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205-134
New Plugback Esets 7/3/2024 Well Name API Number PTD Number ESet Number Date 1D-141A PB1 50-029-22967-73-00 208-016 T39107 7-16-2008 1D-141APB2 50-029-22967-74-00 208-016 T39108 7-16-2008 1D-141APB3 50-029-22967-75-00 208-016 T39109 7-16-2008 2K-08APB2 50-103-20111-71-00 211-049 T39110 6-13-2011 2K-08APB3 50-103-20111-71-00 211-049 T39111 6-13-2011 2K-08B PB1 50-103-20111-73-00 211-152 T39112 2-15-2012 2K-08B PB2 50-103-20111-74-00 211-152 T39113 2-15-2012 2K-08B PB3 50-103-20111-75-00 211-152 T39114 2-15-2012 3K-105L1 PB1 50-029-23479-72-00 212-166 T39115 3-12-2013 3K-105L1 PB2 50-029-23479-73-00 212-166 T39116 3-12-2013 3K-105L1 PB3 50-029-23479-74-00 212-166 T39117 3-12-2013 SP22-FN01 PB3 50-629-23478-72-00 212-162 T39118 3-20-2013 V-214 PB2 50-029-23275-71-00 205-134 T39119 1-29-2007 V-214 PB3 50-029-23275-72-00 205-134 T39120 1-29-2007 V-214 PB4 50-029-23275-73-00 205-134 T39121 1-29-2007 V-VV 214 PB2 50-029-23275-71-00 205-134 T39119 1-29-2007 V-VV 214 PB3 50-029-23275-72-00 205-134 T39120 1-29-2007 V-VV 214 PB4 50-029-23275-73-00 205-134 T39121 1-29-2007 Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 V-214 205134 500292327500 5 12/31/2023 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-214 PRUDHOE BAY UN ORIN V-214 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 V-214 50-029-23275-00-00 205-134-0 G SPT 4147 2051340 1500 688 690 689 688 385 385 385 386 4YRTST P Guy Cook 6/11/2023 Testing was completed with a Little Red Services pump truck and calibrated gauges. 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-214 Inspection Date: Tubing OA Packer Depth 268 1750 1686 1671IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230610153253 BBL Pumped:1.2 BBL Returned:1 Thursday, July 27, 2023 Page 1 of 1 MEMORANDUM TO: Jim Regg 'Q, ! / P.I. Supervisor 1�G% 1 FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 15, 2019 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. V-214 PRUDHOE BAY UN ORM V-214 Src: Inspector Reviewed By�:pp P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-214 API Well Number 50-029-23275-00-00 Inspector Name: Jeff Jones Permit Number: 205-134-0 Inspection Date: 6/4/2019 Insp Num: miUJ190707I63126 Rel Insp Num: T Packer Depth Pretest Well V-214 iType Inj wTVD j 4142 Tubing 1 1369 PTD 2051340 'JTypeTest SPT ITestpsij~1500 IA i 30 BBL Pumped: z.1 BBL Returned. 1 9 OA 635 Interval 4YRTST I-- P Notes: I well inspected, no exceptions noted. Initial 15 Min 30 Min 45 Min 60 Min 1355 13571431_� 0300 - 2238 2 221� 'i— 64640 639 Monday, July 15, 2019 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 30,2015 TO: Jim Regg P.I.Supervisor '. e-6/t1 1 S- SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC V-214 FROM: Bob Noble PRUDHOE BAY UN ORIN V-214 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-214 API Well Number 50-029-23275-00-00 Inspector Name: Bob Noble Permit Number: 205-134-0 Inspection Date: 6/27/2015 Insp Num: mitRCN150628064157 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-214 • Type IRj ''- TVD I 4147 Tubing 1038 I 1044 - I 1049 - f 1040 • PTD 2051340 'Type Test SPT Test psi 1500 IA 622 I 2505 2439 - 2424 - Interval 4YRTST PAF P ✓ OA 721 725 - 725 725 Notes: - - - -- — --- - — -- - SChI�KEL) l t4 June 30,2015 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday,June 19, 2015 10:03 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad LV; Swensen, Brenden;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg,James B (DOA); Pettus,Whitney;Weiss, Troy D; Morrison, Spencer Subject: UNDER EVALUATION:Injector V-214 (PTD#2051340) Place on Injection for Compliance testing Attachments: image001.png; image002.png All, Injector V-214(PTD#2051340)was due for its AOGCC witnessed MIT-IA in April of 2015 and is now ready to be placed on injection. At this time the well has been reclassified as Under Evaluation to facilitate compliance testing. Please use caution when bringing the well online as the annuli are fluid packed. g g Plan Forward: 1. Operations: Place well on injection 2. Downhole Diagnostics: Once thermally stable, perform AOGCC witnessed MIT-IA Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator w1�1 '���'� GA] Growl Wells � 153 z Yv Ufyantaton WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com From: AK, ►;C Well Integrity Coordinator Sent: Thursday, •ril 09, 2015 2:15 PM To: AK, OPS GC2 OS , OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D: - Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RE ': East Wells Opt Engr; AK, OPS Well Pad LV; Swensen, Brenden; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D: ID HD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; ' egg@alaska.gov' Subject: NOT OPERABLE: Injector V-214 (PTD #2051340 e For AOGCC MIT-IA All, t, 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, April 09, 2015 2:15 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M IL; AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad LV; Swensen, Brenden;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg,James B (DOA) Subject: NOT OPERABLE:Injector V-214 (PTD #2051340) Due For AOGCC MIT-IA Attachments: image001.png;Injector V-214 (PTD #2051340) TIO plot.docx All, Injector V-214(PTD#2051340) is due for an AOGCC MIT-IA. The well will not be placed on injection for the test before the due date. The well is reclassified as Not Operable until the well is ready to be placed on injection, and will be added to the Quarterly Not Operable Injector Report. A copy of the TIO plot is included for reference. Kevin Parks %MINED APR 1 0 2015 (Alternate. Laurie Climer) BP Alaska-Well Integrity Coordinator Gt A I Global Wells V V Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com 1 • Injector V-214 (PTD #2051340) TIO plot Weil » DOC ie ODA On 0.Y In/ 0109,15 0"1415 01/13'15 0113(115 02005 EVIVS C2 20 5 03/36'.5 03'.3"5 ?>1015 0321.15 040335 .. • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. v~©~ - ~ ~ ~- Well History File Identifier Organizing (aone> RESCAN ~olor Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: ~wo-sided I~III~IIIIIIIIIIII DIGITAL DATA Diskettes, No, ~ ^ Other, No/Type: o Ra,~a~~eeaea iuiumiuium OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Maria _ Project Proofing BY: Maria Q' ^ Other:: Date: (~ ~ p Date: a-•I + 3 If~ ~P ,,iiiuiuuiiuiuu ~~ ~- ~ 1 Scanning Preparation ~ x 30 = ~~ + ~ =TOTAL PAGES_~_SLrL (Count does not include cover sheet) BY: _ Maria Date: ~ f 1,3I ~ ~ /s/ Production Scanning Stage 1 Page Count from Scanned File: (count does inc~ud~e cover sheet) Page Count Matches Number in Scanning Preparation: ---tom . ES NO BY: Maria Date: ~,I ~~7J Dg lsl rV 1, ~,~ 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 () I II II I I III ReScanned III IIIII) IIIII I I III BY: Maria Date: /s/ Comments about this file: Quality Checked 10/6/2005 Well History File Cover Page.doc MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday, April 08, 2011 P.I. Supervisor ( ��j � I � ' // ( SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V -214 FROM: Matt Herrera PRUDHOE BAY UN ORIN V -214 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN ORIN V - 214 API Well Number: 50 029 - 23275 - 00 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH110408123254 Permit Number: 205 - 134 - Inspection Date: 4/7/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well v -214 "' Type Inj. W `I TVD 4147 ' IA 210 2030 • 1978 - 1968 P.T.D 2051340 • TypeTest SPT Test psi 2000 - OA 120 120 120 120 Interval 4YRTST P/F P ' Tubing 920 920 920 920 Notes: ('eca 4S - iStY3f APR 1 3 2011 Friday, April 08, 2011 Page 1 of 1 • BP Exploration (Alaska) Inc. .__. .--.- •-- Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~y r~ L r C~t7~~VJ~'a..al'.;J ,~ i~ -~~..~ ~ ~ ~~ . August 14, 2009 C~ bp ~~~~~~~~ OCT Q 6 2t~09 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 ~alt8 Oil & Gas Cona. ~ommi~~in~ AnchorAq~ Subject: Corrosion Inhibitor Treatments of GPB V-Pad a.o-~- 3~1- Dear Mr. Maunder, ~,~., ~ ~-,- Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date V-pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al V-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 5002923124000o surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 V-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 V-102 2020330 50029230700000 NA 7.75 NA 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 5002923o830t00 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 5D029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 NA 1.5 NA 13.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-t22 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 V-2o~ 2012220 5002923054000o SC leak NA 4 NA 90.6 8/7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009 V-203 2051680 50029232850000 NA 2 NA 12.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061800 50029233380000 NA 1.8 NA 13.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-210 2042100 50029232310000 NA 2 NA 18.7 7/11/2009 V-211 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-212 2051500 50029232790000 NA 1.2 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11 /2009 V-215 2070410 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 "~ 2080200 50029233830000 NA 1.75 NA ~ 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 03!18/09 ~~~ ... 4r ~~ ~ t,a~ ~~''~ d .~ ~ I `j,, fit-. / `°®T""4 Ul~b~ ~ ~~ ,.. ~~ ~~ ~-a °~ ..~ N0.5133 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 r~~~~3~~ ~ ~h~~ .tars Attn: ChristineMahnken ATTN: Beth - ~ ~ w ya~.~ .. v(':~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 J-27A AY3J-00010 CBL - - -----1 _-_ " 02/21/09 v iv Y S-107 AWJB-26 MEM L L U ~ 'a- 02/25/09 1 1 09-34A AZ4D-00005 USIT (REVISED) 02/07/09 1 1 V-210 AWJB-00025 INJECTION PROFILE 02/23/09 1 1 MPB-22A AXBD-00005 MEM SCMT & TEMP PROFILE . '' 12/23/08 1 1 V-219 12103700 USIT (REVISION #2) . ~ ( - 11/21/08 1 1 11-18 BOCV-00006 PRODUCTION LOG / C/ 03/02/09 1 1 B-25 AVY5-00023 USIT - /'~ /~ 03/06/09 1 1 N-18A AYKP-00013 _ PRODUCTION LOG O~3 - 1'~-S /_ ~ 03/11/09 1 1 F-18 AVY5-00022 USIT ~ %=' _ ''j- 03/04/09 1 1 3-19/R-28 AZ4D-00009 LDL / (l • - 03/06/09 1 1 V-117 BOOR-00003 MEM PRODUCTION PROFILE ~p - ( ~ 03/12/09 1 1 V-211 AY3J-00014 (PROF/RST WFL -' 03/16/09 1 1 V-214 AY3J-00013 IPROF/RST WFL - L 03/15/09 1 1 K-06B AWJI-00017 MCNL _ ~ - f 01/28/09 1 1 L5-15 12113027 RST - /D ~ / - 12/09/08 1 1 07-18 12071915 RST 9 ~ v 12/01/08 1 1 15-15C AWJI-00015 MCNL r ~ 01/02/09 1 1 W-218 40018337 OH MWD/LWD EDIT 12/07/08 2 1 R-41 40018496 OH MWD/LWD EDIT _/5 / 01/04/09 2 1 H-18 11999064 RST / - 10 ~- .12/03/08 1 1 -- - ~ . ~~.+.+.-.+v.~..v ••.-.-v.a~ n._vc~r ~ o r a~aawnvv raw nGl Vn1YllYai VIVC I.VYT CAl.fl 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~.~~--~ i~ _a ~~s 'I 5 a e~ ~ ~ ~ ~ 3~r~- i ~ ~. Copy relit pu ~c~1 3 ~al o~ Alaska Data & Consulting Services 2525 Gambell Str~ e?t w~jte a00 - Anchorage, AK ~_5~2>~; 8 -° }' ATTN: Beth Received by: ~1 tt G.b ~ :~a ?E7, i} ~~_ ~~ oaiosioa ~~ $Cll~llltlh~~'~1' NO.4657 Alaska Data & Consulting Services p Company: State of Alaska 2525 Gambell Street, Suite 400 ~~~~ ~~~ ~ L~, ~~~~, Attnk Christine Mahnkenomm Anchorage, AK 99503-2838 t ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Endicott, Orion ~Ncll Jnh 3t Inn Dpsrrintinn ^ate RL Cnlnr CD 03-10 12045070 USIT -~ 03/24/08 1 1 1-21/K-25 11998996 USIT 03!25/08 1 1 V-223 12061688 CEMENT EVALUATION LOG /(p 03/23/08 1 1 V-214 11978449 MI INJECTOR V '- ((p C O 04/01/08 1 1 18-13B 12061689 PRODUCTION PROFILE '}_'-( ~ 03!27!08 1 1 E-10A 11998994 USIT (~ '} 03/28/08 1 1 02-126 11628789 MCNL a / / U `~ 08/21/07 1 1 15-45B 11963079 MCNL O 02/14/08 1 1 V-220 12031459 CH EDIT PDC GR (USIT)~(5~ !t'p ~} 03/07/08 1 V-214 40016214 OH MWD /LWD 04/01/08 2 1 --c~ J!C ~ 1 - YLtHSt HG RIVVYVLtUtat h{tGtlMl CY JWIVIIVU HryV ritl Vt11V 11VV VIVO ~.VrT tHli l'1 I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~' 900 E. Benson Blvd. Anchorage, Alaska 99508 1 ,, Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-28 ATTN: Beth \ Received b `I' • LJ ~~~.~~ DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drilf 2051340 Well Name/No. PRUDHOE BAY UN ORIN V-214 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23275-00-00 MD 7449 TVD 4874 Completion Date 12/1/2005 Completion Status SUSP Curren t Status WAGIN UIC Y REQU IRED INFORMATION Mud Log No Samples No Directional Surve Yes DATA INFORMATION Types Electric or Other Logs Run: MWD / GR, MWE / GR / RES /DEN / NEU / PWD (data taken from Logs Portio n of Master Welf Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 25 1006 Open 1/9/2006 PB 1 TED D Asc Directional Survey 170 7380 Open 1/9/2006 PB 2 ~D D Asc Directional Survey 3721 6196 Open 1/9/2006 PB 3 >~D D Asc Directional Survey 3721 5336 Open 1/9/2006 PB 4 ~g Sonic 5 Col 1 3700 3773 612312006 UBI24-Nov-2005 D Asc Directional Survey 0 7449 Open 12/18/2006 Rpt Directional Survey 0 7449 Open 12/18/2006 '~6g Cement Evaluation 5 Col 1 3000 7300 Case 1/29/2007 USCE, 6.05' Guage Ring, Junk Basket 2-Nov-2006 ~t 14361~.IS Verification 1 129 1006 Open 1/29/2007 PB1 LIS Veri, GR, ROP ~~D C Lis 14361 ~(nduction/Resistivity 1 129 1006 Open 1/29/2007 PB1 LIS Veri, GR, ROP ~Rpt 14361 ~IS Verification 1 129 7282 Open 1/29/2007 PB2 LIS Veri, GR, ROP, FCNT, DRHO, RHOB, j NCNT, NPHI ~ i~ ~D C Lis 14361 ~lnduction/Resistivity 1 129 7282 Open 1/29/2007 P62 LIS Veri, GR, ROP, FCNT, DRHO, RHOB, NCNT, NPHI ,fit 14361 LIS Verification 1 129 6151 Open 1/29/2007 PB3 LIS Veri, GR, EWR4, , ROP, FET ';~D C Lis 14361 induction/Resistivity 1 129 6151 Open 1/29!2007 P63 LIS Veri, GR, EWR4, , FET ~t 14361 e~LIS Verification 1 129 5286 Open 1/29/2007 PB4 LIS Veri, GR, ROP -:~ C Lis 14361'~Induction/Resistivity 1 129 5286 Open 1!29!2007 PB4 LIS Veri, GR, ROP, ~I i EWR4 ti~ C Lis 15209 Induction/Resistivity 3530 7448 Open 6/11/2007 LIS Veri, GR, ROP, FET, ,. NPHI w/Graphics PDF, Txt I DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051340 Well Name/No. PRUDHOE BAY UN GRIN V-214 Operator BP EXPLORATION (ALASI(A) INC API No. 50-029-23275-00-00 MD 7449 TVD 4874 Completion Date 12/1/2005 Completion Status SUSP Gurrent Status WAGIN UIC Y ;.dg 15209vthduction/Resistivity 25 Blu 3761 7449 Open 6/11/2007 MD Vision Service 30-Oct- 2006 ~og 15209 vinduction/Resistivity 25 Blu 3761 7449 Open 6/11/2007 TVD Vision Service 30-Oct- I 2006 ~D C Lis 15360,, induction/Resistivity 1 129 1006 Open 8/23/2007 PB1 LIS Veri, GR, ROP ~D C Lis 15361 ,.Induction/Resistivity 1 129 7282 Open 8/3/2007 PB2 LIS Veri, GR, ROP, FCNT, DRHO, RHOB, NCNT, NPHI C!~D C Lis 15362 vlnduction/Resistivity 1 129 6151 Open 8/3/2007 PB3 LIS Veri, GR, EWR4, FET D C Lis 15363 Induction/Resistivity 1 129 5286 Open 8/23/2007 PB4 LIS Veri, GR, ROP, EWR4 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? `/`F~~' Analysis `~/~-Pd~' Received? Comments: Compliance Reviewed By: Daily History Received? ~ N Formation Tops ~/ N Date: - V t V-214 (PTD#2051340) Reclassifi~as Operable ~ Page 1 of 1 Regg, James B (DOA} From: Winslow, Jack L. [Lyonsw@BP.com] Sent: Monday, October 01, 2007 10:40 AM To: Rossberg, R Steven; NSU, ADW Weli Operations Supervisor; Regg, James B (DOA); Maunder, Thomas E (DOA); Engel, Harry R Cc: NSU, ADW WI Tech; Lau, John, Jack; NSU, ADW Weil Integrity Engineer; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Weilpad Lead; GPB, Wells Opt Eng; Oakley, Ray (PRA) Subject: V-214 (PTD#2051340) Reclassified as Operable All - Well V-214 was classified as Not Operable due to a THA x master valve flange leak. The leak has been repaired, therefore this well is reclassified as Operable. Please call with any questions or concerns. Thank you - Jack L. Witrslow {for Anna Dine) Well Integrity Engineer office - 659-5102 pager.- 659-5100, 1154 10/1 /2407 r f ~~1 t ~ yet,', li ~ ~ Sehlumberger-DCS <. ~ ~.:..~ ,tom. 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~- Well Job # Log Description NO.4292 Company: Alaska Oil 8 Gas Cons Comm AHn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prutlhoe Bay Orion Borealis Date BL Color CD V-218 Z-102 11661147 11637125 MEMORY TEMP SURVEY CEMENT IMAGEIBOND LOG 05119107 05116!07 1 1 V-04 V-214 40014377 40014206 OH EDIT MWDILWD OH EDIT MWD/LWD 11/28/06 10130106 2 2 1 1 L-250 V-122 40012593 40014531 OH EDIT MWO/LWD OH EDIT MWD/LWD 11109!05 12/30/06 2 2 1 1 V-122PB1 V•122P82 40014531 40014531 OH EDIT MWD/LWD OH EDIT MWDILWD 12116/06 12/28107 2 1 1 1 L-250L1 L-250P81 40012593 40012593 OH EDIT MWDILWD OH EDIT MWD/LWD 11/15/05 10126/05 1 2 1 1 L-04 OWDW-NW 40014142 11477941 OH EDIT MWD/LWD RST 10/09106 11/14/06 2 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: ~._~ ao5 = r3~1 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: '~ ~5 ao 9 06/07/07 o~ • • WELL LOG TRANSMITTAL To: State of Alaska January 11, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs V-214 PB 1, PB2, PB3 & PB4, AK-MW-3954016 1 LDWG formatted CD rom with verification listing. API#: 50-029-23275-70, 71, 72, 73. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETLR~VING A COPY OF THE TRAi~TSl~TITT.YI. LETTER TO TAE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 S ., .~ ~ _~ ~..- ' _~ .. rY~a ~~ Date: ~ o BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~: 01/22/07 • Scfdum~erger Schlumberger-OCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO.4114 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Borealis Orion Date BL Calor CD Z-100 10672336 LDWG OH EDIT WIRELINE 12102105 2 1 V-122 11536192 CH EDIT USIT POC-GR 01/01107 1 1 5-124 11485868 USIT 11/08106 1 V•214- 11212896 USIT 11/02106 1 5-121 11368505 MEM PROD PROFILE 71/06106 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPV EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered. Schlumberger-DCS 2525 Gambell Sl, Suite 400 Anchorage, AK 99503-2838 __ _ _ ___ ATTN: Beth e ~ _ _ ' _ ~, ~.,- n - _- Received by. am " ; -~ ~'" "' ~. n. - MEMORANDUM TO: Jim Rego ~~ ~ , ~ P.I. Supervisor d ~`'H ~ ~ ~ ~~~~'~ t FRO:~i: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 17, 2007 SUBJECT: Mechanical [ntegrity Tests BP EXPLORATION (ALASK.A) INC V-214 PRUDHOE B.AY UN ORIN V-2 f4 Src: Inspector NON-CONFIDENTIAL Reviewed Bv: P.[. Suprv~~lZ- Comm Well Name: PRUDHOE SAY LT1 ORIN V-214 Insp Num: miUCr070ll70'4034 Rel Insp Num API Well Number Permit Number: 59-029-23275-00-00 zos-134-0 Inspector Name: John Crisp Inspection Date: 1i8i2007 Packer Depth Pretest Initial IS Min. 30 Min. 45 Min. 60 Min. ---- Well ~ v-zia ,Type Inj. ~ w j TVD i aia~ ', IA Aso I 2soo T zaso 2aas ! -- - P.T. ~ 201310 ~~,T}'peTest ` SPT '~i Te$t psl '~ - I500 OA - - Z30 330 ~ - 310 300 --', - - -- Interval rniTAi, P/F P / NOteS ~ ~ bbl's pumped for test. Tubing , ioso Soso -- ioso ~ toso - ' - Wednesday. January 17, 2007 Page I of I ' STATE OF ALASKA ~~~'-~ RECEIVED ALASK~IL AND GAS CONSERVATION COM117tf$SION January 17, 2007 WELL COMPLETION OR RECOMPLETION REPORT IQMl+1Qi h~oa Gas Conservation Commission 01/17!07: A;:PUt on Injection 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG zoAACZe.~os zoAACZS.,~o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 11/6/2006 12. Permit to Drill Number 205-134 ' 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/29/2005 13. API Number 50-029-23275-00-00' 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 10/30/2006 14. Well Name and Number: PBU V-2141 4816 FSL, 1862 FEL, SEC. 11, T11N, R11E, UM Top of Productive Horizon: 3773' FSL, 3381' FEL, SEC. 02, 711 N, R11 E, UM 8. KB Elevation (ft): 81.6' 15. Field /Pool(s): Prudhoe Bay Field / Orion ~ Total Depth: 3978' FSL, 3500' FEL, SEC. 02, T11N, R11E, UM 9. Plug Back Depth (MD+TVD) 7356 + 4785 Ft Schrader Bluff 4b. Location of Well (State Base Plane Coordinates): Surface: x- 590439 y- 5970062 Zone- ASP4 10. Total Depth (MD+TVD) 7449 + 4874 Ft 16. Property Designation: ADL 028240 ~ TPI: x- 588865 y- 5974280 Zone- ASP4 Total Depth: x- 588743 y- 5974483 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD / GR, MWD / GR /RES /DEN /NEU /PWD; MWD / GR /RES /DEN /NEU /PWD, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING' DEPTH MO SETTING DEPTH.TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP. BOTTOM.. SIZE CEMENTING RECORD PULLED 20" 215.5# A-53 Surface 102' Surface 102' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 27' 3757' 27' 2642' 12-1 /4" 482 sx AS Lite 682 sx Class 'G' 7" 26# L-8 28' 7440' 28' 48 5' 8-3/4" 105 sx LiteCre 2 sx lass'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", 9.3#, L-80 7206' 6675', 6853', 6948', MD TVD MD TVD 7039' & 7103' 6702' - 6712' 4171' - 4150' 6900' - 6940' 4353' - 4391' 25', ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6966' - 6994' 4416' - 4442' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 7010' - 7028' 4457' - 4474' 7068' - 7082' 4512' - 4525' Freeze Protect with 95 Bbls of Diesel 7120' - 7170' 4562' - 4609' 26. PRODUCTION TEST Date First Production: January 1, 2007 Method of Operation (Flowing, Gas Lift, etc.): Waterlnjection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE .SIZE GAS-OIL RATIO FIOW TUbing PreSS. CaSing PfeSSUre CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~. I~~ll) ~ tQQf None Form 10-407 Revised 12/2003 CONTINUED ~ ~~91~L ~, I a ~ ~8 , ~ GEOLOGIC MARKE 29. RMATION TESTS Include and briefl mmarize test results. List intervals tested, NaNE MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 4263' 2852' None Ugnu MA 6474' 3976' Ugnu MB1 6515' 4010' Ugnu M62 6600' 4081' Ugnu MC 6665' 4138' Schrader Bluff NA 6734' 4200' Schrader Bluff NB 6759' 4222' Schrader Bluff NC 6793' 4253' Schrader Bluff NE 6801' 4261' Schrader Bluff NF 6858' 4314' Schrader Bluff OA 6900' 4353' Schrader Bluff OBa 6966' 4416' Schrader Bluff OBb 7008' 4455' Schrader Bluff OBc 7068' 4512' Schrader Bluff OBd 7122' 4563' Schrader Sluff OBe 7183' 4621' Schrader Bluff OBf 7231' 4667' Base Schrader Bluff 7281' 4714' 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. /~ ~7 v`~ J ~ / Signed Terrie Hubble / Title Technical Assistant Date PBU V-2141 205-134 Prepared !3y NameMumber. Terrie Hubble, 564-4628 Well Number Permit No. / A r val No. OriUing Engineer: Matt Martyn, 564-4101 INSTRUCTIONS GeNeRa~: 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, Satt 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 {nterval). IreM 8: The Ke11y 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 SCHLUMBERGER Survey report Client ...................: Field ..................... Well ...................... API number... .............: Engineer .................. Rig :...................... STATE :...................: ----- Survey calculation m Method for positions.....: Method for DLS...........: BP Exploration (Alaska) Inc. Orion V-214 50-029-23275-00 St. Amour Nabors 9E5 Alaska ethods------------- Minimum curvature Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 53.85 ft KB above permanent.......: N1A (Topdrive) DF above permanent.......: 81.60 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 339.17 degrees d /1 30-Oct-2006 12:13:10 Page 1 of 5 Spud date ................: 28-Oct-06 Last survey date.........: 30-Oct-06 Total accepted surveys...: 114 MD of first survey.......: 0.00 ft MD of last survey........: 7449.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2005 Magnetic date ............: 27-Oct-2006 Magnetic field strength..: 57581.57 GAMA Magnetic dec (+E/W-).....: 24.08 degrees Magnetic dip .............: 80.85 degrees ----- MWD survey Reference Reference G ..............: Reference H ............... Reference Dip ............: Tolerance of G...........: Tolerance of H............ Tolerance of Dip.........: Criteria --------- 1002.68 meal 57626.50 GAMA 80.88 degrees (+/-) 2.50 meal (+/-)300.00 LAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.92 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.92 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 W SCHLUMBERGER Survey Report 30-Oct-2006 12:13:10 Page 2 of 5 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course ------- ------- TVD - -------- - -------- Vertical -------- -------- Displ -------- -------- Displ ------- ------- Total -------- -------- At ----- ----- DLS - - ---- ------ ---- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) ------- (ft) - -------- (ft) -------- (ft) -------- (ft) ------- (deg) -------- 100f) ----- - type (deg) ---- ------ --- 1 -------- 0.00 ------ 0.00 ------- 0.00 ------ 0.00 ------- 0.00 - -------- 0.00 -------- 0.00 -------- 0.00 ------- 0.00 -------- 0.00 ----- 0.00 - ---- ------ TIP None 2 102.80 0.19 285.15 102.80 102.80 0.10 0.04 -0.16 0,17 285.15 0.18 BP _GYD CT DMS 3 172.80 0.27 317.17 70.00 172.80 0.32 0.20 -0.39 0.44 296.74 0.21 BP _GYD CT DMS 4 266.80 1.14 344.20 94.00 266.79 1.46 1.26 -0,79 1.49 327.75 0.97 BP _GYD CT DMS 5 359.80 2.94 357.67 93.00 359.73 4.64 4.53 -1.14 4.67 345.85 1.99 BP _GYD CT DMS 6 453.80 4.06 10.31 94.00 453.55 9.78 10.21 -0.65 10.23 356.39 1.44 BP _GYD CT DMS 7 490.75 4.62 10.87 36.95 490.40 12.16 12.96 -0.13 12.96 359.42 1.52 BP _MWD+IFR+MS 8 537.91 5.97 12.95 47.16 537.36 15.82 17.22 0.78 17.24 2.59 2.89 BP _MWD+IFR+MS 9 580.97 7.59 13.67 43.06 580.11 20.02 22.16 1.95 22.25 5.03 3.77 BP _MWD+IFR+MS 10 630.20 8.81 13.85 49.23 628.84 25.80 28.98 3.62 29.21 7.12 2.48 BP MWD+IFR+MS 11 673.36 9.84 11.62 43.16 671.43 31.63 35.81 5.16 36.17 8.19 2.53 BP _MWD+IFR+MS 12 719.47 10.85 8.60 46.11 716.79 38.74 43.96 6.60 44.45 8.54 2.49 BP_MWD+IFR+MS 13 763.91 12.20 5.91 44.44 760.33 46.57 52.76 7.71 53.32 8.31 3.27 BP _MWD+IFR+MS 14 811.42 13.16 1.72 47.51 806.68 56.05 63.16 8.39 63.72 7.56 2.80 BP _MWD+IFR+M5 15 859.45 14.81 356.48 48.03 853.29 66.96 74.76 8.17 75.20 6.24 4.33 BP MWD+IFR+MS 16 907.90 16.39 354.19 48.45 899.95 79.48 87.74 7.10 88.03 4.63 3.50 BP _MWD+IFR+MS 17 955.18 17.22 355.25 47.28 945.21 92,65 101.35 5.85 101.52 3.30 1.87 BP _MWD+IFR+MS 18 1005.10 19.56 355.86 49.92 992.58 107.75 117.05 4.63 117.14 2.27 4.70 BP _MWD+IFR+MS 19 1051.45 21.49 355.00 46.35 1035.99 123.35 133.25 3.33 133.29 1.43 4.21 BP _MWD+IFR+MS 20 1102.38 21.69 355.05 50.93 1083.34 141.38 151.92 1.71 151.93 0.64 0.39 BP MWD+IFR+MS _ 21 1146.30 22.25 354.66 43.92 1124.07 157.20 168.28 0.23 168.28 0.08 1.32 BP _MWD+IFR+MS 22 1199.10 24.80 353.41 52.80 1172.48 177.57 189.24 -1.97 189.25 359.40 4.92 BP _MWD+IFR+MS 23 1244.22 26.06 354.74 45.12 1213.23 196.29 208.51 -3.96 208.55 358.91 3.07 BP _MWD+IFR+MS 24 1288.56 25.71 354.24 44.34 1253.12 214.96 227..78 -5.82 227.85 358.54 0.93 BP _MWD+IFR+MS 25 1339.26 27.03 354.02 50.70 1298.54 236.72 250.18 -8.13 250.31 358.14 2.61 BP MWD+IFR+MS 26 1390.75 27.84 353.68 51.49 1344.24 259.66 273.76 -10.67 273.97 357.77 1.60 BP _MWD+IFR+MS 27 1432.30 28.31 354.33 41.55 1380.90 278.57 293.21 -12.71 293.49 357.52 1.35 BP _MWD+IFR+MS 28 1482.49 30.05 354.40 50.19 1424.72 302.18 317.56 -15.11 317.92 357.28 3.47 BP _MWD+IFR+MS 29 1532.75 34.70 355.50 50.26 1467.16 328.07 344.36 -17.46 344.8.1 357.10 9.33 BP _MWD+IFR+MS 30 1583.87 37.35 357.08 51.12 1508.50 356.79 374.36 -19.40 374.86 357.03. 5.49 BP _MWD+IFR+MS SCHLUNIBERGER Survey Report 30-Oct-2006 12:13:10 Page 3 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Disp1 Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (f t) (deg) (deg) (ft) (ft) (ft) {ft) (ft) (ft) (deg) 100f) type (deg) 31 1629.72 37.63 356.84 45.85 1544.88 383.36 402.23 -20.88 402.77 357.03 0.69 BP _MWD+IFR+MS 32 1677.39 38.90 354.72 47.67 1582.31 411.65 431.67 -23.06 432.28 356.94 3.83 BP _MWD+IFR+MS 33 1724.64 39.14 353.92 47.25 1619.02 440.36 461.27 -26.00 462.00 356.77 1.18 BP _MWD+IFR+MS 34 1773.89 36.21 353.32 49.25 1658.00 469.51 491.18 -29.34 492.05 356.58 6.00 BP _MWD+IFR+MS 35 1820.83 36.58 352.82 46.94 1695.78 496.54 518.83 -32.70 519.86 356.39 1.01 BP _MWD+IFR+MS 36 1869.56 39.51 353.37 48.73 1734.15 525.69 548.64 -36.31 549.84 356.21 6.05 BP _MWD+IFR+MS 37 1915.71 41.05 354.46 46.15 1769.36 554.54 578.30 -39.46 579.65 356.10 3.67 BP _MWD+IFR+MS 38 1963.54 41.60 357.20 47.83 1805.28 584.79 609.80 -41.76 611.23 356.08 3.95 BP _MWD+IFR+MS 39 2009.38 45.17 357.48 45.84 1838.59 614.70 641.25 -43.21 642.70 356.14 7.80 BP _MWD+IFR+MS 40 2057.77 50.38 355.13 48.39 1871.10 648.94 676.99 -45.55 678.52 356.15 11.35 BP _MWD+IFR+MS 41 2107.43 51.50 355.61 49.66 1902.39 685.96 715.42 -48.66 717.07 356.11 2.38 BP _MWD+IFR+MS 42 2153.24 51.42 356.15 45.81 1930.94 720,28 751.16 -51.24 752.90 356.10 0.94 BP _MWD+IFR+MS 43 2201.96 53.62 354.82 48.72 1960.58 757.39 789.70 -54.29 791.56 356.07 5.01 BP _MWD+IFR+MS 44 2249.81 55.59 353.58 47.85 1988.30 795.06 828.50 -58.24 $30.54 355.98 4.63 BP _MWD+IFR+MS 45 2300.68 57.32 350.48 50.87 2016.41 836.38 870.48 -64.12 872.83 355.79 6.11 BP _MWD+IFR+MS 46 2346.64 58.23 350.25 45.96 2040.92 874.52 908.81 -70.63 911.55 355.56 2.02 BP _MWD+IFR+MS 47 2397.36 60.66 350.34 50.72 2066.70 917.38 951.86 -77.99 955.05 355.32 4.79 BP _MWD+IFR+MS 48 2444.79 62.99 350.10 47.43 2089.09 958.41 993.06 -85.10 996.70 355.10 4.93 BP _MWD+IFR+MS 49 2492.95 64.73 350.54 48.16 2110.31 1000.83 1035.67 -92.36 1039.78 354.90 3.70 BP _MWD+IFR+MS 50 2541.17 63.60 349.98 48.22 2131.32 1043.41 1078.45 -99.71 1083.05 354.72 2.57 BP MWD+IFR+MS 51 2585.14 63.64 350.61 43.97 2150.86 1082.06 1117.27 -106.35 1122.32 354.56 1.29 BP _MWD+IFR+MS 52 2632.99 63.10 350.41 47.85 2172.31 1124.00 11.59.46 -113.40 1165.00 354.41 1.19 BP _MWD+IFR+MS . 53 2680.09 62.10 349.99 47.10 2193.98 1165.05 1200.67 -120.51 1206.70 354.27 2.27 BP _MWD+IFR+MS 54 2728.62 62.28 350.58 48.53 2216.63 1207.17 1242.98 -127.76 1249.53 354.13 1.14 BP _MWD+IFR+MS 55 2777.74 64.95 353.98 49.12 2238.46 1250.01 1286.57 -133.65 1293.49 354.07 8.25 BP MWD+IFR+MS 56 2825.63 68.11 356.33 47.89 2257.53 1292.22 1330.33 -137.35 1337.40 354.11 7.99 BP _MWD+IFR+M5 57 2874.19 67.85 356.96 48.56 2275.74 1335.16 1375.27 -139.99 1382.38 354.19 1.32 BP _MWD+IFR+MS 58 2921.20 67.47 356.41 47.01 2293.61 1376.63 1418.68 -142.50 1425.82 354.26 1.35 BP _MWD+IFR+MS 59 2969.96 67.89 353.12 48.76 2312.13 1420.07 1463.59 -146.62 1470.92 354.28 6.30 BP _MWD+IFR+MS 60 3021.30 67.14 353.06 51.34 2331.76 1466.11 1510.68 -152.32 1518.34 354.24 1.46 BP MWD+IFR+MS SCHLUMBERGER Survey Report 30-Oct-2006 12:13:10 Page 4 of 5 --- --- 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) ---- ------ --- 61 -------- 3066.73 ------ 66.70 ------- 352.82 ------ 45.43 ------- 2349.57 - -------- 1506.70 -------- 1552.16 -------- -157.46 -------- 1560.13 ------- 354.21 ----- 1.08 - BP ---- ------ _MWD+IFR+MS 62 3112.62 66.41 352.94 45.89 2367.83 1547.61 1593.94 -162.68 1602.22 354.17 0.68 BP _MWD+IFR+MS 63 3161.22 66.07 353.01 48.60 2387.41 1590.80 1638.08 -168.12 1646.69 354.14 0.71 BP _MWD+IFR+MS 64 3210.24 65.26 351.94 49.02 2407.61 1634.27 1682.36 -173.97 1691.33 354.10 2.59 BP _MWD+IFR+MS 65 3258.10 64.48 351.21 47.86 2427.94 1676.58 1725.23 -180.31 1734.62 354.03 2.14 BP _MWD+IFR+MS 66 3303.54 64.40 350.88 45.44 2447.54 1716.70 1765.72 -186.69 1775.56 353.96 0.68 BP _MWD+IFR+MS 67 3353.54 63.84 351.07 50.00 2469.37 1760.73 1810.15 -193.75 1820.49 353.89 1.17 BP _MWD+IFR+MS 68 3400.16 63.67 351.62 46.62 2489.98 1801.61 1851.48 -200.04 1862.26 353.83 1.12 BP _MWD+IFR+MS 69 3450.87 65.25 352.08 50.71 2511.84 1846.24 1896.78 -206.53 1907.99 353.79 3.22 BP _MWD+IFR+MS 70 3497.87 66.00 352.13 47.00 2531.24 1887.97 1939.18 -212.41 1950.78 353.75 1.60 BP MWD+IFR+MS 71 3545.73 65.37 349.39 47.86 2550.95 1930.69 1982.22 -219.41 1994.33 353.68 5.38 BP _MWD+IFR+MS 72 3595.31 65.09 348.32 49.58 2571.72 1975.06 2026.39 -228.11 2039.19 353.58 2.04 BP _MWD+IFR+MS 73 3643.02 64.55 346.82 47.71 2592.02 2017.77 2068.56 -237.40 2082.13 353.45 3.06 BP _MWD+IFR+MS 74 3723.82 63.84 344.16 80.80 2627.20 2090.06 2138.97 -255.62 2154.19 353.19 3.09 BP _MWD+IFR+MS 75 3793.86 63.13 343.97 70.04 2658.47 2152.51 2199.23 -272.83 2216.09 352.93 1.04 BP MWD+IFR+MS 76 3888.96 62.76 346.12 95.10 2701.73 2236.75 2281.05 -294.68 2300.01 352.64 2.05 BP _MWD+IFR+MS 77 3986.68 64.86 346.96 97.72 2744.86 2323.71 2366.33 -315.09 2387.21 352.42 2.28 BP _MWD+IFR+MS 78 4083.57 67.98 347.65 96.89 2783.61 2411.60 2452.94 -334.59 2475.66 352.23 3.29 BP _MWD+IFR+MS 79 4180.04 67.57 346.60 96.47 2820.10 2500.04 2540.00 -354.49 2564.62 352.05 1.09 BP _MWD+IFR+MS 80 4276.39 67.17 343.50 96.35 2857.18 2588.49 2625.91 -377.43 2652.90 351.82 3.00 BP MWD+IFR+MS _ 81 4371.53 64.69 339.66 95.14 2895.99 2675.25 2708.31 -404.84 2738.40 351.50 4.51 BP_M[n1D+IFR+MS 82 4466.74 64.95 337.76 95.21 2936.51 2761.41 2788.59 -436.12 2822.48 351.11 1.83 BP _MWD+IFR+MS 83 4561.89 66.45 333.42 95.15 2975.68 2847.93 2867.52 -471.97 2906.10 350.65 4.45 BP MWD+IFR+MS ^ 84 4657.07 65.49 329.54 95.18 3014.45 2934.05 2943.89 -513.45 2988.33 350.11 3.86 BP MWD+IFR+MS 85 4752.46 64.50 325.24 95.39 3054.78 3018.66 3016.69 -560.01 3068.23 349.48 4.21 BP MWD+IFR+MS 86 4848.42 65.23 320.71 95.96 3095.56 3102.05 3086.02 -612.32 3146.18 348.78 4.34 BP _MWD+IFR+MS 87 4943.75 64.95 317.42 95.33 3135.72 3183.23 3151.32 -668.95 3221.54 348.02 3.14 BP _MWD+IFR+MS 88 5039.11 64.76 318.29 95.36 3176.24 3263.64 3215.33 -726.88 3296.46 347.26 0.85 BP _MWD+IFR+MS 89 5134.37 64.79 318.67 95.26 3216.84 3344.26 3279.85 -784.00 3372.25 346.56 0.36 BP _MWD+IFR+MS 90 5230.33 64.67 318.68 95.96 3257.80 3425.55 3345.02 -841.30 3449.19 345.88 0.13 BP MWD+IFR+M5 SCHLUMBERGER Survey Report 30 -Oct-2006 12:13:10 Page 5 of 5 --- 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) ---- ------ --- 91 -------- 5325.06 ------ 64.49 ------- 319.19 ------ 94.73 -------- 3298.46 -------- 3505.83 ------- 3409..52 --------- -897.51 -------- 3525.67 ------- 345.25 ----- 0.52 - BP ---- ------ _MWD+IFR+MS 92 5420.64 64.38 319.17 95.58 3339.71 3586.85 3474.77 -953.87 3603.32 344.65 0.12 BP _MWD+IFR+MS 93 5516.40 64.50 318.92 95.76 3381.03 3667.97 3540.02 -1010.49 3681.41 344.07 0.27 BP _MWD+IFR+MS 94 5612.13 63.31 318.56 95.73 3423.13 3748.53 3604.64 -1067.19 3759.30 343.51 1.29 BP _MWD+IFR+MS 95 5707.78 62.05 319.82 95.65 3467.03 3828.39 3668.96 -1122.73 3836.89 342.99 1.76 BP _MWD+IFR+MS 96 5804.69 58.19 321.52 96.91 3515.31 3908.05 3733.92 -1175.99 3914.73 342.52 4.26 BP _MWD+IFR+MS 97 5899.91 53.92 322.38 95.22 3568.47 3983.48 3796.10 -1224.68 3988.76 342.12 4.55 BP _MWD+IFR+MS 98 5995.88 50.15 323.62 95.97 3627.50 4056.12 3856.50 -1270.22 4060.30 341.77 4.06 BP _MWD+IFR+MS 99 6091.54 46.56 323.63 95.66 3691.05 4124.98 3914.05 -1312.61 4128.28 341.46 3.75 BP _MWD+IFR+MS 100 6186.08 44.84 324.27 94.54 3757.08 4190.27 3968.75 -1352.43 4192.85 341.18 1.88 BP MWD+IFR+MS 101 6283.37 42.15 324.68 97.29 3827.65 4255.03 4023.24 -1391.34 4257.02 340.92 2.78 BP _MWD+IFR+MS 102 6378.59 38.94 325.98 95.22 3900.00 4315.12 4074.12 -1426.56 4316.66 340.70 3.49 BP _MWD+IFR+MS 103 6474.19 35.59 328.51 95.60 3976.08 4371.72 4122.76 -1457.91 4372.95 340.53 3.85 BP _MWD+IFR+MS 104 6569.91 32.01 330.39 95.72 4055.61 4424.19 4168,58 -1485.00 4425.19 340.39 3.90 BP _MWD+IFR+MS 105 6665.50 28.02 330.78 95.59 4138.36 4471.46 4210.22 -1508.49 4472.31 340.29 4.18 BP MWD+IFR+MS 106 6761.34 24.44 329.15 95.84 4224.32 4513.27 4246.90 -1529.66. 