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MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-112 PRUDHOE BAY UN BORE V-112 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 V-112 50-029-23300-00-00 206-020-0 W SPT 6555 2060200 1639 925 928 923 924 584 629 630 630 4YRTST P Bob Noble 9/6/2024 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN BORE V-112 Inspection Date: Tubing OA Packer Depth 261 2023 1927 1920IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240908194803 BBL Pumped:2.1 BBL Returned:1.9 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 9 9 999 9 9 9 9 9 9 7HVWZDVGXH:HOOZDV6, UHWXUQHGWRLQMHFWLRQLQ6HSWHPEHUMEU James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 16:38:54 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector V-112 (PTD #2060200) ready for injection Date:Monday, August 12, 2024 9:57:51 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, August 9, 2024 2:27 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: Injector V-112 (PTD #2060200) ready for injection Mr. Wallace, Injector V-112 (PTD # 2060200) is ready for injection. The well is now classified back to OPERABLE. An AOGCC MIT-IA will be scheduled when the well is online and thermally stable. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, June 15, 2024 9:00 AM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector V-112 (PTD #2060200) will lapse on AOGCC MIT-IA Mr. Wallace, Injector V-112 (PTD #2060200) is due for its 4-year AOGCC MIT-IA in June 2024. The well was shut-in on 06/05/24. There are no plans to put the well back online before the end of June 2024 and will therefore lapse on the 4-year MIT-IA. The well will now be classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector V-112 (PTD #2060200) will lapse on AOGCC MIT-IA Date:Monday, June 17, 2024 8:53:43 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, June 15, 2024 9:00 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector V-112 (PTD #2060200) will lapse on AOGCC MIT-IA Mr. Wallace, Injector V-112 (PTD #2060200) is due for its 4-year AOGCC MIT-IA in June 2024. The well was shut-in on 06/05/24. There are no plans to put the well back online before the end of June 2024 and will therefore lapse on the 4-year MIT-IA. The well will now be classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg � DATE: Monday, June 15, 2020 �[J I P.I. Supervisor Qee-,j jq I.zu I SUBJECT: Mechanical Integrity Tests 1/ BP Exploration (Alaska) Inc. V-112 FROM: Bob Noble PRUDHOE BAY UN BORE V-112 Petroleum Inspector Type Inj W See: Inspector 6555 Tubing Reviewed By: 2012 ' P.I. SuprvJBP— NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE V-112 API Well Number 50-029-23300-00-00 Inspector Name: Bob Noble Permit Number: 206-020-0 Inspection Date: 6/6/2020 " Insp Num: miTRCN200606171128 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-112 Type Inj W TVD 6555 Tubing 2010 2013• 2012 ' 2010 " PTD 1 2060200 Type Test SPT Test psi 1639 240 2880 2798 2788 ' BBL Pumped: 3s BBL Returned: z.z OA 540 616 620 618 ' Interval 4YRrsr P/F I P Notes: Monday, June 15, 2020 Page 1 of I �► s MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,June 09,2016 P.I.Supervisor Teifi 6C1 1 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. V-112 FROM: Jeff Jones PRUDHOE BAY UN BORE V-112 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE V-112 API Well Number 50-029-23300-00-00 Inspector Name: Jeff Jones Permit Number: 206-020-0 Inspection Date: 6/4/2016 Insp Num: mitJJ160608085921 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-112 - Type Inj G'1TVD 6555 - Tubing 2715 2718 , 2717 . 2715 PTD 2060200 - Type Test SPT Test psi 1639 IA 470 2255 . 2165 - 2155 _ Interval 4YRTST P/F P - OA 380 403 403 - 404 Notes: 1 well inspected,no exceptions noted. SCAM" DEC 2 92016 Thursday,June 09,2016 Page 1 of 1 • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q ~ - ~ ~ ~ Well History File Identifier Organizing (done) ^ Two-sided III IIIIIIII III II III ^ Rescan Needed III (I'lII II II III III R SCAN DIGITAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~ ~ " ~ ~ /s/ Project Proofing III II II II V III I I III BY: Maria Date: ~n _ ~ ~- D ~ lsl Scanning Preparation ~ x 30 = ~- + =TOTAL PAGES (Count does not include cover sheet) BY: Maria Date: ~ - ~ - ©~ /s/ T1" Production Scanning I) I II II II V III I I III Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: _~YES NO BY: Maria Date: ~ ,., j L.., O g /s/ ~M Stage 7 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 III IIIIIIIIIII VIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II'III III II'I III P 10/6/2005 Well History File Cover Page.doc • • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 26, 2012 TO: Jim Regg i L,1 Z I v SUBJECT: Mechanical Integrity Tests P.I. Supervisor BP EXPLORATION (ALASKA) INC V -112 FROM: Lou Grimaldi PRUDHOE BAY UN BORE V -112 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv / NON- CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE V - 112 API Well Number 50 029 - 23300 - 00 - 00 Inspector Name: Lou Grimaldi Permit Number: 206 - 020 - Inspection Date: 6/8/2012 Insp Num: mitLG120608122709 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V -112 ' Type Inj W ' TVD 6555 • IA 993 2530 ' 2470 2464 ' PTD 2060200 ' Type Test SPT Test psi 1638 , OA 438 461 470 468 Interval 4YRTST ' P/F P ' Tubing 1604 • 1605 1628 1615 ' Notes: 2.1 bbl's pumped, 2.1 bbl's returned. Good test. - 51ArtikED JUL 2 S 2012 Tuesday, June 26, 2012 Page 1 of 1 ? &ik 1/ --1 tz. • • P7t 2060zo Regg, James B DOA 99 (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Monday, June 11, 2012 10:36 AM To: Regg, James B (DOA) Subject: RE: UNDER EVALUATION: Injector V -112 (PTD #2060200) Well due for MITIA Compliance testing Attachments: MIT BPU V -112 05- 16- 2012.xls My apologies. The MIT form for the pretest conducted on 05/16/12 is attached. Whitney King filling in for Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 - 5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: Regg, James B (DOA) [mailto:jim.re•g©aalaska.gov] Sent: Monday, June 11, 2012 10:06 AM To: AK, D &C Well Integrity Coordinator Subject: RE: UNDER EVALUATION: Injector V -112 (PTD #2060200) Well due for MITIA Compliance testing Guess I should have been more clear; please send test results on AOGCC MIT forna...Tha.nk you. . Jim Regg AOGCC 333 W. 7th Ave, Suite 100 ' [ Anchorage, AK 99501 SOAKED �� U L. i ^ 2 907- 793 -1236 From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWelllntegrityCoordinator @bp.com] Sent: Friday, June 08, 2012 6:38 PM To: Regg, James B (DOA) Subject: RE: UNDER EVALUATION: Injector V -112 (PTD #2060200) Well due for MITIA Compliance testing My apologies for the delayed response. Injector V -112 (PTD #2060200) was pressure tested to approximately 4000 psi. The inner annulus was brought to 3995 psi. In the first 15 minutes the IA lost In the second 15 minutes the IA lost 3 psi for a total of 72 psi in 30 minutes. A total of 10.5 bbls of 60/40 meth was pumped into the annulus. Whitney King filling in for Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: Regg, James B (DOA) [mailto:jim.regg@ alaska.gov] Sent: Friday, June 08, 2012 11:43 AM To: AK, D &C Well Integrity Coordinator Subject: RE: UNDER EVALUATION: Injector V -112 (PTD #2060200) Well due for MITIA Compliance testing Please send results of MIT done 5/16/2012 1 • • Jim Regg, AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 -793 -1236 From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWeIIIntegrityCoordinatorC @bp.com] Sent: Thursday, June 07, 2012 7 :20 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, RES GPB West Wells Opt Engr; Greaves, Damien C Cc: Arend, Jon (NORTHERN SOLUTIONS LLC); Wills, Shane M; LeBaron, Michael J; King, Whitney; AK, D &C DHD Well Integrity Engineer; Yeager, Kevin E Subject: UNDER EVALUATION: Injector V -112 (PTD #2060200) Well due for MITIA Compliance testing All, Injector V -112 (PTD #2060200) is currently due for its 4 year compliance testing for an MIT - IA. The well is currently online and injecting. The well is reclassified as Under Evaluation until an AOGCC MIT -IA can be performed to confirm two competent barriers in the well. There are no known mechanical issues with the well. An MIT -IA passed to 4000 psi on 05/16/12. The plan forward for this well is: 1. Fullbore: Pre AOGCC MIT -IA to 4000 psi — Passed 2. Fullbore: AOGCC MIT -IA to 2300 psi Please call if you have any questions. Thank you, Whitney King filling in for Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 2 • 0 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq @alaska.00vj doa .aoacc.prudhoe.bayealaska.gov; phoebe.brooksCrD.alaska.gov; tom.maunder alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD 1 UNIT / PAD: Prudhoe Bay /PBU/V -PAD DATE: 05/16/12 ' OPERATOR REP: Mehreen Vaziir AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well V -112 Type Inj. W ' TVD ' 6,555' Tubing 1604 ' 1605 1628 1615' Interval O P.T.D. 2060200 Type test P Test psi '1638.75 Casing 993 " 2530' 2470 2464 • P/F P ' Notes: BP internal compliance testing OA 438 ' 461 470 468 ' Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA i TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Dnlling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industnal Wastewater R = Internal Radioactive Tracer Survey V = Required by Vanance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT BPU V - 112 05 - 16 - 2012 ZO4. 0 Z c Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com]t C�frcl �ti Sent: Sunday, June 10, 2012 11:01 AM To: AK, D &C Well Integrity Coordinator; Regg, James B (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, RES GPB West Wells Opt Engr; Greaves, Damien C 9 Cc: Arend, Jon (NORTHERN SOLUTIONS LLC); Wills, Shane M; LeBaron, Michael J; King, Whitney; AK, D &C DHD Well Integrity Engineer; Yeager, Kevin E Subject: OPERABLE: Injector V -112 (PTD #2060200) AOGCC MIT -IA Passed Attachments: MIT PBU V -112 6 -08 -12 .xis All, Injector V -112 (PTD #2060200) passed an AOGCC witnessed MIT -IA to 2500 psi on 06/08/12. The passing test confirms two competent barriers in the welibore. The well is reclassified as Operable. A copy of the MIT is included for review. Please call if you have any questions. Thank you, Whitney King filling in for Gerald Murphy (alt. Mehrcen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWeiIIntegrityCoordinatorCabp .com] Sent: Thursday, June 07, 2012 7:20 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Daniel, Ryan; A , D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK aPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, RES GPB Wes ells Opt Engr; Greaves, Damien C Cc: Arend, Jon (NORTHERN SOLUTIONS LLC); Wills, Shane M; LeBaron, Mich. - 3; King, Whitney; AK, D &C DHD Well Integrity Engineer; Yeager, Kevin E Subject: UNDER EVALUATION: Injector V -112 (PTD #2060200) Well d - - for MITIA Compliance testing All, Injector V - 112 (PTD #2060200) is currently due f. its 4 year compliance testing for an MIT - IA. The well is currently online and injecting. The well is recl. sified as Under Evaluation until an AOGCC MIT -IA can be performed to confirm two competent barr'-rs in the well. There are no known mechanical issues with the well. An MIT -IA passed to 4000 psi on ' /16/12. The plan forward for this well is: 1. Fullbore: Pre AOGCC -IA to 4000 psi — Passed 2. Fullbore: AOGCC MIT-IA to 2300 psi ~ ~ M ~ ~~~ _ ~~ t , -~ , x ' ~ ;~ °+~ L ,..~ ~~ M.r ~. „ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc i BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 - ,~~~+ ~~-.': h~'~ , ` `~~~ ~~~;;~ ~,,;~;,s~,~s,,~;~:6:;~J ~ bp ~~~~~~~~ OCT 0 5 2p09 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, ~Isal(8 01~ ~ GeS COnS. ~utnrn~a~ian ~Anchorape aa6 - Q~o v- ~ ~~- Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date V-pad 8/13/2009 Well Name PTD # API # Initiat top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al V-01 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-03 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA t.7 6/29/2009 v-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 V-102 2020330 50029230700000 NA 7.75 NA 98.2 8/7/2009 V-t03 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 7/11l2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-1o9 2022020 50029231200000 NA 1.2 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 NA 1.5 IVA 13.1 5l912009 V-117 2030900 50029231560000 NA 125 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-122 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 V-201 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.t 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 500292335t0000 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 6/30l2009 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 OPERABLE: V-112 (PTD #2060200) TxIA communication repaired Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ Sent:. Wednesday, July 16, 2008 12:47 PM ~~~ l~31'p To: Maunder, Thomas E (DOA); Regg, James B (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Oakley, Ray (PRA); Rossberg, R Steven Cc: Winslow, Jack L.; NSU, ADW Well Integrity Engineer Subject: OPERABLE: V-112 (PTD #2060200) TxIA communication repaired All, Monitoring of the wellhead pressures on weH V-112 since the slickline intervention to change out the DGLVs on / 05!25108, confirms the IA pressure remains stable when on MI injection. Therefore, the well has been reclassified as Operable. ,i ~5~ ~F ,ewl cae~-~~ 7~~-~ An AA cancellation has been submitted to the AOGCC. Further communication will follow once word is received from the AOGCC. Please contact the Well Integrity Engineer if any communication is observed ar if the IA requires any bleeds. Please call with any questions or concerns. Thank you, Andrea Hughes ~~~N~~ AU G ~ 2008 From: NSU, ADW Well Integrity Engineer Sent: Thursday, June 26, 2008 6:59 PM To: 'tom.maunder@alaska.gov'; 'jim.regg@alaska.gov'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Oakley, Ray (PRA) Ce: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Roschinger, Torin T. Subject: UNDER EVALUATION: V-112 (PTD #2060200) Evaluation of TxIA communication while on MI injection All, V-112 (PTD #2060200) has exhibited TxIA communication when on MI in the past and is currently under AIO 246.001, which restricts the well to produced water injection. In an attempt to restore the well's integrity to miscible gas injection, a slickline intervention installed new dummy gas lift valves with extended packing in the mandrels located above the packer (Sta #3 and #4) on 05/25/08. The well subsequently passed two 4000 psi MIT-IA's; the most recent test was witnessed by Chuck Scheve on 06/07/08. The plan forward for the well is as follows: 1. WOE: Swap well to MI injection 2. WIC: Reclassify well as Under Evaluation and monitor IA repressurization 3. WIC: Submit AA cancellation if no communication observed, or swap well back to water if communication still exists. The well has been reclassified as Under Evaluation and placed on a 28-day clock to begin when the well is placed on MI injection. Please put the well on MI injection when convenient. 7/31 /2008 OPERABLE: V-112 (PTD #2060200) TxIA communication repaired Page 2 of 2 Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 7/31/2008 UNDER EVALUATION: V-112 (PTD #2060200) Evaluation of TxI~mmunication w... Page 1 of 1 Regg, James B (DOAj From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ,~ Sent: Thursday, June 26, 2008 6:59 PM ~/ To: Maunder, Thomas E (DOA); Regg, James B (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Oakley, Ray (PRA) Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Roschinger, Torin T. Subject: UNDER EVALUATION: V-112 (PTD #2060200} Evaluation of TxIA communication while on MI injection All, V-112 (PTD #2060200) has exhibited TxIA communication when on MI in the past and is currently under AIO 248.001, which restricts the well to produced water injection. In an attempt to restore the well's integrity to miscible gas injection, a slickline intervention installed new dummy gas lift valves with extended packing in the mandrels located above the packer (Sta #3 and #4) on 05/25/08. The well subsequently passed two 4000 psi ./ MIT-IA's; the most recent test was witnessed by Chuck Scheve on 06/07/08. The plan forward for the well is as foAows: 1. WOE: Swap well to MI injection 2. WIC: Reclassify well as Under Evaluation and monitor IA repressurization 3. WIC: Submit AA cancellation if no communication observed, or swap well back to water if communication still exists. The well has been reclassified as Under Evaluation and placed on a 28-day clock to begin when the well is placed on MI injection. Please put the well on MI injection when convenient. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 8/28/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / V Pad 06/07/08 Anna Dube ~~ 2~1~~~d~' 02~ ' ~~ ~~ Packer Dep Pretest Initial 15 Min. 30 Min. Well V-112 Type Inj. W TVD 6,555' Tubing 1,740 1,750 1,760 1,760 Interval O P.T.D. 2060200 Type test P Test psi •1639 Casing 1140 X000 3900 3900 P/F P Notes: MIT-IA to eval for MI service. OA 660 850 850 850 Witness declined by C. Scheve. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) ~CANN JUL ~ ~ 2008 MIT Report Form BFL 11/27!07 2008-0607_MIT_PBU_V-112.x1s ~~~~ DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060200 Well Name/No. PRUDHOE BAY UN BORE V-112 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23300-00-00 MD 9538 TVD 5703 Completion Date 3/6/2006 REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR / GR, GYRO, PWD, RES, AIM, NEU /DEN, USIT Well Log Information: Log/ Electr Directional Surv Yes (data taken from Logs Portion of Master Well Data Maint Data Digital Dataset Log Log Run Typ Med/Frmt Number Name Scale Media No D/~ D Asc Directional Survey , l/Rpt Directional Survey I~g Cement Evaluation 5 Col 1 GE'D C Lis 15447 nduction/Resistivity ~og 15447 Induction/Resistivity ~g 15447 Induction/Resistivity Well Cores/Samples Information: Interval Name Start Stop ADDITIONAL INFORMATION Well Cored? 1'~ Chips Received? ~.M~ Analysis Y~ Received? Comments: Completion Status 1-OIL Currenf Status WAGIN 5 Blu 5 Blu Interval OH / Start Stop CH Received Comments 0 9538 Open 3/20/2006 j 0 9538 Open 3/20/2006 2890 7996 Case 3/26/2006 Ultrasonic Cement Image Log USIT/GR/PDC 4-Mar- 2003 100 9537 Open 9/28/2007 LIS Veri, GR, ROP, FET, RH01, NPHI, DRHO w.PDS and TIF graphics 100 9538 Open 9/28/2007 MD Visions Service final print 2-Mat-2006 100 9538 Open 9!28/2007 TVD Visions Service final print 2-Mat-2006 ~ Sample Set Sent Received Number Comments Daily History Received? ~N Formation Tops ~ N DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060200 Well Name/No. PRUDHOE BAY UN BORE V-112 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23300-00-00 MD 9538 TVD 5703 __ _ __ _ __ -- Compliance Reviewed By: Completion Date 3/6/2006 Completion Status 1-OIL Current Status WAGIN UIC Y Date: u MEMORANDUM To: Jim Regg ~ 4l z~~~ P.I. Supervisor e~~l 6 FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commiss~ DATE: Wednesday, April 02, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-] 12 PRUDHOE BAY UN BORE V-1 12 Sre: Inspector NON-CONFIDENTIAL Reviewed By: P.1. Suprv~J.~,~ Comm Well Name: PRUDHOE BAY UN BORE V-112 API Well Number: 50-029-23300-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS080318085330 Permit Number: 206-020-0 / Inspection Date: 3/16/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -- Well v-i 1 ~ - Type Inj. ~ W TVD 6555 IA 700 3000 29ao ~ z9zo p T -- 2060200 - -- TypeTest SPC TCSt pSl - 1638.75 QA ~ 340 420 420 420 --- i Interval OTHER p~F P ~ Tubing laoo -_ laoo I laoo laoo _ - - --- 'Notes' Pretest p ressures appeared stable. Test performed for AA request ~~ Wednesday, April 02, 2008 Page 1 of 1 OPERABLE - V-112 (PTD #206200) for TxIA Comm on MI, restrict w~to PWI only Page 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~ ~t~6 O~ Sent: Tuesday, March 18, 2008 4:18 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer; Roschinger, Torin T.; NSU, ADW WI Tech; Oakley, Ray (PRA) Subject: OPERABLE - V-112 (PTD #2060200) for TxIA Comm on MI, restrict well to PWI only Hi all, ~ o ~ I~~7~ Well V-112 {PTD #2060200) has passed an AOGCC Witnessed MITIA and is being reclassified as Operable. Due to TxIA communication on MI injection, an AOGCC Administrative Approval request Will be submitted for approval for continued injection with the Well restricted to PW injection. The Wei! may continue to be operated While the AA request is being -~ submitted and reviewed.for approval. Please let me know if you have any questions. Thank you, „~nna dude, ~'. E. Well Integrity Coordinator GPB ells Group Phone: (9i}?) 659-51€12 Pager: (9Q7) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, February 20, 2008 11:28 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod ControNers Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION - V-112 (PTD #2060200) for TxIA Comm Hi ail, Well V-112 (PTD #2060200) has confirmed TxIA communication. The IA pressure was bled from 1490 psi to 380 psi and increased 260 psi overnight. The well is now classified as Under Evaluation on a 28 day clock starting 02/19/08. The well should remain shut-in until diagnostics are complete. The plan forward includes: 1. Bleed and monitor IA pressure -DONE 2. AOGCC MITIA to 3000 psi °~ 3. Upon confirmation of a failed MITIA, secure well with a downhole plug and evaluate for repair options A 30-day TIO plot and wellbore schematic have been included for reference. « File: V-112.pdf» Please call with any questions. Thank you, ,~nna tube, ~.~'. E. Well Integrity Coordinator GPB Wells Group 3/19/2008 ~. c~ ~_-. • d O ~ o °a °a • 0 ~-, 0 0 a r 0 0 0 c~ v 0 C~ t 0 0 a v 0 0 o~ ~ N TREE = 1~BD WELLHEAD = FMG GEN 5 ACTUATOR = ,. KB. ELEV - 82.30' BF. ELEV = 65.90' KOP = 4oa . _ .~....._..~_m:,w.n..~.~ Niax AncJle = _. _ _ . _ _. ... . . 100 i<v 8858' ~, Datum MD _._._ _.._,~ 7818' Datum TV D = 6600` SS (20" CONDUCTOR 9-5l8" CSG, 40#, L-80 BTC, ID = 8.835" I 191' i rar NOTES: 7U° @ 7355' -~4-112" HES X NIP; ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3 3196 4843 3020 4515 24 `L5 KBG-2 KBG-2 DMY DMY BK BK 0 0 06116/06 06116106 7"' CSG, 26#, L-80 TCII, ID = 6.276" I-'i 4153' Minimum 1®= 2,813" 7520' BAKER cMO SL1afNG sLEEVE (4-1/2" TBG. 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" I"~ 7419' 3-112" TBG, 9.2#, L-80 TCII, .0087 bpf, ID = 2.992" $056' 7" CSG, 26#, L-80 BTC-M, ID = 6.276" 8193' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 74 @ 7550' Note: Refer to Production DB for historical perf data SCZE SPF INTERVAL OpnlSgz DATE 2-7rg" 5 7550 - 7620 O 03!04/06 2-7!8" 5 7632 - 7660 O 03/04/06 2-7; 8" 5 7680 - 7706 O 03104/06 2-7(8" 5 7745 - 7770 O 03104!06 4-112" 6 9140 - 9190 O 03/04106 4-112" 6 9250 - 9290 O 03104/06 4-112" 6 9320 - 9375 O 03i04r06 4-1l2" 6 9410 - 9438 O 03/04106 PBTD 9450° LNR, 12,6#, L-80 IBT-M, .0152 bpf, ID = 3.958" 953$® WATER INJECT ION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 7430 7491 6570 6587 73 74 M M G-W M M {i-W DMY DMY RK RK 0 0 03105/06 5219' -°'HES ES CEMENTER. STAGE TOOL 730$` 7" MARKERJOINTwlRA TAG 7359' 4-112" HES X NIP, lD = 3.813" I 73$01' 7" X 4-1/2" BKR PRM PROD PKR, ID = 3.875" 740$' 4-1,`2" HES X NIP, ID = 3.813' 7419' 4-112" X 3-112" XO, ID = 2.992" 7520' BKR CMD SLIDING SLV, ID = 2.813" $011' 3-1 i2" HES X NIP, ID = 2.813" $042' T' X 5" BKR ZXP LNR TOP PKR, FLEX-LOK LNR HNGR & 1lEBACK SLV; ID = 4,400 $056' LOCATOR &BKR SPACER TUBE, ID = 3.00" 8069' 4-112" BKR SEAL BORE EXT, ID = 4.00" $077" BKR BONDED SEAL ASSY, ID - 3.00" $426' RA TAG DATE REV BY COMMENTS tJ3f07/06 N9ES ORIGINAL COMPLETION 03?181(?6 GLMlTLH DRt.G DRAFT CORRECT{O 04/20106 DRVlPJC GLV C/O 06i16r06 RCTiPJC GLV CIO DATE ~ REV BY ~ COMMENTS BOREALIS UNfI~ WELL: V-112 PERMfT No: 2060200 AP! No: 50-029-23300-00 SEC 11, T11 N, R11 E, 4627' FSL, 1876' FEL BP Exploration {Alaska) osno/o7 C~ SCh~illq~61'IJBI' Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job p Log Description N0.4409 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Pield: Polaris Odon Borealis Date BL Color CD V-203L7 40012957 OH EDIT MWD/LWD 01/24/06 2 1 V-112 Z-108 Z-100 40013154 40012738 N!A OH EDIT MWDILWD V ~ °' OH EDIT MWD/LWD - SBHP SURVEY ~ 03102/06 02/04107 09N5/07 2 2 1 1 1 S-213A 11855809 SBHP SURVEY 08!31/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: I BP Exploration (Alaska) Inc. _ - ~ r ~ - ; Pefrotechnical Data Center LR2-1 - ' t 900 E Benson Bivd. - - Anchorage AK 99508-4254 g` ) (~ l Date Delivered: ~, ~° S"~ ~ ~ / ~.~ y t i (;tai1lttlli^.1~'~'I ~,. , Schlumberger•DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by:( ~~/ll ~~ ~: " lJ MEMORANDUM To: Jim Regg ~ ~ ~~,: P.I. Supervisor `~'~'+~~ ~~~ •~~ i_ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 19, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-112 PRUDHOE BAY UN BORE V-112 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv -~ Comm Well Name: PRUDHOE BAY UN BORE V-112 Insp Num: mitCS060714063532 Rel Insp Num API Well Number 50-029-23300-00-00 Permit Number: 206-020-o Inspector Name: Chuck Scheve Inspection Date: 7/13/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well v-112 'Type Inj. ~/ ! TVD I 7380 IA ~, 350 2190 2180 2180 i P.T. i 2060200 ITypeTCSt , SPT I Test pSl !,~ 1845 ! OA 570 760 ~ 760 ~ 760 Interval ~T~ P/F P Tubing ~ 2500 ~ 2550 i 2550 ~ 2550 I j Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. Wednesday, July 19, 2006 Page 1 of 1 ~P~ 7I/plow •~. STATE OF ALASKA JUL 0 6 2006 ALAS~IL AND GAS CONSERVATION CO SION WELL COMPLETION OR RECOMPLETION REPORT AND L~ska Oil & Gas Cons. Commission G7/0 r"injection.. 1 a. Well Status: ^ Oil Q Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG zoAAC ze.,oa zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: ^ Development ^ Exploratory ^ Stratigraphie ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 3/6/2006 12. Permit to Drill Number 206-020 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 2/17/2006 13. API Number 50-029-23300-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 3/2/2006 14. Well Name and Number: PBU V-112 4627 FSL, 1876 FEL, SEC. 11, T11 N, R11 E, UM Top of Productive Horizon: 5039' FSL, 4657' FEL, SEC. 11, T11 N, R11 E, UM g. KB Elevation (ft): 81.5' 15. Field /Pool(s): Prudhoe Bay Field /Borealis Pool Total Depth: 3655' FSL, 749' FEL, SEC. 10, T11 N, R11 E, UM 9. Plug Back Depth (MD+TVD) 9450 + 6714 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 590428 y- 5969873 Zone- ASP4 10. Total Depth (MD+TVD) 9538 + 6703 Ft 16. Property Designation: ADL 028241 TPI: x- 587641 y- 5970252 Zone- ASP4 Total Depth: x- 586288 Y- 5968851 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: if ff h 1 W d th Thi k f P f 20 t 18. Directional Survey ®Yes ^ No ater ep , o s ore 9. N/A MSL ness o erma ros . c 1900' (Approx.) 21. Logs Run: MWD , DIR/GR ,GYRO , PWD , RES ,AIM , NEU/DEN , USIT ASING, INER AND EMENTING ECORD CASING ETTING EPTH MD ETTING EPTH TVD HOLE MOUNT SIZE WT. PER FT. GRADE OP TTOM OP OTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 215.5# A53 Surface 108' Surface 108' 42" 260 sx Arctic Set Approx.) 9-5/8" 40# L-80 29' 3003' 29' 2845' 12-1/4" 518 sx AS Lite, 150 sx'G', 73 sx'G' 7" 26# L-80 26' 8193' 26' 6787' 8-3/4" 155 sx AS Lite, 279 sx Class 'G' 4-1/2" 12.6# L-80 8042' 9538' 6745' 6703' 6-1/8" 183 sx Class 'G' 23. Perforations open to Production (MD +TVD of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 5 SPF 4-1/2" Gun Diameter, 6 SPF 4-1/2", 12.6#, L-80 x 8089' 7380' MD TVD MD TVD 3-1/2", 9.2#, L-80 7550' - 7620' 6603' - 6624' 9140' - 9190' 6752' - 6746' 7632' - 7660' 6627' - 6636' 9250' - 9290' 6739' - 6734' 25 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7680' - 7706' 6642' - 6649' 9320' - 9375' 6730' - 6723' 7745' 7770' 6661' 6668' 9410' 9438' 6719' 6515' DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED - - - - 2200' Freeze Protected with 70 Bbls Diesel 26• PRODUCTION TEST Date First Production: July 1, 2006 Method of Operation (Flowing, Gas Lilt, etc.): Water Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS'MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO FIOW 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). Submit core chips; if none, state "none". None BFFIo ,)~j. ~ ~ 206 Form 10-407 Revised 12/2003 ~ ~ ~ ` ~~` f t INUED ON REVERSE SIDE G 28 GEOLOGIC MARKE 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". Top of Ugnu 3078' 2913' None Ugnu M Sands 4355' 4074' Schrader Bluff'N' Sands 4634' 4326' Schrader Bluff'O' Sands 4808' 4484' Top of Colville 5206' 4844' Top of HRZ 6820' 6266' Top of Kalubik 7124' 6455' Kuparuk 'D' 7331' 6539' Kuparuk 'C' 7376' 6561' Kuparuk 'D' 7507' 6591' Kuparuk 'C' 7548' 6603' Kuparuk 'B' 7979' 6727' Kupanak 'C' 9438' 6715' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and a Leak Off Test Summary. 