle, Average Make Up Torque 8,000 ft/Ibs. Utilizing Best-O-Life 2000 NM Thread Dope on All. Connections. Recording P / U and S / O Weights Every 500'. RUNPRD Circulated Bottoms Up at 3,233'. Staged Up Pump Rates 4 bpm, 175 psi and 6 bpm, 260 psi. String Weight Up 112,000#, String Weight Down 100,000#. RUNPRD RIH with 146 Jts 7" 26# L-80 BTM Casing, Average M / U Torque 8,000 tt / lbs. M / U 7" Casing Hanger and Landing Joint. Landed Hanger. String Weight Up 210,000#, String Weight Down 124,000#. RUNPRD B / O and L / D Franks Tool, M / U Cement Manifold and Lines. Staged Up Pumps, 4 bpm - 500 psi, 6 bpm - 700 psi, 8 bpm - 950 psi. Reciprocated Pipe, P / U 5', Pipe Stacked Out, No Pipe Movement. Hanger 5' Off of Wellhead. Circulated to Cool and Clean Hole, 8 bpm - 1,000 psi. Spotted and Rigged Up Schlumberger Equipment. RUNPRD Held PJSM w/ Rig Crew, Schlumberger Crew, Truck Drivers, Mud Engineer, Tool Pusher and Drilling Supervisor. Continued to Circulate While Schlumberger Batch Mixed Cement. RUNPRD Switched to Schlumberger, Pumped 5 bbls Water, 4 bpm, 600 psi. Shut in Cement Manifold, Tested Lines to 4,000 psi, OK, Bled Down Pressure. Pumped 20 bbls CW-100, 5 bpm, 645 psi, Pumped 45 bbls 10.3 ppg Mudpush 4 bpm, 430 psi. Dropped Bottom Plug, Pumped 35 bbls (90 sks) 12.5 ppg Crete Cement w/ 0.300 %bwoc Dispersant, 0.120 %bwoc Retarder, 0.200 gal / sk Antifoam, 1.50 gal / sk GASBLOK, Followed by 40 bbls (85 sxs) 15.8 ppg Premium Class G Cement w/ 0.400 %bwoc Dispersant, 0.150 %bwoc Retarder, 0.200 gal / sk Antifoam, 2.00 gal / sk GASBLOK. Pumped Cement at the Following Rates: Pumped Rate Pressure Flow 5.00 bbls 5.00 bpm 980 psi 12% 10.00 bbls 5.00 bpm 980 psi 12% 15.00 bbls 5.00 bpm 950 psi 12% 20.00 bbls 5.00 bpm 930 psi 12% 25.00 bbls 5.00 bpm 920 psi 12% 30.00 bbls 5.00 bpm 900 psi 11% 35.00 bbls 4.50 bpm 800 psi 11% Tail Cement Pumped Rate Pressure Flow 5.00 bbls 5.00 bpm 865 psi 12% 10.00 bbls 5.00 bpm 850 psi 12% 15.00 bbls 5.00 bpm 800 psi 12% 20.00 bbls 5.00 bpm 750 psi 12% 25.00 bbls 5.00 bpm 725 psi 11 30.00 bbls 5.00 bpm 740 psi 12% 35.00 bbls 5.00 bpm 730 psi 13% 35.00 bbls 5.00 bpm 730 psi 14% Dropped Top Wiper Plug, Pumped 5.0 bbls Water 5.00 bpm, 250 psi. Switched to Rig Pumps and Displaced Cement with Printed: 12/27/2005 1:52:27 PM BP EXPLORATION Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date 12/12/2005 Name: V-212 ell Name: V-2121 e: DRILL+COMPLETE Start: Name: DOYON DRILLING INC. Rig Release: DOYON 16 Rig Number: From - To ~ Hours - I~ I Phase Task Code NPT - 13:00 - 14:00 ~ 1.00 ~ CEMT ~ P ~ ~ RUNPRD 14:00 - 15:00 1.00 ~ CEMT ~ P ~ ~ RUNPRD 15:00 - 16:00 i.00 BOPSU P RUNPRD 16:00 - 17:30 1.50 CASE P RUNPRD 17:30 - 19:00 1.50 CASE P RUNPRD 19:00 - 20:00 1.00 CASE P RUNPRD 20:00 - 21:00 1.00 CASE P RUNPRD 21:00 - 22:30 1.50 BOPSU P RUNPRD 22:30 - 23:30 1.00 BOPSU P RUNPRD 23:30 - 00:00 0.50 BOPSU P RUNPRD 12/13/2005 00:00 - 01:00 1.00 PERFO P OTHCMP 01:00 - 01:30 I 0.501 PERFOBI P I I OTHCMP Oi :30 - 03:30 I 2.001 PERFOBI P { I OTHCMP 03:30 - 04:00 I 0.501 PERFOBI P I I OTHCMP Description of Operations 226 bbls of Clean Seawater at the Following Rates: Pumped Rate Pressure Flow 5.00 bbls 8.00 bpm 340 psi 9% 25.00 bbls 8.00 bpm 340 psi 10% Caught Cement w/ 32.5 bbls Pumped 50.00 bbls 9.00 bpm 920 psi 17% 75.00 bbls 10.00 bpm 1,200 psi 19% 100.00 bbls 10.00 bpm 1,200 psi 20% 125.00 bbls 10.00 bpm 1,190 psi 20% 150.00 bbls 10.00 bpm 1,210 psi 20% 175.00 bbls 9.50 bpm 2,075 psi 19% 200.00 bbls 7.50 bpm 2,050 psi 16% 215.00 bbls 3.00 bpm 1,350 psi 12% w/ 216 bbls Pumped Hole Packed Off, Pressure Increased to 2,250 psi, Flow 0%, w/ 216.5 bbls Pumped, Pressure Dropped to 1,500 psi, Flow 0%. 220.00 bbls 3.00 bpm 1,500 psi 0% Bumped Plug w/ 231.00 bbls Total Displacement Pumped. Pressured up to 2,500 psi to Bump Plug, Held f/ 5 Minutes. Bled Down Pressure and Checked Floats, Floats Held. Cement In Place at 1400 hrs. Attempted to Land Hanger without Success. P / U to 250,000#. Pressure Tested 7" Casing to 4,000 psi f/ 30 Minutes, OK. Bled Down Pressure, Blew Down Lines. R / D Cement Lines and Manifold. Held PJSM. N i D BOP Stack, Break Tubing Head/Casing Head Flange Connection and Lift Stack 18". Held PJSM. Set 7" Emergency Slips with 250,000# Down Weight. Held PJSM. R / U WACH Cutter and Cut 7" Casing. Remove Landing Joint. Cut Off Stub 4.58". R / D Casing Elevators, C / O Bails, P / U DP Elevators. Clear and Clean Rig Floor Held PJSM. P / U Test Joint, Install Packoff Running Tool, Install 7" Packoff, B / O and i 1 D Running Tool N / U BOPE's. Test 7" Packoff to 5,000 psi. Install Test Plug. C / O Lower Rams to 2-7/8" x 5" Variables R / U Test Euipment. Test Lower Rams and 11" 5M Tubing Head Flange x 11" 5M Adaptor Flange to 250 psi low / 4,000 psi high. Tests Held 5 min Each. Witness of Test Wavied by AOGCC Rep. Jeff Jones. Test Witnessed By BP Drilling Supervisor. Pull Test Plug and L / D Test Joint C / O Elevators to 3-1/2" DP. Strap and Tally BHA Components, Stock Rig Floor with Schlumberger Handling Tools Held PJSM on Picking Up DPC Perforating Guns with Rig Crew, Schlumberger Perforating Crew, Tool Pusher Drilling Supervisor and Mud Man P / U and M / U Schlumberger 4-1/2" Perforating Guns and Firing Head, XO, XO, 3 x 4" HWDP, XO, Bumper Sub, MWD, XO. BHA Length 440.12' RIH with Perf Gun BHA and 2 Stands 4" DP to 625'. Break Circulation and Shallow Test MWD with 250 gpm, 350 psi. Printed: 12/21/2005 1:52:21 PM Page 10 of 12 Spud Date: 12/2/2005 12/2/2005 End: 12/15/2005 12/15/2005 BP EXPLORATION Page 11 of 12 Operations Summary Report Legal Well Name: V-212 Common W ell Name: V-2121 Spud Date: 12/2/2005 Event Nam e: DRILL+C OMPLE TE Start : 12/2/2005 End: 12/15/2005 Contractor Name: DOYON DRILLIN G INC . Rig Release: 12/15/2005 Rig Name: DOYON 16 Rig Number: I Date From - To Hours Task Code NPT ' Phase Description of Operations 12/13/2005 03:30 -04:00 0.50 PERFO P OTHCMP Good Pulse 04:00 - 05:00 1.00 PERFO P OTHCMP RIH w/ 4" DP at 1 min /stand to 2,840'. 05:00 - 05:30 0.50 PERFO P OTHCMP Circulate DP Volume at 210 gpm, 475 psi 05:30 - 07:30 2.00 PERFO P OTHCMP RIH w/4" DP to 6,055'. Break Circulation and Test MWD. Good Pulse 07:30 - 08:30 1.00 PERFO P OTHCMP Displace Seawater with 9.0 ppg Brine at 302 gpm, 1,200 psi 08:30 - 13:30 5.00 PERFO P OTHCMP Logged Up from 6,055' to 5,150' at 150` per/hr. Circulating Rate 270 gpm, 1,020 psi. Located RA Tag at 5,183'. RIH and Space Out Guns at the Following Intervals Sand Measured Depth Length OA 5610' - 5644' 34' OBa 5674' - 5700' 26' OBb 5714' - 5736' 22' OBd 5822' - 5874' 52' 13:30 - 14:00 0.50 PERFO P OTHCMP Held PJSM with Rig Crew, Schlumberger Perforating Crew Tool Pusher, Drilling Supervisor and Mud Man. 14:00 - 14:30 0.50 PERFO P OTHCMP Set Up Gun Firing Parameters. Pressure Up to 400 psi, Held 1 min. Pressure Up to 600 psi, Held 1 min. Bled Down Pressure to 0 psi,' Held 2 min. Pressure Up to 1,400 psi, Held 2 min. Bled Down Pressure to 0 psi. Guns Fired After 5 min Time Delay. Guns Fired at 1417 hrs. Lost 2 bbls Fluid. POH 5 Stand Dp to 5,390' 14:30 - 15:00 0.50 PERFO P OTHCMP Circulate Bottoms Up at 294 gpm, 1,100 psi. Monitor Well-Static. 15:00 - 20:30 5.50 PERFO P OTHCMP POH UD DP. MW 9.0 ppg Brine 20:30 - 22:30 2.00 PERFO P OTHCMP Held PJSM. POH with Perf Gun BHA and UD Same. All Shots Fired. 22:30 - 23:00 0.50 PERFO P OTHCMP Clear and Clean Rig Floor 23:00 - 00:00 1.00 EVAL P OTHCMP Held PJSM, R/U Schlumberger E-Line Equipment, String E-line, Hang Sheaves 12/14/2005 00:00 - 02:30 2.50 EVAL P OTHCMP M/U 6.118" Gauge Ring/Junk Basketand RlH to 5,935' Tight at 5,724', 5,420 and 5,122'. POH and Recovered +/- 1 cup Metal Shavings and Plastic. 02:30 - 04:30 2.00 EVAL P OTHCMP Rerun 6.118" Gauge Ring/Junk Basket to 5,930'. Tight at 5,624'. POH and Recovered +/- 1/2 cup Plastic and Cement 04:30 - 07:00 2.50 EVAL P OTHCMP Rerun 6.i 18" Gauge RinglJunk Basket to 5,895'. POH and UD Gauge Ring/Junk Basket 07:00 - 07:30 0.50 EVAL P OTHCMP P/U and M!U USIT Logging Tools 07:30 - 12:00 4.50 EVAL P OTHCMP RIH with USIT Log to 5,893'. Log Up to 4,400'. CMT at 4,600'. POH with USIT Logging Tools and L/D Same 12:00 - 13:00 1.00 EVAL P OTHCMP R/D Schlumberger E-Line Equipment. Clear and Clean Floor. 13:00 - 14:00 1.00 BUNCO RUNCMP Held PJSM. R/U Tubing Handling Equipment and Torque Turn Tongs and Computer 14:00 - 00:00 10.00 BUNCO RUNCMP Held PJSM. RIH with 3-1/2" 9.2# L-80 TCII Completion String. WLEG, 2 x Pup Jts, X nipple, 2 x Pup jts, X Nipple w/ RHC Plug, 2 x Pup Jts, GLM, 2 x Pup Jts, PKR, 2 x Pup Jts, GLM, 2 x Pup Jts, GLM, 2 x Pup Jts, X Nipple, 3 x Pup Jts, PKR w/ RA Tag, 2 x Pup Jts, GLM, 2 x Pup Jts, GLM, Pup Jt, 3 x Tbg Jts, Pup Jt, PKR, 2 x Pup Jts, X Nipple, 2 x Pup Jts, GLM w/ DCK Shear Valve, Pup Jt, 150 x Tbg Jts. All Connections Through Top Packer Bakerloc'd. All Other Connections Utilized Jet-Cube Pipe Dope. All Connections Torque Turned to 2,400 fUlbs. 12/15/2005 00:00 - 01:30 1.50 BUNCO ~ RUNCMP RIH with 3-1/2" 9.2# L-80 TCII Tubing. P/U Joints 151-174. Set Printed: 12/21/2005 1:52:21 PM BP EXPLORATION Operations Summary Report Legal Well Name: V-212 Common Well Name: V-2121 Event Name: DRILL+COMPLETE Start: 12/2/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/15/2005 Rig Name: DOYON 16 Rig Number: Date ~ From - To Hours Task Code NPT I Phase 12/15/2005 00:00 - 01:30 1.50 BUNCO 01:30 - 02:30 1.00 BUNCO 02:30 - 03:30 1.00 BUNCO 03:30 - 04:00 0.50 BUNCO 04:00 - 05:30 1.50 BUNCO 05:30 - 06:30 1.00 RUN 06:30 - 08:00 1.50 RUN 08:00 - 08:30 I 0.501 WHSUR I P 08:30 - 12:00 3.50 BOPSU P 12:00 - 14:00 2.00 WHSUR P 14:00 - 14:30 0.50 WHSUR P 14:30 - 15:30 1.00 WHSUR P 15:30 - 16:00 0.50 WHSUR P 16:00 - 17:00 1.00 WHSUR P 17:00 - 17:30 0.50 WHSUR P 17:30 - 18:30 1.00 WHSUR P 18:30 - 19:30 19:30 - 20:30 20:30 - 21:30 21:30 - 22:30 1.00 WHSUR P 1.00 WHSUR P 1.00 WHSUR P 1.00 WHSUR P 22:30 - 00:00 1.501 WHSURIP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP Page 12 of i 2 Spud Date: 12/2/2005 End: 12/15/2005 Description of Operations WELG at 5,851'. Held PJSM. R/U Schlumberger Equipment, Hang Sheaves and String E-Line M/U GR/CCL Tools and RIH on E-Line. 7" RA Tag at 5,183'. Correlate 3-1/2" RA Tag with 7" RA Tag. POH with Logging Tools and L/D Same. R/D Schlumberger Equipment and Clear Floor UD Joints #174, #173 and #172. P/U Pup Jts. 19.80' and 7.87'. P/U Tubing Jt. #172. M/U Tubing Hanger. M/U Landing Joint and Land Tubing Hanger in Tubing Head. RILDS. String Weight Up 95,000#, String Weight Down 73,000# Drop Roller Ball and Rod. Allowed to Gravitate to Seat, Back out and lay down landing joint. Rig up high pressure lines to set and test packer. Pressure up to 4,200 psi to set packers, hold for 30 min record on chart. Bleed tubing pressure to 2,500 psi, pressure up on annulus to 4,000 psi to test packer, hold for 30 min record on chart. Bleed annulus pressure to zero, bleed tubing pressure to zero, pressure up on annulus to shear DCR shear valve in upper GLM, valve sheared at 2,600 psi, pump through valve both ways at 3 bpm 340 psi. Blow down lines, drain stack and install TWC, test from below to 1,000 psi. N/D BOPE's Install Pack-Off. N/U Adaptor Flange and Tree Test Pack-Off and Tree to 5,000 psi. R/U DSM Lubricator and Pull TWC. R/D Lubricator. Installed VR Plug in Drillers Side Annulus Valve R/U Circulating Lines to Tree and Test to 1,500 psi Reverse Circulate 73 bbls w/ Corrosion Inhibited 9.0 ppg Brine with 26 gal/100 bbls Corexit 7726 Down 3-1/2" x 7" Annulus at 3 bpm, 380 psi R/U Hot Oil Lines to IA and Test to 2,500 psi. Reverse Circulate 90 bbls Diesel Down 3-1/2" x 7" Annulus at 2 bpm, 800 psi. Taking Returns up Tubing to the Slop Tank. Allow Diesel to U-Tube from IA to Tubing Blow Down All Lines and R/D Hot Oil Set BPV and Test from Below to 1,000 psi. Removed Secondary Annulus Valve and Installed VR Plug in the 7" x 3-1/2" Annulus Valve Suck Out Cellar and Secure Well. Clean and Clear cellar Area. RELEASED RIG AT 2400 HRS, 12/15/2005 Printed: 12(21/2005 1:5221 PM Halliburton ~ ~ Global ~ : ~ ~ ~ ~ ~-~ Company: BP Amoco Date: 1/9/2006 Time: 1946:49 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeIL'V-212; True North. Site: PB V Pad Vertical (TVD) Reference: V-212: 80.0 Well: V 212 Section (VS) Referen ce: Well (O.OON,O;OOE,59.81Azi) Wcllhath: V 212 Survey Calculation Method: M inimum Curvature Db! Oracle. Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordin ate System 1 927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea L evel Geomagnetic Mo del: bgg m2005 Well: V-212 Slot Name: Well Position: +N/-S 159.87 ft Northing: 5970123.10 ft Latitude: 70 19 41.190 N +E/-W -102.50 ft Easting : 590666.23 ft Longitude: 149 15 52.864 W Position Uncertainty: 0.00 ft Wellpath: V-212 5002923279 00 Drilled From: Tie-on Depth: Well Ref. Point 26.20 ft Current Datum: V-212: Height 80.00 ft Above System Datum: Mean Sea Level Magnetic Data: Field Strength: 12/2/2005 57580 nT Declination: Mag Dip Angle: 24.42 deg 80.84 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction . ft ft ft deg 26.20 0.00 0.00 59.81 Survey Program for Definitive Wellpath Date: 1/9/2006 Validated: Yes Version: 7 Actual From To Survey Toolcode Tool Nam e ft ft 100.00 912.00 V-212 GyroData (100.00-912.00) GYD-GC-SS Gyrodata gyro single shots 1011.53 6098.65 V-212 IIFR+SAG (1011. 53-6098.65) MWD+IFR+MS MWD +IFR + Multi Station Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE, Tool ft deg deg ft ft' ft ft ft ft 26.20 0.00 0.00 26.20 -53.80 0.00 0.00 5970123.10 590666.23 TIE LINE 100.00 0.17 217.19 100.00 20.00 -0.09 -0.07 5970123.01 590666.16 GYD-GC-SS 171.00 0.04 250.03 171.00 91.00 -0.18 -0.15 5970122.92 590666.08 GYD-GC-SS 263.00 0.24 320.05 263.00 183.00 -0.04 -0.31 5970123.05 590665.92 GYD-GC-SS 354.00 0.37 327.80 354.00 274.00 0.35 -0.59 5970123.44 590665.64 GYD-GC-SS 445.00 1.04 14.26 444.99 364.99 1.40 -0.54 5970124.49 590665.67 GYD-GC-SS 537.00 3.23 37.66 536.92 456.92 4.26 1.25 5970127.38 590667.43 GYD-GC-SS 628.00 5.05 36.54 627.68 547.68 9.51 5.20 5970132.67 590671.32 GYD-GC-SS 720.00 6.76 34.68 719.19 639.19 17.22 10.69 5970140.44 590676.71 GYD-GC-SS 816.00 7.15 31.98 814.48 734.48 26.93 17.07 5970150.23 590682.97 GYD-GC-SS 912.00 8.70 28.64 909.56 829.56 38.37 23.72 5970161.75 590689.48 GYD-GC-SS 1011.53 11.72 32.91 1007.51 927.51 53.47 32.82 5970176.96 590698.40 MWD+IFR+MS 1042.57 12.19 37.48 1037.88 957.88 58.72 36.53 5970182.25 590702.04 MWD+IFR+MS 1076.54 12.55 39.08 1071.06 991.06 64.43 41.04 5970188.01 590706.48 MWD+IFR+MS 1108.30 13.36 41.46 1102.01 1022.01 69.86 45.64 5970193.50 590711.02 MWD+IFR+MS 1139.45 14.23 43.89 1132.26 1052.26 75.31 50.68 5970199.01 590715.99- MWD+IFR+MS 1172.30 15.14 47.90 1164.04 1084.04 81.10 56.66 5970204.87 590721.90 MWD+IFR+MS 1204.34 16.51 50.75 1194.86 1114.86 86.78 63.29 5970210.63 590728.46 MWD+IFR+MS 1236.11 17.40 52.84 1225.25 1145.25 92.51 70.57 5970216.45 590735.67 MWD+IFR+MS 1267.66 18.05 53.93 1255.30 1175.30 98.24 78.28 5970222.27 590743.31 MWD+IFR+MS 1299.60 18.90 56.46 1285.60 1205.60 104.01 86.59 5970228.14 590751.55 MWD+IFR+MS 1331.88 19.79 59.40 1316.06 1236.06 109.68 95.66 5970233.92 590760.55 MWD+IFR+MS 1365.42 20.50 59.80 1347.54 1267.54 115.52 105.62 5970239.88 590770.44 MWD+IFR+MS 1396.65 20.65 60.77 1376.78 1296.78 120.96 115.15 5970245.44 590779.90 MWD+IFR+MS 1428.82 20.75 61.09 1406.88 1326.88 126.49 125.09 5970251.08 590789.77 MWD+IFR+MS 1462.18 22.09 61.44 1437.93 1357.93 132.34 135.77 5970257.06 590800.38 MWD+IFR+MS 1492.71 23.69 61.58 1466.06 1386.06 138.01 146.21 5970262.85 590810.75 MWD+IFR+MS 1523.93 24.69 61.77 1494.53 1414.53 144.08 157.47 5970269.06 590821.93 MWD+IFR+MS 1557.56 26.67 61.83 1524.84 1444.84 -- 150.96 170.31 5970276.10 590834_69 MWD+IFR+MS Halliburton Global Company: BP` Amoco Date: 1/9/2006 Time: 19;46:49 Page; 2 Field: Pru dhoe Bay Co-ordinate(NE) Referenced. WeIC V-212, True North Site: PB V Pad Vertica l (TVD) Reference: V-212: 80:0 Well; V2 12 Section (VS) Referenced Welt (O.OON,O:OOE,59.81Azi) Wellpathc V-2 12 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N!S ENV MapN MapE Tool ft deg deg ft ft ft ft ft ft 1588.93 29.46 60.65 1552.52 1472.52 158.07 183.25 5970283.36 590847.54 MWD+IFR+MS i 1620.71 31.59 59.21 1579.89 1499.89 166.16 197.21 5970291.62 590861.40 MWD+I.FR+MS 1653.04 33.09 58.35 1607.21 1527.21 175.13 212.00 5970300.76 590876.08 MWD+IFR+MS 1685.02 33.56 57.27 1633.93 1553.93 184.49 226.87 5970310.30 590890.83 MWD+IFR+MS 1715.95 31.89 57.84 1659.95 1579.95 193.46 240.98 5970319.44 590904.83 MWD+IFR+MS 1749.07 32.37 58.44 1688.00 1608.00 202.76 255.94 5970328.92 590919.68 MWD+IFR+MS 1781.14 34.14 58.23 1714.81 1634.81 211.99 270.90 5970338.33 590934.53 MWD+IFR+MS 1811.30 35.83 56.71 1739.52 1659.52 221.29 285.48 5970347.81 590948.99 MWD+IFR+MS 1842.38 37.00 57.64 1764.54 1684.54 231.29 300.98 5970357.99 590964.37 MWD+IFR+MS 1904.78 36.71 59.33 1814.47 1734.47 250.85 332.89 5970377.94 590996.03 MWD+IFR+MS 1937.33 36.27 59.08 1840.64 1760.64 260.76 349.51 5970388.05 591012.54 MWD+IFR+MS 1970.23 36.89 59.69 1867.05 1787.05 270.75 366.39 5970398.23 591029.29 MWD+IFR+MS 2000.98 37.89 60.69 1891.49 1811.49 280.03 382.59 5970407.71 591045.37 MWD+IFR+MS 2034.22 39.43 60.92 1917.44 1837.44 290.16 400.72 5970418.05 591063.38 MWD+IFR+MS 2066.42 39.81 61.79 1942.25 1862.25 300.00 418.74 5970428.11 591081.27 MWD+IFR+MS 2097.71 41.12 61.96 1966.05 1886.05 309.57 436.65 5970437.90 591099.06 MWD+IFR+MS 2131.03 44.53 61.87 1990.48 1910.48 320.23 456.63 5970448.80 591118.91 MWD+IFR+MS 2162.96 46.59 60.65 2012.84 1932.84 331.20 476.61 5970460.00 591138.76 MWD+IFR+MS 2194.29 46.82 61.28 2034.32 1954.32 342.27 496.55 5970471.31 591158.56 MWD+IFR+MS 2226.99 47.10 61.45 2056.64 1976.64 353.72 517.52 5970483.01 591179.40 MWD+IFR+MS ~ 2258.89 47.42 61.69 2078.29 1998.29 364.87 538.13 5970494.42 591199.86 MWD+IFR+MS 2290.57 47.74 62.02 2099.66 2019.66 375.90 558.75 5970505.69 591220.35 MWD+IFR+MS 2323.53 48.90 61.81 2121.58 2041.58 387.49 580.47 5970517.54 591241.92 MWD+IFR+MS 2355.01 50.30 60.83 2141.98 2061.98 399.00 601.50 5970529.30 591262.81 MWD+IFR+MS 2387.21 50.18 60.54 2162.58 2082.58 411.12 623.08 5970541.68 591284.24 MWD+IFR+MS 2434.68 50.61 60.61 2192.84 2112.84 429.09 654.94 5970560.03 591315.87 MWD+IFR+MS ~ 2482.64 50.51 60.90 2223.31 2143.31 447.18 687.25 5970578.51 591347.97 MWD+IFR+MS 2528.76 49.49 61.00 2252.95 2172.95 464.34 718.14 5970596.04 591378.64 MWD+IFR+MS 2579.23 48.87 60.57 2285.94 2205.94 482.98 751.47 5970615.08 591411.75 MWD+IFR+MS 2626.96 49.60 61.75 2317.11 2237.11 500.41 783.14 5970632.90 591443.20 MWD+IFR+MS 2675.96 52.07 61.91 2348.05 2268.05 518.35 816.63 5970651.23 591476.46 MWD+IFR+MS 2724.17 52.79 61.66 2377.45 2297.45 536.41 ~~' 850.30 5970669.70 591509.91 MWD+IFR+MS 2771.61 53.31 61.80 2405.96 2325.96 554.37 883.69 5970688.06 591543.08 MWD+IFR+MS 2820.19 53.87 61.39 2434.80 2354.80 572.97 918.08 5970707.07 591577.24 MWD+IFR+MS 2868.09 54.14 61.48 2462.95 2382.95 591.50 952.12 5970726.01 591611.04 MWD+IFR+MS 2915.90 53.89 61.72 2491.04 2411.04 609.90 986.15 5970744.82 591644.85 MWD+IFR+MS 2964.45 53.09 60.34 2519.93 2439.93 628.80 1020.29 5970764.12 591678.75 MWD+IFR+MS 3011.64 51.72 60.56 2548.72 2468.72 647.24 1052.81 5970782.95 591711.05 MWD+IFR+MS 3061.37 51.14 60.16 2579.72 2499.72 666.46 1086.61 5970802.59 591744.60 MWD+IFR+MS 3107.10 50.00 59.99 2608.77 2528.77 684.08 1117.22 5970820.57 591775.00 MWD+IFR+MS 3157.10 50.00 60.67 2640.91 2560.91 703.04 1150.50 5970839.93 591808.04 MWD+IFR+MS 3182.28 50.87 60.58 2656.94 2576.94 712.57 1167.41 5970849.66 591824.84 MWD+IFR+MS 3264.36 49.10 61.37 2709.72 2629.72 743.07 1222.38 5970880.82 591879.43 MWD+IFR+MS 3314.34 49.37 60.35 2742.35 2662.35 761.50 1255.44 5970899.65 591912.26 MWD+IFR+MS 3407.01 51.00 60.02 2801.69 2721.69 796.90 1317.19 5970935.78 591973.58 MWD+IFR+MS 3506.31 53.08 60.96 2862.77 2782.77 835.45 1385.33 5970975.15 592041.24 MWD+IFR+MS 3598.19 51.99 60.62 2918.66 2838.66 871,04 1448.98 5971011.50 592104.45 MWD+IFR+MS ! 3695.09 49.96 61.41 2979.67 2899.67 907.52 1514.82 5971048.78 592169.84 MWD+IFR+MS 3790.00 50.90 58.55 3040.13 2960.13 944.13 1578.15 5971086.14 592232.72 MWD+IFR+MS 3887.49 49.04 59.41 3102.84 3022.84 982.60 1642.12 5971125.38 592296.21 MWD+IFR+MS 3984.00 48.63 59.56 3166.36 3086.36 1019.49 1704.71 5971163.02 592358.34 MWD+IFR+MS 4078.65. 49.11 61.79 3228.62 3148.62 1054.40 1766.86 5971198.68 592420.06 MWD+IFR+MS __~ Hallburton Global Company: BP Amoco Field: Prudhoe. Bay Date: 1/9/2006 Time: 19:46:49 Co-ordinate(NE) Reference: WeIL V-212, True Page: 3 North Site: PB V Pad Vertical (TVD)Iteference: V-212: 80.0 Well: V-.2 12 Section (VS) Reference: Well'(O.OON;O:OOE,59:81Azi) Wellpath: V-2 12 Survey Calculation Method: Mi nimum Curvatu re Db: Oracle Survey _ MD Inch Azim TVD Sys TVD N/S E/W MapN MapE Tool, ft deg deg ft ft ft ft ft ft 4174.90 48.94 63.55 3291.74 3211.74 1087.76 1831.41 5971232.81 592484.20 MWD+IFR+MS 4271.97 50.68 62.52 3354.38 3274.38 1121.39 1897.49 5971267.23 592549.86 MWD+IFR+MS ~ 4367.88 48.32 62.04 3416.67 3336.67 1155.31 1962.05 5971301.93 592614.00 MWD+IFR+MS 4463.10 45.21 60.65 3481.88 3401.88 1188.55 2022.93 5971335.90 592674.47 MWD+IFR+MS 4559.41 42.12 61.27 3551.55 3471.55 1220.83 2081.05 5971368.88 592732.19 MWD+IFR+MS 4655.29 39.44 61.90 3624.14 3544.14 1250.64 2136.12 5971399.34 592786.89 MWD+IFR+MS 4745.95 35.67 60.04 3696.00 3616.00 1277.41 2184.44 5971426.70 592834.88 MWD+IFR+MS 4843.50 31.27 59.73 3777.36 3697.36 1304:39 2230.97 5971454.24 592881.08 MWD+IFR+MS 4938.03 26.41 58.47 3860.14 3780.14 1327.77 2270.11 5971478.08 592919.92 MWD+IFR+MS 5035.55 22.17 61.86 3949.01 3869.01 1347.80 2304.83 5971498.53 592954.40 MWD+IFR+MS 5129.53 19.29 61.79 4036.90 3956.90 1363.50 2334.16 5971514.58 592983.53 MWD+IFR+MS 5226.99 15.56 61.70 4129.87 4049.87 1377.31 2359.86 5971528.70 593009.06 MWD+IFR+MS 5322.83 11.46 60.66 4223.04 4143.04 1388.07 2379.49 5971539.70 593028.55 MWD+IFR+MS 5425.31 8.17 58.92 4324.00 4244.00 1396.82 2394.60 5971548.63 593043.56 MWD+IFR+MS 5521.59 4.54 65.45 4419.68 4339.68 1401.94 2403.93 5971553.86 593052.83 MWD+IFR+MS 5617.96 1.67 124.25 4515.91 4435.91 1402.74 2408.56 5971554.71 593057.45 MWD+IFR+MS 5714.35 0.32 229.33 4612.29 4532.29 1401.77 2409.52 5971553.76 593058.42 MWD+IFR+MS 5810.93 0.48 264.97 4708.87 4628.87 1401.56 2408.91 5971553.54 593057.81 MWD+IFR+MS 5906.52 0.16 293.09 4804.45 4724.45 1401.58 2408.39 5971553.55 593057.29 MWD+IFR+MS 6003.43 0.24 153.22 4901.36 4821.36 1401.45 2408.36 5971553.42 593057.26 MWD+IFR+MS 6098.65 0.07 223.99 4996.58 4916.58 1401.23 2408.41 5971553.20 593057.31 MWD+IFR+MS 6150.00 0.07 223.99 