4513.98 340.19 3.81 BP _MWD+IFR+MS 107 6856.36 20.45 327.87 95.02 4312.12 4548.91 4277.85 -1548.57 4549.51 340..10 4.23 BP _MWD+IFR+MS 108 6952.15 18.48 329.18 95.79 4402.43 4580.28 4305.06 -1565.25 4580.78 340.02 2.11 BP _MWD+IFR+MS 109 7047.45 18.64 330.16 95.30 4492.78 4610.20 4331.24 -1580.57 4610.62 339.95 0.37 BP _MWD+IFR+M5 110 .7143.48 18.63 330.59 96.03 4583.77 4640.52 4357.92 -1595.74 4640.88 339.89 0.14 BP MWD+IFR+MS 111 7239.70 18.55 330.43 96.22 4674.97 4670.84 4384.62 -1610.84 4671.15 339.83 0.10 BP MWD+IFR+M5 112 7334.36 18.35 330.12 94.66 4764.77 4700.44 4410.63 -1625.69 4700.70 339.77 0.24 BP _ _MWD+IFR+MS 113 7379.73 18.29 330.39 45.37 4807.84 4714.53 4423.01 -1632.77 4714.76 339.74 0.23 BP _MWD+IFR+MS 114 7449.00 18.29 330.39 69.27 4873.61 4736.01 4441.91 -1643.51 4736.21 339.70 0.00 Projected to TD [(c)2006 IDEAL ID10_2C_01] ~~ -I~y • • STATE OF ALASKA DEC 4 6 2006 ALASKA O~AND GAS CONSERVATION COMMI~ ~a~ka Qil & Gas Cons. Commission WELL COMPLETION OR RECOMPLETION REPORT AND LOG Anchorage 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG zoAa,czs.,os zoAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 11/6/2006 12. Permit to Drill Number 205-134 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/29/2005 13. API Number 50-029-23275-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 10/30/2006 14. Well Name and Number: PBU V-214i 4816 FSL, 1862 FEL, SEC. 11, T11 N, R11 E, UM Top of Productive Horizon: 3773' FSL, 3381' FEL, SEC. 02, T11N, R11E, UM 8. KB Elevation (ft): 81.6' 15. Field /Pool(s): Prudhoe Bay Fietd l Orion Total Depth: 3978' FSL, 3500' FEL, SEC. 02, T11 N, R11 E, UM 9. Plug Back Depth (MD+TVD) 7356 + 4785 Ft Schrader Bluff 4b. Location of Welt (State Base Plane Coordinates): Surface: x- 590439 y- 5970062 Zone- ASP4 10. Total Depth (MD+TVD) 7449 + 4874 Ft 16. Property Designation: ADL 028240 TPI: x- 588865 y- 5974280 Zone- ASP4 Total Depth: x- 588743 y- 5974483 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD / GR, MWD / GR /RES /DEN /NEU /PWD; MWD / GR /RES /DEN /NEU /PWD, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 215.5# A-53 Surface 102' Surface 102' 42" 260 sx Arctic Se A rox. 9-5/ " 40# L-80 27' 3757' 27' 2642' 12-114" 482 sx AS Lite 682 sx Class'G' 7" 2 L- 0 2 ' 744 ' 2 ' 48 -3/4" 105 sx Li Cret 2 9 sx I s ' ' 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", 9.3#, L-80 7206' 6675', 6853', 6948', MD TVD MD TVD 7039' & 7103' 6702' - 6712' 4171' - 4180' 6900' - 6940' 4353' - 4391' 25, ACID, FRACTURE, CEMENT SDUEEZE, ETC. 6966' - 6994' 4416' -4442' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 7010' - 7028' 4457' - 4474' 7068' 7082' 4512' 4525' Freeze Protect with 95 Bbls of Diesel - - 7120' - 7170' 4562' - 4609' 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 PreSSUfe CALCULATED 24-HOUR RATE C!IL-BBL GAS-McF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none'. C0~ ~+-t r T ~ •;i . f None f ~ i ~~ 6~r~. ~~s, ~ ~ 2~~6 L``~, ,~`~0 I Form 10-407 Revised 12/2003 ,, ~ ~ ' "`-~>~jNTINUED ON REVERSE SIDE ,~_ ~ ~,. ' ~~ ~ `i _.._ 28. ~ GEOLOGIC MARKERS 29. TION TESTS Include and briefly su arize test results. List intervals tested, Nave MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 4263' 2852' None Ugnu MA 6474' 3976' Ugnu M61 6515' 4010' Ugnu M62 6600' 4081' Ugnu MC 6665' 4138' Schrader Bluff NA 6734' 4200' Schrader Bluff NB 6759' 4222' Schrader Bluff NC 6793' 4253' Schrader Bluff NE 6801' 4261' Schrader Bluff NF 6858' 4314' Schrader Bluff OA 6900' 4353' Schrader Bluff OBa 6966' 4416' Schrader Bluff OBb 7008' 4455' Schrader Bluff OBc 7068' 4512' Schrader Bluff OBd 7122' 4563' Schrader Bluff OBe 7183' 4621' Schrader Bluff OBf 7231' 4667' Base Schrader Bluff 7281' 4714' 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. l Z~ ~~/v ~p Signed Terrie Hubble Title Technical Assistant Date PBU V-2141 205-134 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A r val No. Drilling Engineer: Matt Martyn, 584-4101 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 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. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Page ~ of 1 Leak-Off Test Summary Legal Name: V-214 Common Name: V-214 Test Date I Test Type _ ~ Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) 'i EMW _- T _ _ _ L - - --~-- --- ~ ~ - -- -- - T - --- -- ~ -- - _ -- --- 11/9/2005 LOT 3,795.0 (ft) 2,634.0 (ft) 8.90 (ppg) 480 (psi) 1,698 (psi) 12.41 (ppg) 10/28/2006 LOT 3,761.0 (ft) 2,641.0 (ft) 8.80 (ppg) 429 (psi) 1,636 (psi) 11.93 (ppg) Printed: 11/13/2006 10:47:44 AM BP EXPLORATi~JN Operations Summary Report Paye 1 of 7 Legal Well Name: V-214 Common Well Name: V-214 Spud Date: 10/29/2005 Event Name: REENTER+COMPLETE Start: 10/26/2006 End: 11 /612006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/6/2006 Rig Name: NABOBS 9ES Rig Number: Date i From - To Hours ~ Task~Code NPT ~ Phase Description of Operations 10/26/2006 07:00 - 13:30 6.50 RIGD P PRE Prepare rig for derrick do move, bridle up, moved pit complex out, install jeep, PJSM, lower derrick, secured same, trouble shoot moving system blown fuse, move rig off well, set hydrill on stand 13:30 - 15:30 2.00 MOB P PRE Nabors 9ES Turnkey rig move t/ L-04i to V-2141, level pad around well, set mats, place wellhead equipment behind cellar 15:30 - 22:30 7.00 MOB PRE Spot rig over well, level rig, remove jeep f/ pits, spot pits 22:30 - 00:00 1.50 RIGU P PRE RU interconnect, spot cuttings tank, PJSM, raise and pin derrick 10!2712006 00:00 - 02:00 2.00 RIGU P PRE Bridle Down, raise cattle shoot, MU kelly hose and hydraulic loop, RU floor 02:00 - 03:30 1.50 RIGU P PRE ACCEPT RIG at 02:00 hrs on 10127/2006, RU secondary annulus valve, hardline, load pipeshed with 4"DP, Take on 120 degree SW in pits 03:30 - 04:00 0.50 W HSUR P DECOMP Pre Spud Mtg w/ rig crew, review check list 04:00 - 05:30 1.50 WHSUR P DECOMP Test lines, test BPV f/ below to 1000 psi for 30 minutes, record and chart, RD lines, berm cellar area 05:30 - 06:30 1.00 WHSUR P DECOMP RU Lubricator, Pull BPV, RD DSM 06:30 - 08:00 1.50 W HSUR P DECOMP Displace diesel from well w/ 229 bbls of 120 degree seawater, first 50 bbls of SW treated w/ safesurf O soap, 51 spm, 127gpm, icp 80psi, fcp 160psi, monitor well for 15 min, ok, blow do lines, rd same. Recycle 200 bbls of diesel at GC 2 08:00 - 08:30 0.50 WHSUR P DECOMP Install TWC, test f/ below to 1000psi 08:30 - 10:30 2.00 WHSUR P DECOMP ND tree 10:30 - 12:30 2.00 BOPSU P DECOMP NU BOP Stack, install riser, mouse hole and MU turnbuckles 12:30 - 13:00 0.50 BOPSU P DECOMP RU test equipment for BOP's 13:00 - 16:30 3.50 BOPSU P DECOMP PJSM, test BOP's to 250psi low and 4000psi high w/ 3 1/2" and 4" test Jts, Chuck Schieve w/ AOGCC waived witnessing test, WSL B Buzby and Tool Pusher K Cozby witnessed test 16:30 - 17:00 0.50 BOPSU P DECOMP Blow Dn and RD test equipment 17:00 - 18:00 1.00 WHSUR P DECOMP RU Lubricator, Pull TWC, Rd Lubricator 18:00 - 19:00 1.00 PULL P DECOMP RU 3 1/2" tbg handling equipment, BOLDS 19:00 - 23:00 4.00 PULL P DECOMP POH LD 85 joints of 3 1/2" 9.3 L-80 NSCT tbg 23:00 - 00:00 1.00 PULL P DECOMP RD tbg handling equipment, cleared rig floor 10/28/2006 00:00 - 01:30 1.50 BOPSU P DECOMP Install test plug, test lower VBR's to 250 - 4000 psi w/ 3 1/2" and 4" test jts, retr test plug 01:30 - 02:00 0.50 BOPSU P PROD1 Install wear bushing 02:00 - 10:30 8.50 DRILL P PROD1 RIH, PU and rabbit 102 Jts 4" DP, POH std bk 34 std, RIH, PU and rabbit 57 jts 4" DP, POH, std bk 19 stds 10:30 - 12:00 1.50 DRILL P PROD1 PJSM, Cut and Slip 72' of drill line, service top drive 12:00 - 14:00 2.00 DRILL N RREP PROD1 C/0 leaking hydraulic service loop on TD 14:00 - 17:00 3.00 DRILL P PROD1 PJSM, PU, RIH w/ Drlg BHA #1 w/ RR 8 3/4" Hycalog PDC bit, 1.15 deg PDM, MWD -GR-Res-Den-Neu-PWD, DC's ,HWT, Jar, HWT, shallow hole test MWD tools, OK 17:00 - 18:00 1.00 DRILL P PROD1 PU, RIH w/ 51 jts of 4", ghost reamer was installed after PU 27 joints 18:00 - 18:30 0.50 DRILL P PROD1 RIH w/ stds of 4" DP 18:30 - 19:00 0.50 DRILL P PROD1 Wash dn, tagged cmt stringer at 3475', RIH tagged hard cmt at 3560', up wt 96k, do wt 62k 19:00 - 21:30 2.50 DRILL P PROD1 Drilled cmt f/ 3560' - 3775', drilled new hole to 3825' w/ viscosified 2ppb Biozan fresh water at 240spm, 586gpm, 965psi off btm, 1310psi on btm, 65rpm, 4.1 TO off btm, 5.8T0 on btm, up wt 100k, do wt 60k, rot wt 80k, returns had slot of Printed: 11/13/2006 10:47:49 AM BP EXPLORATION Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date ~ From - To Hours ~ Task Code j NPT 10/28/2006 _ _ 19:00 - 21:30 ~ ~_ ~ 2.50 _- DRILL P 21:30 - 22:30 1.00 DRILL P 22:30 - 23:30 1.00 DRILL P 23:30 - 00:00 0.50 DRILL P 10/29/2006 00:00 - 00:30 0.50 DRILL P 00:30 - 01:00 0.50 DRILL P 01:00 - 01:30 0.50 DRILL P 01:30 - 02:30 { 1.001 DRILL 1 N 02:30 - 00:00 I 21.501 DRILL I P 10/30/2006 100:00 - 02:15 I 2.251 DRILL I P 02:15 - 02:30 0.25 DRILL P 02:30 - 03:45 1.25 DRILL P 03:45 - 04:15 0.50 DRILL P 04:15 - 08:00 3.75 DRILL P 08:00 - 08:30 0.50 DRILL P 08:30 - 17:30 9.00 DRILL P 17:30 - 18:00 0.50 DRILL P 18:00 - 20:00 2.00 DRILL P 20:00 - 22:00 2.00 DRILL P 22:00 - 22:30 0.50 DRILL P 22:30 - 23:30 1.00 BOPSU P 23:30 - 00:00 0.50 BOPSU P 10!31/2006 00:00 - 01:00 1.00 BOPSU P Start: 10/26/2006 Rig Release: 11/6/2006 Rig Number: Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Page 2 of 7 Spud Date: 10/29/2005 End: 11 /6/2006 Description of Operations cement and metal shavings Circ hole clean w/ two btm's up Pumped 50bb1 FW spacer, Displaced well to 8.8ppg LSND mud w/ 180spm, 441gpm, 748psi, 60rpm, 5.1 TO, 80rpm POH to 3730', Performed LOT w/ 8.8ppg MW to 428psi = 11.9ppg EMW Established SPR's, SPP's, and benchmark ECD Madd Pass open hole Dir Drill f/ 3825' to 3862', MW D had noise interference from pumps, poor signal POH inside 9 518" csg, troubleshoot pulsation dampeners, both were over charged w/ 1800 and 2000 psi, recharged each to 900 psi Note: Time was rolled back 1 hour for Daylight Savings Time Change at 02:00 hours. PROD1 Dir Drill F/ 3862' TO 6688' w/ 1.15 motor, survey w/ Mwd-Gr-Res-Den-Neu-PWD at 240spm, 588gpm, 2835psi, 100rpm, 9-10k ft-Ibs torque, 165k upwt, 75k do wt, 105k rot wt, calc ECD 9.87ppg, actual ECD 10.36ppg, ast 7.94 hrs, art 3.21 hrs, backream each std at drilling rate up and 75 percent down, pumped 30 and 40 bbl weighted hi-vis sweeps at 5055' and 5943' w/ 25 and 5 percent increase of cuttings in returns PROD1 Dir Drilf f/ 6688' - 6735', 240 spm, 588gpm, 2910psi, 100rpm, 10 - 15k wob, 10000 - 12000ft-Ibs of torque, ROP 300fph, added lubricant total of 2percent Lotorq to mud to control torque and improve sliding. PROD1 Madd Pass f/ 6688' to 6735' PROD1 Dir Drill f( 6735' - 6913', 240 spm, 588gpm, 2910psi, 100rpm, 10 - 15k wob, 8100ft-Ibs of torque, ROP 250-300fph PROD1 Madd Pass f/ 6830' to 6913' PROD1 Dir Drill f/ 6913' - 7449', 240 spm, 588gpm, 3250psi, 100rpm, up wt 155k, do wt 85k, rot wt 107k, 15k wob, 8900ft-Ibs of torque, ROP 250-300fph, backreamed each std up at drilling rate and 75percent of drilling rate dn, cal ECD 9.89ppg, actual ECD 10.31 ppg, ast 3.08 hrs, art 2.20hrs PROD1 Survey and SPR at TD, 7449', pumped 40bb1 11.1 ppg weighted sweep PROD1 Backream OOH f/ 7449' - 3761' at 240spm, 2800psi, 588gpm, 100 rpm, 108 rot wt, 7.8 - 6.6k ft-Ibs, packed off at 4300' - 4151', worked thru tight hole, circ clean, big clay balls in returns PRODi Circ hole clean wi 30bb1 1 i.i ppg weighted sweep at 240spm, 2175psi, 588gpm, 92rpm, 4.2k tq, 71 rot wt, returns w/ 25 percent increase in cuttings PRODi Monitor well, pumped dry job, POH to BHA #1 PROD1 Monitor well, PJSM handling BHA, POH, LD Jar w/ Hwt, Std of DC's, MWD tools, motor and bit PROD1 Clear and clean rig floor PRODi Pull wear bushing, flush stack, install test plug PRODi C/O top rams PRODi C/O top rams to 7", while RU long bails, elevators and Franks fill-up tool Printed: 11/13/2006 10:47:49 AM BP EXPLORATION Page 3 of 7 Operations Summary Report Legal Well Name: V-214 Common W el{ Name: V-214 Spud Date: 10/29/2005 Event Nam e: REENTE R+COM PLET E Start : 10/26/2006 End: 11/6/2006 Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 11/6/2006 Rig Name: NABOB S 9ES Rig Number: Date From - To ~' Hours ~ 7ask Code i NPT ~ Phase Description of Operations 10/31/2006 01:00 - 01:30 0.50 BOPSU P PROD1 RU test equipment, Test 7" rams to 250 / 4,000 psi - 5 minutes - OK. 01:30 - 02:30 1.00 BOPSU P PROD1 Attempt to pull test plug, no go, drained stack, checked LDS, OK, tum test JT i/4 turn to right then back to left a 1/4 turn, pulled test joint, inspected test plug, OK 02:30 - 03:00 0.50 CASE P RUNPRD Make dummy run with 7" casing hanger 03:00 - 04:00 1.00 CASE P RUNPRD RU casing handling tools and power tongs 04:00 - 04:30 0.50 CASE P RUNPRD PJSM w/ rig and csg hands, discussed handling and csg running procedure 04:30 - 08:30 4.00 CASE P RUNPRD Pick up and make up 7" shoe track with Baker-Lok. Fill pipe and check floats - OK. Continue running in hole with a total of 53 jts of 7" 26#, L-80, BTC-M casing to 2204'. 80 fpm running speed without any mud losses. Fill every joint and top off every 15 joints with casing fill-up tool. MU csg to base of triangle, avg MU torque 8,400 fUlbs using Best-O-Life 2000 thread dope. Installing 2 centralizers on shoe joint next to float shoe, 2 centralizers on each joint from 4 thru 13, floating between stop ring in mid joint. 1 centralizer on each joint full floating from 14 thru 53, for total of 62 centralizers and 10 stop rings.Marker Joints wJ RA tags were placed in csg string, Recording Up and Dn Wts every 10 stds 08:30 - 11:30 3.00 CASE P RUNPRD Rig up Torque turn equipment for TC-11 casing, PU, RIH with 7" X-O pup jt BTC-M pin X TCII box followed by 7" 26#, L-80 TC11 casing from 2204' to 3,753'. 1 centralizer on each joint full floating from 1 thru 12, for a grand total of 74 centralizers. 80 fpm running speed without any mud losses, Fill every joint and top off every 15 joints with casing fill-up tool. Torque tum connections to 10,100 fUlbs using Jet Lube dope. Recording Up and Dn Wts every 10 stds 11:30 - 12:00 0.50 CASE P RUNPRD Break circulation, stage pumps up to 6 bpm, 451psi and circulate 1 1/2 annulus volume. No increase in cuttings throughout circulation. Lost 8bbls. PU - 105k, SO - 75k. 12:00 - 12:30 0.50 CASE P RUNPRD PU, RIH w/ 7" 26#, L-80, TC11 casing, sat down at 4021' w/ down drag of 23k, S/O wt 58k 12:30 - 16:00 3.50 CASE P RUNPRD Washed and worked thru intermittent tight spots f/ 4021' to 4388', circulation with casing- fill-up tool at 3 - 4bpm 688 - 770psi for 1 bottoms up. Slight increase in cuttings with bottoms up. Loss Rate at 36bph while circ. PU - 108k w/ an occasional overpult of 30k, SO - 58k w/ do drag of 23k. Note: tight spots were in direct correlation to coal stringers on MWD log. 16:00 - 17:00 1.00 CASE P RUNPRD Circ hole clean w/ casing- fill-up tool, stage pumps up to 6 bpm, 700psi. No increase in cuttings with bottoms up. loss rate at 10bph. PU - 113k, SO - 58k. Able to reciprocate pipe in 15' strokes. 