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Title Technical Assistant Date ~~~~~~~~ PBU V-112 206-020 Prepared ey Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. Drilling Engineer: Shane Gagliardi, 564-5251 INSTRUCTIONS GeNeItA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Irene 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interva!). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only APR ~ 4 200E STATE OF ALASKA ALASK~L AND GAS CONSERVATION COI Ojl ~:G~~ Gors..~amtni~+~n WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~a~:=~~;;;r_" '' Pre Produced WAG Injector 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAACZS.,os zoAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 3/6/2006 12. Permit to Drill Number 206-020 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 2/17/2006 13. API Number 50-029-23300-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 3/2/2006 14. Well Name and Number: PBU V-112 4627 FSL, 1876 FEL, SEC. 11, T11 N, R11 E, UM Top of Productive Horizon: 5039' FSL, 4657' FEL, SEC. 11, T11 N, R11 E, UM g• KB Elevation (ft): 81.5' 15. Field /Pool(s): Prudhoe Bay Field /Borealis Pool Total Depth: 3655' FSL, 749' FEL, SEC. 10, T11 N, R11 E, UM 9. Plug Back Depth (MD+TVD) 9450 + 6714 Ft 4b. Location of Well (State Base Plane Coordinates}: Surface: x- 590428 y- 5969873 Zone- ASP4 10. Total Depth (MD+TVD) 9538 + 6703 Ft 16. Property Designation: ADL 028241 TPI: x- 587641 y- 5970252 Zone- ASP4 Total Depth: x- 586288 Y- 5968851 Zone- ASP4 11. Depth where SSSV set N/A MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD , DIR/GR ,GYRO , PWD , RES ,AIM , NEU/DEN , USIT 2 ASING, INER AND EMENTING ECORD CASING E771NG H MD ETTING EPTH ND HOLE MOUNT SIZE WT. PER FT. GRADE OP OTTOM OR OTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 215.5# A53 Surface 108' Surface 108' 42" 260 sx Arctic Set Approx. 9-5/8" 40# L-80 29' 3003' 29' 2845' 12-1 /4" 518 sx AS Lite, 150 sx 'G', 73 sx 'G' 7" 26# L-80 26' 8193' 26' 6787' 8-3/4" 155 sx AS Lite, 279 sx 'G' 4-1/2" 12.6# L-80 8042' 9538' 6745' 6703' 6-1/8" 183 sx Class 'G' 23. Perforations open,to Production (MD +TVD of Top and " " 24 TUBING RECORD Bottom Interval, Slze and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 5 SPF 4-1/2" Gun Diameter, 6 SPF a-vz•xa-vz•,,zsu«s.zu, L-80TCII 8089' 7380' MD TVD MD TVD 7550' - 7620' 6603' - 6624' 9140' - 9190' 6752' - 6746' 7632' - 7660' 6627' - 6636' 9250' - 9290' 6739' - 6734' 25 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7680' - 7706' 6642' - 6649' 9320' - 9375' 6730' - 6723' 7745' - 7770' 6661' - 6668' 9410' - 9438' 6719' 6515' DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED - 2200' Freeze Protected with 70 Bbls Diesel 26• PRODUCTION TEST Date First Production: Not on Production/Injection Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing 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). Submit core chips; if none, state "none". 0 ri ~~ .. None 3 ' ~~ APR ~~ 5 1QQ6 ~z <:{ iVflf13-letit~ Form 10-407 Revised 12/2003 ~"-, t° ~ O INUED ON REVERSE SIDE 28. GEOLOGIC MARKS 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". Top of Ugnu 3078' 2913' None Ugnu M Sands 4355' 4074' Schrader Bluff'N' Sands 4634' 4326' Schrader Bluff'O' Sands 4808' 4484' Top of Colville 5206' 4844' Top of HRZ 6820' 6266' Top of Kalubik 7124' 6455' Kuparuk 'D' 7331' 6539' Kuparuk 'C' 7376' 6561' Kuparuk 'D' 7507' 6591' Kuparuk 'C' 7548' 6603' Kuparuk 'B' 7979' 6727' Kuparuk 'C' 9438' 6715' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and a Leak Off Test Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra Ste man •` - ~ Title Technical Assistant Date ~ , '~J ~ ~.~ PBU V-112 206-020 Prepared By Name/Number.• Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. ori~iinq engineer: Shane Gagliardi, 564-5251 INSTRUCTIONS GeNeRn~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Irene 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 3/13/2006 10:59:44 AM BP EXPLORATION Page 1 of 12 Operations Summary Report Legal Well Name: V-112 Common Well Name: V-112 Spud Date: 2/17/2006 Event Name: DRILL+COMPLETE Start: 2/17/2006 End: 3/6/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/6/2006 Rig Name: NABOBS 9ES Rig Number: Date II From - To i ~Hours Task ~ Code ! NPT ~ , Phase Description of Operations , 2/17/2006 00:00 - 01:00 1.00 MOB P ~ I PRE PJSM,Lay over derrick. Move pit complex off well V-203. 01:00 - 04:00 3.00 MOB P ~ PRE Move rig off well V-203. Move around end of well row. Move in 04:00 - 06:30 I 2.501 MOB I P I I PRE 06:30 - 08:30 ~ 2.00 MOB P PRE 08:30 - 12:00 ~ 3.50 DIVRTR P SURF 12:00 - 14:00 ~ 2.00 RIGU P SURF 14:00 - 18:00 4.00 RIGU P SURF 18:00 - 18:30 I 0.50 RIGU P SURF 18:30 - 20:30 i 2.00 RIGU P SURF 20:30 - 21:00 ; 0.50 DIVRTR P SURF 21:00 - 21:30 I 0.501 RIGU I P I I SURF 21:30 - 22:00 0.50 RIGU P SURF 22:00 - 22:30 0.50 DRILL P SURF 22:30 - 00:00 i 1.501 DRILL I P I I SURF 8/2006 100:00 - 01:00 1.00 DRILL I P SURF 01:00 - 01:30 I 0.501 DRILL I P I I SURF 01:30 - 02:30 I 1.001 DRILL I P I I SURF 02:30 - 08:30 I 6.001 DRILL I P I I SURF 08:30 - 09:30 1.00 DRILL P SURF 09:30 - 16:30 7.00 DRILL P SURF 16:30 - 17:00 0.50 DRILL N WAIT SURF 17:00 - 21:30 I 4.501 DRILL I P I I SURF 21:30 - 23:00 I 1.501 DRILL I P I I SURF and spot rig over well V-112. Move in and spot pit complex on well V-112. Prepare to raise derrick. Raise derrick, raise and pin cattle chute. Hook up all service lines. Take on FW in pits. Accept rig for operations on Well V-112i at 06:00 hrs. Bridle down and pin blocks, Hang and secure bridle lines. Install and nipple up 20" adapter and riser on divertor. Install 4" valves and nipples on conductor. PJSM, Prep rig floor for picking up drill pipe from pipe shed. Pick up and stand back 66 jts of 4" 15.7ppf of drill pipe from the pipe shed. Pick up and stand back 26 jts HWDP and 3 DC's. Pick up to rig floor directional tools and 12-1/4" bit. PJSM, M/U BHA # 1. Funtion test diverfer system and koomey., OK. John Spaulding, PI AOGCC, waived witnessing test. Pre-spud meeting held with all personal. Review well plan and BP D&W shallow gas operations policy. PJSM, R/U Gyro-data and HES slick line unit. Fill pipe and hole with FW. Inspect entire circulating system, no leaks. Spud-in well. Drill 12-1 /4" Surface hole from 108' to 193'. Pump operations 185 spm, 550 gpm, 650 psi. UWT= 56k, DNWT= 53k, ROTWT= 55k. ART= .62 hrs. PTSM, Drill and surrey 12-1/4" surface hole from 193' to 347'. Pump operations 185 spm, 550 gpm, 800 psi. CBU 775 psi ~ 550 gpm. POH from 347' to 255'. Break off TD. RIH with Gyro-data on HES slick line. POH with surrey tool. POH with BHA from 255' to 108'. Complete M/U on BHA. RIH to 347'. Drill and survey 12-1/4" surface hole from 347' to 1,002'MD. UWT = 75k, DWT = 70k, RWT = 73k. 80 RPM, Tq 3,300 psi/ftlb on btm. 600 gpm C~ 1,350 psi. Back ream 30' after each stand is drilled down. Survey each stand. RIH with Gyro-data on HES slickline for directional surveys. POH and rig down slickline unit. Drill and survey 12-1/4" surface hole from 1,002' to 2,004'MD. UWT = 95k, DWT = 83k, RWT = 87k. 80 RPM, Tq 6,000 psi/ftlb on btm. 700 gpm Q 2,740 psi. Back ream 30' after each stand is drilled down. Survey each stand. Circulate and reciprocate drill string. Outside cuttings box full. Waiting on Guzzlers to truck cuttings to DS 4 G&I. Five Guzzler units unable to keep up with drilling rate. Order out 2 more Guzzler units. Drill and survey 12-1/4" surface hole from 2,004' to 3,011'MD ( 2,852' TVD). Observed slight show of shallow gas hydrates at 2,250'MD, (2,165'TVD). UWT = 108k, DWT = 90k, RWT = 100k. 80 RPM, Tq 6,000 psi/ftlb on btm. 700 gpm ~ 2,950 psi. Back ream 30' after each stand is drilled down. Survey each stand. TD surface hole as per BP Geologists, Bob Dawson. Circulate until clean returns are observed at surface. Pump Printed: 3/13/2006 10:59:49 AM BP EXPLORATION Page 2 of 12 Operations Summary Report Legal Well Name: V-112 Common Well Name: V-112 Spud Date: 2/17/2006 Event Name: DRILL+COMPLETE Start: 2/17/2006 End: 3/6/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/6/2006 Rig Name: NABOBS 9ES Rig Number: Date From - To - -- 2/18/2006 j 21:30 - 23:00 23:00 - 00:00 Hours I Task ~ Code ' NPT i Phase Description of Operations 2/19/2006 100:00 - 02:00 02:00 - 05:00 05:00 - 06:00 06:00 - 09:00 09:00 - 10:30 10:30 - 11:00 11:00 - 12:00 12:00 - 16:30 16:30 - 20:30 20:30 - 21:00 21:00 - 23:30 23:30 - 23:45 23:45 - 00:00 2/20/2006 00:00 - 02:30 02:30 - 04:30 04:30 - 07:30 07:30 - 08:30 1.50 - DRILL _ P - _ SURF , - - operations 240 spm, 700 gpm, 3,010 psi. 1.00 DRILL P ~ SURF Monitor well, stable. Break top drive and blow down same. POH with drill pipe on elevators from 3,011' to 2,588'MD. Hole i conditions are good. 2.00 DRILL P SURF PTSM, POH with drill pipe on elevators from 2,588' to 267', at the drill collars. Observed slight overpull at 1,850' and 1,770'. Work thru once, clean up. 3.00 DRILL P SURF RIH from 267' to 3,011'. Tight spot. M/U top drive. Wash thru 300 spm, 30 rpm. RIH to 1,630', tight spot. M/U top drive. Wash thru to 1,675' at 300 spm, 30 rpm. RIH to 2,270. Tight spot. M/U top drive. Wash thru to 2,310' at 300 spm, 30 rpm. RIH to btm at 3,011'. Tag btm. Mud Wt. 9.5ppg. 1.00 DRILL P SURF Circulate and reciprocate drill string. Pump operations at 225 spm, 2,730 psi. 3.00 DRILL P SURF POH with drill pipe on elevators from 3,011' to 113'. Hole in good condition. Mud Wt. 9.5ppg. 1.50 DRILL P SURF Lay Down BHA # 1. 0.50 DRILL P SURF Clear floor, Remove all directional tools from rig floor. 1.00 CASE P SURF Rig up casing handling tools to run 9-5/8" casing. Make dummy run with 9-5/8" FMC Mandrel Casing Hanger thru riser. OK. 4.50 CASE P SURF PTSM, M/U float equipment and shoe jt. RIH with 9-5/8" 40ppf L-80 BTC casing. 4.00 CASE P SURF RIH with 9-5/8" casing. Tight hole starting at 1,800'. M/U top drive. Circulate and wash down casing from 1,800' to 2,546'. Pump operations 100 spm, 247 gpm, 350 psi. Continue to RIH with 9-5/8" casing. M/U FMC Mandrel Casing Hanger and landing joint. Land casing. 0.50 CASE P SURF Lay down top drive 9-5l8" casing circulating running tool. Blow down top drive. M/U Schlumberger cementing head pre-loaded with plugs. Hook up circulating hose and valve. 2.50 CASE P SURF Break circulation. Stage mud pumps up to 8 bpm 550 psi. Reciprocate casing, up wt = 170k, do wt = 125k. 0.25 CEMT P SURF PJSM with rig crew and all service personal. Review cementing procedure. Continue to circulate and reciprocate 9-5/8" casing. 0.25 CEMT P SURF Start mixing lead slurry cement. Continue to circulate and reciprocate 9-5/8" casing. 2.50 CEMT SURF PTSM, Pump 5 bbls FW, PT surface lines to 3,500 psi, OK. Pump 80 bbls MP II, kick out btm plug. Mix and pump 410 bbls ASL lead slurry at 10.7ppg, followed by 31 bbls class G tail slurry at 15.8ppg, followed by 15 bbls durastone slurry at 16.5ppg. Rate while pumping cement 4-6 bpm at 250-450 psi. Kick out top plug with 10 bbls FW, switch over to rig pumps. Displace cement at 5-7 bpm 450-1000 psi. Bump plug with 1,500 psi. Reciprocated casing thru out cement job. Up wt 170k, Dn tort 125k.Bled off casing pressure floats held. CIP at 02:30 hrs. Observed 10 bbls lead slurry back to surface. 2.00 DIVRTR SURF R/D plug dropping head. Flush diverter stack with FW. Back out and lay down landing joint. Lay down casing handling tools. Change bails. 3.00 DIVRTR SURF Nipple down diverter system. Remove from cellar area. Change out bell nipple. Move FMC wellhead equipment into cellar area. 1.00 WHSUR SURF N/U FMC well head equipment. PT sealing area to 1,000 psi. OK. Printed: 3/13/2006 10:59:49 AM BP EXPLORATION Operations Summary Report Legal Well Name: V-112 Common Well Name: V-112 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date .From - To ~ ' ~ Hours I Task Code i NPT I 2/20!2006 08:30 - 11:00 2.50 BOPSU 11:00 - 12:00 1.00, BOPSU 12:00 - 15:00 I 3.00 15:00 - 15:30 I 0.50 15:30 - 17:00 1.50 ~ DRILL INTf 17:00 - 18:00 1.00 DRILL INTf 18:00 - 20:00 2.00 DRILL INT1 20:00 - 21:30 1.50 DRILL INTf 21:30 - 23:30 2.00 DRILL I INTf 23:30 - 00:00 0.50 DRILL INTf 2/21/2006 00:00 - 01:30 1.50 DRILL P INTf 01:30 - 02:30 1.00 DRILL P INT1 02:30 - 03:00 0.50 DRILL P INT1 03:00 - 03:30 0.50 CASE P INT1 03:30 - 04:00 0.50 CASE P INTf 04:00 - 06:00 2.00 DRILL P INT1 06:00 - 07:00 1.001 DRILL P ~ INTf 07:00 - 07:30 I 0.501 DRILL I P I I INT1 07:30 - 08:00 I 0.501 DRILL I P I I INTf 08:00 - 11:00 3.00 DRILL P INT1 11:00 - 12:00 1.00 DRILL N WAIT INTf 12:00 - 13:00 1.00 DRILL N I WAIT INTf 13:00 - 13:30 I 0.501 DRILL I N I WAIT I INTf 13:30 - 14:00 0.50 DRILL N WAIT INTf 14:00 - 00:00 10.00 DRILL N WAIT INT1 Start: 2/17/2006 Rig Release: 3/6/2006 Rig Number: Page 3 of 12 Spud Date: 2/17/2006 End: 3/6/2006 Description of Operations Phase Nipple up BOPE. Prepare for BOP test. M/U BOP test jt., set test plug in wellhead, and M/U test manifold. R/U chart recorder. PTSM, Test BOPE as per AOGCC Regs. 250 psi low, 4,000 psi high. Chart test. Chuck Scheve, PI AOGCC, waived witnessing the test. Test witnessed by Brian Buzby, BP Company Rep., and Kelly Cozby, Nabors Alaska Drilling Toolpusher. Pull test plug, set wear ring. Lay down test jt. and plug. R/D test manifold and chart recorder. Blow down all lines. PJSM, P/U 4" 15.7ppf drill pipe. RIH to 1,975'. POH, stand back drill pipe in derrick. PJSM, P/U 4" 14ppf drill pipe. RIH to 2,545'. POH, stand back drill pipe in derrick. PJSM, M/U BHA # 2 as per Directional Driller. RIH with BHA # 2 on 4" drill pipe. P/U 4"14ppf drill pipe and RIH with BHA # 2 to 2,692'MD. Pulse test MWD tool at 1,085'. Pump rate 580 gpm 1,650 psi. 108k up wt. 75k do wt. Cut and slip 58' drilling line, Inspect drawworks and linkage. Service Top Drive Unit. Circulate and condition mud for casing test. Pump rate 393 gpm at 1,267 psi. Presure test 9-5/8" casing to 3,500 psi. OK, RIH from 2,692' to 2,855M/U Topdrive and wash from 2,855' tag hard cement ~ 2,900'. Drill cmt and float equipment. Clean out to 3,011' and drill 20' of new hole to 3,031', Up wt = 110k, do wt = 80k, st wt = 95k, 480 gpm @ 1847 psi, 60 rpm, torque 4.3k. Displace well to 8:8 ppg LSND mud, 410 gpm, @ 1200 psi, 60 rpm, torque = 4k Circulate until 8.8 mud around, Pulled bit inside 9 5/8" casing. Perform LOT. Mud weight 8.8 ppg, TVD @ shoe 2,844', 3,031' md, pressure attained 910 psi, EMW = 14.96 ppg. SURF SURF SURF SURF Phase 2 was announced C~ 07:00 hrs. Establish SPM with both pumps ~ 2 & 3 bpm. Obtain benchmark ECD, 580 gpm 80 rpm, ECD = 9.30 Drill 8.75" hole from 3,031' to 3,821'. 10-20 k WOB, 580 gpm, 1,505 psi on bottom, 1,263 psi off bottom. 80 rpm, torque on bottom = 4.2k, torque off bottom = 3.8k, up wt = 115k do wt = 85k, rt wt = 100k, AST = .11 hrs, ART = 2.79 hrs. Phase 3 was announced ~ 11:00 hrs. Circulate bottoms up Q 580 gpm 1,300 psi 80 rpm, torque 3.5k, rotating and reciprocating pipe. Monitor well, POH from 3,821' at 3,219' 20k overpull and swabbing, made up topdrive and backream out from 3,219' to 3,005' 500 gpm, 1,200 psi, 60 rpm, torque = 4k. MW = 8.8 ppg. Circulate bottoms up 2x at 3,005' 500 gpm 1,300 psi, ECD while CBU = 9.98. POH to 2,970' Blow down topdrive and all lines. Wait on weather, Phase 3 weather conditions, Monitor well. Printed: 3/13/2006 10:59:49 AM BP EXPLORATION Page 4 of 12 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date , 1 - Name: ell Name: e: Name: I From - To -- V-112 V-112 DRILL+C NABOB NABOB Hours OMPLE S ALASK S 9ES ' Task TE A DRI I, Code LING NPT Start I Rig Rig Phase Spud Date: 2/17/2006 : 2/17/2006 End: 3/6/2006 Release: 3/6/2006 Number: Description of Operations T ~ 2/21/2006 ~ - - i4:00 - 00:00 0.00 RILL N _-- WAIT - INT1 - -- ---- Made crew change @ 11:30 with 1MT approval, Rig crew and all support personne- were escorted to Wrangle camp with an 1 ! heavy equipment escort. 2/22/2006 00:00 - 12:00 12.00 DRILL N WAIT INT1 PTSM, Continue waiting on weather, Phase 3 weather conditions. Temp -9 deg, wind SW 20-35 mph, blowing snow. Circulate across top of hole. Monitor well. 12:00 - 13:00 1.00 DRILL N WAIT INTi PTSM, Continue waiting on weather, Phase 3 weather i conditions. Temp -13 deg, wind SW 25-30 mph, blowing snow. Circulate across top of hole. Monitor well. ,13:00 - 14:00 1.00 DRILL N WAIT INT1 RIH from 2,880' to 3,256', tag fill in hole. Wash and ream from 3,256' to btm at 3,821'. 14:00 - 15:00 1.00 DRILL N WAIT INTi Circulatr buns up until clean returns were observed coming across shakers. Pump rate 585 gpm 1,456 psi. 15:00 - 00:00 9.00 DRILL P INTi Drill and survey 8-3/4" open hole from 3,821'MD to 5,518'MD Pump rate: 240 spm, 588 gpm, 2,495 psi on btm, 2,010 psi off ~ btm. 80 rpm, 6-7k tq on btm, 4-6k tq off btm, Upwt ~ 148k, Dnwt 111 k, Rtwt 129k. Back ream 60' on every connection Calculated ECD = 9.56ppg, Actual ECD = 10.24ppg. AST = .20 hrs., ART = 6.22 hrs., ADT = 6.42 hrs. Pump # 1, SPR 2 bpm 200 psi, 3 bpm, 270 psi @ 5,237'MD. Pump # 2, SPR 2 bpm 210 psi, 3 bpm, 270 psi @ 4,873' TVD. Current Mud Weight 9.0 ppg. 2/23/2006 00:00 - 00:00 24.00 DRILL P INT1 Directionally drill 8-3/4" intermediate hole from 5,518' MD to 6,669' MD (6,153' TVD) Backream 60' each stand prior to connection, survey every stand. GPM - 564, PSI ON - 3,350, PSI OFF - 2,850, RPM - 80, TO ON - 6-7k, TO OFF - 4.7k, PU - 150k, SO - 125k, ROT - 135k, WOB - 10-20k. AST - 14.18 hrs, ART - 3.53 hrs. CECD - 10.95 ppg, AECD - 11.09 ppg. 'Raised mud weight to 10.3 ppg @ 6,200' 2/24/2006 00:00 - 00:00 24.00 DRILL P INTi Directionally drill 8-3/4" intermediate hole from 6,669' MD to 7,955' MD. Backream 60' each stand prior to connection, survey every stand. GPM - 534, PSI ON - 3,580, PSI OFF - 3,150, RPM - 80, TO ON - 7.8k, TO OFF - 5.8k, PU - 166k, SO - 130k, ROT - 150k, WOB - 20k. CECD - 10.89 ppg, AECD - 11.05 ppg. AST - 13.25 hrs, ART - 5.76 hrs. KupB faulted with 54' throw @ 7,400'. Drill ahead looking for for fault crossing #2. Started losing mud @ 7,940', 35 bph with no fault indication. Treat mud for loses with Mix II. Lossed 28 bbls total. 2/25/2006 00:00 - 02:00 2.00 DRILL P INT1 Drill 8-3/4" intermediate hole looking for fault crossing #2 by rotating out from 7,955' to 8,200' MD, 6,789' TVD. Did not find fault. Loss rate slowed to 15 bph. Backream each stand prior to connection, survey every stand. GPM - 535, PSI ON - 3,495, PSI OFF - 3,140, RPM - 80, TQ ON - 7. f k, TO OFF - 5.2k, PU - 174k, SO - 127k, ROT - 147k, WOB - 15-20k. CECD - 10.89 ppg, AECD - 11.10 ppg. AST - 0 hrs, ART - 1.45 02:00 - 03:00 1.00 DRILL P INTi Circulate sweep surface to surface. 564 gpm, 3,520 psi. Printed: 3/13/2006 10:59:49 AM BP EXPLORATION Page 5 of 12 Operations Summary Report Legal Well Name: V-112 Common W ell Name: V-112 Spud Date: 2/17/2006 Event Nam e: DRILL+C OMPLE TE Start : 2/17/2006 End: 3/6/2006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 3/6/2006 Rig Name: NABOB S 9ES Rig Number: Date From.- To I Hours ; Task Code i ~ NPT Phase Description of Operations I 2/25/2006 02:00 - 03:00 1.00 DRILL P INT1 CECD - 10.89 ppg, AECD - 11.06 ppg, MW - 10.3 ppg. 03:00 - 04:00 i 1.00 DRILL P i INTi Monitor well -small static loss. POH to plug back well from 8,200' to 7,760'. PU - 185k, SO - 134k. Pulled 10-25k over string weight all the way. 04:00 - 06:00 2.00 DRILL P INTi Back ream from 7,760' to 6,827' (above HRZ) @ 520 gpm, 3,040' psi, 80 rpm, 5-10k TO. 06:00 - 08:30 ~ 2.50 DRILL P INT1 Continue POH without pumping from 6,827' to 2,973' (above shoe) with no problem. Monitor well and check static losses - ~ 12 bph. 08:30 - 09:30 1.00 DRILL P INT1 Continue POH from 2,973' to 992'. 09:30 - 10:00 ~ 0.50 DRILL P INT1 Stand back 8 stands HWDP. 10:00 - 12:30 2.50 DRILL P INT1 Hold PJSM on nuclear source. Lay down BHA #2. Remove source, lay down ADN, MWD, LW D, ARC, NMSTB, XO, FS, Motor, and bit. Bit #2 Grade: 3-3-WT-A-X-I-CT-TD 12:30 - 13:00 0.50 DRILL P INTi Clear and clean rig floor of mud and cuttings. 'Decision made to go ahead and run 7" intermediate casing.' 13:00 - 13:30 0.50 DRILL P INTi Pick up and make up clean-out assembly BHA #3. Bit - NBSTB - 3 ea, 5" HWDP -JAR stand. RIH on 4" HWDP to 932'. 13:30 - 18:00 4.50 DRILL P INTi RIH with BHA #3 on 4" drill pipe from 932' to 8,200'. PU - 90k, SO - 80k, RT - 85k @ 3,001'. Filled pipe @ 6,012'. Monitor well - OK. Set down @ 7,200'. Wash and ream from 7,200' to 7,500'. RIH from 7,500' to 8,162'. Wash from 8,162' to 8,200'. 18:00 - 20:30 2.50 DRILL P INT1 Circulate bottoms up. Stage pumps up to 400 gpm, 1,655 psi, 80 rpm, 5.1 k TQ. Pump sweep surface to surface 500 gpm, 2,510 psi, 160 rpm, S.Sk TO. MW - 10.3 ppg 20:30 - 21:30 1.00 DRILL P INT1 Monitor well - no static losses. POH short trip from 8,200' to 6,855 without problem'. Had brief over-pulls @ 7,400' - 25k, and @ 7,200' - 15k. 21:30 - 22:00 0.50 DRILL P INTi RIH from 6,827' to 8,200' without problem. 22:00 - 22:30 0.50 DRILL P INTi Circulate bottoms up @ 512 gpm, 2,575 psi, 160 rpm, 5.7k TO. 10.3 ppg MW. 22:30 - 23:00 0.50 DRILL P INTi Monitor well - 12 bph static loss. POH 3 stands to 7,900'. Spot 50 bbls LCM pill. 23:00 - 00:00 1.00 DRILL P INTi POH from 7,900' to 6,855' without problem, no overpull. Mud Losses: Midnight -Noon = 220 bbls Noon -Midnight = 50 bbls Loss for day = 270 bbls Total loss for well = 298 bbls 2/26/2006 00:00 - 03:00 3.00 DRILL P INTi Pump dry job. POH from 6,855' to 932'. Checked for static losses @ shoe - 0 loss. 03:00 - 03:30 0.50 DRILL P INT1 Stand back 8 stands HWDP. 03:30 - 04:00 0.50 DRILL P INT1 Lay down clean-out assembly BHA #3. Static losses out of hole - 0 loss. 04:00 -04:30 0.50 DRILL P INT1 Clean and clear rig floor. 04:30 - 05:30 1.00 BOPSU P INT1 Change upper pipe rams to 7". Test door seals to 3,500 psi - OK. 05:30 - 08:30 3.00 CASE P INTi Make dummy run with 7" hanger, rig up 7" casing running equipment. 08:30 - 13:30 5.00 CASE P INT1 PJSM. Make up 7" 26# L-80 BTC shoe track, (Baker-Loc) check floats - OK. RIH with 7" BTC x TCII casing per detail to Printed: 3/73/2006 70:59:49 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date !From - To 2/26/2006 ~ 108:30 - 13:30 13:30 - 14:00 14:00 - 16:00 16:00 - 17:00 17:00 - 00:00 2/27/2006 100:00 - 02:00 Page 6 of 12 V-112 V-112 Spud Date: 2/17/2006 DRILL+COMPLETE Start: 2/17/2006 End: 3/6/2006 NABOBS ALASKA DRILLING I Rig Release: 3/6/2006 NABOBS 9ES Rig Number: Hours ' Task I Code ~ NPT ~ Phase ~ Description of Operations 5.00 ~ CASE ~ P ~ INTi 3,002'. Torque BTC connections to 8,200 fUlbs TO, using BOL 0.50 CASE P 2.00 CASE P 1.00 CASE P 7.00 CASE P 2.001 CASE P 2000 NM. Fill pipe every joint with fill-up tool, break circulation every 5 jts. Baker-Lok each side of ES Cememter. INT1 Circulate bottoms up @ 9-5/8" shoe, 250 gpm, 350 psi, PU - 100k, SO - 100k. INTi Continue RIH with 7" 26# L-80 BTC casing from 3,002' to 4,040'. Pick up cross-over joint to TCII. INTi Circulate ~ 4,040' while changing out to TCII casing running equipment. 250 gpm, 380 psi, PU - 120k, SO - 118k. INTi Continue RIH with 7" 26# L-80 BTC x TCII casing from 4,040' to 7,500'. Torque TCII connections to 10,300 fUlbs TO using BOL 2000 NM. Started washing down each joint @ top of LCM pill C~3 7,200' to 7,500', 184 gpm, 485 psi. 0 mud losses for the day, 298 blbls total for well. INT1 Continue washing down 7" 26# L-80 BTC x TCII casing from 7,500' to 8,193' @ 180 gpm, 485 psi. Land casing on depth. PU - 243k, SO - 155k without pump. 0 mud loss or problems on total trip in. Ran total of: 97 joints 7" 26# L-80 BTC casing 1 20' Marker joint w/ RA Tag 7" 26# L-80 BTC casing ~ 7,308' 1 cross-over joint 7" 26# L-80 BTC x TCII casing HES Cementer ~ 5,219' 102 joints 7" 26# L-80 TCII casing 2 Space out Pup joints 7" 26# L-80 TCII 02:00 - 02:30 02:30 - 05:00 00 - 07:00 0.50 CEMT P 2.50 CEMT P 2.001 CEMT I P Ran total of 64 7-1/8" x 8-1/4" x 8" centralizers 2 cent locked down next to shoe. Jts #2 - #33: 1 ea. floating over entire length of jt. 1 locked on each side of ES Cementer Jts #64 - #101: 1 ea. floating over entire lenght of jt. INTi Rig down fill-up tool, make up cement head. INT1 Stage up pumps to 6 bpm, 560 psi for 1 bottoms up. Continue stage up pumps to 8 bpm, 650 psi, PU - 218k, SO - 143k. Held cementing PJSM while circulating. Reciprocate string while circulating hole. Lost 44 bbls of mud while circulating on first bottoms up. INT1 Perform 1st Stage Cement job. Switch to Dowell / Schlumberger. Pump and kick out bypass plug with 5 bbls H2O. Load top plug. Test lines to 4,000 psi - OK. Pump 50 bbls MudPush II viscosified spacer weighted to 10.5 ppg. Mix and pump 80 bbls Dowell LiteCRETE cement ~ 11.0 ppg followed by 30 bbls Dowell Premium G cement Ca? 15.8 ppg. Kick out plug with 5 bbls H2O and displace with 305 bbls of mud ~ 8 bpm, 900 psi max pressure. Slow down pump 20 bbls prior to bump to 2 bpm, 500 psi. Bump plug with 1,500 psi with calculated strokes @ 94.5% efficiency. CIP ~ 07:00 hr. Check floats - OK. Reciprocated string 15 ft strokes through out cement job until tail cement started around shoe with full returns. PU - 235k, SO - 150k. Printed: 3/13/2006 10:59:49 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date I From - To V-112 V-112 DRILL+COMPLETE NABOBS ALASKA DRILLING I NABOBS 9ES Hours Code NPT - -~k '~__ 2/27/2006 07:00 - 13:00 I 6.00 ~ CEMT I P 13:00 - 14:30 14:30 - 15:30 15:30 - 16:30 16:30 - 17:00 17:00 - 18:00 18:00 - 18:30 18:30 - 19:00 19:00 - 20:30 20:30 - 00:00 2/28/2006 100:00 - 00:30 00:30 - 02:00 02:00 - 02:30 02:30 - 03:30 03:30 - 05:00 05:00 - 06:45 1.501 CEMT I P 1.00 CEMT P 1.00 WHSUR P 0.50 WHSUR P 1.00 BOPSUF{P 0.50 BOPSU~j P Page 7 of 12 Spud Date: 2/17/2006 Start: 2/17/2006 End: 3/6/2006 Rig Release: 3/6/2006 Rig Number: Phase ~ Description of Operations INTi Load 2nd stage shut-oft plug. Shear open ES Cementer with 3,300 psi. Circulate and condition mud for 2nd stage cement job. Stage pumps up to 3 bpm, 240 psi. Return high PH mud to surface with traces of cement. Junked 78 bbls of mud. I Increase rate to 8 bpm, 600 psi for several circulations while conditioning mud. Reduce rate to 2 bpm, 225 psi while waiting on 1st stage thickening time. Circulate @ 8 bpm, 445 psi for a circulation prior to 2nd stage. INT1 Perform 2nd Stage Cement job. Switch to Dowell / Schlumberger. Pump 5 bbls H2O. Test lines to 4,000 psi - OK. Pump 10 bbls CW-100 pre-flush. Pump 50 bbls MudPush I I viscosified spacer weighted to 10.5 ppg. Mix and pump 12 bbls Dowell LiteCRETE cement @ 11.0 ppg followed by 31 bbls Dowell Premium G cement C~3 15.8 ppg. Kick out closing plug with 5 bbls H2O and displace with 195 bbls of mud Q 8 bpm, 750 psi max pressure. Slow down pump 20 bbls prior to bump to 4.5 bpm, 650 psi. Bump plug and close ES Cementer with 3,400 psi with calculated strokes @ 95% efficiency. CIP C~3 14:00 hr. Check for flowback - OK. Had full returns through cement job. INTi Rig down cement equipment. Blowdown surface lines. INTi Install 9-5/8" X 7" pack-off. Test same to 5,000 psi - OK INTi Rig up and pump 5 bbls down 7" annulus for infectivity test for EMW of 13.0 ppg INTi Change top pipe rams to 6" VBR's. INTi Pressure test top pipe rams and door seals to 250 low psi / 4,000 high psi. 0.50 BOPSU P INT1 Install 9.125" ID wear bushing. Laydown running tool. 1.50 DRILL P PROD1 Hold PJSM on nuclear source. Pick up 6-1/8" directional drilling BHA #4 3.50 DRILL P PROD1 RIH with BHA #4 from 218' to 5,006 0.50 DRILL P PROD1 Wash down from 5,006' to 5,287'. 280 gpm, 1,860 psi, 65 rpm, 3.4k TO. Did not see any indication of ES Cementer @ 5,219'. Work through area several times. Pressure test casing 1,500 psi - 5 minutes - OK. 1.50 DRILL P PROD1 Continue R!H from 5,287' to 7,900'. Injected 85 bbls 10.3 ppg mud C~3 3 bpm, ICP - 900 psi, FCP - 750 psi, SIP -640 psi. Formation broke down C~3 690 psi for EMW of 14.97 ppg. Freeze protected annulus with 66 bbls dead crude ~ 2 bpm, ICP - 900 psi, FCP - 1150 psi, SIP - 810 psi. Injection and freeze protection done out of the critical path. 0.50 DRILL P PROD1 Service topdrive, crown, and blocks. 1.00 DRILL P PROD1 Cut and slip 72' drilling line. 1.50 DRILL P PROD1 RIH 2 stands to 8,091', Break circulation and get air out of system. Perform 7" casing test to 4,000 psi - 30 min - 50 psi loss. Rig down test equipment. 