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Home My WebLink About206-162Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 8/7/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240807 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 2-72 50029237810000 224016 6/27/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 7/18/2024 HALLIBURTON RBT END 2-72 50029237810000 224016 7/18/2024 HALLIBURTON TEMP END 2-74 50029237850000 224024 7/20/2024 HALLIBURTON MFC MPU B-24 50029226420000 196009 7/16/2024 HALLIBURTON MFC MPU E-19A 50029227460100 224010 6/22/2024 HALLIBURTON COILFLAG NS-10 50029229850000 200182 7/18/2024 HALLIBURTON MFC NS-10 50029229850000 200182 7/18/2024 HALLIBURTON TEMP NS-32 50029231790000 203158 7/16/2024 HALLIBURTON MFC NS-32 50029231790000 203158 7/15/2024 HALLIBURTON TEMP PBU H-13A 50029205590100 209044 7/23/2024 HALLIBURTON RBT PBU L-246 50029237650000 223078 7/23/2024 HALLIBURTON IPROF PBU R-26B 50029215470100 210025 7/5/2024 HALLIBURTON RBT PBU R-36 50029225220000 194144 6/21/2024 HALLIBURTON RBT PBU V-216 50029232160000 204130 7/11/2024 HALLIBURTON IPROF PBU V-217 50029233340000 206162 7/11/2024 HALLIBURTON IPROF Please include current contact information if different from above. T39365 T39365 T39365 T39366 T39367 T39368 T39369 T39369 T39370 T39370 T39371 T39372 T39373 T39374 T39375 T39376PBU V-217 50029233340000 206162 7/11/2024 HALLIBURTON IPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.07 13:19:30 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, May 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-217 PRUDHOE BAY UN ORIN V-217 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/12/2023 V-217 50-029-23334-00-00 206-162-0 G SPT 4196 2061620 1500 722 726 726 724 139 146 146 145 4YRTST P Brian Bixby 4/10/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN ORIN V-217 Inspection Date: Tubing OA Packer Depth 441 1731 1649 1617IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230410143215 BBL Pumped:2.5 BBL Returned:1.5 Friday, May 12, 2023 Page 1 of 1            MEMORANDUM TO: Jim Regg �C I P.I. Supervisor { I \PtfCy `t ((Z- I t Cj FROM: Guy Cook Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, April 10, 2019 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. V-217 PRUDHOE BAY UN ORIN V-217 Ste: Inspector Reviewed By:I f P.I. Supry GiZ Comm Well Name PRUDHOE BAY UN ORIN V-217 API Well Number 50-029-23334-00-00 Inspector Name: Guy Cook Permit Number: 206-162-0 Inspection Date: 4/6/2019 .i Insp Num: mitGDC190406180935 Rel Insp Num: Wednesday, April 10, 2019 Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-217 Type Inj w' TVD 4194 Tubing s73 877 PTD 2061620 (Type TestSPT Test psi Isoo IA 160 2501 - JCS 2385 BBL Pumped:1.7 BBL Returned: 1.7 CIA 503 538 - n Interval 4YRTST p/P 1, Notes: A triplex pump and bleed trailer were used along with digital gauges for thisjob. ✓ Wednesday, April 10, 2019 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,May 07,2015 TO: Jim Regg P.I.Supervisor Z SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC V-217 FROM: Chuck Scheve PRUDHOE BAY UN ORIN V-217 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-217 API Well Number 50-029-23334-00-00 Inspector Name: Chuck Scheve Permit Number: 206-162-0 Inspection Date: 4/30/2015 Insp Num: mitCS150430140146 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-217 " Type Inj W TVD 4196 " Tubing 1326 1454 • 1449 1611 PTD 2061620 Type Test SPT Test psi 1500 IA 623 2502 2458 2473 Interval 4YRTST / PAF P / OA 182 211 217 220 Notes: H34ED MAY 2 2 2015 Thursday,May 07,2015 Page I of 1 1~~~>falge Prvje~ct Well History File haver I''age XF-IVZE 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 inspec/t'ion of the file. ~ - ' CQ oZ Well History File Identifier Organizing (done) RE CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria _ Project Proofing BY: Maria _ Scanning Pr~ep-a-r~ation BY: / Maria l ~,wo,aeo iiiNiiiiiuoiiiii ae.~a~~eed~ iuumiAiuiim DI ITAL DATA Diskettes, No. ^ Other, No/Type: Date: ~ I Date: ~' ~ ~ / x30= Date: ~'l` 1 OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ miumuiaiiu ~P ~ + ~ =TOTAL PAGES (Count does not include cover sheet) ~ q /s/ ~ / ' IIIII'lllllllllllll Production Scanning Stage 7 Page Count from Scanned File: ~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: r~/ ~ ~I ~ 9 /sl ~~ Stage 1 If NO in stage 1, page(s) discrepancies/were found:/ YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II'I II I II II ((III ReScanned II I II ~I II I I III I I III BY: Maria Date: /s/ Comments about this. file: Quality Checked III II'lll III II'I II P 10/6/2005 Well History File Cover Page.doc • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg (e 1 . 5 tl I/ DATE: Monday, May 09, 2011 P.I. Supervisor 1 1 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V -217 FROM: Lou Grimaldi PRUDHOE BAY UN ORIN V -217 Petroleum Inspector Src: Inspector Reviewed By: P.1. Supry NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN ORIN V -217 API Well Number: 50- 029 - 23334 -00 -00 Inspector Name: Lou Grimaldi Insp Num: mitLG110504152531 Permit Number: 206 -162 -0 Inspection Date: 5/4/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! v -217 J Type Inj. ii- TVD i 4196 1 IA 530 1590 1550 1550 P .T.D 061620 ' TypeTest SPT I Test psi y 1500 OA 1 185 210 190 190 LI Interval 'WPM p/F, P . Tubing 1200 1200 1200 1200 Notes: Good solid MIT, .4 barrels MEOH pumped and returned. ., M Monday, May 09, 2011 Page 1 of 1 04/28/11 Schlumberger NO. 5729 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambetl Street, Suite 400 Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 15 -09A BBKA -00096 PRODUCTION PROFILE (93 ^ ( f y�{( 03/14/11 1 • 0`7 1 17 -06 BBKA -00094 INJECTION PROFILE () Mt ( '°• [ ` 03/10/11 1 r s 1 C -12B BAUJ -00064 MEM PRODUCTION PROFILE 03/08111 1 s . Li 1 - G -23B BLPO -00079 MEM PRODUCTION PROFILE C( (e44 03/09/11 1 • " "Sii 1 16.08A BJGT -00022 GLS 1 9 91— ( c,, 03/07/11 1 • . ' 1 02 -18B BLPO -00087 MEM CBL .40 (4 —] 6 (0 03/25/11 _ . "' Y " 1 J -22A BJGT -00023 CBL •CIC) — 1 94 03/10/11 , . , ' 1 1 L -210 BLP0.00080 MEM INJECTION PROFILE —,)(:)`3 $.99 03/23/11 1 p°/ (p 1 V -105 BLPO -00091 MEM INJECTION PROFILE 4, 03/29/11 1 4y 1 V -220 BBSK -00065 INJECTION PROFILEMFL �atl . ♦ • ' - ( y � �'f ' i V -212 BD88-00096 MEM INJECTION PROFILE ' . , 04/03/11 1 C r 1 _ III L -214A BCRJ -00073 INJECTION PROFILE » it . 03/18/11 1 • 1 V -223 BAUJ -00071 MEM INJECTION PROFILE r.• t ' G a� ♦ 1 V -217 BAUJ -00077 {',1•4'110tlxWita}01 :1:W7iA�. !11 i3/y 1 3-05/0-29 BG4H- 00043 Zamg 03/20/11 1l 1 1-47A1M -20 BLPO -00092 MEM PRODUCTION PROFILE ' "' ragkiTi� tOrMZ4 1 w 1- 25A/K -22 BBSK -00057 �LL"�� ' T�Zk, 7 1 _ S -01C BCUE -00113 ' ' CBL 3 ' • 'ri� 1 11 -30 BD88 -00097 EM INJECTION PROFILE 1 '" -- O ' - 04/18/11 _ 1 F 1 04 -11A AWJI -00134 NJECTION PROFILE 0z , 0 __II 03/24/11 1 - 1 P2 -41 BG4H -00044 • RODUCTION PROFILE - „... - 03/22/11 1 a - >(s 1 _ D -26B BMSA -00009 SCMT !la- - * ' 03/24/11 T1ZMi� 1 02 -18B BLPO.00087 MEM PRODUCTION PROFILE - ' AL 03/24/11 1 Pr...... 1 Z -20 BPSG -00010 GLS )' -((7O 03/29/11 1 rt A 95 1 Y -29A BCUE -00122 MEM LDL l 4, — lac}, 03/20/11 1 36" - 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambe /l Street, Suite 400 900 E Benson Blvd Anchorage, AK 99503 -2838 • f,, t - ~. ,~„ ~. ,. ~, _ .~ y~a i 564 t~ K a ~ ' ~ ' MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm Marker.doc Schhenherger Alaska Data b Consulting Services 2525 GambeN Street, Suke 400 Anchorage, AK 99503-2938 ATTN: Beth Well Job # NO.5463 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD 09-45 AP3O-00077 s CROSSFLOW CHECK 01/28!10 1 1 V-217 82NJ-00051 MEMORY INJ PROFN.E 01/27/10 1 1 C-t0A B3S0-00038 RST 12/28/09 1 1 V-227 09AKA0146 OH MWD/LWD EDIT ~' ... 11/12/09 2 1 nca.crr r o i omrvma nrvu rcc i unrvma vnc a.vrr cncn i v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. f ll. ( V f Alaska Data & Consulting Services 2525 Gambell Street, Sufte 400 Anchorage, AK 99503-2539 P4-~ ~ p~ to ' f ~' p'~ V E ~; ~-- . ~ - 0?/05/10 ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ~,~~s`~~~~~: ;`'.~''~' ~`° ZGr~~s i bp ~~~~I~~~ OCT ~ 5 2~09 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, Oil & Gas Cons. Camm~w~io~ AnchorAp~ ~,a ~- (~'~-~- ~1- ~~'~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • ~ BP Exploration (Alaska ) inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date V-pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Finai top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbis ft na al V-Ot 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 v-03 2022150 500292312a00o0 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 V-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 V-t02 2020330 50029230700000 NA 7.75 NA 98.2 8/7/2009 V-103 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009 V-104 2021420 50029231030000 NA 1.5 NA 21.3 7/11/2009 V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-106A 2041850 50029230830100 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-109 2022020 50029231200000 NA 1.2 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 NA 1.5 NA 13.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-119 2040410 50029232ot0000 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-2o1 2012220 5002923o5a0000 SC leak NA 4 NA 90.6 8/7/2009 V-202 2030770 5002923t530000 NA 1.75 NA 12.8 7/11/2009 V-203 2051680 50029232850000 NA 2 NA 12.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061800 50029233380000 NA 1.8 NA 13.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-210 2042100 50029232310000 NA 2 NA 18.7 7/11/2009 V-211 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-212 2051500 50029232790000 NA 1.2 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 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 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7/12/2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 ".i'~ 2080200 50029233830000 NA 1.75 NA ~.6 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 os/o8/os S~h~~~g Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description N0.5271 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD H-35 AYTO-00018 CROSS FLOW CHECK j 05/09/09 1 1 14-35 ANHY-00087 INJECTION PROFILE - _ ~ 05/15/09 1 1 06-08A AViH-00012 IBP/FBS/CFS/GRADIO/PRESS/T P 05/11/09 1 1 A-44 AWLS-00017 SCMT 05/25/09 1 1 12-07A BOCV-00016 SBHP SURVEY 05/19/09 1 1 09-24 ANHY-00088 CROSS FLOW CHECK/IBP ~ 05!17/09 1 1 H-29A AYOO-00027 PPROF/RST - 05/19/09 1 1 09-09 AYTU-00032 CROSS FLOW CHECK - j 05/06/09 1 1 15-456 ANHY-00010 PRODUCTION PROFILE ~- 05/09/09 1 1 13-13A AYTU-00033 USIT - ~ ~ 05/08/09 1 1 M-196 AY3J-00024 PRODUCTION PROFILE 05/14/09 1 1 Z-12 ANHY-00084 INJECTION PROFILE 05/07/09 1 1 E-36A B1JJ-00018 MEM CNUSTP ~ e 05/18/09 1 1 X-30A B2WY-00005 C MEM PROD PROFILE 05/10/09 1 1 12-23 AYKP-00021 USIT L - 05/08/09 1 1 W-34A AWJI-00031 MEM PROD PROFILE 05/19/09 1 1 Z-146 AZCM-00022 PROD PROFILE/JEWELRY LOG ~ (o- 05/20/09 1 1 L1-21 62NJ-00006 PRODUCTION PROFILE 05/24/09 1 1 A-31A AZCM-00023 USIT Z~ - O (o G 05/22/09 1 1 H-196' B2WY-00004 MEM PROD PROFILE ~ 05/07/09 1 1 G-16 AYKP-00022 SCMT f / - 05/09/09 1 1 M-19B AY3J-00024 SCMT o 05/15/09 1 1 12-37 AWL9-00032 PRODUCTION PROFILE _ G,/G~ / 04/21/09 1 1 11-04A AYOO-00028 USIT f L~ ~ 05/21/09 1 1 18-30 61JJ-00015 MEM PROD PROFILE jG/ 05/13/09 1 1 4-14A/S-37 AYKP-00024 PRODUCTION PROFILE ~ o~ i 05/11!09 1 1 3-37/L-35 AWL9-00035 PROD/INJECTION PROFILE _ 05/22/09 1 1 3-37/L-35 AWL9-00035 TEMPERATURE SURVEY 05/20/09 1 1 V-217 AYOQ-00024 INJ PROFILE/RST WFL /~j(5 04/26/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE DOPY EAGR TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~ ~; ~~~~,~~~~ ,t ,~~ ., ,~~, ~ry~~, Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 -~ r~ DATA SUBMITTAL COMPLIANCE REPORT 11 /10/2008 Permit to Drill 2061620 Well Name/No. PRUDHOE BAY UN ORIN V-217 Operator BP EXPLORATION (ALASKA) INC MD 5155 TVD 4976 Completion Date 1/18/2007 Completion Status WAGIN Current Status WAGIN REQUIRED INFORMATION Mud Log No Samples No Directional Survey API No. 50-029-23334-00-00 DATA INFORMATION Types Electric or Other Logs Run: DIR / GR, GR / RES / PWD, AZI-DENS / NEU, USIT Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Ty Med/Frmt Number Name Scale Media No (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 1~ED D Asc Directional Survey pRpt Directional Survey C Lis 14550 Induction/Resistivity '~yl eg Cement Evaluation 'fig Corrosion C Las 15138 Temperature ''Log 15138 Temperature I `` C Lis 15166 Gamma Ray ~og 15166 Induction/Resistivity og 15166 Induction/Resistivity Well Cores/Samples Information: Name 0 5155 Open 1/25/2007 0 5155 Open 1/25/2007 142 5012 Open 3/22/2007 LIS Veri, CET 5 Col 142 5018 Case 3/22/2007 CEL, USIT, DSLT, GR< CCL 15-Jan-2007 Revised 5 Col 142 5018 Case 3/22/2007 CEL, USIT, DSLT, GR< CCL 15-Jan-2007 Revised 0 4874 Case 5/21/2007 CCL, Digt, GR w/Graphics LAS, PDF, TIF 5 Blu 1 0 4870 Case 5/21/2007 Temp Survey, GR, CCL 8- May-2007 101 5143 Open 5/31/2007 LIS Veri, GR, ROP, FET, DRHO, NPHI w/Graphics 25 Blu 108 5155 Open 5/31/2007 MD Vision Service 12-Jan- 2007 25 Blu 108 5155 Open 5/31/2007 TVD Vision Service 12-Jan- 2007 Sample Interval Set Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 11 /10/2008 Permit to Drill 2061620 Well Name/No. PRUDHOE BAY UN GRIN V-217 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23334-00-00 MD 5155 TVD 4976 ADDITIONAL INFORMAjION ' Well Cored? Y / Chips Received? '1`7'IQ- Analysis Y / N Received? Comments: Compliance Reviewed By: Completion Date 1/18/2007 Completion Status WAGIN Daily History Received? Formation Tops Current Status WAGIN ~" Y/N UIC Y Date: nn((~~~~~ ~~ STATE OF ALASKA ~ ~,S'-~O~ ,iUN ~ F~L~'~KA OIL AND GAS CONSERVATION COM ISSION Alaska Oil &~~~~~i6ilON OR RECOMPLETION REPORT AND LOG j~g0(10faj)° Revised 06/27!07: Put on Injection 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC 25.,05 zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ®WAG ^ Other No. of Completions One 1 b. Well Class: ^ Development ^ Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 1/18/2007 12. Permit to Drill Number 206-162 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1!8/2007 13. API Number 50-029-23334-00-00 ' 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 1/12/2007 14. Well Name and Number: PBU V-2171 4696 FSL, 1605 FEL, SEC. 11, 711 N, R11 E, UM Top of Productive Horizon: 4363' FSL, 627' FEL, SEC. 11, 711 N, R11 E, UM 8. KB (ft above MSL): 82.85' ~ Ground (ft MSL): 54.45' 15. Field /Pool(s): Prudhoe Bay Field / Orion , Total Depth: 4335' FSL, 436' FEL, SEC. 11, 711 N, R11 E, UM 9. Plug Back Depth (MD+TVD) 5063 ` 4887 Schrader Bluff 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 590698 y- 5969945 Zone- ASP4 10. Total Depth (MD+TVD) 5155 4976 ' 16. Property Designation: ADL 028240 TPI: x- 591680 y- 5969623 Zone- ASP4 Total Depth: x- 591871 y- 5969599 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1787' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIR / GR, GR / RES / PWD, AZI-DENS / NEU, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD .SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM- SIZE CEMENTING RECORD PULLED 20" 215.5# A-53 Surface 108' urface 108' 42" 26 sx Arc is Set A rox. 9-5/8" 40# L-80 28' 2999' 28' 2907' 12-1 /4" 469 sx AS Lite 409 sx Class 'G' 7" 26# L-80 26' 5146' 26' 4967' 8-3/4" 266 sx Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each i (MD+ND of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 4-1/2" Gun Diameter, 5 spf 3-1/2", 9.2#, L-80 4920' 4346', 4577', 4654', 4795' MD TVD MD TVD 4378' - 4388' 4227' - 4237 4598' - 4638' 4438' -4477' 25, ACID, FRACTURE, CEMENT SQUEEZE, ETC. 4668' - 4696' 4505' - 4532' DEPTH INTERVAL MD AMOUNT He KIND OF MATERIAL USED 4710' - 4726' 4546' - 4561' 4820' - 4870' 4652' - 4700' 2750' Freeze Protected w! 96 Bbls of Diesel 26. PRODUCTION TEST Date First Production: June 10, 2007 Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date Of Test: HOUTS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: FIOW TUbing PreSS. Ca51ng PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Gores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None $ ®F~ JUL 0 6 2007 Form 10-407 Revised 02/2007 o n ~ /"~ ~ ~~ ~ONTINUED ON REVERSE SIDE ~~~~~~/ .~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this fomti, if needed, and submit Permafrost Base 1825' 1787' detailed test information per 20 AAC 25.071. Top Ugnu 3047' 2953' None UG_MA (top of Ugnu Ma Zone 4170' 4027' UG_MB1 4220' 4075' UG_MB2 4287' 4140' UG MC 4358' 4208' Schrader Bluff NA 4427' 4274' Schrader Bluff NB 4450' 4296' Schrader Bluff NC 4486' 4331' Schrader Bluff NE 4494' 4339' Schrader Bluff NF 4551' 4393' Schrader Bluff OA 4597' 4437' Schrader Bluff OBa 4668' 4505' Schrader Bluff OBb 4709' 4545' Schrader Bluff OBc 4768' 4602' Schrader Bluff OBd 4820' 4652' Schrader Bluff OBe 4887' 4716' Schrader Bluff OBf 4923' 4751' Base Schrader Bluff OBf 4975' 4802' Formation at Total Depth (Name): 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg ing is true and correct to the best of my knowledge. Q ~ l ~7/Q Si ned 9 Terrie Hubble Title Technics! Assistant Date PBU V-2171 206-162 Prepared eyName/Number. Terre Hubble, 564-4628 Well Number Drilling Engineer: Brandon Peltier, 564-5912 Permit No. / A royal No. INSTRUCTIONS GeNer~au: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 welt completion report and 10-404 well sundry report when the downhole well design is changed. IreM 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. Irea 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Ireau 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: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only MEMORANDUM • TO: Jim Regg P.I. Supervisor ~ ~ ~(zz/e~ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 20, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-217 PRUDHOE BAY UN ORIN V-217 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UN ORIN V-217 Insp Num: mitCS070617100417 Rel Insp Num: API Well Number: 50-029-23334-00-00 Permit Number: 206-162-0 Inspector Name: Chuck Scheve Inspection Date: 6/16/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well v-217 Type Inj. W TVD 4196 IA 20 1970 1870 1860 P.T.D 2061620 TypeTCSt . SPT Test psi 1500 OA Ito 270 270 270 Interval mIT^~ P/F P Tubing soo soo soo soo Notes' Pretest pressures observed and found stable . Wednesday, June 20, 2007 Page 1 of 1 05!29!07 Schium6erger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well ~1C ~~~ ~-C~ ~ l~f~ Job # Log Description No. azs7 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Orion Polaris Date BL Color CD V-217 40014668 OH EDIT MWDILWD 01!12/07 2 1 5.401 40014121 OH EDIT MWDILWD 10/21/06 2 1 5-401P81 40014121 OH EDIT MWDILWD 10I08I06 2 1 W-210 11708631 MDT 02127/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: ara ^^~ BP Exploration (Alaska) Inc. i-~ jt~3 _ Petrotechnical Dala Center LR2-1 ,,~ .,_ _ _ "*..~J ~ ~ ' "" 900 E Benson Blvd Anchorage AK 99508-4254 ~lA~ ~ ~ ?_007 Date Delivered: ~a~:a~(~9~~~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 n ATTN: Beth n /' Received by:l~~i jV ~"""°-~-°'-°--- ~ ~ DELL L~~ '=~ ==1 r TI~AI~SI~/1~'~4L ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing (nspection(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax (907) 245-8952 1) 2) 3) 4) 5) s) 7) Signed 1 BL/ EDE Disk V - 217 Temperature Survey Prhnt Name: U=C avc~ - dCo2 ~ t 5i 3~ 0&May-07 ~. Date +T ~ +'~ ~f ~ ~~~~. ~cr~,~iic~ `1~;.~;e PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL : s~D51~~VC"r;OR.4GE((~~fiEL~10RY'JG.~QkVI WEBSITE :'JU~hMI.MEENOPY' t3G.CON1 DiMaster_CopY_00_PDSANC-20~c~Z_Word\DistrihuQon\T~++~~+~'a~_SheeLslTransmit_O~ig~al.doc STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ECEIVELI FHB 1 4 2001 WELL COMPLETION OR RECOMPLETION REPORT AND L~laska Oii & Gas Cons. Commission Q1cL P~ Y^' p1~ 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG zoAac zs.,os zoaAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Ab 1/18/2007 12. Permit to Drill Number 206-162 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1/8/2007 13. API Number 50-029-23334-00-00 `~ 4a. Location of Well (Governmental Section): Surface: 05' FEL ' S SEC ~ 7. Date T.D. Reached 1/12/2007 14. Well Name and Number: PBU V-2171 r , 4696 F L, 16 . 11, T11 N, R11 E, UM Top of Productive Horizon: 4363' FSL, 627' FEL, SEC. 11, T11 N, R11 E, UM - 8. KB Elevation (ft): 82.85' ~ 15. Field /Pool(s): Prudhoe Bay Field / Orion ~~ Total Depth: 4335' FSL, 436' FEL, SEC. 11, T11 N, R11 E, UM ~ 9. Plug Back Depth (MD+TVD) 5063- + 4887 ` Ft Schrader Bluff 4b. Location of Well (State Base Plane Coordinates): Surface: x- 590698 y- 5969945 Zone- ASP4 10. Total Depth (MD+TVD) 5155 - + 4976 ~- Ft 16. Property Designation: ADL 028240 ~ TPI: x- 591680 y- 5969623 Zone- ASP4 Total Depth: x- 591871 y- 5969599 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: DIR / GR, GR / RES / PWD, AZI-DENS / NEU, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING' DEPTH MD SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM ` TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 215.5# A-53 Surface 108' Surface 108' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 28' 2999' 28' 2907' 12-1/4" 469 sx AS Lite 409 sx Class 'G' 7" 26# L-80 26' 5146' 2 ' 4967' 8-3/4" 266 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 4-1/2" Gun Diameter, 5 spf 3-1/2", 9.2#, L-80 4920' 4346', 4577', 4654', 4795' MD TVD MD TVD 4378' - 4388' 4227 - 423T 4598' - 4638' 4438' -4477 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 4668' - 4696' 4505' - 4532' DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED 4710' - 4726' 4546' - 4561' 820' - 4870' 4652' - 4700' 2750' Freeze Protected w/ 96 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 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 pr ppce of oil, gas or water (attach separate shaei:ecessary). Submit core chips; if none, state "none". "`~(`t ~I, ~ ' ~ ~,} { ` ~""i `~J~ None Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE G 28 GEOLOGIC MARKER 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, Na,Me MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top Ugnu 3047' 2953' None UG_MA (top of Ugnu Ma Zone 4170' 4027' UG_MB1 4220' 4075` UG_M62 4287' 4140' UG MC 4358' 4208' Schrader Bluff NA 4427' 4274' Schrader Bluff NB 4450' 4296' Schrader Bluff NC 4486' 4331' Schrader Bluff NE 4494' 4339' Schrader Bluff NF 4551' 4393' Schrader Bluff OA 4597' 4437' Schrader Bluff OBa 4668' 4505' Schrader Bluff OBb 4709' 4545' Schrader Bluff OBc 4768' 4602' Schrader Bluff OBd 4820' 4652' Schrader Bluff OBe 4887' 4716' ~ Schrader Bluff OBf 4923' 4751' Base Schrader Bluff OBf 4975' 4802' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. / / ~Z t ~y107 Signed Terrie Hubble Title Technical Assistant Date PBU V-2171 206-162 Prepared eyName/Number. Te-rie Hubble, 564-4628 Well Number Drilling Engineer: Brandon Peltier, 564-5912 Permit No. / A royal No. 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. IreM 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 BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: V-217 Common Name: V-217 Test Date Test Type -- 1 /11 /2007 ~ LOT Test Depth (TMD) Test Depth (TVD) AMW I Surface Pressure !Leak Off Pressure (BHP) 2,999.0 (ft) 2,917.0 (ft) 8.80 (ppg) 1,230 (psi) ~ 2,563 (psi) EMW __ _I _- 16.92 (ppg) Printed: 1/30/2007 11:45:20 AM BP EXPLORATION Operations Summary Report Legal Well Name: V-217 Common Well Name: V-217 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date From - To 1 Hours i Task ~ Code NPT - _i_ _ -~ ---~- 1 /5/2007 20:00 - 00:00 ~ 4.00 ~ MOB ~ P 1/6/2007 100:00 - 03:00 3.001 MOB P 03:00 - 04:00 I 1.001 RIGU I P 04:00 - 10:30 I 6.501 DIVRTR I P 10:30 - 12:30 2.00 RIGU P 12:30 - 13:00 0.50 RIGU P 13:00 - 15:30 2.50 RIGU P Start: 1 /5/2007 Rig Release: 1/18/2007 Rig Number: Phase PRE PRE PRE PRE PRE PRE PRE 15:30 - 18:30 3.00 RIGU P PRE 18:30 - 19:00 0.50 RIGU P PRE 19:00 - 20:00 1.00 RIGU P PRE 20:00 - 21:00 1.00 RIGU P PRE 21:00 - 22:00 I 1.001 DIVRTR I P I I PRE 22:00 - 23:30 I 1.501 RIGU I P I I PRE 23:30 - 00:00 0.50 RIGU P PRE 1/7/2007 00:00 - 02:00 2.00 RIGU P PRE 02:00 - 04:30 2.50 RIGU P PRE 04:30 - 06:30 2.00 RIGU P PRE 06:30 - 07:30 1.00 RIGU P PRE 07:30 - 19:00 11.50 RIGU N WAIT PRE 19:00 - 20:00 1.00 RIGU P PRE 20:00 - 00:00 I 1 /8/2007 100:00 - 11:00 4.001 RIGU I N I WAIT I PRE 11.001 RIGU I N I WAIT I PRE 11:00 - 12:00 1.00 RIGU P PRE 12:00 - 12:30 0.50 RIGU P PRE 12:30 - 14:00 1.50 DRILL P SURF Page 1 of 9 ~ Spud Date: 1/8/2007 End: 1 /18/2007 Description of Operations Move mud pit complex away from sub base. Jack up rig and remove rig mats from under rig. Move sub off of V-122. Position rig for move to next well. Position rig close to well. Set wellhead equipment, tree and diverter behind rig. Lay herculite, spot rig over well. Install rig mats under rig and set down rig. Level sub base. Position and spot mud pits to rig. Level mud pits. 'Rig accepted for V-2171 operations ~ 03:00 hr, 1/6/2007. Change out 16" flow nipple adapter to 20". Prepare 4" drill pipe in pipeshed. Set annular diverter on 20" conductor pipe. Nipple up diverter lines and flow riser. Change out topdrive saver sub. Service topdrive and drawworks. Continue preparing drill pipe in pipeshed. Clean rig. Prepare rig floor to pick up drill pipe. Pick up 69 jts of 4" drill pipe and stand back in derrick. Pick up miscellaneous BHA tools to rig floor. Pick up 24 jts of 4" HWDP and stand back in derrick. Pick up and make up JAR stand and NM drill collar stand and set back in derrick. Perform surface diverter function test and accumulator D4 drill - OK. Witnessing of test waived by AOGCC rep. Lou Grimaldi. Test witnessed by BP WSL R. French and NAD TP B. Tiedemann. Prepare 81 joints of 4" drill pipe in pipeshed. *Super Suckers needed C~3 other BP drilling operation. Turn-around time for Super Suckers delayed due to necessity of steaming out of units due to cold temperatures of -35 deg. Hold Pre-Spud meeting with both crews. Continue preparing 4" drill pipe in pipeshed. Pick up 81 jts of 4" drill pipe and stand back in derrick. Pick up and make up BHA #1: New 12 1/4" HTC, MXL-1X bit, 1.5 deg PDM, NM Lead DC, NM STAB, MWD, NM STAB, NM XO, UBHO. HSE Meeting. WSL and TP discussed with the crew and support crew the feedback results from the investivative team regarding the allegations reported on 9ES. Wait on Super Suckers. General housekeeping. Installed new sprocket on drag chain. Prepare 9 5/8" casing. HSE Meeting. WSL and TP discussed with the crew the feedback results from the investivative team regarding the allegations reported on 9ES. Wait on Super Suckers. General housekeeping. Check inventory. Prepare 9 5/8" casing. Continue waiting on Super Suckers. General housekeeping and preparing 9 5/8" casing. Rig up Gyro Data. Fill mud lines and conductor. Check for leaks - OK. Spud V-217i. Drill from bottom of conductor @ 108' to 350'. 600 gpm, 900 psi off, 1,100 psi on, 80 rpm, 690 fUlbs TO off, 2.2k TO on, PU - 54k, SO - 52k, RWT - 54k, WOB - 15-20k. Printed: 7/30/2007 17:45:25 AM BP EXPLORATION Operations Summary Report Page 2 of 9 ~ Legal Well Name: V-217 Common Well Name: V-217 Spud Date: 1/8/2007 Event Name: DRILL+COMPLETE Start: 1/5/2007 End: 1/18/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/18/2007 Rig Name: NABOBS 9ES Rig Number: Date j From - To ;Hours Task Code I NPT j Phase Description of Operations - -- i __ 1_ _ _ __--- -- - 1/8/2007 12:30 - 14:00 1.50 DRILL P SURF Gyro survey every 100'. 14:00 - 15:00 1.00 DRILL P SURF Trip for BHA. Pick up NM STAB and Jar stand. Wash from 15:00 - 18:30 ~ 3.501 DRILL P 18:30 - 19:30 I 1.001 DRILL I P 19:30 - 00:00 I 4.501 DRILL I P '.1/9/2007 100:00 - 04:00 I 4.001 DRILL I P 04:00 - 04:30 ~ 0.50 ~ DRILL ~ P 04:30 - 06:30 2.00 DRILL P 06:30 - 07:30 1.00 DRILL P 07:30 - 12:00 I 4.501 DRILL I P 269' to 350'. Tagged fill ~ 335'. SURF Directionally drill from 350' to 725'. 600 gpm, 1,230 psi off, -- 1,400 psi on, 80 rpm, 1.2k TO off, 3.4k TO on, PU - 62k, SO - 61k, RWT - 62k, WOB - 15-25k. Gyro survey every 100'. SURF Gyro multi-shot surveys to surface. Rig down Gyro Data and Sperry. SURF Directionally drill from 725' to 1,196' ~ 600 gpm, 1,620 psi off, ^. 