17:00 - 00:00 7.00 CASE P RUNPRD Attempt to RIH without the pumps, casing stacking out, Brk Circ, Wash and work thru intermittent tight spots f/ 4388' to 6163' at 4bpm, 635psi, Up Wt 165k, Dn Wt 65k, Loss rate 4bph. Total losses for day was 98bbls, Note: tight spots were in direct correlation to coal stringers on MW D log. 11/1/2006 00:00 - 03:30 3.50 CASE P RUNPRD PU, RIH w/ 7" csg, Wash down f/ 6163' at 4bpm, 635psi, Up Wt 195k, Dn Wt 75k, Loss rate at a minimum. Ran Total of 53 jts 7" 26# L-80, BTC-M and 129 Jts 7" 26# L-80 TC11 casing. Printed: 11/13/2006 10:47:49 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 11/1/2006 00:00 - 03:30 03:30 - 04:00 04:00 - 04:30 04:30 - 07:30 07:30 - 10:00 10:00 - 10:30 10:30 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 14:30 14:30 - 15:00 15:00 - 17:30 V-214 V-214 REENTER+COMPLETE NABOBS ALAS KA DRILLING NABOBS 9ES Hours Task I Code I NPT 3.50 -- CASE _ P __ 0.50 CASE P 0.50 CEMT P 3.00 CEMT P 2.501 CEMT I P 0.50 CEMT P 1.50 CEMT P 1.00 WHSUR~P 1.00 BOPSU P 0.50 BOPSU P 0.50 PERFOB~ P 2.50 PERFO P 17:30 - 22:00 I 4.50 I PERFOBI P 22:00 •00:00 I 2.001 PERFOBI P Start: 10/26/2006 Rig Release: 11/6/2006 Rig Number: Phase Page 4 of 7 Spud Date: 10/29/2005 End: 11 /6/2006 Description of Operations RUNPRD Up Wt 220K, Dn Wt 85K RUNPRD MU and Land FMC fluted Mandrel Hanger RUNPRD RD Franks fill-up tool, RU Cmt Hd and lines RUNPRD Circ and condition mud at 3 - 5bpm, 565 - 770psi, Up Wt 220k, Dn Wt 85k, Reciprocate pipe 15' strokes. RUNPRD Switch to Dowell. Pump 5 bbls water, test lines to 4,000 psi - OK. Pump 30 bbls CW100, 50bbls MudPush 10.5ppg at 5bpm, 700psi. Shut down, drop bottom plug, pump 46 bbls 12.0 ppg Lite Crete lead cement at 2 - 5bpm, 68 - 500psi followed by 54bbls 15.8 ppg class "G" tail cement at 2 - 5bpm, 315 - 120psi. Shut down and wash out lines to rig floor. Switch to rig pumps, kick out top plug with 50bbls 9.Oppg Perf Pill followed by 231 bbls of 9.Oppg brine, ICP 100psi, FCP 1830psi. Full returns throughout cmt job and reciprocated csg until the last 30 bbls, landed csg hgr in place. RUNPRD Bumped plug to 4000psi, held for 30 min, released pressure, checked floats, holding. CIP ~ 10:00 hr on 11/1106. RUNPRD Rig down cementing head and casing running equipment. Lay down landing joint. Clear and clean off rig floor. RUNPRD Install 7" x 9 5/8" pack-off. Test same to 5,000 psi - OK. RUNPRD Install test plug, Change top rams from 7" to 3.5" x 6" VBR's. RUNPRD Rig up to test rams. Test VBR's with 3.5" test joint to 250 psi low / 4,000 psi high - 5 minutes each, Pull test plug OTHCMP Pick up pert gun tools to rig floor and rig up to run pert guns. OTHCMP PJSM. PU, RIH w/ 4.5" 5 SPF 4505PJ pert gun assembly with bumper sub and impulse MWD and 8 stands HWDP to 1,314'. OTHCMP Shallow hole test MWD. 250 gpm, 455 psi, RIH with pert guns on 4" drill pipe from 1,314' to 7166'. Perform LOT on 7" x 9 5/8" annulus. 3,757' MD, 2,641' TVD, 9.2ppg MW, 390 psi leak-off pressure, 12.02 ppg EMW. **Injected 125 bbls of 9.2 ppg mud down 7" annulus @ 3 bpm, 1025 - 975psi followed by 80bbls dead crude C~ 1.75bpm, ICP 1450psi, FCP 650psi. Injection and freeze protecting done out of critical path** OTHCMP Log Up at 300fph f/ 6520' -6400' (MW D depth) to verify top RA tag at 6459', 250 gpm, 840 psi, Ran repeat pass to confirm RA tag and GR points, PU - 170k, SO - 45k. 11/2/2006 (00:00 - 01:00 I 1.001 PERFOBI P I I OTHCMP 01:00 - 01:30 0.50 PERFO P OTHCMP 01:30 - 02:30 1.00 PERFO P OTHCMP 02:30 - 06:00 3.50 PERFO P OTHCMP 06:00 - 06:30 0.50 PERFO P OTHCMP 06:30 - 09:30 3.00 PERFO P OTHCMP 09:30 - 11:30 I 2.001 EVAL I P I I OTHCMP Position guns on depth for firing with bottom pert ~ 7,170' and top pert ~ 6,702'. Circ w/ 9.0 ppg brine, 250 gpm, 730 psi, Held PJSM on firing guns while circulating. Work through fire sequence per Schiumberger pert rep, good surface indication of guns firing, Initially lost 7bbls when guns fired POH w/ 6 stands to 6,668", above perfs. No overpull. Circulate bottoms up ~ 270 gpm, 890 psi. Lost 4bbls to hole POH to pert guns assy, no losses. PJSM w/ all involved personnel on RU and handling fired guns RU handling equipment, POH, LD perf guns, all shots fired, RD pert gun equipment, cleared and cleaned rig floor PJSM w/ all involved personnel on RU and operational proceedures, PU a-line equipment to rig floor, RU a-line Printed: 11/13/2006 10:47:49 AM BP EXPLORATION Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Event Name: REENTER+COMPLETE Start: 10/26/2006 Contractor Name: NABOBS ALASKA DRILLING l Rig Release: 11!6!2006 Rig Name: NABOBS 9ES Rig Number: Date I From - To I Hours I Task I Code ! NPT I Phase 11/2/2006 09:30 - 11:30 2.00 EVAL P OTHCMP 11:30 - 12:30 1.00 EVAL P OTHCMP 12:30 - 13:00 0.50 EVAL P OTHCMP 13:00 - 17:30 4.50 EVAL P OTHCMP 17:30 - 20:00 2.50 PERFO P OTHCMP 20:00 - 21:30 1.50 EVAL P OTHCMP 21:30 - 22:30 1.00 EVAL P OTHCMP 22:30 - 00:00 1.50 EVAL P OTHCMP 11/3/2006 00:00 - 03:00 3.00 EVAL P OTHCMP 03:00 - 04:00 1.00 EVAL N DFAL OTHCMP 04:00 - 04:30 0.50 EVAL N DFAL OTHCMP 04:30 - 07:00 2.50 EVAL N DFAL OTHCMP 07:00 - 09:00 2.00 EVAL P OTHCMP 09:00 - 10:00 1.00 PERFO P OTHCMP 10:00 - 10:30 0.50 PERFO P OTHCMP 10:30 - 11:30 1.00 N OTHCMP 11:30 - 13:00 1.50 PERFO N OTHCMP 13:00 - 13:30 0.50 PERFO N OTHCMP 13:30 - 15:00 1.50 PERFO P OTHCMP 15:00-15:30 0.50 CONDH~P OTHCMP 15:30 - 19:30 4.00 CONDH P OTHCMP 19:30 - 21:00 1.50 CONDH P OTHCMP 21:00 - 00:00 3.00 CONDH P OTHCMP 11/4/2006 00:00 - 03:30 3.50 CONDH P OTHCMP 03:30 - 04:30 1.00 CONDH P OTHCMP 04:30 - 06:00 1.50 CONDH P OTHCMP 06:00 - 10:30 I 4.501 RUNCOMP I I RUNCMP 10:30 - 11:00 I 0.501 RUNCOMP I I RUNCMP 11:00 - 00:00 I 13.001 RUNCON'~ I I RUNCMP Page 5 of 7 Spud Date: 10/29/2005 End: 11 /6/2006 Description of Operations equipment, hang sheaves RIH w/ 6.05" OD GR/JB to 7300', POH, LD GR/JB, no debris. PU, MU USIT tools RIH w/ USIT, log up f/ 7300' to 3000', POH, LD USIT tools PJSM w/ all involved hands, PU, RIH w/ 1' 4.5" pert gun, 6spf, run strip log, confirmed depth w/ repeat log, position and fire gun at 7011 - 7012', POH, LD gun, all shots fired. No losses to hole MU 6.05" OD GR/JB, RIH to 7300', POH, LD GR/JB, no debris PJSM w/ all involved hands on handling and running MDT tools RIH w! MDT for fluid sample f/ OBb sand RIH w/ SLB MDT for fluid sample f/ OBb sand, Tie-in to RA tag at 7150', PU, position MDT across perfs at 7011 - 7012', inflate pkrs to 1000 psi, opening interval valve would cause seal on inflatable pkrs to fail POH to MDT Change out inflate and interval valves RIH w/ SLB MDT, tie-in, position MDT at 7011' Second attempt to obtain MDT fluid sample was unsuccesful, POH, LD tools, MDT tool plugged with metal and pert debris, Consult with Anch Office, Decision made to abandon further attempts to obtain MDT sample PJSM, rehead a-line, MU 4.5 " Perf Guns RIH, Position guns at 7010' to 7028', guns did not fire, POOH, LD guns Troubleshoot problem, found loose wire causing electrical short in GR tool RIH, Position guns at 7010' to 7028', guns fired POH, LD guns, all shots fired, RD eline, cleared and cleaned off rig floor PU clean out assy, bit, csg scrapper, 2 boot baskets RIH, tagged up on float collar at 7355' Displaced well with new 9.Oppg NaCI brine at 6 bpm, 700 psi, UWT 175k, DWT 75k, rotate at 100rpm reciprocating pipe POH, LD 4" DP to 4703' POH, LD HWT Cut and slip drill line, service TD Lay out bit, 7" casing scraper and 2 boot baskets. Recovered app. 10 ounces of sand and small metal debris in boot baskets. Lay down all excess vendors equipment and prepare floor for tubing run. Pull wear ring, RU handling tools, torque turn equipment and I-wire spool, Make dummy run with tbg hgr. PJSM w/ Baker, SLB, Halliburton and rig crew, discussed safety and operational procedures for PU and running 3 1/2' completion string PU, RIH with 3.5" completion string per running detail, Baker-Lok all connections below 1st packer. Torque turn connections to 2,300 Wlbs using Jet Lube Seal Guard lubricant. RIH w! 104 jts and completion accessories. Note: Ran Halliburton Pheonix Sensor below Halliburton AHR retrievable packer w/ i-wire, maintaining 1500psi while RIH, Printed: 11/13/2006 10:47:49 AM BP EXPLORATION Page 6 of 7 Operations Summary Report Legal Well Name: V-214 Common W ell Name: V-214 Spud Date: 10/29/2005 Event Nam e: REENTE R+COM PLET E Start : 10/26/2006 End: 11/6/2006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 11/6/2006 Rig Name: NABOB S 9ES Rig Number: Date I From - To Hours l Task Code' NPT Phase ~, Description of Operations 11/4/2006 11:00 - 00:00 13.00 BUNCO RUNCMP Installed Clamps below AHR Pkr and PS, above AHR Pkr on the next 9 jts, then one clamp on every third joint 11/5/2006 00:00 - 06:30 6.50 BUNCO RUNCMP PU, RIH with 3.5" 9.2# L-80 TCII tubing. Torque turn connections to 2,300 fUlbs using Jet Lube Seal Guard lubricant. RIH a total of 210 jts Note: Ran Halliburton Pheonix Sensor below Halliburton AHR retrievable packer w/ i-wire, maintaining 1500psi while RIH, Installed 3 half clamps below AHR Pkr and PS, above AHR Pkr, pup jt and GLM # 9, then full clamps on the next 9 jts, then one full clamp on every third joint for a total of 78 full clamps and 3 half clamps 06:30 - 08:00 1.50 BUNCO RUNCMP Pick up and make up tubing hanger and landing joint, terminate i-wire w/final line pressure of 1944psi, Ran total of 210 jts 3.5" 9.2# L-80 TCII tubing. Land tubing on depth ~ 7205'. PU - 100k, SO - 68k (with 35k blocks included). Run in tubing hanger lockdown screws, drop roller ball/rod assembly down tubing. Lay down landing joint, 1-5/16" ball with 1.375" fishing neck 08:00 - 09:00 1.00 BUNCO P RUNCMP Set packers. and pressured up to 4,250 psi. Hold pressure for 30 minutes for tubing test - OK. Bleed tubing pressure to 0 psi, then pressure up on tubing annulus to 3500 psi for casing test. 30 min - OK. 09:00 - 09:30 0.50 BUNCO RUNCMP Install 2-way check valve in tubing hanger and test same from above to 1000 psi - 5 minutes - OK. 09:30 - 12:00 2.50 BOPSU P RUNCMP LD mouse hole, pull riser, ND BOP's and secure in cellar. 12:00 - 14:00 2.00 WHSUR P WHDTRE Prep wellhead and tubing hanger. NU tree adapter, connect i-wire, test seals to 5,000 psi - OK. 14:00 - 17:00 3.00 WHSUR P WHDTRE Remove master valve f/ Leo Actuator, Orient to off driller's side, install Leo Actuator, position at 10:30, install wing and swab valves, NU and test tree to 5,000 psi - OK. 17:00 - 17:30 0.50 WHSUR P WHDTRE PJSM w/ DSM, RU lubricator, pull TWC, install VR plug in IA valve on off driller's side 17:30 - 20:30 3.00 BUNCO RUNCMP PJSM w/ SLB slickline and rig crew, RU sheaves, lubricator and packing head, MU tool string 20:30 - 22:00 1.50 BUNCO RUNCMP RIH, set catcher sub at 6652', POH 22:00 - 23:30 1.50 BUNCO RUNCMP RIH, attempt to retrieve DV f/ GLM at 6614', POH, 1 5/8" JDS pulling tool was sheared, no recovery 23:30 - 00:00 0.50 BUNCO RUNCMP RIH wl second attempt to retrieve DV 11/6/2006 00:00 - 01:30 1.50 BUNCO DFAL RUNCMP RIH to 4854', tool setting down, POH, kickover tool was sheared, second attempt to retrieve DV failed 01:30 - 03:00 1.50 BUNCO DFAL RUNCMP Third attempt, RIH to 6614" w/ 1 5/8" JDS pulling tool pin with steel stock and added roller stem to tool string, retrieve DV, POH, LD DV 03:00 - 04:30 1.50 BUNCO RUNCMP RIH w/ 3" GS, retrieved slip stop catcher sub set at 6652', POH, RD wireline, clear off rig floor 04:30 - 05:30 1.00 WHSUR P RUNCMP Rig up to reverse circulate. Pressure test lines to 2,500 psi. 05:30 - 08:00 2.50 WHSUR P RUNCMP Rev Circ 104bb1s of 9.Oppg NaCI w/ corrosion inhibitor followed by 95 bbls of diesel for Freeze protect, u-tube back to tbg and let equalize 08:00 - 11:00 3.00 WHSUR P RUNCMP RU DSM lubricator, install and test BPV f/ below, BPV would not hold pressure, Changed out BPV, tested f! below to 1000psi, OK, RD lubricator, Lubricate VR plug in IA valve, Printed: 11/13/2006 10:47:49 AM Printed: 11/13/2006 10:47:49 AM ~'±I t r,~ .~ ,v V-214 Survey Report Sehlumberger Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: V•Pad / Plan V Slot (N-E) Well: V-214 Borehole: V-214 UWI/API#: 500292327500 Survey Name /Date: V-214 /October 30, 2006 Tort /AHD / DDI / ERD ratio: 198.618° / 4889.94 ft / 6.172 / 1.003 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaUlong: N 70.32794830, W 149.26653198 Location Grid NIE Y/X: N 5970061.760 ftUS, E 590439.130 ftUS Grid Convergence Angle: +0.69066335° Grid Scale Factor: 0.99990929 Vertical Section Azimuth: 339.170° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 81.60 ft relative to MSL Sea Bed /Ground Level Elevation: 53.10 ft relative to MSL Magnetic Declination: 23.903° Total Field Strength: 57627.251 nT Magnetic Dip: 80.880° Declination Date: October 29, 2006 Magnetic Declination Model: BGGM 2006 North Reference: True North Total Corr Mag North -> True North: +23.903° • Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Nole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de tt ft ft ft ft ft tt de 100 tt ftUS ftUS R I t 0.00 0.00 0.00 -81.60 O.OU O.UU U.UU 0.00 O.W O.OU O.W 59/UU61.76 590439.13 N 70.3L/94830 W 149.26653198 2.80 0.00 0.00 -78.80 2.80 0.00 0.00 0.00 0.00 0.00 0.00 5970061.76 590439.13 N 70.32794830 W 149.26653198 GYD CT DMS 102.80 0.19 285.15 21.20 102.80 0.10 0.17 0.17 0.04 -0.16 0.19 5970061.80 590438.97 N 70.32794841 W 149.26653327 172.80 0.27 317.17 91.20 172.80 0.32 0.44 0.43 0.19 -0.38 0.21 5970061.95 590438.74 N 70.32794883 W 149.26653509 266.80 1.14 344.20 185.19 266.79 1.46 1.58 1.48 1.26 -0.79 0.97 5970063.01 590438.33 N 70.32795173 W 149.26653838 359.80 2.94 357.67 278.13 359.73 4.64 4.88 4.67 4.53 -1.14 1.99 5970066.28 590437.94 N 70.32796067 W 149.26654121 Last GYD CT DMS 453.80 4.06 10.31 371.95 453.55 9.77 10.60 10.23 10.21 -0.64 1.44 5970071.96 590438.37 N 70.32797620 W 149.26653717 MWD+IFR+MS 490.75 4.62 10.87 408.80 490.40 12.16 13.39 12.96 12.96 -0.13 1.52 5970074.72 590438.85 N 70.32798370 W 149.26653300 537.91 5.97 12.95 455.76 537.36 15.81 17.74 17.23 17.22 0.78 2.89 5970078.98 590439.70 N 70.32799533 W 149.26652564 580.97 7.59 13.67 498.51 580.11 20.02 22.83 22.25 22.16 1.96 3.77 5970083.94 590440.82 N 70.32800884 W 149.26651612 630.20 8.81 13.85 547.24 628.84 25.80 29.85 29.21 28.98 3.63 2.48 5970090.78 590442.41 N 70.32802747 W 149.26650257 673.36 9.84 11.62 589.83 671.43 31.63 36.84 36.17 35.80. 5.16 2.53 5970097.62 590443.86 N 70.32804611 W 149.26 719.47 10.85 8.60 635.19 716.79 38.73 45.12 44.45 43.95 6.60 2.49 5970105.79 590445.20 6 N 70.32806838 W 149.26 763.91 12.20 5.91 678.73 760.33 46.57 54.00 53.32 52.76 7.71 3.27 5970114.61 590446.21 N 70.32809244 W 149.26 811.42 13.16 1.72 725.08 806.68 56.05 64.42 63.72 63.16 8.39 2.80 5970125.01 590446.76 N 70.32812085 W 149.26646393 859.45 14.81 356.48 771.69 853.29 66.96 76.02 75.20 74.75 8.18 4.33 5970136.60 590446.41 N 70.32815252 W 149.26646565 907.90 16.39 354.19 818.35 899.95 79.48 89.05 88.02 87.74 7.11 3.50 5970149.57 590445.18 N 70.32818798 W 149.26647435 955.18 17.22 355.25 863.61 945.21 92.64 102.72 101.52 101.35 5.85 1.87 5970163.16 590443.76 N 70.32822517 W 149.26648452 1005.10 19.56 355.86 910.98 992.58 107.75 118.46 117.14 117.05 4.64 4.70 5970178.84 590442.35 N 70.32826806 W 149.26649438 1051.45 21.49 355.00 954.39 1035.99 123.35 134.71 133.29 133.25 3.34 4.21 5970195.02 590440.86 N 70.32831231 W 149.26650492 1102.38 21.69 355.05 1001.74 1083.34 141.38 153.45 151.93 151.92 1.71 0.39 5970213.67 590439.01 N 70.32836332 W 149.26651810 1146.30 22.25 354.66 1042.47 1124.07 157.20 169.88 168.28 168.28 0.24 1.32 5970230.02 590437.34 N 70.32840802 W 149.26653005 1199.10 24.80 353.41 1090.88 1172.48 177.57 190.96 189.25 189.24 -1.96 4.92 5970250.94 590434.88 N 70.32846528 W 149.26654791 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V Slot (N-E)\V-214\V-214\V-214 Generated 11/28/2006 2:50 PM Page 1 of 4 Comments Measured Inclination Azimuth Subsea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft n n ft ft de 100 ft ftUS ftUS 1244.LLL6.06 354.74 1131.63 1213.L3 196.29 210.33 208.55 208.51 -3.96 3.U7 5970270.19 1288.56 25.71 354.24 1171.52 1253.12 214.96 229.69 227.85 227.78 -5.82 0.93 5970289.43 1339.26 27.03 354.02 1216.95 1298.55 236.71 252.21 250.31 250.18 -8.12 2.61 5970311.80 1390.75 27.84 353.68 1262.64 1344.24 259.66 275.93 273.97 273.76 -10.66 1.60 5970335.35 1432.30 28.31 354.33 1299.30 1380.90 278.56 295.48 293.49 293.21 -12.71 1.35 5970354.77 1482.49 30.05 354.40 1343.12 1424.72 302.18 319.95 317,92 317.56 -15.11 3.47 5970379.09 1532.75 34.70 355.50 1385.56 1467.16 328.06 346.86 344.80 344.36 -17.46 9.33 5970405.86 1583.87 37.35 357.08 1426.90 1508.50 356.79 376.92 374.86 374.36 -19.39 5.49 5970435.83 1629.72 37.63 356.84 1463.28 1544.88 383.36 404.83 402.77 402.23 -20.87 0.69 5970463.67 1677.39 38.90 354.72 1500.71 1582.31 411.65 434.34 432.28 431.66 -23.05 3.83 5970493.07 1724.64 39.14 353.92 1537.42 1619.02 440.36 464.09 462.00 461.27 -26.00 1.18 5970522.64 1773.89 36.21 353.32 1576.40 1658.00 469.51 494.19 492.05 491.18 -29.34 6.00 5970552.50 1820.83 36.58 352.82 1614.18 1695.78 496.54 522.04 519.85 518.83 -32.70 1.01 5970580.11 1869.56 39.51 353.37 1652.55 1734.15 525.69 552.07 549.84 548.64 -36.30 6.05 5970609.87 1915.71 41.05 354.46 1687.76 1769.36 554.54 581.90 579.65 578.30 -39.46 3.67 5970639.49 1963.54 41.60 357.20 1723.68 1805.28 584.79 613.48 611.22 609.80 -41.75 3.95 5970670.95 2009.38 45.17 357.48 1756.99 1838.59 614.70 644.97 642.70 641.25 -43.21 7.80 5970702.38 2057.77 50.38 355.13 i 789.50 1871.10 648.93 680.79 678.52 676.99 -45.55 11.35 5970738.08 2107.43 51.50 355.61 1820.79 1902.39 685.96 719.35 717.07 715.42 -48.66 2.38 5970776.47 2153.24 51.42 356.15 1849.34 1930.94 720.28 755.18 752.90 751.16 -51.23 0.94 5970812.18 2201.96 53.62 354,82 1878.98 1960.58 757.38 793.84 791.56 789.70 -54.28 5.01 5970850.67 2249.81 55.59 353.58 1906.70 1988.30 795.05 832.84 830.54 828.50 -58.23 4.63 5970889.42 2300.68 57.32 350.48 1934.81 2016.41 836.38 875.23 872.83 870.48 -64.12 6.11 5970931.32 2346.64 58.23 350.25 1959.32 2040.92 874.52 914.11 911.55 908.81 -70.63 2.02 5970969.57 2397.36 60.66 350.34 1985.10 2066.70 917.37 957.79 955.05 951.86 -77.99 4.79 5971012.52 2444.79 62.99 350.10 2007.49 2089.09 958.41 999.59 996.69 993.05 -85.09 4.93 5971053.63 2492.95 64.73 350.54 2028.71 2110.31 1000.82 1042.83 1039.78 1035.67 -92.36 3.70 5971096.15 2541.17 63.60 349.98 2049.72 2131.32 1043.41 1086.23 1083.05 1078.45 -99.70 2.57 5971138.83 2585.14 63.64 350.61 2069.26 2150.86 1082.06 1125.62 1122.32 1117.27 -106.34 1.29 5971177.57 2632.99 63.10 350.41 2090.71 2172.31 1124.00 1168.39 1164.99 1159.46 -113.39 1.19 5971219.66 2680.09 62.10 349.99 2112.38 2193.98 1165.04 1210.21 1206.70 1200.67 -120.51 2.27 5971260.78 2728.62 62.28 350.58 2135.03 2216.63 1207.16 1253.13 1249.52 1242.98 -127.75 1.14 5971302.99 2777.74 64.95 353.98 2156.86 2238.46 1250.00 1297.13 1293.49 1286.57 -133.65 8.25 5971346.51 2825.63 68.11 356.33 2175.93 2257.53 1292.22 1341.05 1337.40 1330.33 -137.35 7.99 5971390.22 2874.19 67.85 356.96 2194.14 2275.74 1335.16 1386.07 1382.38 1375.27 -139.98 1.32 5971435.12 2921.20 67.47 356.41 2212.01 2293.61 1376.63 1429.55 1425.82 1418.68 -142.50 1.35 5971478.49 2969.96 67.89 353.12 2230.53 2312.13 1420.06 1474.65 1470.92 1463.59 -146.61 6.30 5971523.34 3021.30 67.14 353.06 2250.16 2331.76 1466.11 1522.09 1518.34 1510.68 -152.32 1.46 5971570.36 3066.73 66.70 352.82 2267.97 2349.57 1506.70 1563.88 1560.13 1552.16 -157.46 1.08 5971611.77 3112.62 66.41 352.94 2286.23 2367.83 1547.60 1605.99 1602.22 1593.94 -162.67 0.68 5971653.47 3161.22 66.07 353.01 2305.81 2387.41 1590.80 1650.47 1646.69 1638.08 -168.11 0.71 5971697.55 590432.66 N 70.32851792 W 149.26656408 590430.57 N 70.32857056 W 149.26657915 590427.99 N 70.32663176 W 149.26659784 590425.17 N 70.32869619 W 149.26661845 590422.89 N 70.32874932 W 149.26663501 590420.20 N 70.32881585 W 149.26665449 590417.52 N 70.32888906 W 149.26667356 590415.23 N 70.32897102 W 149.26668923 590413.41 N 70.32904715 W 149.26670123 590410.88 N 70.32912756 W 149.26671891 590407.58 N 70.32920843 W 149.26674279 590403.88 N 70.32929015 W 149.26676987 590400.19 N 70.32936568 W 149.263 590396.22 N 70.32944712 W 149.26682637 590392.71 N 70.32952817 W 149.26685198 590390.04 N 70.32961421 W 149.26687057 590388.20 N 70.32970012 W 149.26688240 590385.43 N 70.32979776 W 149.26690137 590381.86 N 70.32990276 W 149.26692660 590378.85 N 70.33000039 VV 149.26694748 590375.34 N 70.33010568 W 149.26697222 590370.92 N 70.33021168 W 149.26700423 590364.53 N 70.33032636 W 149.26705198 590357.56 N 70.33043108 W 149.26710477 590349.68 N 70.33054868 W 149.26716447 590342.08 N 70.33066123 W 149.26722208 590334.30 N 70.33077766 W 149.26728103 590326.45 N 70.33089452 W 149.26734057 590319.34 N 70.33100059 W 149.26739443 590311.78 N 70.33111584 W 149.26 590304.17 N 70.33122841 W 149.26 590296.42 N 70.33134400 W 149.267 1 590290.00 N 70.33146309 W 149.26761592 590285.77 N 70.33158264 W 149.26764592 590282.60 N 70.33170542 W 149.26766730 590279.56 N 70.33182401 W 149.26768770 590274.90 N 70.33194670 W 149.26772109 590268.63 N 70.33207535 W 149.26776739 590262.99 N 70.33218866 W 149.26780906 590257.27 N 70.33230279 W 149.26785139 590251.30 N 70.33242339 W 149.26789552 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V Slot (N-E)\V-214\V-214\V-214 Generated 11/28/2006 2:50 PM Page 2 of 4 Comments Measured Inclination Azimuth Suh.Sea ND NO Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure n de de n ft n n n n n de 100 n nUS nUS 3210.L4 6516 351.94 2326.07 2407.61 1634.26 1695.13 1691.33 1682.36 -173.96 2.59 5971741./5 590244.9E N /0.33254436 W 149.26794296 3258.10 64.48 351.21 2346.34 2427.94 1676.58 1738.46 1734.62 1725.22 -180.31 2.14 5971784.53 590238.06 N 70.33266145 W 149.26799445 3303.54 64.40 350.88 2365.94 2447.54 1716.70 1779.45 1775.56 1765.72 -186.69 0.68 5971824.94 590231.19 N 70.33277208 W 149.26804622 3353.54 63.84 351.07 2387.77 2469.37 1760.73 1824.44 1820.48 1810.15 -193.75 1.17 5971869.27 590223.60 N 70.33289345 W 149.26810346 3400.16 63.67 351.62 2408.38 2489.98 1801.60 1866.25 1862.26 1851.48 -200.04 1.12 5971910.53 590216.81 N 70.33300638 W 149.26815451 3450.87 65.25 352.08 2430.24 2511.84 1846.24 1912.00 1907.98 1896.77 -206.52 3.22 5971955.73 590209.78 N 70.33313011 W 149.26820712 3497.87 66.00 352.13 2449.64 2531.24 1887.96 1954.82 1950.78 1939.18 -212.40 1.60 5971998.06 590203.39 N 70.33324596 W 149.26825483 3545.73 65.37 349.39 2469.35 2550.95 1930.68 1998.43 1994.33 1982.22 -219.40 5.38 5972041.01 590195.87 N 70.33336355 W 149.26831161 3595.31 65.09 348.32 2490.12 2571.72 1975.06 2043.45 2039.19 2026.39 -228.11 2.04 5972085.07 590186.64 N 70.33348421 W 149.26838220 3643.02 64.55 346.82 2510.42 2592.02 2017.77 2086.62 2082.13 2068.55 -237.40 3.06 5972127.11 590176.84 N 70.33359940 W 149.26845758 Tie-In Survey 3723.82 63.84 344.16 2545.60 2627.20 2090.06 2159.36 2154.19 2138.97 -255.62 3.09 5972197.29 590157.78 N 70.33379176 W 149.26860537 MWD+IFR+MS 3793.86 63.13 343.97 2576.87 2658.47 2152.51 2222.03 2216.09 2199.23 -272.82 1.04 5972257.34 590139.85 N 70.33395640 W 149.2 3888.96 62.76 346.12 2620.13 2701.73 2236.75 2306.73 2300.01 2281.05 -294.68 2.05 5972338.88 590117.01 6 N 70.33417991 W 149.26 3986.68 64.86 346.96 2663.26 2744.86 2323.70 2394.41 2387.21 2366.32 -315.08 2.28 5972423.90 590095.58 N 70.33441287 W 149.26908781 4083.57 67.98 347.65 2702.01 2783.61 2411.60 248320 2475.66 2452.94 -334.59 3.29 597251027 590075.03 N 70.33464951 W 149.26924606 4180.04 67.57 346.60 2738.50 2820.10 2500.04 2572.50 2564.62 2540.00 -354.49 1.09 5972597.07 590054.09 N 70.33488733 W 149.26940750 4276.39 67.17 343.50 2775.58 2857.18 2588.49 2661.43 2652.89 2625.91 -377.42 3.00 5972682.69 590030.12 N 70.33512203 W 149.26959358 4371.53 64.69 339.66 2814.39 2895.99 2675.25 274828 2738.40 2708.31 -404.83 4.51 5972764.74 590001.72 N 70.33534713 W 149.26981598 4466.74 64.95 337.76 2854.91 2936.51 2761.40 2834.44 2822.48 2788.58 -436.12 1.83 5972844.63 589969.47 N 70.33556643 W 149.27006980 4561.89 66.45 333.42 2894.08 2975.68 2847.92 2921.15 2906.10 2867.52 -471.96 4.45 5972923.11 589932.68 N 70.33578206 W 149.27036060 4657.07 65.49 329.54 2932.85 3014.45 2934.05 3008.08 2988.32 2943.88 -513.45 3.86 5972998.97 58989029 N 70.33599068 W 149.27069718 4752.46 64.50 325.24 2973.18 3054.78 3018.65 3094.52 3068.23 3016.69 -560.01 4.21 5973071.20 589842.85 N 70.33618957 W 149.27107496 484$.42 65.23 320.71 3013.96 3095.56 3102.05 3181.38 3146.17 3086.01 -612.31 4.34 5973139.88 589789.72 N 70.33637895 W 149.27149929 4943.75 64.95 317.42 3054.12 3135.72 3183.23 3267.84 3221.54 3151.32 -668.95 3.14 5973204.50 589732.31 N 70.33655735 W 149.27195880 5039.11 64.76 318.29 3094.64 3176.24 3263.64 3354.16 3296.46 3215.32 -726.87 0.85 5973267.79 589673.62 N 70.33673219 W 149.27242875 5134.37 64.79 318.67 3135.24 3216.84 3344.26 3440.34 337225 3279.85 -784.00 0.36 5973331.61 589615.73 N 70.33690844 W 149.27289223 5230.33 64.67 318.68 3176.20 3257.80 3425.55 3527.12 3449.19 3345.01 -841.30 0.13 5973396.08 589557.65 N 70.33708646 W 149.27335715 5325.06 64.49 319.19 3216.86 3298.46 3505.82 3612.68 3525.67 3409.52 -897.50 0.52 5973459.90 589500.68 N 70.33726267 W 149.27381319 5420.64 64.38 319.17 3258.11 3339.71 3586.85 3698.90 3603.32 3474.77 -953.86 0.12 5973524.46 589443.54 N 70.33744091 W 149.27427051 5516.40 64.50 318.92 3299.43 3381.03 3667.96 3785.29 3681.41 3540.01 -1010.49 0.27 5973589.01 589386.14 N 70.33761912 W 149.2 5612.13 63.31 318.56 3341.53 3423.13 3748.53 3871.26 3759.30 3604.64 -1067.18 1.29 5973652.94 589328.68 7 N 70.33779566 W 149.27 5707.78 62.05 319.82 3385.43 3467.03 3828.39 3956.24 3836.89 3668.96 -1122.72 1.76 5973716.58 589272.37 N 70.33797133 W 149.27564067 5804.69 58.19 321.52 3433.71 3515.31 3908.05 4040.25 3914.73 3733.92 -1175.99 426 5973780.89 589218.33 N 70.33814879 W 149.27607287 5899.91 53.92 322.38 3486.87 3568.47 3983.47 4119.22 3988.76 3796.10 -1224.67 4.55 5973842.47 589168.91 N 70.33831864 W 149.27646795 5995.88 50.15 323.62 3545.90 3627.50 4056.12 4194.87 4060.30 3856.50 -1270.21 4.06 5973902.31 589122.65 N 70.33848363 W 149.27683751 6091.54 46.56 323.63 3609.45 3691.05 4124.98 4266.34 4128.28 3914.05 -1312.60 3.75 5973959.34 589079.57 N 70.33864082 W 149.27718150 6186.08 44.84 324.27 3675.48 3757.08 4190.26 4334.00 4192.85 3968.75 -1352.42 1.88 5974013.55 589039.10 N 70.33879023 W 149.27750466 6283.37. 42.15 324.68 3746.05 3827.65 4255.03 4400.96 4257.02 4023.24 -1391.33 2.78 5974067.56 588999.54 N 70.33893908 W 149.27782044 6378.59 38.94 325.98 3818.40 3900.00 4315.11 4462.84 4316.66 4074.12 -1426.56 3.49 5974118.01 588963.70 N 70.33907807 W 149.27810630 6474.19 35.59 328.51 3894.48 3976.08 4371.72 4520.71 4372.94 4122.76 -1457.91 3.85 5974166.27 588931.77 N 70.33921093 W 149.27836073 6569.91 32.01 330.39 3974.01 4055.61 4424.18 4573.95 4425.19 4168.58 -1485.00 3.90 5974211.76 588904.13 N 70.33933611 W 149.27858063 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V SIoY(N-E)\V-214\V-214\V-214 Generated 11/28/2006 2:50 PM Page 3 of 4 Comments Measured Inclination Azimuth SulrSea ND ND vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de n ft ft ft ft ft ft de 00 ft ftUS ftUS 6665.50 28.02 330.78 4056.76 4138.36 4471.45 4621.76 4472.30 4210.22 -1508.49 4.18 5974253.10 6761.34 24.44 329.15 4142.72 4224.32 4513.26 4664.11 4513.98 4246.90 -1529.65 3.81 5974289.52 6856.36 20.45 327.87 4230.52 4312.12 4548.91 4700.38 4549.51 4277.85 -1548.57 4.23 5974320.24 6952.15 18.48 329.18 4320.83 4402.43 4580.28 4732.30 4580.78 4305.06 -1565.25 2.11 5974347.24 7047.45 18.64 330.16 4411.18 4492.78 4610.19 4762.63 4610.62 4331.24 -1580.56 0.37 5974373.24 7143.48 18.63 330.59 4502.17 4583.77 4640.52 4793.31 4640.88 4357.92 -1595.73 0.14 5974399.72 7239.70 18.55 330.43 4593.37 4674.97 4670.84 4823.99 4671.15 4384.62 -1610.83 0.10 5974426.24 7334.36 18.35 330.12 4683.17 4764.77 4700.44 4853.95 4700.69 4410.63 -1625.69 0.24 5974452.07 Last MWD+IFR+MS 7379.73 18.29 330.39 4726.24 4807.84 4714.53 4868.21 4714.76 4423.01 -1632.76 0.23 5974464.36 TD (Projected) 7449.00 18.29 330.39 4792.01 4873.61 4736.01 4889.94 4736.21 4441.91 -1643.50 0.00 5974483.13 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) IftUSI Easting (Xl IftUSI Surface : 4815 FSL 1862 FEL S11 T11 N R11 E UM 5970061.76 590439.13 BHL : 3977 FSL 3501 FEL S2 T11 N R11 E UM 5974483.13 588742.36 588880.15 N 70.33944985 W 149.27877127 588858.54 N 70.33955004 W 149.27894304 588839.26 N 70.33963457 W 149.27909657 588822.25 N 70.33970890 W 149.27923195 588806.62 N 70.33978042 W 149.27935627 588791.14 N 70.33985328 W 149.27947939 588775.72 N 70.33992622 W 149.27960195 588760.55 N 70.33999728 W 149.27972252 588753.33 N 70.34003110 W 149.27977995 588742.36 N 70.34008273 W 149.27986713 • • SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V Slot (N-E)\V-214\V-214\V-214 Generated 11/28/2006 2:50 PM Page 4 of 4 I TRF~= 4.1/8'" WELL#dEAD= FMC ,, AC111ATC7R- KB_ ELEV ,,,,,,,,,,~ t.EQ 81.6 BF. F:t.EV - 53.1 KOP = Max Angle = 300 F~° ~ 2825' Datum MD = _-._ Datum TVD= e xxxx' xxxx' SS • ~R~~ CRAFT SAFETY OTES: HES PKR @ 6675 IS A "PULL TO REL UT CAN ALSO BE RELEASED BY ~ ~ PRES CAUTION M UST BE USED WHEN PT ON IA & TBG AT THE SAM E TIM E AS THIS COUL D RELEASE ~~ THE PKR 2752' 3-1f2" HE S X NIP, ID = 2.813' 9 5!8" CSG, 4t'?~, L-80, .#)758 ID = 8.83a 3758' 7" 26# L-80 TC II x 7" 26# L-80 BTGM XO jt 5219' Minimum IL] - 2.813"' 3-112" HES X NIRP~ES 1NATERFLOOCIVYGAS L~1`MANDREIS ST MD TVD DEV' TYPE VLV LATCH PORT DATE 9 6815 4094 ~ MMGW DMY RK Q 11/U4146 8 8725 4185 26 AiMG-W DMY RK 0 111fl41fl6 7 8895 4346 2D ' NIMO-W pAil'f RK Q 11ro4106 8 f+924 4376 19 FUI141O-W ~)AR'( RK 0 11104106 5 6886 4434 99 IUNVIG-U1t C')M'++ RtC 0 11/04/os 4 7014 4481 19 ' MMG-+VYV L7MY RK D 11 lDAl06 3 7f~5 4StK! 19 ' MMGW DA+T'( RK 0 11/04/06 2 7084 4527 19 ' MMG-W DAM RK 0 11/04106 1 7145 .4584 19 AINVIG-W E]MT~' RFC 0 11144JOB PERFORA"Tl(?!V SUMMARY F2EF LOG ANGLEATTOPPEF2F: 26~ ~ 6702' Note: Re€er to Productian DB for h€storieal perf dafa SQE SPF INTERVAL. OpnJSgz DATE 45" 5 6702-6712 O 1 i I041t?fi 4.5" 5 69K}0-694p C3 f it(3414~f 4.5" s9s&-6994 O 19fO410& 4.5"' S 7090-7028 O 1:1J041Q6 4.5" 5 7(168-7082 0 11/04106 4.5" 5 7120-717D O 11 /041Q6 3.11?~ TSC3, s.zu, L-Ba, .Ut387 epf, ID _ ?.ss?• Read the info provided in the well file in regards to pressure testing limitations of the upper packer. 7051 ~ Marker joint with RA tag in collar 7" Halliburton packer with 1J4" feed throuoh I 6688' --~ Phoenix sensor sub ~ 6708' 3-112" FtES X NIP, ID = 2.813" 6853 7" X3-112" BKR PREMIER PKR, ID = 2.87" 6879 3-1 /2" HES X NIP, ID = 2.813" it94$' ~ 7` X 3»1f2` BKR PFiEMtER PICK, ID = 2.87" 6975' 3-1/2" HES X NIP, ID = 2.813" I 7" X3-1 J2" BKR PREMIER PKR, ID = 2.87" I 7050 I Markerjoint with RA tag in collar 7102' 7" X 3-1J2" BKR PREMIER PKR, ID = 2.87" 7124' 3-1/2" HES X NIP, ID = 2.813" w/RHGm plug _ 7173 3-112" HES X NIP, ID = 2.813" 7194' 3-1/2" HES X NIP, ID = 2.813" PBTD 7" GSG, 26#, 1_-80, ID = fi.?7fi" ~-iJZ'E~, ~=z" DATE REV 8Y COAN,itt'tVT'S DAT€ REV BY COMMENTS ORLON t11+FIT iilp6/0!i AM final ng tevsion WELL: V-2141 11t11JQfi tI1H CORREGTEC3NS F'ERMlrl~b:2O5-13d API No: S{)-029-23275-QO S>=C 11, T11 N, tZ11 E, 4816' FSL S~ i$62' FF:J.. SP Ecplaratiorl (AFaska~ Sedpne~ger Schlumberger43CS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Bath A ~ ~~1 P, ~~ ]l V / Well Job # Log Description NO. 3862 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100. Anchorage, AK 99501 Field: Orion, Aurora, Borealis, Polaris Date BL Color CD 5-111 5-114A 11216189 10572082 MEMORY INJECTION PROFILE RST UPFLOW WFL 04/15/06 03/01103 1 1 V-105 E-103 10663005 10560276 INJECTION PROFILE TEMPERATURE WARMBACK 03/12!04 06/22/03 1 1 V-214 V-213 71162720 11076450 UBI INJECTION PROFILE 11/24/05 07101/05 1 1 V-216 V-221 11076451 11058523 INJECTION PROFILE INJECTION PROFILE 07/02/05 07!03105 1 1 L-103 W-209 NIA 17076461 INJECTION PROFILE INJECTION PROFILE 07/18!09 08/20/05 1 1 W-207 W-212 10980589 NIA INJECTION PROFILE INJECTION PROFILE 07/20/05 07!19/05 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechniral Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508.4254 Date Delivered: Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503.2838 ATTN: Beth Received ~~ UVI'i ~ ~ L~U~ d ~.+tl .~i X2+5 CGf1S. ~CiCtti}ISSi~'f1 ~l1ChO1"i'.~e 06/21/06 •a ' ~'~ ~> e~ STATE OF ALASKA ~~p 4 ALASKA AND GAS CONSERVATION C SSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~~~ ~, ~~~r 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Other ~ _ ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ®Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension 2: Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 205-134 ~ 3. A ress: ^ Stratigraphic ®Service / 6. API Number: ~ P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23275-00-00 7. KB Elevation (ft): 78 8' 9. Well Na and Number: j PBU V-2141 8. Property Designation: 10. Fiel / Poo s): ADL 028240 Prudhoe Bay Field / Orion Schrader Bluff ~ t. PRESENT WELL OMDI ON SUM ARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD ( E ctive Depth VD (ft)' Plugs (measured): Junk (measured): 7380 4858 3541 2547 3541 None Casin Len th Size M TVD Burst Colla se Structural Conductor 102' 20" 2' 102' Surface 3730' 9-518" 57' 2640' 5750 3090 Intermediate Production Liner i Perforation Depth MD (ft): Perforation th TVD ): Tu ng Si Tubing Grade: Tubing MD (ft}: None N e Non 3-1/2", 9.2# ~ 2752' (Kill String) Packers and SSSV Type: None Packers and SSSV MD (ft): N/A 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Propo I ^ BO Sketch ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: y 8, 2006 ^ Oil ^ Gas ^ Plugged ^ Abandoned 16. Verbal Approval: t~'. ®WAG ^ GINJ ^ WINJ ^ WDSPL Commission Re resentative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Martyn, 564-4101 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/Number: ~d ~ Terrie Hubble, 564-4628 564-4166 D Si nature Ph t ,/ one a e Commission Use Only Sundry Number:.,3aG_/SS Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: S~?hIS BFI ~lAY 0 . :~ 2006 Subsequent Form Required: APPROVED BY Approved By: C M I I R THE COMMISSION Date corm ~u-4u3 Kevisetl Ui/LUUb y ` f~ 6 ~ ~ ~~ ~ ~ Submit In Duplicate by c,~,y To: Winton Aubert - AOGCC From: Matt Martyn - BPXA GPB Rotary Drilling • Date: Apr 26, 2006 Subject: V-2141 Application for Sundry Approval - Re-Enter & Complete Reference: API # 50-029-23275-00 Approval is requested for the proposed Re-Enter and Complete of Orion well V-214 (Permit# 205-134). This Ultra-Slimhole Orion injector was originally drilled in 4Q 2005 and had drilling problems that required suspension (Sundry# 305-370). The well was suspended with surface casing set and a P&A cement plug 200' inside of the surface shoe. The Re-Enter and complete of V-214i is currently scheduled for Nabors rig 9ES, beginning around May 28tH 2006, after the completion of the S-121 Grassroots well. The directional plan for V-214i has only moved 100' and is intended to stay within the original drilling permit. The pre-rig work for this sidetrack will begin at the Well's Group earliest convenience. '/a Mile Wellbore Near Wellbore Mechanical Integrity Summary: Listed below is the'/a mile integrity summary that was given in a-mail dialogues after applying for the original V-2~ 4i ,permit to drill (# 205-134): 10~'s a Borealis well that enters the 1/4 mile radius in all Schrader sands below the Na. The w.ttlbore lies 1043' from V-214 at the top OBe. During cementing of V-102, no losses were noted, and assuming a 30% excess hole volume, Top of Cement would be expected at 3979' MD or 1190' MD above the top Ma. There are no other wells within ~/a mile of this injector throughout the Schrader lntervat. The only addition to this in the Schrader interval is the existence of V-214 PB#2 from the first drilling of V- ~". 