1.75 DRILL P PROD1 Wash down from 8,091' to 8,101'. Drill 6' cement above landing collar. Drill out shoe track to 8,193'. Float equipment on depth. Clean out rat hole from 8,193' to 8,200'. PU - 177k, SO - 112k, RT - 125k, GPM - 270, PSI OFF - 2,260 psi, PSI ON - 2,400 psi, WOB - 0-5k, RPM - 60, TO OFF - 6.8k, TO ON - 7.6k Printed: 3/13/2006 10:59:49 AM BP EXPLORATION Operations Summary Report Page 8 of 12 Legal Well Name: V-112 Common Well Name: V-112 Spud Date: 2/17/2006 Event Name: DRILL+COMPLETE Start: 2/17/2006 End: 3/6/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/6/2006 Rig Name: NABOBS 9ES Rig Number: Date ~ From - To Hours I Task ~ Code ! NPT "Phase ~ Description of Operations 2/28/2006 06:45 - 07:00 ~ 0.25 ~ DRILL P ~ PRODi Drill new 6-1/8" hole from 8 200' to 8,220'. PU - 177k, SO - 07:00 - 08:00 I 1.001 DRILL I P I I PROD1 08:00 - 09:00 I 1.001 DRILL I P I I PROD1 09:00 - 11:00 ~ 2.00 ~ DRILL ~ P ~ PROD1 11:00 - 00:00 I 13.001 DRILL I P I I PROD1 3/1/2006 100:00 - 03:00 I 3.001 DRILL I P I I PROD1 03:00 - 03:30 I 0.501 DRILL I N I DFAL I PRODi 03:30 - 04:00 0.50 DRILL N DFAL PROD1 04:00 - 05:00 1.00 DRILL N DFAL PROD1 05:00 - 08:30 3.50 DRILL N DFAL PROD1 08:30 - 10:00 1.50 DRILL N DFAL PROD1 10:00 - 10:30 0.50 DRILL N DFAL PROD1 10:30 - 13:00 2.50 DRILL N DFAL PROD1 13:00 - 16:30 I 3.50) DRILL I N I DFAL I PROD1 16:30 - 17:00 0.50 DRILL N DFAL PROD1 17:00 - 17:30 0.50 DRILL N DFAL PROD1 17:30 - 18:00 0.50 DRILL P PROD1 18:00 - 00:00 I 6.001 DRILL I P I I PROD1 00:00 - 11:30 I 11.501 DRILL I P I I PROD1 11:30 - 12:00 I 0.501 DRILL I P I I PROD1 112k, RT - 125k, GPM - 270, PSt OFF - 2,260 psi, PSI ON - 2,400 psi, WOB - 0-5k, RPM - 60, TO OFF - 6.8k, TO ON - 7.6k Displace well with new 10.3 ppg, 46 vis, LSND mud. GPM - 290, PSI - 2,030, RPM - 60, TO - 6.6k. Pick up above 7" shoe. Perform FIT. TVD - 6,787, MW - 10.3 ppg, PSI - 250, EMW - 11.01 ppg. Build HI-LOSS LCM pill in pill pit. 40 bbls C~? 85 ppb. Pill consisted of 30 sacks SEAL F, 48 sacks MIX II MED, 16 sacks NUT PLUG M, 4 sacks DESCO, 2 sacks SAPP. Directionally drill 6-1/8" production hole from 8,220' to 8,560'. PU - 148k, SO - 115k, RT - 131 k, GPM - 290, PSI OFF - 2,300 psi, PSI ON - 2,540 psi, WOB - 15k, RPM - 60, TO OFF - 5.3k, TQ ON - 6.2k, AST - 6.35 hrs, ART - .51 hr. Directionally drill 6-1/8" production hole from 8,560' to 8,695'. PU - 145k, SO - 118k, RT - 131 k, GPM - 290, PSI OFF - 2,270 psi, PSI ON - 2,575 psi, WOB - 5-15k, RPM - 60, TO OFF - 3.7k, TO ON - 4-6k, AST - .72 hr, ART - 1.63 hrs. Attempt to drill. Trouble shoot pressure increase. Motor appears to be chunking rubber. Pressure fluctuating intermittently from 2,660 psi to 3,500 psi off of bottom with no apparent hole problem. Monitor well - OK. 10.2 ppg MW POH above shoe from 8,695' to 8,185'. PU - 161 k, SO - 127k. Shear out circulating sub C~3 2,300 psi and circulate bottoms up 350 gpm, 1,530 psi, 60 rpm, 2.8 TO. Small chunks of rubber found in bottoms up samples. POH for motor from 8,185' to 331'. PJSM on nuclear source. Lay down BHA #4. Large pieces of rubber found in bit. Clear and clean rig floor. Change out mud motor and bit. Held PJSM on nuclear source crew change. Make up BHA #5. RIH from 216' to 8,195'. Tested MWD @ 1,157' - OK. Filled pipe @ 4,060' and 8,185'. Service topdrive, crown, and blocks. Continue RIH with BHA #5 from 8,195' to 8,564'. Wash and MadPass from 8,564' to 8,695' C~3 600 fph, 264 gpm, 2,270 psi, 60 rpm, 4.7k TO. Directionally drill 6-1/8" production hole from 8,695' to 8,842'. PU - 150k, SO - 118k, RT - 131 k, GPM - 280, PSI OFF - 2,030 psi, PSI ON - 2,330 psi, WOB - 15k, RPM - 60, TO OFF - 3.1 k, TO ON - 4.4k, AST - 2.57 hrs, ART - 1.30 hrs. 0 bbl Mud loss for the day 298 bbls total loss for well Directionally drill 6-1/8" production hole from 8,842' to TD C~3 9,538' MD, 6,702' TVD. PU - 143k, SO - 111 k, RT - 128k, GPM - 285, PSI OFF - 2,145 psi, PSI ON - 2,350 psi, WOB - 10-15k, RPM - 60, TO OFF - 3.9k, TO ON - 4.9k, AST - .85 hrs, ART - 7.44 hrs. 0 mud losses. Survey every 30', backream every stand. Circulate open hole volume. GPM - 285, PSI - 2,160 psi, RPM - 60, TO - 3.5k, TO ON - 4.9k, MW - 10.2 ppg. Printed: 3/13/2006 10:59:49 AM BP EXPLORATION Operations Summary Report Legal Well Name: V-112 Common Well Name: V-112 Event Name: DRILL+COMPLETE Start: 2/17/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/6/2006 Rig Name: NABOBS 9ES Rig Number: Date ~ From - To ' Hours Task Code ~ NPT I Phase 3/2/2006 ~_ II 12:00 - 16:00 ~ - - ~ 4.00 ~ _ _ _ DRILL - P ~ r- ~ PRODi 16:00 - 17:00 I 1.001 DRILL I P I 1 PROD1 17:00 - 20:00 3.00 DRILL P 1 PROD1 20:00 - 22:30 2.50 DRILL P PROD1 22:30 - 23:00 0.50 DRILL P PROD1 23:00 - 00:00 1.00 CASE P RUNPRD 3/3/2006 00:00 - 02:30 ~ 2.50 CASE P RUNPRD 02:30 - 03:00 ~ 0.50 ~ CASE ~ P ~ ~ RUNPRD 03:00 - 08:30 I 5.501 CASE I P I I RUNPRD 08:30 - 09:00 I 0.501 CASE I P I I RUNPRD 09:00 - 11:00 I 2.001 CASE I P I I RUNPRD 11:00 - 13:30 I 2.501 CEMT I P I I RUNPRD 13:30 - 14:30 I 1.001 CEMT I P I I RUNPRD Page 9 of 12 Spud Date: 2/17/2006 End: 3/6/2006 Description of Operations Monitor well - OK. POH from 9,538' to 9,400'. MadPass log from 9,400' to 8,193'. 280 gpm, 2,120 psi, 60 rpm, 4k TO. Started losing appx 5 bph during MadPass. Drop circ sub dart, open circ sub, and circulate bottoms up. 350 gpm, 1,480 psi, 60 rpm, 3.7k TO 10.2 ppg MW. POH from 8,193' to 216. Hoid PJSM on nuclear source. Laydown BHA #5. Clear and clean rig floor. Rig up 4.5" liner running tools. 55 bbls mud loss for day. 353 bbls total for well. PJSM on running casing. Make up, Baker-lok shoe track, fill pipe, and check floats - OK. RIH with 35 joints total of 4.5" 12.6# L-80 IBT-M production liner, made up to 3,500 ft/Ibs TO using Best O Life 2000 NM pipe lubricant, Baker 80-40 SBE, Baker 5" x 7" HMC Liner Hanger, and Baker 5" x 7" C-2 Liner Top Packer to 1,504'. Pick up 1 5 ft pup and 1 single joint drill pipe. Circulate one liner volume. PU - 56k, SO - 54k. RIH with 4.5" liner on drill pipe from 1,543' to 8,108' @ 1 minute per stand, fill pipe every 10 stands. Circulate bottoms up C~ 252 gpm, 460 psi. Make up cement head on single joint of drill pipe and lay down on pipe skate. RIH from 8,108' to 9,515'. Pick up single with cement head and RIH to bottom ~ 9,538'. Shoe C~3 9,538' Tops: Float Collar ~ 9,493' Landing Collar @ 9,450' PBTMD RA Tag C~3 8,426' SBE w/ 19' L x 4" ID throat @ 8,069' ZXP Liner Top Packer w/ 11.42' L x 5.25" ID Tie Back Extension C~? 8,041:7' Circulate and condition mud for cement job. Stage pumps up to 247 gpm, 1200 psi. PU - 144k, SO - 125k. Held PJSM on cement job while circulating & reciprocating. Switch to Dowell / Schlumberger. Pump 5 bbls H2O. Test lines to 3,500 psi - OK. Pump 10 bbls 8.2 ppg CW-100, pump 20 bbls 11.1 ppg MudPush, followed by 38 bbls, 183 sacks of 15.8 ppg class "G" cement. Shut down pumps. Wash cement line to rig floor Tee with H2O. Switch to Rig. Drop drill pipe wiper plug and displace cement with 102 bbls 10.2 ppg mud C 6 bpm to catch plug. Caught up with plug @ 520 strokes, latched up liner wiper plug ~ 1,346 strokes (96% effc). Slow pump to 4 bpm, 1000 psi maximum pressure, PU - 175k, SO - 75k. Bump plug with 1,718 strokes (96% effc) with 3,000 psi to set hanger. CIP ~ 14:30 hr. Bleed off pressure, check floats - OK. Rotate 20 turns to the right with 3.8k TO to release from hanger. Pressure up to 1,000 psi and pick up slowly. Observed pressure loss, and pump 10 bbls mud C~3 4 bpm to move cement away from liner top. Reduce rate to 2 bpm and Printed: 3/13/2006 10:59:49 AM BP EXPLORATION Page 10 of 12 Operations Summary Report Legal Well Name: V-112 Common Well Name: V-112 Spud Date: 2/17/2006 Event Name: DRILL+COMPLETE Start: 2/17/2006 End: 3/6/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/6/2006 Rig Name: NABOBS 9ES Rig Number: Date ~ From - To Hours ! Task 'Code NPT 3/3/2006 13:30 - 14:30 1.00 (CEMT I P ~ 14:30 - 15:30 I 1.001 CEMT I P 15:30 - 17:00 I 1.501 CEMT I P 17:00 - 21:00 4.00 CEMT P 21:00 - 22:00 1.00 EVAL P 22:00 - 00:00 2.00 EVAL P 3/4/2006 ~ 00:00 - 04:30 4.50 EVAL P 04:30 - 05:00 0.50 EVAL P 05:00 - 06:00 1.00 SIT P 06:00 - 06:30 0.50 PERFOB~ P 06:30 - 07:30 1.00 PERFO P 07:30 - 10:00 2.50 PERFO P 10:00 - 11:30 1.50 PERFO P 11:30 - 14:30 3.001 PERFOB~ P 14:30 - 15:00 I 0.501 PERFO~ P Phase i Description of Operations RUNPRD pick up high enough to ensure setting dogs are exposed. Slack off and set down 50k to set packer. Repeat twice. Rotate down with 4.5k and repeat setting process. Good indication of packer set on the first time 50K was applied. RUNPRD Circulate bottoms up @ 415 gpm, 2,200 psi. PU - 139k, SO - 118k. Returned 5 bbls good cement plus 20 bbls of high PH 12+ mud back to surface. Lay down cement head and top single so that tooljoints can be crossed while circulating. Pump app. 50 bbls. of mud while working 60 ft. of pipe. RUNPRD Displace well from 10.2 ppg LSND mud to 8.5 ppg seawater @ 400 gpm, 1,800 psi. RUNPRD POH from 7,906' to surface. Lay down liner running tool. OTHCMP PJSM with Schlumberger WL. Rig up to run USIT. OTHCMP Run in hole with wiretine USIT to 5,200'. OTHCMP Run in hole with wiretine USIT from 5,200' to 8,000'. USIT log 7" casing from 8,000' to 2,880'. POH with USIT OTHCMP Rig down Schlumberger WL. OTHCMP Pressure test 4.5" 12.6# L-80 IBT-M liner, liner lap, and 7" 26# L-80 BTC-M casing to 4,000 psi - 30 min - 50 psi loss. OTHCMP Pick up pert gun tools to rig floor. OTHCMP Hold PJSM with Schlumberger on DPC perforating. Pick up 15 ea. 2-7/8" HSD 6SPF pert guns and redundant HDF firing head. OTHCMP RIH with 2/78" pert gun on 43 jts of 2-7/8" PAC drill pipe to 1,661'. OTHCMP Pick up 11 ea. 4.5" HSD 5SPF pert guns, redundant HDF firing head and 7/8" ball disconnect. OTHCMP RIH with 2-7/8" x 4.5" perforating assembly on 4" drill pipe to landing collar @ 9,450'. Stopped at shoe for string weights. PU - 151 k, SO - 125k. Stopped @ perforating depth @ 9,438' to mark pipe then tagged landing collar on depth. Picked up pipe back to mark for perforating depth. PU - 160k, SO - 125k. OTHCMP Close annular. Pump down drill pipe and annulus to 2,200 psi. Had surface indication of 2-7/8" and 4.5" guns firing. Bleed off pressure, open annular. Observed 5 bbls initial loss. 8.5 ppg seawater. Perforation Depths: 7,550' to 7,620', 70' @ 5 spf 7,632' to 7,660', 28' @ 5 spf 7,680' to 7,706', 26' @ 5 spf 7,745' to 7,770', 25' @ 5 spf 9,140' to 9,190', 50' @ 6 spf 9,250' to 9,290', 40' @ 6 spf 9,320' to 9,375', 55' @ 6spf 9,410' to 9,438', 28' @ 6 dpf 15:00 - 16:00 1.00 PERFO P OTHCMP POH standing back drill pipe from 9,438' to 7,550'. No excess drag coming out of perforated area. 16:00 - 17:00 1.00 PERFO P OTHCMP Monitor well for 5 min -no static losses. Circulate bottoms up @ 300 gpm, 745 psi. Lost 12 bbls. 17:00 - 23:30 6.50 PERFO P OTHCMP POH laying down drill pipe from 7,550' to 2,100' with guns 200' below rotary table. 9 bph loss rate while POH 23:30 - 00:00 0.50 PERFO P OTHCMP Lay down 4.5" spent pert guns to 1,800'. Losses continue @ 9 Printed: 3/13!2006 10:59:49 AM BP EXPLORATION Operations Summary Report Page 11 of 12 Legal Well Name: V-112 Common Well Name: V-112 Spud Date: 2/17/2006 Event Name: DRILL+COMPLETE Start: 2/17/2006 End: 3!6/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/6/2006 Rig Name: NABOBS 9ES Rig Number: i Date From - To Hours ~ Task 'Code NPT Phase Description of Operations 3/4/2006 23:30 - 00:00 0.50 PERFO~ P ~OTHCMP bph. I Fluid losses for day - 50 bbls. ~ Losses for well - 403 bbls. 3/5!2006 00:00 - 01:00 1.00 PERFO P OTHCMP Lay down 4.5" pert guns. All guns fired. 01:00 - 02:30 1.50 PERFO P OTHCMP Lay down 43 joints 2-7/8" PAC drill pipe. 02:30 - 04:00 1.50 PERFO P OTHCMP Lay down 2-7/8" pert guns. All guns fired. 04:00 - 05:00 1.00 PERFO P OTHCMP Clean and clear rig floor. Lay down all vendor tools. 05:00 - 06:30 1.50 PERFO P OTHCMP RIH with remaining drill pipe and HWDP in derrick to 3,629' 06:30 - 09:30 3.00 PERFO P j OTHCMP POH laying down drill pipe trom 3,629' to 736'. 09:30 - 10:30 1.00 PERFO P ~ OTHCMP Cut and slip 78' drilling line. Cleanout from under drawworks. 10:30 - 11:30 1.00 PERFO P OTHCMP Lay down HWDP from 736' to surface. 11:30 - 12:00 0.50 BOPSU P OTHCMP PuII wear bushing, rig up to test BOPE. 12:00 - 15:00 3.00 BOPSU P OTHCMP Test ROPE and floor related equipment to 250 psi low, 4,000 psi high. Test annular preventer to 250 psi low, 3,500 psi high. Function tested accumulator system, PVT's and flow show. "Test witnessed by AOGCC rep Jeff Jones, BP WSL Alan Madsen, NAD TP Bitl Bixby. Pump operator Sean Holcomb. 15:00 - 15:30 0.50 BOPSU P OTHCMP Rig down test equipment. 15:30 - 17:00 1.50 BUNCO RUNCMP Make tubing hanger dummy run. Rig up to run 3.5" x 4.5" completion assembly. 17:00 - 20:00 3.00 BUNCO RUNCMP Hold PJSM on running tubing. Make up and run in hole with 3.5" 9.2# L-80 TCII tubing assembly per running order detail to 691'. 3.5" MU TO - 2,300 ft/Ibs. 20:00 - 00:00 4.00 BUNCO RUNCMP Switch to 4.5" equipment and run in hole with 3.5" 9.2# L-80 TCII X 4.5" 12.6# L-80 TCII tubing assembly per running order detail from 691' to 2,780' with 4.5" MU TO - 3,800 ft/Ibs. Used Jet Lube lubricant on all connections. Fluid losses: Mid -Noon = 51 bbls Noon -Mid = 35 bbls Well total = 489 bbls 3/6/2006 00:00 - 06:00 6.00 BUNCO RUNCMP Continue running in hole with 3.5" x 4.5" completion assembly to 8,040' 06:00 - 06:30 0.50 BUNCO RUNCMP Tag up with locator on bottom of Liner Top Packer Tie Back Sleeve @ 8,056' with 15k set down. Pick up, slack off to verify. PU - 90k, SO - 70k (less block weight). Space out for 16' of seal assembly in Seal Bore Extension. Lay down 3 joints 4.5" tubing. 06:30 - 09:00 2.50 BUNCO RUNCMP Rig up to reverse circulate. Pump and reverse circulate 137 bbls clean seawater followed with 47 bbls inhibited seawater followed with 90 bbls clean seawater @ 3 bpm, 300 psi. 09:00 - 09:30 0.50 BUNCO RUNCMP Make up space oui pups under 1 joint of 4.5" tubing. Make up tubing hanger, land tubing and run in lock down screws. PU - 90k, SO - 70k (less block weight). Ran total of: 17 jts, 531', 3.5" 9.2# L-80 TCII tubing 174 jts, 7,225', 4.5" 12.6# L-80 TCII tubing FMC 4.5" x 11 "Gen 5 tubing hanger with TCII lift threads 3 ea. 4.5" 9.2# L-80 TCII Space Out Pups below top joint of 4.5" tubing Printed: 3/13/2006 10:59:49 AM BP EXPLORATION Page 12 of 12 Operations Summary Report Legal Well Name: V-112 Common Well Name: V-112 Event Name: DRILL+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 9ES Date 'From - To ', Hours i Task ,Code NPT 3/6/2006 ~ 09:00 - 09:30 ~ 0.50 ~ RUNCOIv4P 09:30 - 10:30 I 1.00 10:30 - 12:00 I 1.50 12:00 - 12:30 I 0.50 12:30 - 14:30 I 2.001 BOPSUR P 14:30-17:00 ~ 2.50~WHSUR~P 17:00 - 18:00 1.00 WHSUR P 18:00 - 20:00 2.00 WHSUR P 20:00-21:00 I 1.001 WHSURIP 21:00-21:30 I 0.501 WHSURIP 21:30-00:00 2.50 WHSURIP Spud Date: 2/17/2006 Start: 2/17/2006 End: 3/6/2006 I Rig Release: 3/6/2006 Rig Number: Phase ! Description of Operations RUNCMP 3 ea 4.5" X nipples @ 2,220', 7,359', 7,409' 4.5" x 1" KBG-2 GLM w/ Dummy valve and BK latch Q 3,196' 4.5" x 1" KBG-2 GLM w/ 1" DCK-2 Shear valve and BEK latch C~ 4,833' Baker Premier Hyd Set Packer @ 7,380' 3.5" x 4.5" 9CR X-over ~ 7,419' 2 ea. 3.5" x 1.5" MMG-W GLM w/ 1.5" Dummy valve and RK latch C~3 7,430' & 7,491' Baker CMD Non Elastomer sliding sleeve w! RHC-plug in "BX" profile C~? 7,520' 3.5" X nipple @ 8,011' RUNCMP Drop 1.313" (1.375" fishing neck) roller type ball and rod. (Rod missing top roller). Rig down tubing equipment. *Ball is in seat of the RHC @ 7,519' in the Sliding Sleeve* RUNCMP Pressure up and set packer to 4,200 psi. Hold pressure for 30 min tubing test - OK. Bleed down tubing pressure to 2,000 psi, pressure up annulus to 4,000 psi and hold 30 min for packer and 7" casing test - OK. Bleed annulus to 0 psi, bleed tubing to 0 psi. Pump down annulus, pressure up to 2,350 psi and shear DCK-2 valve. Pump 2 bbls through valve to verify opening - OK. Lost 18 bbls prior to setting packer. **Total losses for well: 10.3 ppg mud - 353 bbls 8.5 ppg seawater - 152 bbls RUNCMP Drain BOP stack, install 2-way check in tubing hanger and test to 1,000 psi from below. RUNCMP Remove mouse hole, pull drilling nipple. Nipple down BOPE and secure in cellar. RUNCMP Clean, prep tubing hanger and adapter flange. Install adapter flange, test same to 5,000 psi - 10 min - OK. Nipple up double valve temporary tree. Test same 5,000 psi - OK. RUNCMP Rig up DSM lubricator and pull 2-way check. RUNCMP Rig up to freeze protect well. Pressure test lines to 3,000 psi - OK. Reverse in 80 bbls of 70 deg diesel for freeze protection to 2,200' TVD. 2 bpm, ICP - 500 psi, FCP - 1,000 psi. RUNCMP Line up to U-tube. U-tube diesel from tubing annulus back to tubing. SIP - 120 psi. RUNCMP Install back pressure valve in tubing hanger with lubricator. Test to 1,000 psi from below - OK. RUNCMP Secure well. Rig down circulating manifold and working valves. Install VR plug in inner & outer annulus. *Release rig from operations on V-112i @ 23:59 hr, 3/6/2006* (Rig will be standing by on location for L-214a prep work) Printed: 3/13/2006 10:59:49 AM V-112 Survey Report $chlumb~nger Report Date: 2-Mar-06 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 298.000° Field: Prudhoe Bay Unit • WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure /Slot: V-Pad /Plan V-112 (S-A) TVD Reference Datum: Rotary Table. Well: V-112 TVD Reference Elevation: 81.50 ft relative to MSL Borehole: V-112 Sea Bed I Ground Level Elevation:. 52.60 ft relative to MSL UWVAPI#: 500292330000 Magnetic Declination: 24.333° Survey Name /Date: V-112 /March 2, 2006 Total Field Strength: 57579.812 nT Tort IAHD I DDI / ERD ratio: 198.400° / 5099.99 ft / 6.150 / 0.746 Magnetic Dip: 80.843° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: February 22, 2006 Location Lat/Long: N 7019 38.754, W 14915 59.917 Magnetic Declination Model: BGGM 2005 Location Grid WE Y/X: N 5969872.530 ftUS, E 590427.660 ftUS North Reference: True North Grid Convergence Angle: +0.69055612° Total Corr Mag North -> True North: +24.333° Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Nole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 h ftUS ftUS Hit u.uu u.uu u.uu -ai.5u u.uu u.uu u.uu u.uu u.uu v.uu u.vv oabaarz.os oyvw~i.eb iv iv iasrs.io4 vv iwy t5oa.aii GYD GC MS 100.00 0.28 194.49 18.50 100.00 -0.06 0.24 0.24 -0.24 -0,06 0.28 5969872.29 590427.60 N 70 19 38.752 W 149 15 59.918 200.00 0.54 195.09 118.50 200.00 -0.22 0.96 0.96 -0.93 -0.24- 0.26 5969871.60 590427.43 N 70 19 38.745 W 149 15 59.924 300.00 0.76 198.18 218.49 299.99 -0.44 2.09 2.09 -2.01 -0.57 0.22 5969870.51 590427.11 N 70 19 38.734 W 149 15 59.933 400.00 2.56 232.85 318.45 399.95 0.39 4.93 4.74 -3.99 -2.56 1.98 5969868.51 590425.15 N 70 19 38.715 W 149 15 59.991 500.00 4.60 242.38 418.25 499.75 3.59 11.16 10.69 -7.20 -7.90 2.12 5969865.24 590419.85 N 70 19 38.683 W 149 16 0.147 600.00 6.90 247.83 517.74 599.24 9.70 21.17 20.44 -11.33 -17.01 2.36 5969861.00 590410.79 N 70 19 38.643 W 149 16 0.413 700.00 9.08 251.86 616.76 698.26 19.02 35.06 34.09 -16.05 -30.08 2.25 5969856.12 590397.78 N 70 19 38.596 W 149 16 0.794 800.00 11.22 254.38 715.19 796.69 31.53 52.68 51.48 -21.13 -46.95 2.19 5969850.84 590380.98 N 70 19 38.546 W 149 16 1.287 Last GYD GC MS 900.00 12.09 257.41 813.13 894.63 46.53 72.88 71.45 -26.03 -66.54 1.06 5969845.70 590361,45 N 70 19 38.498 W 14916 1.859 First MWD+IFR+MS 944.22 12.38 262.35 856.35 937.85 53.90 82.24 80.65 -27.67 -75.75 2.46 5969843.95 590352,25 N 701938.482 W 149 8 1037.18 13.37 273.68 946.98 1028.48 71.79 102.89 100.43 -28.31 -96.36 2.91 5969843.07 590331.66 N 70 19 38.476 W 149 9 1130.16 14.54 285.59 1037.24 1118.74 92.99 125.24 120.84 -24.48 -118.34 3.33 5969846.63 590309.64 N 7019 38.513 W 149 16 371 1224.15 .14.44 296.33 1128.25 1209.75 116.23 148.69 141.13 -16.11 -140.21 2.86 5969854.73 590287.67 N 70 19 38.596 W 149 16 4.009 1317.35 15.62 298.94 1218.26 1299.76 140.39 172.86 161.68 -4.88 -161.60 1.46 5969865.70 590266.14 N 70 19 38.706 W 149 16 4.634 1411.01 16.46 301.18 1308.28 1389.78 166.25 198.73 184.17 8.09 -183.99 1.11 5969878.40 590243.60 N 70 19 38.834 W 149 16 5.288 1504.06 18.64 300.28 1396.99 1478.49 194.28 226.79 209.32 22.41 -208.11 2.36 5969892.43 590219.31 N 70 19 38.975 W 149 16 5.992 1597.99 22.95 298.95 1484.78 1566.28 227.60 260.13 240.28 38.85 -237.12 4.62 5969908.52 590190.12 N 70 19 39.136 W 149 16 6.838 1691.38 23.30 298.73 1570.67 1652.17 264.28 296.80 275.12 56.55 -269.24 0.39 5969925.82 590157.78 N 70 19 39.310 W 149 16 7.776 1785.04 22.44 298.04 1656.96 1738.46 300.67 333.20 310.19 73.85 -301.27 0.96 5969942.74 590125.55 N 70 19 39.480 W 149 16 8.711 1878.75 23.36 297.83 1743.29 1824.79 337.14 369.67 345.66. 90.93 -333.48 0.99 5969959.43 590093.14 N 70 19 39.648 W 149 16 9.652 1972.03 25.23 299.77 1828.30 1909.80 375.51 408.04 383.06 109.44 -367.10 2.18 5969977.53 590059.31 N 70 19 39.830 W 14916 10.633 2067.68 24.92 299.73 1914.94 1996.44 416.02 448.58 422.64 ..129.56 -402.29 0.32 5969997.22 590023.88 N 70 19 40.028 W 149 16 11.660 SurveyEditor Ver SP 1.0 Bld( doc40x_56) Plan V-112 (S-A)\V-112\V-112\V-112 Generated 3/21/2006 1:09 PM Page 1 of 4 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS L16U.26 24.44 300.LV 1999.06L080.56 4b4.66 48/.23 46U.bU 148.86 -4~b./8 U.b6 59/UU16.lZ 2253.23 24.11 300.38 2083.81 2165.31 492.85 525.46 498.03 168.14 -468.78 0.36 5970034.99 2344. 22 25.55 298. 85 2166.39 2247.89 531. 04 563.66 535 .71 187.01 -502.00 1.73 5970053.46 2437. 24 25.16 299. 50 2250.45 2331.95 570. 86 603.50 575 .11 206.42 -536 .79 0.52 5970072.45 2530. 28 24.95 299. 23 2334.73 2416.23 610. 25 642.90 614 .12 225.75 -571 .12 0.26 5970091.36 2621. 92 24.65 298. 80 2417.92 2499.42 648. 69 681.33 652 .25 244.39 -604 .74 0.38 5970109.59 2716. 27 24.23 298. 46 2503.82 2585.32 687. 72 720.37 691 .04 263.10 -639 .00 0.47 5970127.88 2809. 20 25.63 299. 30 2588.09 2669.59 726. 88 759.54 729 .97 282.02 -673 .29 1.55 5970146.39 2901. 69 25.45 299. 34 2671.54 2753.04 766. 75 799.42 769 .60 301.55 -708 .06 0.20 5970165.49 2951. 61 25.15 298. 58 2716.67 2798.17 788. 08 820.75 790 .82 311.88 -726 .73 0.89 5970175.60 3038. 12 24.91 298. 47 2795.06 2876.56 824. 68 857.35 827 .27 329.36 -758 .89 0.28 5970192.69 3091. 05 24.66 296. 81 2843.11 2924.61 846. 87 879.54 849 .40 339.65 -778. 54 1.40 5970202.74 3184.51 3278.43 3373.09 3467.54 3561.23 3655.74 3749.87 3845.03 3938.79 4033.71 4128.48 4223.86 4318.20 4412.85 4506.54 4601.65 4693.61 4787.41 4881.49 4978.50 24.34 24.07 23.93 25.10 25.48 25.22 24.82 24.80 24.48 24.32 295.60 2928.16 294.53 3013.82 294.03 3100.30 296.15 3186.23 299.35 3270.95 299.29 3356.36 299.00 3441.65 298.72 3528.03 299.13 3613.25 298.93 3699.70 24.27 298.71 3786.07 23.79 299.41 3873.19 25.10 297.05 3959.07 25.47 296.94 4044.65 25.52 296.96 4129.22 25.15 295.90 4215.18 24.90 296.19 4298.51 24.95 296.08 4383.57 24.95 296.08 4468.87 25.11 297.57 4556.77 3009.66 3095.32 3181.80 3267.73 3352.45 3437.86 3523.15 3609.53 3694.75 3781.20 3867.57 3954.69 4040.57 4126.15 4210.72 4296.68 4380.01 4465.07 4550.37 4638.27 885.60 924.06 962.48 1001.61 1041.62 1082.08 1121.88 1161.80 1200.89 1240.09 1279.08 1317.92 1356.95 1397.37 1437.69 1478.37 1517.25 1556.76 1596.42 1637.45 918.30 956.80 995.30 1034.49 1074.51 1114.97 1154.78 1194.71 1233.80 1273.01 1312.00 1350.84 1389.88 1430.30 1470.63 1511.33 1550.23 1589.76 1629.45 1670.49 888.12 926.62 965.12 1004.29 1044.21 1084.50 1124.17 1163.98 1202.95 1242.06 1280.95 1319.69 1358.67 1399.07 1439.38 1480.07 1518.97 1558.49 1598.17 1639.20 5072.23 25.12 297.39 4641.64 4723.14 1677.23 1710.27 1678.96 5166.54 24.83 296.91 4727.13 4808.63 1717.05 1750.09 1718.76 5260.27 24.53 296.28 4812.30 4893.80 1756.17 1789.23 1757.89 5353.48 24.38 295.66 4897.15 4978.65 1794.73 1827.81 1796.47 5446.87 24.53 296.79 4982.16 5063.66 1833.38 1866.47 1835.13 5540.39 24.38 297.26 5067.29 5148.79 1872.09 1905.19 1873.83 5633.65 24.20 296.23 5152.30 5233.80 1910.44 1943.55 1912.18 5730.95 23.78 296.50 5241.19 5322.69 1949.98 1983.11 1951.74 5820.56 24.42 292.05 5323.00 5404.50 1986.47 2019.68 1988.29 356.77 -813.31 373.08 -848.19 388.91 -883.29 405.54 -918.77 424.18 -954.17 443.99 -989.45 463.38 -1024.22. 482.66 -1059.19 501.56 -1093.41 520.59 -1127.69 539.39 -1161.85 558.25 -1195.80 576.70 -1230.20 595.05 -1266.22 613.32 -1302.17 631.44 -1338.61 648.52 -1373.56 665.93 -1409.05 683.38 -1444.70 701.90 -1481.32 720.26 -1516.62 738.43 -1552.05 755.95 -1587.04 772.85 -1621.73 789.93 -1656.41 807.52 -1690.90 824.79 -1725.16 842.36 -1760.60 857.37 -1793.94 0.64 5970219.44 0.55 5970235.33 0.26 5970250.73 1.55 5970266.93 1.51 5970285.14 0.28 5970304.53 0.44 5970323.49 0.13 5970342.34 0.39 5970360.83 0.19 5970379.45 0.11 5970397.83 0.59 5970416.28 1.73 5970434.30 0.39 5970452.22 0.05 5970470.06 0.62 5970487.73 0.30 5970504.39 0.07 5970521.37 0.00 5970538.38 0.67 5970556.46 0.08 5970574,39 0.38 5970592.13 0.43 5970609.23 0.32 5970625.71 0.53 5970642.37 b8999U.11i N /V 19 4U.G18 W 149 16 1'L.tiVB 589956.93 N 70 19 40.408 W 149 16 13.602 589923.48 N 70 19 40.593 W 149 16 14.571 589888.48 N 70 19 40.784 W 149 16 15.587 589853.91 N 70 19 40.974 W 14916 16.589 589820.08 N 70 19 41.157 W 149 16 17.571 589785.59 N 70 19 41.341 W 149 16 18.571 589751.08 N 70 19 41.527 W 149 16 19.572 589716.08 N 70 19 41.719 W 149 16 20.587 589697.29 N 70 19 41.821 W 149 16 21.132 589664.93 N 70 19 41.993 W 149 1 ~1 589645.16 N 70 19 42.094 W 149 1 5 589610.18 N 70 19 42.262 W 149 16 23.660 589575.11 N 70 19 42.423 W 149 16 24.678 589539.83 N 70 19 42.579 W 149 16 25.703 589504.16 N 70 19 42.742 W 149 16 26.739 589468.54 N 70 19 42.925 W 149 16 27.772 589433.02 N 70 19 43.120 W 149 16 28.802 589398.02 N 70 19 43.311 W 149 16 29.817 589362.83 N 70 19 43.500 W 149 16 30.838 589328.39 N 70 19 43.686 W 149 16 31.837 589293.88 N 70 19 43.873 W 149 16 32.838 589259.50 N 70 19 44.058 W 149 16 33.836 589225.33 N 70 19 44.244 W 149 16 34.827 589190.71 N 70 19 44.425 W 149 16 35.831 589154.47 N 70 19 44.605 W 149 16 36.883 589118.31 N 70 19 44.785 W 149 16 37.933 589081.66 N 70 19 44.963 W 149 1 7 589046.51 N 70 19 45.131 W 149 1 7 589010.81 N 70 i 9 45.302 W 149.16 3 588974.97 N 70 19 45.474 W 149 16 42.094 588938.12 N 70 19 45.656 W 149 16 43.163 588902.61 N 70 19 45.836 W 149 16 44.194 588866.97 N 70 19 46.015 W 149 16 45.228 588831.77 N 70 19 46.187 W 149 16 46.250 588796.88 N 70 19 46.353 W 149 16 47.263 588762.00 N 70 19 46.521 W 149 16 48.276 0.26 5970659.54 588727.31 N 70 19 46.694 W 149 16 49.283 0.49 5970676.39 588692.85 N 70 19 46.864 W 149 16 50.283 0.45 5970693.53 588657.20 N 70 19 47.037 W 149 16 51.318 2.15 5970708.14 588623.68 N 70 19 47.184 W 14916 52.291 SurveyEditor Ver SP 1.0 Bld( doc40x_56) Plan V-112 (S-AjiV-112\V-112\V-1 i2 Generated 3/21/2006 1:09 PM Page 2 of 4 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS byl~.bt5 GS.Ub 'Lif/.bU b4V/.4tf b42ftS.yi3 LVL4.y/ 'LUbtS.bU LUL/.Ul t5/U.bb -12f3U.bb L.1L ba/u/~u.a/ biSYSbifb.y:i IV /V ly4/.;514 VV 14y 1bbJ..ibV 6007.41 27.20 282.76 5491.73 5573.23 2065.22 2099.90 2067.64 881.30 -1870.41 3.22 5970731.14 588546.94 N 70 19 47.419 W 149 16 54.524 6100.13 28.77 277.21 5573.62 5655.12 2106.53 2143.38 2109.59 888.78 -1913.23 3.28 5970738.11 588504.04 N 70 19 47.493 W 149 16 55.774 6193.31 29.88 267.64 5654.90 5736.40 2147.55 2188.93 2151.67 890.64 -1958.69 5.16 5970739.42 588458.56 N 70 19 47.511 W 149 16 57.101 6287.63 28.82 258.25 5737.16 5818.66 2185.32 2235.08 2191.14 885.04 -2004.45 5.00 5970733.27 588412.88 N 70 19 47.456 W 149 16 58.437 6381.24 26.41 248.76 5820.14 5901.64 2216.28 2278.39 2224.39 872.89 -2045.97 5.35 5970720.62 588371.51 N 70 19 47.336 W 149 16 59.649 6474.69 27.76 244.95 5903.35 5984.85 2242.94 2320.93 2253.99 856.15 -2085.06 2.35 5970703.41 588332.63 N 70 19 47.171 W 149 17 0.790 6567.35 30.51 245.32 5984.27 6065.77 2270.17 2366.04 2284.89 837.19 -2125.99 2.97 5970683.96 588291.93 N 70 19 46.985 W 149 17 1.985 6663.08 36.73 244.85 6063.95 6145.45 2302.10 2419.02 2321.72 814.85 -2174.03 6.50 5970661.05 588244.17 N 70 19 46.765 W 149 17 3.388 6756.29 40.23 243.55 6136.91 6218.41 2336.33 2477.01 2362.10 789.59 -2226.23 3.85 5970635.16 588192.29 N 70 19 46.516 W 149 17 4.911 6849.99 45.15 243.49 6205.76 6287.26 2373.23 2540.52 2406.65 761.27 -2283.07 5.25 5970606.16 588135.79 N 70 19 46.238 W 149 1~1 6943.59 49.63 242.24 6269.11 6350.61 2412.57 2609.39 2455.33 729.84 -2344.35 4.89 5970573.99 588074.90 N 70 19 45.928 W 149 17 59 7036.69 54,86 240.18 6326.10 6407.60 2452.83 2682.97 2506.89 694.36 -2408.81 5.88 5970537.75 588010.88 N 70 19 45.579 W 149 17 10.241 7130.83 60.13 238.13 6376.68 6458.18 2493.85 2762.33 2561.71 653.64 -2476.92 5.89 5970496.21 587943.27 N 70 19 45.179 W 149 17 12.229 7222.74 65,71 237.16 6418.50 6500.00 2534.30 2844.13 2618.03 609.85 -2546.01 6.14 5970451.59 587874.72 N 70 19 44.748 W 149 17 14.246 7315.77 70.91 234.70 6452.88 6534.38 2574.74 2930.54 2677.10 561.41 -2617.57 6.11 5970402.31 587803.76 N 70 19 44.271 W 149 17 16.334 7408.60 72.44 227.99 6482.09 6563.59 2609.62 3018.65 2733.63 506.39 -2686.32 7.06 5970346.47 587735.68 N 70 19 43.730 W 149 17 18.341 7502.25 74.56 224.60 6508.70 6590.20 2637.78 3108.44 2786.86 444.35 -2751.21 4.14 5970283.65 587671.55 N 70 19 43.119 W 149 17 20.234 7595.83 72.58 224.13 6535.16 6616.66 2663.07 3198.19 2839.53 380.19 -2813.97 2.17 5970218.75 587609.58 N 70 19 42.488 W 149 17 22.066 7689.15 72.97 224.19 6562.80 6644.30 2687.88 3287.33 2893.40 316.24 -2876.06 0.42 5970154.06 587548.26 N 70 19 41.859 W 149 17 23.878 7782.60 73.31 224.54 6589.90 6671.40 2713.08 3376.76 2949.41 252.31 -2938.60 0.51 5970089.38 587486.51 N 70 19 41.230 W 149 17 25.703 7876.18 73.98 225.04 6616.25 6697.75 2739.02 3466.55 3007.78 188.58 -3001.86 0.88 5970024.91 587424.03 N 70 19 40.603 W 149 17 27.549 7970.33 73.06 224.59 6642.96 6724.46 2765.14 3556.83 3068.02 124.54 -3065.49 1.08 5969960.11 587361.18 N 70 19 39.973 W 149 17 29.406 8062.98 73.48 224.52 6669.63 6751.13 2790.42 3645.56 3128.34 61.32 -3127.74 0.46 5969896.14 587299.70 N 70 19 39.351 W 149 17 31.222 8129.18 74.13 225.34 6688.09 6769.59 2808.93 3709.13 3172.68 16.31 -3172.64 1.54 5969850.60 587255.35 N 70 19 38.908 W 149 17 32.532 8230.93 74.15 223.63 6715.90 6797.40 2836.70 3807.01 3241.66 -53.52 -3241.22 1.62 5969779.96 587187.62 N 70 19 38.221 W 149 17 34.533 8261.94 74.21 224.14 6724.36 6805.86 2844.87 3836.84 3262.77 -75.02 -3261.90 1.59 5969758.21 587167.20 N 70 19 38.009 W 149 17 35.137 8292.45 74.77 224.30 6732.52 6814.02 2853.08 3866.24 3283.81 -96.09 -3282.41 1.90 5969736.90 587146.95 N 70 19 37.802 W 149 175 8322.57 75.17 224.09 6740.33 6821.83 2861.19 3895.33 3304.75 -116.95 -3302.68 1.49 5969715.80 587126.93 N 70 19 37.597 W 149 17 7 8355.09 78.66 224.44 6747.69 6829.19 2870.07 3927.00 3327.72 -139.63 -3324.79 10.78 5969692.86 587105.10 N 70 19 37.374 W 149 17 2 8386.05 82.26 225.08 6752.82 6834.32 2878.87 3957.53 3350.17 -161.30 -3346.29 11.81 5969670.93 587083.87 N 70 19 37.160 W 149 17 37.599 8417.85 84.60 224.58 6756.46 6837.96 2888.01 3989.12 3373.56 -183.70 -3368.56 7.52 5969648.26 587061.87 N 70 19 36.940 W 149 17 38.249 8448.81 89.30 224.60 6758.10 6839.60 2896.84 4020.03 3396.49 -205.71 -3390.25 15.18 5969625.99 5$7040.45 N 70 19 36.723 W 149 17 38.882 8479.34 91.39 224.63 6757.92 6839.42 2905.57 4050.55 3419.27 -227.45 -3411.69 6.85 5969604.01 587019.27 N 70 19 36.510 W 149 17 39.508 8508.48 94.86 225.97 6756.33 6837.83 2914.22 4079.65 3441.31 -247.91 -3432.37 12.76 5969583.30 586998.84 N 70 19 36.308 W 149 17 40.111 8539.84 94.80 223.64 6753.69 6835.19 2923.25 4110.90 3464.93 -270.08 -3454.39 7.41 5969560.87 586977.09 N 70 19 36.090 W 149 17 40.753 8571.76 96.71 226.10 6750.49 6831.99 2932.47 4142.65 3489.08 -292.58 -3476.79 9.73 5969538.10 586954.97 N 70 19 35.869 W 149 17 41.407 8601.96 97.98 224.40 6746.63 6828.13 2941.35 4172.60 3512.10 -313.67 -3498.07 6.99 5969516.76 586933.95 N 70 19 35.661 W 149 17 42.028 8632.77 97.32 223.17 6742.53 6824.03 2949.66 4203.14 3535.17 -335.71 -3519.19 4.50 5969494.46 586913.09 N 70 19 35.444 W 149 17 42.644 8673.32 95.33 223.09 6738.06 6819.56 2960.17 4243.44 3565.49 -365.13 -3546.75 4.91 5969464.72 586885.90 N 70 19 35.155 W 149 17 43.448 8703.61 94.65 222.60 6735.42 6816.92 2967.91 4273.62 3588.22 -387.25 -3567.27 2.76 5969442.35 586865.65 N 70 19 34.937 W 149 17 44.047 SurveyEditor Ver SP 1.0 Bld( doc40x_56) Plan V-112 (S-A)\V-112\V-112\V-112 Generated 3/21/2006 1:09 PM Page 3 of 4 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS 8734 .16 97.70 223.60 6732.14 6813.64 2975.82 4303.99 3611.30 -409.42 -3588. 