1,850 psi on, 80 rpm, 2k TO off, 4-5k TO on, PU - 72k, SO - 70k, RWT - 70k, WOB - 15-25k. AST - 5.23 hrs, ART - 2.31 hrs. SURF Directionally drill from 1,196' to 1,675' X600 gpm, 1,900 psi off, 2,070 psi on, 80 rpm, 1.6k TO off, 5.2k TO on, PU - 79k, SO - 77k, RWT - 77k, WOB - 15-25k. SURF Circulate shakers clean for wiper trip. 600 gpm, 1,900 psi, 80 rpm, 1.6k TO. 9.3 ppg. Mud Wt in /out SURF Wiper trip. POH from 1,675'to 1,090' with minimal problems. Pulled 30k over at 1,090'. Pumped out 1 stand from 1,090' - 1000' ~ 300 gpm, 600 psi., Pulled 1000' - 267' O.K. SURF RIH 267' - 1569' without problems, precautionary ream last stand to bottom SURF Directionally Drill from 1,675'-2631' -700 gpm, 2230 psi off, 2470 psi on, -80 rpm, 2k TO off, 6k TO on, -PU - 105k, SO - 97k, RWT - 98k, -WOB - 25-40k. 12:00 - 14:00 I 2.001 DRILL I N I SFAL I SURF Changed out suction valve and seat in #1 mud pump , #3 pod, 14:00 - 17:00 3.00 DRILL P 17:00 - 18:00 1.00 DRILL P 18:00 - 19:00 I 1.001 DRILL I P 19:00 - 21:00 I 2.001 DRILL I P 21:00 - 22:00 I 1.001 DRILL I P 22:00 - 00:00 I 2.001 DRILL I P ~ 1/10/2007 ~ 00:00 - 01:30 ~ 1.50 ~ DRILL ~ P 01:30 - 03:30 I 2.001 DRILL I P -Circ. during repairs C~ 161 gpm 320 psi SURF Directionally Drill from 2631'- 3010'.- -700 gpm, 3000 psi off, 3230 psi on, -80 rpm, 3k TO off, 6k TO on, -PU - 102k, SO - 91 k, RWT - 95k, -WOB 30-35k. SURF CBU 3x @ 710 gpm, 2955 psi, 100 rpm, 3k tq 9.5 ppg in /out mud wt. Monitor well, hole static SURF Wiper trip 3010 - 2280'. 10 - 25k overpull and hole started to swab SURF Backream f/2280' - 1579' -600 gpm, 2160 psi, 80 rpm @ 3k tq. No problems backreaming out of hole SURF RIH 1579 - 3010' Encountered some drag ~ 2408 - 2440, work through and hole cleaned up. RIH to bottom without issues SURF Circ. & condition mud for trip out to run casing. -CBU 1 x @ 675 gpm / 3115 psi, 100 rpm / 3k tq. -CBU 2x @ 710 gpm 3100 psi, 100 rpm / 3k tq SURF Monitor well, static 9.5 ppg mud wt. in/out POH from 3010' - 205', No problems POH, proper fill SURF Set back collars -L/D MWD Printed: 1/30/2007 11:45:25 AM BP EXPLORATION Page 3 of 9 Operations Summary Report Legal Well Name: V-217 Common Well Name: V-217 Spud Date: 1/8/2007 Event Name: DRILL+COMPLETE Start: 1/5/2007 End: 1/18/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/18/2007 Rig Name: NABOBS 9ES Rig Number: Date From - To ~ Hours Task Code NPT Phase __ --- - 1/10/2007 01:30 - 03:30 ~ 2.00 DRILL P SURF 03:30 - 04:30 04:30 - 06:30 06:30 - 12:30 1.00 CASE P 2.00 CASE P 6.00 CASE P SURF SURF SURF 12:30 - 13:00 13:00 - 16:30 16:30 - 19:30 19:30 - 00:00 1 /11 /2007 100:00 - 02:00 02:00 - 05:30 05:30 - 07:00 07:00 - 11:30 11:30 - 12:30 0.50 CEMT P 3.50 CEMT P 3.001 CEMT I P 4.501 DIVRTR I P 2.00 WHSUR P 3.50 BOPSU P 1.50 BOPSU P 4.50 BOPSU P 1.001 BOPSUFI P SURF SURF SURF SURF SURF SURF SURF SURF SURF Description of Operations -Break bit & UD Motor Clear BHA from rig floor PJSM ,Clean rig floor, UD BHA Tools & handling equip Rig up casing running equipment PJSM, Run 73 jts of 40# L-80 9 5/8" BTC surface casing. -Make up torque - 7,500 ft/Ibs avg. using Best-O-Life 2000 NM. -Ran 25 bowspring centralizers on first 25 joints with 2 locked down 10 ft above Float Shoe and Float Collar. Fill every joint with casing fill-up tool. -Pump down through base of permafrost (1785'-1895'), string taking wt. to go down. -No other problems running the casing to bottom. M/U hanger and Landing jt. and Land string on hanger 133k PUW / 95k SOW Float Shoe @ 2999' Float Collar @ 2915' R/D Franks fill-up tool and R/U Cement Head Circ. & Condition mud for cement job. -Staged up pump rates, ICP @ 8 bpm = 680 psi, FCP @ 8 BPM = 425 psi PJSM with rig crew and Dowell / Schlumberger cement crew Shut down pumps and switch to Dowell. Pump 5 bbls water and test lines to 3,500 psi - OK. Pump 69 bbls of 10.3 ppg MudPush II spacer @ 5 bpm avg, Drop bottom plug, pump 378 bbls of 10.7 ppg ArcticSet LiteCrete cement @ 6 bpm avg. Pump 86 bbls of 15.8 ppg Class "G" cement @ 5 bpm avg, Last 15 bbls with Durastone in tail cement, Drop top plug and kick out same with 10 bbls of water. Switch to rig pump and displace cement with 212 bbls of 9.5 ppg mud @ 6.5 bpm, Stop reciprocating pipe with 83 bbls left to bump due to pipe drag increasing, Slowed pump to 1.5 bpm/ 650 psi with 5 bbls prior to bumping plug. Bump plug on schedule @ 95% efficiency 3026 stks with 1,200 psi. CIP @ 17:00 hr. Bleed off pressure and check floats - OK. Full returns during all of circulating cementing and displacement. Returned -100bb1s of cement back to surface. PU - 160k, SO - 70k prior to landing casing. Flush all surface equipment, riser, Hydril, UD landing joint, cleanout cellar box and remove 4" valves, remove diverter line and set back hydril and secure same in cellar. Prep to install wellhead. Install casing head.Test metal to metal seal to 1,000 psi - 10 minutes - OK. Torque tubing head to casing head bolts. N/U BOP's, drilling nipple & flowline PJSM, Flush Stack, Set test plug and test joint, R/U to test Pressure test BOPE to 250 low psi for 5 minutes each, 4,000 high psi for 5 minutes each. Test annular preventer to 250 low psi for 5 minutes, 3,500 high psi for 5 minutes. Perform accumulator drill (D4). Witness of Test waived by AOGCC rep John Crisp, BP WSL Brian Buzby, NAD TP Bill Bixby. Pull Test Plug & Set Wear bushing Printed: 1/30/2007 11:45:25 AM i li- BP EXPLORATION Operations Summary Report Page 4 of 9 ~ Legal Well Name: V-217 Common Well Name: V-217 Spud Date: 1/8/2007 Event Name: DRILL+COMPLETE Start: 1/5/2007 End: 1/18/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/18/2007 Rig Name: NABOBS 9ES Rig Number: Date I From - To ~ Hours ; Task Code ~ NPT ! Phase Description of Operations ~~ I'' _ _ 1/11/2007 - 11:30 - 12:30 1.00 BOPSU - P _ __ -- SURF -_ _ _ __ ___ _ _- -Blow down choke Manifold, choke & kill lines Line up Valves for Drilling Operations 12:30 - 15:00 2.50 DRILL P PROD1 M/U BHA #2 -Bit, PDM, NM stab, LWD/MWD, 2xNMDC, HWDP, Jars, HWDP 15:00 - 15:30 0.50 DRILL P PROD1 MWD shallow hole test, 550 gpm / 1150 psi Good test 15:30 - 16:30 1.00 DRILL P PROD1 RIH to 2810' 16:30 - 17:00 0.50 DRILL P PROD1 Service TDS and Crown 17:00 - 18:00 1.00 CASE P SURF Break Circ. -Chart & Test Casing to 4000 psi for 30 min -Good Test 18:00 - 20:00 I 2.001 DRILL I P 20:00 - 20:30 I 0.501 DRILL I P 20:30 - 21:30 I 1.001 DRILL I P 21:30 - 00:00 I 2.501 DRILL I P 1/12/2007 100:00 - 11:30 I 11.501 DRILL I P 11:30 - 13:00 I 1.501 DRILL I P 13:00 - 20:30 7.501 DRILL P 20:30 - 21:00 I 0.501 DRILL I P 21:00 - 21:30 0.50 DRILL P 21:30 - 22:30 1.00 DRILL P PROD1 Drill Float Equipment & cement plus 20' of New hole to 3030'_ -550 gpm / 2035 psi -60 rpm /Torque 3k off / 4k on / 5k WOB -PUW 105 SOW 79 RtWt 93 PRODi Displace to New LSND 8.8 ppg mud 2 575 gpm Perform SPR's PROD1 Perform LOT ~ 2999' MD / 2917' Tvd -Leaked off C~3 1230 psi -EMW= 16.92 1.6 bbl pumped / 1.5 bbl returned PROD1 Directionally drill 8.75" intermediate hole from 3030' to 3480'. , -585 gpm, 1250 psi off / 1450 psi on, -100 rpm, 4.2k TO on, 3.7k TO off, -PUW 111k, SOW - 90k, RtWt - 101k, -WOB 5-15k, CECD - 8.89 ppg, AECD - 9.46 ppg. AST=0.6hrs/ART=0.9/ADT=1.5hrs Backream 90' prior to connections. PROD1 Directionally drill 8.75" intermediate hole from 3480' to 5155'. -585 gpm, 2000 psi off / 2120 psi on, -100 rpm, 5.5k TO on, 4.7k TO off, -PUW 137k, SOW - 108k, RtWt - 115k, -WOB 5-15k, CECD= 9.31 AECD=9.99 Backream 90' prior to connections. AST = 3.11 /ART = 2.34 /ADT = 5.45 PROD1 Circ. Hole clean -585 gpm 1 1855 psi -100 rpm / 4.4k tq -9.0 ppg in /out monitor well -static PROD1 Backream out hole pulling ~ drlg rates 5155' - 2999' -585 gpm / 100 rpm PROD1 Circ. Hole clean @ shoe -585 gpm / 1550 psi -IECD = 10.08 / FECD = 9.74 -9.0 ppg in /out monitor well -static PROD1 POOH f / 2995 - 2725', -Pulling 25k over and starting to swab - RIH with 1 stand PROD1 CBU 2x @ 2810' Printed: 1/30/2007 11:45:25 AM BP EXPLORATION Operations Summary Report Page5of9~ Legal Well Name: V-217 .Common Well Name: V-217 Spud Date: 1/8/2007 Event Name: DRILL+COMPLETE Start: 1/5/2007 End: 1/18/2007 '.Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/18/2007 ..Rig Name: NABOBS 9ES Rig Number: Date ~I From - To ~ Hours ~ Task Code NPT Phase ~ Description of Operations I 1/12/2007 21:30 - 22:30 1.00 DRILL P PROD1 -590 gpm / 1455 psi -100 rpm / 3k tq 75% Increased in cuttings @ Bottoms up IECD = 9.8 / FECD = 9.5 ppg 22:30 - 00:00 1.50 DRILL P PROD1 Monitor well -static 9.0 ppg in /out POOH f / 2995 - 256' (bha), No issues in POH after circulating 1/13/2007 00:00 - 02:30 2.50 DRILL P PROD1 UD BHA -UD 2 x NMDC'S -remove nuke sources -UD LWD & MWD tools Break Bit -UD Mud Motor & NM Stab Clear floor and UD tools off rig floor 02:30 - 03:00 0.50 CASE P PROD1 Pulled Wear Bushing, Flush Stack, set Test plug 03:00 - 05:00 2.00 CASE P PROD1 Change out 3 1/2" Variables rams to 7" rams Test to 250psi low / 4000 high Witness of test by Roy Hunt -NAD TP, Dave Newlon - BP WSL 05:00 - 06:30 1.50 CASE P RUNPRD R/U to run 7" casing -Make Dummy run with Landing joint 06:30 - 11:00 4.50 CASE P RUNPRD PJSM, M/U 7" 26# L-80 BTC-M casing shoe track. Bakerlocked all connections below float collar Check floats,O.K. Continue to run to shoe (2995') Avg Torgue 9200 ft/Ibs on BTC-M, doped with BOL 2000 Torque turn TCII connections, Avg. Torque 10,100 fUlbs, doped with Jet Lube Seal Guard 11:00 - 11:30 0.50 CASE P RUNPRD Break Circ. 9 5/8" shoe, -Staged pumps up to 5 bpm / 320 psi 11:30 - 13:00 1.50 CASE P RUNPRD cont, RIH w/ 7" 26# L-80 TCII casing Torque turn TCII connections, Avg. Torque 10,100 ft/Ibs, doped with Jet Lube Seal Guard 13:00 - 15:00 2.00 CASE N SFAL RUNPRD PJSM, Change out rubber cup on Franks fill up tool 15:00 - 18:00 3.00 CASE P RUNPRD cont, RIH w/ 7" 26# L-80 TCII casing Torque turn TCII connections, Avg. Torque 10,100 fUlbs, doped with Jet Lube Seal Guard Pumped down 3384 - 3440, no other problems seen RIH 18:00 - 19:00 1.00 CASE P RUNPRD M/U landing joint and rig down csg. handling equipment, Land casing PUW - 170k /SOW - 125k UD Franks fill up tool ,Blow down top drive, R/U cement head 19:00 - 20:30 1.50 CEMT P RUNPRD Break Circ. -Staged pumps up to 5 bpm / 350 psi minimal increase in cuttings on bottoms up PJSM with NAD rig crew and DS cementing crew 20:30 - 22:30 2.00 CEMT P RUNPRD Pump 5 bbls of water, Test lines to 4000 psi, Pump 20 bbl of CW, Pump 29 bbls of 12 ppg Mud push II, Drop Bottom plug, Pump 55 bbls of 15.8 ppg "G" cement with Durastone @ 5 bbls /min, Flush cement lines through "T", Drop Top Plug, Displace cement with clean 8.5 ppg seawater ~ 5 bbl/min, caught up to plug ~ 2500 strokes (142 bbls), Slowed to 2 bbl/min / 890 psi, with 10 bbls to bump, Bump Plug with 3362 strokes (95%eff) Printed: 1/30/2007 11:45:25 AM .~ • • BP EXPLORATION Page 6 of 9 Operations Summary Report ',Legal Well ',Common W 'Event Nam 'Contractor ',Rig Name: Date '~~ Name: V ell Name: e: Name: From - To ~ -217 V-217 DRILL+C NABOBS NABOBS Hours OMPLE ALASK 9ES Task ~, TE A DRI Code LING NPT ( Start I Rig Rig Phase Spud Date: 1/8/2007 : 1/5/2007 End: 1/18/2007 Release: 1/18/2007 Number: Description of Operations 1/13/2007 20:30 - 22:30 2.00 CEMT P RUNPRD and pressure up to 4000 psi, O.K., Full returns during cement job -CIP @ 22:15 hrs 22:30 - 23:00 0.50 CASE P RUNPRD Test casing for 30 min. @ 4000 psi -Good Test 23:00 - 00:00 1.00 CASE P RUNPRD Check floats, O.K. Blow down lines and R/D csg. handling equip and cementing equipment 1/14/2007 00:00 - 01:00 1.00 CASE P RUNPRD Install 7" packoff and seal assembly, Test to 5000 psi for 10 min. O.K. 01:00 - 02:30 1.50 EVAL P RUNPRD While Flushing stack - Perform LOT in 7" x 9 5/8" annulus with 9.Oppg brine Injection rate of 1 bbl /min Pumped 6.8 bbls away & 850 psi before breaking down to 720 psi -injected 3 bbl @ 1 bbl/min with 720 psi Stop pumping pressure bled down from 720 psi to 480 psi -continue to inject 2 bbl every hour 02:30 - 04:00 1.50 BOPSU P OTHCMP Replace 7" pipe rams with 3 1/2" x 6 variables Test rams with 4' test joint and 3 1 /2' test joint -250 psi low / 4000 psi high -all tests held 5 min. Witness by NAD TP Roy Hunt, BP WSL Dave Newton 04:00 - 04:30 0.50 PERFO P OTHCMP PJSM with Schlumberger DPC perforating crew and NAD rig crew 04:30 - 06:00 1.50 PERFO N HMAN OTHCMP Make up Schlumberger DPC Perforating gun -P/U gun #1 and #2, no booster in bottom of #2, Lay Down both guns Install booster in # 2 guns 06:00 - 07:30 1.50 PERFO P OTHCMP Make up 4.5" PJ4505 perforating guns, 5 spf - M/U firing head 07:30 - 08:30 1.00 PERFO P OTHCMP Makeup MWD and RIH with 4" HWDP -Shallow hole test MWD @ 290 gpm / 750 psi - O.K. 08:30 - 11:00 2.50 PERFO P OTHCMP RIH w/4" DP to 5062', tag float collar on depth -PUW 123k / SOW 93k 11:00 - 13:00 2.00 PERFO P OTHCMP Displace to 9.0 brine while logging with MWD tool 276 gpm / 750 psi logged @ 500'/hr correlated depths and set guns on depth ~ 4870' PUW 125k /SOW 90k 13:00 - 14:00 1.00 PERFO P OTHCMP PJSM with Schlumberger, -Run Test Fire sequence, Fire guns Initial losses ~ 8 bph Perf depths, 4378-4388, 4598-4638, 4668-4696, 4710-4726, 4820-4870 14:00 - 14:30 0.50 PERFO P OTHCMP POOH, 4870-4306', -9.0 ppg in /out, Monitor well losses ~ 24 bph 14:30 - 15:00 0.50 PERFO P OTHCMP Circ. one full circulation @ 290gpm / 750 psi loss rate @ 30 bbl / hr Monitor well, loss rate slowing down 15:00 - 19:00 4.00 PERFO P OTHCMP POH laying down 4" DP - losses @ 6 bph 19:00 - 23:00 4.00 PERFO P OTHCMP PJSM with Schlumberger PDC crew and NAD rig crew -R/U power tongs and gun handling equip. Printed: 1/30/2007 11:45:25 AM • BP EXPLORATION Operations Summary Report Page 7 of 9 Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: V ell Name: V e: Name: From - To ; -217 -217 DRILL+C NABOB NABOB Hours OMPLE S ALASK S 9ES Task ; TE A DRI Code LING NPT Start I Rig Rig Phase ~ Spud Date: 1/8/2007 : 1/5/2007 End: 1/18/2007 Release: 1/18/2007 Number: Description of Operations 1/14/2007 19:00 - 23:00 4.00 PERFO P OTHCMP L/D Perforating guns -All Shots fired Clear rig floor of handling equip. 