5047.93 4967.93 1401.18 2408.36 5971553.16 593057.27 PROJECTED to TD TREE= 4-1116" CNV WELLHE~^,D = FMC GEN 5 ACTUATOR = ll - KB. ELEV = T 79.9' BF. ELEV = 52.6' KOP = 354' Max Angle = 54 @ 2868 -Datum MD = 5577 Datum TV D = 4400' I20" CONDUCTOR 9-518" CSG, 40#, L-80 BTC, ID = 8.835" NOTES: V -Z 12 26' 4-1/2" X 3-1/2" XO, ID = 2.992" 63' ~- 7" SHORT JOINT w / RA TAG • 2506' ~-~ 3-112" HES X NIP, ID = 2.813" I 101' I GAS LIFT MANDRELS REV TYPE VLV LATCH PORT DATE 8 MMG DMY RK 0 01/10/06 WATER INJECTION MANDRELS Minimum ID = 2.813" @ 2506' 3-112" HES X NIPPLE ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 5606 4504 2 MMG-W DMY RK 0 12/14/05 4 5630 4528 2 MMG-W P-15 RK 7 01/15!06 3 5711 4609 0 MMG-W DMY RK 0 12/14!05 2 5740 4638 4 MMG-W P-15 RK 7 41/15/06 1 5785 4683 0 MMG-W P-15 RK 6 01/15/06 5183' 7" SHORT JOINT w / RA TAG 5469' 3-1/2" HES X NIP, ID = 2.813" 5485' 7" X 3-112" BKR PREMIER PKR, ID = 2.875" PERFORATION SUMMARY REF LOG: MWD/ LWD LOGS ON 07/17/05 ANGLE AT TOP PERF: 2 @ 5610' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE OA 3-1/2" 5 5610 - 5644 O 12!13/05 Oba 3-112" 5 5674 - 5700 O 12/13/05 Obb-Obd 3-1/2" 5 5714 - 5736 C 12/13/05 3-1/2" 5 5822 - 5874 C 12/13/05 3-112" TBG, 9.3#, L-80 TCII, .0087 bpf, ID = 2.992" 3-1/2" PUPw/RA MARKER 7" X 3-1/2" BKR PREMIER PKR, ID = 2.875" 5690, F- ~3-1/2" HES X NIP, ID = 2.813" 5763' 7" X 3-1/2" BKR PREMIER PKR, ID = 2.875" 5$0$' 3-1I2" HES X NIP, lD = 2.813" 5824' 3-1/2" HES X NIP, ID = 2.813" 5824' 3-1/2" PX PLUG (01!15/06} 5846' 3-112" WLEG, ID = 2.992" PBTD -j 6055• 7" CSG, 26#, L-80 BTGM, ID = 6276" 6140' 8-3/4" TD DATE REV BY COMMENTS DATE REV BY COMMENTS 72/16/05 D16 ORIGINAL COMPLETION 01/04/06 MCZ/TLH DRLGDRAFTCORRECTIONS 01/10/06 DAViTLH GLV C/O 01!15/06 WTSfTLH WFV C/O & PX PLUG SET ORION UNIT WELL• V-212 PERMIT No: 2051500 API No: 50-029-23279-00 SEC 11 T11 N, R11 E 4874' FSL & 1634' FEL BP Exploration (Alaska) • • 12-Jan-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well V-212 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 26.20' MD ao~-i5o Window /Kickoff Survey: 6,098.65' MD (if applicable) Projected Survey: 6,150.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed, Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) MEMORANDUM • To: Jim Regg `~~~~ Z~ ~ ~ ~~ P.I. Supervisor j ~ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, Febniary OI, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-212 PRUDHOE BAY iIN ORIN V-2 L Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UN ORIN V-212 Insp Num: mitCS060 13 1 143 124 Rel Insp Num API Well Number Permit Number: 50-029-23279-00-00 205-150-0 Inspector Name: Chuck Scheve Inspection Date: 1/31/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well v-ziz (Type Inj. ~ w i TVD ~ as32 ~ IA Iaoo zslo za6o za6o P T zosisoo 'TypeTest j SPT Test psi Izos OA i lao zoo ~~ 1so , Iso Interval ~IT~- P/F P Tubing, 1300 loco ~ lsoo ~ 1300 Notes Wednesday, February 01, 2006 Page 1 of 1 • ~~~® ~~ Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 December 27, 2005 Ms. Sharmaine Copeland BP Exploration (Alaska), Inc. Petrotechnical Data Center, LR2-1 900 E Benson Blvd Anchorage, Alaska 99508 Re: V-Pad, Well #V-212 Prudhoe Bay, Alaska Enclosed, please find one (1) original, two (2) copies, and two (2) disks of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, ~, ~~~ Rob Shoup North American Operations Manager RS:tf Serving the Worldwide Energy Industry with Precision Survey Instrumentation • ~~~® ~~ Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY REPORT BP V-PAD #'~-212 DOYON #16 PRUDHOE BAY, AK AK1105G_573 DECEMBER 4, 2005 Serving the Worldwide Energy Industry with Precision Survey Instrumentation A Gyrodata Directional Surve y for BP EXPLORATION (ALASKA) INC. Lease: V-Pad Well: V-212, 4" Drillpipe Location: Doyon #16, Prudhoe Bay, Alaska Job Number: AK1105G 573 Run Date: 04 Dec 2005 Surveyor: Steve Thompson; Jeff Smith Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.328108 deg. N Longitude: 149.264684 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location ~J Horizontal Coordinates Calculated from Well Head Location A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: V-Pad Well: V-212, 4" Drillpipe Location: Doyon #16, Prudhoe Bay, Alaska Job Number: AK1 lOSG 573 MEASURED I N C L AZIMUTH BORE HOLE DOGLEG VERTICAL CLOS URE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZ[MUTH COORDINATES feet deg. deg. deg. min. deg./ feet feet deg. feet 100 ft. 0.00 0.00 oo O N 0 0 E 0.00 0 00 O O O O 0.00 N-------- -- - --- O-oo- E - ------------ - ---------- -------- ------------ - 0 - 912 FT. RATE GYROSCOPIC SURVEY RUN ------- --------------- --------------- INSIDE 4" DRILLPIPE ---------- ------- -------- ----- - ------- -- -- ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO DOYON #16 R.K.B. OF 79.3 F'I'. ABOVE MSL ------------------------------------------------------------------------------------------------------------------------------------------------------------ ------------------------ -------------- 100.00 0.17 217.19 S 37 12 W 0.17 100.00 0.1 217.2 0.12 S 0.09 W 171.00 0.04 250.03 S 70 2 W 0.19 171.00 0.3 220.3 0.21 S 0.18 W 263.00 0.24 320.05 N 39 57 W 0.25 263.00 0.3 258.1 0.07 S 0.33 W 354.00 0.37 327.80 N 32 12 W 0.14 354.00 0.7 297.9 0.33 N 0.62 W 445.00 1.04 14.32 N 14 19 E 0.91 444.99 1.5 337.6 1.37 N 0.57 W 537.00 3.23 37.66 N 37 40 E 2.51 536.92 4.4 16.1 4.24 N 1.22 E 628.00 5.05 36.54 N 36 33 E 2.00 627.68 10.8 28.6 9.48 N 5.18 E 720.00 6.76 34.68 N 34 41 E 1.88 719.19 20.2 31.8 17.19 N 10.67 E 816.00 7.15 31.98 N 31 59 E 0.53 814.48. 31.9 32.4 26.91 N 17.05 E 912.00 8.70 28.64 N 28 38 E .1.68 909.56 45.1 31.7 38.35 N 23.70 E Final Station Closure: Distance: 45.08 ft z: A 1.71 de 3 g 2 BP Exploration (Alaska) Inc. Well: V-Pad V-212 4" Drillpipe Location: Doyon #16, Prudhoe Bay, Alaska 40 - 35 - 30 - 25 - ,-. C7 20 ._ z 0 z 15 - 10 - 5- 0- Inrun Gyrodata AK1105G_573 DEFINITIVE _ i i B LO M TTOM HOLE ATED :912.00 - _ --- • i i i ~ 0 5 10 15 20 FASTING (ft) • • BP Exploration (Alaska) Inc. Well: V-Pad V-212 4" Drillpipe Location: Doyon #16, Prudhoe Bay, Alaska 10 9- 8 7- ,-. 0 0 6- m a~ 5- w w w 4 J 3- 2- 1 0 Inrun Gyrodata AK1105G 573 DEFINITIVE - I . ~,, ~~ B L M TTOM HOLE CATE D :912.00 - -~ _- ~ - ,- - - I I ~ ~ i i i 100 200 300 400 500 600 i'00 800 900 1000 MEASURED DEPTH (ft) • • ~ ; ,~ ~ ~, ~; a ~ ~~? ~~ ~ ~ J ~ ', ^,~ .~ ~ a , r ,~ ;~~~°~ `, ~ ~ ~ ,~~ ~ FRANK H. MURKOWSKI, GOVERNOR ~ tam a ~~ OII/ ~ ~ Ir 333 W. T" AVENUE, SUITE 100 CO1~T5F.RVA'1`IO1~T COMI~IISSIOIIT :~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Robert Tirpack >y FAx (so7> 27sasa2 Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: PBU V-212 BP Exploration (Alaska) Inc. Permit No: 205-150 Surface Location: 4874' FSL, 1634' FEL, SEC. 11, T 11 N, R 1.1 E, UM Bottomhole Location: 992' FSL, 4511' FEL, SEC. Ol, Tl 1N, R1 lE, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in_.the. event it was erroneously-ssued.- 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. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum f ~ nspector at (907) 659- 3607 (pager). DATED this~day of month, 2005 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~/Jfi/~-. t is f I z ~ z.s."c~5' STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMISSION ~E..~., ~._, PERMIT TO DRILL ~~~~~ ~ `` 20 AAC 25.005 QCT 1 0 ~on~ 1a. Type of work ®Drill ^ Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ^ Develop fl t~p ~Q Multiple Zone. ^ Stratigraphic Test ®Service ~ ^ d~311itp~it56~S(g~ingle done' 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Nam #0 0U13~er: PBU V-212 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 6139 TVD 5034 12. Field /Pool(s): Prudhoe Bay Field f Orion 4a. Location of Well (Governmental Section): Surtace: 4874' FSL 1634' FEL SEC T11N 11 R11E UM 7. Property Designation: ADL 028240 Schrader Bluff , , . , , , Top of Productive Horizon: 992' FSL, 4511' FEL, SEC. 01, T11 N, R11 E, UM 8. Land Use Permit: 13. Approximate Spud Date: November 1, 2005 ~ Total Depth: 992' FSL, 4511' FEL, SEC. 01, T11 N, R11 E, UM / 9. Acres in Property: 2560 i4. Distance to Nearest Property: 11540' 4b. Location of Well (State Base Plane Coordinates): Surtace: x- 590666 - 5970123 Zone- ASP4 10. KB Elevation (Height above GL):Plan 75.3 feet 15. Distance to Nearest Well Within Pool 1001' to V-204L1 16. Deviated Wells: Kickoff Depth: 300 feet Maximum Hole Angle: 51 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2138 Surface: 1663 ia. asng rogram: Size Specifications Setting Depth To Bottom _ - uant o ernent c.f. or sacks Hole. Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 215.5# A-53 Welded 80' 22' 22' 102' 102' 60 sx Arctic Set A rox: 12-1/4" 9-5/8" 40# L-80 BTC 3210' 22' 22' 3232' 2690' 02 sx AS Lite, 348 sx Class 'G' 8-3/4" 7" 26# L-80 BTC-M 6116' 22' 22' 6138' 5034' 36 sx Class 'G' 19. PRESENT WELL CONDITI ON SUMMARY (To be completed for RedriO AND Re-ent Operations). Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casin Len th Size Cement Volume MD TVD r r P in Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Martyr, 564-4101 Printed Name Robert Tirpack Title Senior Drilling Engineer ce-- X32.3$62 Preparetl By Name/Number. Si nature .-- ~ '~' Phone 564-4166 Date /~!r r Terrie Hubble, 56a-4628 Commission Use Only Permit To Drill Number: ,20 API Number: q .50- O~ - ~. 3.Z 7 / Permit Approval Date: /d i D ~ See cover letter for other requirements Conditions of Approval: Samples equ' ed [ Yes No Mud Log Required ^ Yes No Hydro n Sul de Measures ^ Yes +No Directional Survey Required Yes ^ No Other: ~ ~' S ~~ " 4 `C~ ~~ ~,.t~ (( Pal L ~" ~ t'.~-~ ~~...'~' r,L a. ~r f- ., ~ti a V'E' ~ ~ Yom' ~ . ~~L~/ 2r/~ C ~~ _~'SS ~~i~ ~C ~ r r~ In-~,~ ~ t ~ ~ pt= f ~~~` l ~ ter-~'~1 ~f I ~' ~ ~~~ vu J ~ d . / APPROVED BY A rove / ~= E I'~ ~ HE COMMISSION Date Form 10-401 used 0004 u ~/~ ~~ ~ ~~~i~ (.~ A SutSmit Ir/Duplicate ~ f Well Name: V-212i Well Plan Summary T e of Well roducer or injector : USH Injector Surface Location: 4874' FSL, 1634' FEL, Sec. 11, T11 N, R11 E Slot NR As Built .a ,- ,~. .. "~ . ~. w.... . X = 590,666.23 Y = 5,970,123.10 ,.. . . . . ~ . Shallow Target .~_, . ~ . ... , ~ . , . ~ . . 263". ~ FSL, 538' FEL, Sec. 2, T11 N, R11 E Coordinates To SV1 : X = 591,754 Y = 5,970,804 Z = -2515' TVDss Target Start ASP 992' FSL, 4511' FEL, Sec. 1, T11 N, R11 E Coordinats To OA : X = 593,050 Y = 5,971,550 Z = -4415' TVDss BHL ASP Coordinates: 992' FSL, 4511' FEL, Sec. 1, T11 N, R11 X = 593,050 Y = 5,971,550 Z = -4960' TVDss AFE Number: ORD5M3586 Ri Doy 16~' GL: 53.8' KB: 21.5' Estimated Start Date: November 1 , 2005 O eratin da s to com lete: 12 TD: 6,139' MD TVD: 5,035 Max Inc: 50.8° KBE: 75.3' Well Design: I USH Grassroots Schrader Injector 3-~h" TCII 3-Packer Completion. Current Well Information General Distance to Nearest Property: 11,540' to PBU boundary Distance to Nearest Well in Pool: 1,001' to V-204L1 at OBb sand level API Number: 50-029-XXXXX Well Type: Development -Orion Schrader Injector Current Status: New well, 20" X 34" insulated conductor Conductor: 20" X 34", 215.5 Ib/ft, A53 ERW set at 101' RKB BHP: 2138 psi -Top of OBf Sand (8.7 ppg C~ 4750' TVDss) % BHT: 95°F C~ 4,960' TVDss estimated 1/a Mile Wellbore Near Wellbore Mechanical Integrity Summary: 2~~.