01 10.50 5969419.93 586845.17 N 70 19 34.719 W 149 17 44.652 8764 .32 97.69 223.06 6728.10 6809.60 2983.72 4333.87 3634.19 -431.17 -3608. 52 1.77 5969397.95 586824.93 N 70 19 34.505 W 149 17 45.250 8795 .49 99.40 222.93 6723.47 6804.97 2991.69 4364.70 3657.79 -453.71 -3629. 54 5.50 5969375.16 586804.18 N 70 19 34.283 W 149 17 45.864 8826 .34 99.46 223.42 6718.41 6799.91 2999.66 4395.13 3681.26 -475.90 -3650. 37 1.58 5969352.71 586783.63 N 70 19 34.065 W 149 17 46.471 8857 .88 99.53 224.45 6713.21 6794.71 3008.20 4426.24 3705.61 -498.31 -3671. 95 3.23 5969330.06 586762.32 N 70 19 33.845 W 149 17 47.101 8888.20 99.57 224.03 6708.18 6789.68 3016.56 4456.14 3729.20 -519.73 -3692.81 1.37 5969308. 39 8919.16 99.40 223.72 6703.08 6784.58 3024.91 4486.67 3753.28 -541.74 -3713.97 1.13 5969286. 12 8949.31 99.28 224.90 6698.19 6779.69 3033.27 4516.42 3776.96 -563.03 -3734.76 3.88 5969264. 59 8980.81 99.24 225.35 6693.12 6774.62 3042.42 4547.51 3802.06 -584.96 -3756.79 1.42 5969242. 39 9011.72 99.02 225.28 6688.21 6769.71 3051.51 4578.03 3826.84 -606.42 -3778.49 0.75 5969220. 67 9042.66 98.93 225.58 6683.39 6764.89 3060.66 4608.59 3851.78 -627.87 -3800.26 1.00 5969198. 97 9073.61 97.33 224.42 6679.01 6760.51 3069.62 4639.23 3876.72 -649.53 -3821.92 6.36 5969177. 04 9104.35 97.05 224.67 6675.16 6756.66 3078.30 4669.73 3901.50 -671.27 -3843.31 1.22 5969155. 05 9134.94 97.05 224.55 6671.41 6752.91 3086.98 4700.09 3926.26 -692.88 -3864.63 0.39 5969133. 19 9167.67 96.80 224.80 6667.46 6748.96 3096.30 4732.58 3952.86 -715.99 -3887.48 1.08 5969109. 81 9198.88 96.51 224.96 6663.84 6745.34 3105.31 4763.58 3978.39 -737.95 -3909.35 1.06 5969087. 59 9229.83 97.02 225.38 6660.20 6741.70 3114.38 4794.31 4003.87 -759.62 -3931.15 2.13 5969065. 66 9260.64 97.76 225.88 6656.23 6737.73 3123.63 4824.87 4029.40 -780.99 -3952.99 2.89 5969044. 03 9291.57 97.39 225.66 6652.16 6733.66 3132.99 4855.53 4055.13 -802.37 -3974.96 1.39 5969022. 39 9321.97 97.18 226.34 6648.30 6729.80 3142.31 4885.68 4080.57 -823.32 -3996.65 2.32 5969001. 18 9352.55 96.71 225.97 6644.61 6726.11 3151.77 4916.04 4106.29 -844.35 -4018.54 1.95 5968979. 89 9383.99 97.78 226.80 6640.64 6722.14 3161.60 4947.23 4132.84 -865.86 -4041.12 4.29 5968958. 11 9414.83 97.57 227.08 6636.52 6718.02 3171.52 4977.79 4159.08 -886.73 -4063.45 1.13 5968936. 98 9445.86 97.21 225.88 6632.53 6714.03 3181.28 5008.56 4185.43 -907.92 -4085.77 4.01 5968915. 52 9478.20 97.07 226.54 6628.51 6710.01 3191.30 5040.65 4212.89 -930.13 -4108.93 2.07 5968893. 04 Last MWD+IFR+MS 9492.22 97.11 226.17 6626.78 6708.28 3195.69 5054.56 4224.84 -939.73 -4119.00 2.63 5968883. 32 TD (Projected) 9538.00 97.11 226.17 6621.11 6702.61 3209.85 5099.99 4263.85 -971.19 -4151.77 0.00 5968851. 47 Survey Type: Definitive Survey NOTES: GYD-GC-MS - (Gyrodata -gyro compassing m/s -- Older Gyrodata gyro multishot s-plus all battery/memory tool surveys (RGS-BT). Replaces ex-BP "Gyrodata multishot into open hole" mo del. Not to be run above 70 degrees inclination.. ) MWD +IFR + MS - (In-field referen ced MWD with mutt-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 4626 FSL 1876 FEL S11 Ti 1 N Ri 1 E UM 5969872.53 590427.66 BHL : 3654 FSL 749 FEL S10 Ti 1 N R11 E UM 5968851.47 586288.28 586741.72 N 70 19 33.634 W 149 17 47.709 586720.83 N 70 19 33.417 W 149 17 48.327 586700.31 N 70 19 33.208 W 149 17 48.933 586678.54 N 70 19 32.992 W 149 17 49.576 586657.11 N 70 19 32.781 W 149 17 50.209 586635.60 586614.20 586593.07 586572.01 586549.45 586527.85 586506.31 586484.73 586463.03 586441.59 586419.96 586397.64 586375.56 586353.51 586330.62 586320.67 586288.28 N 70 19 32.570 W 149 1 4 N 70 19 32.356 W 149 17 476 N 70 19 32.143 W 149 17 52.100 N 70 19 31.930 W 149 17 52.722 N 70 19 31.703 W 149 17 53.389 N 70 19 31.486 W 149 17 54.027 N 70 19 31.273 W 149 17 54.663 N 70 19 31.063 W 149 17 55.300 N 70 19 30.853 W 149 17 55.941 N 70 19 30.646 W 149 17 56.574 N 70 19 30.439 W 149 17 57.212 N 70 19 30.228 W 149 17 57.871 N 70 19 30.022 W 149 17 58.523 N 70 19 29.814 W 149 17 59.174 N 70 19 29.595 W 149 17 59.849 N 70 19 29.501 W 149 18 0.143 N 70 19 29.191 W 149 18 1.099 I ~ SurveyEditor Ver SP 1.0 Bld( doc40x_56) Plan V-112 (S-A)\V-112\V-112\V-112 Generated 3/21/2006 1:09 PM Page 4 of 4 TREE _ . WELLHEAD = -. FMC GEN 5 ACTUATOR = It6. ELEV = 82.30' BF. ELEV - 55.90' KOP = 400 Max Angle = 100 @ 8858' Datum MD = 7818' batum TV D = 6600' SS TuFi I20" CONDUCTOR 9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" V ~ 112 S NOTES: 70° @ 7365' -f 2220' I-14-1/2" HES X NIP, ID = 3.813" 101' 3003' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3196 3020 24 KBG-2 DMY BK 0 03/05/06 3 4843 4515 25 KBG-2 DCK BEK 0 03/05/06 WATER INJECTION MANDRELS 7" CSG, 26#, L-80 TCiI, tD = 6.276" ~-~ 4153' Minimum ID = 2.$13" @ 7520' BAKER CMD SLIDING SLEEVE ~4-112" TBG, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" ( 3-112" TBG, 9.2#, L-80 TCII, .0087 bpf, ID = 2.992" ~ 8056' 7" CSG, 26#, L-80 BTGM, ID = 6.276" ~ $193' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 74 @ 7550' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-718" 5 7550 - 7620 O 03(04!06 2-718" 5 7632 - 7660 O 03/04!06 2-7/8" 5 7680 - 7706 O 03/04/06 2-7/8" 5 7745 - 7770 O 03/04/06 4-1/2" 6 9140 - 9190 O 03/04/06 4-1/2" 6 9250 - 9290 O 03104!06 4-1/2" 6 9320 - 9375 O 03/04/06 4-1/2" 6 9410 - 9438 O 03/04/06 PBTD 9450' 4-1/2" LNR, 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" 953$' ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 7430 7491 6570 6587 73 74 MMG-W MMG-W DMY DMY RK RK 0 0 03!05!06 5219' -~ HES ES CEMENTER STA GE TOOL I 7308' 7" MARKER JOINT w IRA TAG 7359' 4-1/2" HES X NIP, ID = 3.813" 7380' 7" X 4-1/2" BKR PRM PROD PKR, ID = 3.875" 7408' 4-1/2" HES X NIP, ID = 3.813" 7419' 4-112" X 3-1 /2" XO, ID = 2.992" 7520' BKR CMD SLIDING SLV, ID = 2.813" 8011' 3-112" HES X NIP; ID = 2.813" 0142' 7" X 5" BKR ZXP LNR TOP PKR, FLEX-LOK LNR HNGR & TBS, ID = 4.400 8056' LOCATOR &BKR SPACER TUBE, ID = 3.00" 8(969' 4-1/2" BKR SEAL BORE EXT, ID = 4.00" 8077' BKR BONDED SEAL ASSY, ID - 3.00" 8426' RA TAG DATE REV BY COMMENTS DATE REV BY COMMENTS 03/07/06 N9ES ORIG9NAL COM PLETtON 03!18/06 ???/TLH DRLGDRAFTCORRECTIONS BOREALIS UNff WELL: V-112 PERMff No: °2060200 API No: 50-029-23300-00 SEC 11, T11N, R11E, 4627' FSL, 1876' FEL BP Exploration (Alaska) SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ....................: Borealis Well .....................: V-112 API number ...............: 50-029-23300-00 Engineer .................: St. Amour Rig :.....................: Nabors 9ES STATE :...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 52.60 ft KB above permanent.......: N/A (TopDrive) DF above permanent.......: 81.50 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 226.00 degrees 2-Mar-2006 14:41:13 Page 1 of 6 Spud date ................: 17-Feb-06 Last survey date.........: 02-Mar-06 Total accepted surveys...: 132 MD of first survey.......: 0.00 ft MD of last survey........: 9538.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2005 Magnetic date ............: 17-Feb-2006 Magnetic field strength..: 1151.60 HCNT Magnetic dec (+E/W-).....: 24.34 degrees Magnetic dip .............: 80.84 degrees ----- MWD survey Reference Reference G ..............: Reference H ............... Reference Dip ............: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 meal 1151.60 HCNT 80.84 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.34 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.34 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • r SCHLUMBERGER Survey Report 2-Mar-2006 14:41:13 Page 2 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.28 194.49 100.00 100.00 0.21 -0.24 -0.06 0.24 194.49 0.28 BP GYD CT DMS 3 200.00 0.54 195.09 100.00 200.00 0.82 -0.93 -0.24 0.96 194.78 0.26 BP _ _GYD CT DMS 4 300.00 0.76 198.18 100.00 299.99 1.81 -2.01 -0.57 2.09 195.93 0.22 BP GYD CT DMS 5 400.00 2.56 232.85 100.00 399.95 4.62 -3.99 -2.56 4.74 212.69 1.98 BP _ GYD CT DMS 6 500.00 4.60 242.38 100.00 499.75 10.68 -7.20 -7.90 10.69 227.64 2.12 BP GYD CT DMS 7 600.00 6.90 247.83 100.00 599.24 20.11 -11.33 -17.01 20.44 236.34 2.36 BP _ GYD CT DMS 8 700.00 9.08 251.86 100.00 698.26 32.78 -16.05 -30.08 34.09 241.91 2.25 BP _ GYD CT DMS 9 800.00 11.22 254.38 100.00 796.69 48.45 -21.13 -46.95 51.48 245.77 2.19 BP _ GYD CT DMS 10 900.00 12.09 257.41 100.00 894.63 65.94 -26.03 -66.54 71.45 248.63 1.06 BP _ GYD CT DMS 11 944.22 12.38 262.35 44.22 937.85 73.71 -27.67 -75.75 80.65 249.93 2.46 BP MWD+IFR+MS 12 1037.18 13.37 273.68 92.96 1028.48 88.98 -28.31 -96.36 100.43 253.63 2.91 BP _ MWD+IFR+MS 13 1130.16 14.54 285.59 92.98 1118.74 102.13 -24.48 -118.34 120.84 258.31 3.33 BP _ MWD+IFR+MS 14 1224.15 14.44 296.33 93.99 1209.75 112.05 -16.11 -140.21 141.13 263.45 2.86 BP _ MWD+IFR+MS 15 1317.35 15.62 298.94 93.20 1299.76 119.64 -4.88 -161.60 161.68 268.27 1.46 BP _ MWD+IFR+MS 16 1411.01 16.46 301.18 93.66 1389.78 126.73 8.09 -183.99 184.17 272.52 1.11 BP MWD+IFR+MS 17 1504.06 18.64 300.28 93.05 1478.49 134.13 22.41 -208.11 209.32 276.15 2.36 BP _ MWD+IFR+MS 18 1597.99 22.95 298.95 93.93 1566.28 143.58 38.85 -237.12 240.28 279.31 4.62 BP _ MWD+IFR+MS 19 1691.38 23.30 298.73 93.39 1652.17 154.40 56.55 -269.24 275.12 281.86 0.39 BP _ MWD+IFR+MS 20 1785.04 22.44 298.04 93.66 1738.46 165.41 73.85 -301.27 310.19 283.77 0.96 BP _ MWD+IFR+MS 21 1878.75 23.36 297.83 93.71 1824.79 176.72 90.93 -333.48 345.66 285.25 0.99 BP MWD+IFR+MS 22 1972.03 25.23 299.77 93.28 1909.80 188.04 109.44 -367.10 383.06 286.60 2.18 BP _ MWD+IFR+MS 23 2067.68 24.92 299.73 95.65 1996.44 199.39 129.56 -402.29 422.64 287.85 0.32 BP _ MWD+IFR+MS 24 2160.26 24.44 300.20 92.58 2080.56 210.06 148.86 -435.78 460.50 288.86 0.56 BP _ MWD+IFR+MS 25 2253.23 24.11 300.38 92.97 2165.31 220.41 168.14 -468.78 498.03 289.73 0.36 BP _ MWD+IFR+MS 26 2344.22 25.55 298.85 90.99 2247.89 231.20 187.01 -502.00 535.71 290.43 1.73 BP MWD+IFR+MS 27 2437.24 25.16 299.50 93.02 2331.95 242.74 206.42 -536.79 575.11 291.03 0.52 BP _ MWD+IFR+MS 28 2530.28 24.95 299.23 93.04 2416.23 254.02 225.75 -571.12 614.12 291.57 0.26 BP _ MWD+IFR+MS 29 2621.92 24.65 298.80 91.64 2499.42 265.24 244.39 -604.74 652.25 292.01 0.38 BP _ MWD+IFR+MS 30 2716.27 24.23 298.46 94.35 2585.32 276.90 263.10 -639.00 691.04 292.38 0.47 BP _ MWD+IFR+MS • • SCHLUMBERGER Survey Report 2-Mar-2006 14:41:13 Page 3 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At ----- DLS - ---- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (f t) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2809.20 25.63 299.30 92.93 2669.59 288.42 282.02 -673.29 729.97 292.73 1.55 BP MWD+IFR+MS 32 2901.69 25.45 299.34 92.49 2753.04 299.86 301.55 -708.06 769.60 293.07 0.20 BP _ MWD+IFR+MS 33 2951.61 25.15 298.58 49.92 2798.17 306.12 311.88 -726.73 790.82 293.23 0.89 BP _ MWD+IFR+MS 34 3038.12 24.91 298.47 86.51 2876.56 317.11 329.36 -758.89 827.27 293.46 0.28 BP _ MWD+IFR+MS 35 3091.05 24.66 296.81 52.93 2924.61 324.09 339.65 -778.54 849.40 293.57 1.40 BP _ MWD+IFR+MS 36 3184.51 24.34 295.60 93.46 3009.66 337.22 356.77 -813.31 888.12 293.69 0.64 BP MWD+IFR+MS 37 3278.43 24.07 294.53 93.92 3095.32 350.97 373.08 -848.19 926.62 293.74 0.55 BP _ MWD+IFR+MS 38 3373.09 23.93 294.03 94.66 3181.80 365.22 388.91 -883.29 965.11 293.76 0.26 BP _ MWD+IFR+MS 39 3467.54 25.10 296.15 94.45 3267.73 379.19 405.54 -918.77 1004.29 293.82 1.55 BP _ MWD+IFR+MS 40 3561.23 25.48 299.35 93.69 3352.45 391.71 424.18 -954.17 1044.21 293.97 1.51 BP _ MWD+IFR+MS 41 3655.74 25.22 299.29 94.51 3437.86 403.33 443.99 -989.45 1084.50 294.17 0.28 BP MWD+IFR+MS 42 3749.87 24.82 299.00 94.13 3523.15 414.87 463.38 -1024.22 1124.17 294.34 0.44 BP _ MWD+IFR+MS 43 3845.03 24.80 298.72 95.16 3609.53 426.64 482.66 -1059.19 1163.98 294.50 0.13 BP _ MWD+IFR+MS 44 3938.79 24.48 299.13 93.76 3694.75 438.11 501.56 -1093.41 1202.95 294.64 0.39 BP _ MWD+IFR+MS 45 4033.71 24.32 298.93 94.92 3781.20 449.56 520.59 -1127.69 1242.06 294.78 0.19 BP _ MWD+IFR+MS 46 4128.48 24.27 298.71 94.77 3867.57 461.08 539.39 -1161.85 1280.95 294.90 0.11 BP MWD+IFR+MS 47 4223.86 23.79 299.41 95.38 3954.69 472.39 558.25 -1195.80 1319.69 295.03 0.59 BP _ MWD+IFR+MS 48 4318.20 25.10 297,05 94.34 4040.57 484.33 576.70 -1230.20 1358.67 295.12 1.73 BP _ MWD+IFR+MS 49 4412.85 25.47 296.94 94.65 4126.15 497.49 595.05 -1266.22 1399.07 295.17 0.39 BP _ MWD+IFR+MS 50 4506.54 25.52 296.96 93.69 4210.72 510.65 613.32 -1302.17 1439.38 295.22 0.05 BP _ MWD+IFR+MS 51 4601.65 25.15 295.90 95.11 4296.68 524.28 631.44 -1338.61 1480.07 295.25 0.62 BP MWD+IFR+MS 52 4693.61 24.90 296.19 91.96 4380.01 537.56 648.52 -1373.56 1518.97 295.27 0.30 BP _ MWD+IFR+MS 53 4787.41 24.95 296.08 93.80 4465.07 550.99 665.93 -1409.05 1558.49 295.30 0.07 BP _ MWD+IFR+MS 54 4881.49 24.95 296.08 94.08 4550.37 564.51 683.38 -1444.70 1598.17 295.32 0.00 BP _ MWD+IFR+MS 55 4978.50 25.11 297.57 97.01 4638.27 577.99 701.90 -1481.32 1639.20 295.35 0.67 BP _ MWD+IFR+MS 56 5072.23 25.12 297.39 93.73 4723.14 590.63 720.26 -1516.62 1678.96 295.40 0.08 BP MWD+IFR+MS 57 5166.54 24.83 296.91 94.31 4808.63 603.49 738.43 -1552.05 1718.76 295.44 0.38 BP _ MWD+IFR+MS 58 5260.27 24.53 296.28 93.73 4893.80 616.49 755.95 -1587.04 1757.89 295.47 0.43 BP _ MWD+IFR+MS 59 5353.48 24.38 295.66 93.21 4978.65 629.71 772.85 -1621.73 1796.47 295.48 0.32 BP _ MWD+IFR+MS 60 5446.87 24.53 296.79 93.39 5063.66 642.79 789.93 -1656.41 1835.13 295.50 0.53 BP _ MWD+IFR+MS • • SCHLUMBERGER Survey Report 2-Mar-2006 14:41:13 Page 4 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (f t) (f t) (ft) (ft) (deg) 100f) type (deg) 61 5540.39 24.38 297.26 93.52 5148.79 655.38 807.52 -1690.90 1873.83 295.53 0.26 BP MWD+IFR+MS 62 5633.65 24.20 296.23 93.26 5233.79 668.03 824.79 -1725.16 1912.18 295.55 0.49 BP _ MWD+IFR+MS 63 5730.95 23.78 296.50 97.30 5322.69 681.32 842.35 -1760.60 1951.74 295.57 0.45 BP _ _MWD+IFR+MS 64 5820.56 24.42 292.05 89.61 5404.50 694.87 857.37 -1793.94 1988.29 295.54 2.15 BP MWD+IFR+MS 65 5913.58 25.06 287.60 93.02 5488.98 712.05 870.55 -1830.55 2027.01 295.43 2.12 BP _ MWD+IFR+MS 66 6007.41 27.20 282.76 93.83 5573.23 733.26 881.30 -1870,41 2067.64 295.23 3.22 BP _MWD+IFR+MS 67 6100.13 28.77 277.21 92.72 5655.12 758.86 888.78 -1913.23 2109.59 294.92 3.28 BP - MWD+IFR+MS • 68 6193.31 29.88 267.64 93.18 5736.40 790.27 890.64 -1958.6 9 2151.67 294.45 5.16 BP MWD+IFR+MS 69 6287.63 28.82 258.25 94.32 5818.66 827.08 885.04 -2004.45 2191.14 293.82 5.00 BP _ _MWD+IFR+MS 70 6381.24 26.41 248.76 93.61 5901.64 865.38 872.89 -2045.97 2224.39 293.11 5.35 BP MWD+IFR+MS 71 6474.69 27.76 244.95 93.45 5984.85 905.14 856.15 -2085.06 2253.99 292.32 2.35 BP MWD+IFR+MS 72 6567.35 30.51 245.32 92.66 6065.77 947.75 837.19 -2125.99 2284.89 291.49 2.97 BP _ _MWD+IFR+MS 73 6663.08 36.73 244.85 95.73 6145.45 997.82 814.85 -2174.03 2321.72 290.55 6.50 BP _MWD+IFR+MS 74 6756.29 40.23 243.55 93.21 6218.41 1052.92 789.59 -2226.23 2362.10 289.53 3.85 BP MWD+IFR+MS 75 6849.99 45.15 243.49 93.70 6287.26 1113.48 761.27 -2283.07 2406.65 288.44 5.25 BP _ MWD+IFR+MS 76 6943.59 49.63 242.24 93.60 6350.61 1179.39 729.84 -2344.35 2455.33 287.29 4.89 BP _MWD+IFR+MS 77 7036.69 54.86 240.18 93.10 6407.60 1250.41 694.36 -2408.81 2506.89 286.08 5.88 BP _MWD+IFR+MS 78 7130.83 60.13 238.13 94.14 6458.18 1327.69 653.64 -2476.92 2561.71 284.78 5.89 BP MWD+IFR+MS 79 7222.74 65.71 237.16 91.91 6500.00 1407.81 609.85 -2546.01 2618.03 283.47 6.14 BP _ MWD+IFR+MS 80 7315.77 70.91 234.70 93.03 6534.38 1492.93 561.41 -2617.57 2677.09 282.11 6.11 BP _ MWD+IFR+MS 81 7408.60 72.44 227.99 92.83 6563.59 1580.61 506.39 -2686.32 2733.63 280.68 7.06 BP MWD+IFR+MS 82 7502.25 74.56 224.60 93.65 6590.19 1670.38 444.35 -2751.21 2786.86 279.17 4.14 BP _ _MWD+IFR+MS 83 7595.83 72.58 224.13 93.58 6616.66 1760.10 380.19 -2813.97 2839.53 277.69 2.17 BP _MWD+IFR+MS 84 7689.15 72.97 224.19 93.32 6644.30 1849.18 316.24 -2876.06 2893.40 276.27 0.42 BP _MWD+IFR+MS 85 7782.60 73.31 224.54 93.45 6671.40 1938.58 252.31 -2938.60 2949.41 274.91 0.51 BP MWD+IFR+MS 86 7876.18 73.98 225.04 93.58 6697.75 2028.35 188.58 -3001.86 3007.78 273.59 0.88 BP _MWD+IFR+MS 87 7970.33 73.06 224.59 94.15 6724.46 2118.61 124.54 -3065.49 3068.02 272.33 1.08 BP _MWD+IFR+MS 88 8062.98 73.48 224.52 92.65 6751.13 2207.31 61.32 -3127.74 3128.34 271.12 0.46 BP _MWD+IFR+MS 89 8129.18 74.13 225.34 66.20 6769.59 2270.88 16.31 -3172.64 3172.68 270.29 1.54 BP _MWD+IFR+MS 90 8230.93 74.15 223.63 101.75 6797.40 2368.71 -53.52 -3241.22 3241.66 269.05 1.62 BP MWD+IFR+MS SCHLUMBERGER Survey Report 2-Mar-2006 14:41:13 Page 5 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (f t) (deg) 100f) type (deg) 91 8261.94 74.21 224.14 31.01 6805.86 2398.53 -75.02 -3261.90 3262.77 268.68 1.59 BP MWD+IFR+MS 92 8292.45 74.77 224.30 30.51 6814.02 2427.91 -96.09 -3282.41 3283.81 268.32 1.90 BP _ MWD+IFR+MS 93 8322.57 75.17 224.09 30.12 6821.83 2456.99 -116.95 -3302.68 3304.75 267.97 1.49 BP _ MWD+IFR+MS 94 8355.09 78.66 224.44 32.52 6829.19 2488.64 -139.63 -3324.79 3327.72 267.60 10.78 BP _ MWD+IFR+MS 95 8386.05 82.26 225.08 30.96 6834.32 2519.16 -161.30 -3346.29 3350.17 267.24 11.81 BP _ MWD+IFR+MS 96 8417.85 84.60 224.58 31.80 6837.96 2550.75 -183.70 -3368.56 3373.56 266.88 7.52 BP MWD+IFR+MS 97 8448.81 89.30 224.60 30.96 6839.60 2581.64 -205.71 -3390.25 3396.49 266.53 15.18 BP _ • MWD+IFR+MS 98 8479.34 91.39 224.63 30.53 6839.42 2612.16 -227.45 -3411.69 3419.27 266.19 6.85 BP - MWD+IFR+MS 99 8508.48 94.86 225.97 29.14 6837.83 2641.25 -247.91 -3432.37 3441.31 265.87 12.76 BP _ MWD+IFR+MS 100 8539.84 94.80 223.64 31.36 6835.19 2672.49 -270.08 -3454.39 3464.93 265.53 7.41 BP _ MWD+IFR+MS 101 8571.76 96.71 226.10 31.92 6831.99 2704.24 -292.58 -3476.79 3489.08 265.19 9.73 BP MWD+IFR+MS 102 8601.96 97.98 224.40 30.20 6828.13 2734.19 -313.67 -3498.06 3512.10 264.88 6.99 BP _ MWD+IFR+MS 103 8632.77 97.32 223.17 30.81 6824.03 2764.70 -335.71 -3519.19 3535.17 264.55 4.50 BP _ MWD+IFR+MS 104 8673.32 95.33 223.09 40.55 6819.56 2804.95 -365.13 -3546.75 3565.49 264.12 4.91 BP _ MWD+IFR+MS 105 8703.61 94.65 222.60 30.29 6816.92 2835.08 -387.25 -3567.27 3588.22 263.80 2.76 BP _ MWD+IFR+MS 106 8734.16 97.70 223.60 30.55 6813.64 2865.41 -409.42 -3588.01 3611.30 263.49 10.50 BP MWD+IFR+MS 107 8764.32 97.69 223.06 30.16 6809.60 2895.27 -431.17 -3608.52 3634.19 263.19 1.77 BP _ MWD+IFR+MS 108 8795.49 99.40 222.93 31.17 6804.97 2926.05 -453.71 -3629.54 3657.79 262.87 5.50 BP _ MWD+IFR+MS 109 8826.34 99.46 223.42 30.85 6799.91 2956.44 -475.90 -3650.37 3681.26 262.57 1.58 BP _ MWD+IFR+MS 110 8857.88 99.53 224.45 31.54 6794.71 2987.53 -498.31 -3671.95 3705.61 262.27 3.23 BP _ MWD+IFR+MS 111 8888.20 99.57 224.03 30.32 6789.68 3017.42 -519.73 -3692.81 3729.20 261.99 1.37 BP MWD+IFR+MS 112 8919.16 99.40 223.72 30.96 6784.58 3047.93 -541.74 -3713.97 3753.28 261.70 1.13 BP _ MWD+IFR+MS 113 8949.31 99.28 224.90 30.15 6779.69 3077.67 -563.03 -3734.76 3776.96 261.43 3.88 BP _ MWD+IFR+MS 114 8980.81 99.24 225.35 31.50 6774.62 3108.75 -584.96 -3756.79 3802.06 261.15 1.42 BP MWD+IFR+MS 115 9011.72 99.02 225.28 30.91 6769.71 3139.27 -606.42 -3778.49 3826.84 260.88 0.75 BP _ MWD+IFR+MS 116 9042.66 98.93 225.58 30.94 6764.89 3169.83 -627.87 -3800.26 3851.78 260.62 1.00 BP MWD+IFR+MS 117 9073.61 97.33 224.42 30.95 6760.51 3200.46 -649.53 -3821.92 3876.72 260.35 6.36 BP _ MWD+IFR+MS 118 9104.35 97.05 224.67 30.74 6756.66 3230.95 -671.27 -3843.31 3901.50 260.09 1.22 BP _ MWD+IFR+MS 119 9134.94 97.05 224.55 30.59 6752.91 3261.30 -692.88 -3864.64 3926.26 259.84 0.39 BP _ MWD+IFR+MS 120 9167.67 96.80 224.80 32.73 6748.96 3293.78 -715.99 -3887.48 3952.86 259.56 1.08 BP _ MWD+IFR+MS SCHLUMBERGER Survey Report 2-Mar-2006 14:41:13 Page 6 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (f t) (deg) (deg) (ft) (f t) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 121 9198.88 96.51 224.96 31.21 6745.34 3324.78 -737.95 -3909.35 3978.39 259.31 1.06 BP MWD+IFR+MS 122 9229.83 97.02 225.38 30.95 6741.70 3355.51 -759.62 -3931.15 4003.87 259.06 2.13 _ BP MWD+IFR+MS 123 9260.64 97.76 225.88 30.81 6737.73 3386.06 -780.99 -3952.99 4029.40 258.82 2.89 _ BP MWD+IFR+MS 124 9291.57 97.39 225.66 30.93 6733.66 3416.72 -802.37 -3974.96 4055.13 258.59 1.39 _ BP MWD+IFR+MS 125 9321.97 97.18 226.34 30.40 6729.80 3446.88 -823.32 -3996.65 4080.57 258.36 2.32 _ BP MWD+IFR+MS 126 9352.55 96.71 225.97 30.58 6726.10 3477.23 -844.35 -4018.54 4106.29 258.13 1.95 BP MWD+IFR+MS 127 9383.99 97.78 226.80 31.44 6722.14 3508.42 -865.86 -4041.12 4132.84 257.91 4.29 _ BP MWD+IFR+MS 128 9414.83 97.57 227.08 30.84 6718.02 3538.98 -886.73 -4063.45 4159.08 257.69 1.13 - BP MWD+IFR+MS 129 9445.86 97.21 225.88 31.03 6714.03 3569.75 -907.92 -4085.77 4185.43 257.47 4.01 _ BP MWD+IFR+MS 130 9478.20 97.07 226.54 32.34 6710.01 3601.84 -930.13 -4108.93 4212.89 257.25 2.07 _ BP MWD+IFR+MS 131 9492.22 97.11 226.17 14.02 6708.28 3615.75 -939.73 -4119.00 4224.84 257.15 2.63 BP MWD+IFR+MS 132 9538.00 97.11 226.17 45.78 6702.61 3661.18 -971.19 -4151.77 4263.85 256.83 0.00 _ Projected to TD [(0)2006 IDEAL ID10 2C O1] • • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: AOGCC -Librarian Well No V-112 Date Dispatched: 15-Mar-06 Nabors 9ES Dispatched By: Mauricio Perdomo Installation/Rig LWD Log Delivery V1.1,10-02-03 Data No Of Prints No of Floppies Surveys 2 1 Received By: Please sign and return to: Drilling & Measurements LWD Division 2525 Gambell Street, Suite 400 Anchorage, Alaska 99501 nrosei~slb.com Fax:907-561-8317 • Terries We agree with your concerns. We'll cancell the 206-034 permit, 50 029 23300 O1 api number and V-112A well name. For your information, we'll be simply reiussuing the original permit next time this happens. Thanks for your comments Bob Crandall Steve Davies Robert Fleckenstein wrote: -------- Original Message -------- Subject: Approved Revised Permit to Drill for V-112, PTD 206-034, 50-029-23300-01 Date: Mon, 13 Mar 2006 11:12:25 -0900 From: Hubble, Terrie L <Terrie.Hubble@bp.com> To: steve_davies@admin.state.ak.us CC: Gagliardi, Shane T <Shane.Gagliardi@bp.com>, bob fleckenstein@admin.state.ak.us Hi Steve, Bob Fleckenstein and I discussed the above mentioned Permit to Drill earlier today. He indicated that he would like the name changed to V-112A since a new Permit to Drill number and API extension number were assigned by the Commission. I had not picked up on the fact that a new number had been assigned when we received the approved revised Permit to Drill. We disagree with handling it in this manner. This is not an sidetracked well, which is what the -O1 indicates and the regulations do allow for sending in a revised Permit to Drill to extend the bottom hole location. We think that the name change would be confusing and inappropriate. It is our view that the Permit to Drill and API numbers should have remained the same as the originally approved Permit to Drill. (PTD 206-020). How can we rectify this? Your help would be greatly appreciated. Terrie 1 of 1 3/13/2006 1:36 PM 20 AAC 25.015 CHANGES TO A PROGRAM IN A PERMIT TO DRILL. (a) To change a program approved in a Permit to Drill (Form 10-401) before drilling operations start, the operator shall (1) submit and obtain the commission's approval of a new application for a Permit to Drill if the proposed surface location is changed, if the proposed bottom-hole location or the proposed location of an objective formation is changed by more than 500 feet laterally or vertically, or if the change requires a spacing exception under 20 AAC 25.055; however, no additional fee is required; or (2) otherwise notify the commission and obtain its approval of the change if the change is not covered by (1) of this subsection. (b) To change a program approved in a Permit to Drill or to change information under 20 AAC 25.005(c) after drilling operations start, the operator shall (1) submit and obtain the commission's approval of a new application for a Permit to Drill, accompanied by a fee of $100, if the proposed bottom-hole location or the proposed location of an objective formation is changed by more than 500 feet laterally or vertically, or if the change requires a spacing exception under 20 AAC 25.055; or (2) submit and obtain the commission's approval of an Application for Sundry Approvals (Form 10-403) if the change is not covered by (1) of this subsection; the Application for Sundry Approvals must set out the approved program, the current condition of the well, and the proposed changes; in cases where prompt approval is needed, oral approval may be requested from the commission; if oral approval is obtained, the name of the representative of the commission who provided oral approval and the date of the approval must be included on the Application for Sundry Approvals, which must be submitted within three days for final approval by the commission. History - Eff. 4/13/80, Register 74; am 4/2/86, Register 97; am 11/7/99, Register 152; am / / ,Register Authority. - AS 31.05.030 AS 31.05.090 • ~~ ~ ~' ;, ~ ~,,~ a~ j~ ~~ d ~ ~ ~ ~ ~ 1 ~ ~ ~; ~ 3 ~ 1 1 ~ ~ ~~ i t ~ ,~.