23:00 - 00:00 1.00 PERFO P OTHCMP Run 19 stands in from derrick to lay down 1x1 1/15!2007 00:00 - 01:00 1.00 PERFO P OTHCMP Slip and cut drilling line, Service TDS and Draw Works 01:00 - 02:30 1.50 PERFO P OTHCMP Finish laying down DP from Derrick 02:30 - 17:00 14.50 EVAL P OTHCMP PJSM with SWS &NAD rig crew, -R/U wireline -Make Junk basket / 6.05" gauge ring run, Hit obstruction C~ 4628' -POH and change out to 5.95" Gauuge ring, RIH to 5050' -Apx. 1 qt of sand/metal shavings in Junk basket -Change out gauge ring to 6.05', RIH to 5050' -Apx. 1 pint of sand /metal shaving in junk basket -Change out to 6.125' gauge ring, RIH, Hit obstruction ~ 4628' unable to work through -make up USIT / DSLT / GR / CCL Logging tools -Run cement bond log, TOC C~ 3430' -34 bbls of brine lost during logging operations, total to well 129 bbl's HSE Meeting. BP WSL and NAD TP discussed with Jeff Quittschreiber crew the feedback results from the investigative team regarding the allegations reported on 9ES. 17:00 - 18:00 1.00 EVAL P OTHCMP Rig Down SWS wireline equipment 18:00 - 00:00 6.00 CLEAN N DPRB CLEAN Perform 7" casing cleanout run, wireline unable to get 6.125 gauge ring by 4628' -P/U BHA - 6.125 rerun Bit, Junk Basket, Bit Sub, 6.125 string mill, XO, 12 x Hwdp, Jars, 11 x Hwdp, -P/U4"DP1x1 -break circ 2900' cont. P/U 4" DP 1 x 1 to a depth of 3583' 1/16/2007 00:00 - 01:00 1.00 CLEAN N DPRB CLEAN cont. P/U 4" DP 1 x 1 to a depth of 4620' 01:00 - 01:30 0.50 CLEAN N DPRB CLEAN Screw in to Top Drive,. Break circ. ~ 3 bpm / 460 psi, 10 rpm 2.3 fUlb TO Work down to 4650', No indication of obstruction Work through 2x, no problems 01:30 - 02:30 1.00 CLEAN N DPRB CLEAN No issues RIH to 5062' Break Circ, .bring up flowrate to 205 strokes /min, 500 gpm / 1600 psi PUW - 125 /SOW 98k Pump 30 bbl of Hi-Vis brine sweep and circulate out Moderate amount of sand & shot debris cuttings on bottoms up, hole cleaned up after sweep. Complete circ. 1.5 x Monitor well, static - 9.0 brine in/out 02:30 - 07:00 4.50 CLEAN N DPRB CLEAN UD 4" DP and BHA -No Problems POH through Perfs. 07:00 - 07:30 0.50 BOPSU P RUNCMP Pull Wear bushing and make dummy run with hanger 07:30 - 09:00 1.50 BUNCO P RUNCMP Rig Up to run completion String Conducted Comprehensive PJSM with BP WSL, HES, Schlumberger and NAD TP & rig Crew Printed: 1/30/2007 11:45:25 AM • BP EXPLORATION Operations Summary Report Page 8 of 9 Legal Well Name: V-217 Common Well Name: V-217 Spud Date: 1/8/2007 Event Name: DRILL+COMPLETE Start: 1/5/2007 End: 1/18/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/18/2007 Rig Name: NABOBS 9ES Rig Number: Date ;From - To j Hours ~ Task Code NPT Phase Description of Operations 1/16/2007 09:00 - 00:00 15.00 BUNCO RUNCMP Run 3.5" 9.2# L-80 TC-II & Jewellery as per running detail. -Running 2 control lines, testing wire intergrity every 15 jts -Jet Lube Seal Guard tubing dope. -Pipe torque-turned 2300 ft Ibs 1/17/2007 00:00 - 08:00 8.00 BUNCO RUNCMP cont. to Run 3.5" 9.2# L-80 TC-II -Running 2 I-Wires lines, testing wire intergrity every 10 jts -Jet Lube Seal Guard tubing dope. -Pipe torque-turned 2300 ft Ibs Jewellery ran in completion string: WLEG,X Nipple, X Nipple, GLM, X Nipple, Packer, GLM, GLM, Packer, X Nipple, GLM, GLM, X Nipple, GLM, Packer, X Nipple, GLM, X NippleGLM, X Nipple 23 Half clamps and 81 Full Clamps For I-Wire 08:00 - 11:00 3.00 BUNCO RUNCMP PJSM with SWS, NAD TP & Rig Crew, BP WSL -RU Wireline ,Run GR LOG to Tie-in & verify Depths, R/D Wireline Ran log to 4700' 11:00 - 11:30 0.50 BUNCO RUNCMP M/U Hanger & Landing jt. -Tubing ran to 4920' 11:30 - 12:30 1.00 BUNCO RUNCMP Terminate I-Wires to Hanger and test to 5000 psi, O.K. 12:30 - 13:30 1.00 BUNCO RUNCMP Land Completion string -75k PUW / 60k SOW with 30k block wt. -Run in and tighten all lock down screws (450 fUlbs)and packing gland nuts 13:30 - 15:30 2.00 BOPSU P RUNCMP Drop 1 5/16" ball /rod, UD Landing Joint, Pressure up on tubing to 4000 psi to set packer and test for 30 min., Good Test,Bled tubing down to 2500 psi, Started to pressure up annulus, Pressure started coming up on Tubing @ 2800 psi(suspected DCR-1 shear valve leaking by), Pressure continued to equalized as we pressured up to 4000 psi, held for 30 min., good test, Bled off annulus and then tubing to 0 psi, pressure up on annulus to shear DCR-1 valve @ 2300 psi, Pumped both ways to insure the ability to pump. 15:30 - 16:00 0.50 BOPSU P RUNCMP Set TWC and test to 1000 psi from below 16:00 - 18:00 2.00 BOPSU P RUNCMP N/D BOPE's and set back 18:00 - 21:30 3.50 WHSUR P RUNCMP Install SBMS, NU Adaptor, Terminate I-Wires and check intergrity, Test to 5000 psi for i 5 minutes, O.K. 21:30 - 23:30 2.00 WHSUR P RUNCMP N/U tree and test to 5000, O. K. 23:30 - 00:00 0.50 WHSUR P RUNCMP PJSM with DSM &NAD rig crew, Rig up DSM Lubricator to pull TWC 1/18/2007 00:00 - 00:30 0.50 WHSUR P RUNCMP Pull TWC with DSM 00:30 - 01:00 0.50 WHSUR P RUNCMP Rig up to reverse circ.down clean brine and Brine with Corrision Inhibtor 01:00 - 02:30 1.50 WHSUR P RUNCMP PJSM, reverse circ.148 bbls of clean 9.0 ppg brine followed by 44 bbls of Corrision Inhibitor treated 9.0 ppg brine. -3 bpm @ 275 psi 02:30 - 04:30 2.00 WHSUR P RUNCMP PJSM with Little Red Pumping Services, NAD TP & Rig Crew, BP WSL -Reversed circ. @ 2 bpm, 96 bbls of 70 degree diesel to Printed: 1/30/2007 11:45:25 AM • BP EXPLORATION Page 9 of 9 Operations Summary Report Legal Well Name: V-217 Common Well Name: V-217 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date From - To i Hours Task Code ---~ - - _-_ -_ NPT 1/18/2007 102:30 - 04:30 ~ 2.00 WHSUR ~ P 04:30 - 05:30 1.00 WHSUR P 05:30 - 07:00 1.50 WHSUR P Spud Date: 1 /8/2007 Start: 1 /5/2007 End: 1 /18/2007 Rig Release: 1/18/2007 Rig Number: Phase ! Description of Operations RUNCMP freeze protect 3.5" x 7" annulus & 3.5 tubing ICP = 250 psi / FCP 500 psi -U-Tubed Diesel for 1hour,-Diesel C~? 2750 MD / 2500 tvd RUNCMP Set BPV with DSM Lubricator and test below to 1000 psi RUNCMP Blow down Injection lines and secure wellhead. Release Rig from V-217i ~ 07:00 hrs 1/18/2007 . A~ ~flN~ Printed: 1/30/2007 11:45:25 AM by ,ti, ~ ~~. ~. . ~~~, V-217 Survey Report Schlumberger Report Date: 12-Jan-07 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: V-Pad / V-217 Well: V-217 Borehole: V-217 UWI/API#: 500292333400 Survey Name /Date: V-217 /January 12, 2007 Tort /AHD / DDI / ERD ratio: 50.468° / 1263.86 ft / 4.820 / 0.254 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaULong: N 70.32762127, W 149.26444465 Location Grid NIE Y/X: N 5969945.180 ftUS, E 590697.940 ftUS Grid Convergence Angle: +0.69262747° -ifL.yS V .UU U.VV V.UU V.VV U.VV U.UV V.VV bybaa4b.la 17.05 100 .00 -0.19 0.27 0.27 0.24 -0.12 0.31 5969945.42 117.05 200 .00 -0.67 0.91 0.91 0.78 -0.46 0.12 5969945.95 217.04 299 .99 -1.30 1.74 1.74 1.48 -0.91 0.13 5969946.65 317.04 399 .99 -1.15 2.34 1.52 1.29 -0.81 1.33 5969946.46 Vertical Section Azimuth: 106.930° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 82.85 ft relative to MSL Sea Bed /Ground Level Elevation: 54.45 ft relative to MSL Magnetic Declination: 23.816° Total Field Strength: 57631.604 nT Magnetic Dip: 80.886° Declination Date: January 12, 2007 Magnetic Declination Madel: BGGM 2006 North Reference: True North Total Corr Mag North -> True North: +23.816° Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub,Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft n n ft ft ft n de loon ftUS ftUS lilt GYD CT DMS Last GYD CT DMS First MWD+IFR+MS U. UU 100.00 200.00 300.00 400.00 500.00 600.00 668.20 760.07 851.65 943.60 1039.51 1136.09 1231.82 1327.37 U.UU 0.31 0.42 0.54 0.79 2.87 5.31 7.88 10.72 11.74 11.66 13.06 14.39 15.71 16.44 1423.65 16.54 1518.87 16.77 1615.05 16.93 1709.59 16.45 1805.48 15.81 1901.44 17.28 1997.15 17.20 2092.71 16.94 2188.26 16.69 U.UU 332.90 324.36 329.77 151.03 155.23 155.15 159.07 161.93 157.39 149.01 138.95 129.80 117.80 108.94 105.40 100.57 100.63 100.02 99.86 102.27 101.85 101.44 101.03 416.99 516.72 584.47 675.12 764.95 854.99 948.69 1042.52 1134.99 1226.81 1319.14 1410.37 1502.42 1592.97 1685.09 1777.07 1868.48 1959.83 2051.30 499.94 599.67 667.42 758.07 847.90 937.94 1031.64 1125.47 1217.94 1309.76 1402.09 1493.32 1585.37 1675.92 1768.04 1860.02 1951.43 2042.78 2134.25 1.01 5.76 10.73 19.50 30.31 43.17 59.55 79.86 103.56 129.78 157.09 184.30 212.01 238.98 265.42 292.60 320.86 348.79 376.30 5.54 1.69 -1.59 0.57 2.08 5969943.60 12.67 8.81 -8.06 3.56 2.44 5969937.16 20.50 16.64 -15.29 6.56 3.82 5969929.97 35.34 31.46 -29.30 11.46 3.13 5969916.02 53.17 49.28 -46.00 17.68 1.47 5969899.40 • OyVby/.y4 IV /V.3Z/bLIL/ VV 14`J.Zb4444bb 590697.81 N 70.32762192 W 149.26444565 590697.47 N 70.32762340 W 149.26444838 590697.01 N 70.32762532 W 149.26445204 590697.11 N 70.32762479 W 149:26445126 590698.53 N 70.32761693 W 149.26444004 590701.60 N 70.32759924 W 149.26441576 590704.68 N 70.32757949 W 149.26439146 590709.75 N 70.32754122 W 149.26435172 590716.18 N 70.32749560 W 149.26430125 71. 78 67.81 -62.60 26.07 1.85 5969882.90 590724.76 N 70 .32745024 W 149.2642 92. 26 87.82 -79.08 38.17 2.67 5969866.57 590737.06 N 70 .32740521 W 149.2641 115. 13 109.55 -95.00 54.56 2.63 5969850.86 590753.64 N 70 .32736174 W 149.26400 139. 90 132.13 -108.66 75.17 3.53 5969837.45 590774.41 N 70 .32732441 W 149.26383509 166. 31 155.12 -119.09 99.41 2.68 5969827.32 590798.77 N 70 .32729593 W 149.26363856 193.63 220.91 248.79 275.94 302.58 329.90 358.26 386.31 413.95 178.66 202.21 226.64 251.08 275.48 301.09 328.11 354.99 381.58 -127.15 125.51 1.05 5969819. 57 590824.96 N 70 .32727391 W 149.26342693 -133.27 152.08 1.47 5969813. 77 590851.61 N 70 .32725719 W 149.26321146 -138.39 179.48 0.17 5969808. 98 590879.07 N 70 .32724318 W 149.26298925 -143.26 206.20 0.54 5969804. 43 590905.83 N 70 .32722988 W 149.26277266 -147.86 232.44 0.67 5969800. 15 590932.12 N 70 .32721731 W 149.26255988 -153.13 259.24 1.69 5969795. 21 590958.99 N 70 .32720292 W 149.26234251 -159.06 286.98 0.15 5969789. 62 590986.80 N 70 .32718672 W 149.26211758 -164.72 314.46 0.30 5969784. 29 591014.33 N 70 .32717125 W 149.26189481 -170.11 341.57 0.29 5969779. 23 591041.51 N 70 .32715653 W 149.26167497 SurveyEditor Ver SP 2.1 Bld( doc40x_100) V-217\V-217\V-21 TV-217 Generated 2/12/2007 1:54 PM Page 1 of 2 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude ' Depth Section Departure tt de de ft tt ft ft ft n n de 100 ft ttUS ftUS LLtf4.16 ltf .bl lUb.43 Y14Z./1 ZZZb.bb 4Ub. ZZ 44Z. y4 2379.85 18 .11 106.04 2233.56 2316.51 435. 27 473. 00 2475.47 17 .81 106.64 2324.52 2407.47 464. 76 502. 48 2570.44 18 .03 103.14 2414.88 2497.83 493. 94 531. 70 2667.23 17 .83 103.23 2506.97 2589.92 523. 68 561. 49 2762.63 17 .51 103.93 2597.87 2680.82 552. 59 590. 45 2858.15 17 .28 104.12 2689.02 2771.97 581. 11 619. 01 2952.57 16 .92 105.14 2779.27 2862.22 608. 84 646. 77 3025.83 17 .12 104.75 2849.32 2932.27 630. 28 668. 21 3120.39 16 .88 107.10 2939.75 3022.70 657. 91 695. 86 3216.62 16 .20 107.49 3032.00 3114.95 685. 31 723. 25 3312.59 16 .00 106.17 3124.20 3207.15 711. 92 749. 86 3409.01 16 .20 105.45 3216.84 3299.79 738. 65 776. 60 3505.70 16 .10 105.68 3309.71 3392.66 765. 54 803. 50 3601.74 17 .38 106.34 3401.68 3484.63 793. 20 831. 16 3697.20 17 .42 105.18 3492.77 3575.72 821. 74 859. 70 3793.04 17.63 102.33 3584.17 3667.12 850.54 888.56 3888.38 16.99 101.96 3675.19 3758.14 878.81 916.93 3983.91 16.97 103.02 3766.56 3849.51 906.62 944.82 4079.84 17.26 104.81 3858.24 3941.19 934.81 973.05 4175.57 16.53 103.78 3949.84 4032.79 962.60 1000.87 4270.86 16.39 101.62 4041.22 4124.17 989.53 1027.87 4366.88 15.73 100.26 4133.49 4216.44 1015.94 1054.43 4462.08 16.42 99.76 4224.97 4307.92 1042.11 1080.79 4557.78 16.82 98.70 4316.67 4399.62 1069.23 1108.16 4653.67 16.10 97.83 4408.63 4491.58 1096.09 1135.33 4748.68 15.62 97.74 4500.03 4582.98 1121.73 1161.30 4844.84 15.10 97.74 4592.75 4675.70 1146.87 1186.77 4940.78 14.66 97.40 4685.47 4768.42 1171.18 1211.41 5036.94 14.13 98.26 4778.61 4861.56 1194.79 1235.31 Last MWD+IFR+MS 5087.05 13.96 97.41 4827.23 4910.18 1206.79 1247.47 4Vy.t5b 439.50 468.68 497.51 526.83 555.40 583.64 611.17 632.46 659.97 687.29 713.83 740.46 767.24 794.81 823.25 851.92 880.01 907.68 935.77 963.48 990.30 1016.59 1042.64 1069.64 1096.39 1121.93 1147.00 1171.26 1194.82 1206.82 -7 /b./y -184.94 -193.24 -200.74 -207.53 -214.33 -221.25 -228.26 -233.79 -241.37 -249.51 -257.22 -264.50 -271.72 -279.35 -287.11 -293.96 -299.93 -305.97 -312.76 -319.63 -325.57 -330.62 -335.20 -339.58 -343.49 -347.01 -350.44 -353.69 -356.94 -358.60 Jby. / b 398.70 426.99 455.22 484.23 512.38 540.08 566.95 587.66 614.25 640.40 665.87 691.60 717.51 744.10 771.57 799.59 827.32 854.56 881.96 908.92 935.25 961.33 987.29 1014.31 1041.19 1066.92 1092.16 1116.58 1140.26 1152.31 C.35 5`Jb`J//L.tS`J 0.46 5969765.09 0.37 5969757.14 1.16 5969749.98 0.21 5969743.53 0.40 5969737.08 0.25 5969730.49 0.50 5969723.81 0.31 5969718.53 0.77 5969711.27 0.72 5969703.45 0.43 5969696.05 0.29 5969689.08 0.12 5969682.18 1.35 5969674.87 0.37 5969667.45 0.92 5969660.93 0.68 5969655.30 0.32 5969649.59 0.63 5969643.13 0.82 5969636.59 0.66 5969630.97 0.79 5969626.24 0.74 5969621.97 0.52 5969617.91 0.79 5969614.33 0.51 5969611.12 0.54 5969608.00 0.47 5969605.05 0.59 5969602.08 0.53 5969600.57 TD (Projected) 5155.00 13.96 97.41 4893.17 4976.12 1222.96 1263.86 1222.97 -360.71 1168.56 0.00 5969598.65 Survey Type: Definitive Survey NOTES: GYD CT DMS (Gyrodata -cont. drillpipe m/s -- Gyrodata pump-down multishot surveys with continuous tool (RGS-CT) in drill-pipe.) MWD +IFR + MS - (In-field referenced MWD with mull-station analysis and correction applied in post-processing.) Legal Description: Northing (Y) fftUSl Easting (X) fftUSl Surface : 4696 FSL 1605 FEL S11 Ti 1 N Ri 1 E UM 5969945.18 590697.94 BHL : 4335 FSL 437 FEL St 1 T11 N R11 E UM 5969598.65 591870.67 Dy I Vb`J. / i5 IV / V.JZ / I J6Lb VV 14`J.Zb i 44b3b 591098.81 N 70.32711599 W 149.26121173 591127.19 N 70.32709333 W 149.26098231 591155.51 N 70.32707284 W 149.26075341 591184.60 N 70.32705426 W 149.26051817 591212.82 N 70.32703569 W 149.26028993 591240.61 591267.55 591288.33 591315.00 591341.25 591366.81 591392.62 591418.61 591445.29 591472.85 N 70.32701678 W 149.26006528 N 70.32699762 W 149.25984746 N 70.32698251 W 149.25967947 N 70.32696180 W 149.25946393 N 70.32693954 W 149.25925184 N 70.32691848 W 149.2590 N 70.32689858 W 149.25883670 N 70.32687886 W 149.25862662 N 70.32685799 W 149.25841105 N 70.32683681 W 149.25818829 591500.95 N 70.32681807 W 149.25796105 591528.75 N 70.32680175 W 149.25773619 591556.06 N 70.32678526 W 149.25751534 591583.53 N 70.32676670 W 149.25729318 591610.57 N 70.32674791 W 149.25707461 591636.97 N 70.32673168 W 149.25686107 591663.11 N 70.32671788 W 149.25664963 591689.12 N 70.32670536 W 149.25643914 591716.18 N 70.32669337 W 149.25622007 591743.11 N 70.32668268 W 149.25600207 591768.88 N 70.32667306 W 149.25579347 591794.15 N 70.32666368 W 149.25558883 591818.61 N 70.32665480 W 149.2553 591842.33 N 70.32664590 W 149.2551 591854.39 N 70.32664136 W 149.25510109 591870.67 N 70.32663558 W 149.25496928 SurveyEditor Ver SP 2.1 Bld( doc40x_100) V-217\V-217~V-217\V-217 Generated 2/12/2007 1:54 PM Page 2 of 2 TREE = ~9-115" -- WE! t HFAb = fMC ACTUATpR = Leo KB. ELEV = 28.5 BF. ELEV = 83' KC?P . - ........... 