~~,~ V-204 is a Schrader multilateral producer that enters the 1/4 mile radius in all 4 of its Schrader laterals. The closest point of the OBd, OBb, OBa, and OA legs are 1097', 1001', 1120', & 1118' from V-2121 respectively. During cementing of V-204, no losses were noted, and assuming a 30% excess hole volume, the 101 BBLs of cement would cover the 9-7l8"x7-5/8" annulus for an expected Top of Cement at 3436' MD or 775' MD above the top Ma. There are no other wells within'/a mile of this injector throughout the Schrader Interval. ~ Anti-Collision Issues: On a Global Scan, all wells pass BP's major risk assessment V-2121 Permit to Drill Application Page • Formation Markers V-2121 (Based on SOR) Est. Form. Top Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. Formation (MD) (TVD-kb) (TVDss) (Yes/No) (Psi) ( EMW) G1 315 315 -240 No 108 8.7 SV6 968 965 -890 No 401 8.7 SV5 1693 1640 -1565 No 704 8.7 SV4 1858 1775 -1700 Poss. Gas H drates 765 8.7 Base Permafrost 1858 1775 -1700 No 765 8.7 Fault 1 2425 2180 -2105 SV3 -Faulted To 2425 2180 -2105 Poss. Gas H drates 947 8.7 SV2 2520 2240 -2165 Poss. Gas H drates 974 8.7 SV1 3074 2590 -2515 Gas Hydrates; below 2700 SS 1132 8.7 UG4 3557 2895 -2820 Thin coal 1269 8.7 UG4A 3596 2920 -2845 Heavy Oil betty 2845 and 3080' SS 1280 8.7 UG3 4181 3290 -3215 Thin coals 1447 8.7 UG1 4908 3830 -3755 Heavy oil betty 3875' and 4015' SS. 1690 8.7 Ma 5188 4090 -4015 No -Water 1807 8.7 Mb1 5240 4140 -4065 No -Water 1829 8.7 Mb2 5312 4210 -4135 Heavy oil betty 4135' and 4160' SS. 1861 8.7 Mc 5368 4265 -4190 No -water 1886 8.7 Na 5433 4330 -4255 No 1915 8.7 Nb 5459 4355 -4280 Yes - 5-10' oil sand 1926 8.7 Nc 5504 4400 -4325 Yes 1946 8.7 OA 5594 4490 -4415 Yes 1710 - 1990 7.4 - 8.7 OBa 5664 4560 -4485 Yes 1930 - 2018 8.3 - 8.7 OBb 5714 4610 -4535 Yes 1970 - 2040 8.4 - 8.7 OBc 5774 4670 -4595 Yes 2068 8.7 OBd 5824 4720 -4645 Yes 1790 - 2090 7.4 - 8.7 OBe 5889 4785 -4710 Yes 2120 8.7 OBf 5929 4825 -4750 Yes 2138 8.7 OBf_Base 5969 4865 -4790 T.D. 6138 5035 -4960 V-2121 Permit to Drill Application Page CasinalTubina Program Hole Size Csg / Tb O.D. WUFt Grade ~ Conn ~ Burst si Collapse si Length Top MD /TVDrkb Bottom MD /TVDrkb 42" 20" 215.5# A-53 Welded 80' 22' / 22' 102' / 102' 12-~/a" 9 5/8" 40# L-80 BTC 5,750 3,090 3,210' 22' / 22' 3,232' / 2,690' 8-3/a" 7" 26# L-80 BTC-M 7,240 5,410 6,116' 22' / 22' 6,138' / 5,034' Tubin 4'/z" 12.6# L-80 TCII 8,430 7,500 20' 22' / 22' 42' / 42' Tubin 3'h" 9.30# L-80 TCII 10,160 10,530 5,770' 43' / 43' 5,813' MD Mud Program: 12 ~/a" Surface Hole Mud Properties: Spud -Freshwater Mud ~ Interval Densit Funnel Vis PV YP FL Chlorides PH 0-1,850' Base Perm 8.8 - "~~ 250-300 20-45 50-70 NC-8.0 <1000 9.0-9.5 1,850-3,757 TD 9. .5, 200-250 20-40 40-50 8.0-7.0 <1000 9.0-9.5 S 3/a" Production Bole Mud erties: Freshwater Mud (LSNU) Interval Densi Funnel Vis PV YP FL H Chlorides MBT Surface shoe to TD 8.8 - 9.3 38-50 10-16 18-24 4.0-6.0 9.0-9.5 <600 < 20 Survev and Loaaina Proaram: 12-'/a" Hole Section: Surface Gyro will be needed (run to 1200' or as conditions dictate) O en Hole: MWD / GR Cased hole: None 8-3/a" Hole Section: MWD / GR / Res /Den / Neu / PWD (all real-time except for Den-Neu Recorded) Cased Hole: USIT (Follow Primary Depth Control Procedures) /dual packer MDT possible Surface and Anti-Collision Issues Surface Shut-in Wells: Nearb Well V-103 V-106 Distance to V-212i 14.53 15.70 V-103 & V-106 will require surface shut-in and wellhouse removal in order to move over well V-212i. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. Hydrogen Sulfide V Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: #1 Closest SHL Well H2S Level V-106 15 #2 Closest SHL Well H2S Level V-102 25 #1 Closest BHL Well H2S Level V-201 11 Max. Recorded H2S on Pad/Facility V-201 1 No other V Pad Schrader Bluff H2S #2 Closest BHL Well H2S Level data available. 8/3/2003 8/17/2005 V-201 H2S levels due to 6/22/2004 injection water being used in jet pump, and not from 6/22/2004 formation. V-201 was converted to water injection in 2/05. No other V Pad well has measured H2S > 25 ppm. Faults One fault is expected to be crossed in V-212i. No losses are expected to be associated with this fault. Details are listed below for reference: Fault 1 ("V" Pad Fault -Lower SV4): 2425' MD 2180' TVD -2105' TVDss Throw: -110' W V-2121 Permit to Drill Application Page 3 Cement Calculations: Casin Size: 9 5/a-in 40-Ib/ft L-80 BTC -Single StagE Basis: Lead: 250% excess over gauge hole in permafi Lead TOC: Surface Tail: 1,000' of open hole with 30% excess, plus Tail TOC: 2232' MD Total Cement Volume: Spacer 75 bbls of Viscosified 30% excess over gauge hole below permafrost to 10. Lead 397 bbls, 2229cuft, s 10.7 Ib/ al ASL G + adds @ cuft/sk Tail 73 bbls, 421 cuft sks 15.8 Ib/ al Class G + adds - cuft/sk Temp BHST = 48° F, B T 80° F estimated by Schlumberger In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casin Size: 7" 26 Ib/ft L-80 BTC-M -Single Stage Basis: Lead: None Lead TOC: N/A Tail: 1,550' op n hole with 30% excess, plus 80' shoe track Tail TOC: ,68 ' MD 500' MD above tanned Ma to at 5,188' MD Total Cement Volu Wash 15 bbls CW100 S acer 30 bbls of Viscosifie acer Mud ush II Desi n C~ 1 , . above mudwei ht Tail 50 bbls, 283 cuft, 3 s 15.8 Ib/ al G + Gasblok - ft/sk Temp BHST ~ 100° F, T 80° F estimated by Schlumb er Centralizer Recommendations: 9 5/e" Casing Centralizer Placement a) Run (25) 9 5/" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 2,232' MD (1,000' MD above the shoe). b) Run 2Bow-spring centralizers on either side of the TAM Port Collar (if run). 7" String Centralizer Placement a) Place 2 rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. b) With the exception stated above, run one centralizer per joint, floating across the entire joint up to 4,688' MD (500' MD above Ma sand). Zonal isolation with cement is required across the Ma sands. The centralizer program is subject to change pending modeling and hole conditions. V-2121 Permit to Drill Application Page 4 • • Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi. - ~. wc~ ~-- BOP regular test frequency for V-2121 will be 14 days. Below is an excerpt from the permit application requesting a variance to the requirements of 20 AAC 25.035 (e)(10)C PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285 (f)(2) TUBING WORKOVERS: or, 20 AAC 25.286(e)(1) WORKSTRING SERVICE OPERATIONS "BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, exce t when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment." Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section • Maximum anticipated BHP: • Maximum surface pressure; • Planned BOP test pressure: • 7" Casing Test: • Integrity Test - 8-3/4" hole: • Kick Tolerance: • Planned completion fluid: Disposal 2138 psi -Top of OBf Sand (8.7 ppg @ 4750' TVDss) 1,663 psi -Based on a full column of gas Cd1 0.10 psi/ft ~ 4,000 psi/250 psi Rams ~ 2,500 psi/250 psi Annular 4,000 psi 11.2 ppg minimum EMW LOT 20' from 9-5/8" shoe 52.3 bbls with an 11.2 ppg EMW LOT Estimated 9.0 ppg Brine (w/6.8 ppg Diesel freeze protect) • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. V-2121 Permit to Drill Application Page 5 • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control A. The Schrader in the Polygon 2 fault block is expected to be normal to sub-normally pressured at 7.6-8.8 ppg EMW. II. Hydrates and Shallow gas A. Gas Hydrates are present at V-pad and have been encountered in wells as close as V-100 and V-111 and throughout the SV4, SV3, SV2, and SV1. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Both offset wells to V-100 and V-111 had to have the mud treated and were able to drill to section TD. In V-100 the hydrates came from the SVi . Occasionally hydrates are encountered below the SVi . III. Lost Circulation/Breathing A. Lost circulation is not expected due to the benign nature of V Pad fault. In addition the fault will be crossed at high angle and move away quickly. • Note: Massive losses were encountered on L pad at L-118 due to high penetration rates (1100-1300 fph) and inadequate hole cleaning strategy. B. We do not expect breathing on this well. IV. Kick Tolerance/Integrity Testing A. The 9-s/" casing will be cemented to surface. B. The 7" casing will be cemented with 15.8 Ib/gal ment to 500' MD above the Ma sand 4,688' MD. C. The Kick Tolerance for the surface casing i 2.3 Is with 9.0 ppg mud, 11.2 ppg LOT, and an 8.7 ppg pore pressure. D. Integrity Testing Test Paint Test De th Test EMW 16 al 9-s/-in shoe 20-ft minimum from 9-5/--in shoe LOT 11.2 minimum V. Stuck Pipe A. We do not expect stuck pipe if the hole is kept adequately clean. VI. Hydrogen Sulfide V Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: o Adjacent producers at Surface: o Adjacent producers t TD: V-106 15 ppm V-201 110/' pm V-102 25 ppm No other H2S"Data C~ TD VII. Faults A. One fault is expected to be crossed in V-212i. No losses are expected to be associated with this fault. Details are listed below for reference: Fault 1 ("V" Pad Fault -Lower SV4): 2425' MD 2180' TVD -2105' TVDss Throw: -110' W VIII. Anti-Collision Issues All wells pass Major Risk criteria. Gyro will need to be run within 1200' of surface or as conditions dictate for clean directional measurements due to the surface proximity to neighboring wellbores. CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION V-2121 Permit to Drill Application Page 6 • • V-2121-Drill and Complete Procedure Summar Pre-Rig Work: 1. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Prepare neighboring wells for the rig move and simops production. Shut in V-106 and V-103 and remove well houses as necessary. Rig Operations: 1. MIRU Doyon 16. f 2. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 12-Ya" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3,232' MD. The actual surface hole TD will be -100' TVD below the top of the SV1 sands. 4. Run and cement the 9 5/8", 40.0-Ib/ft. surface casing back to surface. A TAM Port Collar will be run in the casing string only if hole conditions dictate. 5. ND diverter spool and NU casing /tubing head. NU BOPE and test to 4,000 psi. ~' 6. MU 8-3/a" drilling assembly with MWD/GR/Res/Den(recorded)/Neu(recorded)/PWD and RIH to float collar. Test the 9-5/e" casing to 4,000 psi for 30 minutes. 7. Drill shoe track and displace over to new 8.8 ppg mud 8. Drill new formation to 20' below 9 5/e" shoe and perform LOT (Notify ODE if 11.2 ppg LOT is not obtained). ~ 9. Drill ahead to Polygon 2 Target TD at 6,139' MD, (250' MD below Top OBe marker). 10. Circulate and condition hole, POOH to run casing. Perform wiper trip if hole conditions dictate. ~ 11. Run and cement the 7" production casing as required to cover all significant hydrocarbon intervals. Displace the casing with seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Freeze i protect the 7" x 9 5/s" annulus. 12. PU DPC guns and RIH w/ -150' of 4.5" Power Jet 5 spf, pert guns (total assembly length to be -300') with Sperry LWD GR for gun correlation. Tag PBTD. 13. Circ hole over to 9.0 brine. 14. Space out utilizing GR and RA tags in 7" casing. Once spaced out correctly, confirm cement compressive strength is at least 2,000 psi. Perforate OA, OBa, and OBd. 15. 