~ ! I ~ a ALASSA OIL A1~TD GAS COI~TSERQATIOI~T COMD'IISSIOIQ Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, PBU V-112 BP Exploration (Alaska) Inc. Permit No: 206-034 Surface Location: 4627' FSL, 1876' FEL, SEC. 11, T 11 N, R 11 E, UM Bottomhole Location: 3655' FSL, 749' FEL, SEC. 10, T 11 N, R 11 E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Cathy P. Foerster ,~/,~ Commissioner DATED this 7" ~ day of March, 2006 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALA~IL AND GAS CONSERVATION COMM~N PERMIT TO DRILL 20 AAC 25.005 Revised: 03/06/06, Extend BHL 1 a. Type of work 1 b. Current Well Class ^ Exploratory ^ Development Gas 1 c. Specify if well is proposed for: ® Drill ^Redrill ®Service ^ Multiple Zone ^ Coalbed Methane ^ Gas Hydrates ^ Re-Entry ^ Stratigraphic Test ^ Development Oil ^ Single Zone ^ Shale Gas 2. Operator Name: 5. Bond: ®Blanket ^ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 PBU V-112 3. Address: 6. Proposed Depth: 12. Field /Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 9538 TVD 6703 Prudhoe Bay Field /Borealis Pool 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ADL 028241 4627' FSL 1876' FEL SEC 11 T11 N R11 E UM , , , , . , 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: ' ' February 20, 2006 FSL, 4518 FEL, SEC. 11, T11 N, R11 E, UM 5086 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 3655' FSL, 749' FEL, SEC. 10, T11 N, R11 E, UM 2560 5800' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Plan 15. Distance to Nearest Well Within Pool: Surface: x- 590428 y- 5969873 Zone- ASP4 (Height above GL): 81.5' feet 1780' from V-108 16. Deviated Wells: ~ Kickoff Depth: 600 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 2535) Maximum Hole Angle: 100 de rees Downhole: 3423 Surface: 2758m 18. Casin Pr ram: S ecifications T - Settin De th -Bottom Quanti of Cemen .f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin st data a ~ d o c'~ ~ ~ c~ 19. PRESENT WELL CONDITION S UMMARY (To be completed f or Redrill and Re-entry Operations) °'~ Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Ju (measure 9538 6703 None 9450 6714 h None Casin Len h Size Cement Volume MD ~ TVD Conductor /Structural Surface 110' 20" x 34" 60 sx Arctic Set A rox. 110' 110' Intermediate 9-5/8" 2974' 18 sx AS Lite, 150 sx'G', 73 sx'G' 3003' 2845' 7" 8167' 134 sx AS Lite, 20 sx AS Lite 145 sx 'G' 8193' 6787' Liner 4-1/2" 1496' 183 sx Class 'G' 9538' 6703' Perforation Depth MD (ft): 7550' - 9438' Perforation Depth TVD (ft): 6603' - 6715' 20. Attachments ®Filing Fee, $100 BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ~ Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Shane Gagliardi, 564-5251 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/Number. Si nature Phone 564-4166 Date ~~~ ~ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill - API Number: Permit Approval See cover letter for Number: - 50- OZ. -2,x.3 ~D --0;(.~ Date: .a ~ other requirements Conditions of Apprq~~~3~j ~%-"`^ " l ~ 1j ~~`• l i h d b ne s a es: ed methane, gas hydrates, or gas conta f ox c ecked, well may not be used to explore for, test, or produce coal Samples Req'd: ^ Yes~No Mud Log Req'd: ^ Yes ~No L ~7 H2S Measures: "'Yes ^ No Directional Survey Req'd: ~es ^ No ~ Other: l tiS ~l ~ O I C O 40 D O ~ Sa.. /1./l = r~ CP~r~v~ ~t t ~~ `O u-L Y'C ~ . d ~~ ~ ~ ~ . d s pn~~e ~~ ~ ~ ~r+ c zs. o ~ ~ L~ ~ C t J ~l ~-~ ~-e i3 0 ~ ~ ,s~- / ~ ~ ~ APPROVED BY THE COMMISSION 3 -q,-6 Date ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ' ~ ~ n , /~ Submit In Duplicate i • • To: Winton Aubert - AOGCC Date: March 3, 2006 From: Shane Gagliardi - BPXA GPB Rotary Drilling Subject: V-1121 Application for Permit to Drill -Extension API # 50-029-23300-00 Reference: During the drilling phase for the intermediate hole, an unanticipated fault was encountered at approximately 7,400' md. Initially this fault was thought to be of large enough magnitude that the proposed injection pattern would be compromised. The decision was made to extend the intermediate section of hole on the current plan beyond the additional proposed fault crossing in preparation for an open hole sidetrack. After further evaluation of the data, the shallower unplanned fault was deemed insignificant for the injection strategy. Intermediate TD was called 500' and deeper than the original plan but prior to the expected fault crossing. With the dip of the fault and the extension of the intermediate casing point, trFar- 'bottom hole location tolerance line was crossed. The actual bottom hole location is approximately 4 from the permitted location with ASP coordinates of Northing 5968851.47 and Easting ~- 586288.28. P to drilling the extended section all anti-collision issues were considered and verbal approval from the AOGCC was~ed. Planned versus actual plots are attached with the final corrected directional survey. 4 ' ~`"''`-a ~tilGvE' If you have any questions or require further information please give me a call. Shane Gagliardi Operations Drilling Engineer 564-5251 AGI-07A Application for Sundry KB. ELEV = 82.5' BF. ELEV = 54' KOP= Max Angle = 97 DEG @ 8337 Datum MD = Datum TV D = V-112i Proposed Completion ~ ~ Proposed TOC 3,830' 7", 26#, TCII to ~ 4,330' Surface TC-II,ID = 3.958", 7,439' 0.01522 BPF RA Tag in 7" 1 Jt 7,468' above TKUPC KupC Perfs ~7, 550 `-7, 770 ` TC-II, ID = 2.992", 8,053' 0.00870 B P F TREE = CM! 4-1/16 5M WELLHEAD = FMC Gen 5 CSG HEAD = 11" 5M W/ 7" MANDREL HANGER & PA CKOFF TBG SPOOL = 11" X 11" 5M TBG HANGER = 11" X 4-1/2" ADP FLANGE= 11"X4-1/16" 101' 20" X 34" 215.5 Ib/ft, A53 ERW Insulated 2,222' 4-1 /2" 'X' Landing Nipple, ID = 3.813" ~ 2,853' t-j9-5/8", 40 #/ft, L-80, BTC, ID = 8.835, 0.07583 B 3,167' Camco 4-1 /2" x 1" KBG-2 GLM 4,790' Camco 4-1 /2" x 1" KBG-2 pinned to 2,500 7,369' 4-1 /2" 'X' Landing Nipple, ID = 3.813" 7,390' 7" x 4-1 /2" Baker `PRM' Prod Pkr, ID = 3.875" 7,418' 4-1 /2" `XN' Landing Nipple, ID = 3.725" 7,439' 3-1 /2" TC-II x 4-1 /2" TC-II XO 7,451' Camco 3-1 /2" x 1-1 /2"MMG-W GLM 7,510' Camco 3-1/2" x 1-1 /2" MMG-W GLM 7,538' 3-1 /2" Baker CMD Sliding Sleeve, ID = 2.813" 8,010' 3-1 /2" 'X' Landing Nipple, ID = 2.813" 8,043' 7" x 4-1 /2" Baker Flex-Loc Liner Hanger (ID =2.992) w/ ZXP Liner Top Pkr w/ 10' TBS (ID = 5.25") 8,056' 4-1 /2" Baker SBR Assy w/ 4.0" Seal Diameter 8,193' 7', 26 #/ft, L-80, BTC-M, ID = 6.276", 0.0383 BPF TO TOC (cD, 4,330' RA Tag in 4-1 /2° 8,751' well inversion V-112i Estimated Perf Depths Zone MD TVDss Inc. Perf Int. Feet 7" String 7550 -6462 68 7550-7770 220 - nng - - Proposed KupC Perfs 9,458' 4-1/2" PBTD 9,140-9, 438 ` - - i 9,538' H4-1/2", 12.6#, L-80, IBT-M, ID = 3.958", 0.01522 BPF DATE REV BY COMMENTS DATE REV BY COMMENTS 01/12/06 MJM Original Completion 01/17/06 STG 03/03/06 STG Extension PRUDHOE BAY UNrf WELL: V-112i PERMrf No: 206-020 API No: 50-029-23300 SEC 11, T11 N, R11 E, 653' FNL, 1876' FEL BP Exploration (Alaska) Schlumberger BP Exploration Alaska ~~ V-112 ~~~ Prudhoe Bay Unit - WOA „~" ~~ V~ad • 1000 500 -500 • -1000 -1500 X000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 • • SChlumherger BP Exploration Alaska "` V-112 ~`~ Prudhoe Bay Unit - WOA .a~"u"`V-Pad 800 1600 2400 3200 4000 4800 5600 6400 0 800 1600 2400 3200 4000 4800 • V-112 Final Su Report Date: March 2, 2006 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure I Slot: V-Pad /Plan V-112 (S-A) Well: V-112 Rig: Nabors 9ES U W gAPI#: 50-029-23300-00 Survey Name 1 Date: V-112 I February 16, 2006 Tort I AHD 1 DDI I ERD ratio: 198.400° 15099.99 ft / 6.150 10.746 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaUlong: N 7019 38.754, W 14915 59.917 Location Grid WE YIX: N 5969872.530 ftUS, E 590427.660 ftUS Grid Convergence Angle: +0.69055612° Vertical Section Azimuth: 226.000° Vertical Section Ortgin: N 0.000 ft, E 0.000 ft ND Reference Datum: Rotary Table ND Reference Elevation: 81.5 ft relative to MSL Sea Ned 1 Ground Level Elevation: 54,000 ft relative to MSL Magnetk Declination: 24.136° Total Feld Strength: 57641.420 nT Magnetic Dip: 80.809° Declination Date: February 16, 2006 Magnetic Declination Model: GYRO&MWD+IFR+GMAG North Reference: True North Total Corr Mag North -> True North: +24.136° Measured Vertical Survey Tool Comments Inclina8on Azimuth ND NS EW DLS Northing Fasting Latitude Longhude DapM Secton Model ft d de ft ft ft ft de t00ft ftUS ftUS I le-Irl U.VV U.UV U.UV V.UV V.UV U.UU U.UU U.UU b`Jb`JC/Y.SJ b`JU4Z /.bb N /U 18 Jtf./54 VV 14`J lb b`J.`Jl / 100.00 0.28 194.49 100.00 0.21 -0.24 -0.06 0.28 5969872.29 590427.60 N 70 19 38.752 W 149 15 59.918 200.00 0.54 195.09 200.00 0.82 -0.93 -0.24 0.26 5969871.60 590427.43 N 70 19 38.745 W 149 15 59.924 300.00 0.76 198.18 299.99 1.81 -2.01 -0.57 0.22 5969870.51 590427.11 N 70 19 38.734 W 149 15 59.933 400.00 2.56 232.85 399.95 4.62 -3.99 -2.56 1.98 5969868.51 590425.15 N 70 19 38.715 W 149 15 59.991 500.00 4.60 242.38 499.75 10.68 -7.20 -7.90 2.12 5969865.24 590419.85 N 70 19 38.683 W 149 16 0.147 600.00 6.90 247.83 599.24 20.11 -11.33 -17.01 2.36 5969861.00 590410.79 N 70 19 38.643 W 149 16 0.413 700.00 9.08 251.86 698.26 32.78 -16.05 -30.08 2.25 5969856.12 590397.78 N 70 19 38.596 W 149 16 0.794 800.00 11.22 254.38 796.69 48.45 -21.13 -46.95 2.19 5969850.84 590380.98 N 70 19 38.546 W 149 16 1.287 900.00 12.09 257.41 894.63 65.94 -26.03 -66.54 1.06 5969845.70 590361.45 N 70 19 38.498 W 149 16 1.859 944.22 12.38 262.35 937.85 73.71 -27.67 -75.75 2.46 5969843.95 590352.25 N 70 19 38.482 W 149 16 2.128 1037.18 13.37 273.68 1028.48 88.98 -28.31 -96.36 2.91 5969843.07 590331.66 N 70 19 38.476 W 149 16 2.729 1130.16 14.54 285.59 1118.74 102.13 -24.48 -118.34 3.33 5969846.63 590309.64 N 70 19 38.513 W 149 16 3.371 1224.15 14.44 296.33 1209.75 112.05 -16.11 -140.21 2.86 5969854.73 590287.67 N 70 19 38.596 W 149 16 4.009 1317.35 15.62 298.94 1299.76 119.64 -4.88 -161.60 1.46 5969865.70 590266.14 N 70 19 38.706 W 149 16 4.634 1411.01 16.46 301.18 1389.78 126.73 8.09 -183.99 1.11 5969878.40 590243.60 N 70 19 38.834 W 149 16 5.288 1504.06 18.64 300.28 1478.49 134.14 22.41 -208.11 2.36 5969892.43 590219.31 N 70 19 38.975 W 149 16 5.992 1597.99 22.95 298.95 1566.28 143.58 38.85 -237.12 4.62 5969908.52 590190.12 N 70 19 39.136 W 149 16 6.838 1691.38 23.30 298.73 1652.17 154.40 56.55 -269.24 0.39 5969925.82 590157.78 N 70 19 39.310 W 149 16 7.776 1785.04 22.44 298.04 1738.46 165.41 73.85 -301.27 0.96 5969942.74 590125.55 N 70 19 39.480 W 149 16 8.711 1878.75 23.36 297.83 1824.79 176.72 90.93 -333.48 0.99 5969959.43 590093.14 N 70 19 39.648 W 149 16 9.652 1972.03 25.23 299.77 1909.80 188.04 109.44 -367.10 2.18 5969977.53 590059.31 N 70 19 39.830 W 149 16 10.633 2067.68 24.92 299.73 1996.44 199.39 129.56 -402.29 0.32 5969997.22 590023.88 N 70 19 40.028 W 149 16 11.660 2160.26 24.44 300.20 2080.56 210.06 148.86 -435.78 0.56 5970016.12 589990.16 N 70 19 40.218 W 149 16 12.638 2253.23 24.11 300.38 2165.31 220.41 168.14 -468.78 0.36 5970034.99 589956.93 N 70 19 40.408 W 149 16 13.602 2344.22 25.55 298.85 2247.89 231.21 187.01 -502.00 1.73 5970053.46 589923.48 N 70 19 40.593 W 149 16 14.571 2437.24 25.16 299.50 2331.95 242.74 206.42 -536.79 0.52 5970072.45 589888.48 N 70 19 40.784 W 149 16 15.587 2530.28 24.95 299.23 2416.23 254.02 225.75 -571.12 0.26 5970091.36 589853.91 N 70 19 40.974 W 149 16 16.589 2621.92 24.65 298.80 2499.42 265.24 244.39 -604.74 0.38 5970109.59 589820.08 N 70 19 41.157 W 149 16 17.571 2716.27 24.23 298.46 2585.32 276.90 263.10 -639.00 0.47 5970127.88 589785.59 N 70 19 41.341 W 149 16 18.571 2809.20 25.63 299.30 2669.59 288.42 282.02 -673.29 1.55 5970146.39 589751.08 N 70 19 41.527 W 149 16 19.572 2901.69 25.45 299.34 2753.04 299.87 301.55 -708.06 0.20 5970165.49 589716.08 N 70 19 41.719 W 149 16 20.587 2951.61 25.15 298.58 2798.17 306.12 311.88 -726.73 0.89 5970175.60 589697.29 N 70 19 41.821 W 149 16 21.132 3038.12 24.91 298.47 2876.56 317.11 329.36 -758.89 0.28 5970192.69 589664.93 N 70 19 41.993 W 149 16 22.071 3091.05 24.66 296.81 2924.61 324.09 339.65 -778.54 1.40 5970202.74 589645.16 N 70 19 42.094 W 149 16 22.645 3184.51 24.34 295.60 3009.66 337.22 356.77 -813.31 0.64 5970219.44 589610.18 N 70 19 42.262 W 149 16 23.660 3278.43 24.07 294.53 3095.32 350.97 373.08 -848.19 0.55 5970235.33 589575.11 N 70 19 42.423 W 149 16 24.678 3373.09 23.93 294.03 3181.80 365.22 388.91 -883.29 0.26 5970250.73 589539.83 N 70 19 42.579 W 149 16 25.703 3467.54 25.10 296.15 3267.73 379.19 405.54 -918.77 1.55 5970266.93 589504.16 N 70 19 42.742 W 149 16 26.739 3561.23 25.48 299.35 3352.45 391.71 424.18 -954.17 1.51 5970285.14 589468.54 N 70 19 42.925 W 149 16 27.772 3655.74 25.22 299.29 3437.86 403.33 443.99 -989.45 0.28 5970304.53 589433.02 N 70 19 43.120 W 149 16 28.802 3749.87 24.82 299.00 3523.15 414.87 463.38 -1024.22 0.44 5970323.49 589398.02 N 70 19 43.311 W 149 16 29.817 3845.03 24.80 298.72 3609.53 426.64 482.66 -1059.19 0.13 5970342.34 589362.83 N 70 19 43.500 W 149 16 30.838 3938.79 24.48 299.13 3694.75 438.12 501.56 -1093.41 0.39 5970360.83 589328.39 N 70 19 43.686 W 149 16 31.837 4033.71 24.32 298.93 3781.20 449.56 520.59 -1127.69 0.19 5970379.45 589293.88 N 70 19 43.873 W 149 16 32.838 4128.48 24.27 298.71 3867.57 461.08 539.39 -1161.85 0.11 5970397.83 589259.50 N 70 19 44.058 W 149 16 33.836 4223.86 23.79 299.41 3954.69 472.40 558.25 -1195.80 0.59 5970416.28 589225.33 N 70 1944.244 W 149 16 34.827 4318.20 25.10 297.05 4040.57 484.33 576.70 -1230.20 1.73 5970434.30 589190.71 N 70 19 44.425 W 149 16 35.831 4412.85 25.47 296.94 4126.15 497.49 595.05 -1266.22 0.39 5970452.22 589154.47 N 70 19 44.605 W 149 16 36.883 BP_GYD CT DMS BP_GYD CT DMS BP_GYD CT DMS BP_GYD CT DMS BP_GYD CT DMS BP_GYD CT DMS BP_GYD CT DMS BP_GYD CT DMS BP GYD CT DMS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP MWD+IFR+MS BP_MWD+IFR+MS BP MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP MWD+IFR+MS BP_MWD+IFR+MS BP MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP MWD+IFR+MS BP MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP MWD+IFR+MS Page 1 of 3 • Comments Measured Inclinatlon Azimuth TVD Vertical NS EW DLS Northing Easdng Latitude Longitude Survey Tool Depth Section Model k de de fl k fl ft de 100 k kUS kUS +.iJV..i+ cJ.JC cav.av +c lv./c JIV.VV VIJ.JG -IJVG.I/ U.UJ V~/V4/V.UO JO`11 IO.JI IV /V 1y 44./8J VV 14y IO J/.`JJJ LSF' MVV V~IrRTMJ 4601.65 25.15 295.90 4296.68 524.28 631.44 -1338.61 0.62 5970487.73 589081.66 N 70 19 44.963 W 149 16 38.997 BP_MWD+IFR+MS 4693.61 24.90 296.19 4380.01 537.56 648.52 -1373.56 0.30 5970504.39 589046.51 N 70 19 45.131 W 149 16 40.017 BP_MWD+IFR+MS 4787.41 24.95 296.08 4465.07 550.99 665.93 -1409.05 0.07 5970521.37 589010.81 N 70 19 45.302 W 149 16 41.053 BP_MWD+IFR+MS 4881.49 24.95 296.08 4550.37 564.51 683.38 -1444.70 0.00 5970538.38 588974.97 N 70 19 45.474 W 149 16 42.094 BP_MWD+IFR+MS 4978.50 25.11 297.57 4638.27 577.99 701.90 -1481.32 0.67 5970556.46 588938.12 N7O1945.656 W1491643.163 BP MWD+IFR+MS 5072.23 25.12 297.39 4723.14 590.63 720.26 -1516.62 0.08 5970574.39 588902.61 N7O1945.836 W1491644.194 BP_MWD+IFR+MS 5166.54 24.83 296.91 4808.63 603.49 738.43 -1552.05 0.38 5970592.13 588866.97 N 70 19 46.015 W 149 16 45.228 BP_MWD+IFR+MS 5260.27 24.53 296.28 4893.80 616.50 755.95 -1587.04 0.43 5970609.23 588831.77 N 70 19 46.187 W 149 16 46.250 BP_MWD+IFR+MS 5353.48 24.38 295.66 4978.65 629.71 772.85 -1621.73 0.32 5970625.71 588796.88 N 70 19 46.353 W 149 16 47.263 BP_MWD+IFR+MS 5446.87 24.53 296.79 5063.66 642.79 789.93 -1656.41 0.53 5970642.37 588762.00 N7O1946.521 W1491648.276 BP MWD+IFR+MS 5540.39 24.38 297.26 5148.79 655.38 807.52 -1690.90 0.26 5970659.54 588727.31 N7O1946.694 W1491649.283 BP_MWD+IFR+MS 5633.65 24.20 296.23 5233.80 668.03 824.79 -1725.16 0.49 5970676.39 588692.85 N 70 19 46.864 W 149 16 50.283 BP_MWD+IFR+MS 5730.95 23.78 296.50 5322.69 681.32 842.36 -1760.60 0.45 5970693.53 588657.20 N 70 19 47.037 W 149 16 51.318 BP MWD+IFR+MS 5820.56 24.42 292.05 5404.50 694.87 857.37 -1793.94 2.15 5970708.14 588623.68 N 70 19 47.184 W 149 16 52.291 BP_MWD+IFR+MS 5913.58 25.06 287.60 5488.98 712.05 870.55 -1830.55 2.12 5970720.87 588586.93 N 70 19 47.314 W 149 16 53.360 BP MWD+IFR+MS 6007.41 27.20 282.76 5573.23 733.26 881.30 -1870.41 3.22 5970731.14 588546.94 N 70 19 47.419 W 149 16 54.524 BP_MWD+IFR+MS 6100.13 28.77 277.21 5655.12 758.86 888.78 -1913.23 3.28 5970738.10 588504.04 N 70 19 47.493 W 149 16 55.774 BP_MWD+IFR+MS 6193.31 29.88 267.64 5736.40 790.27 890.64 -1958.69 5.16 5970739.42 588458.56 N 70 19 47.511 W 149 16 57.101 BP MWD+IFR+MS 6287.63 28.82 258.25 5818.66 827.08 885.04 -2004.45 5.00 5970733.27 588412.88 N 70 19 47.456 W 149 16 58.437 BP MWD+IFR+MS 6381.24 26.41 248.76 5901.64 865.38 872.89 -2045.97 5.35 5970720.62 588371.51 N 70 19 47.336 W 149 16 59.649 BP MWD+IFR+MS 6474.69 27.76 244.95 5984.85 905.14 656.15 -2085.06 2.35 5970703.41 588332.63 N 70 19 47.171 W 149 17 0.790 BP_MWD+IFR+MS 6567.35 30.51 245.32 6065.77 947.75 837.19 -2125.99 2.97 5970683.96 588291.93 N 70 19 46.985 W 149 17 1.985 BP MWD+IFR+MS 6663.08 36.73 244.85 6145.45 997.82 814.85 -2174.03 6.50 5970661.05 588244.17 N 70 19 46.765 W 149 17 3.388 BP_MWD+IFR+MS 6756.29 40.23 243.55 6218.41 1052.92 789.59 -2226.23 3.85 5970635.16 588192.29 N 70 19 46.516 W 149 17 4.911 BP_MWD+IFR+MS 6849.99 45.15 243.49 6287.26 1113.48 761.27 -2283.07 5.25 5970606.16 588135.79 N 70 19 46.238 W 149 17 6.571 BP MWD+IFR+MS 6943.59 49.63 242.24 6350.61 1179.40 729.84 -2344.35 4.89 5970573.99 588074.90 N 70 19 45.928 W 149 17 8.359 BP_MWD+IFR+MS 7036.69 54.86 240.18 6407.60 1250.41 694.36 -2408.81 5.88 5970537.75 588010.88 N 70 19 45.579 W 149 17 10.241 BP_MWD+IFR+MS 7130.83 60.13 238.13 6458.18 1327.69 653.64 -2476.92 5.89 5970496.21 587943.27 N 70 19 45.179 W 149 17 12.229 BP MWD+IFR+MS 7222.74 65.71 237.16 6500.00 1407.81 609.85 -2546.01 6.14 5970451.59 587874.72 N 70 1944.748 W 149 17 14.246 BP MWD+IFR+MS 7315.77 70.91 234.70 6534.38 1492.93 561.41 -2617.57 6.11 5970402.31 587803.76 N 70 1944.271 W 149 1716.334 BP MWD+IFR+MS 7408.60 72.44 227.99 6563.59 1580.61 506.39 -2686.32 7.06 5970346.46 587735.68 N7O1943.73O W1491718.341 BP MWD+IFR+MS 7502.25 74.56 224.60 6590.20 1670.38 444.35 -2751.21 4.14 5970283.65 587671.55 N 70 19 43.119 W 149 17 20.234 BP_MWD+IFR+MS 7595.83 72.58 224.13 6616.66 1760.10 380.19 -2813.97 2.17 5970218.75 587609.58 N 70 19 42.488 W 149 17 22.066 BP MWD+IFR+MS 7689.15 72.97 224.19 6644.30 1849.18 316.24 -2876.06 0.42 5970154.06 587548.26 N 70 19 41.859 W 149 17 23.878 BP_MWD+IFR+MS 7782.60 73.31 224.54 6671.40 1938.58 252.31 -2938.60 0.51 5970089.38 587486.51 N 70 19 41.230 W 149 17 25.703 BP MWD+IFR+MS 7876.18 73.98 225.04 6697.75 2028.35 188.58 -3001.86 0.88 5970024.91 587424.03 N 70 19 40.603 W 149 17 27.549 BP_MWD+IFR+MS 7970.33 73.06 224.59 6724.46 2118.62 124.54 -3065.49 1.08 5969960.11 587361.18 N 70 19 39.973 W 149 17 29.406 BP MWD+IFR+MS 8062.98 73.48 224.52 6751.13 2207.32 61.32 -3127.74 0.46 5969896.14 587299.70 N 70 19 39.351 W 149 17 31.222 BP_MWD+IFR+MS 8129.18 74.13 225.34 6769.59 2270.88 16.31 -3172.64 1.54 5969850.60 587255.35 N 70 19 38.908 W 149 17 32.532 BP MWD+IFR+MS 8230.93 74.15 223.63 6797.40 2368.71 -53.52 -3241.22 1.62 5969779.96 587187.62 N 70 19 38.221 W 149 17 34.533 BP MWD+IFR+MS 8261.94 74.21 224.14 6805.86 2398.53 -75.02 -3261.90 1.59 5969758.21 587167.20 N 70 19 38.009 W 149 17 35.137 BP_MWD+IFR+MS 8292.45 74.77 224.30 6814.02 2427.91 -96.09 -3282.41 1.90 5969736.90 587146.95 N 70 19 37.802 W 149 17 35.735 BP_MWD+IFR+MS 8322.57 75.17 224.09 6821.83 2456.99 -116.95 -3302.68 1.49 5969715.80 587126.93 N 70 19 37.597 W 149 17 36.327 BP MWD+IFR+MS 8355.09 78.66 224.44 6829.19 2488.65 -139.63 -3324.79 10.78 5969692.86 587105.10 N 70 19 37.374 W 149 17 36.972 BP_MWD+IFR+MS 8386.05 82.26 225.08 6834.32 2519.17 -161.30 -3346.29 11.81 5969670.93 587083.87 N 70 19 37.160 W 149 17 37.599 BP MWD+IFR+MS 8417.85 84.60 224.58 6837.96 2550.75 -183.70 -3368.56 7.52 5969648.26 587061.87 N 70 19 36.940 W 149 17 38.249 BP MWD+IFR+MS 8448.81 89.30 224.60 6839.60 2581.65 -205.71 -3390.25 15.18 5969625.99 587040.45 N 70 19 36.723 W 149 17 38.882 BP_MWD+IFR+MS 8479.34 91.39 224.63 6839.42 2612.16 -227.45 -3411.69 6.85 5969604.01 587019.27 N 70 19 36.510 W 149 17 39.508 BP_MWD+IFR+MS 8508.48 94.86 225.97 6837.83 2641.25 -247.91 -3432.37 12.76 5969583.30 586998.84 N 70 19 36.308 W 149 17 40.111 BP MWD+IFR+MS 8539.84 94.80 223.64 6835.19 2672.49 -270.08 -3454.39 7.41 5969560.87 586977.09 N 70 19 36.090 W 149 17 40.753 BP MWD+IFR+MS 8571.76 96.71 226.10 6831.99 2704.24 -292.58 -3476.79 9.73 5969538.10 586954.97 N 70 19 35.869 W 149 17 41.407 BP_MWD+IFR+MS 8601.96 97.98 224.40 6828.13 2734.19 -313.67 -3498.07 6.99 5969516.76 586933.95 N 70 19 35.661 W 149 17 42.028 BP_MWD+IFR+MS 8632.77 97.32 223.17 6824.03 2764.70 -335.71 -3519.19 4.50 5969494.46 586913.09 N 70 19 35.444 W 149 17 42.644 BP_MWD+IFR+MS 8673.32 95.33 223.09 6819.56 2804.95 -365.13 -3546.75 4.91 5969464.72 586885.90 N 70 19 35.155 W 149 17 43.448 BP_MWD+IFR+MS 8703.61 94.65 222.60 6816.92 2835.08 -387.25 -3567.27 2.76 5969442.35 586865.65 N 70 19 34.937 W 149 17 44.047 BP MWD+IFR+MS 8734.16 97.70 223.60 6813.64 2865.41 -409.42 -3588.01 10.50 5969419.93 586845.17 N 70 1934.719 W 149 17 44.652 BP_MWD+IFR+MS 8764.32 97.69 223.06 6809.60 2895.27 -431.17 -3608.52 1.77 5969397.95 586824.93 N 70 19 34.505 W 149 17 45.250 BP_MWD+IFR+MS 8795.49 99.40 222.93 6804.97 2926.05 -453.71 -3629.54 5.50 5969375.16 586804.18 N 70 19 34.283 W 149 17 45.864 BP_MWD+IFR+MS 8826.34 99.46 223.42 6799.91 2956.44 -475.90 -3650.37 1.58 5969352.71 586783.63 N 70 19 34.065 W 149 17 46.471 BP_MWD+IFR+MS 8857.88 99.53 224.45 6794.71 2987.53 -498.31 -3671.95 3.23 5969330.06 586762.32 N 70 19 33.845 W 149 17 47.101 BP MWD+IFR+MS 8888.20 99.57 224.03 6789.68 3017.42 -519.73 -3692.81 1.37 5969308.39 586741.72 N 70 19 33.634 W 149 17 47.709 BP MWD+IFR+MS 8919.16 99.40 223.72 6784.58 3047.93 -541.74 -3713.97 1.13 5969286.12 586720.83 N 70 19 33.417 W 149 17 48.327 BP_MWD+IFR+MS 8949.31 99.28 224.90 6779.69 3077.67 -563.03 -3734.76 3.88 5969264.59 586700.31 N 70 19 33.208 W 149 17 48.933 BP_MWD+IFR+MS 8980.81 99.24 225.35 6774.62 3108.76 -584.96 -3756.79 1.42 5969242.39 586678.54 N 70 19 32.992 W 149 17 49.576 BP_MWD+IFR+MS 9011.72 99.02 225.28 6769.71 3139.27 -606.42 -3778.49 0.75 5969220.67 586657.11 N 70 19 32.781 W 149 17 50.209 BP MWD+IFR+MS Page 2 of 3 • Measured Vertical Survey Tool Comments inclination Azimuth ryp NS EW DLS Northing Fasting Latitude Longitude Depth Section Model ft de d ft ft ft ft de 100 ft ftUS (tUS 9042.66 98.93 225.58 6764.89 3169.83 -627.87 -3800.26 1.00 5969198.97 586635.60 N 70 19 32.570 W 149 17 50.844 9073.61 97.33 224.42 6760.51 3200.46 -649.53 -3821.92 6.36 5969177.04 586614.20 N 70 19 32.356 W 149 17 51.476 9104.35 97.05 224.67 6756.66 3230.95 -671.27 -3843.31 1.22 5969155.05 586593.07 N 70 19 32.143 W 149 17 52.100 9134.94 97.05 224.55 6752.91 3261.30 -692.88 -3864.63 0.39 5969133.19 586572.01 N 70 19 31.930 W 149 17 52.722 9167.67 96.60 224.80 6748.96 3293.78 -715.99 -3887.48 1.08 5969109.81 586549.45 N 70 19 31.703 W 149 17 53.389 9198.88 96.51 224.96 6745.34 3324.78 -737.95 -3909.35 1.06 5969087.59 586527.85 N 70 19 31.486 W 149 17 54.027 9229.83 97.02 225.38 6741.70 3355.51 -759.62 -3931.15 2.13 5969065.66 586506.31 N 70 19 31.273 W 149 17 54.663 9260.64 97.76 225.88 6737.73 3386.06 -780.99 -3952.99 2.89 5969044.03 586484.73 N 70 19 31.063 W 149 17 55.300 9291.57 97.39 225.66 6733.66 3416.72 -802.37 -3974.96 1.39 5969022.39 586463.03 N 70 19 30.853 W 149 17 55.941 9321.97 97.18 226.34 6729.80 3446.88 -823.32 -3996.65 2.32 5969001.18 586441.59 N 7019 30.646 W 149 17 56.574 9352.55 96.71 225.97 6726.11 3477.23 -844.35 -4018.54 1.95 5968979.89 586419.96 N 70 19 30.439 W 149 17 57.212 9383.99 97.78 226.80 6722.14 3508.42 -865.86 -4041.12 4.29 5968958.11 586397.64 N 70 19 30.228 W 149 17 57.871 9414.83 97.57 227.08 6718.02 3538.98 -886.73 -4063.45 1.13 5968936.98 586375.56 N 70 19 30.022 W 149 17 58.523 9445.86 97.21 225.88 6714.03 3569.75 -907.92 -4085.77 4.01 5968915.52 586353.51 N 70 19 29.814 W 149 17 59.174 9478.20 97.07 226.54 6710.01 3601.84 -930.13 -4108.93 2.07 5968893.04 586330.62 N 70 19 29.595 W 149 17 59.849 9492.22 97.11 226.17 6708.28 3615.75 -939.73 -4119.00 2.63 5968883.32 586320.67 N 70 19 29.501 W 149 18 0.143 Projection to TD 9538.00 97.11 226.17 6702.61 3661.18 -971.19 -4151.77 0.00 5968851.47 586288.28 N 70 19 29.191 W 149 18 1.099 BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP MWD+IFR+MS BP_MWD+IFR+MS BP MWD+IFR+MS BP_MWD+IFR+MS BP_MWD+IFR+MS BP MWD+IFR+MS BP MWD+IFR+MS Page 3 of 3 • • TERRIE L RUBBLE a9-si,zez 258 BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612 MB 7-5 l l~~V / "~~ ANCHORAGE, AK 9951.9-6612 DA-rE PA DER OF E ~ ~ ~ ~- ~.d_J DOLLARS First National Bank Alaska Anchorage, AK 99501 MEMO ~:L25200060~:99L4~~~6227~~~L55611' 0258 a • • TRANSMITTAL LETTER CHECKLIST WELL NAME _ /b~E'-mil f/ `" ~~ Z PTD# Development ~ Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If Last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception, assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C:\jody\transmittal checklist • ~ W ~ ° : d 4 ~ ~ ~ ~ ~. 7 Q : ~ ~ ~ O , IU ~ ~ ~ ~ ~ : 0 W ~ ~ U O E O rn o ` a I Zoi p, ~~ Z N +, m, ~ ~' J ~ ~ ~ ~ Q' J' _ W' ~ Q LLA Z' ~: ' ~: ~ ~ i w~ O ~ z~ ~~ . : I I ~ : ~ ~ ~: - >' I O JR o = Q W I U' W . ~, W: ~ O x ~ J = aU. O, _, f1O ~~° z o ~ ~ aII fXN~ Q ¢ : O ~ m' ~' M ~ al is ~~ Q ~ ~ . ~ ~ : : ~ Z, J, N p OC fn, °: d' W W. C7 ~: > ui C9 , Q• N• ~ ~ Z' r` ~ ~ ~ ~ Q• W O N ~ ~ ~ ~ ~ N' N' f/Y qD N~ N. N. N, N, fU, ~ ~ : N~ N~ Vf tn~ tn~ Vb NS N~ Ub tn~ N, IU, fU: N, fU~ IU, IU, N, N, N. Q. Q. ~ m ~: ~~ ~: ~ "~ c ( U ~ ~ I I w ~ : ~ c N, E. ~ 3 i c E, lu. c ~. M ~ `°) ~ C to ~ m - J ~ ~ ~ C~ ~ ~ ~ ~ ~ j~ ~ S w~j ~ ~ y a 1 ~ I . ~ ~' m s I < m U; _: t: ~ ~, Z ~ O I ~ ~ ~ a o ~ a' ~ c' m ~~ a ~ IU c C ~ ~_' Z ~~ ~ O' O "O T O' a i D ~ ~, a w w c ~ ~ p' ~ oa < ~ Q~ ~ ~ .~ ~ N ~' 4 ~ ~, N ~ ~ ~° 'o' 'o ~' i a ¢ ° ~ m' m' ~ t ~~ < f6, l6 N o O~ a, o, c w: ~, ~, ~, o a: a aai` ~~ o~ ~ ~I L. d N: ~~ d d ~ ~~ ~~ d NA to d j a ~~. fV0' to ~' C O, O, Sp 3, l0 ~ N; N co .y ~ Q ~ d ~. d T N.. N IU x la E~ ar .. ~, v' o' ~' ~ c' ~ ~ N d~' w N. 3. ~~ O~ d U. ~' ~, ~~, ~' ' 1 ~1 ~ ° c ~ d d 'o m fu m , a> , , , . ~ O" O N M ~ U U --- -_ --------- _----- -- ----- ~' O ~ a O ~ G ~ W p ' M 00 J N C IiJ ~ E a a ~ U Q ~ `a c 7 S ~, ~ u ~S c' 1 :' o' i i' 3' { ~ ~ r i i. Z )' N' t T ~ f O. f ,~ ~ t r a <. 3' ~' j' C f ~ ;~ S 3' 3' s, fU f S. ~ ~ S t w o .<, 3 ~ ~ ' ~: j: N, "s ~~~ i f c l 3 ~ ~ '3 ~' W i >' i lu , 3 1 ¢, c r fn o i i v y 'o i d fA )~ ?~ O i. v )' N' 3 7. 3, N, N• is ~ _, i 's c m, s: u~, ;~ a >~ U' o 3 c ~ c' LL: a i ~ ~, Q: i i i ~ ~ : : : I ~ ~ ~ ~ ~ ~ : ~ ~: i i j ~ ~ ~ ~ ~ ~, : i ~ ~ : ~ ~. j ~: : y~ y, y. ~ N~ tn~ y. N~ ~ y: N~ tn~ y~ N~ 1 lu, lu, fu, o, fu. a~ Iv, Q, lu, Q. fu. Iv, lu; lu, lu. Q, 1 ': ~ ~ ~ ~~ ~ w : c' -O~ N• .i yy ~ O: p N• Of ~, ,~: v. ~ ~ fu, a, •y: 170: ti ~~ C• ~~ ~: ~ to O, ~ d T ~ ~ ~ ~: ~ O, °- lU a: 4 ~ O L _ a ~' c rn t~ °~ ~ ar° ,~ fn p ~: ~ `~ °. m. o. o m asi N a N, j ~: ~, '~ ~ o °: o ~ o rn n 'Q ~ m i a p, o. o, c ~ o o ,~ -o: ~: ~ p ~ L; rn tl O~ rty,' Y Y. a• N N, .p N' ~~ OS O' (/T o~ d la' ~ m ~6' ~ m O a~; ~ T c v '3 = 01 ~' °~ ~ ~ C. Y to _~ 7 ~ ~ ~. ~ 7 O IA O ~ N M V O O r` M O O N M ~ ~ N N N N N N N N N N M M M M f to C .~ d c C w O d O l+'0 N 0 M $~ Q ~ o. Q. Q Q. Q. Z, Z, Z, Z, Z, ~, O { N: S N ~ tn: ~ C• ~ f N S O N. c a w: °, rn ~ o `~ N' d c N' t t rn In' o, ~ m a, o rn o' f r m 3' v, f a O tLA Z f N O- r- y, S •fN_n; ° N o s S N ~ ~+ :0 f ~ c m c' ~ c. N. c, O, < U, ` O U, s U a, j •~' ~ •~' ~ N, (p, ~ a; o, in; in; c to O r` f7D G M M M M c O d R N ~ ~ M T O ~ °~' a ~ c~ a~ c 0 U •N 7 a~ U i .~ s r >' A 1 i J i 3' i ~, l6 O M J 01 fU C c 0 •~ p lu !_n c ~ c E W U V ~U N (0 (~ ~ ~ ~ \J ~\ -- • ~~ ~ ~ 1 ~ ~ ~ j ~~ ~ ,~ ~ i, ~ 7 ~ , ~1 \ 1 ~ ~ 3 ®. ~ ~ 9 f , ? ALA.SSA OIL A1~TD GABS CO1~T5ERQATIOi~T COMbIISSIOIQ Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ,~-. FRANK H. MURKOWSK/, GOVERNOR 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 h -~ ~J~ L.