30Q' .. Max Angle = _. _ _~ . 1$° r~ 2379' , Datum MD = 4644' Datum TUD = ~ 4q$~' FRC? L/[1.~ - RAFT AFEf Y NQT~S; CAM'S ~ STA#1-#fi ARE 112" X 9-112" MMCrW V4/HI+GHARE WATER~LOOi3 MANDRELS. ~~~' ~~ 3-1f2' HES X N#P, ID = 2.813" 9 518" CSG, 4flN, L-80, .07583 bpf, ~ = 8.835" 2999' 7" 26# L-80 TC=II X BTG-M Xt~ Jaint ~ ~"~ 26' __ _. Minimum Id = 2.813" 3-112"" HES X NIPPLE T" MARKER JbINTW! RA TAG A165' WA TERFLOODIGAS LtFTMANDREtS ST h~l TVD DEV TYPE VLV LATCH PORT BATE 7 4234 4089 16 MMG DCR-1 F2KP ,. 01/17'07 6 4-71 ~#~' ~i 16 M11f11lGW #~PW1`' RK Q 4117JQ7 ~~ ,:1~7 4436 17 M~11G-W LN1rP~' RMS t~ 0#l#Tr(#7 4 _~ _- _ :-'~.4 16 M~AG-1N CtPu~' RK t~ tlt7#71t17 3 4574 4511 1%; Mt,AG-W C3P~RY RK 4 0#1#7/07 f'S ~`> 16 t 5 tv9U{G-W JfaTY RK (} 0# t# 7,'07 1 .~3=i9 4679 15 MNIG-1N t>tvPY RK 0 Ot/t7107 ..~. - 3-112" t•tES X Nlp, tD = 2.$13" 7" X 3-112" HES AHR Packer, ID = 2.855" Phaen#x Sensor Sub., iD = 2.875" ~~~'~"-"~ 3-112" HES X NIP, ID = 2.813" #~, ~` 7"X3-112" HES AHR Packer, tD = 2.955" 3-112" T6~ 1At1 RR Tap #n Centralizer MARfCER JOINT1tV1 RA TAG 4645' PERFORATION Sl~v1ARY REF LOG: A NGLE A T TOP PERF: 18 4375' Note; SIZE SPF SERVAL t3pnlSgz t)ATE 4.5" 5 4378 -4388 O 01114107 4:5" 5 4598 -4538 O 01114107 4.5" 5 4 -4596 O 01114107 4,5" 5 4710 - 4726 O 01114107 4;5" 5 4820 -4870 (~ 01 t14J07 3-1 f2" TSG, 9.24. L-50..0457 bpf. ID = 2.932' ~~' PBTD ~ 5462'_ 7" CSG, z6#, L-80„ .0382 bpf,. iD = 6.276" ~'~4~" 4643' ~~ 3-# t2" HES X NIP, ID = 2.813" 46~;f` ~_~ 7" X 3-112" HES AtIR Packer, tD = 2.965" 4667' Phoenix Sensor sub, ID = 2.875" 14795' ~~ 7' X 3-112' HES AHR Parker, tD ° 2.965" 4$2$' 3-112" HES X NIP,. ID = 2:813" 4E7T 3-112" HES X NtP, tD = 2.813" w1RHC-rr, p#ug 4~9~' 3-112" HES X NIP. ID = 2.8#3" 4824' 3-112" wLEC~, ID = z.9o5" DATE REV BY COMMENTS DATE REV BY COMMENTS 01/17/07 9-es Original Drill & Complete 01/19/07 JDM/PAG DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: V-217i Perrr~t No: 206-162 API No: 50-029-2334-00 SEC 11, T11 N, R11 E, UM BP Exploration (Alaska) A .,~ SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ....................: Prudhoe Bay Well .....................: V-217 API number ...............: 50-029-23334-00 Engineer .................: Bezerra RIG :.....................: Nabors 9ES STATE :...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: GROUND LEVEL Depth reference..........: 54.45 ft KB above permanent.......: N/A (Top Drive) DF above permanent.......: 82.95 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-)........: -9.99.25 ft Azimuth from Vsect Origin to target: 106.93 degrees [(c)2007 IDEAL ID12_OC_01] /~°~ ' ~6 ~ 12-Jan-200.7 15:03:14 Page 1 of 3 Spud date ................: 08-Jan-07 Last survey date..........: 12-Jan-07 Total accepted surveys...: 56 MD of first survey.......: 0.00 ft MD of last survey........: 5155.00 ft ----- Geomagnetic data --- ------------ ------- Magnetic model...........: BGGM versio n 2006 Magnetic date ............: 07-Jan-2007 Magnetic field strength..: 57631.52 GAMA Magnetic dec (+E/W-).....: 23.82 degrees Magnetic dip .............: 80.89 degrees ----- MWD survey Reference Criteria -- ------- Reference G ..............: 1002.68 meal Reference H ..............: 57631.50 GAMA Reference Dip ............: 80.89 degrees Tolerance of G...........: (+/-) 2.50 meal Tolerance of H...........: (+/-)300.00 LAMA Tolerance of Dip.........: (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.82 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.82 degrees (Total az corr = magnetic dec - grid cony) 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 12 -Jan-2007 15:03:14 Page 2 of 3 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 0.00 160.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 100.00 0.31 332.90 100.00 100.00 -0.19 0.24 -0.12 0.27 332.90 0.31 BP _GYD CT DMS 3 200.00 0.42 324.36 100.00 200.00 -0.67 0.78 -0.46 0.91 329.45 0.12 BP _GYD CT DMS 4 300.00 0.54 329.77 100.00 299.99 -1.30 1.48 -0.91 1.74 328.47 0.13 BP _GYD CT DMS 5 400.00 0.79 151.03 100.00 399.99 -1.15 1.29 -0.81 1.52 327.71 1.33 BP GYD CT DMS 6 500.00 2.87 155.23 100.00 499.93 1.01 -1.59 0.57 1.69 160.30 2.08 BP _GYD CT DMS 7 600.00 5.31 155.15 100.00 599.67 5.76 -8.06 3.56 8.81 156.16 2.44 BP _GYD CT DMS . 8 668.20 7.88 159.07 68.20 667.42 10.73 -15.29 6.56 16.64 156.78 3.82 BP _MWD+IFR+MS 9 760.07 10.72 161.93 91.87 758.07 19.50 -29.30 11.46 31.46 158.64 3.13 BP _MWD+IFR+MS 10 851.65 11.74 157.39 91.58 847.90 30.31 -46.00 17.68 49.28 158.97 1.47 BP MWD+IFR+MS 11 943.60 11.66 149.01 91.95 937.94 43.17 -62.60 26.07 67.81 157.39 1.85 BP _MWD+IFR+MS 12 1039.51 13.06 138.95 95.91 1031.64 59.55 -79.08 38.17 87.82 154.23 2.67 BP _MWD+IFR+MS 13 1136..09 14.39 129.80 96.58 1125.47 79.86 -95.00 54.56 109.55 150.13 2.63 BP _MWD+IFR+MS 14 1231.82 15.71 117.80 95.73 1217.94 103.56 -108.66 75.17 132.13 145.32 3.53 BP _MWD+IFR+MS 15 1327.37 16.44 108.94 95.55 1309.76 129.78 -119.09 99.41 155.12 140.15 2.68 BP MWD+IFR+MS 16 1423.65 16.54 105.40 96.28 1402.09 157.09 -127.15 125.51 178.66 135.37 1.05 BP _MWD+IFR+MS 17 1518.87 16.77 100.57 95.22 1493.32 184.30 -133.27 152.08 202.21 131.23 1.47 BP _MWD+IFR+MS 18 1615.05 16.93 100.63 96.18 1585.37 212.01 -138.39 179.48 226.64 127.63 0.17 BP _MWD+IFR+MS 19 1709.59 16.45 100.02 94.54 1675.92 238.98 -143.26 206.20 251.08 124.79 0.54 BP _MWD+IFR+MS 20 1805.48 15.81 99.86 95.89 1768.04 265.42 -147.86 232.44 275.48 122.46 0.67 BP MWD+IFR+MS 21 1901.44 17.28 102.27 95.96 1860.02 292.60 -153.13 259.24 301.09 120.57 1.69 BP _MWD+IFR+MS • 22 1997.15 17.20 101.85 95.71 1951.43 320.86 -159.06 286.98 328.11 119.00 0.15 BP _MWD+IFR+MS 23 2092.71 16.94 101.44 95.56 2042.78 348.79 -164.72 314.46 354.99 117.65 0.30 BP _MWD+IFR+MS 24 2188.26 16.69 101.03 95.55 2134.25 376.30 -170.11 341.57 381.58 116.47 0.29 BP _MWD+IFR+MS 25 2284.16 18.51 105.43 95.90 2225.66 405.22 -176.79 369.76 409.85 115.55 2.35 BP MWD+IFR+MS 26 2379.85 18.11 106.04 95.69 2316.51 435.27 -184.94 398.70 439.50 114.89 0.46 BP _MWD+IFR+MS 27 2475.47 17.81 106.64 95.62 2407.47 464.76 -193.24 426.99 468.68 114.35 0.37 BP _MWD+IFR+MS 28 2570.44 18.03 103.14 94.97 2497.83 493.94 -200.74 455.22 497.51 113.80 1.16 BP _MWD+IFR+MS 29 2667.23 17.83 103.23 96.79 2589.92 523.68 -207.53 484.23 526.83 113.20 0.21 BP _MWD+IFR+MS 30 2762.63 17.51 103.93 95.40 2680.82 552.59 -214.33 512.38 555.40 112.70 0.40 BP MWD+IFR+MS [(c)2007 IDEAL ID12_OC_01] SCHLUN~ERGER Survey Report 12-Jan-2007 15:03:14 Page 3 of 3 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) 31 2858.15 17.28 104.12 95.52 2771.97 581.10 -221.25 540.08 583.64 112.28 0.25 BP _MWD+IFR+MS 32 2952.57 16.92 105.14 94.42 2862.22 608.84 -228.26 566.95 611.17 111.93 0.50 BP _MWD+IFR+MS 33 3025.83 17.12 104.75 73.26 2932.27 630.28 -233.79 587.66 632.46 111.69 0.31 BP _MWD+IFR+MS 34 3120.39 16.88 107.10 94.56 3022.70 657.91 -241.37 614.24 659.97 111.45 0.77 BP _MWD+IFR+MS 35 3216.62 16.20 107.49 96.23 3114.94 685.31 -249.51 640.40 687.29 111.29 0.72 BP _MWD+IFR+MS 36 3312.59 16.00 106.17 95.97 3207.15 711.92 -257.22 665.87 713.83 111.12 0.43 BP _MWD+IFR+MS 37 3409.01 16.20 105.45 96.42 3299.79 738.65 -264.50 691.60 740.45 110.93 0.29 BP _MWD+IFR+MS • 38 3505.70 16.10 105.68 96.69 3392.66 765.54 -271.72 717.51 767.24 110.74 0.12 BP _MWD+IFR+MS 39 3601.74 17.38 106.34 96.04 3484.63 793.20 -279.35 744.10 794.81 110.58 1.35 BP _MWD+IFR+MS 40 3697.20 17.42 105.18 95.46 3575.72 821.74 -287.11 771.57 823.25 110.41 0.37 BP MWD+IFR+MS 41 3793.04 17.63 102.33 95.84 3667.12 850.54 -293.96 799.59 851.92 110.19 0.92 BP _MWD+IFR+MS 42 3888.38 16.99 101.96 95.34 3758.14 878.81 -299.93 827.32 880.01 109.93 0.68 BP _MWD+IFR+MS 43 3983.91 16.97 103.02 95.53 3849.50 906.62 -305.97 854.56 907.68 109.70 0.32 BP _MWD+IFR+MS 44 4079.84 17.26 104.81 95.93 3941.19 934.81 -312.76 881.96 935.77 109.53 0.63 BP _MWD+IFR+MS 45 4175.57 16.53 103.78 95.73 4032.78 962.60 -319.63 908.92 963.48 109.37 0.82 BP MWD+IFR+MS 46 4270.86 16.39 101.62 95.29 4124.17 989.53 -325.57 935.25 990.30 109.19 0.66 BP _MWD+IFR+MS 47 4366.88 15.73 100.26 96.02 4216.44 1015.94 -330.62 961.33 1016.59 108.98 0.79 BP _MWD+IFR+MS 48 4462.08 16.42 99.76 95.20 4307.92 1042.11 -335.20 987.29 1042.64 108.75 0.74 BP _MWD+IFR+MS 49 4557.78 16.82 98.70 95.70 4399.62 1069.23 -339.58 1014.31. 1069.64 108.51 0.52 BP _MWD+IFR+MS 50 4653.67 16.10 97.83 95.89 4491.58 1096.09 -343.49 1041.19 1096.39 108.26 0.79 BP MWD+IFR+MS 51 4748.68 15.62 97.74 95.01 4582.97 1121.73 -347.01 1066.92 1121.93 108.02 0.51 BP _MWD+IFR+MS • 52 4844.84 15.10 97.74 96.16 4675.70 1146.87 -350.44 1092.16 1147.00 107.79 0.54 BP _MWD+IFR+MS 53 4940.78 14.66 97.40 95.94 4768.42 1171.18 -353.69 1116.58 1171.26 107.58 0.47 BP _MWD+IFR+MS 54 5036.94 14.13 98.26 96.16 4861.56 1194.79 -356.94 1140.26 1194.82 107.38 0.59 BP _MWD+IFR+MS 55 5087.05 13.96 97.41 50.11 4910.17 1206.79 -358.60 1152.31 1206.82 107.29 0.53 BP MWD+IFR+MS 56 5155.00 13.96 97.41 67.95 4976.12 1222.96 -360.71 1168.56 1222.97 107.15 0.00 Project to TD [(c)2007 IDEAL ID12_OC_01] Schlumberger NO.4164 Schlumberger-DCS 2525 Gambell St, Suife 400 Anchorage, AK 99503-2838 ATTN: Beth \ ~~ ~ ~ ~ ~ ~ ~ ~ 1 / ~ Company: Alaska Oii & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 \"•/ ~ i ~-y\ Field: Aurora ~ ~ ~'( ~ v Borealis Well Job # Log Description Orion Date BL Color CD V-217 11638607 CH EDIT USIT PDC 01115107 1 V-217 11638607 USIT CEMENT EVALUATION 01/15107 1 V-217 11638607 USIT CORROSION EVALUATION 01/15107 1 W-204 11638608 MDT _ 01/16!07 1 V-221 40011617 OH EDIT MWDILWD 03103/05 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TJ: BP Exploration (Alaska) Inc. "~ I ~ ~ ~ $ Petrotechnical Dala Cenler LR2-1 ~~ ~ '~ ~...,. , ~, _J' 900 E Benson Bivd. - ' - '" Anchorage AK 99508-4254 /~, P1t!~'`' 16.1{li Date Delivered: e ~' F ~f e Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth .1 / Received by: ~,,,/. ~~~~~ 02/27/2007 03/02/7007 i~ • • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To Well No V-217 Date Dispatched Installation/Rig Nabors-9ES Helen Warman 22-Jan-07 Dispatched By: Emil Guliyev 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 ~ ~` A ~ It ~ Anchorage, Alaska 99501 V nrose1C~?slb.com Fax:907-561-8367 LWD Log Delivery V1.1,10-02-03 ~ a ~ -16 z r'/~ • • FRANK H. MURKOWSKI, GOVERNOR 333 W. 7~" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Re: Prudhoe Bay Field, Orion Schrader Bluff Oil Pool, PBU V-217i BP Exploration (Alaska) Inc. Permit No: 206-162 Surface Location: 4696' FSL, 1605' FEL, SEC. 1 1, T11N, Rl lE, UM Bottomhole Location: 4343' FSL, 443' FEL, SEC. 11, 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) C~9-3607 (pager). DATED this ~ ~of December, 2006 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMON PERMIT TO DRILL 20 AAC 25.005 ~~~ `~ g Zeds ~issica Oil & Gas Cons. Commission 1 a. Type of work ®Drill ^Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is propos . ~a8e ^Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU V-2171 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 5137 TVD 4962 12. Field /Pool(s): Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): Surface: 4696' FSL 1605' FEL SEC 11 T11N UM (Pro R11E osed) 7. Property Designation: ADL 028240 Schrader Bluff , , , . , , p Top of Productive Horizon: 4379' FSL, 597' FEL, SEC. 11, T11 N, R11 E, UM 8. Land Use Permit: 13. Approximate Spud Date: December 27, 2006 Total Depth: 4343' FSL, 443' FEL, SEC. 11, T11N, R11E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: g,g00' 4b. Location of Well (State Base Plane Coordinates): Surface: x-590698 y-5969945 Zone-ASP4 10. KB Elevation Planned (Height above GL): 82.4 feet 15. Distance to Nearest Well Within Pool: 524' 16. Deviated Wells: Kickoff Depth: 300 feet Maximum Hole An le: 17 de tees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2244 Surface: 1749 1 Ca in Pr tarn: S 'fi i s T - S in . D h - B om uanti of Cement c.f. ors s Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 215.5# A-53 Weld 108' Surfac urfa e 1 8' 108' 260 sx Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BTC 2970' Surface urfa 2 '~ 288T 473 sx A Lie 411 sx Class' ' _ /4~~ 7~~ 26# _ 0 TC-II / BTCM 51 T Su a rf 13 -' 4 26 sx CI 'G' ~ 1 g, PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): asing Length : Size ement Volume MD D Conductor /Structural Surface Intermediate Pr n Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Dril~ing Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Brandon Peltier, 564-5912 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/Number: Si nature ~C~~~~% ~~ ~.;/ Phone 564-4166 Date ~~~v7'~ ~~ Terrie Hubble, 564-4628 Commission Use On Permit To Drill Number: -- APl Number: 50- ®Z 9'' .Z -7~~,3 ~ Permit pproval Dat See cover letter for other r uir men Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained shales: Tt? ~~ ~ ~ ~~ L- ` r' ~ ~ ~ ~ ~ Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes No ~lG`'Z,'"r/ CQ~,pr,~'1~ /q) ~(A,~ t!