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 (OBd pert predicted 5824'-5864'). Note: It is imperative that we have a clean wellbore so we don't damage the MDT packers while RIH. 16. Run USIT/GR log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. Obtain high resolution (0.5"x5deg) repeat section over OBb interval (approx. 5,700'-5,750' MD on directional plan) ? 17. Transmit High-Res USIT pass to town as soon as possible for MDT Cased Hole OBb sample depth picking. 18. If cement integrity found to be suitable for MDT sampling needs, RIH w/ 1' OBb perforating gun (depth TBD) followed by MDT configured for obtaining fluid sample from OBb Sand. Depths TBD based on cement evaluation. 19. Wireiine perforate the OBb interval after POOH w/ MDT. 20. RD E-Line. Run the 3-'/z", L-80 TCII completion with a 7" x 3-'/2" straddle packer assembly and injection mandrels. Note: Do not circulate inhibited brine down the backside yet. 21. Run in the lockdown screws and set the packers. Test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCR shear valve and pump both ways to confirm circulation ability. 22. Install FMC TWC. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 23. Freeze protect the well to 2,500 MD /-2,200' TVD by first pumping --95 BBLS corrosion inhibited brine down the IA with rig pumps followed by -100 BBLS diesel down IA w/ Hot Oil taking clean brine returns to surface throughout. Allow diesel to U-tube. 24. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-'/2" annulus valve and secure the well. Assure that IA/OA are both protected with two barriers. 25. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC from the tailpipe. 2. Replace the DCR shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. 5. Install wellhouse and flowlines. V-212i Permit to Drill Application Page 7 • • Variance Request ~ Issue Compliance with AOGCC testing requirements for BOP rams after they have been used in the normal coarse of operations. Request The AOGCC is in the process of developing a guideline document clarifing the intent of the regulations pertaining to function pressure testing ram type BOP's. BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. Background AOGCC regulations require rams that have been used in the course of primary drilling & completion, workover and through tubing drilling operations be function pressure tested before the next wellbore entry. This is not a new regulation. The intent of this regulation is to ensure that ram type equipment has integrity after it has been utilized in a wellbore...for example; to ensure integrity if a ram was closed on a tool joint. The exact regulation language is: "if BOP sealing ram type equipment has been used, it must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure;" The pertinent sections are: 20 AAC 25.035 (e)(10)C PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285 (f)(2) TUBING WORKOVERS; 20 AAC 25.286(e)(1) WORKSTRING SERVICE OPERATIONS This issue has been discussed with Winton Aubert at the AOGCC. The test requirement in the regulation is intended to apply to ram type equipment only. The AOGCC understands that ram type BOP's are utilized for purposes other than well control in the normal coarse of operations. The regulations allowing a variance are at 20 AAC 25.035(h) PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036(f) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285(h) TUBING WORKOVERS; 20 AAC 25.286(g) WORKSTRING SERVICE OPERATIONS...which says generally: 20 AAC 25.035(h)... Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the BOPE requirements in (e) of this section if the variance provides at least an equally effective means of well control; V-2121 Permit to Drill Application Page ' 11CEE: FMC 41/16" 5M V-212i Proposed Completion WELLHEAD: FMC Gen 5 System 11 ", 5M csg.head w/ 7" mandrel hanger 8~ packoff 11 ° x 11 ", 5M, tbg spool w/ Cedar Elevation =53.8' 11 " x 41 /2° tubing hanger cbynr, r6R/CB=75.3 11° X 4-1/16" Adaptor Flange 20" X 34" 215.51b/ft, 4-1/2", 12.6 Ib/ft, L-80, TCII A53 ERW Insulated 4-1/2" X 3-1/2° TCII XO 101' Drift / ID : 3.833"/3.958" 3-1/2", 9.3 Ib/ft, L-80, TCII Drift / ID : 2.867"/2.992" 2,500` ND ~ ~ F ~ ~ ~ 3-1/2" 'X' Landing Nipple with 2.813° seal bore. 9-518", 40 #/ft, L-80, BTC 3,232' 4,688` 7" Short Joint & RA Tag T M d 5 188' Proposed Top of Cement ~ op a san ( , ) ` Camco gas lift mandrel 3-1/2" x 1-1 /2" KBG2 5,334 l i d 2 500 424` 5 ve p nne to , With DCK Shear Va 813" seal bore 3-1/2" `X' Landin Nipple with 2 , g . . 5,445` 7" x 3-1/2" Baker `PRM' Production Packer 7" Short Joint & RA Tag 5,504` Camco 3-112" x 1-1/2" MMG-W GLM Above Top OA (5,594`) 5,596` OA sand Perfs 5,594`-5,634' RA Tag in 3-1 /2" 5,624` 3-1/2" `X' Landing Nipple with 2.813" seal bore. 5,645` 7" x 3-1/2" Baker `PRM' Production Packer 5,671` Camco 3-1/2" x 1-1/2" MMG-W GLM 5,700` OBa & OBb sand Perfs: 5,664`-5,694` & 5,714`-5,734` 5,729` 3-1/2" 'X' Landing Nipple with 2.813" seal bore. 5,745` 7" x 3-1/2" Baker `PRM' Production Packer 5°771 3-1 /2" `X' Landing Nipple with 2.813" seal bore 5,792` 5,813` ~ ~ ~( 3-1/2" WireLine Entry Guide Bd sand Perfs: 5,824`-5,864' 6,039` 7", PBTD 6,139` 7", 26 #/ft, L80, BTC-Mod 8 3/4", TD (Injector Mainbore) 6,139` MD Date Rev By Comments 9/9/05 MJM Proposed Completion ~P~~er~I~~~.~a~ J WELL: V-2121 API NO: ~ i Sperry-Sun BP Planning Report Company: BP Amoco Date: 9!13/2005 Time: 15:43:57 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan V-212 (N-R), True North Site: PB V Pad Vertical (TVI))Reference: 53.8+21.5 75.3 Well: Plan V-212 (N-R) Section (VS) Reference: Well (O.OON,O.OOE,59.79Azi) Wellpath: ' Plan V-212 Survey Calculation Method: Minimum Curvature Db: Oracle Plan: V-212 wp04 Date Composed: 6/7/2005 Version: 11 Principal: Yes Tied-to: From Well Ref. Point Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB V Pad TR-12-12 UNITED STATES :North Slope Site Position: Northing: 5969964.50 ft Latitude: 70 19 39.618 N From: Map Easting: 590770.65 ft Longitude: 149 15 49.871 W Position Uncertainty: 0.00 ft North Reference: True Cround Level: 0.00 ft Grid Convergence: 0.69 deg Well: Plan V-212 (N-R) Slot Name: Well Position: +N/-S 159.87 ft Northing: 5970123.10 ft Latitude: 70 19 41.190 N +E/-W -102.50 ft Easting : 590666.23 ft Longitude: 149 15 52.864 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole.Size Name ft ft in in 3232.15 2690.30 9.625 12.250 9 5/8" 6138.00 5034.48 7.000 8.750 7" Formations MI) TVD Formations Lithology Dip Angle I)ip Direction ft ft deg deg 315.30 315.30 G 1 0.00 0.00 968.28 965.30 SV6 0.00 0.00 1693.38 1640.30 SV5 0.00 0.00 1858.14 1775.30 SV4 0.00 0.00 1858.14 1775.30 Base Permafrost 0.00 0.00 2425.22 2180.30 Fault 1 0.00 0.00 2425.22 2180.30 SV3 Faulted Top 0.00 0.00 2520.16 2240.30 SV2 0.00 0.00 3073.93 2590.30 SV1 0.00 0.00 3556.50 2895.30 ~ UG4 0.00 0.00 3596.05 2920.30 UG4A 0.00 0.00 4181.47 3290.30 UG3 0.00 0.00 4907.91 3830.30 UG1 0.00 0.00 5188.43 4090.30 Ma 0.00 0.00 5240.24 4140.30 Mb1 0.00 0.00 5312.01 4210.30 Mb2 0.00 0.00 5367.89 4265.30 Mc 0.00 0.00 5433.49 4330.30 Na 0.00 0.00 5458.62 4355.30 Nb 0.00 0.00 5503.77 4400.30 Nc 0.00 0.00 5593.82 4490.30 OA 0.00 0.00 5663.82 4560.30 OBa 0.00 0.00 5713.82 4610.30 OBb 0.00 0.00 5773.82 4670.30 OBc 0.00 0.00 5823.82 4720.30 OBd 0.00 0.00 5888.82 4785.30 OBe 0.00 0.00 5928.82 4825.30 OBf 0.00 0.00 5968.82 4865.30 OBf Base 0.00 0.00 Sperry-Sun BP Planning Report Company: BP Amoco Date: 9!1312005 Timc; 15:43.`57 Page: 2 Field: Prudhoe Bay Co-ordinate(NE)Reference: Well: Plan V-212 (N-R), True North Site: PB V Pad Vertical (TVD) Reference: 53.8+21.5 75.3 Neil: 'Plan V-212 (N-R) Section (VS)Reference: Well (O.OON,O.OOE,59.79Azi) Wellpath: .Plant/-212 Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <--- Latitude --> <- Longitude -> Name Description TVD +N/-S " +E/-W Northing Easling Deg' Min Sec Deg Min Sec Dip..:. Dir. ft ft ft ft ft V-212 SV1 Flt 2175.30 2940.84 -1525.90 5973045.02 589105.04 70 20 10.112 N 149 16 37.427 W -Polygon 1 2175.30 2940.84 -1525.90 5973045.02 589105.04 70 20 10.112 N 149 16 37.427 W -Polygon 2 2175.30 1292.82 -470.65 5971410.02 590180.04 70 19 53.905 N 149 16 6.606 W -Polygon 3 2175.30 340.66 523.01 5970470.02 591185.04 70 19 44.540 N 149 15 37.595 W -Polygon 4 2175.30 -262.29 1585.90 5969880.02 592255.04 70 19 38.609 N 149 15 6.568 W -Polygon 5 2175.30 -861.00 2298.78 5969290.02 592975.04 70 19 32.719 N 149 14 45.763 W -Polygon 6 2175.30 -262.29 1585.90 5969880.02 592255.04 70 19 38.609 N 149 15 6.568 W -Polygon 7 2175.30 340.66 523.01 5970470.02 591185.04 70 19 44.540 N 149 15 37.595 W -Polygon 8 2175.30 1292.82 -470.65 5971410.02 590180.04 70 19 53.905 N 149 16 6.606 W -Plan out by 3331.61 at 2175.30 419.40 651.71 5970550.31 591312.77 70 19 45.315 N 149 15 33.837 W V-212 Top OA 4490.30 1398.08 2401.08 5971549.97 593050.02 70 19 54.936 N 149 14 42.756 W -Plan hit target V-212 Top OBd 4720.30 1398.08 2401.08 5971549.97 593050.02 70 19 54.936 N 149 14 42.756 W -Plan hit target V-212 TD 5035.30 1398.08 2401.08 5971549.97 593050.02 70 19 54.936 N 149 14 42.756 W -Plan hit target Plan Section Information MD Inc! Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100tt deg 21.50 0.00 0.00 21.50 0.00 0.00 0.00 0.00 0.00 0.00 293.30 0.00 15.00 293.30 0.00 0.00 0.00 0.00 0.00 15.00 393.30 1.00 15.00 393.29 0.84 0.23 1.00 1.00 0.00 15.00 995.82 10.00 30.00 992.43 51.33 27.80 1.50 1.49 2.49 16.63 1809.71 36.36 63.49 1736.30 223.80 284.33 3.50 3.24 4.11 43.30 1909.71 36.36 63.49 1816.83 250.27 337.38 0.00 0.00 0.00 0.00 2325.63 50.80 60.78 2117.35 384.71 589.70 3.50 3.47 -0.65 -8.38 4323.83 50.80 60.78 3380.28 1140.74 1941.09 0.00 0.00 0.00 0.00 5593.82 0.00 0.00 4490.30 1398.08 2401.08 4.00 -4.00 0.00 180.00 V-212 Top OA 5823.82 0.00 0.00 4720.30 1398.08 2401.08 0.00 0.00 0.00 0.00 V-212 Top OBd 6138.82 0.00 0.00 5035.30 1398.08 2401.08 0.00 0.00 0.00 0.00 V-212 TD Survey MI) Iucl Azim TVD Sys TVD N/S E/W DLS MapN MapE TooVCoa-me' t ft deg = deg ft, ft ft ft deg/100ft ft_ ft 21.50 0.00 0.00 21.50 -53.80 0.00 0.00 0.00 5970123.10 590666.23 GYD-GC-SS 100.00 0.00 15.00 100.00 24.70 0.00 0.00 0.00 5970123.10 590666.23 GYD-GC-SS 200.00 0.00 15.00 200.00 124.70 0.00 0.00 0.00 5970123.10 590666.23 GYD-GC-SS 293.30 0.00 15.00 293.30 218.00 0.00 0.00 0.00 5970123.10 590666.23 Start Dir 1/100 300.00 0.07 15.00 300.00 224.70 0.00 0.00 1.00 5970123.10 590666.23 GYD-GC-SS 315.30 0.22 15.00 315.30 240.00 0.04 0.01 1.00 5970123.14 590666.24 G 1 393.30 1.00 15.00 393.29 317.99 0.84 0.23 1.00 5970123.95 590666.45 Start Dir 1.5/1 400.00 1.10 16.50 399.99 324.69 0.96 0.26 1.50 5970124.06 590666.48 GYD-GC-SS 500.00 2.57 25.25 499.94 424.64 3.91 1.49 1.50 5970127.03 590667.67 GYD-GC-SS 600.00 4.07 27.60 599.77 524.47 9.09 4.09 1.50 5970132.23 590670.21 GYD-GC-SS 700.00 5.57 28.69 699.41 624.11 16.48 8.06 1.50 5970139.68 590674.09 GYD-GC-SS 800.00 7.06 29.31 798.80 723.50 26.10 13.40 1.50 5970149.36 590679.31 GYD-GC-SS 900.00 8.56 29.72 897.87 822.57 37.93 20.10 1.50 5970161.27 590685.87 GYD-GC-SS 968.28 9.59 29.93 965.30 890.00 47.27 25.46 1.50 5970170.67 590691.12 SV6 995.82 10.00 30.00 992.43 917.13 51.33 27.80 1.50 5970174.76 590693.41 Start Dir 3.5/1 1000.00 10.11 30.57 996.55 921.25 51.96 28.17 3.50 5970175.39 590693.77 GYD-GC-SS 1100.00 12.90 41.27 1094.54 1019.24 67.91 40.00 3.50 5970191.48 590705.40 GYD-GC-SS 1200.00 15.96 48.07 1191.38 1116.08 85.49 57.59 3.50 5970209.27 590722.78 MWD+IFR+MS 1300.00 19.18 52.69 1286.71 1211.41 104.64 80.89 3.50 5970228.70 590745.85 MWD+IFR+MS 1400.00 22.47 56.01 1380.17 1304.87 125.29 109.81 3.50 5970249.69 590774.51 MWD+IFR+MS 1500.00 25.82 58.51 1471.41 1396.11, 147.36 144.24 3.50 5970272.18 590808.67 MWD+IFR+MS 1600.00 29.20 60.47 1560.09 1484.79 170.76 184.05 3.50 5970296.06 590848.19 MWD+IFR+MS Sperry-Sun BP Planning Report Company: BP Amoco Date: 9/13/2005 Time: 15:43:57 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan V-21 2 (N-R), True North Site: PB V Pad Vertical (TVD) Reference: 53:8+21.5 75.3 Well: Plan V-212 (N-R) Section (VS) Reference: Well (O.OON,O.OOE,59.79Azi) Wellpat6: .Plan V-212. Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SysTVD N/S E/W I)LS MapN, MapE TooUComme t ft deg deg ft ft ft ft deg/100ft - ft ft 1693.38 32.38 61.96 1640.30 1565.00 193.75 225.95 3.50 5970319.55 590889.81 SV5 1700.00 32.61 62.06 1645.88 1570.58 195.42 229.09 3.50 5970321.26 590892.92 MWD+IFR+MS 1800.00 36.03 63.37 1728.46 1653.16 221.24 279.20 3.50 5970347.67 590942.71 MWD+IFR+MS 1809.71 36.36 63.49 1736.30 1661.00 223.80 284.33 3.50 5970350.30 590947.81 End Dir :1809 1858.14 36.36 63.49 1775.30 1700.00 236.62 310.02 0.00 5970363.43 590973.34 Base Permafro 1900.00 36.36 63.49 1809.01 1733.71 247.70 332.23 0.00 5970374.77 590995.41 MWD+IFR+MS 1909.71 36.36 63.49 1816.83 1741.53 250.27 337.38 0.00 5970377.40 591000.53 Start Dir 3.5/1 2000.00 39.49 62.76 1888.04 1812.74 275.36 386.87 3.50 5970403.09 591049.71 MWD+IFR+MS 2100.00 42.96 62.06 1963.24 1887.94 305.89 445.26 3.50 5970434.32 591107.72 MWD+IFR+MS 2200.00 46.43 61.45 2034.32 1959.02 339.18 507.20 3.50 5970468.35 591169.25 MWD+IFR+MS 2300.00 49.91 60.91 2101.00 2025.70 375.10 572.47 3.50 5970505.06 591234.08 MWD+IFR+MS 2305.97 50.12 60.88 2104.84 2029.54 377.32 576.47 3.50 5970507.33 591238.04 End Dir :2305 2325.63 50.80 60.78 2117.35 2042.05 384.71 589.70 3.50 5970514.88 591251.19 MWD+IFR+MS 2400.00 50.80 60.78 2164.36 2089.06 412.85 640.00 0.00 5970543.62 591301.14 MWD+IFR+MS 2417.31 50.80 60.78 2175.30 2100.00 419.40 651.71 0.00 5970550.31 591312.77 V-212 SV1 Flt 2425.22 50.80 60.78 2180.30 2105.00 422.40 657.06 0.00 5970553.37 591318.08 SV3 Faulted T 2500.00 50.80 60.78 2227.56 2152.26 450.69 707.63 0.00 5970582.27 591368.30 MWD+IFR+MS 2520.16 50.80 60.78 2240.30 2165.00 458.31 721.26 0.00 5970590.05 591381.84 SV2 2600.00 50.80 60.78 2290.76 2215.46 488.52 775.26 0.00 5970620.91 591435.46 MWD+IFR+MS 2700.00 50.80 60.78 2353.97 2278.67 526.36 842.89 0.00 5970659.56 591502.62 MWD+IFR+MS 2800.00 50.80 60.78 2417.17 2341.87 564.20 910.52 0.00 5970698.21 591569.79 MWD+IFR+MS 2900.00 50.80 60.78 2480.37 2405.07 602.03 978.15 0.00 5970736.85 591636.95 MWD+IFR+MS 3000.00 50.80 60.78 2543.58 2468.28 639.87 1045.78 0.00 5970775.50 591704.11 MWD+IFR+MS 3073.93 50.80 60.78 2590.30 2515.00 667.84 1095.78 0.00 5970804.07 591753.76 SV1 3100.00 50.80 60.78 2606.78 2531.48 677.70 1113.41 0.00 5970814.15 591771.27 MWD+IFR+MS 3200.00 50.80 60.78 2669.98 2594.68 715.54 1181.04 0.00 5970852.79 591838.43 MWD+IFR+MS 3232.15 50.80 60.78 2690.30 2615.00 727.70 1202.78 0.00 5970865.22 591860.02 9 5/8" 3300.00 50.80 60.78 2733.19 2657.89 753.37 1248.67 0.00 5970891.44 591905.60 MWD+IFR+MS 3400.00 50.80 60.78 2796.39 2721.09 791.21 1316.30 0.00 5970930.09 591972.76 MWD+IFR+MS 3500.00 50.80 60.78 2859.59 2784.29 829.04 1383.93 0.00 5970968.73 592039.92 MWD+IFR+MS 3556.50 50.80 60.78 2895.30 2820.00 850.42 1422.14 0.00 5970990.57 592077.86 UG4 3596.05 50.80 60.78 2920.30 2845.00 865.39 1448.89 0.00 5971005.85 592104.43 UG4A 3600.00 50.80 60.78 2922.79 2847.49 866.88 1451.56 0.00 5971007.38 592107.08 MWD+IFR+MS 3700.00 50.80 60.78 2986.00 2910.70 904.72 1519.19 0.00 5971046.02 592174.24 MWD+IFR+MS 3800.00 50.80 60.78 3049.20 2973.90 942.55 1586.82 0.00 5971084.67 592241.41 MWD+IFR+MS 3900.00 50.80 60.78 3112.40 3037.10 980.39 1654.46 0.00 5971123.32 592308.57 MWD+IFR+MS 4000.00 50.80 60.78 3175.61 3100.31 1018.22 1722.09 0.00 5971161.96 592375.73 MWD+IFR+MS 4100.00 50.80 60.78 3238.81 3163.51 1056.06 1789.72 0.00 5971200.61 592442.89 MWD+IFR+MS 4155.60 50.80 60.78 3273.95 3198.65 1077.09 1827.32 0.00 5971222.10 592480.23 Start Dir 4/100 4181.47 50.80 60.78 3290.30 3215.00 1086.88 1844.81 0.00 5971232.10 592497.61 UG3 4200.00 50.80 60.78 3302.01 3226.71 1093.89 1857.35 0.00 5971239.26 592510.05 MWD+IFR+MS 4300.00 50.80 60.78 3365.22 3289.92 1131.73 1924.98 0.00 5971277.90 592577.22 MWD+IFR+MS 4323.83 50.80 60.78 3380.28 3304.98 1140.74 1941.09 0.00 5971287.11 592593.22 MWD+IFR+MS 4400.00 47.75 60.78 3429.97 3354.67 1168.93 1991.46 4.00 5971315.90 592643.24 MWD+IFR+MS 4500.00 43.75 60.78 3499.73 3424.43 1203.89 2053.97 4.00 5971351.62 592705.31 MWD+IFR+MS 4600.00 39.75 60.78 3574.31 3499.01 1236.40 2112.07 4.00 5971384.82 592763.02 MWD+IFR+MS 4700.00 35.75 60.78 3653.36 3578.06 1266.29 2165.49 4.00 5971415.35 592816.07 MWD+IFR+MS 4800.00 31.75 60.78 3736.49 3661.19 1293.41 2213.97 4.00 5971443.05 592864.21 MWD+IFR+MS 4900.00 27.75 60.78 3823.29 3747.99 1317.63 2257.27 4.00 5971467.79 592907.21 MWD+IFR+MS 4907.91 27.44 60.78 3830.30 3755.00 1319.42 2260.47 4.00 5971469.62 592910.39 UG1 5000.00 23.75 60.78 3913.34 3838.04 1338.84 2295.18 4.00 5971489.46 592944.86 MWD+IFR+MS 5100.00 19.75 60.78 4006.20 3930.90 1356.93 2327.52 4.00 5971507.93 592976.97 MWD+IFR+MS 5188.43 16.22 60.78 4090.30 4015.00 1370.26 2351.35 4.00 5971521.55 593000.63 Ma Sperry-sun BP Planning Report Company: BP Amoco Date:. 9/13/2005 lime: 15:43:57 Page: 4 ..Field:. Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan V-212 (N-R), True North Site: PB V Pad Vertical (1'VD) Reference:. 53.8+21.5 75.3 Well: Plan V-212 (N-R) Section (VS) Reference: Well (O:OON,O.OOE,59.79Azi) Wellpath:' Plan V-212 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim T'VD Sys-TVD N/S E/W DLS MapN MapE TooUComme t ft deg - !deg ft - fit ft ft deg/100ft ft ft 5200.00 15.75 60.78 4101.42 4026.12 1371.82 2354.13 4.00 5971523.14 593003.39 MWD+IFR+MS 5240.24 14.14 60.78 4140.30 4065.00 1376.88 2363.18 4.00 5971528.31 593012.39 Mb1 5300.00 11.75 60.78 4198.53 4123.23 1383.42 2374.87 4.00 5971534.99 593023.99 MWD+IFR+MS 5312.01 11.27 60.78 4210.30 4135.00 1384.59 2376.96 4.00 5971536.19 593026.07 Mb2 5367.89 9.04 60.78 4265.30 4190.00 1389.40 2385.56 4.00 5971541.10 593034.61 Mc 5400.00 7.75 60.78 4297.07 4221.77 1391.69 2389.65 4.00 5971543.44 593038.67 MWD+IFR+MS 5407.90 7.44 60.78 4304.90 4229.60 1392.20 2390.56 4.00 5971543.96 593039.58 End Dir :5407 5433.49 6.41 60.78 4330.30 4255.00 1393.71 2393.25 4.00 5971545.50 593042.25 Na 5458.62 5.41 60.78 4355.30 4280.00 1394.97 2395.51 4.00 5971546.79 593044.49 Nb 5500.00 3.75 60.78 4396.54 4321.24 1396.58 2398.40 4.00 5971548.44 593047.36 MWD+IFR+MS 5503.77 3.60 60.78 4400.30 4325.00 1396.70 2398.61 4.00 5971548.56 593047.57 Nc 5593.82 0.00 0.00 4490.30 4415.00 1398.08 2401.08 4.00 5971549.97 593050.02 V-212 Top OA 5600.00 0.00 0.00 4496.48 4421.18 1398.08 2401.08 0.00 5971549.97 593050.02 MWD+IFR+MS 5663.82 0.00 0.00 4560.30 4485.00 1398.08 2401.08 0.00 5971549.97 593050.02 OBa 5700.00 0.00 0.00 4596.48 4521.18 1398.08 2401.08 0.00 5971549.97 593050.02 MWD+IFR+MS 5713.82 0.00 0.00 4610.30 4535.00 1398.08 2401.08 0.00 5971549.97 593050.02 OBb 5773.82 0.00 0.00 4670.30 4595.00 1398.08 2401.08 0.00 5971549.97 593050.02 OBc 5800.00 0.00 0.00 4696.48 4621.18 1398.08 2401.08 0.00 5971549.97 593050.02 MWD+IFR+MS 5823.82 0.00 0.00 4720.30 4645.00 1398.08 2401.08 0.00 5971549.97 593050.02 V-212 Top OBd 5888.82 0.00 0.00 4785.30 4710.00 1398.08 2401.08 0.00 5971549.97 593050.02 OBe 5900.00 0.00 0.00 4796.48 4721.18 1398.08 2401.08 0.00 5971549.97 593050.02 MWD+IFR+MS 5928.82 0.00 0.00 4825.30 4750.00 1398.08 2401.08 0.00 5971549.97 593050.02 OBf 5968.82 0.00 0.00 4865.30 4790.00 1398.08 2401.08 0.00 5971549.97 593050.02 OBf_Base 6000.00 0.00 0.00 4896.48 4821.18 1398.08 2401.08 0.00 5971549.97 593050.02 MWD+IFR+MS 6052.00 0.00 0.00 4948.48 4873.18 1398.08 2401.08 0.00 5971549.97 593050.02 Total Depth : 6 6100.00 0.00 0.00 4996.48 4921.18 1398.08 2401.08 0.00 5971549.97 593050.02 MWD+IFR+MS 6138.00 0.00 0.00 5034.48 4959.18 1398.08 2401.08 0.00 5971549.97 593050.02 7" 6138.82 0.00 0.00 5035.30 4960.00 1398.08 2401.08 0.00 5971549.97 593050.02 V-212 TD i ~ Sperry-Sun Anticollision Report Company: BP Amoco Date: 9(1312005 Timc: 15:42:55 Page: 1 Field: Prudhoe Bay Reference Site: PB V Pad Co-ordinate(NE) Reference: Well: Pla n V-212 (N-R), True North Reference Well: Plan V-212 (N-R) Vertical (TVD) Referencez 53.8+21. 5 75.3 Reference Wellpath: Plan V-212 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are T>~~~ls in this fiZldh: V-212 wp04 & NOT PLANNED PR Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 21.50 to 6138.82 ft Scan Method: Trav Cylinder North Maximum Radius: 811.73 ft Error Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft : ' in in 3232.15 2690.30 9.625 12.250 9 5/8" 6138.00 5034.48 7.000 8.750 7" Plan: V-212 wp04 Date Composed: 6/7/2005 Version: 11 Principal: Yes Tied-to: From Well Ref. Point Summary ~--- Offset Wellpath -- -----> Reference Offset. Ctr-Ctr No-Go Allowable Site Well Wellpath:. MD iVID Distance Area Deviation Waroing ft ft ft ft ft, /' PB V Pad Plan V-112 (S-R) Plan V-112 V2 Plan: PI 397.12 400.00 180.93 7.62 173.30 Pass: Major Risk PB V Pad Plan V-112 (S-R) Plan V-112PB1 V1 Plan: 397.12 400.00 180.93 7.62 173.30 Pass: Major Risk PB V Pad Plan V-205 (S-P) Plan V-205 V2 Plan: PI 324.07 325.00 183.00 6.41 176.60 Pass: Major Risk PB V Pad Plan V-206 (SS) Plan V-206 V1 Plan: PI 324.19 325.00 181.09 6.41 174.68 Pass: Major Risk PB V Pad Plan V-214 (N-E) Plan V-214 V5 Plan: V- 684.96 700.00 235.52 13.06 222.46 Pass: Major Risk PB V Pad Plan V-3a06 (S-U) Plan V-3a06 V1 Plan: P 543.96 550.00 186.91 11.69 175.22 Pass: Major Risk PB V Pad V-01 V-01 V15 250.00 250.00 190.60 4.65 185.95 Pass: Major Risk PB V Pad V-02 V-02 V12 250.00 250.00 176.34 4.70 171.64 Pass: Major Risk PB V Pad V-03 V-03 V7 978.44 975.00 65.98 16.16 49.82 Pass: Major Risk PB V Pad V-100 V-100 V7 299.85 300.00 190.91 5.34 185.57 Pass: Major Risk PB V Pad V-101 V-101 V7 421.56 425.00 248.10 7.25 240.85 Pass: Major Risk PB V Pad V-102 V-102 V5 398.67 400.00 129.30 8.10 121.20 Pass: Major Risk PB V Pad V-103 V-103 V6 575.63 575.00 15.64 10.20 5.44 Pass: Major Risk PB V Pad V-104 V-104 V13 373.70 375.00 191.18 6.48 184.70 Pass: Major Risk PB V Pad V-105 V-105 V13 448.62 450.00 61.47 7.78 53.70 Pass: Major Risk PB V Pad V-106 V-106 V10 424.75 425.00 13.03 6.87 6.16 Pass: Major Risk PB V Pad V-106 V-106A V9 249.78 250.00 15.58 4.83 10.76 Pass: Major Risk PB V Pad V-106 V-106AP61 V6 249.78 250.00 15.58 4.83 10.76 Pass: Major Risk PB V Pad V-106 V-106AP62 V2 249.78 250.00 15.58 4.83 10.76 Pass: Major Risk PB V Pad V-106 V-106APB3 V2 249.78 250.00 15.58 4.83 10.76 Pass: Major Risk PB V Pad V-107 V-107 V5 446.73 450.00 160.56 7.15 153.40 Pass: Major Risk PB V Pad V-111 V-111 V25 801.81 800.00 48.45 14.87 33.57 Pass: Major Risk PB V Pad V-111 V-111 PB1 V8 801.81 800.00 48.45 14.87 33.57 Pass: Major Risk PB V Pad V-111 V-111P62 V2 801.81 800.00 48.45 14.87 33.57 Pass: Major Risk PB V Pad V-111 