- Re: Prudhoe Bay Field, PBU V-112 +~ BP Exploration (Alaska), Inc. ~ ~. ~~ ~° ~~ Permit No: 206-020 Surface Location: 4627' FSL, 1876' FEL, SEC. 11, T 11 N, R 11 E, UM Bottomhole Location: 4010' FSL, 332' FEL, SEC. 10, T 11 N, R 11 E, UM Dear Mr. Tirpack: . C'~ Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with. an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Daniel T. Seamount Jr. ~'~ Commissioner DATED this day of February, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA LAND GAS CONSERVATION COIDT~11SSION FEB 0 2 2006 PERMIT TO DRILL Alaska Oil & Gas Cons. Commissiol-r 20 AAC 25.005 1a. Type of work ®Drill ^Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ^ Development Oil Multi le Zone ^ Stratigraphic Test ®Service ^ Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU V-112 i` 3. Address: P.O. Box 196612, Anchorage, Alaska .99519-6612 6. Proposed Depth: MD 8978 TVD 6733 12. Field /Pool(s): Prudhoe Bay Field /Borealis Pool 4a. Location of Well (Governmental Section): Surface: 4627' FSL 1876' FEL SEC 11 T11 N UM R11 E 7. Property Designation: ADL 028241 , , , . , , Top of Productive Horizon: 5086' FSL, 4518' FEL, SEC. 11, T11 N, R11 E, UM 8. Land Use Permit: 13. Approximate Spud February 0 006 Total Depth: 4010' FSL, 332' FEL, SEC. 10, T11 N, R11 E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 6500' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 590428 - 5969873 Zone- ASP4 10. KB Elevation plan (Height above GL): 81.5' feet 15. Distance to Nearest Well Within Pool 1600' 16. Deviated Wells: Kickoff Depth: 600 feet Maximum Hole Angle: 97 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3423 Surface: 2758 ° 18. Casing rogram: Size Specifications Setting Depth To Bottom uantity o ement cf. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD ND includin sta a data 42" 20" x 34" 215.5# A53 Weld 80' Surface Surface 110' 110' 60 sx Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BTC 2826' Surface Surface 2854' 2712' 01 sx AS Lite, 150 sx'G', 71 sx'G' 8-3l4" 7" 26# L-80 BTC-M / TCII 7818' Surface Surface 7818' 6683' 82 sx 'G', 71 sx 'G', 208 sx 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 1312' 7666' 6625' 8978' 6733' 174 sx Class 'G' 19. PRESENT W ELL CONDITION SUMMARY (To be completed fior Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casin Len h Size Cement Volume MD TVD n r i 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 Shane Gagliardi, 564-5251 Printed Name Robert Tirpack Title Senior Drilling Engineer / Prepared By Name/Number: Si nature ~ f~ Phone 564-4166 Date ~-%~ ~ 6 Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: Z .-O2U API Number: 50- U2 `~~ .23 30~ Permit Approval Date: See cover letter for other requirements Conditions of Approval: Samples Required [j Yes '~~ No Mud Log Required ~LJ Yes ^ No Hydrogen Sulfide Measures ~ Yes `i No Directional S//urvey Re/quired ~=_; Yes ; J' No Other: 1 2 s ~- 13 r~ ~ E t"~J ~ nO D Sti M ~ T C2t~ ~P.rc.~' CG~e~rti G O ~J ~"~~ ~ 1^Pd . (~~r 2 ~ /a-~-~ 2s . o '~ S C G~ ~ ~ t ~ a.l ~~~ti•-~'~ ~ ~ rah` t-~~ ~- ~v c.edu`~.-e ~ s a-~'f'~'~ v ~ d ~ APPROVED BY ~ / ~j A roved B F~'° ~~ z THE COMMISSION Date wv~ ~~~EI~/ED Form 10-401 Revised 06/2004 ~ ~-:w Submit In Duplicate C7 • Well Name: V-112i Planned Well Summary Well V-1121 Wee Slant Injector Obaect ve Kuparuk AFE Number: BRD5M4195 Surface Northin Eastin Offsets TRS Location 5,969,873 590,428 653' FNL / 1,876' FEL 11 N, 11 E, 11 API Number: 50-029-##### T t Northin Eastin Offsets TRS arge L ti 5,970,300.00 587,780.00 194; FNL / 762; FWL 11 N, 11 E, 11 oca on 5,969,714.00 587,195.00 773 FNL / 169 FWL 11 N, 11 E, 11 Bottom Northin Eastin Offsets TRS Location 5,969,212.00 586,700.00 1,269' FNL / 332' FEL 11 N, 11 E, 10 Planned KOP: 600' and / 600' tvd Planned TD: 8,978' and / 6,733' tvd Ri Nabors 9ES CBE: 53' RTE: 81.5' Estimated S ud Date: 3/15/2006 Planned O eratin Da s: 20 days Directional Program i A roved Well Ian: W 18 Exit oint: Throu h Shoe Maximum Hole Inclination: 96.8° from 8,336' to 8,978' in the tanned 6'/8" roduction section. The WKUPST-01 well is a P&A'd exploratory well that fails major risk C~1 7,977' md. Due to the size of the error ellipse and the current condition of the well, the well has been deemed a minor risk and passes 1:200 minor risked Proximity Issues: base analysis. All other surrounding wells pass major risk criteria. Wells V- 113 is the closest neighboring well at 30' center. There is an empty slot between V-1121 and V-113. The closest approach to V-113 is at 658' md, with acenter-to-center distance of 26.73'. Surve Pro ram: Standard MWD with IIFR and MS. Nearest Well Within Pool: 1,600' SE of V-113 and 1,600' SW of V-107 Nearest Pro ert Line PBU bounda 6,500' Northeast of TD ~- ln7 ~-tl3 V-d~~ V ~ln~ ZOtISS~ ZoZZI[o~ ,ottGG' ZdZLd2..~ Lopping Program Hole Section: Required Sensors /Service 12'/a" Surface Real time MWD Dir/GR throu hout the interval. G ro to ± 700'. 8 3/a" intermediate: Real time MWD Dir/GR/Res/PWD. Recorded Neu/Den. 6 3/a" roduction: Real time MWD Dir/GR/Res/AIM. Recorded Neu/Den. Cased Hole: USIT for Intermediate 7" Casin . V-1121 Permit to Drill Application Page 1 • Mud Program Hole Section / o eration: Drillin 12 ~/a" interval from surface to 1,838' T e Densit Viscosit PV YP Chlorides API FL H S ud 8.8 - 9.2 300 - 250 30 - 55 50 - 70 <1000 NC - 8.0 9.0 - 9.5 Hole Section / o eration: Drillin 12 ~/a" interval from 1,838' to -2,859' T e Densi Viscosit PV YP Chlorides API FL H S ud 9.2 - 9.5 250 - 225 30 - 55 45 - 60 <1000 8.0 9.0 - 9.5 Hole Section / o eration: Drillin 8 3/a" interval, surface shoe - 6,825 To HRZ T e Densi PV YP API FL H Drill Solids MBT LSND 8.8-9.2 8-16 18-24 4.0-7.0 9.0-10.0 <6.0 <18 Hole Section / o eration: Drillin 8 3/a" interval, 6,825 THRZ - 7,712 TKC2 T e Densit PV YP API FL H Drill Solids MBT LSND 10.3 12-22 18-24 3.0-4.0 9.0-10.0 <6.0 <20 Hole Section / o eration: Drillin 6 %a" roduction interval to 8,978' TD T e Densi PV YP API FL H Drill Solids MBT LSND 10.3- 12-22 18-24 5.0-8.0 9.5 <6.0 <10 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade ~ Connection Length Top and / tvd Bottom and / tvd 42" 20" x 34" insulated 215.5# A53 W LD 80' Surface 110' / 110' 12 '/a" 9 5/8" 40# L-80 BTC 2,826' Surface 2,854' / 2,712' 8 3/a" 7" 26# L-80 BTC-M 3,382' 4,330' / 4,057' 7,818' / 6,683' 8 3/a" 7" 26# L-80 TC-II 4,330' Surface 4,330' / 4,057' 6'/8" 4 %z" 12.6# L-80 IBT-M 1,312' 7,666'/ 6,625' 8,978' / 6,733' Tubin 3'/z" 9.2# L-80 TC-II 469' 7,217' / 6,459' 7,686' / 6,623' Tubin 4 ~'/z" 12.6# L-80 TC-II 7,189' Surface 7,217' / 6,459' Disposal Annular No annular injection in this well. In'ection: Cuttings Cuttings generated from drilling operations are to be hauled to the Grind and Inject Handlin station at DS-04. Any metal cuttings should be sent to the North Slope Borough. Fluid All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 for Handlin injection. All Class I wastes are to be hauled to Pad 3 for disposal. V-112i Permit to Drill Application Page 2 • Cementing Program • Casin Strin 9 5/8", 40#, L-80, BTC Surface Casin Slurry Design Basis: Lead slurry. 1,833' of 9 5/e" X 12 ~/a" annulus from surface to the base of the Permafrost, with 250% ex , ~lus 471' of 9 5/a" x 12 1/a" annulus with 30% excess. Lead TOC to rfac .Incorporate TAM port collar if necessary. Tail slurry. 550' of 9 2 ~/a" annulus with 30% excess, plus ~ 86' of 9 5/a", 40#, shoe tract. Tail TOC to ~ 2,304'md, ~ 2,212' tvd Pre-Flush: None Planned S acer Fluid: 80.Obbls MudPUSH II at 10.0 Slur T e 10.70 Arctic Set Lite Permafrost Mix method Batch mix Lead Slurry: BHST /BHCT 59° F / 65° F Thickenin time 6 hrs 00 min Slur Volume 396 bbl / 2,224 cf / 0 sx ASL 10.7 ; 4.4 cf/sk. Slur T e 15.8 Class `G Mix method Batch mix BHST /BHCT 59° F / 65° F Thickenin time 4 hrs 35 min T il Sl Slur Volume 30.9 bbl / 174 cf 15 ~sx Class `G', 15.8 ; ..1 f/sk. a urry: Slur T e 15.8 Class ` w/ Durastone Mix method Batch mix BHST /BHCT 59° F / 65° F Thickenin time 4 hrs 35 min Slur Volume 15.0 bbl / 84 cf 71 x Class `G', 15.8 1.1 f/sk. Casin Strin 7" , 26#, L-80, BTC-M Int Cs Ion strin 2 Sta a w/ ESC C~ 6,128' CM1 Stage 1 Slurry Design Basis: Lead Slurry: None Planned ° Tail Slurry. 1,584 of 7 x 9 /e s with 30 /° excess. Tail cement is tanned to the sta a collar @ ,128' Pre-Flush: None Planned S acer Fluid: 50.0 bbls MudPush II at 11.10 Sta e 1 Tail Slur Slur T e 15.8 Class G with `GASBLOK' additive Mix method Batch mix BHST /BHCT 150° F / 118° F Thickening time 4 hrs 27 min - Slurry Volume 58.2 bbl / 327 cf 8 x Class G, 15.8 ppg~ 1.1 f/sk. Stage 2 Slurry Design Basis: Lead Slurry: 1,298' of 7" x 9 5/8" an us with 30% excess. Le TOC is planned to be 500; and above the top of the Ma°sand. 3 ~1 R ~ Tail Slurry. 1,000 of 7 x 9 /8 annulus with 30 f excess. Tail TOC is planned to be 1,150' and above the stage collar. Tail TOC should be just above the Obf Base. Pre-Flush: As necessa ,until sta e 1 reaches 500 si com ressive stren th S acer Fluid: 50.0 bbls MudPush II at 10.5 Sta e 2 Lead Slur Slur T e 11.0 Class G Litecrete Mix method Batch mix BHST /BHCT 80° F / 80° F Thickening time 4 hrs 27 min ~ Slurry Volume 45.2 bbl / 142 cf 7')~sx Class G, 11.0 ppg; 3.5 f/sk. Sta e 2 Tail Slur Slur T e 15.8 Class ~ ~ ~~° Mix method Batch mix BHST /BHCT 80° F / 80° F Slur Volume 43.1 bbl / 242 cf / 2 sx Class G, 15.8 , 1.16 f/sk. :1` ~/ V-1121 Permit to Drill Application Page 3 • • Cementing Program (Cont) Casin Strin 4 %z", 12.6#, L-80, IBT-M Production liner Slurry Design Basis: Lead slurry. None planned. Tail slurry. 1,266' of 4 ~/z" X 6'/a" annulus with 30% excess, plus 150' of 4 %z" x 7" liner lap, plus 200' of 4" ~ pipe x 7" annulus, plus -86' of 4 /z , 12.6#, shoe tract. Tail TOC to ~ ,56 'and Pre-Flush: 10.0 bbls CW100 S acer Fluid: 20.Obbls MudPUSH II at 11.1 Slur T e 15.8 Class `G' liner slur with `GASBLOK' additive Mix method Batch mix Tail Slurry: BHST / BHCT 150°F / 119° F Thickenin time 6 hrs 6 min Slur Volume 36.2 bbl / 203 cf / 174 sx Class `G', 15.8 ; 1.17 cf/sk. Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 9 5/8" casin Float a ui ment to surface 30 min recorded 3,500 si surface 9 5/8" casin shoe 20' new formation be and LOT 12.8 EMW 7" casin Float a ui ment to surface 30 min recorded 4,000 si surface 7" shoe 20' new formation be and FIT 11.0 EMW 4 ~/z" roduction liner Float a ui ment to surface 30 min recorded 4,000 si surface Well Control The surface hole interval will be drilled with a diverter. Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. Due to anticipated surface pressures not exceeding 3,000 psi, it will not be necessary to have two sets of pipe rams installed at all times. BOP regular test frequency for V-1121 will be 14 days w/function test every 7 days. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8 3/a" intermediate interval into Ku B Maximum antici ated BHP: 3,310 si at 6,430' sstvd. Maximum surface ressure: 2,667 SI (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: 50.5 bbls wit EMW LOT Planned ROPE test ressure: 250 si low / ,00 si hi h -14 da test c cle, 7 da function test BOPE configuration for 7" intermediate casin . ~» pipe rams, ind/shear rams, and an annular preventer. Well Interval: 6'/8" roduction interval in Ku aruk C sands Maximum antici ated BHP: 3,423 si at 6,650' sstvd. Maximum surface ressure: 2,758 SI (based upon BHP and a full column of gas from TD C~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 11 l EMW FIT. Planned BOPE test ressure: 250 si low / ,00 si hi h -14 da test c cle, 7 da function test Planned com letion fluid: 8.8 brine Diesel V-1121 Permit to Drill Application Page 4 • • 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. Geologic Prognosis Formation Est. Formation To s Est. Formation To s Uncertain Commercial H drocarbon Bearin Est. Pore Press. Est. Pore Press. (MD) (TVDss) eet) (Yes/No) (Psi) ( EMW) NOTE: All formation to s are re uired from 1000' above ro osed KOP to TD for sidetracks NOTE: All formation to s are re uired from surface to TD for all new wells G1 326 245 +/-30' No 110.25 8.7 SV6 964 880 +/-30' No 396 8.7 SV5 1645 1530 +/-30' No 689 8.7 SV4 1777 1650 +/-30' No 743 8.7 Base Permafrost 1832 1700 +/-30' No 765 8.7 SV3 2205 2040 +/-50' No 918 8.7 SV2 2392 2210 +/-50' No 995 8.7 SV1 2743 2530 +/-50' No 1139 8.7 UG4 3067 2825 +/-50' No 1271 8.7 UG4A 3100 2855 +/-50' No 1285 8.7 UG3 3495 3215 +/-50' No 1447 8.7 UG1 4 3685 +/-50' No 1658 8.7 UG_Ma 32 3975 +/-50' No 1789 8.7 SB-Na 09 4230 +/-50' possible 1904 8.7 SB-OA 4790 4395 +/-50' possible 1956 8.6 SB-OBd 5020 4605 +/-50' possible 2049 8.6 SB-OBf base 5185 4755 +/-50' No 2116 8.6 CM2 (K-10) 5399 4950 +/-50' No Fault 1 5520 5060 +/-200' n/a CM1 (Colville shales 6127 5610 +/-50' No THRZ 6824 6160 +/-50' No BHRZ (Top Kalubik 7165 6360 +/-50' No K-1 7185 6370 +/-50' No TKD 7317 6430 +/-50' yes 3310 9.9 TKC4 7393 6460 +/-50' yes 2700 8.0 TKC3 7426 6472 +/-50' yes TKC2 7440 6477 +/-50' yes Set 7" csg* 7711 6560 +/-50' n/a LCU/KUPB U thrown 7767 6581 +/-50' yes 3387 9.9 Fault 2 7818 6600 +/-100' n/a KUPC2 (Downthrown- invert 8268 6730 +/-50' yes 2700 7.7 TKD - BHL 8978 6650 +/-50' yes 3423 9.9 q, t 9•i ~ n. 3 V-112i Permit to Drill Application Page 5 ~ • TD Criteria TD Criteria: TD 100' and passed TKD after drilling the inverted section Fault Prognosis Fault Formation MD Intersect TVDss Estimated Direction of Uncertainty Encountered Intersect Throw Throw Fault #1 Colville 520' 5 -5060 140' D o +/- 200' MD , West Fault #2 Lower KupB to 7 820' -6600 170' Down to +/- 100' MD Lower Ku C ° West V-112i Permit to Drill Application Page 6 i • • V-112i Drill and Complete Procedure Summary Pre-Rig Work: 1. The V-112i conductor has been set in slot V-SA at the end of the well row. There is an empty slot between V- 112i and V-113. 2. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. 4. Prepare neighboring wells for the rig move and simops production. Shut in V-113 and remove well house. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up diverter spool and function test diverter PU 4" DP as required and stand back in derrick. 3. MU 12-~/a" drilling assembly with Dir/GR and directionally drill surface hole to approximately 2,854' MD. The actual surface hole TD will be +/-100' TVD below the top of the SV1 sands. An intermediate wiper/bit trip to surface will be performed prior to exiting the permafrost. 4. Run and cement the 9 5/s", 40.0-Ib/ft. surface casing bask-to surface. A TAM port collar should be on location, ~ but will be run only if hole conditions dictate. p plug and ensure that floats hold. ND diverter spool and NU casing /tubing head. NU BOPE and test to ,OQO'`psi. 5. MU 8-3/a" drilling assembly with Dir/GR/Res/Azi-Den/Neu(recorded)/PWD and RIH to float collar. Circulate and condition cement contaminated mud. Displace over to new 8.8 ppg LSND mud. 6. Test the 9 5/e° casing to 3,500 psi for 30 minutes. 7. Drill new formation to 20' below 9-5/8" shoe and perform LOT. If a 12.8 ppg EMW is not obtained contact ODE. ~ 8. Drill to ± 200' above the HRZ, ensure mud is conditioned and weighted to 10.3 ppg. Ensure pre-reservoir meeting is held highlighting kick tolerance and detection prior to entering the HRZ. 9. Drill ahead to target TD at 7,712' MD, (approx 100' MD below TKC2). 10. Circulate and condition hole, POOH to run casing. Perform wiper trip ONLY if hole conditions dictate. 11. Run and cmt the 7" production casing in two stages with stage tool C«3 -6128'. Ensure 500 psi compressive on first stage prior to pumping second stage. Displace with seawater during cementing operations. Bump plug and ensure that float holds. Install 7" casing packoff and test per FMC rep. Freeze protect the 7" x 9-5/8" annulus. 12. MU 6-'/8" drilling assembly with MWD / GR / Res /Den / Neu (All real time) and TIH. 13. Test casing to 4,000 psi. Drill shoe and 20' of new formation. Perform FIT to 11.0 ppg EMW. Production section will be drilled with the same LSND fluid that the intermediate section was drilled. 14. Drill ahead to proposed TD @ 8,978'MD / 6,733' TVD. Short trip as required; condition hole to RIH w/ 4-'/z" liner. 15. Run 4-'/z" 12.6 ppf, L-80 IBT-M solid liner. There will be 150' of overlap into the 7" intermediate casing. Cement %' liner as directed. Set liner top packer. Release from liner, displace well to filtered 8.8 ppg seawater and POOH. 16. RU Schlumberger wireline and run USIT from liner top packer C~ 7,562' and to TOC (estimated to be 3,830' md. '' 17. PU DPC 2906HMX (for 4-'/z") 6 spf, 60 deg phase and 4505HMX (for 7") 5 spf, 72 deg phase Powerjet Omega ~ pert guns and RIH w/ - 100' and 350' respectively. Tag PBTD for depth control. 18. Run 4-'/z" 12.6 ppf / 3-'/z" 9.2 ppf, L-80 IBT-M completion w/ injection mandrels. RILD. Set packer ~ 7,168' MD and test tubing to 4,000 psi and annulus to 4,000 psi for 30 minutes. 19. Shear DCK valve and install TWC. 20. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. Remove TWC. 21. RU hot oil truck. Freeze protect the well from lowest GLM. Install BPV in tubing hanger. Install a VR plug in the 7"x 4-'/z" annulus valve and secure the well. Ensure that IA/OA are both protected with two barriers. 22. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC. 2. Replace the DCK shear valve with a dummy GLV 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. V-112i Permit to Drill Application Page 7 • • Phase 1: Move In / Rig Up /Accept Planned Phase Time Planned Phase Cost 43.4 hours $222,360 Reference RP • "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards - There is one neighboring well, V-113 that is 30' to the north of the V-112i conductor. - V-113 is currently on production. The well will have to be SI for MIRU and the well house will require removal. Any surface pressure will have to be bled off during the rig MI/RU. Care should be taken while moving onto the well. Spotters should be employed at all times. - V-pad is~taLesignated as an H2S site. However, Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading V-113 5 ppm V-107 0 ppm V-109 10 ppm V-108 0 ppm The maximum level recorded of H2S on the pad was 180 ppm in 12/2005. - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud. - Check the landing ring height on V-1121 prior to rig mobilization. The BOP nipple up may need review for proper space-out prior to spud. Phase 2: Drill 12-~/a" Surface Hole Interval Planned Phase Time Planned Phase Cost 66.9 hours $364,688 Reference RP • "Prudhoe Bay Directional Guidelines" RP • "Well Control Operations Station Bill" RP Issues and Potential Hazards - There are four close approach issues while drilling the surface hole summarized below: Close Approach Well Name Reference MD Ctr to Ctr Distance V-109 540 58.22 V-113 658 26.73 V-114 770 70.70 V-119 436 20.24 V-112i Permit to Drill Application Page 8 • • - The W KUPST-01 well is a P&A'd exploratory well that fails major risk C«~ 7,977' md. Due to the size of the error ellipse and the current condition of the well, the well has been deemed a minor risk and passes 1:200 minor risked base analysis. - Due to shallow close approach issues, gyro surveys should be used for the first 700' and or until clean surreys are attained. Surveys MUST be taken every stand. - Surveys will need to be IFR + MS corrected. - Gas hydrates have been observed in some wells drilled on V-Pad. These were encountered near the base of permafrost to TD. Expect to encounter hydrates in the SV3, SV2 and SV1 sands. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to MI mud recommendation, DefoamX is not recommended for hydrates. - There are no anticipated faults in the surface hole section, and no significant problems are expected during drilling. A TAM port collar in the 9 5/a" casing is proposed as a contingency, should unexpected problems arise. Phase 3: Run and Cement 9 5/a" Surface Casing Planned Phase Time Planned Phase Cost 29.10 hours $421,477 Reference RP • "Casing and Liner Running Procedure" RP • "Surface Casing and Cementing Guidelines" RP • "Surface Casing Port Collar Procedure" RP Issues and Potential Hazards - It is critical that cement is circulated to the surface for well integrity. Planned cement volume is based upon: 250% excess cement through the permafrost zone and 30% excess below the permafrost. - One `bow-spring' centralizer, per joint, will be run on the first 15 joints. Additionally, one will be placed on each side of the port collar (if run). - Reciprocate the casing ~10' while displacing cement, if the hole condition will allow it. - Note: Check surface cement level prior to leaving the location to determine whether or not the cement has slumped. Record depth tagged on Morning Report. If TOC is greater than 20' below top of conductor, notify AOGCC and perform a top job at the next / opportune time. - Note: 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. Phase 4: Drill 8-3/a" Intermediate Hole Interval Planned Phase Time Planned Phase Cost 120.4 hours $723,271 Reference RP • "Standard Operating Procedure for Leak-off and Formation Integrity Tests" RP • "Shale Drilling, Kingak and HRZ" RP V-112i Permit to Drill Application Page 9 • ~ • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards - This well bore will build angle in the HRZ from ~48° to ~60° inclination as well as making a slight left hand turn before terminating below the TKC2. The HRZ will require a mud weight of 10.3 ppg. Maintain mud weight at 10.3 ppg from above the HRZ to the interval TD. Follow all shale drilling practices to minimize potential problems. - It is imperative that this section of hole TD 100' and or better prior to fault crossing #2. The potential for lost circulation or breathing is moderate. Monitor ECD and consult the Lost Circulation Decision Tree, embedded in the mud program, regarding LCM treatments and procedures. - In the past, several V-pad wells have had shallow gas cut mud due to encountered overpressure (9.6 ppg EMW). The overpressure is due to area injection which should not affect this well. However, gas cut mud, mud flow and oil in the returns may indicate that the overpressure is present at which point the mud should be weighted up in small increments. During weight up, be mindful of possible breathing issues due to overbalance. - KICK TOLERANCE: In the scenario of 9.6 ppg pore pressure in the Kuparuk, a minimum fracture grad' of 12.8 ppg at the surface casing shoe, and 10.3 ppg mud in the hole, the kick tolerance is .5 bls. ~u Phase 6: Run and Cement 7" Intermediate Casing Planned Phase Time Planned Phase Cost __ __ 23 hours $510,932 Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Freeze Protecting an Outer Annulus" RP Issues and Potential Hazards - Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. In offset wells casing running speed was 2 minutes per joint, no problems were noted in either case. Excessive swab /surge pressures could initiate HRZ instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Proper casing centralization will facilitate minimizing the potential for differential sticking. The 10.3 ppg LSND used for drilling the HRZ will create a 400 psi over-balance in the Schrader sands. Minimize the amount of time spent stationary. - This intermediate casing cement job is planned as a two stage job. The first stage is planned using 15.8 ppg tail cement from the 7" shoe @ 7,712' to the ES Cementer C 6,128'. The second stage is planned using a 11.0 ppg Class G Litecrete lead slurry to 500' above the Schrader Ma, followed by a 1150' 15.8 ppg class `G' tail slurry to ~ the Obf Base. The TOC lead will be 3,830' md, 3,600' tvd. The TOC tail will be 4,978' md, 4,648' tvd. - Confirm that the intermediate casing cement has had adequate thickening time (70 Bc value), prior to freeze protecting the 9 5/8" by 7" casing annulus. If necessary, ensure a double barrier is in place on the annulus, at the surface, until the cement has set up for at least 12 hours. V-1121 Permit to Drill Application Page 10 i - Request a UCA from Schlumberger Dowell. Confirm a cement compressive strength of 1,000 psi prior to pressure testing the 7" casing. Phase 7: Drill 6'/a" Production Hole Interval Planned Phase Time Planned Phase Cost 82.5 hours $732,507 Reference RP :• "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards - There is one significant fault crossing in the production hole section. There is a high probability that losses will be encountered within a couple of hundred feet outside of the intermediate casing shoe. The available data indicates that there is no pressure communication across the fault; however, the mud weight will high enough to compensate for any pressure communication. In the event of losses, refer to the LCM decision tree in the MI mud program. - If a request is made to extend the well bore beyond the planned TD coordinate, regardless the revised TD location relative to the polygon, contact the drilling engineer prior to drilling ahead. It will be prudent to confirm proximity clearance. Phase 9: Run 4~/s" Production Liner Planned Phase Time Planned Phase Cost 28.8 hours $209,002 Reference RP • "Modified Conventional Liner Cementing" RP Issues and Potential Hazards - The planned production liner is a 4-~h", 12.6#, L-80, IBT-M solid liner throughout the production interval. - Differential sticking is possible. The 10.3 ppg LSND will create an over balanced of 775 psi in the C4 Sand. Minimize the time the pipe is left stationary while running the liner. - Sufficient 4-~/z" liner will be run to extend --150' back up into the 7" casing shoe. - Ensure the 4'/z" liner top packer is set prior to POOH. Phase 5: Wireline Logginq Planned Phase Time Planned Phase Cost 13.3 hours $61,586 Reference RP • "Wireline Pressure Control SOP" V-1121 Permit to Drill Application Page 11 ~ • Issues and Potential Hazards - Log the 7" intermediate casing from the liner top packer @ 7,562' to the TOC estimated ~ 3,830'. - Send log data via a-mail to ODE as soon as possible for evaluation. Phase 10: DPC Perforate Planned Phase Time Planned Phase Cost 25.6 hours $237,227 Reference RP • "Drill Pipe Conveyed Perforating" RP Issues and Potential Hazards - The well will be DPC perforated, 200 psi overbalanced in the up thrown block and 300 psi overbalanced in the down thrown block. There will be two different size perf guns run in the hole to accomplish the job in one run. Ensure all personnel are well briefed on Schlumberger's perforating procedures and that all responsibilities are understood. Only essential personnel should be present on the rig floor while making up DPC guns. - Expect to lose fluid to the formation after perforating. Have ample 8.6 ppg seawater on location and be prepared with LCM if necessary. Phase 12: Run 3-'/z"x 4-'/z" L-80 Completion Planned Phase Time Planned Phase Cost 35.3 hours $461,043 Reference RP • "Completion Design and Running" RP • "Tubing Connections" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. - The completion, as designed, will be to run a 3-Yz", 9.2# , L-80, IBT-M production tubing string crossed over to 4-'/z", 12.6# , L-80, IBT-M with two gas lift mandels and two injection mandrels. Phase 13: ND/NU/Release Rig Planned Phase Time Planned Phase Cost 11.3 hours $41,182 Reference RP • "Freeze Protecting an Inner Annulus" RP V-112i Permit to Drill Application Page 12 ~ • Issues and Potential Hazards - There is one near-by neighboring well, V-113, which is 30' feet to the North. - Care should be taken while moving off of the well. Spotters should be employed at ail times. - During ND BOPE/NU tree operations, the V-112i well bore will be secured with the following barriers: o Tubing: TWC and kill weight fluid above ball/rod. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. - During RD/MO operations, the V-112i well bore will be secured with the following barriers: o Tubing: BPV and kill weight fluid above ball/rod. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. V-1121 Permit to Drill Application Page 13 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE 1. Well Control A. The Ugnu contains hydrocarbons in this area, but is not expected to be over pressured. II. Hydrates and Shallow gas A. Gas Hydrates are present at V-pad throughout the SV4, SV3, SV2 and SV1. Setting casing ~ through the SV1 should keep hydrate exposure from extending past the surface hole; however, hydrates have been encountered below the SV1. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. III. Lost Circulation/Breathing A. Lost circulation is possible, it will most likely appear at the second fault crossing. Losses have also been reported during casing running; pay close attention to running speeds. B. Breathing was experienced in V-108 and suspected in V-109. It is possible in this well. IV. Kick Tolerance/Integrity Testing A. The 9 5/a" casing will be cemented to surface. B. The 7" casing will be cemented with 15.8 Ib/gal tail and 11.0 Ib/gal lead cement to 500' MD above the Top Schrader Ma 4,328' and in two stages. a. The Kick Tolerance for the surface casing is 50.5 bbls with 10.3 ppg mud, 12.8 ppg LOT, and a 9.6 ppg pore pressure. Integrity Testing -12.8 ppg EMW LOT C. The 4-~/z" production liner will be cemented with 15.8 ppg tail cement to the liner top. a. The Kick Tolerance for the intermediate casing is infinite with 10.3 ppg mud, 11.0 ppg FIT and a 9.9 ppg pore pressure. Integrity Testing -11.0 ppg EMW FIT V. Stuck Pipe A. Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. B. Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions C. We do not expect stuck pipe if the hole is kept adequately clean. VI. Hydrogen Sulfide V Pad is no designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Personal monitors must be worn at all times. Recent HzS data from the pad is as follows: Adjacent Producers at Surface: Adjacent Producers at TD: V-109 10 ppm V-107 N/A V-113 5 ppm V-108 N/A VII. Faults A. Two faults are expected to be crossed by V-112i. Losses are expected to be associated with fault 2. Be prepared with LCM strategy. Details are listed below for reference: MD TVD TVDss Throw Fault 1 Colville : 5,409' 3,353' 3,270' 55' NE Fault 2 Ku aruk : 5,986' 3,638' 3,555' 50' NE CONSULT THE V PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION V-112i Permit to Drill Application Page 14 • 2 5' TREE= CM/4-1/16 KB. ELEV - 8 54 V-112i Proposed Completion WELLHEAD= FMCGe BF_E1.EV --- -- - KOP= ------------------------------- 7 CSG HEAD = 11" 5M W/ 7" MANDF HANGER & PACK( Max Angle = 97 DEG @ 833 - TBG SPOOL = 11" X 11" ------- Datum MD = -------- ----------- - ~ ~ ~ ~ TBG HANGER = 11" X 4- Datum N D = I I ADP FLANGE = 11" X 4-1, 101' 20" X 34" 215.5 Ib/ft, A53 ERW Insulated Proposed TOC 3,830' 7", 26#, TCII to 4,330' Surface 4-112",12.6#/ft, L-80, TC-II,ID = 3.958", 7,217' 0.01522 BPF RA Tag in 7" 1 Jt 7 276, above TKUPC~- KupC Perfs 7,395`-7,441 ` TC-II, ID = 2.992", 7,582' 0.00870 BPF RA Tag in 4-1/~8 270, well inversion V-1121 Estimated Perf Depths Zone MD TVDss Inc. Perf Int. Feet 7" String 7395 -6462 68 7395-7441 46 - nng - - 2,222' 4-1 /2" 'X' Landing Nipple, ID = 3.813" 2,853' 9-518", 40 #/ft, L-80, BTC, ID = 8.835, 0.07583 BPF 3,167' Camco 4-1 /2" x 1" KBG-2 GLM 4,790' Camco 4-1/2'` x 1" KBG-2 GLM w/ DCK Shear Valve pinned to 2,500 7,211' 4-1/2" 'X' Landing Nipple, ID = 3.813' 7,232' 7" x 4-1/2"Baker 'PRM' Prod Pkr, ID = 3.875" 7,260' 4-1/2" 'XN' Landing Nipple, ID = 3.725" 7,281' 3-1 /2" TC-II x 4-1 /2" TC-II XO 7,293' Camco 3-1/2" x 1-1/2" MMG-W GLM 7,352' Camco 3-1 /2" x 1-112" MMG-W GLM 7,380' 3-1/2" Baker CMD Sliding Sleeve, ID = 2.813" 7,532' 3-1 /2" 'X' Landing Nipple, ID = 2.813" 7,562' 7" x 4-1/2" Baker Flex-Loc Liner Hanger (ID =2.992) w/ ZXF' Liner Top Pkr w/ 10' TBS (ID = 5.25") 7,575' 4-1/2" Baker SBR Assy w/ 4.0" Seal Diameter 7,711' 7", 26 #/ft, L-80, BTC-M, ID = 6.276", 0.0383 BPF TO TOC na. 3830' Proposed KupC Perfs 8,892' 4-1/2" PBTD 8,300-8,650 8,978' 4-1/2", 12.6#, L-80, IBT-M, ID = 3.958", 0.01522 BPF DATE REV BY COMMENTS DATE REV BY COMMENTS 01/12/06 MJM Original Completion 01/17/06 STG PRUDHOE BAY UNfr WELL: V-1121 PERMIT No: API No: 50-029-XXXXX-XX SEC 11, T11 N, R11 E, 653' FNL, 1876' FEL BP Exploration (Alaska) KB. ELEV = 82.5' `, A BF. ELEV = 54' Y ~ 1 KOP = Max Angle = 97 DEG @ 8337 Datum MD = j ~ Datum TV D = I I TREE= CIW 4-1/16 5M WELLHEAD = FMC Gen 5 CSG HEAD = 11" 5M W/ 7" MANDREL HANGER & PACKOFF TBG SPOOL = 11" X 11" 5M TBG HANGER = 11" X 4-1/2" ADP FLANGE = 11" X 4-1/16" 101' 20" X 34" 215.5 Ib/ft, A53 ERW Insulated 2,211' 4-1 /2" `X' Landing Nipple, ID = 3.813" Proposed TOC 3,830' 7", 26#, TCII to 4,330' Surface 4-1 /2",12.6#/ft, L-80, TC-II,ID = 3.958", 7,217' 0.01522 BPF RA Tag in 7" 1 Jt above TKUPC 7,276' KupC Perfs 7,395`-7,441 ` TC-II, ID = 2.992", 7,582' 0.00870 B P F RA Tag in 4-1 /2" 8,270, well inversion i Proposed Completion V-1121 Estimated Perf Depths Zone MD TVDss Inc. Perf Int. Feet 7" String 7395 -6462 68 7395-7441 46 - tying - - = 3. DATE REV BY COMMENTS DATE REV BY COMMENTS 01/12/06 MJM Original Completion 01/17/06 STG PRUDHOE BAY UNIT WELL: V-1121 PERMIT No: API No: 50-029-XXXXX-XX SEC 11, T11 N, R11 E, 653' FNL, 1876' FEL BP Exploration (Alaska) 2,853' f-j9-5/8", 40 #/ft, L-80, BTC, ID = 8.t 3,187' Camco 4-1/2" x 1" KBG-2 GLM 4,810' HCamco 4-112" x 1" KBG-2 GLM w/ DCK Shear Valve ~ pinned to 2,500 7,147' 4-1/2" `X' Landing Nipple, ID = 3.813" - 7,168' 7" x 4-1 /2" Baker `PRM' Prod Pkr, ID = 3.875" 7,196' 4-1 /2" `XN' Landing Nipple, ID = 3.725" 7,217' I 7, 261' 7, 320' 7,338' wU I 3-1 /2" TC-II x 4-1 /2" TC-II XO Camco 3-1/2" x 1-1/2" MMG-W GLM Camco 3-1/2" x 1-1/2"MMG-W GLM 3-1/2" 'X' Landing Nipple, ID = 2.813" ~; w~t~I G~ ,~ 2 G- ~7 0 ~--o ~; +~ ~ / ~'2or,4 . 7,562' 7 x 4-1/2" Baker Flex-Loc Liner Hanger (ID =2.992) w/ ZXP Liner Top Pkr w/ 10' TBS (ID = 5.25") 7,582' 4-1 /2" Baker SBR Assy w/ 4.0" Seal Diameter 7 711, 7", 26 #/ft, L-80, BTC-M, ID = 6.276", 0.0383 BPF TO TOC ~ 3830' Proposed KupC Perfs 8, 892' 4-1 /2" P BTD 8,300-8,650` ........ -----_ --------- E 5,172 --------_ ~ ~:. ~L-PAD -~~~~ ~ ~~~ ~~ 34 . 35 ~ 36 I I ~ N_ I ARID I T12N ,? ~ _ -_ ~ { I 15°p0' 00" I I T11N ,~ ~ PLANT ~ I ', K uan R UK ~ I $$ 77 ~~ *~ 03r 11s i s 2 '' 1' °~ 3 ~~ ~"~ PROJECT~~, I ^ v-120 ^ v-11s I ~ ~ AREA ° I ^ V-03 ^ V-213i I ~ I ^ V-110 ^ V-100 I _ I ^ v-111 ? i I ^ V-117 ~ ~~ ~~ v-Pay I ^ V- 03 I 0 I ~ I ^ V-212 ^ SLOT S-R I ,~ ~ ~ 11 ~ 12 ~~°. i N ^ V-106 FR ~ c I I ~ .._ I ^ V-1051 ^ V-01 ^ v-22,. i VICINITY MAP I I M ^ V-102 I ^ V-SPARE (aor s-E) I N.T.S. ^ V-201 I I m ^ V-107 ^ SLOT S-J (z I ^ V-02 ^ V-1041 m ^ V-204 ml I ^ V-210i ^ V-114 ~ ^ V-202 ^ V-119 zl I ^ V-214i ^ V-109 I ^ V-101 I I ^ V-211 i ^ V-113 I I ^ V-108 ^ V- 203 / I -~- V-112 I I oo I I I ~ ~ , ~ OF A~q ° I I `_ V-PAD ,`P ~ ° S °°~,~ ~ ° ° Tp SPINE ROAp ~' - - ° ~ _ _ ~ - - - ° ° ~~ WoA ~~Pp° , - ~ ~ ~ _ 'r~ °° Leonard J. O~Hanley °` ~ ~j0 ,,-' '~ LEGEND ~'s 11386 °°° ~ ~~ ~ AS-BUILT CONDUCTOR °°°°°°,,~~ ESSIOTlP~L ^ EXISTING CONDUCTOR NOTES SURVEYOR'S CERTIFICATE 1. DATE OF SURVEY: JANUARY 19 & 20, 2006. I HEREBY CERTIFY THAT I AM 2. REFERENCE FIELD BOOK: W006-01 PG's 29-31 PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, THE STATE OF ALASKA AND THAT NAD 27. GEODETIC POSITIONS ARE NAD-27. THIS PLAT REPRESENTS A SURVEY 4. BASIS OF HORIZONTAL CONTROL IS V-PAD MADE BY ME OR UNDER MY DIRECT OPERATOR MONUMENTATION SUPERVISION AND THAT ALL . DIMENSIONS AND OTHER DETAILS ARE 5. BASIS OF ELEVATION IS KUPARUK PIPELINE CONTROL. CORRECT AS OF JANUARY 20, 2006. ELEVATIONS ARE BP MEAN SEA LEVEL DATUM. 6. THE MEAN SCALE FACTOR FOR V-PAD IS 0.999909334. 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-112 Y=5,969,872.53 N= 9,999.92 70'19'38.754~~ ' " 70,3274317' 53 0' 4,627' FSL ' X= 590,427.66 E= 4630.00 149'15 59.917 149.2666436° 1,876 FEL F. Robert °RA KwN (~ ~~ CHECSPM ~p O I II ~ DATE: ~~UJn ~~ 1/20/06 ~~~ DRAWING: FRSes wov el-0a GREATER PRUDHOE BAY V-PAD SHEET` ~ ~~~~~p JDa N° AS-BUILT CONDUCTOR 0 1 20 0 ISSUED FOR INfORMAT[ON KWH SPM sxeixems ,wo ux SCALE: 1 ~ 1 N0. DAIE REVISION BY CHK m~~ u~wsx Ix-150' WELL V-112 by Schlumberger V-112 (P18) Proposal Report Date: January 27, 2006 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: Field: SUucture I Slot: BP Exploration Alaska Prudhoe Bay Unit - WOA V-Pad /Plan V-112 (S-A) ~ Vertical Section Azimuth: 298.000° O~ Vertical Section Origin: N 0.000 ft, E 0.000 ft O~' 3' TVD Reference Datum: Rotary Table Well: Plan V-112 (S-A) ~OVe TVD Reference Elevation: 81.50 ft relative to MSL Borehole: Plan V-112 ppp Sea Bed I Ground Level Elevation: 53.00 ft relative to MSL UWIIAPI#: 50029 Magnetic Declination: 24.328° Survey Name I Date: V-112 (P18) /January 27, 2006 Total Field Strength: 57579.839 nT Tort 1 AHD I DDI 1 ERD ratio: 136.441 ° / 4527.68 ft / 5.911 / 0.665 Magnetic Dip: 80.844° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: February 27, 2006 Location LatlLong: N 70.32743170, W 149.26664348 Magnetic Declination Model: BGGM 2005 Location Grid WE YIX: N 5969872.530 ftUS, E 590427.660 RUS North Reference: True North Grid Convergence Angle: +0.69055612° Total Corr Mag North -> True North: +24.328° Grid Scale Factor: 0.99990929 Local Coordinates Referenced To: Well Head Measured Vertical Comments Inclination Azimuth Subsea TVD TVp NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section R de de ft R R R ft de 1100 ft de de 1100 R de 100 R RUS RUS KIC u.uu u.uu cOV.VU -t5"LbU U.UU U.UU U.UU U.UU U.UU -I"I U.UUM U.UU U.VV bybytS/Y.b3 byU4ZLU6 N/U.3Z/431/U VV l4y.Z666434tS 100.00 0.00 250.00 18.50 100.00 0.00 0.00 0.00 0.00 -110.OOM 0.00 0.00 5969872.53 590427.66 N 70.32743170 W 149.26664348 200.00 0.00 250.00 118.50 200.00 0.00 0.00 0.00 0.00 -110.OOM 0.00 0.00 5969872.53 590427.66 N 70.32743170 W 149.26664348 300.00 0.00 250.00 218.50 300.00 0.00 0.00 0.00 0.00 -110.OOM 0.00 0.00 5969872.53 590427.66 N 70.32743170 W 149.26664348 Gl 326.50 0.00 250.00 245.00 326.50 0.00 0.00 0.00 0.00 -110.OOM 0.00 0.00 5969872.53 590427.66 N 70.32743170 W 149.26664348 400.00 0.00 250.00 318.50 400.00 0.00 0.00 0.00 0.00 -110.OOM 0.00 0.00 5969872.53 590427.66 N 70.32743170 W 149.26664348 KOP Bld 1.5/100 500.00 0.00 250.00 418.50 500.00 0.00 0.00 0.00 0.00 -110.OOM 0.00 0.00 5969872.53 590427.66 N 70.32743170 W 149.26664348 Bld 2.5/100 600.00 1.50 250.00 518.49 599.99 0.88 -0.45 -1.23 1.50 -110.OOM 1.50 0.00 5969872.07 590426.44 N 70.32743048 W 149.26665346 700.00 4.00 250.00 618.37 699.87 4.09 -2.09 -5.74 2.50 -110.OOM 2.50 0.00 5969870.37 590421.95 N 70.32742600 W 149.26669001 800.00 6.50 250.00 717.94 799.44 10.21 -5.22 -14.34 2.50 O.OOG 2.50 0.00 5969867.14 590413.39 N 70.32741745 W 149.26675973 900.00 9.00 250.00 817.02 898.52 19.23 -9.83 -27.01 2.50 O.OOG 2.50 0.00 5969862.38 590400.78 N 70.32740485 W 149.26686248 SV6 963.92 10.60 250.00 880.00 961.50 26.51 -13.55 -37.23 2.50 O.OOG 2.50 0.00 5969858.53 590390.60 N 70.32739468 W 149.2669 Crv 3/100 1000.00 11.50 250.00 915.41 996.91 31.14 -15.92 -43.73 2.50 74.26G 2.50 0.00 5969856.09 590384.13 N 70.32738822 W 149.2669 1100.00 12.64 263.31 1013.22 1094.72 46.81 -20.60 -63.97 3.00 61.25G 1.14 13.31 5969851.16 590363.95 N 70.32737542 W 149.26716219 1200.00 14.33 273.99 1110.47 1191.97 67.11 -21.02 -87.18 3.00 50.85G 1.68 10.69 5969850.47 590340.74 N 70.32737429 W 149.26735045 1300.00 16.38 282.27 1206.91 1288.41 91.99 -17.16 -113.31 3.00 42.87G 2.06 8.27 5969854.01 590314.57 N 70.32738483 W 149.26756232 1400.00 18.69 288.65 1302.27 1383.77 121.38 -9.04 -142.28 3.00 36.79G 2.31 6.38 5969861.78 590285.51 N 70.32740701 W 149.26779722 1500.00 21.17 293.62 1396.28 1477.78 155.20 3.32 -174.01 3.00 32.10G 2.48 4.98 5969873.75 590253.64 N 70.32744077 W 149.26805451 1600.00 23.76 297.58 1488.69 1570.19 193.35 19.89 -208.41 3.00 28.44G 2.59 3.96 5969889.90 590219.04 N 70.32748603 W 149.26833348 End Crv 1622.23 24.35 298.35 1508.99 1590.49 202.41 24.14 -216.41 3.00 O.OOG 2.65 3.47 5969894.06 590210.99 N 70.32749764 W 149.26839836 SV5 1645.29 24.35 298.35 1530.00 1611.50 211.92 28.65 -224.78 0.00 O.OOG 0.00 0.00 5969898.47 590202.57 N 70.32750997 W 149.26846621 1700.00 24.35 298.35 1579.84 1661.34 234.48 39.36 -244.63 0.00 O.OOG 0.00 0.00 5969908.94 590182.60 N 70.32753923 W 149.26862716 SV4 1777.01 24.35 298.35 1650.00 1731.50 266.22 54.44 -272.57 0.00 O.OOG 0.00 0.00 5969923.68 590154.48 N 70.32758042 W 149.26885371 1800.00 24.35 298.35 1670.95 1752.45 275.70 58.94 -280.91 0.00 O.OOG 0.00 0.00 5969928.08 590146.09 N 70.32759272 W 149.26892136 Base Perm 1831.89 24.35 298.35 1700.00 1781.50 288.85 65.19 -292.48 0.00 O.OOG 0.00 0.00 5969934.18 590134.45 N 70.32760977 W 149.26901516 WeIlDesign Ver SP 1.0 Bld( doc40x_56) Plan V-112 (S-A)\Plan V-112 (S-A)\Plan V-112\V-112 (P18) Generated 1/27/2006 12:06 PM Page 1 of 4 Measured Vertical Comments Inclination Azimuth Sub-Sea TVD TVD NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section ft de de ft ft ft ft ft de 100 ft de de 1100 ft de 1100 ft ftUS ftUS 1900.00 24.35 298.35 1762.06 1843.56 316.92 78.52 -317.19 0.00 O.OOG 0.00 0.00 5969947.22 590109.58 N 70.32764620 W 149.26921555 2000.00 24.35 298.35 1853.16 1934.66 358.15 98.10 -353.47 0.00 O.OOG 0.00 0.00 5969966.36 590073.07 N 70.32769968 W 149.26950975 2100.00 24.35 298.35 1944.27 2025.77 399.37 117.68 -389.75 0.00 O.OOG 0.00 0.00 5969985.49 590036.56 N 70.32775317 W 149.26980395 2200.00 24.35 298.35 2035.38 2116.88 440.60 137.26 -426.03 0.00 O.OOG 0.00 0.00 5970004.63 590000.05 N 70.32780665 W 149.27009815 SV3 2205.07 24.35 298.35 2040.00 2121.50 442.69 138.25 -427.87 0.00 O.OOG 0.00 0.00 5970005.60 589998.20 N 70.32780936 W 149.27011308 2300.00 24.35 298.35 2126.48 2207.98 481.82 156.84 -462.31 0.00 O.OOG 0.00 0.00 5970023.77 589963.54 N 70.32786013 W 149.27039235 SV2 2391.67 24.35 298.35 2210.00 2291.50 519.61 174.79 -495.56 0.00 O.OOG 0.00 0.00 5970041.31 589930.07 N7O.3279O916 W149.27O662O5 2400.00 24.35 298.35 2217.59 2299.09 523.05 176.42 -498.59 0.00 O.OOG 0.00 0.00 5970042.91 589927.03 N 70.32791361 W 149.27068656 2500.00 24.35 298.35 2308.70 2390.20 564.27 196.00 -534.87 0.00 O.OOG 0.00 0.00 5970062.05 589890.52 N 70.32796709 W 149.27098076 2600.00 24.35 298.35 2399.80 2481.30 605.50 215.57 -571.15 0.00 O.OOG 0.00 0.00 5970081.19 589854.01 N 70.32802057 W 149.27127497 2700.00 24.35 298.35 2490.91 2572.41 646.72 235.15 -607.43 0.00 O.OOG 0.00 0.00 5970100.32 589817.50 N 70.32807405 W 149.2715 SVl 2742.90 24.35 298.35 2530.00 2611.50 664.41 243.55 -622.99 0.00 O.OOG 0.00 0.00 5970108.54 589801.84 N 70.32809700 W 149.27169541 2800.00 24.35 298.35 2582.02 2663.52 687.95 254.73 -643.71 0.00 O.OOG 0.00 0.00 5970119.46 589780.99 N 70.32812753 W 149.27186339 9-5/8" Csg Pt 2852.67 24.35 298.35 2630.00 2711.50 709.66 265.04 -662.81 0.00 O.OOG 0.00 0.00 5970129.54 589761.76 N 70.32815570 W 149.27201834 2900.00 24.35 298.35 2673.12 2754.62 729.17 274.31 -679.99 0.00 O.OOG 0.00 0.00 5970138.60 589744.48 N 70.32818101 W 149.27215760 3000.00 24.35 298.35 2764.23 2845.73 770.40 293.89 -716.27 0.00 O.OOG 0.00 0.00 5970157.74 589707.97 N 70.32823449 W 149.27245182 UG4 3066.70 24.35 298.35 2825.00 2906.50 797.89 306.95 -740.46 0.00 O.OOG 0.00 0.00 5970170.50 589683.62 N 70.32827016 W 149.27264806 UG4A 3099.63 24.35 298.35 2855.00 2936.50 811.47 313.40 -752.41 0.00 O.OOG 0.00 0.00 5970176.81 589671.60 N 70.32828777 W 149.27274494 3100.00 24.35 298.35 2855.34 2936.84 811.62 313.47 -752.55 0.00 O.OOG 0.00 0.00 5970176.88 589671.46 N 70.32828797 W 149.27274603 3200.00 24.35 298.35 2946.44 3027.94 852.85 333.05 -788.82 0.00 O.OOG 0.00 0.00 5970196.02 589634.95 N 70.32834144 W 149.27304025 3300.00 24.35 298.35 3037.55 3119.05 894.07 352.63 -825.10 0.00 O.OOG 0.00 0.00 5970215.15 589598.44 N 70.32839492 W 149.27333447 3400.00 24.35 298.35 3128.66 3210.16 935.30 372.20 -861.38 0.00 O.OOG 0.00 0.00 5970234.29 589561.93 N 70.32844840 W 149.27362869 UG3 3494.77 24.35 298.35 3215.00 3296.50 974.37 390.76 -895.77 0.00 O.OOG 0.00 0.00 5970252.43 589527.33 N 70.32849908 W 149.27390752 3500.00 24.35 298.35 3219.77 3301.27 976.52 391.78 -897.66 0.00 O.OOG 0.00 0.00 5970253.43 589525.42 N 70.32850187 W 149.27392291 3600.00 24.35 298.35 3310.87 3392.37 1017.75 411.36 -933.94 0.00 O.OOG 0.00 0.00 5970272.57 589488.91 N 70.32855535 W 149.27421713 3700.00 24.35 298.35 3401.98 3483.48 1058.97 430.94 -970.22 0.00 O.OOG 0.00 0.00 5970291.71 589452.40 N 70.32860882 W 149.27451135 3800.00 24.35 298.35 3493.09 3574.59 1100.20 450.52 -1006.50 0.00 O.OOG 0.00 0.00 5970310.85 589415.89 N 70.32866230 W 149.27480558 3900.00 24.35 298.35 3584.19 3665.69 1141.42 470.10 -1042.78 0.00 O.OOG 0.00 0.00 5970329.98 589379.38 N 70.32871577 W 149.27509981 4000.00 24.35 298.35 3675.30 3756.80 1182.65 489.68 -1079.06 0.00 O.OOG 0.00 0.00 5970349.12 589342.87 N 70.32876925 W 149.27539 UG1 4010.65 24.35 298.35 3685.00 3766.50 1187.03 491.76 -1082.93 0.00 O.OOG 0.00 0.00 5970351.16 589338.99 N7O.32877494 W149.2754~ 4100.00 24.35 298.35 3766.41 3847.91 1223.87 509.26 -1115.34 0.00 O.OOG 0.00 0.00 5970368.26 589306.36 N 70.32882272 W 149.27568827 4200.00 24.35 298.35 3857.51 3939.01 1265.09 528.83 -1151.62 0.00 O.OOG 0.00 0.00 5970387.40 589269.86 N 70.32887619 W 149.27598250 4300.00 24.35 298.35 3948.62 4030.12 1306.32 548.41 -1187.90 0.00 O.OOG 0.00 0.00 5970406.54 589233.35 N 70.32892966 W 149.27627673 Ma 4328.96 24.35 298.35 3975.00 4056.50 1318.26 554.08 -1198.41 0.00 O.OOG 0.00 0.00 5970412.08 589222.77 N 70.32894515 W 149.27636193 4400.00 24.35 298.35 4039.73 4121.23 1347.54 567.99 -1224.18 0.00 O.OOG 0.00 0.00 5970425.68 589196.84 N 70.32898314 W 149.27657097 4500.00 24.35 298.35 4130.83 4212.33 1388.77 587.57 -1260.46 0.00 O.OOG 0.00 0.00 5970444.81 589160.33 N 70.32903661 W 149.27686520 4600.00 24.35 298.35 4221.94 4303.44 1429.99 607.15 -1296.74 0.00 O.OOG 0.00 0.00 5970463.95 589123.82 N 70.32909008 W 149.27715944 Na 4608.85 24.35 298.35 4230.00 4311.50 1433.64 608.88 -1299.95 0.00 O.OOG 0.00 0.00 5970465.65 589120.59 N 70.32909481 W 149.27718547 4700.00 24.35 298.35 4313.05 4394.55 1471.22 626.73 -1333.02 0.00 O.OOG 0.00 0.00 5970483.09 589087.31 N 70.32914355 W 149.27745368 OA 4789.95 24.35 298.35 4395.00 4476.50 1508.30 644.34 -1365.66 0.00 O.OOG 0.00 0.00 5970500.31 589054.47 N 70.32919165 W 149.27771836 4800.00 24.35 298.35 4404.15 4485.65 1512.44 646.31 -1369.30 0.00 O.OOG 0.00 0.00 5970502.23 589050.80 N 70.32919702 W 149.27774792 WeIlDesign Ver SP 1.0 Bld(doc4Ox_56) Plan V-112 (S-A)\Plan V-112 (S-A)\Plan V-1121V-112 (P18) Generated 1/27/2006 12:06 PM Page 2 of 4 Measured Vertical Comments Inclination Azimuth Sub-Sea TVD TVD NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section ft de de ft k ft ft ft d 1100 ft de de 1100 ft de 1100 ft ftUS ftUS tiaVO.w LY.JO cao.Ja wY.70.LO 4010./0 I00J.0/ 000.Oy -14V0A6 U.VU U.000 V.UU U.UU 0a/000L3/ 00yU l4.Ly IV /U.3LyL0U4`J VV l4`J.L /tlU4C1/ 5000.00 24.35 298.35 4586.37 4667.87 1594.89 685.47 -1441.86 0.00 O.OOG 0.00 0.00 5970540.51 588977.78 N 70.32930396 W 149.27833641 OBd 5020.45 24.35 298.35 4605.00 4686.50 1603.32 689.47 -1449.28 0.00 O.OOG 0.00 0.00 5970544.42 588970.31 N 70.32931489 W 149.27839659 5100.00 24.35 298.35 4677.47 4758.97 1636.12 705.04 -1478.14 0.00 O.OOG 0.00 0.00 5970559.64 588941.27 N 70.32935742 W 149.27863066 OBf Base 5185.09 24.35 298.35 4755.00 4836.50 1671.20 721.70 -1509.01 0.00 O.OOG 0.00 0.00 5970575.93 588910.20 N 70.32940292 W 149.27888104 5200.00 24.35 298.35 4768.58 4850.08 1677.34 724.62 -1514.42 0.00 O.OOG 0.00 0.00 5970578.78 588904.76 N 70.32941089 W 149.27892490 5300.00 24.35 298.35 4859.69 4941.19 1718.57 744.20 -1550.70 0.00 O.OOG 0.00 0.00 5970597.92 588868.25 N 70.32946436 W 149.27921915 CM2 5399.13 24.35 298.35 4950.00 5031.50 1759.43 763.61 -1586.66 0.00 O.OOG 0.00 0.00 5970616.89 588832.06 N 70.32951736 W 149.27951084 5400.00 24.35 298.35 4950.79 5032.29 1759.79 763.78 -1586.98 0.00 O.OOG 0.00 0.00 5970617.06 588831.74 N 70.32951783 W 149.27951340 5500.00 24.35 298.35 5041.90 5123.40 1801.02 783.36 -1623.26 0.00 O.OOG 0.00 0.00 5970636.20 588795.23 N 70.32957129 W 149.27980766 Fault Crossing 5519.86 24.35 298.35 5060.00 5141.50 1809.21 787.25 -1630.47 0.00 O.OOG 0.00 0.00 5970640.00 588787.98 N 70.32958191 W 149.2798 5600.00 24.35 298.35 5133.01 5214.51 1842.24 802.94 -1659.54 0.00 O.OOG 0.00 0.00 5970655.34 588758.72 N 70.32962476 W 149.280 5700.00 24.35 298.35 5224.12 5305.62 1883.47 822.52 -1695.82 0.00 O.OOG 0.00 .0.00 5970674.47 588722.21 N 70.32967822 W 149.2803 5800.00 24.35 298.35 5315.22 5396.72 1924.69 842.10 -1732.10 0.00 O.OOG 0.00 0.00 5970693.61 588685.70 N 70.32973169 W 149.28069042 Crv 4/100 5825.87 24.35 298.35 5338.79 5420.29 1935.36 847.16 -1741.48 0.00 -83.15G 0.00 0.00 5970698.56 588676.26 N 70.32974552 W 149.28076654 5900.00 24.86 291.34 5406.20 5487.70 1966.12 860.09 -1769.45 4.00 -76.77G 0.70 -9.46 5970711.15 588648.13 N 70.32978083 W 149.28099340 6000.00 26.05 282.44 5496.53 5578.03 2008.18 872.48 -1810.50 4.00 -68.73G 1.19 -8.89 5970723.05 588606.95 N 70.32981464 W 149.28132629 6100.00 27.74 274.42 5585.73 5667.23 2050.68 879.01 -1855.16 4.00 -61.57G 1.68 -8.03 5970729.03 588562.21 N 70.32983244 W 149.28168854 CMl 6127.48 28.28 272.37 5610.00 5691.50 2062.41 879.77 -1868.05 4.00 -59.77G 1.96 -7.43 5970729.64 588549.32 N 70.32983452 W 149.28179301 6200.00 29.83 267.33 5673.40 5754.90 2093.42 879.64 -1903.24 4.00 -55.36G 2.15 -6.95 5970729.09 588514.14 N 70.32983414 W 149.28207838 6300.00 32.26 261.16 5759.09 5840.59 2136.20 874.38 -1954.48 4.00 -50.07G 2.43 -6.17 5970723.21 588462.97 N 70.32981974 W 149.28249393 6400.00 34.95 255.80 5842.38 5923.88 2178.79 863.25 -2008.64 4.00 -45.60G 2.69 -5.36 5970711.43 588408.95 N 70.32978929 W 149.28293314 6500.00 37.84 251.14 5922.89 6004.39 2221.00 846.30 -2065.46 4.00 -41.85G 2.89 -4.66 5970693.80 588352.35 N 70.32974295 W 149.28339389 6600.00 40.89 247.07 6000.20 6081.70 2262.63 823.62 -2124.65 4.00 -38.70G 3.05 -4.08 5970670.41 588293.43 N 70.32968095 W 149.28387392 6700.00 44.08 243.47 6073.95 6155.45 2303.45 795.32 -2185.94 4.00 -36.05G 3.18 -3.59 5970641.38 588232.49 N 70.32960359 W 149.28437089 6800.00 47.36 240.27 6143.77 6225.27 2343.29 761.54 -2249.02 4.00 -33.81 G 3.28 -3.20 5970606.84 588169.83 N 70.32951124 W 149.28488239 Top HRZ 6824.15 48.16 239.55 6160.00 6241.50 2352.74 752.57 -2264.49 4.00 -33.33G 3.33 -2.99 5970597.69 588154.47 N 70.32948674 W 149.28500780 6900.00 50.72 237.40 6209.32 6290.82 2381.94 722.43 -2313.59 4.00 -31.93G 3.37 -2.84 5970566.96 588105.74 N 70.32940435 W 149.28540592 7000.00 54.14 234.79 6270.30 6351.80 2419.22 678.20 -2379.33 4.00 -30.33G 3.42 -2.61 5970521.94 588040.55 N 70.32928345 W 149.28593892 7100.00 57.62 232.40 6326.39 6407.89 2454.94 629.05 -2445.92 4.00 -28.99G 3.48 -2.39 5970472.00 587974.56 N 70.32914912 W 149.2864 Base HRZ 7164.80 59.89 230.95 6360.00 6441.50 2477.17 594.69 -2489.37 4.00 -28.24G 3.51 -2.24 5970437.12 587931.53 N 70.32905520 W 149.2868 K-1 7184.96 60.60 230.51 6370.00 6451.50 2483.93 583.61 -2502.92 4.00 -28.02G 3.53 -2.17 5970425.88 587918.12 N 70.32902494 W 149.28694091 7200.00 61.14 230.19 6377.32 6458.82 2488.93 575.22 -2513.04 4.00 -27.86G 3.53 -2.15 5970417.37 587908.11 N 70.32900202 W 149.28702293 7300.00 64.69 228.12 6422.86 6504.36 2521.03 516.99 -2580.35 4.00 -26.92G 3.55 -2.07 5970358.34 587841.51 N 70.32884286 W 149.28756866 TKD 7316.90 65.29 227.78 6430.00 6511.50 2526.25 506.73 -2591.72 4.00 -26.78G 3.57 -1.99 5970347.95 587830.26 N 70.32881483 W 149.28766083 TKC4 7392.55 68.00 226.31 6459.99 6541.43 2548.90 459.41 -2642.54 4.00 -26.20G 3.58 -1.94 5970300.02 587780.02 N 70.32868549 W 149.28807284 V-112 Tgt 1 7392.58 68.00 226.31 6460.00 6541.50 2548.91 459.39 -2642.56 4.00 0.64G 3.59 -1.90 5970300.00 587780.00 N 70.32868545 W 149.28807298 7400.00 68.30 226.32 6462.76 6544.26 2551.08 454.63 -2647.54 4.00 0.64G 4.00 0.05 5970295.18 587775.08 N 70.32867244 W 149.28811338 TKC3 7425.55 69.32 226.33 6472.00 6553.50 2558.57 438.18 -2664.77 4.00 0.63G 4.00 0.05 5970278.52 587758.05 N 70.32862747 W 149.28825305 TKC2 7439.90 69.89 226.33 6477.00 6558.50 2562.80 428.89 -2674.50 4.00 0.63G 4.00 0.05 5970269.12 587748.43 N 70.32860210 W 149.28833191 7500.00 72.30 226.36 6496.47 6577.97 2580.69 389.65 -2715.64 4.00 0.62G 4.00 0.05 5970229.39 587707.78 N 70.32849484 W 149.28866539 End Crv 7516.51 72.96 226.37 6501.40 6582.90 2585.66 378.77 -2727.04 4.00 O.OOG 4.00 0.05 5970218.38 587696.50 N 70.32846512 W 149.28875785 WeIlDesign Ver SP 1.0 Bld(doc40x_56) Plan V-112 (S-A)\Plan V-112 (S-A)\Plan V-112\V-112 (P18) Generated 1/27/2006 12:06 PM Page 3 of 4 Measured Vertical Comments Inclination Azimuth Sub-Sea TVD TVD NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section R de de R R R R R de 1100 R de de 1100 R de 1100 R ftUS RUS /OVV.UU /G.yb GGOA/ OOGOA/ bbU/.3/ ZbIU.C"I SZS.b`J -Z/254.t5Z U.UU U.UUIi U.UU Drp 4/100 7640.15 72.96 226.37 6537.64 6619.14 2622.91 297.21 -2812.60 0.00 -175.02G 0.00 7700.00 70.57 226.15 6556.37 6637.87 2640.72 257.91 -2853.67 4.00 -174.95G -3.98 7" Csg Pt 7710.81 70.14 226.11 6560.00 6641.50 2643.89 250.85 -2861.01 4.00 -174.93G -3.98 V-112 Tgt 2 7739.46 69.00 226.00 6570.00 6651.50 2652.21 232.22 -2880.34 4.00 180.OOG -3.98 LCU/KUPB 7766.69 67.91 226.00 6580.00 6661.50 2660.04 214.63 -2898.56 4.00 180.OOG -4.00 7800.00 66.58 226.00 6592.88 6674.38 2669.53 193.29 -2920.65 4.00 180.OOG -4.00 End Drp 7817.66 65.87 226.00 6600.00 6681.50 2674.52 182.07 -2932.28 4.00 O.OOG -4.00 Fault Crossing 7817.68 65.87 226.00 6600.01 6681.51 2674.53 182.05 -2932.29 0.00 O.OOG 0.00 Crv 10/100 7837.66 65.87 226.00 6608.18 6689.68 2680.16 169.39 -2945.41 0.00 -40.85G 0.00 End Crv 7857.64 67.39 224.58 6616.10 6697.60 2685.61 156.48 -2958.44 10.00 O.OOG 7.60 7900.00 67.39 224.58 6632.39 6713.89 2696.77 128.63 -2985.89 0.00 O.OOG 0.00 Crv 10/100 7990.31 67.39 224.58 6667.11 6748.61 2720.57 69.25 -3044.42 0.00 21.82G 0.00 V-112 Tgt 3 7997.95 68.10 224.89 6670.00 6751.50 2722.61 64.23 -3049.39 10.00 36.35G 9.29 8000.00 68.27 225.02 6670.76 6752.26 2723.16 62.88 -3050.73 10.00 36.30G 8.06 End Crv 8002.43 68.46 225.18 6671.66 6753.16 2723.82 61.29 -3052.33 10.00 O.OOG 8.06 Crv 10/100 8052.36 68.46 225.18 6689.99 6771.49 2737.54 28.55 -3085.27 0.00 0.34G 0.00 8100.00 73.23 225.20 6705.62 6787.12 2750.84 -3.16 -3117.19 10.00 O.OOG 10.00 8200.00 83.22 225.26 6726.00 6807.50 2779.80 -72.01 -3186.61 10.00 O.OOG 10.00 V-112 Tgt 4 8267.75 90.00 225.30 6730.00 6811.50 2799.88 -119.57 -3234.64 10.00 O.OOG 10.00 8300.00 93.22 225.29 6729.09 6810.59 2809.47 -142.24 -3257.55 10.00 O.OOG 10.00 End Crv 8335.74 96.80 225.29 6725.97 6807.47 2820.05 -167.28 -3282.85 10.00 O.OOG 10.00 8400.00 96.80 225.29 6718.36 6799.86 2839.01 -212.18 -3328.19 0.00 O.OOG 0.00 8500.00 96.80 225.29 6706.53 6788.03 2868.52 -282.04 -3398.76 0.00 O.OOG 0.00 8600.00 96.80 225.29 6694.69 6776.19 2898.03 -351.90 -3469.32 0.00 O.OOG 0.00 8700.00 96.80 225.29 6682.85 6764.35 2927.53 -421.76 -3539.89 0.00 O.OOG 0.00 8800.00 96.80 225.29 6671.01 6752.51 2957.04 -491.62 -3610.45 0.00 O.OOG 0.00 8900.00 96.80 225.29 6659.17 6740.67 2986.55 -561.48 -3681.02 0.00 O.OOG 0.00 TD / 4-1/2" Lnr 8977.49 96.80 225.29 6650.00 6731.50 3009.42 -615.61 -3735.70 0.00 O.OOG 0.00 Legal Description: Northi ng (Y) [RUS] Eastin g (X) [RUS] Surface : 4626 FSL 1876 FEL S11 T11N R11E UM 5969872.53 590427.66 V-112 Tgt 1 : 5086 FSL 4518 FEL S11 T11N R11E UM 5970300.00 587780.00 TD / BHL : 4010 FSL 332 FEL S10 T11N R11E UM 5969212.00 586700.00 U.UU b5i/U"IbZ.b"I btf/b3`J.4U N /U.3L25S"14bU VV l4`J.Ztf`JLLbZU 0.00 5970135.79 587611.94 N 70.32824221 W 149.28945142 -0.37 5970096.01 587571.35 N 70.32813481 W 149.28978432 -0.37 5970088.86 587564.10 N 70.32811552 W 149.28984383 -0.38 5970070.00 587545.00 N 70.32806460 W 149.29000052 0.00 5970052.19 587526.99 N 70.32801651 W 149.29014821 0.00 5970030.59 587505.16 N 70.32795820 W 149.29032730 0.00 5970019.23 587493.68 N 70.32792753 W 149.29042151 0.00 5970019.21 587493.66 N 70.32792749 W 149.29042164 0.00 5970006.39 587480.70 N 70.32789287 W 149.29052794 -7.08 5969993.33 587467.82 N 70.32785760 W 149.2906 0.00 5969965.16 587440.71 N 70.32778149 W 149.2908 0.00 5969905.08 587382.91 N 70.32761920 W 149.29133049 4.01 5969900.00 587378.00 N 70.32760548 W 149.29137081 6.38 5969898.64 587376.67 N 70.32760180 W 149.29138171 6.36 5969897.03 587375.09 N 70.32759745 W 149.29139467 0.00 5969863.89 587342.55 N 70.32750797 W 149.29166167 0.06 5969831.81 587311.02 N 70.32742131 W 149.29192039 0.06 5969762.13 587242.45 N 70.32723313 W 149.29248305 0.06 5969714.00 587195.00 N 70.32710314 W 149.29287235 -0.02 5969691.05 587172.36 N 70.32704118 W 149.29305803 -0.02 5969665.71 587147.37 N 70.32697273 W 149.29326308 0.00 5969620.28 587102.57 N 70.32685004 W 149.29363061 0.00 5969549.58 587032.86 N 70.32665910 W 149.29420254 0.00 5969478.88 586963.15 N 70.32646816 W 149.29477447 0.00 5969408.18 586893.44 N 70.32627722 W 149.29534638 0.00 5969337.49 586823.73 N 70.32608627 W 149.29591828 0.00 5969266.79 586754.02 N 70.32589533 W 149.29649017 0.00 5969212.00 586700.00 N 70.32574737 W 149.29693332 u WeIlDesign Ver SP 1.0 Bld( doc40x_56) Plan V-112 (S-A)\Plan V-112 (S-A)\Plan V-112\V-112 (P18) Generated 1/27/2006 12:06 PM Page 4 of 4 t>~ ~ • Schlumberger wELL V-112 (P18) HELD Prudhoe Bay Unit - WOA srnurrune V-Pad MagnetK Parameters Surface Lucatan NAD2l Alaska Slate Plarea. Zone 06. US Feot M11lscellaneous MWeI. RGGA!2C05 Ofp Bo.B4a' Date February 2). 2006 1930 /'iy S9ft90 /25)IIUS GrN Donv ~~fi9066fi 12' F g SbL. Plan V~!1213-AI NDRat. Rotary Tabfe f0!. SOfiabova MSLf Mag Dec .26.320' FS'. 5)5)90 nT Lon VIa9 15599'/ Eas ag '~50a 2I fi511U3 Scale Fau. 09999092091 PNn -1 f2 (P!01 Srvy Dale. January 29. 2006 0 800 1600 2400 3200 0 800 1600 2400 O O °° 3200 c m U >~ ~ 4000 4800 5600 6400 RTE .._.. _.. _. .' _.._.._.._.._.._.._.._.