~ /P yttr~ d, HZS Measures:(' Yes ^ No Directional Survey Req'd:~Yes No Qther: O/{ rpJSSuYe_ Vwotvi, ~-o r'r' ~e ~ -^{'~ ~v~. ue-GI~S ~(- !O0 ~Pl ~t t75 ~ q,,,~,d ~' (~cj(P~D ~2Zoz~ I~w~S~t P~ ~ 2~ iM4-~ 25 . o z~ i` (~'j1) (~~, al {-er-~.~~c ~3 o r~ = ~ ~u ~ ~ s ~ job ~/P c~. ` ~ APPROVED BY THE COMMISSION Date ~ ~ ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ ~J,. Submit In Duplicate • • Well Name: V-2171 Drill and Complete Plan Summary Type of Well service / roducer / in'ector : Injector 4Co 4l0 ! (o 0 5 -+~-G~-- Tar et X Y Z TVDss Townshi Ran a Section FSL FEL Surface As-Staked 590698 5969945. 0 11 N 11 E 11 -4~#-1~ fr- T ti : To OA 591710 5969640 4355 11 N 11 E 11 4379 597 T t2: 250' below OBe 591864 5969606 4879 11 N 11 E 11 4343 443 AFE Number: N/A API Number: 50-029-xxxxx Estimated Start Date: December 27, 2006 Operatin days: 13 Rig: Nabors 9E TMD 5,137' TVD rkb: 4,962' RKB/GL 28.5'/53.9' RTE 82.4' Well Design: USH Grassroots Schrader Bluff Injector 3-'h", L-80, TC-II, multi acker, zonal in'ection, and zonal monitorin com letion Current Status: New drill General Well Information: Estimated BHP: 2244 psi (8.7 ppg EMW) at 4962' TVD Estimated BHT: 87 deg F at 4962' TVD Formation Markers: Est. Formation Tops Est. Formation Tops Uncertainty Commercial Hydrocarbon Bearing Est. Pore Press. Est. Pore press. Formation MD (TVDss) (feet) (Yes/No) (Psi) (ppg EMW G1 327 -245 +/- 50' no 110 8.7 SV6 977 -890 +/- 50' no 401 8.7 SV5 1665 -1555 +/- 50' no 700 8.7 SV4 1806 -1690 +/- 50' Poss. gas hydrates 761 8.7 BPRF 1816 -1700 +/- 50' - 765 8.7 SV3 2223 -2090 +/- 50' Poss. gas hydrates 941 8.7 SV2 2396 -2255 +/- 50' Poss. as h drates 1015 8.7 SV1 2735 -2580 +/- 50' Poss. gas hydrates 1161 8.7 UG4 3054 -2885 +/- 50' 1298 8.7 UG4A 3090 -2920 +/- 50' Heavy Oil 1314 8.7 Fault #1 3127 -2955 +/- 150' 1330 8.7 UG3 3346 -3165 +/- 50' Minor Heavy Oil 1424 8.7 UG1 3884 -3680 +/- 50' Heavy Oil 1656 8.7 UG Ma 4166 -3950 +/- 50' no 1778 8.7 UG Mb1 4218 -4000 +/- 50' no 1800 8.7 UG_Mb2 4286 -4065 +/- 50' Heavy oil 1829 8.7 UG Mc 4348 -4125 +/- 50' no 1856 8.7 SB Na 4421 -4195 +/- 25' no 1888 8.7 SB Nb 4442 -4215 +/- 25' no 1897 8.7 V-217i Permit to Drill Page 1 • • Ztl~05~ 2oLZo2 SB Nc 4479 -4250 +/- 25' no 1913 8.7 SB_Ne 4484 -4255 +/- 25' no 1915 8.7 SB_OA 4588 -4355 +/- 25' yes 1700-1900 7.5-8.4 SB_OBa 4662 -4425 +/- 25' yes 1850-1900 8.0-8.3 SB_OBb 4703 -4465 +/- 25' yes 1920-1980 8.3-8.5 SB_OBc 4761 -4520 +/- 25' yes 2034 8.7 SB_OBd 4813 -4570 +/- 25' yes 1750-2000 7.6-8.4 SB_OBe 4886 -4640 +/- 25' yes 2088 8.7 SB_OBf 4917 -4670 +/- 25' yes 2102 8.7 Base SB OBf 4970 -4720 +/- 25' no 2124 8.7 Wells within a'/a mile of this injection well, scanned from the top of the reservoir to TD Well Name Distance ft Annulus Inte rit Comments V-100 524 TOC at 6850' MD, which is below the Na 4738' MD . Monitorin ro osed in Mc. V-109 677 TOC at 4986' MD, which is below the Na 4348' MD . Monitorin ro osed in Mc. V-03 914 Good cement covera e. TOC at 3558' MD, which is above the Na 4316' MD . V-115 1004 Good cement covera e. TOC at 3996' MD, which is above the Na 4810' MD . V-111 PB1 1182 Good cement coverage. TOC at 2804' MD. This cement was used to plug V- 111 P61. An o en hole side track was kicked off from the to of this cement. V-111 1188 Good cement covera e. TOC at 3459' MD, which is above the Na 4231' MD . V-02 1206 Good cement covera e. TOC at 3412' MD, which is above the Na 4225' MD . V-204L1 1224 Good cement covera e. TOC at 3300' MD. L1 is OBb le with slotted liner. V-204L3 1284 Good cement covera e. TOC at 3300' MD. L3 is OA le with slotted liner. V-204 1306 Good cement coverage. TOC at 3300' MD, which is below the Na (4469' MD). Main bore is OBd le with slotted liner. Casing/Tubing Program: Hole Size Csg/ Tbg O.D. Wt/Ft Grade / Connection ~ Length (ft) Top MD/TVD RTE ft Btm MD/TVD RTE ft 42" Insulated 20" 215.5 A-53 WLD 108 GL 108/108 12-'/a" 9-5/8" 40 L-80 BTC 2970 GL 2970/2887 8-3/a" 7" 26 L-80 TC-II 4166 GL 4166/4032 8-3/a" 7" 26 L-80 BTC-M 971 4166/4032 5137/4962 Tobin 3-%z" 9.2 L-80 TC-II 4917 GL 4917/4752 Note: Top roduction acker within 200' MD of to erforation Directional: Directional Plan: Schlumber er Feasibilit Stud P2 Ref Elev: 82.4' MD KOP: 300' MD, be in 1.5/100 build Close A roach Wells: All Wells ass Ma'or Risk Scan, reference anti-collision re ort Surve Pro ram: GYD-GC-SS 1000' , MWD + IFR + MS 5137' Maximum Hole An le: 16.7 de rees tan ent section Distance to Nearest Pro ert Line: 9900' from PBU bounda Distance to Nearest Well in Pool: 524' from V-100 12-'/a" Surface Hole Mud Pro erties Spud -Freshwater Mud Interval Densit PV YP PH Funn Vis FL 0-1816' BPRF 8.8-9 30-55 50 - 70 9.0 - 9.5 300-400 NC - 8 1816'-2970' SVi 9.2-9 5 30-55 45 - 60 9.0 - 9.5 250-300 < 8.0 Mud Pro ram: ~/ V-217i Permit to Drill Page 2 i • • 8-3/a" Intermediate Hole Mud Pro erties Freshwater Mud (LSND) Interval Density PV YP PH API Filtrate MBT 2970'-5137' OBf Base 8.8-9.0 8-14 18-24 9.0-9.5 4 - 7 < 15 Survev and Loaaina Proaram: 12-'/a" Hole Section: Surface Gyro until MWD surveys are clean. MWD /LWD: Dir/GR O en Hole: None Cased hole: None 8-3/a" Hole Section: Sample as required by well site Geologist MWD /LWD: GR/RES/PW D real time and Azi-Dens/Neu recorded O en Hofe: None Cased Hole: USIT in primary depth control mode Cement Calculations: Casin Size Surface Casing - 9 5/a" 40 Ib/ft L-80 BTC -Single Stage Basis Lead: Open hole volume + 250% excess in permafrost and 40% excess below permafrost. TOC at surface Tail: O en hole volume + 40% excess + 80' shoe track. TOC 1000' MD above shoe 1970' MD). Fluid Sequence and Tam Port collar located at 1,000' as a contingency for cement to surface Volume: Wash None 3 acer 70 bbls of Push II wei hted to 10.3 Lead 374 bbls sks 10.7 Ib/ al Arctic Set Lite cement - uft/sk Tail 84 bbls 41 sks 15.8 Ib/ al Class G + Durastone - .15 cuft/sk Temp BHST = 40° F from SOR Casin Size Intermediate Casing - 7" 26 Ib/ft L-80 BTC-M x TC-II -Single Stage Basis Lead: None Tail: Open hole volume + 30% excess + 80' shoe track. TOC 500' above Ma (3666' MD) -higher top than 1000' below surface shoe. Fluid Sequence and This cement job is planned for one stage. Volume: 1" Sta e Wash None 3 acer 70 bbl of MUDPUSH XL S acer wei hted to 10.3-Ib/ Lead none Tail 55 bbl 6 sks 15.8 Class G cement + Latex - Temp BHST = 87° F from SOR Surface and Anti-Collision Issues: • Surface Shut-in Wells: The closest existing surface wells are V-117 (45' away), and V-01 (45' away). • Close Approach Shut-in Wells: All wells have passed the major risk scan. No wells will require subsurface shut-in during drilling operations. Reference the Anti-collision report in the directional plan for a full list of offset well paths. V-217i Permit to Drilt Page 3 • • Well Control Surface hole will be drilled with a diverter. The production hole section will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer. This equipment is capable of handling m m potential surface pressures. Based upon calculations below, BOP equipment will be tested to psi. Anticipated surface pressures will not exceed 3,000psi, therefore it will not be necessary to have ets of pipe rams installed at all times. ¢ oo n t<-~ G ~ Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Surface Section • BOPE: • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 9-5/8" Casing Test: • Kick Tolerance: Hydril GK, 21-1/4", 2000 psi 1,306 psi - SV1 (8.7 ppg EMW C~3 2887' TVD) 1,018 psi -Based on a full column of gas C«~ 0.10 psi/ft Function Test 3,500 psi surface pressure test NA Intermediate Section Kick Tolerance and Intearity Testin • BOPE: Hydril, 13-5/8", 5000 psi • Maximum anticipated BHP: 2,244 psi - OBf Base (8.7 ppg EMW @ 4962' TVD) • Maximum surface pressure: psi -Based on a full column of gas @ 0.10 psi/ft • Planned BOP test pressure:'~'n~ si/250 psi Rams and 2,500 psi/250 psi Annular • 7" Casing Test: -~'aG psi surface pressure test • Integrity Test - 8-3/4" hole: T 20' - 50' from 9 g/e" shoe • Kick Tolerance: 25.0 bbl KT with a 9.0 ppg mud and a 10.7 ppg LOT • Planned completion fluid: Estimated 9.0 ppg Brine / 6.8 ppg Diesel Disposal • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. V-2171 Permit to Drill Page 4 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control /Reservoir Pressures: The Schrader Bluff sands are expected to be pressured at 7.6-8.7 ppg EMW. II. Hydrates and Shallow gas: Gas Hydrates are expected at V-pad near the base of the permafrost. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Occasionally hydrates are encountered below the SVi . III. Lost Circulation /Breathing: Lost circulation is considered low at the faults in the production hole section. Seepage losses could occur in the Schrader O-sands. IV. Kick Tolerance /Integrity Testing: Production Section Kick Tolerance and Integrity Testing • Integrity Test - 8-3/4" hole: L 20' - 50' from 9 s/8' shoe • Kick Tolerance: 5. bl KT with a 9.0 ppg mud and a 10.7 ppg LOT V. Stuck Pipe There could be slight differential sticking across the open hole while running the 7" casing. Keep the casing moving as much as possible and follow the centralizer program to help with standoff. VI. Hydrogen Sulfide V Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followeTaf all times. H2S levels across the pad are typically in the 10 ppm range based on the latest samples taken. V-117 has read 20 ppm and V-106A 110 ppm. VI1. Faults There is a low risk of losses incurred when crossin the fault. Formation Where Encounter Fault MD Intersect TVDSS Intersect Est. Throw Throw Direction Uncertaint Fault #1 - UG4A V Pad Fault 3128' -2955' -75' Southwest +/- 150' MD CONSULT THE V PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION V-2171 Permit to Drill Page 5 • • V-217i Drill and Complete Procedure Summary Pre-Rig Work: 1. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the 20" conductor. 2. Prepare pad and neighboring wells for the rig move and sim-ops production. Shut in nearby wells, bleed off process lines, and remove well houses as necessary. Rig Operations: 1. MIRU Nabors 9ES. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. 2. MU 12-'/a" drillin ss mbly with MWD/GR and directionally drill surface hole to TD with one BHA. Conduct a short trip a the P The actual surface hole TD will be 240' MD below the top of the SVi sands. CBU, short trip, RIH t ,CBU, then POOH and lay down BHA. 3. Run and cement the 9 5/e", 40.0 Ib/ft. surface casing~iaelrto surface. A TAM Port Collar may be run at 1000' MD as a contingency. Use Durastone in the last 15 bbls of tail cement. ~C~/t•` 4. ND diverter spool and NU and test casing/tubing head. NU BOPE and test to si / 2500 psi annular. PU 4" DP as needed. 5. MU 8-3/a" drilling assembly with MWD/GR/Res/Azi-Den/Neu/PWD and RIH to float collar. Confirm 1,000 psi cement compressive strength prior to testing casing. Test the 9-s/8' casing to 3,500 psi for 30 minutes. 6. Drill shoe track and displace over to new 8.8 ppg LSND mud. Drill new formation to 20' below 9 5/8" shoe and perform LOT. 7. Drill ahead to Production hole Target TD (250' MD below OBe). Circulate one BU, back-ream out to the surface shoe, then POOH to run casing. 8. Run and cement the 7", 26#, L-80, BTC-M x TC-II production casing. Displace the casing with seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. Freeze protect the 7" x 9 5/8" annulus. 9. PU DPC guns and RIH w/ 125' of 4.5" Power Jet 4505 5 spf, pert guns with Schlumberger LWD GR/CCL for gun correlation. 10. Space out perf guns by tagging PBTD and utilizing GR/CCL and RA tags in 7" casing. Once correlated correctly, circulate over to 9.0 ppg brine. Confirm cement compressive strength is at least 1,000 psi before firing. Perforate OA, OBa, OBb, and OBd. POOH LD DP and guns. 11. RU Schlumberger E-line. RIH with gauge ring and junk basket to recover any perf debris. Repeat until clean to at least 50' below the bottom perforation. ~~''`` 12. Run USIT log following Primary Depth Control procedures as(USI~ log will be primary depth control for future well work. ~~~ 13. Run the 3-'/z", 9.2#, L-80, TCII completion with a 7" x 3-'h" straddle packer assembly, I-wire, gauges, and injection mandrels. Torque turn TC-II threaded tubing. 14. Run in the lockdown screws and set the packers. casing/tubing annulus and tubing to 4,000 psi each confirm circulation ability. 15. Install and test FMC TWC. Nipple down the BOPE. Valve. Nipple up and test the tree to 5,000 psi. Give AOGCC 24 hours notice, then test the production Shear the DCR shear valve and pump both ways to Be sure the tree is equipped with a Leo Surface Safety 16. Freeze protect the well to 2,500' TVD by first pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ a hot oil truck, taking clean brine returns to surface. Allow diesel to u-tube into j tubing. 17. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-'/z" annulus valve and secure the well. Assure that IA/OA are protected with two barriers. 18. Rig down and move off. Post-Rig Work: 1. R/U Slick-line and pull ball and rod / RHC from the tailpipe. 2. Replace the DCR shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. 5. Install well house and flow lines. V-2171 Permit to Drill Page 6 = 41/8" ,HEAD = FMC IATOR= Leo LEV = 28.5' -~'° ~ Proposed WBD 9-5/8" CSG, 40#, L-80, ID = 8.835" 2970' XO from BTGMto TGII 4186' Minimum ID = 2.813" 3-1 /2" HES X NIPPLE 7" MARKER JOINT W/ RA TAG XXXX' CTS cause ID=xx 4365' •1/2" TBG W/ RA Tag in Centralizer ~ XXXX I-Wire run from surface XXXX 7" MARKER JOINT W/ RA TAG XXXX PERFORAT~N SUMMARY REF LOG: ANGLEAT TOP PERF: Note: SIZE SPF INTERVAL Opn/Sqz DATE 4.5" 5 MC 4.5" 5 OA 4.5" 5 Oba 4.5" 5 Obb 4.5" 5 Obd ~ 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" ~~ 4916' PBTD 6056' 7" CSG, 28#, L-80, ID = 6.278" 6136' SAFETY NOTES: CAM'S ~ STA #1-#5 ARE V ~ ~ ~ ~' WATERFLOOD MAN E SHICH ARE 2600' 3-1 /2" HES X NIP, ID = 2.813" WATERFLOOOVGAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 4230 MMG DCR 1 RKP 1.5" 6 4406 MMG-W DUM RK 1.5" 5 4595 MMG-W DUM RK 1.5" 4 4623 MMG-W DUM RK 1.5" 3 4672 MMGW DUM RK 1.5" 2 4722 MMG-W DUM RK 1.5" 1 4845 IUINIG-W DLIM RK 1.5" 4321' -t 3-1/2" HES X NIP, ID = 2.813" 134-~ 7" X 3-1/2" HES AHR Packer, ID = 2.921" .