214i in 40, 2005. This is best shown graphically on the attached suspended completion, and directional plan maps. PB#2 extends to the Schrader OBf interval and has an 800' cement plug where PB#4 intersected PB#2 (3915'-4750' MD). The final condition of the PB#2 wellbore was discussed with Commission Staff shortly after V-2141 was suspended, and a verbal opinion was given that a replacement wellbore could be drilled nearby. Scope Pre-Riq Work: 1. If necessary, level the pad and prepare location for rig move. 2. Prepare neighboring wells for the rig move and simops production. Shut in V-101 and V-202 and remove well houses as necessary. Riq Operations: 1. M{RU Nabors 9ES. 2. Pull BPV. Circulate out freeze protection and displace well to seawater. 3. Set TWC. Nipple down tree. Nipple up and test BOPE to 4,000 psi. Pull TWC. 4. Pull and LD 3-'/z" 9.2# tubing from 2,724' MD. 5. PU 4" DP as required and stand back in derrick. 6. MU 8-3/a" drilling assembly with MWD/GR/Res/Den(recorded)/Neu(recorded)/PWD and RIH to float collar. Test the 9 5/" casing to 3,500 psi for 30 minutes. V-2141 Application for Sundry 7. Drill shoe track and displace over to 8.8 ppg LSND mud 8. Drill new formation to 20' below 9-b/" shoe and perform LOT (Notify ODE if 10.7 ppg LOT is not obtained). 9. Drill ahead to Polygon 2 Target TD at 7,420' MD, (250' MD below Top OBe marker). 10. Circulate and condition hole, POOH to run casing. Perform wiper trip if hole conditions dictate. 11. Run and cement the 7" production casing as required to cover all significant hydrocarbon intervals. Displace the casing with seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Freeze protect the 7" x 9 5/8" annulus. 12. PU DPC guns and RIH w/ 130' of 4.5" Power Jet 5 spf, pert guns (total assembly length to be 400') with Schlumberger LWD GR for gun correlation. Tag PBTD. Circ hole over to 9.0 brine while correlating. 13. Space out utilizing GR and RA tags in 7" casing. Once correlated correctly, Gently tag TD and w/ guns on bottom, Circ in pert pill. Pulf back to shooting depth & confirm cement compressive strength is at least 2,000 psi. Perforate Mc, OA, OBa, OBc, and OBd. POOH standing DP back. 14. RU Schlumberger E-line. RIH with gage ring and junk basket to recover any pert debris. Repeat until clean to at least 50' below the bottom perforation (OBd perf predicted 7102'-7138'). Note: It is imperative that we have a clean wellbore so we don't damage the MDT packers while RIH. 15. Run USIT/GR log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. Obtain high resolution (0.5"x5deg) repeat section over OBb interval (approx. 6,975'-7,060' MD on directional plan) 16. Transmit High-Res USIT pass to town as soon as possible for MDT Cased Hole OBb sample depth picking. 17. If cement integrity found to be suitable for MDT sampling needs, RIH and wireline perforate (GR-CCL tie in) one foot of OBb sand (depth TBD). POOH &RIH w/MDT configured for obtaining fluid sample from OBb Sand. Depths TBD based on cement evaluation. See attached MDT operations flowchart 18. Wireline perforate the entire OBb interval after POOH w! MDT. RD E-Line. 19. RIH w/ DP to 50' below bottom perforation. Circ hole to 9# brine cleaning out any remaining pert pill. POOH laying down DP. 20. Run the 3-~/z", L-$0 TCII completion with 7" x 3-~/z" straddle packer assemblies, injection mandrels, and phoenix pressure gauge. Note: Do not circulate inhibited brine down the backside yet. 21. Run in the lockdown screws and set the packers. Test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCR shear valve and pump both ways to confirm circulation ability. 22. Install FMC TWC. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 23. Freeze protect the well to 2,800 MD /2,200' TVD by first pumping ~99 BBLS corrosion inhibited seawater down the IA with rig pumps followed by 110 BBLS diesel down IA w/ Hot Oil taking clean seawater returns to surface throughout. Allow diesel to U-tube. 24. 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 both protected with two barriers. 25. Rig down and move off. Post-Rig Operations: 1. Install wellhouse, flowlines and instrumentation. 2. MIRU slickline. 3. Drift & Tag PBTD & Install gas lift valves. 4. MIRU E-Line. Record Jewelry Log & Perforate well (Approximately 40' of perforations). 5. POP well and evaluate production for ~2 months prior to frac job to ensure frac will be effective. Estimated Rig Move Date: Matt Martyn Operations Drilling Engineer 564-4101 -Office 632-3862 -Cell 564-4040 -Fax Mart49 ~ bp.com 5/28/06 V-2141 Application for Sundry V-214i Suspens n Completion TREE= C 4-1/16" 5M WELL AD FMC Gen 5 System 11 ", SM csg.head w/ 7" mandrel hanger & packoff 11 " x 1 1 ", SM, tbg spool w/ Cellar Elevation=53.1' 11" x 4-1 /2" tubing hanger DoyonI6RKB=74.5' 11" X 4-1/16" Adaptor Flange 101 ` ~ ~ 20"X34" 215.5 IbH`t, A53 ERW Insulated ~ PB#1 TD at 1006' 3-1/2", 9.2#!ft, NSCT, Kill String • 2,752` . , 2,740` 3-1/2", X-Nip, ID = 2.813 2,752` 3-1/2", WLEG 9-5/8°, 40 #/ft, L-80, BTC ' 3, 541 ` 3,758` 3,808` / I 3,820` 5,336` 6 3/4", TD (PB#4 -Successful Intersection & P&A) 3,915` 4,750` • 8 3/4", TD (PB#3 -Unintentional Sidetrack & 1st intersection attempt) 196` 7,380` 8 3/4", TD (PB#2, Original Injector Mainbore) Date Rev 30-Nov-05 MJM Comments Suspended Completion WELL: V-2141 API NO: 50-029-23275 V-214i Pro Cellar Elevation =53.1 ' Doyen 16 RK13 = 74.5' Max Deviation 65 Deg ~2 101' 3, 615' 9-5/8", 40 #/ft, L-S0, BTC 3,758` ~ 7" Short Joint 8 RA Tag (2-pips) Top Ma sand (6,374') 6,610` 6,668` Phoenix Pressure Gauge on I-Wire- 6,695` 6,716' 6,839` 6,867` 6,883` 7" Short Joint & RA Tag (2-pips) OA Above Top OA (6,790`) 6,912` RA Tag in 3-1 /2" TREE~C 4-1/16" 5M Completion ;;E, 5M csg.head wGl 7nmandrel hanger & packoff 11" x 11", SM, tbg spool w/ 11 " x 4-1 /2" tubing hanger TTt 1 1 " X 4-1 /16" Adaptor Flange 3-1 /2" x 4-1 /2" XO w/ 3' x 4-1 /2" pup to hanger ~ 20" X 34" 215.5 Ib/ft, A53 ERW Insulated 3-1/2" `X' Landing Nipple with 2.813" seal bore. 4-12", 12.6 Ib/ft, L-80, TCII Drift / ID : 3.833"/3.958" 3-1 /2", 9.3 Ib/ft, L-80, TCII Drift / ID : 2.867"/2.992" Camco 3-1 /2" x 1-1 /2" MMG GLM w/ - DCR-1 Shear Valve pinned to 2,500 7° x 3-1/2" HES 'AHR' Feed Through Production Packer 3-1/2" `X' Landing Nipple with 2.813" seal bore. -Camco 3-1 /2" x 1-1 l2" MMG-W GLM 7" x 3-1/2" Baker `PRM' Production Packer - 3-1/2" `X' Landing Nipple with 2.813" seal bore. Camco 3-1/2" x 1-1/2" MMG-W GLM 7" x 3-1 /2" Baker `PRM' Production Packer 3-1/2" `X' Landing Nipple with 2.813" seal bore. 6,936` OBa 6,957` 3-1 /2" x 1-1 /2" MMG-W GLM • 3-1/2" `X' Landing Nipple with 2.813" seal bore. 7" x 3-1 /2" Baker `PRM' Production Packer 3-1/2" x 1-1/2" MMG-W GLM 6,973` OBb 7,002` 7,016` 7,032` 7' OBc 7" x 3-1/2" Baker `PRM' Production Packer 3-1/2" `X' Landing Nipple with 2.813" seal bore. -Camco 3-1 /2" x 1-112" MMG-W GLM 3-1/2"'X' Landing Nipple with 2.813" seal bore. 7,068` 7,087` 7,108` 7,129` 7,158 ` 7,179 ` 7,189 ` 3-1 /2" WireLine Entry Guide 7,266` 7", PBTD 7,346` 7", 26 #/ft, L80, BTC-Mod 8 3/4", TD (Injector Mainbore) Date Rev By Comments 11-Apr-06 MJM Proposed Completion for wp10 V-214 1 Estimated Perf Depths, 6 sands Zone MD Inc. Perf Int. Feet Mc 6690 6690-6700 10 OA 6887 16 6887-6924 37 OBa 6952 16 6952-6981 29 OBb 6993 16 6993-7009 16 OBc 7053 16 7053-7065 12 OBd 7102 16 7102-7138 36 Li~a1~r,~,~rr~'~~t' .~al~ WELL: V-2141 API NO: 50-029-23275-00 by V-214 (P10) Pro Repoli Date: January 17, 2006 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure I Slot: V-Pad / Plan V Slot (N-E) ~~~ f ~~ Well: V-214 ~~~~ Borehole: Plan V-214 UWUAPI#: 500292327500 Survey Name I Date: V-214 (P10) /January 17, 2006 Tort 1 AHD 1 DDI 1 ERD ratio: 196.586° 14852.05 ft 16.164 11.001 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Location LaULong: N 70.32794898, W 149.26653211 Location Grid NIE YIX: N 5970062.010 ftUS, E 590439.110 ftUS Grid Convergence Angle: +0.69066322° Schlumberger Survey I DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 339.170° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 82.00 ft relative to MSL Sea Bed 1 Ground Level Elevation: 54.00 ft relative to MSL Magnetic Declination: 24.260° Total Field Strength: 57580.233 nT Magnetic Dip: 80.847° Declination Date: May 05, 2006 Magnetic Declination Model: BGGM 2005 North Reference: True North Total Corr Mag NoRh -> True North: +24.260° Measured Vertical Comments inclination Azimuth Sub-Sea TVD TVD NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section 8 de de ft ft ft ft ft de 1100 k de de 1100 ft de 1100 ft ftUS ftU5 Ile-In survey StfU/.Z7 bb./5 3~i4.V5 ZOBU.`J4 ZbbL. `J4 Llb4.t5/ LLII .I`J -Z/b.lt5 4.L4 -`JU.3bb U.LL -4Ab bJ/LLOJ.DU bJV IJO. 3L IV /U .3JJJ8y/3 VV l4y.Gb6//LJ.7 KOP Crv 4/100 3900.00 65.78 339. 99 2619.04 2701. 04 2249. 35 2291. 64 -302.29 3.99 95.OOG 0.03 -4.37 5972349.63 590109. 25 N 70. 33420953 W 149.26898416 4000.00 65.50 344. 37 2660.31 2742. 31 2340. 29 2378 .34 -330.16 4.00 93.19G -0.29 4.38 5972435.97 590080. 34 N 70 .33444637 W 149.26921025 End Crv 4100.00 65.34 348. 77 2701.93 2783. 93 2430. 44 2466 .76 -351.28 4.00 O.OOG -0.16 4.40 5972524.12 590058. 16 N 70. 33468792 W 149.26938157 Crv 4/100 4150.00 65.34 348. 77 2722.79 2804. 79 2475. 24 2511 .32 -360.13 0.00 -95.91 G 0.00 0.00 5972568.58 590048. 77 N 70 .33480968 W 149.26945339 4200.00 65.15 346. 57 2743.74 2825. 74 2520. 14 2555 .68 -369.82 4.00 -94.99G -0.38 -4.39 5972612.81 590038. 55 N 70 .33493084 W 149.26953203 UG4 4245.70 65.00 344. 57 2763.00 2845. 00 2561. 33 2595. 81 -380.15 4.00 -94.14G -0.32 -4.40 5972652.81 590027. 74 N 70. 33504049 W 149.26961582 4300.00 64.86 342. 17 2786.01 2868. 01 2610. 37 2642 .93 -394.22 4.00 -93.13G -0.25 -4.41 5972699.75 590013 .10 N 70 .33516922 W 149.26973001 UG4A 4321.15 64.82 341. 24 2795.00 2877.00 2629. 50 2661. 11 -400.23 4.00 -92.73G -0.20 -4.41 5972717.85 590006. 87 N 70. 33521887 W 149.26977876 4400.00 64.71 337. 75 2828.63 2910. 63 2700. 81 2727 .90 -425.21 4.00 -91.25G -0.14 -4.42 5972784.34 589981. 09 N 70 .33540134 W 149.26998140 4500.00 64.69 333. 33 2871.38 2953. 38 2791. 00 2810 .17 -462.63 4.00 -89.36G -0.02 -4.42 5972866.14 589942. 69 N 70 .33562608 W 149. 8 4600.00 64.80 328 .91 2914.06 2996. 06 2880. 52 2889 .33 -506.29 4.00 -87.47G 0.11 -4.42 5972944.76 589898 .07 N 70 2 .33584234 W 149.2 7 4700.00 65.04 324 .50 2956.47 3038. 47 2968. 93 2965 .01 -556.00 4.00 -85.60G 0.24 -4.41 5973019.83 589847. 46 N 70 .33604908 W 149.2 55 End Crv 4727.06 65.13 323 .31 2967.87 3049. 87 2992. 60 2984 .84 -570.46 4.00 O.OOG 0.32 -4.40 5973039.48 589832 .77 N 70 .33610325 W 149.27115984 UG3 5103.06 65.13 323. 31 3126.00 3208. 00 3320. 75 3258. 39 -774.28 0.00 O.OOG 0.00 0.00 5973310.53 589625. 69 N 70. 33685050 W 149.27281350 Crv 4/100 5677.12 65.13 323 .31 3367.43 3449. 43 3821. 75 3676 .03 -1085.46 0.00 174.74G 0.00 0.00 5973724.35 589309 .52 N 70 .33799135 W 149.27533848 5700.00 64.22 323 .40 3377.22 3459. 22 3841. 64 3692 .62 -1097.80 4.00 174.70G -3.98 0.41 5973740.79 589296 .98 N 70 .33803668 W 149.27543864 5800.00 60.24 323 .83 3423.81 3505. 81 3926. 86 3763 .83 -1150.28 4.00 174.SOG -3.98 0.43 5973811.36 589243 .65 N 70 .33823121 W 149.27586450 5900.00 56.26 324 .29 3476.43 3558. 43 4008. 94 3832 .66 -1200.19 4.00 174.26G -3.98 0.46 5973879.57 589192 .93 N 70 .33841921 W 149.27626947 6000.00 52.28 324 .79 3534.82 3616. 82 4087. 46 3898 .76 -1247.27 4.00 173.96G -3.98 0.51 5973945.09 589145 .05 N 70 .33859977 W 149.27665158 UGf 6029.33 51.11 324. 95 3553.00 3635. 00 4109. 77 3917. 59 -1260.52 4.00 173.87G -3.98 0.54 5973963.76 589131. 58 N 70. 33865120 W 149.27675906 6100.00 48.30 325 .36 3598.70 3680. 70 4162. 05 3961 .81 -1291.31 4.00 173.60G -3.98 0.57 5974007.60 589100 .26 N 70 .33877201 W 149.27700897 6200.00 44.33 325 .99 3667.76 3749. 76 4232 .35 4021 .51 -1332.09 4.00 173.16G -3.97 0.64 5974066.80 589058 .77 N 70 .33893508 W 149.27733990 WeIlDesign Ver SP 1.0 Bld(doc40x_56) Plan V Slot (N-E)\V-2141PIan V-2141V-214 (P10) Generated 1/17/2006 1:17 PM Page 1 of 2 Measured Verbal Comments inclination Azimuth Sub-Sea ND ND NS EW DLS Tool Face Build Rate Walk Rate Northing Fasting Latitude Longitude . Depth Section ft d de ft ft ft ft ft de 100 ft de 100 ft de 1100 ft ftUS ftUS 63UU.UU 4U.3ti 3L6./3 3/41.liti 32f"L3.lili 41yS.U1 4U//.5/ -136y.4U 4.UU 1/Y.ti1Ci 6400.00 36.39 327.59 3820.04 3902.04 4358.72 4129.71 -1403.08 4.00 171.94G Ma 6467.16 33.74 328.27 3875.00 3957.00 4396.55 4162.39 -1423.57 4.00 171.39G 6500.00 32.44 328.64 3902.52 3984.52 4414.17 4177.67 -1432.95 4.00 171.OSG Mb1 6510.03 32.04 328.76 3911.00 3993.00 4419.43 4182.24 -1435.72 4.00 170.98G Mb2 6585.51 29.06 329.73 3976.00 4058.00 4457.22 4215.21 -1455.36 4.00 170.14G 6600.00 28.49 329.94 3988.70 4070.70 4464.10 4221.23 -1458.86 4.00 169.96G Mc 6661.11 26.09 330.91 4043.00 4125.00 4491.79 4245.59 -1472.70 4.00 169.10G Target 6663.33 26.00 330.95 4045.00 4127.00 4492.75 4246.45 -1473.17 4.00 -180.OOG 6700.00 24.53 330.95 4078.16 4160.16 4508.24 4260.13 -1480.77 4.00 -180.OOG Na 6723.92 23.58 330.95 4100.00 4182.00 4517.89 4268.65 -1485.51 4.00 -180.OOG Nb 6747.84 22.62 .330.95 4122.00 4204.00 4527.18 4276.85 -1490.06 4.00 -180.OOG Nc 6783.49 21.20 330.95 4155.00 4237.00 4540.31 4288.46 -1496.51 4.00 -180.OOG Ne 6789.84 20.94 330.95 4161.00 4243.00 4542.60 4290.48 -1497.63 4.00 -180.OOG 6800.00 20.53 330.95 4170.50 4252.50 4546.16 4293.62 -1499.38 4.00 -180.OOG Nf 6845.12 18.73 330.95 4213.00 4295.00 4561.16 4306.87 -1506.74 4.00 -180.OOG OA 6887.15 17.05 330.95 4253.00 4335.00 4573.94 4318.16 -1513.01 4.00 -180.OOG 6900.00 16.53 330.95 4265.30 4347.30 4577.61 4321.40 -1514.81 4.00 -180.OOG End Crv 6908.12 16.21 330.95 4273.09 4355.09 4579.88 4323.40 -1515.92 4.00 O.OOG OBa 6951.77 16.21 330.95 4315.00 4397.00 4591.94 4334.05 -1521.84 0.00 O.OOG OBb 6993.42 16.21 330.95 4355.00 4437.00 4603.45 4344.22 -1527.49 0.00 O.OOG OBc 7052.78 16.21 330.95 4412.00 4494.00 4619.84 4358.70 -1535.53 0.00 O.OOG OBd 7102.77 16.21 330.95 4460.00 4542.00 4633.65 4370.90 -1542.31 0.00 O.OOG OBe 7168.38 16.21 330.95 4523.00 4605.00 4651.78 4386.91 -1551.20 0.00 O.OOG Target 7170.46 16.21 330.95 4525.00 4607.00 4652.35 4387.42 -1551.49 0.00 O.OOG OBf 7211.07 16.21 330.95 4564.00 4646.00 4663.58 4397.33 -1556.99 0.00 O.OOG OBf Base 7261.06 16.21 330.95 4612.00 4694.00 4677.39 4409.52 -1563.77 0.00 O.OOG TD / 7" Csg 7420.46 16.21 330.95 4765.06 4847.06 4721.42 4448.42 -1585.38 0.00 O.OOG -S.y/ U./3 5y /41L1.4U SiSyULU./y N /U.:53yUtttfll W 14y.1//li4L/4 -3.96 0.87 5974174.12 588986.49 N 70.33923062 W 149 .27791603 -3.96 1.01 5974206.56 588965.61 N 70.33931991 W 149. 27808230 -3.95 1.12 5974221.72 588956.05 N 70.33936165 W 149 27815844 -3.95 1.17 5974226.26 588953.21 N 70.33937414 W 149. 27818099 -3.95 1.29 5974258.98 588933.19 N 70.33946417 W 149. 27834033 -3.94 1.44 5974264.96 588929.61 N 70.33948064 W 149 .27836877 -3.93 1.59 5974289.15 588915.49 N 70.33954718 W 149. 27848107 -3.93 1.73 5974290.00 588915.00 N 70.33954951 W 149 .27848492 -4.00 0.00 5974303.59 588907.24 N 70.33958688 W 149 .27854661 -4.00 0.00 5974312.05 588902.40 N 70.33961017 W 149. 2 4 -4.00 0.00 5974320.20 588897.74 N 70.33963257 W 149. 2 3 -4.00 0.00 5974331.72 588891.16 N 70.33966426 W 149. 27867434 -4.00 0.00 5974333.73 588890.01 N 70.33966978 W 149. 27868345 -4.00 0.00 5974336.85 588888.23 N 70.33967837 W 149 .27869763 -4.00 0.00 5974350.01 588880.71 N 70.33971457 W 149. 27875738 -4.00 0.00 5974361.22 588874.30 N 70.33974540 W 149. 27880827 -4.00 0.00 5974364.44 588872.46 N 70.33975426 W 149 .27882290 -4.00 0.00 5974366.43 588871.33 N 70.33975972 W 149 .27883192 0.00 0.00 5974377.00 588865.28 N 70.33978881 W 149. 