V-111 PB3 V6 801.81 800.00 48.45 14.87 33.57 Pass: Major Risk PB V Pad V-115 V-115 V5 324.38 325.00 201.93 5.61 196.33 Pass: Major Risk PB V Pad V-115 V-115PB1 V4 324.38 325.00 201.93 5.60 196.33 Pass: Major Risk PB V Pad V-117 V-117 V9 324.22 325.00 183.84 5.87 177.97 Pass: Major Risk PB V Pad V-117 V-117PB1 V6 324.22 325.00 183.84 5.87 177.97 Pass: Major Risk PB V Pad V-117 V-117PB2 V6 324.22 325.00 183.84 5.87 177.97 Pass: Major Risk PB V Pad V-120 V-120 V5 274.99 275.00 89.52 5.13 84.39 Pass: Major Risk PB V Pad V-201 V-201 V8 373.99 375.00 146.80 6.36 140.44 Pass: Major Risk PB V Pad V-202 V-202 V9 421.79 425.00 220.95 7.82 213.13 Pass: Major Risk PB V Pad V-202 V-202L1 V5 421.79 425.00 220.95 7.77 213.18 Pass: Major Risk PB V Pad V-202 V-202L2 V5 421.79 425.00 220.95 7.77 213.18 Pass: Major Risk PB V Pad V-204 V-204 V2 652.60 675.00 241.62 11.88 229.74 Pass: Major Risk PB V Pad V-204 V-204L1 V2 652.60 675.00 241.62 11.88 229.74 Pass: Major Risk PB V Pad V-204 V-204L1 PB1 V6 652.60 675.00 241.62 11.88 229.74 Pass: Major Risk PB V Pad V-204 V-204L2 V2 652.60 675.00 241.62 11.88 229.74 Pass: Major Risk PB V Pad V-204 V-204L2P61 V5 652.60 675.00 241.62 11.88 229.74 Pass: Major Risk PB V Pad V-204 V-204L3 V3 652.60 675.00 241.62 11.88 229.74 Pass: Major Risk PB V Pad V-204 V-204PB1 V9 652.60 675.00 241.62 11.88 229.74 Pass: Major Risk PB V Pad V-204 V-204P62 V2 652.60 675.00 241.62 11.88 229.74 Pass: Major Risk PB V Pad V-210 V-210 V9 445.79 450.00 204.44 8.11 196.33 Pass: Major Risk PB V Pad V-213 V-213 V5 1529.18 1525.00 86.56 25.33 61.23 Pass: Major Risk PB V Pad V-213 V-213P61 V5 1529.18 1525.00 86.56 25.33 61.23 Pass: Major Risk PB V Pad V-216 V-216 V8 249.97 250.00 31.95 4.77 27.18 Pass: Major Risk SAM --------- E 5,172 15'00'00" ARID I I I I I I PLANT I I I I I I ^ V-120 ^ V-115 I ^ V-03 ^ V-2131 ^ V-110 ^ V-100 I ^ V-111 I ^ V 1031 ^ V-117 - I V-212 ~ ^ SLOT s-R I V-106 I ^ V-1051 ^ V-01 I ^ V-221 i I M ^ V-102 ^ V-SPARE (aor s-L) I m ^ I V-201 I I ^ V-107 ^ SLOT S-J z ^ V-02 m l I ^ V-1041 ^ V-204 a' ~D I ^ V-2101 ^ V-114 ~ I ^ V-202 ^ V-119 z I I ^ V-2141 ^ V-109 I ^ V-101 I ^ V-2111 ^ V-113 I ^ V-108 I I ^ V-203 I I I ~ ~ I I I I ~ ~ I , V-PAD I 5p1NE ROAD "'~ TO _ - - ~ - ~ / _ _ LPPD / _ ~~~~ jOwOP ,/ ~ ,- ~ LEGEND ~' ~ / -~- AS-BUILT CONDUCTOR ^ EXISTING CONDUCTOR NOTES 1. DATE OF SURVEY: 7/27/05 and 8/02/05 2. REFERENCE FIELD BOOK: W005-12 Pg's 48-49 and 68-70 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD-27. 4. BASIS OF HORIZONTAL CONTROL IS V-PAD OPERATOR MONUMENTATION. 5. BASIS OF ELEVATION IS KUPARUK PIPELINE CONTROL. ELEVATIONS ARE BP MEAN SEA LEVEL DATUM. 6. THE MEAN SCALE FACTOR FOR V-PAD IS 0.999909334. 'C1 '~1 ~ a ~ ~.V ~ 1 L-PAD 9 °, 34 ~ ~' d e i s~!( \~ ~, t ~\ ~` ~°, 35 ~~ ~ a ~ ~~ /~ov ° ~ ~ ~ ~~ ~ .~ I~ 2 c' ~,~~ a \ ~i i ~ _~., ~.~ _ ' ° ` Tl~~v ~` ~ °'° ~~ ,- ~ ~ - 5 i ° a - a y~ _ WEST ~ pp ~ ea ;QK TAK t. ~,~5 ~~ ->i ~ o c~ / c o ~ 3 ~~ ~ ' PROJECTR`~ ~{ _ ~ AREA ~ ~c . ~~ ~~ r ` ~ t 10~' „ ~ ' ~~ ~ ~a t~^ ° ~,, ~ ~ ~ a ~, `fir _S;J"' VICINITY MAP N.T.S. OF ,~~ A ~~ ~Q'°°°,°°°°°°°° °S~C~h, °49 ~ ~ 9* °°°°°°°°°°°°°°°°°°°°°°°°°°°°°°° ~° Richard F. Allison ~s °° 10608 °° SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY D[RECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 8/02/05 LOCATED WITHIN PROTRACTED SEC. 11, T. 11 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION D.DD BOX ELEV. OFFSETS V-212 Y= 5,970,123.10 N=10,180.20 70'19'41.190" 70.3281083' 53 8' 4,874' FSL ' X= 590,666.23 E= 4,925.32 149'15'52.864" 149.2646844' . 1,634 FEL r . nooerr. - °°~KyyH CHECKEDA {1h O ~ DATEBRRFF/03/05 l/r e DRAN7NG: SHEET: FRees wov as-ee GREATER PRUDHOE BAY V-PAD ~ ~~~~~o doB No. AS-BUILT CONDUCTOR 1 of 1 l9J SCALE: WELLS V-212 B 8 03 0 ISSUED FOR INFORMATION KWH RFA resr n~x® ux 1'=150• NO. DATE REVISION BY CHK w+~~. K~x~ ~ ~ • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~~I~~ ~ ~Z, PTD# 2.OS ~ ~5~3 CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing wel! , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), atl (p)~ records, data and togs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. fCompany Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH Atl dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev; 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKl.tST Field & Pool PRUDHOE BAY, ORION SCHR BLOIL-640135 Well Name: PRUDHOE BAY UN ORIN V•212 Program SER Well bare seg ^ PTD#:2051500 Company BP EXPLORATION (ALASItA) INC Initial ClasslType SER 1 WAGIN GeoArea Unit OnlOff Shore On Annular Disposal ^ Administration 1 Permit-fee attached - - Yes - - - - - - 2 Lease number appropriate- - - - - - - - Yea - - - - - - - - - - - 3 Uniquewell_nameandnumbe[_______________________________ _______Yea_ --__-___-_____-_ ---------------------------------------------------------- 4 Welllocat_edina_defnedpool-------------------------------- ------Yes- -------------------------.- - - - - 5 Well located properdistanGefromdrillingunit_boundary________________ __-__-Ye5 ___-_-_-__.__--__--___.-_--__-__-__--_-----___-_---_____-_-_-__--_- --- 6 Well located properdistance_fromotherwells---------------------- --_---Yes- ----.----------------------------------------------.------------- _-- 7 Sufficieni acreage ayail_able in-drilling unit- - - - Yes - - - - - - - - 8 If deviated, is-we_Ilborep/at-included - - - - - - - - - Yes - - - - - - - - - - - - - 9 Ope[ator gnly affected party - - - - - - Yes - - - - - - - - - - - 10 Ope[atorhas-appropriate-bondip force ----•-------------------- -- --Yes- ----- -------------- -- --- ----- ------- ----------- -- ----- -------- 11 Pe[mit_canbeissuedwithoutconservationorder--------------------- ------YeS- -----.-------------------------,--------------------.------------------ Appr Date 12 Permit_canbeissuedwithoutadministrative_approyal-___-__-________ _____-__Y_es_ __-_________________________________ RPC 1D/1112005 13 Can permit be approved before 15-day wait Yes 14 Well located withinarQaand-strataauth4rizedby-InjectionOrde[#(put1C1#in_comments)_(FQr_Yes_ _-__--AIO.24_________________________________________________---_---_---__. 15 All wells within114_milearea.ofreviewidentified(Forserv_ieewellonly)________ _______Yes_ _-__.-V-204_--__--___--__-__-___-___--__-_-________--_ --------------------- 16 Pre•produced injector: duration of pre production less than_ 3 months_(For service well only) - No_ _ 17 ACMP-Finding of Consistency-has been issued-for_this pro[ect_ - - - - - _ - N_A- - - - _ - _ - - - - - - Engineering 18 Conductorst[ing-plovided_---_--_-______--_________ _______Yes_ _--_--20"x34"-@102'.____--_---_--__-__---_--_--_______---- --_--_ 19 Surface casingprotects aII known USDWs - - - - - - Yes - - - - 20 CMT-vol adequate_to circulate-on conductor& surf_csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ - _ -Adequate excess. - _ _ _ - . _ _ - _ _ _ _ - - _ _ _ _ - 21 CMT_voladequate_totie-inlongstringtosu_rfcsg__----------------- --- --- No_ -_____--_-__-____--_--_-___-__--------------------------- _--- 22 CMT_willcoverallknown_productivehorizons_-.____-_------------- -------Yes- __-___-__---_-___--__--__--__-_-- - - 23 Casing desyns adegr~ate for C, T, B &_permafrost- - - - - - - Yes - - - - - - - - - - - - - - 24 Adequate tankage-or reserve pit - - - - - Yes - - Doyon 16. - - - - - 25 Ifa_re-drill,has-a-1.0-403forabandonment been approved_______________ _____ NA__ -__--_Newwell,______-_------.---_-_-__--_---___-___--_- - 26 Adequatewellbo-reseparation-proposed__________________________ _______Yes_ _-__.----_---___-__----_---_-__-___-___--__---_ --------------------------- 27 Ifdiverterrequired,doesitmeetregu-lations---------------------- ------Yes- _-_-__-._ - - Appr Date 28 Dnllingfluid_pregramschQmatic&e4uiplistadequate-________________ _______Yes- _-__--Max MW-9.5ppg,-_---__-______-_-__-__--___-_--__---_-_--_-__---- WGA 10/1212005 29 BOPES,dotheymeetregulation__________________--____--_ _---___Yes- -__--__-___________--_-__-______ _______-__--__________--__---___ 30 BQPE_pressratingappropriate;testto_(putpsigincomments)------------- -------Yes- ____Testto 4000psi._MSP1663psi.__________---__--___---______-_-__-___-_-.-_-.__ 31 Choke_manifoldcomplieswlAPl_RP-53(May84)_____________________ _______Yes_ _--__---_-._ - - - ~ - 32 Work willoccurwithgutoperationshutdown________________________ _ __-.Yes- ----___-_____-__- -------------------------------------------------------- 33 Ispresence_ofH2Sgas_probable--------------------.-------- -._--Yes- ---- -Not anH2Spad,butllDppm.---_-_--_-.-__------------------------ ----- 34 Mechanical condition of wells within AOR verified (For-service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - - _ - - -Cement records indicate meeh integri_ty_of V-204. _ - _ - _ - - - _ _ _ _ _ _ - _ _ - . , _ - _ _ - _ _ _ - _ _ - - - - - - _ _ Geology 35 Permitcan be issued wlo hydrogen_sul_fide measures - _ - _ - _ - _ Yes - 36 Data-presented on potentialoverpressu[ezones__-_-_____--------- ------- NA-_ _______-__________________-_____-_-_-_--__----_------_--_---__----_-.-_ Appr Date 37 Seismic analysis of shallow gas-zones------------------------ ---- --NA_- -_--__.__-_--__-_--_-.__-_--_-__----------.-.---- ----- - RPC 10111!2005 38 Seabed conditionsuryey_(ifoff-shore)--------------------------- -------NA- - -- --- _- 39 -Contact name/phone for weekly progress_reports [exploratory only]_ _ _ _ _ _ NA - _ Geologic Commissioner: Engineering Pu Date: Commissioner: Date Com ' s' ner Date ~~ C7 • Well History File APPENDIX Information of detailed nature that is not particularly germane io the Well Permitting Process but is part of the history frie. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made 1o chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb 02 15:06:24 2007 Reel Header Service name .............LISTPE Date .....................07/02/02 Origin ...................STS Reel Name..... ..........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................07/02/02 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Greater Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 1 JOB NUMBER: W-0004084736 LOGGING ENGINEER: D. RICHARDSO OPERATOR WITNESS: B. BUZBY Scientific Technical Services Scientific Technical Services V-212 500292327900 BP Exploration (Alaska), Inc. Sperry Drilling Services 02-FEB-07 MWD RUN 2 MWD RUN 4 W-0004084736 W-0004084736 N. WHITE D. RICHARDSO C. GALLOWAY C. GALLOWAY MAD RUN 4 JOB NUMBER: W-0004084736 LOGGING ENGINEER: D. RICHARDSO OPERATOR WITNESS: C. GALLOWAY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 11 i1N 11E 4874 1634 80.00 53.80 WELL CASING RECORD OPEN HOLE CASING DRILLERS . i ~ BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 20.000 106.0 2ND STRING 8.750 9.625 3233.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 4. MWD RUNS 1,2,4 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUN 4 ALSO INCLUDED ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON (CTN), AZIMUTHAL LITHO-DENSITY (ALD), ACOUSTIC CALIPER (ACAL), AND PRESSURE WHILE DRILLING (PWD) NO DATA WERE ACQUIRED ON MWD RUN 3. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. DORTCH (SAIL/BP) DATED 1/9/2007. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1,2,4 REPRESENT WELL V-212 WITH API#: 50-029-23279-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6150'MD/5048'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (ACAL-DERIVED SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR-TO-BIT DISTANCE. PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: MUD WEIGHT: MUD SALINITY: FORMATION WATER SALINITY: FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: ACAL (8.75" BIT} 8.9 PPG 2800 - 4500 PPM CHLORIDES 10994 PPM CHLORIDES 1.0 G/CC 2.65 G/CC SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 65.5 6103.5 ROP 106.5 6150.0 RPS 3210.0 6096.0 RPX 3210.0 6096.0 FET 3210.0 6096.0 RPM 3210.0 6096.0 RPD 3210.0 6096.0 GALA 3220.0 6056.5 PEF 3220.0 6067.0 NPHI 3220..0 6054.0 RHOB 3220.0 6067.0 FCNT 3220..0 6054.0 NCNT 322000 6054.0 DRHO 3220.0 6067.0 I~ L BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 MWD 4 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 65.5 1867.0 1867.0 3239.0 3239.0 6150.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD INCH 4 1 68 4 2 FCNT MWD CNTS 4 1 68 8 3 NCNT MWD CNTS 4 1 68 12 4 RHOB MWD G/CM 4 1 68 16 5 DRHO MWD G/CM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 RPM MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPX MWD OHMM 4 1 68 36 10 FET MWD HOUR 4 1 68 40 11 GR MWD API 4 1 68 44 12 PEF MWD BARN 4 1 68 48 13 ROP MWD FT/H 4 1 68 52 14 NPHI MWD PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 65.5 6150 3107.75 12170 65.5 6150 CALA MWD INCH 8.72 13.5 9.52542 5305 3220 6056.5 FONT MWD CNTS 442.91 3300.55 873.672 5669 3220 6054 NCNT MWD CNTS 104098 190095 131189 5669 3220 6054 RHOB MWD G/CM 1.118 3.764 2.17427 5695 3220 6067 DRHO MWD G/CM -1.114 0.552 0.0619554 5695 3220 6067 RPD MWD OHMM 0.14 2000 22.0377 5773 3210 6096 RPM MWD OHMM 0.52 1743.45 19.471 5773 3210 6096 RPS MWD OHMM 0.88 2000 10.1973 5773 3210 6096 RPX MWD OHMM 0.6 2000 7.14019 5773 3210 6096 FET MWD HOUR 0.08 82.92 1.46312 5773 3210 6096 GR MWD API 11.83 159.05 69.0865 12077 65.5 6103.5 PEF MWD BARN -0.83 11.43 1.78461 5695 3220 6067 ROP MWD FT/H 0.04 1483.77 196.074 12088 106.5 6150 NPHI MWD PU-S 10.24 105.06 37.7431 5669 3220 6054 First Reading For Entire File..........65.5 Last Reading For Entire File...........6150 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH all MAD runs merged using earliest passes. STOP DEPTH PEF 3282.5 6056.0 RHOB 3282.5 6056.0 DRHO 3282.5 6056.0 CALA 3296.5 6045.5 NPHI 3305.0 6042.5 FCNT 3305.0 6042.5 NCNT 3305.0 6042.5 RPD 3312.5 6085.0 RPX 3312.5 6085.0 FET 3312.5 6085.0 RPS 3312.5 6085.0 RPM 3312.5 6085.0 GR 3318.5 6092.0 RAT 3359.5 6137.0 MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS N0. MERGE TOP MERGE BASE MWD 4 1 3198.0 6150.0 REMARKS: MERGED MAD PASS. Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type..... 0 Logging Direction ................. Down Optical log depth units........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MAD INCH 4 1 68 4 2 FCNT MAD CNTS 4 1 68 8 3 NCNT MAD CNTS 4 1 68 12 4 RHOB MAD G/CM 4 1 68 16 5 DRHO MAD G/CM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 RPM MAD OHMM 4 1 68 28 8 RPS MAD OHMM 4 1 68 32 9 RPX MAD OHMM 4 1 68 36 10 FET MAD HOUR 4 1 68 40 11 GR MAD API 4 1 68 44 12 PEF MAD BARN 4 1 68 48 13 RAT MAD FT/H 4 1 68 52 14 NPHI MAD PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3282.5 6137 4709.75 5710 3282.5 6137 CALA MAD INCH 8.71 11.95 9.61786 3410 3296.5 6045.5 FCNT MAD CNTS 478.63 3241.31 911.69 3425 3305 6042.5 NCNT MAD CNTS 108186 204465 133744 3425 3305 6042.5 RHOB MAD G/CM 1.268 2.784 2.15938 3542 3282.5 6056 DRHO MAD G/CM -0.093 0.417 0.048939 3542 3282.5 6056 RPD MAD OHMM 0.67 1888.86 22.8293 3560 3312.5 6085 RPM MAD OHMM 0.62 491.15 13.2524 3560 3312.5 6085 RPS MAD OHMM 0.7 93.85 7.74202 3560 3312.5 6085 RPX MAD OHMM 0.7 58.02 5.37858 3560 3312.5 6085 FET MAD HOUR 150.46 2728.32 1548.82 3560 3312.5 6085 r~ ~J GR MAD API 13.27 157.76 75.0952 3564 PEF MAD BARN -0.65 7.07 1.72395 3542 RAT MAD FT/H 0.04 2835.93 258.661 3571 NPHI MAD PU-S 11.44 92.86 37.8035 3425 First Reading For Entire File..........3282.5 Last Reading For Entire File...........6137 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER r-~ ~~ 3318.5 6092 3282.5 6056 3359.5 6137 3305 6042.5 FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 65.5 1826.0 ROP 106.5 1867.0 LOG HEADER DATA DATE LOGGED: 04-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 1867.0 TOP LOG INTERVAL (FT) 106.0 BOTTOM LOG INTERVAL (FT) 1867.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 35.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 76571 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 106.0 • • BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S): 340.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3) 14.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWD010 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 65.5 1867 966.25 3604 65.5 1867 GR MWDO10 API 18.73 135.53 61.2422 3522 65.5 1826 ROP MWDO10 FT/H 0.04 1010.47 91.3817 3522 106.5 1867 First Reading For Entire File..........65.5 Last Reading For Entire File...........1867 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF • • File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 1826.5 3197.5 ROP 1867.5 3239.0 LOG HEADER DATA DATE LOGGED: 05-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 3239.0 TOP LOG INTERVAL (FT) 1867.0 BOTTOM LOG INTERVAL (FT) 3239.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 37.0 MAXIMUM ANGLE: 54.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 76571 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 106.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 340.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 2000 FLUID LOSS (C3) 14.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 90.5 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • S Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1826.5 3239 2532.75 2826 1826.5 3239 GR MWD020 API 26.18 120.46 72.5751 2743 1826.5 3197.5 ROP MWD020 FT/H 0.82 618.59 188.009 2744 1867.5 3239 First Reading For Entire File..........1826.5 Last Reading For Entire File...........3239 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/02 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3198.0 6103.5 RPD 3210.0 6096.0 RPX 3210.0 6096.0 FET 3210.0 6096.0 • RPM 3210.0 6096.0 RPS 3210.0 6096.0 DRHO 3220.0 6067.0 RHOB 3220.0 6067.0 PEF 3220.0 6067.0 NCNT 3220.0 6054.0 FCNT 3220.0 6054.0 CALA 3220.0 6056.5 NPHI 3220.0 6054.0 ROP 3239.5 6150.0 LO G HEADER DATA DATE LOGGED: 10-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6150.0 TOP LOG INTERVAL (FT) 3239.0 BOTTOM LOG INTERVAL (FT) 6150.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .l MAXIMUM ANGLE: 53.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 157645 CTN COMP THERMAL NEUTRON 1844674407370955 ALD Azimuth Litho-den 10718055 ACAL Acoustic Caliper 10718055 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 3233.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 8.90 MUD VISCOSITY (S) 44.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 11000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.000 76.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.870 126.0 MUD FILTRATE AT MT: 2.800 76.0 MUD CAKE AT MT: 3.200 76.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet • Data Reference Point ..............Undefined Frame Spacing .. ........... . .......60 .lIN Max frames per record ..... ........Undefined Absent value ... ........... . .......-999 Depth Units .... ........... ........ Datum Specifica tion Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD040 INCH 4 1 68 4 2 FCNT MWD040 CNTS 4 1 68 8 3 NCNT MWD040 CNTS 4 1 68 12 4 RHOB MWD040 G/CM 4 1 68 16 5 DRHO MWD040 G/CM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 RPM MWD040 OHMM 4 1 68 28 8 RPS MWD040 OHMM 4 1 68 32 9 RPX MWD040 OHMM 4 1 68 36 10 FET MWD040 HOUR 4 1 68 40 11 GR MWD040 API 4 1 68 44 12 PEF MWD040 BARN 4 1 68 48 13 ROP MWD040 FT/H 4 1 68 52 14 NPHI MWD040 PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3198 6150 4674 5905 3198 6150 GALA MWD040 INCH 8.72 13.5 9.52542 5305 3220 6056.5 FCNT MWD040 CNTS 442.91 3300.55 873.672 5669 3220 6054 NCNT MWD040 CNTS 104098 190095 131189 5669 3220 6054 RHOB MWD040 G/CM 1.118 3.764 2.17427 5695 3220 6067 DRHO MWD040 G/CM -1.114 0.552 0.0619554 5695 3220 6067 RPD MWD040 OHMM 0.14 2000 22.0377 5773 3210 6096 RPM MWD040 OHMM 0.52 1743.45 19.471 5773 3210 6096 RPS MWD040 OHMM 0.88 2000 10.1973 5773 3210 6096 RPX MWD040 OHMM 0.6 2000 7.14019 5773 3210 6096 FET MWD040 HOUR 0.08 82.92 1.46312 5773 3210 6096 GR MWD040 API 11.83 159.05 72.1937 5812 3198 6103.5 PEF MWD040 BARN -0.83 11.43 1.78461 5695 3220 6067 ROP MWD040 FT/H 0.17 1483.77 263.208 5822 3239.5 6150 NPHI MWD040 PU-S 10.24 105.06 37.7431 5669 3220 6054 First Reading For Entire File..........3198 Last Reading For Entire File...........6150 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/02 Maximum Physical Record..65535 • • File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH PEF 3282.5 RHOB 3282.5 DRHO 3282.5 CALA 3296.5 FONT 3305.0 NCNT 3305.0 NPHI 3305.0 FET 3312.5 RPM 3312.5 RPD 3312.5 RPX 3312.5 RPS 3312.5 GR 3318.5 RAT 3359.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 6056.0 6056.0 6056.0 6045.5 6042.5 6042.5 6042.5 6085.0 6085.0 6085.0 6085.0 6085.0 6092.0 6137.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON ACAL Acoustic Caliper ALD Azimuth Litho-den BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 10-DEC-05 Insite 66.37 Memory 6150.0 3239.0 6150.0 .1 53.1 TOOL NUMBER 132482 157645 1844674407370955 10718055 10718055 8.750 3233.0 Polymer 8.90 44.0 8.9 11000 .0 3.000 76.0 1.870 126.0 2.800 76.0 e • MUD CAKE AT MT: 3.200 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • 76.0 DEPT FT 4 1 68 0 1 GALA MAD041 INCH 4 1 68 4 2 FCNT MAD041 CNTS 4 1 68 8 3 NCNT MAD041 CNTS 4 1 68 12 4 RHOB MAD041 G/CM 4 1 68 16 5 DRHO MAD041 G/CM 4 1 68 20 6 RPD MAD041 OHMM 4 1 68 24 7 RPM MAD041 OHMM 4 1 68 28 8 RPS MAD041 OHMM 4 1 68 32 9 RPX MAD041 OHMM 4 1 68 36 10 FET MAD041 HOUR 4 1 68 40 11 GR MAD041 API 4 1 68 44 12 PEF MAD041 BARN 4 1 68 48 13 RAT MAD041 FT/H 4 1 68 52. 14 NPHI MAD041 PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3282.5 6137 4709.75 5710 3282.5 6137 GALA MAD041 INCH 8.71 11.95 9.61786 3410 3296.5 6045.5 FCNT MAD041 CNTS 478.63 3241.31 911.69 3425 3305 6042.5 NCNT MAD041 CNTS 108186 204465 133744 3425 3305 6042.5 RHOB MAD041 G/CM 1.268 2.784 2.15938 3542 3282.5 6056 DRHO MAD041 G/CM -0.093 0.417 0.048939 3542 3282.5 6056 RPD MAD041 OHMM 0.67 1888.86 22.8293 3560 3312.5 6085 RPM MAD041 OHMM 0.62 491.15 13.2524 3560 3312.5 6085 RPS MAD041 OHMM 0.7 93.85 7.74202 3560 3312.5 6085 RPX MAD041 OHMM 0.7 58.02 5.37858 3560 3312.5 6085 FET MAD041 HOUR 150.46 2728.32 1548.82 3560 3312.5 6085 GR MAD041 API 13.27 157.76 75.0952 3564 3318.5 6092 PEF MAD041 BARN -0.65 7.07 1.72395 3542 3282.5 6056 RAT MAD041 FT/H 0.04 2835.93 258.661 3571 3359.5 6137 NPHI MAD041 PU-S 11.44 92.86 37.8035 3425 3305 6042.5 First Reading For Entire File..........3282.5 Last Reading For Entire File...........6137 File Trailer . • Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/02/02 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................07/02/02 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File