~_.._.._.._.._.._.._.._.._4_.._.._.._.._.._.._.._.._j._.. _.. _.._.. _.. _.. _.. _.. y.. _.. _.._ KOP Bld 1.5/100 ' Bld 2.51100 ............... .................................:..................................l..................................j..................................:............ Crv 31100 i End Crv Top -.._.._.. _. _i._.._.. _.._.._.._.._.._..i.. .. _. .................:.................................. Y........... F~on•cra5~1~~;._.. _.._.._.._.._.._.._...._.._.._ crv aeon .. ...............:............................. 0 800 1600 2400 3200 4000 4800 ••~• 5600 6400 ~:;~ Lnr 0 800 1600 2400 3200 Vertical Section (ft) Azim = 298°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-V by Schlumherger V-112 (P18) Proaosal Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure 1 Slot: V-Pad /Plan V-112 (S-A) ~ O~ Well: Plan V-112 (S-A) ro e Borehole: ppp Plan V-112 UWIIAPI#: 50029 Survey Name 1 Date: V-112 (P18) /January 27, 2006 Tort 1 AHD 1 DDI 1 ERD ratio: 136.441 ° / 4527.68 ft / 5.911 / 0.665 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location Latllong: N 70.32743170, W 149.26664348 Location Grid NIE YIX: N 5969872.530 ftUS, E 590427.660 ftUS Grid Convergence Angle: +0.69055612° Grid Scale Factor: 0.99990929 O~ Vertical Section Azimuth: Vertical Section Origin: 226.000° N 0.000 ft, E 0.000 ft ND Reference Datum: Rotary Table TVD Reference Elevation: 81.50 ft relative to MSL Sea Bed I Ground Level Elevation: 53.00 ft relative to MSL Magnetic Declination: 24.328° Total Field Strength: 57579.839 nT Magnetic Dip: 80.844° Declination Date: February 27, 2006 Magnetic Declination Model: BGGM 2005 North Reference: True North Total Corr Mag North -> True North: +24.328° Local Coordinates Referenced To: Well Head • Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section ft de de k ft ft ft ft de 1100 ft de de 1100 k de 1100 it ftUS ftUS O/UU .UV 44 .U8 L43.4/ OU/3.yJ blb0.4b -IUl`J .Jb /`JO .3L -CIt50. `J4 4.UU -3b.Ubh 3.~1 t3 -SA`J b`J/Ub41.3i5 b25iSL3L .4`J IV /V.SL`JbU3b`J VV l4`J.Yt543/Vtfy 6800 .00 47 .36 240.27 6143. 77 6225 .27 1088 .80 761 .54 -2249 .02 4.00 -33.81 G 3.28 -3.20 5970606. 84 588169 .83 N 70.32951124 W 149.28488239 Top HRZ 6824. 15 48. 16 239.55 6160. 00 6241. 50 1106. 16 752. 57 -2264. 49 4.00 -33.33G 3.33 -2.99 5970597. 69 588154. 47 N 70.32948674 W 149.28500780 6900 .00 50 .72 237.40 6209. 32 6290 .82 1162 .42 722 .43 -2313 .59 4.00 -31.93G 3.37 -2.84 5970566. 96 588105 .74 N 70.32940435 W 149.28540592 7000 .00 54 .14 234.79 6270. 30 6351 .80 1240 .43 678 .20 -2379 .33 4.00 -30.33G 3.42 -2.61 5970521. 94 588040 .55 N 70.32928345 W 149.28593892 7100 .00 57 .62 232.40 6326. 39 6407 .89 1322 .47 629 .05 -2445 .92 4.00 -28.99G 3.48 -2.39 5970472. 00 587974 .56 N 70.32914912 W 149.28647880 Base HRZ 7164. 80 59. 89 230.95 6360. 00 6441. 50 1377. 60 594. 69 -2489. 37 4.00 -28.24G 3.51 -2.24 5970437. 12 587931. 53 N 70.32905520 W 149.28683110 K-1 7184. 96 60. 60 230.51 6370. 00 6451. 50 1395. 04 583. 61 -2502. 92 4.00 -28.02G 3.53 -2.17 5970425. 88 587918. 12 N 70.32902494 W 149.28694091 7200 .00 61 .14 230.19 6377. 32 6458 .82 1408 .14 575 .22 -2513 .04 4.00 -27.86G 3.53 -2.15 5970417. 37 587908 .11 N 70.32900202 W 149.28702293 7300 .00 64 .69 228.12 6422. 86 6504 .36 1497 .02 516 .99 -2580 .35 4.00 -26.92G 3.55 -2.07 5970358. 34 587841 .51 N 70.32884286 W 149.28756866 TKD 7316. 90 65. 29 227.78 6430. 00 6511. 50 1512. 32 506. 73 -2591. 72 4.00 -26.78G 3.57 -1.99 5970347. 95 587830. 26 N 70.32881483 W 149.28 83 TKC4 7392. 55 68. 00 226.31 6459. 99 6541. 49 1581. 76 459. 41 -2642. 54 4.00 -26.20G 3.58 -1.94 5970300. 02 587780. 02 N 70.32868549 W 149.2 4 V-112 Tgt 1 7392 .58 68 .00 226.31 6460. 00 6541 .50 1581 .78 459 .39 -2642 .56 4.00 0.64G 3.59 -1.90 5970300. 00 587780 .00 N 70.32868545 W 149.28 98 7400 .00 68 .30 226.32 6462 .76 6544 .26 1588 .67 454 .63 -2647 .54 4.00 0.64G 4.00 0.05 5970295. 18 587775 .08 N 70.32867244 W 149.28811338 TKC3 7425. 55 69. 32 226.33 6472. 00 6553. 50 1612. 49 438. 18 -2664. 77 4.00 0.63G 4.00. 0.05 5970278. 52 587758. 05 N 70.32862747 W 149.28825305 TKC2 7439. 90 69. 89 226.33 6477. 00 6558. 50 1625. 94 428. 89 -2674. 50 4.00 0.63G 4.00 0.05 5970269. 12 587748. 43 N 70.32860210 W 149.28833191 7500 .00 72 .30 226.36 6496 .47 6577 .97 1682 .79 389 .65 -2715 .64 4.00 0.62G 4.00 0.05 5970229. 39 587707 .78 N 70.32849484 W 149.28866539 End Crv 7516 .51 72 .96 226.37 6501 .40 6582 .90 1698 .55 378 .77 -2727 .04 4.00 O.OOG 4.00 0.05 5970218. 38 587696 .50 N 70.32846512 W 149.28875785 7600 .00 72 .96 226.37 6525 .87 6607 .37 1778 .37 323 .69 -2784 .82 0.00 O.OOG 0.00 0.00 5970162. 61 587639 .40 N 70.32831460 W 149.28922620 Drp 4/100 7640 .15 72 .96 226.37 6537 .64 6619 .14 1816 .76 297 .21 -2812 .60 0.00 -175.02G 0.00 0.00 5970135. 79 587611 .94 N 70.32824221 W 149.28945142 7700 .00 70 .57 226.15 6556 .37 6637 .87 1873 .60 257 .91 -2853 .67 4.00 -174.95G -3.98 -0.37 5970096. 01 587571 .35 N 70.32813481 W 149.28978432 7" Csg Pt 7710. 81 70. 14 226.11 6560. 00 6641. 50 1883. 78 250. 85 -2861. 01 4.00 -174.93G -3.98 -0.37 5970088. 86 587564. 10 N 70.32811552 W 149.28984383 V-112 Tgt 2 7739 .46 69 .00 226.00 6570 .00 6651 .50 1910 .63 232 .22 -2880 .34 4.00 180.OOG -3.98 -0.38 5970070. 00 587545 .00 N 70.32806460 W 149.29000052 WeIlDesign Ver SP 1.0 Bld(docAOx_56) Plan V-112 (S-A)\Plan V-112 (S-A)\Plan V-112\V-112 (P18) Generated 1/27/2006 12:27 PM Page 1 of 2 Measured Vertical Comments Inclination Azimuth Sub-Sea TVD TVD NS EW DLS Tool Face Build Rate Walk Rate Northing Fasting Latitude Longitude Depth Section ft de de ft ft ft ft ft de 1100 ft de de 1100 ft de 1100 ft ftUS ftUS u;uinures End Drp Fault Crossing Crv 10/100 End Crv Crv 10/100 V-112 Tgt 3 End Crv Crv 10/100 V-112 Tgt 4 End Crv TD / 4-1/2" Lnr //oo.oa 7800.00 7817.66 7817.68 7837.66 7857.64 7900.00 7990.31 7997.95 8000.00 8002.43 8052.36 8100.00 8200.00 8267.75 8300.00 8335.74 8400.00 8500.00 8600.00 8700.00 8800.00 8900.00 8977.49 t7/. `J7 66.58 65.87 65.87 65.87 67.39 67.39 67.39 68.10 68.27 68.46 68.46 73.23 83.22 90.00 93.22 96.80 96.80 96.80 96.80 96.80 96.80 96.80 96.80 ZZb. UU 226.00 226.00 226.00 226.00 224.58 224.58 224.58 224.89 225.02 225.18 225.18 225.20 225.26 225.30 225.29 225.29 225.29 225,29 225.29 225.29 225.29 225.29 225.29 (ibt{U.UU tififi7.bU 7y:f5.y(i 174.fi;f -1tS'Jtf.b(i 4.UU 72fU.UU(i -4.UU U.UU by/UUbL.7S 6592.88 6674.38 1966.67 193.29 -2920.65 4.00 180.OOG -4.00 0.00 5970030.59 6600.00 6600.01 6608.18 6616.10 6632.39 6667.11 6670.00 6670.76 6671.66 6689.99 6705.62 6726.00 6730.00 6729.09 6725.97 6718.36 6706.53 6694.69 6682.85 6671.01 6659.17 6650.00 6681.50 6681.51 6689.68 6697.60 6713.89 6748.61 6751.50 6752.26 6753.16 6771.49 6787.12 6807.50 6811.50 6810.59 6807.47 6799.86 6788.03 6776.19 6764.35 6752.51 6740.67 6731.50 1982.83 182.07 1982.85 182.05 2001.08 169.39 2019.43 156.48 2058.52 128.63 2141.86 69.25 2148.93 64.23 2150.83 62.88 2153.09 61.29 2199.53 28.55 2244.51 -3.16 2342.28 -72.01 2409.87 -119.57 2442.09 -142.24 2477.69 -167.28 2541.49 -212.18 2640.78 -282.04 2740.07 -351.90 2839.36 -421.76 2938.65 -491.62 3037.94 -561.48 3114.88 -615.61 Northing (Y) [ftUS] 5969872.53 5970300.00 5969212.00 Legal Description: Surface : 4626 FSL 1876 FEL S11 T11 N R11 E UM V-112 Tgt 1:5086 FSL 4518 FEL S11 T11 N R11 E UM TD / BHL : 4010 FSL 332 FEL S10 T11 N R11 E UM Plan V-112 (S-A)\Plan V-112 (S-A)\Plan V-112\V-112 (P18) btf/92(i.yy N /U.:iL8U1(ib1 W 74y.2yU14tl21 587505.16 N 70.32795820 W 149.29032730 587493.68 N 70.32792753 W 149.29042151 587493.66 N 70.32792749 W 149.29042164 587480.70 N 70.32789287 W 149.29052794 587467.82 N 70.32785760 W 149.29063363 587440.71 N 70.32778149 W 149.29085611 587382.91 N 70.32761920 W 149.29133049 587378.00 N 70.32760548 W 149.29137081 587376.67 N 70.32760180 W 149.291 587375.09 N 70.32759745 W 149.2 7 587342.55 N 70.32750797 W 149.2 7 587311.02 N 70.32742131 W 149.29192039 587242.45 N 70.32723313 W 149.29248305 587195.00 N 70.32710314 W 149.29287235 587172.36 N 70.32704118 W 149.29305803 587147.37 N 70.32697273 W 149.29326308 587102.57 N 70.32685004 W 149.29363061 587032.86 N 70.32665910 W 149.29420254 586963.15 N 70.32646816 W 149.29477447 586893.44 N 70.32627722 W 149.29534638 586823.73 N 70.32608627 W 149.29591828 586754.02 N 70.32589533 W 149.29649017 586700.00 N 70.32574737 W 149.29693332 WeIlDesign Ver SP 1.0 Bld(doc40x_56 ) -2932.28 4.00 -2932.29 0.00 -2945.41 0.00 -2958.44 10.00 -2985.89 0.00 -3044.42 0.00 -3049.39 10.00 -3050.73 10.00 -3052.33 10.00 -3085.27 0.00 -3117.19 10.00 -3186.61 10.00 -3234.64 10.00 -3257.55 10.00 -3282.85 10.00 -3328.19 0.00 -3398.76 0.00 -3469.32 0.00 -3539.89 0.00 -3610.45 0.00 -3681.02 0.00 -3735.70 0.00 Fasting (X) [ftUS] 590427.66 587780.00 586700.00 O.OOG -4.00 0.00 5970019. 23 O.OOG 0.00 0.00 5970019. 21 -40.85G 0.00 0.00 5970006. 39 O.OOG 7.60 -7.08 5969993. 33 O.OOG 0.00 0.00 5969965. 16 21.82G 0.00 0.00 5969905. 08 36.35G 9.29 4.01 5969900. 00 36.30G 8.06 6.38 5969898. 64 O.OOG 8.06 6.36 5969897. 03 0.34G 0.00 0.00 5969863. 89 O.OOG 10.00 0.06 5969831. 81 O.OOG 10.00 0.06 5969762. 13 O.OOG 10.00 0.06 5969714. 00 O.OOG 10.00 -0.02 5969691. 05 O.OOG 10.00 -0.02 5969665. 71 O.OOG 0.00 0.00 5969620. 28 O.OOG 0.00 0.00 5969549. 58 O.OOG 0.00 0.00 5969478. 88 O.OOG 0.00 0.00 5969408. 18 O.OOG 0.00 0.00 5969337. 49 O.OOG 0.00 0.00 5969266. 79 O.OOG 0.00 0.00 5969212. 00 Generated 1 /27/2006 12:27 PM Page 2 of 2 by Schlumberger weu V-112 (P18) HELD Prudhoe Bay Unit - WOA sTauctuaE V-Pad K~ ~~~ ~.~ Surla~u L.... ~ N~Vlll AWS a Slala Plan s. Zune 0a. US Fee i~~e an. i. u h B GM'2u05 Uip: BO.BW' Ua{o. FeS~uary Z/.1006 N/0 X930 ~5a 9b/2 S]11U5 Grid G°nv: .069055612" y FIanV 1~2 9 I ND Raf /{ary al. bt SObaSeva MSL{ A May Uev 4]28" FS 5/5]90 nT Wta5 ~5 tl59~/ Easeng 11US Scab Fac1:09999092b91 PNn 21{'181 6400 6600 O O N C m 6800 U O F- 7000 7200 600 1800 2000 2200 2400 2600 2800 3000 .......... :..................................:..................................:............................................................:........:..................................:.....................................................................:............................... V-112 Tg[ 7 Entl Crv .._.._.. .. _.._ _.. _.. _..~._.._. .._.._.. _.._.._.._.._. ..-. -. c..- .- - .- - ~.. Csg Pt ._.._.._.._.._.. _.. _.. _.. _.._. .. .. -. _ .-. _ _ _ - V-112 Tgt 2 ......... y ........................ .....:................. ........ ....:...................................:..................................:.................................. j..................................,..................................; ............................... End Orp ` Fault Crossing LCUlKUPB TD 14-112" Lnr Crv 10/100 Crv 101100 '~ ~ V-112 Tgt 4 End Crv -112 (Pi End Crv ..........y ..................................i.................................. ~........... ........ .. ... _..... ~ ............. ..............y. .......... .... .....I..................................0..................................y............................... Crv 10/100 V-112 Tgt 3 End Crv 6400 6600 6800 7000 7200 600 1800 2000 2200 2400 2600 2800 3000 Vertical Section (ft) Azim = 226°, Scale = 1(in):200(ft) Origin = 0 N/-S, 0 E/-V by Schlumberger ~LL V-112 (P18) F~E`D Prudhoe Bay Unit - WOA s,aD~.DRE V-Pad lagne- ~ Suna~s ~ A/.U[/ P s_ZIr1 US Fa.. ~ b M1luce a M1IOON. BGGA12005 OiV ~~~-- L , i-. ~~,ii ~ lal N]0 y M. a. GrJ C~~ ~ • ~> >a ~ Pay': ~' ~ r TAD R.•i ~ w 815011 apove MSLI ll~-A R hleyD . CI a Sum a %an. 2P'~9i rvY Daa 1000 n n ~ 500 Z 0 0 c n °~ 0 m U V V V -500 -1000 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 -4000 -3500 -3000 -2500 -2000 -1500 c« W Scale = 1(in):500(ft) E »> 1000 500 0 -500 -1000 1000 -500 0 • Oilfield Services, Alaska Schlumberger Drilling & Measurements C] Schlum~erger 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8367 Friday, January 27, 2006 Shane Gagliardi Prudhoe Bay V-112 (P18) BP Exploration Alaska Nabors 9ES Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analysis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two thousand feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey Program: Instrument Type Start Depth End Depth CB GYRO SS 28.50'md 700.00'md MWD 700.00'md 2,100.00'md MWD + IFR + MS 700.00'md 8,977.49'md Close Approach Analysis results: Under method (2), all wells may flow. Note: Well WKUPST-01 fails the conventional Major Risk rules. However, this is a plugged and abandon exploration well. A Tolerable Collision Risk worksheet should be filled out to assess any risk. The wells pass a 1:200 risk based rule. Note: It is recommended to run a gyro to +/- 700'md due to potential magnetic interference from offset casing. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drilling Aids to be provided: A drilling map and traveling cylinder will be provided. Checked by: Scott DeLapp 01/27/06 BP Alaska by '~~" Anticollision Report Company: BP Amoco Date: 1/27!2006 Time:..12:43:01 Page: I Field: Prudhoe Bay ':Reference Site: PB V Pad Co-ordinate(NE) Keference: Well: Plan V-112 (S-A), True North 12eferenceWel1: Plan V-112{S-A) Vertical(TVD) Reference: V=112 plan S-A 81.5 Reference Wellpath:,. Plan V-412 Ub: Oracle NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 20.00 ft Depth Range: 28.50 to 8977.49 ft ~ Maximum Radius:10000.00 ft Survey Program for Definitive Wellpath Date: 10/25!2005 Validated: No Planned From To Survev ft ft -- - -- - -- 28.50 700.00 Planned: Plan #18 V1 700.00 2100.00 Planned: Plan #18 V1 700.00 8977.49 Planned: Plan #18 V1 Reference: Error Model: Scan Method: Error Surface: Version: 6 1'oolcode Tool Name Principal Plan ~ PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North ', Ellipse + Casing CB-GYRO-SS Camera based gyro single shots MWD MWD -Standard MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD 'CVl) Diameter Hote Size Name - '; ft ft in ih ', I 2852.67 2711.50 9.625 12.250 9 5/8" ' 7710.81 6641.50 7.000 8.750 7" 8977.49 6731.50 4.500 6.125 41/2" Summary ~ -T -- --- _ - ----- ~- _ _T <-------------- Offset Wellpath -_--------->' Reference -Offset Ctr-Ctr No-Go Allowable ,_ ~ ' Site Well ' Wellpath MD MD Distance Area Devi$tion Warning ft ft ft ft ft J -- -- - EX WKUPST-01 - - WKUPST-01 - -- - - - WKUPST-01 V1 - __ 7977.09 - - 8260 00 _ ~ 3689.5713642.27 9952.69 =1 FAIL Major Risk PB L Pad L-01 L-01 V14 6856.42 6660 00 7626.01 78.55 7547.46 Pass: Major Risk PB L Pad L-02 L-02 V1 6251.50 2980.00 9961.03 67.37 9893.67 Pass: Major Risk PB L Pad L-02 L-02A V5 6200.00 2740.00 9984.44 70.25 9914.20 Pass: Major Risk PB L Pad L-02 L-02AP61 V2 6200.00 2740.00 9984.44 70.25 9914.20 Pass: Major Risk PB L Pad L-02 L-02PB1 V21 6251.50 2980.00 9961.03 67.37 9893.67 Pass: Major Risk PB L Pad L-03 L-03 V5 6400.00 10920.00 6243.63 194.52 6049.11 Pass: Major Risk ', PB L Pad L-101 L-101 V4 6360.56 4700.00 9879.09 100.63 9778.46 Pass: Major Risk ', PB L Pad L-102 L-102 V2 6000.00 7840.00 7754.53 178.79 7575.74 Pass: Major Risk ', PB L Pad L-102 L-102PB1 V10 5900.00 3464.00 8708.27 95.83 8612.44 Pass: Major Risk ', PB L Pad L-102 L-102PB2 V2 5900.00 3464.00 8778.02 94.46 8683.56 Pass: Major Risk PB L Pad L-103 L-103 V23 6346.89 9370.00 8065.62 164.27 7901.35 Pass: Major Risk PB L Pad L-104 L-104 V7 6100.00 9320.00 6550.57 199.53 6351.04 Pass: Major Risk PB L Pad L-105 L-105 V4 6400.00 8360.00 6933.81 151.24 6782.58 Pass: Major Risk PB L Pad L-106 L-106 V14 6600.00 6640.00 8260.81 96.27 8164.54 Pass: Major Risk PB L Pad L-107 L-107 V14 6700.00 8720.00 4538.14 119.90 4418.24 Pass: Major Risk PB L Pad L-108 L-108 V18 7000.00 8294.00 5197.57 88.73 5108.84 Pass: Major Risk PB L Pad L-109 L-109 V12 7614.69 7820.00 6469.89 104.22 6365.68 Pass: Major Risk PB L Pad L-110 L-110 V11 8975.65 7160.00 6981.04 134.83 6846.21 Pass: Major Risk PB L Pad L-111 L-111 V24 7100.00 7500.00 8981.53 85.66 8895.87 Pass: Major Risk PB L Pad L-112 L-112 V8 Out of range PB L Pad L-114 L-114 V15 6237.57 2860.00 9932.52 66.71 9865.81 Pass: Major Risk ', PB L Pad L-114 L-114A V4 6258.68 2920.00 9923.92 70.17 9853.75 Pass: Major Risk PB L Pad L-115 L-115 V7 Out of range PB L Pad L-116 L-116 V10 Out of range ', PB L Pad L-117 L-117 V11 Out of range PB L Pad L-118 L-118 V9 Out of range ', PB L Pad L-119 L-119 V9 6000.00 2560.00 9983.68 75.75 9907.93 Pass: Major Risk PB L Pad L-120 L-120 V8 6100.00 4960.00 9230.50 112.85 9117.65 Pass: Major Risk PB L Pad L-121 L-121 V14 7640.15 5260.00 8455.13 120.43 8334.70 Pass: Major Risk PB L Pad L-121 L-121A V1 8974.72 6160.00 7311.97 166.04 7145.93 Pass: Major Risk PB L Pad L-122 L-122 V5 Out of range PB L Pad L-123 L-123 VS Out of range PB L Pad L-123 L-123P61 V3 Out of range ', PB L Pad L-124 L-124 V13 Out of range ', PB L Pad L-124 L-124PB1 V5 Out of range j PB L Pad L-124 L-124P62 V4 Out of range ', PB L Pad L-200 L-200 V7 Out of range PB L Pad L-200 L-200L1 V3 Out of range PB L Pad L-200 L-200L2 V6 Out of range !i PB L Pad L-201 L-201 V6 5452.97 13698.24 7225.96 189.81 7036.16 Pass: Major Risk BP Alaska ~di'~ by Anticollision Report Companx: BP Amoco -- Date: 1/27/2006 Time; :12:43:01 gage: 2 , Field; Prudhoe Bay Reference Site: PB V Pad Co-ordinate(NE)Refcrence: Well: Plan V-112 (S-A), True North 'i Reference Well: 'Plan U-112 {S-A) Vertical (TVD) Reference: V-142 plan S-A 81.5 I Reference Wellpath: Plan V-112 Db: Oracle Summary --------=----- - Offset Wellpakh -----------> T ~ T - _-- Reference Offset Ctr-Ctr No-Go Allo~tiable Site Well Wellnath MD ~fD Dista~nCe Area lleviation Warning I ft ft ft ft ft / PB L Pad L-201 L-201 L1 V9 5373.44 13540.00 7158.11 197.50 6960.61 Pass: Major Risk PB L Pad L-201 L-201 L1 P61 V10 5825.87 12172.00 7568.87 191.79 7377.09 Pass: Major Risk ', PB L Pad L-201 L-201 L2 V5 5334.85 13490.00 7193.78 218.19 6975.59 Pass: Major Risk PB L Pad L-201 L-201 L3 V2 6000.00 9860.00 8129.94 132.00 7997.95 Pass: Major Risk '~ PB L Pad L-201 L-201 L3PB1 V6 6000.00 9378.00 8586.37 132.81 8453.56 Pass: Major Risk ', PB L Pad L-201 L-201 PB1 V12 Out of range PB L Pad L-201 L-201 P62 V3 5825.87 12327.00 7539.47 189.26 7350.21 Pass: Major Risk ', PB L Pad L-202 L-202 V5 Out of range PB L Pad L-202 L-202L1 V7 Out of range PB L Pad L-202 L-202L2 V6 Out of range ' PB L Pad L-202 L-202L3 V6 Out of range PB L Pad L-210 L-210 V6 5859.41 6440.00 8747.62 154.09 8593.53 Pass: Major Risk PB L Pad L-210 L-210P61 V8 5825.87 6160.00 8756.70 152.90 8603.80 Pass: Major Risk ', PB L Pad L-211 L-211 V6 Out of range ', PB L Pad L-211 L-211 P61 V6 Out of range PB L Pad L-212 L-212 V11 Out of range PB L Pad L-212 L-212P61 V9 Out of range PB L Pad L-212 L-212PB2 V2 Out of range PB L Pad L-214 L-214 V9 5959.58 7640.00 7668.08 180.60 7487.48 Pass: Major Risk ', PB L Pad L-214 Plan L-214A V2 Plan: L 5900.00 6580.00 7731.01 162.57 7568.44 Pass: Major Risk ' PB L Pad L-215 L-215 V7 Out of range ', PB L Pad L-215 L-215PB1 V4 Out of range ', PB L Pad L-215 L-215PB2 V2 Out of range ', ', PB L Pad L-216 L-216 V6 Out of range ', PB L Pad L-218 L-218 V4 Out of range ', PB L Pad L-250 L-250 V4 Out of range ', PB L Pad L-250 L-250L1 V14 Out of range PB L Pad L-250 L-250L2 V10 5900.00 12635.00 9923.91 191.72 9732.19 Pass: Major Risk PB L Pad L-250 L-250PB1 V3 Out of range PB L Pad L-250 L-250PB1_005 V4 Plan: Out of range ~, PB L Pad L-50 L-50 V1 6700.00 12814.00 6854.82 138.80 6716.01 Pass: Major Risk PB L Pad L-50 L-50PB1 V4 6700.00 12628.00 6844.60 143.76 6700.84 Pass: Major Risk ~I PB L Pad L-50 L-50P61_003 V6 Plan: P 6500.00 4000.00 9281.78 167.14 9114.64 Pass: Major Risk !i PB L Pad NWE1-01 L-100 V2 8347.52 8940.00 9548.05 214.14 9333.91 Pass: Major Risk PB L Pad NWE1-01 NWE1-01 V5 8969.72 5560.00 9914.01 225.34 9688.67 Pass: Major Risk ', ', PB L Pad Plan L-203 (N-0) Plan L-203 V6 Plan: PI Out of range ', ', PB L Pad Plan L-213 (S-O) Plan L-213 V5 Plan: PI 6100.00 6675.11 6247.40 140.52 6106.89 Pass: Major Risk ', PB L Pad Plan L-51 (S-B) Plan L-51 V1 Plan: Pla 6652.43 13085.11 8291.83 167.75 8124.09 Pass: Major Risk ', PB L Pad Plan L-52 (S-E) Plan L-52 V1 Plan: Pla 6300.00 3160.00 9605.20 70.05 9535.15 Pass: Major Risk ', PB V Pad Plan V-205 (S-P) Plan V-205 V2 Plan: PI 733.13 760.00 255.82 15.66 240.16 Pass: Major Risk ', PB V Pad Plan V-206 (S-S) Plan V-206 V1 Plan: PI 608.34 620.00 309.28 13.15 296.13 Pass: Major Risk ', ~', PB V Pad Plan V-3a06 (S-U) Plan V-3a06 V1 Plan: P 399.49 400.00 341.13 10.15 330.97 Pass: Major Risk ', PB V Pad V-01 V-01 V15 592.75 600.00 235.96 12.12 223.84 Pass: Major Risk PB V Pad V-02 V-02 V12 915.01 940.00 197.33 16.61 180.72 Pass: Major Risk ', PB V Pad V-03 V-03 V7 519.50 440.00 414.55 9.65 404.89 Pass: Major Risk PB V Pad V-100 V-100 V7 552.99 560.00 354.57 10.62 343.95 Pass: Major Risk ' PB V Pad V-101 V-101 V7 339.18 340.00 187.22 7.13 180.09 Pass: Major Risk 'i PB V Pad V-102 V-102 V5 499.34 500.00 243.62 11.07 232.55 Pass: Major Risk j PB V Pad V-103 V-103 V6 358.97 360.00 361.30 7.52 353.78 Pass: Major Risk PB V Pad V-104 V-104 V13 634.24 640.00 210.20 12.13 198.07 Pass: Major Risk PB V Pad V-105 V-105 V13 664.94 680.00 291.36 13.01 278.35 Pass: Major Risk ', ~~ PB V Pad V-106 V-106 V10 517.29 520.00 336.33 9.53 326.80 Pass: Major Risk ~~ PB V Pad V-106 V-106A V9 138.69 140.00 333.51 3.22 330.29 Pass: Major Risk ', '~ PB V Pad V-106 V-106APB1 V6 138.69 140.00 333.51 3.22 330.29 Pass: Major Risk PB V Pad V-106 V-106AP62 V2 138.69 140.00 333.51 3.22 330.29 Pass: Major Risk PB V Pad V-106 V-106AP63 V2 138.69 140.00 333.51 3.22 330.29 Pass: Major Risk PB V Pad V-107 V-107 V5 707.14 720.00 215.50 13.15 202.35 Pass: Major Risk PB V Pad V-108 V-108 V7 1831.77 1780.00 188.11 35.43 152.68 Pass: Major Risk PB V Pad V-109 V-109 V2 539.54 540.00 58.22 10.52 47.70 Pass: Major Risk ', PB V Pad V-109 V-109P61 VS 539.54 540.00 58.22 10.52 47.70 Pass: Major Risk PB V Pad V-109 V-109P82 V2 539.54 540.00 58.22 10.52 47.70 Pass: Major Risk ', PB V Pad V-111 V-111 V25 517.94 520.00 389.33 11.12 378.21 Pass: Major Risk ', PB V Pad V-111 V-111 PB1 V8 517.94 520.00 389.33 11.12 378.21 Pass: Major Risk ~~~"~~. ~ BP Alaska s by '~j4¢ Anticollision Report Company; BP Amoco Field: Prudhoe Bay Reference Site: ': PB V Pad Reference Well: Plan V-112 (S-A) Reference Wellpath: Plan V-112 Date: 1/27/2006 Tim Co-ordinate(NEJ Reference: Vertical' (CW) Reference: Summary - - - -_ <--------------- Offset Wellpath ----------------~ Reference Offset Ctr-Ctr 'Site Welt Wellpath MD MD Distance ft ft ft PB V Pad V-111 V-111 P62 V2 PB V Pad V-111 V-111 PB3 V6 ', PB V Pad V-113 V-113 V6 ', PB V Pad V-114 V-114 V5 PB V Pad V-114 V-114A V4 PB V Pad V-114 V-114AP61 V4 ', PB V Pad V-114 V-114AP62 V2 PB V Pad V-115 V-115 V5 PB V Pad V-115 V-115P61 V4 ', PB V Pad V-117 V-117 V9 ', PB V Pad V-117 V-117P61 V6 PB V Pad V-117 V-117PB2 V6 PB V Pad V-119 V-119 V13 PB V Pad V-120 V-120 V5 PB V Pad V-201 V-201 V8 PB V Pad V-202 V-202 V9 PB V Pad V-202 V-202L1 V5 PB V Pad V-202 V-202L2 V5 PB V Pad V-203 Plan V-203L1 OBd V4 PI PB V Pad V-203 Plan V-203L2 OBb V2 PI PB V Pad V-203 Plan V-203L3 Oba V2 PI ', PB V Pad V-203 Plan V-203L4 OA V2 Pla PB V Pad V-203 V-203 V17 PB V Pad V-204 V-204 V2 ', PB V Pad V-204 V-204L1 V2 ', PB V Pad V-204 V-204L1P61 V6 ~ PB V Pad V-204 V-204L2 V2 PB V Pad ~ V-204 V-204L2P61 V5 ', PB V Pad V-204 V-204L3 V3 PB V Pad V-204 V-204P61 V9 ~, PB V Pad V-204 V-204PB2 V2 PB V Pad V-210 V-210 V9 ~~ PB V Pad ~ V-211 V-211 V5 I PB V Pad V-212 V-212 V7 PB V Pad V-213 V-213 V5 PB V Pad V-213 V-213PB1 V5 PB V Pad V-214 Plan V-214 V1 Plan: PI ', PB V Pad V-214 V-214PB1 V2 ~', PB V Pad V-214 V-214PB2 V3 PB V Pad V-214 V-214PB3 V5 '~ PB V Pad V-214 V-214P64 V2 ', PB V Pad V-216 V-216 V8 ', PB V Pad V-221 V-221 V6 517.94 520.00 517.94 520.00 658.06 660.00 769.70 780.00 769.70 780.00 769.70 780.00 769.70 780.00 338.48 340.00 338.48 340.00 397.67 400.00 397.67 400.00 397.67 400.00 538.99 540.00 259.39 260.00 497.92 500.00 711.82 720.00 711.82 720.00 711.82 720.00 718.76 720.00 718.76 720.00 718.76 720.00 718.76 720.00 718.10 720.00 2075.13 2100.00 2075.13 2100.00 2075.13 2100.00 2075.13 2100.00 2075.13 2100.00 2075.13 2100.00 2075.13 2100.00 2075.13 2100.00 220.39 220.00 240.59 240.00 441.49 440.00 497.12 500.00 497.12 500.00 279.49 280.00 342.69 340.00 282.69 280.00 282.69 280.00 282.69 280.00 219.88 220.00 299.86 300.00 389.33 389.33 26.73 70.70 70.70 70.70 70.70 387.65 387.65 324.76 324.76 324.76 74.95 425.38 236.53 182.07 182.07 182.07 169.04 169.04 169.04 169.04 159.84 103.27 103.27 103.27 103.27 103.27 103.27 103.27 103.27 201.91 184.07 346.56 375.30 375.30 190.58 191.53 191.13 191.13 191.13 373.82 285.98 e: 12`43.01 Pager 3 Well: Plan V-Y12 (S-A), True North V-Y12 plan S-A 81.5 llh•. (lrorla No-Go Allowable Area. Deviation. ft ft 11.12 378.21 11.12 378.21 12.06 14.66 15.20 55.51 15.20 55.51 15.20 55.51 15.20 55.51 6.93 380.73 6.92 380.73 8.24 316.52 8.24 316.52 8.24 316.52 11.04 63.91 5.82 419.56 9.71 226.83 13.98 168.10 13.93 168.14 13.93 168.14 14.34 154.70 15.47 153.58 15.47 153.58 15.47 153.58 14.80 145.03 36.14 67.13 36.14 67.13 36.14 67.13 36.14 67.13 36.14 67.13 36.14 67.13 36.14 67.13 36.14 67.13 4.90 197.01 5.22 178.85 8.99 337.57 10.63 364.67 10.63 364.67 6.81 183.77 8.43 183.10 6.72 184.41 6.72 184.41 6.72 184.41 5.08 368.74 7.26 278.72 Warning Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk ', Pass: Major Risk I Pass: Major Risk ', Pass: Major Risk ', Pass: Major Risk '~ Pass: Major Risk Pass: Major Risk ', Pass: Major Risk !~ Pass: Major Risk Pass: Major Risk ', Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk ', Pass: Major Risk ', Pass: Major Risk Pass: Major Risk ', Pass: Major Risk Pass: Major Risk I Pass: Major Risk Pass: Major Risk Pass: Major Risk !, Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk ', Pass: Major Risk i Pass: Major Risk I zT_~ ~ BP Alaska by ~~~~9~~ Anticollision Report Company: BP Amoco Date: 1/27/2006 Timc: 12'.45:23 Page: 'Field: Prudhoe Bay Reference Site: PB V Pad Co-ordinate(NEf Reference: Well: Plan V-112 (S-A), True North 'Reference Well: Plan V-112 (S-A) Vertical (TVD) Reference: V-112 plan S-A 81.5 :Reference Wellpath: Plan V-112 [)b: Oracle NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM ~~~ Interpolation Method: MD Interval: 20.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 8977.49 ft I Scan Method: Trav Cylinder North LL Maximum Radius:10000.00 ft Error Surface: Ellipse + Casing Survey Program for Definifive Wellpath '~ Date: 10/25!2005 Validated: No Version: 6 Planned From To Survev - "foolcode Tool Name ft ft 28.50 700.00 Planned: Plan #18 V1 CB-GYRO-SS Camera based gyro single shots ', 700.00 2100.00 Planned: Plan #18 V1 MWD MWD -Standard ', 700.00 8977.49 Planned: Plan #18 V1 MWD+IFR+MS MWD +IFR + Multi Station ~ Casing Points -- -- --- - - - Mll 1'VD Diameter. Hole Size Name ft ft in in ,; 2852.67 2711.50 9.625 12.250 9 5/8" I ~, 7710.81 6641.50 7.000 8.750 7" ' 8977.49 6731.50 4.500 6.125 i 41/2" __ 1 Summary <- ------- -- -Offset Wellpath -------_-----_-> ' -- Keference Offset Ctr-Ctr No-Co :Vlovvablc Site Well -Wellpath MD MD Distadce Area Deviation Warning ft ft ft ft' ft EX WKUPST-01 WKUPST-01 WKUPST-01 V1 7407.07 6540.00 3310.99 0.00 3310.99 Pass: Minor 1!200 -158 100 0 loo Field: Prudhoe Bay Site: PB V Pad Well: Plan V-112 (S-A) Wellpath: Plan V-112 ', n Trnvelling Cylinder Azimuth (TFO+AZf) [deg] vs Centre to Centre Separation [IOOft/in] ,--., Site: PB V Pad Drilling Target Conf.: 95% Description: Map Northing:.:5970300.00 ft Map Fasting,: 587780.00 ft Latitude: 70° 19'43:268N P 1 2 3 4 Target: V-112 Poly .--~; Well: Plan V-112 (S-A) Based on; Planned Program Verkical Depth: 6670.00 ft below Mean Sea Level Local+N/-S 459.39 ft Locale+E/-W: -2642:56 ft Lonsitude: 149° 1 T 17:063 W Xft 3.62 -1293.28 -L096.17 260.00 Yft' 30001'- -1.:084:59 -1327.01 -3.13 Map E ft MapN ft 587780:00 5970600.00 586500:00 5969200.00 5867DOA0 5968960.00 588040.00 5970300.00 N • SONDRA D STEWMAN as-si,z52 140 BP EXPLORATION AK iNC "Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 SATE ~V-~~-- ORDER OF E --~'~J\~~~~ $ ~1~~.~~J~ l ~-- v r -~- ' ---'DOLLARS First National B rtk Alaska Anchorage, AK 99501 MEMO F 4..J~s~ _ ~f / ~ ~ h .~~--~ ~: Z 25 200060:99 14~~~6 2 27~~~ 156ti~~' 0 L40 • • TRANSMITTAL LETTER CHECKLIST WELL NAME ___ P~ l~~ ~i2, PTD# ~0~~ dZ d Development -7xService Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Compan~Zmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C: \j ody\transmittal_checkl i st • • N ~ ; ~, p ~, Q , , N N . ~ o ;~ ~ ~ ~ Q I ! ci a ~ ~ ~ I ~ : ~ ,. ~ ~. _ ~ ~ ,. ~ : 0 ~ ~ ,. W fn , E O . O ~ ~ ~ ~ P ~ ~ ~ ~~ ~ ~~ ; ' I I , ~ , W ~ 00 ~ ~ ~ ' , ~ ~, ~ m ~ ~~ ~ ~ ~~ ~ ..; ~ ( ~ 0 ~ ~ ~ ~ ~ ~ ¢ i m ~. ; a ' m ~ ~ m. ~ d ~ r « I . O ~ c ~ m o ~, ~ ~, to o. °o. ~, ~ , E N ~ ~ ~ ~ ~ O ~ ~ ~ W_ ~ O. ~ N, Z• ' ~. O: ' ' x. ~ ~ ' . ~ 3, x' ~ ~ ~ R. ~ m, o a ti' . 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