27687994 0.00 0.00 5974387.10 588859.52 N 70.33981658 W 149. 27892578 0.00 0.00 5974401.48 588851.30 N 70.33985614 W 149. 27899109 0.00 0.00 5974413.60 588844.37 N 70.33988946 W 149. 27904609 0.00 0.00 5974429.50 588835.29 N 70.33993319 W 149. 27911828 0.00 0.00 5974430.00 588835.00 N 70.33993458 W 149. 27912057 0.00 0.00 5974439.84 588829.38 N 70.33996165 W 149. 27916526 0.00 0.00 5974451.96 588822.45 N 70.33999497 W 149. 27922026 0.00 0.00 5974490.58 588800.38 N 70.34010122 W 149.27939565 WeIlDesign Ver SP 1.0 Bld( doc40x_56) Plan V Slot (N-E)\V-2141PIan V-214\V-214 (P10) Generated 1/17/2006 1:17 PM Page 2 of 2 ~, ~ • • Schlumberger WELL V-214 (P10) FIEID Prudhoe Bay Unit - WOA STRUCTURE V-Pad MagnHic Paramalers ve tla L M1aD2] to Planas. Zone 0a US Feet e a Mecella reous Mptlel. BGGM 2005 Dip fl Date. May 05. 2d1fi Lal N)019 a0 fit6 NprlM~g: 59100fi201 !IUS Gritl Cnnv . .fifi.322' Sbl anV Slol (N-E1 ND RnI R~uary Tabin 19300fla~ove MSLI VI Mag Dec: 2a 360' FS 5>SB0.2 nT Lan W1a91559.5f6 Easling. 590x19 ~'rtUS ScabFailn 90929'a Plan 21a1Pt01 Sny Date lnuary 1T 2IX16 2500 3000 00 3500 ~n c a~ m U ~ 4000 4500 5000 2000 2500 3000 3500 4000 4500 Tie-In Survey .; ............... ..................i.................................. i. KoP crv a~oo • 4PBZ lens crv /: crv aioo .................:...................................i.................................. i................................. ............... i.................................3.................................. i................................. ..Y..-..-..-..-..-..-..-.. .i- .~..-..-..-..-..-..-.. ..-.. -.. -..-..-..-..- civ a~oo V-214P64 v-ziaps~ V-214 (P70 TD I T' Csg 2000 2500 3000 3500 4000 4500 Vertical Section (ft) Azim = 339.17°, Scale = 1(in):500(ft) Origin = 0 N/-S, 0 E/-V 2500 3000 3500 4000 4500 5000 . by • Schlumberger WELL V-214 (P10) FIELD Prudhoe Bay Unit - WOA STRUCTURE V-Pad Ma9rretic Paramalers SWace Wra9on NnD2l nlaska Stale PWws.2weOx. US Feel Miswlbneous MOEeI BGGM 2005 01p BO BC 7' Dale May 05. 2006 lal: N)019 <O.fi tfi NoriNng 006301 tU5 Grd GOnv •0.69068112' Sbt PIanV 5411N_EI TVD fteI. Rotary Ta61e 1620011 above MSL1 Ma9 Dec'. •2x.360' FS 5]560.2 nT Lon. Wtx916696t6 Ea30a9: 590x]9.11 MIS Srab Fatl: 0999909191< Plan V-2 t41P101 Srvy Dele: Janwrytt. 3006 -1800 -1500 -1200 -900 -600 -300 4500 4200 3900 3600 n n n Z `o 0 M ~ 3300 n a~ U V V ~ 3000 2700 2400 2100 TD l 7" Csg 300 -1500 -1200 -900 -600 -300 c« W Scale = 1(in):300(ft) E »> 4500 4200 3900 3600 3300 3000 2700 2400 2100 V-214i Sundry #306155 Withdrawal ~~ • Subject: V-2141 Sundry #3061.55 Withdrawal From: "Tirpack, Robert B" <Robert.Tirpack@bp.com> Date: Tue, 02 May 2006 10:43:42 -0800 To: winton_aubert@admin.state.ak.us CC: "Phillips, Ron" <Ron.Phillips@bp.com>, "Martyn, Matthew" <Matthew.Martyn@bp.com>, "Hubble, Terrie L" <Terrie.Hubble@bp.com> Winton, As per your phone message yesterday, please withdrawal V-214i Sundry #306155. We will get a second permit to drill for V-214i on the way. Regards, Rob Tirpack Senior Drilling Eng GPB Rotary 907-564-4166 office 907-440-8633 cell tirpacrb@bp.com 1 of 1 5/2/2006 11:02 AM ~ r ~ t ~ i ~ -~ j a '~ ~ !~ ~ ice; .R - .~ ~ i ~ , .tea !~~' ~-a-~ ~~ _ .yi .~ ~ ,. ' _, ~..;,~ x. ~~ t~,f a t1i4L~-7~t1 ®IL ~ R]!l1-7 COlOTSER`TATI01~1T COMNII55IO1~T Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Orion Schrader Bluff Oil Pool, BP Exploration (Alaska) Inc. Permit No: 205-134 Surface Location: 4816' FSL, 1862' FEL, SEC. 11; Bottomhole Location: 3985' FSL, 3443' FEL, SEC, Dear Mr. Tirpack: FRANK H. MURKOWSKI, GOVERNOR 333 W. 7`" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 V-214i T11N, R11E, UM 02, T11N, R11E, UM Enclosed is the approved application for permit to drill the above referenced suspended 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. This permit V-214i was originally approved on September 8, 2005 and was suspended on December 5, 2005. In accordance with 20 AAC 25.010 (b}, an approved permit to drill (form 10-401) is required before re-entering a suspened well to conduct drilling operations. This approval supersedes the original approval dated September 8, 2005. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). r i BPX Orion Schrader Bluff, V-2141 Permit No: 205-134 DATED this ~ day of May, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAIL AND GAS CONSERVATION COMM~N ~:;a"~~ PERMIT TO DRILL _ 20 AAC 25.005 ~ ~ 5 ~5 tAOG 05/03/06: Revised Permit to Drill 1 a. Type of work ` ® Drill ^Redrill ^ Re-Entry "f b. CUtrent W8N Cias~ Exploratory p Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ~ Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^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-214i 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 7420 TVD 4847 12. Field /Pool(s): Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): Surface: 4816' FSL 1862' FEL 11 T11N R11E SEC UM 7. Property Designation: ADL 028240 Schrader Bluff , , . , , , Top of Productive Horizon: 3782' FSL, 3331' FEL, SEC. 02, T11 N, R11 E, UM 8. Land Use Permit: 13. Approximate ud ate: Ma 27/`L006 Total Depth: 3985' FSL, 3443' FEL, SEC. 02, T11N, R11E, UM 9. Acres in Property: 2560 14. Distance to rest Property: 11750' 4b. Location of Well (State Base Plane Coordinates): Surface: x-590439 y-5970062 Zone-ASP4 10. KB Elevation p{an (Height above GL): g2 feet 15. Distance to Nearest Well Within Pool: 1062' 16. Deviated Wells: Kickoff Depth: 3900 feet Maximum Hole Angle: 66 de rees 17. Maximum Anticipated Pressures in psig (see 20 .035) Downhole: 2030 Surface: 57 18. Casin Pro ram: Specifications To - Settin : De th -Bottom Quanti of ent, c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-3/4" 7" 26# L-80 TCII / BTCM 7398' 22' 22' 7420' 4847' 64 sx LiteCrete, 328 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY`(To be completed' for Redril l and Re-entry Operations) Total Depth MD (ft): 7380 Total Depth TVD (ft): 4858 Plugs (measured): 3541 Effective Depth MD (ft): 3541 Effective Depth TVD (ft): 2547 Junk (measured): None Casing Length Size Cement Volume MD TVD Conductor /Structural 102' 20" 260 sx ArctiC Set A rox. 102' 102' Surface 3730' 9-5/8" 482 sx AS Lite, 682 sx Class 'G' 3757' 2640' Intermediate Production Liner Perforation Depth MD (ft): None Perforation Depth TVD (ft): None 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Matt Martyn, 564-4101 Printed Name Robert Tirpack Title Senior Drilling Engineer on i ips, 5 -5 Prepared By Name/Number: Si nature :~~' G Phone 564-4166 Date S / ~ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: 205-134 API Number: 50- 029-23275-00-00 Permit A proval Date: See cover letter for other requirements 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 shalestw Samples Req'd: ^ Yes~No Mud Log Req'd: ^ Yes ~(No HZS Measures: Y s No Directional Survey Req'd:~Yes ^ No Other: 1 LS ~ ~ t7 P L= ~'0 4-v c~ o ~ L-~ . 1~~. ~. T / C,e rvt..~ }" t~ta~; ~' ~j r u,-t t~(d . ~w ~ ~ 2s . o ~, 5 C ~ 1 c ~ 1, ~. ~ }'~' ~- ~c 13n PC ~e.s JO t~ cc '^`~, °~r 1~~~ . ~R~~D~ APPROVED B HE COMMISSIO Date ,COMMISSIONER Form 10-401 Revised 12/2005 Submit In Duplicate ORlGl~l~i~__ • • Well Name: V-2141 Well Plan Summary T e of Well roducer or in'ector : USH Injector Surface Location: 4816' FSL, 1862' FEL, Sec. 11, T11 N, R11 E Slot NE As Built X = 590,439.13 Y = 5,970,061.76 Shallow Target 174T FSL, 2135' FEL, Sec. 2, T11 N, R11 E Coordinates 9-5/8" Shoe : X = 590,136 Y = 5,972,270 Z = -2580' TVDss Target Start ASP 3782' FSL, 3331' FEL, Sec. 2, T11 N, R11 E Coordinats To Mc : X = 588,915 Y = 5,974,290 Z = -4045' TVDss BHL ASP Coordinates: 3985' FSL, 3443' FEL, Sec. 2, Ti 1 N, R11 E X = 588,800 Y = 5,974,491 Z = -4765' TVDss AFE Number: XXXXXXXXX Ri : Nabors 9ES GL; 53.1' KB: 28.5' Estimated Start Date: May 27 , 2006 O eratin da s to com lete: 10.5 TD: 7,420' MD TVD: 4,847' Max Inc: 65.8° KBE: 82.0' Well Design: I USH Grassroots Schrader Injector 3-'/z" TCII 5-Packer Completion. Current Well Information General Distance to Nearest Property: 11,750' to PBU boundary Distance to Nearest Well in Pool: 1,062' to V-102 at top OBe, 90' to V-214i P62 @ top OA API Number: 50-029-XXXXX-XX Well Type: Development -Orion Schrader Injector Current Status: Suspended well, 9-5/8" Surface casing already set, kill string hung off. Conductor: 20" X 34", 215.5 Ib/ft, A53 ERW set at 101' RKB BHP: 2030 psi -Top of OBf Sand (8.6 ppg @ 4560' TVDss) BHT: 85°F @ 4,550' TVDss estimated '/a Mile Wellbore Near Wellbore Mechanical Integrity Summary: V-102 is a Borealis well that enters the 1 /4 mile radius in all Schrader sands below the Na. The wellbore lies 1062' from V-214 at the top OBe. During cementing of V-102, no losses were noted, and assuming a 30%~ excess hole volume, Top of Cement would be expected at 3979' MD or 1190' MD above the top Ma. The only addition to this in the Schrader interval is the existence of V-214 PB#2 from the first drilling of V-2141 in 4Q, 2005. This is best shown graphically on the attached suspended completion, and directional plan maps. PB#2 extends to the Schrader OBf interval and has an 800' cement plug where PB#4 intersected PB#2 (3915'-4750' MD). The final condition of the PB#2 wellbore was discussed with Commission Staff shortly after V-2141 was suspended, and a verbal opinion was given that a replacement wellbore could be drilled nearby. Anti-Collision Issues: On a Global Scan, all wells pass BP's major risk assessment. V-214i Drilling Permit Page • Formation Markers V-2141 (Based on SOR) Est. Form. Top Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. Formation (MD) (TVD-kb) (TvDss) (Yes~No) (Psi) ( EMW) SV1 -behind surface casin Poss. Hydrates or Free Gas 1107 8.7 UG4 4246 2845 -2763 Thin coal 1242 8.7 UG4A 4321 2877 -2795 Heavy Oil betty 2825 and 3030' SS 1258 8.7 UG3 5103 3208 -3126 Heavy Oil betty 3110 and 3200' SS 1404 8.7 UGl 6029 3635 -3553 Heavy Oil betty 3710 - 3850' SS 1611 $.7 Ma 6467 3957 -3875 Heavy Oil betty 3850 - 3890' Ss 1735 8.7 Mbl 6510 3993 -3911 38039140' SS 1753 8.7 Mb2 6585 4058 -3976 Heavy Oil betty 3870-3990' SS 1782 8.7 Mc 6661 4125 -4043 Heavy Oii betty 4035-4060' SS 1820 8.7 Na 6724 4182 -4100 No 1845 8.7 Nb 6748 4204 -4122 Yes 1850 8.7 Nc 6783 4237 -4155 Yes 1870 8.7 OA 6887 4335 -4253 Yes 1670 7.6-8.3 OBa 6952 4397 -4315 Yes 1885 8.0-8.3 OBb 6993 4437 -4355 Yes 1900 8.4-8.6 OBc 7053 4494 -4412 Yes 1935 8.6-8.8 OBd 7103 4592 -4460 Yes 1750 7.6-8.3 OBe 7168 4605 -4523 Yes 2010 8.6 OBf 7211 4646 -4564 Yes 2030 8.6 OBf Base 7261 4694 -4612 No 2050 8.6 T.D. 7420 4847 -4765 CasinglTubing Program Hole Size Csg / Tb O.D. WUFt Grad a Conn Burst si Collapse si Length Top MD /TVDrkb Bottom MD /TVDrkb * 42" 20" 215.5# A-53 Welded 80' 22' / 22' 102' ! 102' * 12-'/a" 9 $~$" 40# L-80 BTC 5,750 3,090 3,728' 22' / 22' 3,758' / 2,638' 8-3/a" 7" 26# L-80 TC-II 7,240 5,410 5,236' 22' / 22' 5,258' / 3,325' 8-3/a" 7" 26# L-80 BTC-M 7,240 5,410 2,162 5,258' / 3,325' 7,420' / 4,847' Tubin 4 %z" 12.6# L-80 TCII 8,430 7,500 20' 22' / 22' 42' 142' Tubin 3'h" 9.30# L-80 TCII 10,160 10,530 7,147' 43' / 43' 7,190' 14,545' * Conductor and Surface casing have already been set. Mud Pro ram: 8 3/a" Production Hole Mud Properties: Freshwater Mud (LSND) Interval Densit Funnel Vis PV YP FL H Chlorides MBT Surface shoe to TD 8.8 - 9.3 38-50 10-16 18-24 4.0-6.0 9.0-9.5 <600 < 20 Survey and Logging Program: 8-3/a" Hole Section: MW D / GR I Res I Den / Neu / PW D (all real-time except for Den-Neu Recorded) Cased Hole: USIT Follow Primary Depth Control Procedures) /dual packer MDT V-2141 Drilling Permit Page 2 • • Bit Recommendations BHA Hole Size De the MD Bit T e Nozzles K-Revs Hours Production 8-3/a 3758' - 7420' H calo DSX619M-D2 6x14 Surface and Anti-Collision Issues Surtace Shut-in Wells: Nearb Well V-202 V-101 Distance to V-2141 14.61 15.01 V-202 & V-101 will require surface shut-in and wellhouse removal in order to move over well V-2141. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. Cement Calculations: Size: 17" 26 Ib/ft L-80 BTC-M / TC-II -Sin aasis: ~eaa: iu~' of ti.75" open Hole w~ 3v°~° excess. Lead TOC: 4,846' MD 1000' MD below 9-5l8" shoe Tail: 1,867' of 8.75" open hole with 30% excess, plus 80' shoe track Tail TOC: 5,553' MD 500' MD above tanned Mato at 6,374' MD Total Cement Volume: Wash 50 bbls CW100 > acer 50 bbls of Viscosified S acer Mud ush XT Desi n Ca3 10.0 Lead 24.6 bbls, 139 cuft, 64s 12.5 Ib/ al LiteCRETE - 2.17 cuft/sk Tail 68 bbls, 382 cuft, 328s 15.8 Ib/ al G + Gasblok -1.17 cuft/sk Temp BHST =100° F, BHCT 80° F estimated by Schlumberger Centralizer Recommendations: 7" String Centralizer Placement a) Place 2 rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. b) With the exception stated above, run 2 centralizers per joint up to6,880' MD (Top OA) by running 2 rigid straight blade centralizers separated by a stop collar in the middle of the joint. c) From 6,880' MD (top OA) to 4,850' MD (1000' MD from Surface Shoe) run 1 rigid straight blade centralizer per joint free floating. Note: Zonal isolation with cement is required across the Ma sands. The centralizer program is subject to change pending hole conditions. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi. Due to Max Anticipated WHP not exceeding 3,000psi it will not be necessary to have two sets of pipe rams installed at all times. BOP regular test frequency for V-2141 will be 14 days. Function test every 7 days. Below is an excerpt from the permit application requesting a variance to the requirements of 20 AAC 25.035 (e)(10)C PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285 (f)(2) TUBING WORKOVERS: or, 20 AAC 25.286(e)(1) WORKSTRING SERVICE OPERATIONS "BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP. ram type equipment for other than well control or equivalent purposes, exce t when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment." BOPE and drilling fluid system schematics on file with the AOGCC. V-214i Drilling Permit Page • Production Section • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 7" Casing Test: • Integrity Test - 8-3/4" hole: • Kick Tolerance: • Planned completion fluid: Disposal :] 2030 psi -Top of OBf Sand (8.6 ppg C~3 4560' TVDss) 1,575 psi -Based on a full column of gas C~1 0.10 psi/ft 4,000 psi/250 psi Rams 2,500 psi/250 psi Annular 4,000 psi 10.7 ppg minimum EMW LOT 20' from 9-5/8" shoe 51.8 bbls with an 10.7 ppg EMW LOT Estimated 9.0 ppg Brine (w/6.8 ppg Diesel freeze protect) • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. V-2141 Drilling Permit Page 4 • r Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control A. The Schrader in the Polygon 2 fault block is expected to be normal to sub-normally pressured at 7.6-8.8 ppg EMW. II. Hydrates and Shallow gas A. Gas Hydrates are present at V-pad and have been encountered in wells as close as V-100 and V-111 and throughout the SV4, SV3, SV2, and SV1. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole. Occasionally hydrates are encountered below the SVi . 111. Lost Circulation/Breathing A. We do not expect to encounter any faults while drilling this production interval of V-2141 B. Massive losses were encountered on L pad at L-118 due to high penetration rates {1100-1300 fph) and inadequate hole cleaning strategy. C. We do not expect breathing on this well. IV. Kick Tolerance/Integrity Testing A. The 9 5/" casing is in place and cemented to surface. B. The 7" casing will be cemented with 15.8 Iblgal ail to 5,553' MD and 12.5# LiteCRETE lead to 4,836' MD. C. The Kick Tolerance for the surface casing is°`51.8 kbls with 9.0 ppg mud, 10.7 ppg LOT, and an 8.8 ppg pore pressure. D. Integrity Testing Test Point Test De th Test a EMW Ib/ I 9 5/8-in shoe 20-ft minimum from 9 5/8--in shoe LOT 10.7 minimum V. Stuck Pipe A. We do not expect stuck pipe if the hole is kept adequately clean. VI. Hydrogen Sulfide V Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: o Adjacent producers at Surface: o Adjacent producers at TD: V-102 10 ppm V-201 110 ppm l V-101 10 ppm VII. Faults D. We do not expect to encounter any faults while drilling this production interval of V-2141 VIII. Anti-Collision Issues All wells pass Major Risk criteria. V-214i PB#2, PB#3, & PB#4 all lie close to the planned wp10 separating to --90' by the top OA sand. No problems are expected as PB#3 & PB#4 are filled with cement. CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION V-2141 Drilling Permit Page 5 • • V-2141-Drill and Complete Procedure Summary Pre-Rig Work: 1. If necessary, level the pad and prepare location for rig move. 2. Prepare neighboring wells for the rig move and simops production. Shut in V-101 and V-202 and remove well houses as necessary. Rig Operations: 1. MIRU Nabors 9ES. 2. Pull BPV. Circulate out freeze protection and displace well to seawat~ 3. Set TWC. Nipple down tree. Nipple up and test BOPE to 4,000 psi. Pull TWC. 4. Pull and LD 3-YZ" 9.2# tubing from 2,724' MD. 5. PU 4" DP as required and stand back in derrick. 