~ 4435' ~ 3-1 /2" HES X NIP, ID = 2.813" 4576' 7" X 3-112" HES AHR Packer, ID = 2.921" 4643' -i 3-1/2" HES X NIP, ID = 2.813" 4654' 7" X 3-1/2" HES AHR Packer, ID = 2.921" - j 4701' r-j CTS gauge ID = xx" 4802' 7" X 3-1/2" HES AHR Packer, ID = 2.921" 4825' 3-112" HES X NIP, ID = 2.813" 4875' 3-1/2" HES X NIP, ID = 2.813" w/RHC-m plug 4895' 3-1/2" HES X NIP, ID = 2.813" 4916' 3-1/2" WLEG, ID = 3.00" I/25/O6 BJP Proposed Camp~tion Ver. 1.0 WELL: V-2171 PERMIT No: API No: Sec Tw p Rg~ bR Schlumberger V-217 (P2) Proaosal Client: BP Exploration Alaska Field; Prudhoe Bay Unit - WOA Structure 1 Slot: V-Pad I Plan V Slot (S-0) ~~~~'~~ Well: Plan V-217 (S-0) Borehole: Plan V-217 uwuAPlfs: 50029 Survey Name 1 Date: V-217 (P2) /October 24, 2006 Tort l AHD I DDI 1 ERD ratio: 23.937° 11243.81 ft 14.489 10.251 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Location LatlLong: N 70.32762102, W 149.26444369 Location Grid NIE YIX: N 5969945.090 ftUS, E 590698.060 ftUS Grid Convergence Angle: +0.69262837° Grid Scale factor: 0.99990934 Vertical Section Azimuth: 106.930° Vertical Section Origin: N 0.000 ft, E 0.000 ft '~ TVD Reference Datum: Rotary Table TVD Reference Elevation: 82.40 ft relative to MSL Sea Bed 1 Ground Level Elevation: 53.90 ft relative to MSL Magnetic Declination: 23.837° Total Field SVength: 57630.712 nT Magnetic Dip: 80.885° Declination Date: December 25, 2006 Magnetic Declination Model: BGGM 2006 North Reference: True North Total Corr Mag North •> True NoRh: +23.837° Local Coordinates Referenced To: Well Head • Measured Vertical Gravity Comments Inclination Azimuth Sub•Sea TVD TVD NS EW DLS Build Rate Walk Rate Northing Fasting Latitude Longitude Depth Section Tool Face ft de de ft ft ft ft ft de de 1100 ft de 1100 ft de 1100 ft ftUS ftUS Kit u.UU U.uu -rou.uu -25[.4u V.uu U.UU V.VV U.VV --- U.UU U.UU U.VU bybyy4O.Uy DyUGyt3.VO IV/U.3Z/dZ1UZ VVl4y.Zti44436y KOP Bld 1.5/100 300.00 0.00 160.00 217.60 300.00 0.00 0.00 0.00 HS 0.00 0.00 0.00 5969945.09 590698.06 N 70.32762102 W 149.26444369 G1 327.40 0.41 160.00 245.00 327.40 0.06 -0.09 0.03 HS 1.50 1.50 0.00 5969945.00 590698.09 N 70.32762076 W 149.26444342 Crv 2/100 400.00 1.50 160.00 317.59 399.99 0.79 -1.23 0.45 HS 1.50 1.50 0.00 5969943.87 590698.52 N 70.32761766 W 149.26444006 500.00 3.50 160.00 417.49 499.89 3.41 -5.33 1.94 HS 2.00 2.00 0.00 5969939.79 590700.06 N 70.32760646 W 149.26442796 600.00 5.50 160.00 517.17 599.57 8.12 -12.70 4.62 HS 2.00 2.00 0.00 5969932.45 590702.84 N 70.32758632 W 149.26440620 700.00 7.50 160.00 616.53 698.93 14.92 -23.34 8.49 HS 2.00 2.00 0.00 5969921.86 590706.84 N 70.32755726 W 149.26437481 800.00 9.50 160.00 715.42 797.82 23.80 -37.23 13.55 HS 2.00 2.00 0.00 5969908.03 590712.06 N 70.32751932 W 149.26433382 Crv 2.5/100 825,00 10.00 160.00 740.06 822.46 26.35 -41.21 15.00 92.57E 2.00 2.00 0.00 5969904.07 590713.55 N 70.32750845 W 149.26432208 900.00 10.09 149.25 813.92 896.32 35.12 -52.97 20.58 81.98E 2.50 0.12 -14.34 5969892.38 590719.28 N 70.32747630 W 149.26427677 SV6 977.32 10.53 138.72 890.00 972.40 46.13 -64.10 28.71 71.62E 2.50 0.57 -13.62 5969881.34 590727.54 N 70.32744589 W 149.2 1000.00 10.72 135.83 912.29 994.69 49.74 -67.17 31.55 68.78E 2.50 0.85 -12.75 5969878.31 590730.42 6 N 70.32743750 W 149.26 1100.00 11.86 124.41 1010.36 1092.76 67.69 -79.66 46.51 57.58E 2.50 1.13 -11.41 5969866.01 590745.53 N 70.32740340 W 149.2640 653 1200.00 13.36 115.25 1107.96 1190.36 88.93 -90.39 65.44 48.64E 2.50 1.51 -9.17 5969855.50 590764.59 N 70.32737407 W 149.26391301 1300.00 15.13 108.04 1204.89 1287.29 113.42 -99.37 88.31 41.65E 2.50 1.77 -7.21 5969846.81 590787.56 N 70.32734955 W 149.26372760 End Bld 1382.49 16.73 103.27 1284.21 1366.61 136.03 -105.43 110.10 --- 2.50 1.93 -5.78 5969841.01 590809.42 N 70.32733299 W 149.26355089 SV5 1665.24 16.73 103.27 1555.00 1637.40 217.24 -124.11 189.30 --- 0.00 0.00 0.00 5969823.29 590888.83 N 70.32728194 W 149.26290865 SV4 1806.21 16.73 103.27 1690.00 1772.40 257.73 -133.43 228.79 --- 0.00 0.00 0.00 5969814.45 590928.43 N 70.32725649 W 149.26258847 Base Perm 1816.65 16.73 103.27 1700.00 1782.40 260.73 -134.12 231.72 --- 0.00 0.00 0.00 5969813.79 590931.36 N 70.32725460 W 149.26256476 SV3 2223.88 16.73 103.27 2090.00 2172.40 377.69 -161.03 345.79 --- 0.00 0.00 0.00 5969788.26 591045.73 N 70.32718107 W 149.26163979 SV2 2396.17 16.73 103.27 2255.00 2337.40 427.18 -172.42 394.05 -- 0.00 0.00 0.00 5969777.46 591094.12 N 70.32714996 W 149.26124847 SV1 2735.53 16.73 103.27 2580.00 2662.40 524.65 -194.84 489.10 --- 0.00 0.00 0.00 5969756.19 591189.44 N 70.32708868 W 149.26047767 9-5/8" Csg Pt 2970.47 16.73 103.27 2805.00 2887.40 592.13 -210.37 554.91 --- 0.00 0.00 0.00 5969741.46 591255.43 N 70.32704625 W 149.25994405 WeIlDesign Ver SP 2.1 Bld(doc40x_100) Plan V Slot (S-Q)\Plan V-217 (S-Q)\Plan V-217\V-217 (P2) Generated 10/24/2006 2:58 PM Page 1 of 2 Measured VeRical Gravity Comments Inclination Azimuth Sub•Sea TVD ND NS EW DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool Face ft de de ft ft ft ft ft de de 1100 ft de 1100 ft de 1100 ft ftUS ftUS U(i4 ;lU04.UU 70./:i 7U.S.L/ Ltftfb.UU L`Jb/.4U ti76.7L -L7 J.ify 5/tf.:f7 --- U.UV U.UU U.UU Oy0y/.SO.LJ Dy7L/if.tly IV /U..SL/U.f77t7 W 74`J.Lby/b4:i7 UG4A 3090.55 16. 73 103.27 2920.00 3002.40 626.61 -218.31 588.55 --- 0.00 0.00 0.00 5969733.93 591289.15 N 70:32702456 W 149.25967131 Fault Crossing 3127.09 16. 73 103.27 2955.00 3037.40 637.11 -220.72 598.79 --- 0.00 0.00 0.00 5969731.64 591299.42 N 70.32701796 W 149.25958830 UG3 3346.37 16. 73 103.27 3165.00 3247.40 700.09 -235.21 660.21 --- 0.00 0.00 0.00 5969717.90 591361.00 N 70.32697836 W 149.25909025 UG1 3884.12 16. 73 103.27 3680.00 3762.40 854.54 -270.75 810.84 --- 0.00 0.00 0.00 5969684.19 591512.04 N 70.32688123 W 149.25786886 Ma 4166.05 16. 73 103.27 3950.00 4032.40 935.52 -289.38 889.81 --- 0.00 0.00 0.00 5969666.51 591591.22 N 70.32683031 W 149.25722853 Mb1 4218.26 16. 73 103.27 4000.00 4082.40 950.51 -292.83 904.44 --- 0.00 0.00 0.00 5969663.24 591605.89 N 70.32682088 W 149.25710995 Mb2 4286.13 16. 73 103.27 4065.00 4147.40 970.01 -297.32 923.45 --- 0.00 0.00 0.00 5969658.98 591624.95 N 70.32680862 W 149.25695579 Mc 4348.78 16. 73 103.27 4125.00 4207.40 988.00 -301.46 941.00 --- 0.00 0.00 0.00 5969655.06 591642.55 N 70.32679730 W 149.25681350 Na 4421.88 16. 73 103.27 4195.00 4277.40 1008.99 -306.29 961.47 --- 0.00 0.00 0.00 5969650.48 591663.07 N 70.32678410 W 149.2 Nb 4442.76 16. 73 103.27 4215.00 4297.40 1014.99 -307.67 967.32 --- 0.00 0.00 0.00 5969649.17 591668.94 5 N 70.32678033 W 149.25 Nc 4479.31 16. 73 103.27 4250.00 4332.40 1025.49 -310.08 977.56 --- 0.00 0.00 0.00 5969646.87 591679.20 N 70.32677372 W 149.25 5 Ne 4484.53 16. 73 103.27 4255.00 4337.40 1026.99 -310.43 979.02 --- 0.00 0.00 0.00 5969646.55 591680.67 N 70.32677278 W 149.25650519 V-217 Tgt 4588.95 16 .73 103.27 4355.00 4437.40 1056.98 -317.33 1008.27 --- 0.00 0.00 0.00 5969640.00 591710.00 N 70.32675392 W 149.25626803 OA 4588.96 16. 73 103.27 4355.01 4437.41 1056.98 -317.33 1008.27 --- 0.00 0.00 0.00 5969640.00 591710.00 N 70.32675392 W 149.25626801 OBa 4662.04 16. 73 103.27 4425.00 4507.40 1077.97 -322.16 1028.74 --- 0.00 0.00 0.00 5969635.42 591730.53 N 70.32674071 W 149.25610202 OBb 4703.81 16. 73 103.27 4465.00 4547.40 1089.97 -324.92 1040.44 --- 0.00 0.00 0.00 5969632.80 591742.26 N 70.32673317 W 149.25600715 OBc 4761.24 16. 73 103.27 4520.00 4602.40 1106.46 -328.71 1056.53 --- 0.00 0.00 0.00 5969629.20 591758.39 N 70.32672280 W 149.25587672 OBd 4813.44 16. 73 103.27 4570.00 4652.40 1121.46 -332.16 1071.15 --- 0.00 0.00 0.00 5969625.93 591773.05 N 70.32671336 W 149.25575814 4886.54 16 .73 103.27 4640.00 4722.40 1142.45 -336.99 1091.63 --- 0.00 0.00 0.00 5969621.35 591793.58 N 70.32670016 W 149.25559213 OBe 4886.55 16. 73 103.27 4640.01 4722.41 1142.46 -337.00 1091.63 --- 0.00 0.00 0.00 5969621.35 591793.58 N 70.32670016 W 149.25559210 OBf 4917.86 16. 73 103.27 4670.00 4752.40 1151.45 -339.06 1100.40 --- 0.00 0.00 0.00 5969619.38 591802.38 N 70.32669450 W 149.25552098 OBf Base 4970.07 16. 73 103.27 4720.00 4802.40 1166.45 -342.51 1115.03 --- 0.00 0.00 0.00 5969616.11 591817.04 N 70.32668507 W 149.25540240 5136.10 16. 73 103.27 4879.00 4961.40 1214.13 -353.49 1161.53 --- 0.00 0.00 0.00 5969605.70 591863.67 N 70.32665508 W 149.25502532 TD / 7" Csg Pt 5136.54 16 ~. .73 103.27 4879.42 4961.82 1214.26 -353.52 1161.66 --- 0.00 0.00 0.00 5969605.67 591863.80 N 70.32665500 W 149.25502432 • WeIlDesign Ver SP 2.1 Bld(doc40x_100) Plan V Slot (S-Q)\Plan V-217 (S-Q)\Plan V-2171V-217 (P2) Generated 10/24/2006 2:58 PM Page 2 of 2 by Schlumberger 'HELL V-217 (P2) FIELD Prudhoe Bay Unit - WOA STRUCTURE V-Pad Ala9nellc P.vamelors Surface L acaM1On tuAD2' Alaska Stale Planes Zone Oa. US Feel •. nN an ~ AIOWI: fiGGM _OOa Dip. 30665' Dale Dnrmm~ar 252006 Of939936 nine i96 9 995 0 9 11U5 .na Conv. •0 o32fi2632' Slol PIan VSlol ~.S-O~ ND R~fI Rmary Tabls 19290 habove M1l4Li Atag Deo •2361]' >>330 ~ni Lon: W1<9155t 99i Eastlrg: 59065606 hUS Scale Fx1.0995509199] Plan V~21)IP21 rvy Dale' Octofier 21. 2006 -600 0 600 1200 1800 0 600 1200 1800 x 0 0 ~ 2400 u a~ m U 3000 3600 4200 4800 TD l 7" Csg P /:V-217 (P2) 600 0 600 1200 1800 Vertical Section (ft) Azim = 106.93°, Scale = 1(in):600(ft) Origin = 0 N/-S, 0 E/-V 0 600 1200 1800 2400 3000 3600 4200 4800 by Schlumherger WELL V-217 (P2) FIELU Prudhoe Bay Unit - WOA STHUCTUHL V-Pad Ma911ebc Paramewrs Motlnl: BGGM 2006 Diy. fi0.6d5' nla9 Dnc •236J]' DeW. Unwn~5ur 25. 2006 f5- 5]fi30.]nT Surlai;n NND2] N.uAa Sw1u Pwiiu~. Zuiix W. US Fux LW. Ly~N]019 J9A66 NUMUVY: S96YYYSUS nUS nJ fuin •u ti5(6261]" Wt<91551.99] Eaalap. 55U69b U0IIUS SVab facl U955Y05}la] ixnWiwuua SIW. PIr~VSWtIS UI TVD ReI. RWary Table 1636011 above MlSll f'Ln. V3111P21 SnY Daln: OWUWr 2Y. 200fi 0 150 300 450 600 750 900 1050 1200 0 n n n Z o -150 Ln c u a> m U ~ -300 v v v -450 9-5/8" Csg Pl Fault Crossing ............ i ...................................y..................................~.................................. ~..................................; ............:...................................:.................................:..................................:..................................: ................................................ ... ...................r .................................: ...... -zv ~ez~ V-217 Tgt TD 1 7" Csg Pt .......:..................................:..................................:.......................................... 0 150 300 450 600 750 900 1050 1200 c« W Scale = 1(in):150(ft) E »> ~ I, 0 -150 -300 -450 BP Alaska Anticollision Report Compan}: BP Amoco Date: 10/24/2006 Time: 15:12:42 Page: 1 Field: Prudhoe Bay Reference Site: PB V Pad Co-ordinutc (NE) Refe rence: Well: Pla n V-217 (S-Q), True North Reference Well: Plan V-217 (5-O) Vertical (TV D) Refere nce: V-217 Pl an 82.4 Reference Wcllpath: Plan V-217 Db: Oracle NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan $ PLANNED PROGRAM Interpolation Method: MD [nterval: 5.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 28.50 to 5136.54 ft Scan Method: Trav Cylinder No rth Maximum Radius:10000.00 ft Erro r Surface: Ellipse + Casing Survey Program for Definitive Wellpath ', Date: 9/21/2006 Validated: No Version: 2 Planned From To Survev Toolcode Tool Name ft ft ' 28.50 1000.00 Planned: Plan #2 V2 GYD-GC-SS Gyrodata gyro s ingle shots ', 1000.00 2900.00 Planned: Plan #2 V2 MWD+IFR+MS MWD +IFR + M ulti Station 2900.00 5136.54 Planned: Plan #2 V2 MWD+IFR+MS MWD +IFR + M ulti Station '. Casing Points -.T--- - -_ - - - - - -- MD TVD _ Diaaneter Hole Size Name - ft ft in in 2970.47 2887.40 9.625 12.250 9 5I8" .- ', 5136.54 4961.83 7.000 8.750 7" Summary <--------~----- O ffset W'ellpath ----- -----> Reference Offset Ctr-Gtr No-Gn Allowable Site Well Wellpa~th- h'1D NID Distance ,area Deviation Warning ft ft ft ft ft PB V Pad Plan V-04 (N-O) Plan V-04 V2 Plan: Pla 371.48 375.00 183.13 7.14 176.00 Pass: Major Risk PB V Pad Plan V-121 (S-R) Plan V-121 V2 Plan: PI 503.54 505.00 15.52 9.54 5.98 Pass: Major Risk PB V Pad Plan V-122 (S-U) Plan V-122 V4 Plan: PI 503.39 505.00 60.74 9.49 51.25 Pass: Major Risk ', PB V Pad Plan V-122 (S-U) Plan V-122P61 V5 Plan: 503.39 505.00 60.74 9.49 51.25 Pass: Major Risk PB V Pad Plan V-205 (S-P) Plan V-205 V10 Plan: P 474.67 475.00 15.98 9.10 6.88 Pass: Major Risk ' ', PB V Pad Plan V-205 (S-P) Plan V-205L1 OBa V5 PI 474.67 475.00 15.98 9.10 6.88 Pass: Major Risk PB V Pad Plan V-205 (S-P) Plan V-205L2 OA V6 Pla 474.67 475.00 15.98 9.10 6.88 Pass: Major Risk I ', PB V Pad V-01 V-01 V15 544.84 545.00 46.60 9.80 36.80 Pass: Major Risk ' PB V Pad V-02 V-02 V12 348.30 350.00 242.81 6.24 236.57 Pass: Major Risk PB V Pad V-03 V-03 V7 345.37 265.00 202.02 5.60 196.42 Pass: Major Risk ', PB V Pad V-100 V-100 V7 693.44 695.00 73.62 11.12 62.50 Pass: Major Risk '~, PB V Pad V-101 V-101 V7 352.29 355.00 294.65 6.14 288.52 Pass: Major Risk ', ', PB V Pad V-102 V-102 V5 357.46 360.00 210.01 7.30 202.72 Pass: Major Risk ', PB V Pad V-103 V-103 V6 279.89 280.00 184.45 4.92 179.52 Pass: Major Risk PB V Pad V-104 V-104 V13 323.85 325.00 252.50 5.59 246.91 Pass: Major Risk PB V Pad V-105 V-105 V13 517.86 530.00 184.09 8.91 175.18 Pass: Major Risk PB V Pad V-106 V-106 V10 337.82 340.00 178.70 5.62 173.08 Pass: Major Risk PB V Pad V-106 V-106A V9 119.60 120.00 180.26 2.30 177.96 Pass: Major Risk PB V Pad V-106 V-106AP61 V6 119.60 120.00 180.26 2.30 177.96 Pass: Major Risk ' PB V Pad V-106 V-106AP62 V2 119.60 120.00 180.26 2.30 177.96 Pass: Major Risk ' PB V Pad V-106 V-106AP63 V2 119.60 120.00 180.26 2.30 177.96 Pass: Major Risk PB V Pad V-107 V-107 V5 573.55 590.00 229.24 9.47 219.77 Pass: Major Risk PB V Pad V-108 V-108 V7 175.09 175.00 321.65 3.11 318.54 Pass: Major Risk PB V Pad V-109 V-109 V2 528.85 530.00 223.16 8.97 214.19 Pass: Major Risk PB V Pad V-109 V-109P61 V5 528.85 530.00 223.16 8.97 214.19 Pass: Major Risk ', PB V Pad V-109 V-109PB2 V2 528.85 530.00 223.16 8.97 214.19 Pass: Major Risk ', PB V Pad V-111 V-111 V25 377.10 380.00 190.48 7.12 183.36 Pass: Major Risk ', PB V Pad V-111 V-111 PB1 V8 377.10 380.00 190.48 7.12 183.36 Pass: Major Risk I, ', PB V Pad V-111 V-111 P62 V2 377.10 380.00 190.48 7.12 183.36 Pass: Major Risk ', PB V Pad V-111 V-111 PB3 V6 377.10 380.00 190.48 7.12 183.36 Pass: Major Risk ', PB V Pad V-112 V-112 V7 330.68 330.00 281.40 6.14 275.26 Pass: Major Risk i PB V Pad V-113 V-113 V6 459.09 460.00 252.23 7.27 244.96 Pass: Major Risk ~I ', PB V Pad V-114 V-114 V5 335.43 335.00 191.01 5.80 185.21 Pass: Major Risk ~' PB V Pad V-114 V-114A V4 335.43 335.00 191.01 5.80 185.21 Pass: Major Risk ', ', PB V Pad V-114 V-114AP61 V4 335.43 335.00 191.01 5.80 185.21 Pass: Major Risk PB V Pad V-114 V-114AP62 V2 335.43 335.00 191.01 5.80 185.21 Pass: Major Risk ', PB V Pad V-115 V-115 V5 334.47 335.00 107.56 5.67 101.89 Pass: Major Risk L PB V Pad V-115 V-115PB1 V4 334.47 3.35.00 107.56 5.67 101.89 Pass: Major Risk PB V Pad V-117 V-117 V9 398.74 400.00 44.66 6.98 37.67 Pass: Major Risk PB V Pad V-117 V-117PB1 V6 398.74 400.00 44.66 6.98 37.67 Pass: Major Risk ', PB V Pad V-117 V-117P62 V6 398.74 400.00 44.66 6.98 37.67 Pass: Major Risk ', PB V Pad V-119 V-119 V13 607.01 610.00 207.53 10.79 196.74 Pass: Major Risk BP Alaska Anticollision Report Cumpan~: BP AMOCO Field: Prudhoe Bay Reference Site: PB V Pad Reference Nell: Plan V-217 (S-Q) Reference ~Vellpath : Plan V-217 Sumnrir~ ~----------------- Offset 1Vellpath ----- --------> Sete Nell Wellpath PB V Pad V-120 V-120 VS 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 V-203 V18 ~~ PB V Pad V-203 V-203L1 V6 PB V Pad V-203 V-203L2 V4 PB V Pad V-203 V-203L3 V3 ~ PB V Pad V-203 V-203L4 V3 PB V Pad V-204 V-204 V2 ', PB V Pad V-204 V-204L1 V2 ' PB V Pad V-204 V-204L1 PB1 V6 PB V Pad V-204 V-204L2 V2 ', PB V Pad V-204 V-204L2P61 VS PB V Pad V-204 V-204L3 V3 PB V Pad V-204 V-204PB1 V9 PB V Pad V-204 V-204P62 V2 ', PB V Pad V-210 V-210 V9 PB V Pad V-211 V-211 V5 '~ PB V Pad V-212 V-212 V7 PB V Pad V-213 V-213 VS ~, 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-214P61 V2 PB V Pad V-214 V-214P62 V3 PB V Pad V-214 V-214P63 VS PB V Pad V-214 V-214P64 V2 PB V Pad V-216 V-216 V8 PB V Pad V-221 V-221 V6 Date: 10/24/2006 Cime: 15:12:42 Page: 2 i Co-ordinate(NE) Reference: Well: Plan V-217 (S-Q), True North ~ Vertical (TVD) Reference: V-217 Plan 82.4 Db: Oracle Reference Offset Ctr-Ctr Vo-Go ;Ulowahic (vID i~ID Distance area Deviation Warning ft ft ft ft ft 245.30 245.00 209.36 4.53 204.84 Pass: Major Risk 308.47 310.00 222.71 5.33 217.37 Pass: Major Risk 516.83 530.00 272.30 9.45 262.85 Pass: Major Risk 516.83 530.00 272.30 9.40 262.90 Pass: Major Risk 516.83 530.00 272.30 9.40 262.90 Pass: Major Risk ' 503.61 515.00 323.09 10.12 312.97 Pass: Major Risk 3171.83 7715.00 5873.15 No Offset Errors 3067.78 6965.00 5523.65 No Offset Errors 3048.77 6915.00 5490.28 No Offset Errors !, 503.61 .515.00 323.09 10.12 312.97 Pass: Major Risk ', 491.64 495.00 175.35 8.83 166.51 Pass: Major Risk ', 491.64 495.00 175.35 8.83 166.51 Pass: Major Risk 491.64 495.00 175.35 8.83 166.51 Pass: Major Risk 491.64 495.00 175.35 8.83 166.51 Pass: Major Risk ', 491.64 495.00 175.35 8.83 166.51 Pass: Major Risk !, 491.64 495.00 175.35 8.83 166.51 Pass: Major Risk '~, 491.64 495.00 175.35 8.83 166.51 Pass: Major Risk ', 491.64 495.00 175.35 8.83 166.51 Pass: Major Risk 241.29 240.00 262.41 4.28 258.13 Pass: Major Risk 246.49 245.00 308.97 4.31 304.66 Pass: Major Risk 340.51 340.00 181.43 5.97 175.46 Pass: Major Risk ', 269.51 270.00 91.59 5.03 86.56 Pass: Major Risk 269.51 270.00 91.59 5.03 86.56 Pass: Major Risk 295.39 295.00 285.26 5.98 279.28 Pass: Major Risk 379.33 380.00 286.09 8.05 278.04 Pass: Major Risk ', 303.40 300.00 285.78 6.00 279.77 Pass: Major Risk ', 303.40 300.00 285.78 6.00 279.77 Pass: Major Risk ', 303.40 300.00 285.78 6.00 279.77 Pass: Major Risk I 215.78 215.00 187.50 4.04 183.46 Pass: Major Risk 319.79 320.00 190.11 6.54 183.57 Pass: Major Risk ', • • FieldPrudhoe Bay Site PB V Pad We11:Plan V-217 (S-Q) WellpathElan V-217 313 300 200 100 0 2 100 200 300 313 0 Travelling Cylinder Azimuth (TFO+AZI) [deg[ vs Centre t LJ Site: PB V Pad Drilling Target Conf.: 95% Description: Map Northing: 5969640.00 ft Map Easting :591710.00 ft Latitude: 70° 19'36.3 l4N _ _- - -_ Shape: Circle '\ Target: V-217 Tgt Well: Plan V-217 (S-Q) Based on: Planned Program Vertical Depth: 4355.00 ft below Mean Sea Level Local +N/-S: -317.33 ft Local +E/-W: 1008.27 ft Longitude: 149° l5'22.565W _ Radius: 50 ft ___ __ -150 -200 -250 -000 -350 -x+00 0 0 0 0 0 ~ o In o In ~ o o - - --------- E 5,172 I ~ I o~ i> z I o< I ~U ®it ^ V-120 ~^ V-115 ` " ~ ^ V-03 ^ V-213i ~ ~ '~ ~ ~ ~\ ^ V-110 ' V-100 ^~V-111 -~-V-122 ~ ~ ~ I ^~/-216i V-117 ~ ^ V-103 = - ~" I V-212 --~ ^ SLOT S-R w I ~ ~ ~ ^tiv-10s V-217i I j ^ V-04 I ~. i ^ V-105i ; V-01 i ' I ~-V-205 i ^~/-22u' I ~--------------' ~ I I M ~ «, ~ ^ V-102 ~'^ V-SPARE (~aT ~}~ ^~ ~ I m /-201 1 ~ ( ^ ^ SLOT S-J II ~ 7 I z i ^ V-02 Ilum ^~/-104i '"^ V-204 li ~' i) ~l ^~-210i ^ V-114 I~O 1 iI '^ V-119 liz ^ V-202 ~ l ^ V-214i r.^ V-109 ^ V-101 ^~/-211i ~^ V-113 ^~V-108 ^ V-203 ^ V-112 ----- U/G ELECTRIC CABLE 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD-27. ---------- U/G FIBER OPTICS CABLE 2. BASIS OF HORIZONTAL CONTROL IS V-PAD OPERATOR MONUMENTATION. ~( LIGHT POLE 3. BASIS OF ELEVATION [S KUPARUK PIPELINE CONTROL. O-~• INDICATES 2 FINNED OFFSET THERMOSIPHON ELEVATIONS ARE BP MEAN SEA LEVEL DATUM. SEE DWG SS-WPV-00059 SHT 1 &SHT 2 4. THE MEAN SCALE FACTOR FOR V-PAD IS 0.999909334. FOR DETAILS. LOCATED WITHIN PROTRACTED SEC. 11, T. 11 N., R. 11 E., UMIAT MERIDIAN, ALASKA ~--Br------------JI a s ~ ~l° Vj~ ~ ~ i ~ ©a~~ 7 ~~ L-PAD ,,'~°_ s~~o ,~ ~~ \i ~~~\ ~,r~P 34~,=~ a ~: ~r3~6 ~0 A w~` d .a o:a" j.. < ~r ~~` ~`'` ~ 0 1~. ',~ e, , a G ~ WUEST ~u 1~ ti ' ~ ~ , .~ ~ ~ 03 Li .~~•• { 2 ~ '' s 1 ~ b. -~ o E,~ ~ V '~!.. ~f . AREA ° # ~ y1 ~ ~ i~~ ~ ~ ~~.: ...~ nii ^*'~. ~ ~ . ' ~~ ~ ~ ~ its ~ `~ \ ~.a f2 . , V-P D ~ Pl ~ .U ~ \3 .S 1i VICINITY MAP N.T.S. V-PAD TO SpiNE ROAD ~~ OY10Pl.~PpO ~~~~~~~~ ,- GR/p I LEGEND -' 15°00'00 ~Z PLANT -PROPOSED CONDUCTOR I ^ EXISTING CONDUCTOR NOTES WELL A.S.P. PLANT. GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD BOX ELEV. OFFSETS V-122 Y= 5,969,960.7 N= 10,000 70'19'39.582" ' " 70.3276617' N A ~ 4 711' FSL ' X= 590,.756.0 E= 4,970 149'15 50.299 149.2639719' 1,546 FEL V-205 Y= 5,969,929.6 N= 10,000 70'19'39.290" " ' 70.3275806' ' N A ~ 4 681' FSL ' X= 590,640.1 E= 4,850 53.694 149'15 149.2649150 1,663 FEL V-217i Y= 5,969,945.1 N= 10,000 70'19'39.436" " ' 70.3276211' NSA 4,696' FSL ' X= 590,698.1 E= 4,910 51.997 149'15 149.2644436' 1,605 FEL by ~ ~(~~\(]~\ JOB N0: ~ ly.Jl°Jl'JO~~ SCALE: ~~~ en vcs. nncnccoA u~ i"=150 ,~. GREATER PRUDHOE BAY V-PAD PROPOSED CONDUCTOR WELL V-0122, V-205, V-217i SHEET: 1 ov 1 ~: ~i Variance Request Compliance with AOGCC testing requirements for BOP rams after they have been used in the nom~al coarse of operations, RR-e= The AOGCC is in the process of developing a guideline document clarifing the intent ofi the regulations pertaining to function pressure testing ram type BOP's, BPXA requests a variance to the provisions ofi 20 AAC 25,035 (e)(10)C regarding the function pressure test requirement after the use of 60P ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness, (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations,) The activities associated with this request will not compromise the integrity of the BOP equipment. Background AOGCC regulations require rams that have been used in the course of primary drilling & completion, workover and through tubing drilling operations be fiunction pressure tested before the next wellbore entry. This is not a new regulation. The intent ofi this regulation is to ensure that ram type equipment has integrity after it has been utilized in a wellbore.:,for example; to ensure integrity if a ram was closed on a tool joint. The exact regulation language is: "if BOP sealing ram type equipment has been used, it must be function pressure-tested, before the next wellbore entry, to the required working pressure specifiied in the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent ofi its rated working pressure;" The pertinent sections are: 20 AAC 25.035 (e)(10)C PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285 (f)(2) TUBING WORKOVERS: 20 AAC 25,286(e)(1) WORKSTRING SERVICE OPERATIONS This issue has been discussed with Winton Aubert at the AOGCC. The test requirement in the regulation is intended to apply to ram tvoe eauipment only. The AOGCC understands that ram type BOP's are utilized for purposes other than well control in the normal coarse of operations, The regulations allowing a variance are at 20 AAC 25,035(h) PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036(f) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285(h) TUBING WORKOVERS• 20 AAC 25,286(8) WORKSTRING SERVICE OPERATIOPIS,,,which says generally: 20 AAC 25,035(h).., Upon request ofi the operator, the commission will, in its discretion, approve a variance {1) from the BOPS requirements in (e) ofi this section if the variance provides at least an equally effective means of well control; • • Terri- Hubble _ ss-str2s2 313 _ $P Exploration AK InC. ~~Mastercard Check" PO Box 196612 MB 7-5 - Anchora e AK 99519 ~ ~ ' ~+ g , HATE- `''`~' PAY TO THE ~ ER OF $ ' ~ ~ ` First National Barik Alaska ..Anchorage, AK 9 9501 1 MEMO- _~' 2` 71 ~ . ~: i 25 200060:99 l46 2 23 L 5 56~P 0 3 L 3 • ,. ~'i®IS~I~I'T'~I~ LETTER C'HE~'I{L.~~T PT®# OCR ~ ~~~ ®evelopment Ser`~ice E~cpdoratory~ Stratigraphic Test lion-Conventional Fell Circle Appropriate better /Paragraphs to be Included in Transmitted Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER ~h'H.aT (OPTIOtiSj APPLIES ;MULTI LATERAL ~ The permit is for a new wellbore segment of existing ~~ well (If last two digits in Permit No. . API No. ~0- ~~ API number are - - between 60-69) Production should continue to be reported as a function of the ' original API number stated above. PLOT HOLE In accordance with 20 A.4C 25.006(t~, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (~ 0- - -_) from records. data and logs acquired for well SPACPVG 'The permit is approved subject to full compliance with 20 AAC EXCEPTION Z~.O». 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 AI( dry ditch sample sets submitted to the Commission must be in i SAMPLE ! no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals !through target zones. ~ ~~ Non-Conventional ' Please note the following special condition of this permir: ~ production or production testing of coal bed methane is not allowed Well 'for (name of well) until after (Com~anv Name) has designed and j 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 we([ testing _,_ !program. Rev: 1 25:'06 C 'jod;;`transmittal checRlist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, ORION SCHR Bl OIL - 640135 Well Name: PRUDH__O_E BAY l1N_ORIN V-217_ _Program SER ____ _ Well bore seg __I PTD#: 2061620 Company BP_EXPLORATION (ALASKAN INC _ _ _ - Initial Classlfype _SER / 1WINJ GeoArea ____-_______ _-_ _ Unit __ _ On/Off Shore On _- Annular Disposal I"I Administration 11 Permit_fee attached- Yes 2 Lease number appropriate- - - Yes ' '3 Unique well-name and number Yes 4 Well located in a_definedpool Yes 5 Well located proper distance_from drilling unit boundary Yes i 6 Well located proper distance from other wells_ Yes 7 Sufficient acreage available in drilling unit _Yes 8 If deviated, is wellbore platincluded Yes 1 9 Operator only affected party Yes 10 Operator has appropriate_bond in force Yes 11 Permit can be issued without conservation order_ _ _ _ _ _ - Yes _ - 12 Permit_can be issued without administrative approval _ _ _Yes _ _ Appr Date 13 Can permit be approved before 15-day_wait Yes RPC 11129/2006' 14 Well located within area and strata authorized by Injection Order # (put 10# in_comments),(For Yes A1O 24 15 All wells-within 1!4-mile.area of review identified (For service well only) Yes V-100, V-109, V-03, V-915 V-111PBi V-111, V-02 ', 16 Pre-produced injector; duration ofpre-production less than 3 months_(For_service well only) NA_ V-204L1, V-204L3, V-204_ ~ 17 Nonconven, gas conforms to AS31 05,030Q.1.A) ~.2.A-D) NA_ 18 Conductor string_provided Yes - - 20" ~ 108 Engineering 1 19 .Surface casing protects all known_ USDWS - - - - - Yes 20 CMT_vol_ adequate to circulate on conductor-& surf_csg Yes Adequate excess. 21 CMT_vol adequate to tie-in long string to surf csg _ _ _ No i22 CMT_will cover all know_nproductiye horizons- _ _ _ _ Yes _ 23 Casing designs adequate f_or C, T, B &_permafrost_ Yes - - 24 Adequate tankage_or reserve pit _ _ _ _ _ . _ _ _ _ _ . - _ _ Yes _ _ _ IJabors 9ES. _ _ - _ _ - - _ 125 If a_re-drill, has_a_ 10-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ NA- New well, _ _ - I26 Adequate wellbore separation proposed - - - - Yes '27 If_diverter required, does it meet_regulations_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 28 Drilling fluitl_program schematic & equip list adequate Yes - - Max MW 9.5 ppg, Appr Date 29 BOPES, do the meet re ula_tion _ - - - Y 9 Yes _ WGA 11130/2006 30 BOPE_press rating appropriate; test t_o_(put psig in comments). - - - - Yes Test to 4000. psi.. MSP 1749 psi, 31 Chgke_manifold complies w1APl_RP-53 (May 84)_ Yes - - 32 Work will occur without_operation shutdown _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 33 Is presenee_ of H2S gas probable _ _ _ - - - - - - - - - - - - - - - - - - - - - - _ Yes _ Max i_10 ppm on pad. 34 Mechanical condition of wells within AOR verified (For_service well only) Yes All AOR wells reviewed.. 35 -- - Permit_can be issued w/o hydrogen sulfide measures _ No_ _ -- Geology 36 Data presented on potential overpressure zones NA_ 37 Seismic analysis of shallow gas zones_ _ _ .. _ _ _ _ . _ _ _ NA_ _ _ _ Appr Date 38 Seabed condition survey-(if off-shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA. _ _ _ _ _ _ RPC 11/29!2006 39 Contact name/ hone for week/ ro ress reports, ex lorato onl p Y p- 9- [ P rY - Yj - - NA_ Geologic Date: Engineering Date P ' Date Commissioner: ~%S I ~~ 30 ~ Coin'' is~'sio~,ne~/r: C~7~ ~~2~-g6 C miss ~l ~d - D-~' - --- -- _ _ - •