6. MU 8-3/a" drilling assembly with MWD/GR/Res/Den(recorded)/Neu(recorded)/PWD and RIH to float collar. Test the 9-5/d' casing to 3,500 psi for 30 minutes. 7. Drill shoe track and displace over to 8.8 ppg LSND mud 8. Drill new formation to 20' below 9-5/a" shoe and perform LOT (Notify ODE if 10.7 ppg LOT is not obtained). 9. Drill ahead to Polygon 2 Target TD at --7,420' MD, (250' MD below Top OBe marker). 10. Circulate and condition hole, POOH to run casing. Perform wiper trip if hole conditions dictate. 11. Run and cement the 7" production casing as required to cover all significant hydrocarbon intervals. Displace the casing ~.- with seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Freeze protect the 7" x 9-5/a" annulus. 12. PU DPC guns and RIH w/ -130' of 4.5" Power Jet 5 spf, pert guns (total assembly leng#h to be --400') with Schlumberger LWD GR for gun correlation. Tag PBTD. Circ hole over to 9.0 brine while correlating. 13. Space out utilizing GR and RA tags in 7" casing. Once correlated correctly, fd`ently tag TD and w/ guns on bottom, circ in pert pill. Pull back to shooting depth & confirm cement compressive strength is at least 2,000 psi. Perforate Mc, OA, OBa, OBc, and OBd. POOH standing DP back. 14. RU Schlumberger E-tine. RIH with gage ring and junk basket to recover any pert debris. Repeat until clean to at least 50' below the bottom perforation (OBd pert predicted 7102'-7138'). Note: It is imperative that we have a clean wellbore so we don't damage the MDT packers while RIH. 15. Run USIT/GR log following Primary Depth Control procedures as USIT log will be primary depth control for future well /~~ work. Obtain high resolution (0.5"x5deg) repeat section over OBb interval (approx. 6,975'-7,060' MD on directional plan) 16. Transmit High-Res USIT pass to town as soon as possible for MDT Cased Hole OBb sample depth picking. 17. If cement integrity found to be suitable for MDT sampling needs, RIH and wireline perforate (GR-CCL tie in) one foot of OBb sand (depth TBD). POOH &RIH w/ MDT configured for obtaining fluid sample from OBb Sand. Depths TBD based on cement evaluation. See attached MDT operations flowchart 18. Wireline perforate the entire 08b interval after POOH w/ MDT. RD E-Line. ~ 19. RIH w/ DP to 50' below bottom perforation. Circ hole to 9# brine cleaning out any remaining pert pill. POOH laying down DP. 20. Run the 3-Yz", L-80 TCII completion with 7" x 3-YZ" straddle packer assemblies, injection mandrels, and phoenix pressure gauge. Note: Do not circulate inhibited brine down the backside yet. 21. Run in the lockdown screws and set the packers. Test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCR shear valve and pump both ways to confirm circulation ability. 22. Install FMC TWC. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 23. Freeze protect the well to 2,800 MD /-2,200' TVD by first pumping -99 BBLS corrosion inhibited seawater down the IA with rig pumps followed by -110 BBLS diesel down IA w/ Hot Oil taking clean seawater returns to surface throughout. Allow diesel to U-tube. 24. 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 /~ both protected with two barriers. 25. Rig down and move off. Post-Rig Work: 1. RJU Slickline and pull ball and rod / RHC from the tailpipe. 2. Replace the DCR shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. 5. Install wellhouse and flowlines. 0 V-214i Drilling Permit Page 6 • Variance Request {ssue Compliance with AOGCC testing requirements for BOP rams after they have been used in the normal coarse of operations. Re uest The AOGCC is in the process of developing a guideline document clarifing the intent of the regulations pertaining to function pressure testing ram type BOP's. BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a too{ joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. Background AOGCC regulations require rams that have been used in the course of primary drilling & completion, workover and through tubing drilling operations be function pressure tested before the next wellbore entry. This is not a new regulation. The intent of this regulation is to ensure that ram type equipment has integrity after it has been utilized in a wellbore...for example; to ensure integrity if a ram was closed on a tool joint. The exact regulation language is: "if BOP sealing ram type equipment has been used, it must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure;" The pertinent sections are: 20 AAC 25.035 (e)(10)C PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285 (f)(2) TUBING WORKOVERS; 20 AAC 25.286(e)(1) WORKSTRING SERVICE OPERATIONS This issue has been discussed with Winton Aubert at the AOGCC. The test requirement in the regulation is intended to apply to ram type eguiprrfent only. The AOGCC understands that ram type BOP's are utilized for purposes other than well control in the normal coarse of operations. The regulations allowing a variance are at 20 AAC 25.035(h) PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036(f) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285(h) TUBING WORKOVERS; 20 AAC 25.286(g) WORKSTRING SERVICE OPERATIONS...which says generally: 20 AAC 25.035(h)... Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the ROPE requirements in (e) of this section if the variance provides at least an equall,~ c:fecti~,•e moanc cf :~~~I ccr;:c!; TREE:~C 4-1/16" 5M V-214i Proposed Completion WELLHEAD: FMC Gen 5 System 11 ", 5M csg.head w! 7" mandrel hanger & packoff 11"x 11", SM, tbg spool w/ CeHarElevation =53.7' 1 1 " x 4-1 /2" tubing hanger Ma6ors 9ES RKB = 87.6' 1 1 " X 4-1 /16" Adaptor Flange Max Deviation 65 Deg -20 3-1 l2" x 4-1 /2" XO w/ 3' x 4-1 /2° pup to hanger 101` 20" X 34" 215.5 Ib/ft, A53 ERW Insulated 3,615 ` 9-5/8", 40 #/ft, L-80, BTC 3,758` ~ 7° Short Joint & RA Tag (2-pips) Top Ma sand (6,374`) 6,610` 6,668` Phoenix Pressure Gauge on I-Wire- 6, 695 ` 6,716` 7" Short Joint & RA Tag Above Top OA (6,790`) ~ RA Tag in 3-1 /2" 3-1/2" `X' Landing Nipple with 2.813" seal bore. 4-1 /2", 12.6 Ibfft, L-80, TCII Drift / ID : 3.833"/3.958" 3-1 /2", 9.3 Ib/ft, L-80, TCII Drift / ID : 2.867"/2.992" Camco 3-1 /2" x 1-1 /2" MMG GLM w/ - DCR-1 Shear Valve pinned to 2,500 7° x 3-1/2° HES 'AHR' Feed Through Production Packer 3-1/2" `X' Landing Nipple with 2.813" seal bore. -Camco 3-1 /2" x 1-1 /2" MMG-W GLM 7" x 3-1/2" Baker `PRM' Production Packer - 3-1 /2" `X' Landing Nipple with 2.813" seal bore. Camco 3-1/2" x 1-1 /2" MMG-W GLM 6,839` 6,867` 6,883` yips) OA 6,912` 7" x 3-1/2" Baker `PRM' Production Packer 3-1 /2" 'X' Landing Nipple with 2.813" seal bore. mco 3-1 /2" x 1-1/2" MMG-W GLM 6,936` OBa 6,957` 6,973` 3-1/2" `X' Landing Nipple with 2.813" seal bore. 7" x 3-1/2" Baker `PRM' Production Packer 3-1/2" x 1-1 /2" MMG-W GLM 7,002` 7, 016 ` 7,032` 7,049` OBC 7" x 3-1/2" Baker `PRM' Production Packer 3-1 /2" 'X' Landing Nipple with 2.813" seal bore. -Camco 3-1 /2" x 1-1/2" MMG-W GLM 3-1 /2" `X' Landing Nipple with 2.813" seal bore. 7,068` 7,087` 7,108` 7,129` 7,158` 7,179` OBd 7,189 ` 3-1 /2" WireLine Entry Guide 7,340` 7", PBTD 7,420` 7", 26 #/ft, L80, BTC-Mod 8 3/4", TD (Injector Mainbore) Date Rev By Comments 11-Apr-06 MJM Proposed Completion for wp10 02-May-06 ~ RLP ( Changed T.D. and Rig RKB V-214 i Estimated Perf Depths, 6 sands Zone MD Inc. Perf Int. Feet Mc 6690 6690-6700 10 OA 6887 16 6887-6924 37 OBa 6952 16 6952-6981 29 OBb 6993 16 6993-7009 16 OBc 7053 16 7053-7065 12 OBd 7102 16 7102-7138 36 GP,ater~'.r~r~I ~~ 8~~ WELL: V-2141 API NO: 50-029-XXXXX-XX _----- 1- -_-_ - _ _ -___---_-- E 5,172 I I GRID I 15'00 '00.. I I Z I PLANT I I I ^ V-120 ^ V-115 i I ^ V-03 ^ V-2131 I ^ V-110 ^ V-100 I ^ V-ttt V 1031 ^ V-117 I ^ - I ^ SLOT S-R I ^ V-106 I ^ V-105i ^ V-01 I ^ V-2211 1 ^ V-102 ^ V-SPARE (sLOr ~)I I ^ V-201 I ^ V-107 ^ SLOT S-J ^ V-02 0l ^ V-1041 ^ V-204 o~OI ^ V-210i ^ V-114 ~ I V-202 ^ V-119 z V-2141 ^ v-1os I V-101 I ^ V-2111 ^ V-113 I ^ V-108 I ^ V-203 I ,~/ SO`NOPLPPO ~ ~~' NOTES I I I I V-PAD '- TO SPINE ROAD - ~~ LEGEND -~- AS-BUILT CONDUCTOR ^ EXISTING CONDUCTOR 1. DATE OF SURVEY: JULY 17 & 1 S, 2004. 2. REFERENCE FIELD BOOK: W004-11 PGS. 19-26. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD-27. 4. BASIS OF HORIZONTAL CONTROL IS V-PAD OPERATOR MONUMENTATION. 5. BASIS OF ELEVATION IS KUPARUK PIPELINE CONTROL. ELEVATIONS ARE BP MEAN SEA LEVEL DATUM. 6. THE MEAN SCALE FACTOR FOR V-PAD IS 0.999909334. -1 (~' V 9 v V •0 ~ ° L-PAD e d ~~~~~ ~ e ' : o on o~~la 8 U 3 ~~o PROJECT AREA . L 0 (~o, ~ ~ ~o ,~N~ 1 6 ~ 12 ° ° d . -a 4 VICINITY MAP N.T.S. WELL V-2141 RE-NAME NOTE THIS AS-BUILT DRAWING IS A RE-ISSUE OF A PREVIOUS CONDUCTOR AS-BUILT FOR WELL V-SPARE (SLOT V-NE) DATED 7/22/04. V SPARE (SLOT V-NE) IS BEING RE-NAMED WELL V-214i. ~P~~ ~ O F ~ A `qs'~- oooooeovoooaaaveovoveovaoovooee ~'o~~Richard F. Allison , ` 10608 oe ~~~q~~,,~_ °°°~ "4't35I O-JAI- ~' SURVEYOR'S CERTIFICATE f HEREBY CERTIFY THAT 1 AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF APRIL 22, 2005. LOCATED WITHIN PROTRACTED SEC. 11, T. 11 N., R. 11 E.. UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION DMS) POSITION(D.DD) BOX ELEV. OFFSETS * V-2141 Y= 5,970,061.76 N=10,179.73 70'19'40.614" ' " 70.3279483' S3 1' 4,816' FSL ' X= 590,439.13 E= 4,690.07 149'15 59.515 149.2665319' 1,862 FEL * PREVIOUSLY NAMED V-SPARE (SLOT V-NE) o~ r. I{,ouei'L "....'FENTIE pp (~ cNE O~~I~ANLEY by 11 I II I. DATE: ~ ~~ ~~~ ~ DRAMNC: SHEET: L°JUy~I.1L{ ~ FReos wov os-oo GREATER PRUDHOE BAY V-PAD ® W~~~~o dos Na. AS-BUILT CONDUCTOR 0 4 22 O RE-NANED WELL V-SPARE SLOT V-NE TO V-21H ,A,~F I,q~ °'d1~"s ''M0 ~'"0 a'"`E''0A3 SCALE: 1 OF 1 WELL V-2141 NO. DATE RENSION BY CHK •xwow.ac wws.. ww 1"=ISO' by V-214 (P101 P Client: BP Exploretion Alaska Field: Prudhoe Bay Unit - WOA Structure I Slot: V-Pad I Plan V Slot (N-E) ~~ WHI: ~~~~' V-214 ~ Borehole: ~~ Plan V-214 UWIIAPt#: 500292327500 Survey Name I Date: V-214 (P10) /January 17, 2006 Tort I AHD 1 DDI I ERD ratio: 196.586° 14852.05 ft / 6.164 / 1.001 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Location LaVLong: N 70.32794898, W 149.26653211 Location Grid NIE YIX: N 5970062.010 ftUS, E 590439.110 ftUS Grid Convergence Angle: +0.69066322° Grid Scale Factor: 0.99990929 Schlumberger oral Survey 1 DLS Computation Method: Minimum Curvature I Lubinski Vertical Section Azimuth: 339.170° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table ND Reference Elevation: 82.00 ft relative to MSL Sea Bed 1 Ground Level Elevation: 54.00 ft relative to MSL Magnetic Declination: 24.260° Total Field Strength: 57580.233 nT Magnetic Dip: 80.847° Declination Date: May 05, 2006 Magnetic Declination Model: BGGM 2005 North Reference: True North Total Corr Mag North -> True North: +24.260° Local Coordinates Referenced To: Well Head Measured Vertical Comments Inclination Azimuth Sub-Sea TVD TVD NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section ft d de ft ft ft ft ft H00 ft d de 1100 fl de 100 ft ftUS ttUS lie-in survey 3CU/. G"I bb. /D 344. VJ ZOtSV .`J4 ZbbZ.`J4 Z"Ib4. tf/ ZZ1l. l`J -L/b.ltf 4.24 -yU .3bld U.ZZ -4.b5 b`J/ZGb`J.bU b`JUl3b.3L N /U. 333`J25'J/3 VV 14y.Z62S//'L3b KOP Crv 4/100 3900. 00 65. 78 339. 99 2619 .04 2701.04 2249. 35 2291. 64 -302 .29 3.99 95 .OOG 0.03 -4.37 5972349.63 590109.25 N 70. 33420953 W 149.26898416 4000. 00 65. 50 344. 37 2660 .31 2742.31 2340. 29 2378. 34 -330. 16 4.00 93 .19G -0.29 4.38 5972435.97 590080.34 N 70. 33444637 W 149.26921025 End Crv 4100. 00 65. 34 348. 77 2701 .93 2783.93 2430. 44 2466. 76 -351 .28 4.00 O .OOG -0.16 4.40 5972524.12 590058.16 N 70. 33468792 W 149.26938157 Crv 4/100 4150. 00 65. 34 348. 77 2722 .79 2804.79 2475. 24 2511. 32 -360 .13 0.00 -95 .91 G 0.00 0.00 5972568.58 590048.77 N 70. 33480968 W 149.26945339 4200. 00 65. 15 346. 57 2743 .74 2825.74 2520. 14 2555 .68 -369 .82 4.00 -94 .99G -0.38 -4.39 5972612.81 590038.55 N 70. 33493084 W 149.26953203 UG4 4245. 70 65. 00 344. 57 2763. 00 2845.00 2561. 33 2595. 81 -380. 15 4.00 -94. 14G -0.32 -4.40 5972652.81 590027.74 N 70. 33504049 W 149.26961582 4300. 00 64. 86 342. 17 2786 .01 2868.01 2610. 37 2642. 93 -394. 22 4.00 -93 .13G -0.25 -4.41 5972699.75 590013.10 N 70. 33516922 W 149.26973001 UG4A 4321. 15 64. 82 341. 24 2795. 00 2877.00 2629. 50 2661. 11 -400. 23 4.00 -92. 73G -0.20 -4.41 5972717.85 590006.87 N 70. 33521887 W 149.26977876 4400. 00 64. 71 337. 75 2828 .63 2910.63 2700. 81 2727 .90 -425 .21 4.00 -91 .25G -0.14 -4.42 5972784.34 589981.09 N 70. 33540134 W 149.26998140 4500. 00 64. 69 333. 33 2871 .38 2953.38 2791. 00 2810. 17 -462 .63 4.00 -89 .36G -0.02 -4.42 5972866.14 589942.69 N 70. 33562608 W 149.2702 98 4600. 00 64. 80 328 .91 2914 .06 2996.06 2880. 52 2889 .33 -506 .29 4.00 -87 .47G 0.11 -4.42 5972944.76 589898.07 N 70. 33584234 W 149.271 4700. 00 65. 04 324. 50 2956 .47 3038.47 2968. 93 2965 .01 -556 .00 4.00 -85 .60G 0.24 -4.41 5973019.83 589847.46 N 70. 33604908 W 149.271 End Crv 4727. 06 65. 13 323. 31 2967 .87 3049.87 2992. 60 2984. 84 -570 .46 4.00 O .OOG 0.32 -4.40 5973039.48 589832.77 N 70. 33610325 W 149.27115984 UG3 5103.06 65. 13 323. 31 3126. 00 3208.00 3320. 75 3258. 39 -774. 28 0.00 O. OOG 0.00 0.00 5973310.53 589625.69 N 70. 33685050 W 149.27281350 Crv 4/100 5677. 12 65. 13 323. 31 3367 .43 3449.43 3821. 75 3676 .03 -1085 .46 0.00 174 .74G 0.00 0.00 5973724.35 589309.52 N 70. 33799135 W 149.27533848 5700. 00 64. 22 323 .40 3377 .22 3459.22 3841. 64 3692 .62 -1097 .80 4.00 174 .70G -3.98 0.41 5973740.79 589296.98 N 70. 33803668 W 149.27543864 5800. 00 60. 24 323 .83 3423 .81 3505.81 3926. 86 3763 .83 -1150 .28 4.00 174 .50G -3.98 0.43 5973811.36 589243.65 N 70. 33823121 W 149.27586450 5900. 00 56. 26 324 .29 3476 .43 3558.43 4008. 94 3832 .66 -1200 .19 4.00 174 .26G -3.98 0.46 5973879.57 589192.93 N 70. 33841921 W 149.27626947 6000. 00 52. 28 324 .79 3534 .82 3616.82 4087. 46 3898 .76 -1247 .27 4.00 173 .96G -3.98 0.51 5973945.09 589145.05 N 70. 33859977 W 149.27665158 UG1 6029. 33 51. 11 324. 95 3553. 00 3635.00 4109. 77 3917. 59 -1260. 52 4.00 173. 87G -3.98 0.54 5973963.76 589131.58 N 70. 33865120 W 149.27675906 6100. 00 48. 30 325 .36 359$ .70 3680.70 4162. 05 3961 .81 -1291 .31 4.00 173 .60G -3.98 0.57 5974007.60 589100.26 N 70. 33877201 W 149.27700897 6200. 00 44. 33 325 .99 3667 .76 3749.76 4232. 35 4021 .51 -1332 .09 4.00 173 .16G -3.97 0.64 5974066.80 589058.77 N 70. 33893508 W 149.27733990 WeIlDesign Ver SP 1.0 Bld( doc40x_56) Plan V Slot (N-E)\V-214\Plan V-214\V-214 (P10) Generated 1/17/20061:17 PM Page 1 of 2 Measured Vertical Comments Inclination Azimuth Sub-Sea TVD TVD NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth SecOon ft d de ft ft ft ft ft de 1100 ft de de 1100 ft de 1100 ft ftUS ftUS Ma Mb1 M62 Mc Target Na Nb Nc Ne Nf OA End Crv Oea OBb OBc OBd Oee Target OBf OBf Base TD / 7" Csg (i3UU.UU 6400.00 6467.16 6500.00 6510.03 6585.51 6600.00 6661.11 6663.33 6700.00 6723.92 6747.84 6783.41 6789.84 6800.00 6845.12 6887.15 6900.00 6908.12 6951.77 6993.42 7052.78 7102.77 7168.38 7170.46 7211.07 7261.06 7420.46 4U.3ti 36.39 33.74 32.44 32.04 29.06 28.49 26.09 26.00 24.53 23.58 22.62 21.20 20.94 20.53 18.73 17.05 16.53 16.21 16.21 16.21 16.21 16.21 16.21 16.21 16.21 16.21 16.21 31Fi. / 3 327.59 328.27 328.64 328.76 329.73 329.94 330.91 330.95 330.95 330.95 330.95 330.95 330.95 330.95 330.95 330.95 330.95 330.95 330.95 330.95 330.95 330.95 330.95 330.95 330.95 330.95 330.95 WeIlDesign Ver SP 1.0 Bld( docAOx_56 ) 3/41.66 3tf23.66 41yS.U1 4U77.5/ -1369.4U 4.UU 17'L .6"LG 3820.04 3902.04 4358.72 4129.71 -1403.08 4.00 171 .94G 3875.00 3957.00 4396.55 4162.39 -1423.57 4.00 171. 39G 3902.52 3984.52 4414.17 4177.67 -1432.95 4.00 171 .08G 3911.00 3993.00 4419.43 4182.24 -1435.72 4.00 170. 98G 3976.00 4058.00 4457.22 4215.21 -1455.36 4.00 170. 14G 3988.70 4070.70 4464.10 4221.23 -1458.86 4.00 169 .96G 4043.00 4125.00 4491.79 4245.59 -1472.70 4.00 169. 10G 4045.00 4127.00 4492.75 4246.45 -1473.17 4.00 -180 .OOG 4078.16 4160.16 4508.24 4260.13 -1480.77 4.00 -180 .OOG 4100.00 4182.00 4517.89 4268.65 -1485.51 4.00 -180. OOG 4122.00 4204.00 4527.18 4276.85 -1490.06 4.00 -180. OOG 4155.00 4161.00 4170.50 4213.00 4253.00 4265.30 4273.09 4315.00 4355.00 4412.00 4237.00 4540.31 4243.00 4542.60 4252.50 4546.16 4295.00 4561.16 4335.00 4573.94 4347.30 4577.61 4355.09 4579.88 4397.00 4591.94 4437.00 4603.45 4494.00 4619.84 4542.00 4633.65 4605.00 4651.78 4607.00 4652.35 4646.00 4663.58 4694.00 4677.39 4288.46 -1496.51 4290.48 -1497.63 4293.62 -1499.38 4306.87 -1506.74 4318.16 -1513.01 4321.40 -1514.81 4323.40 -1515.92 4334.05 -1521.84 4344.22 -1527.49 4358.70 -1535.53 4370.90 -1542.31 4386.91 -1551.20 4387.42 -1551.49 4397.33 -1556.99 4409.52 -1563.77 4.00 -180.OOG 4.00 -180.OOG 4.00 -180.OOG 4.00 -180.OOG 4.00 -180.OOG 4.00 -180.OOG 4.00 O.OOG 0.00 O.OOG 0.00 O.OOG 0.00 O.OOG 0.00 O.OOG 0.00 O.OOG 0.00 O.OOG 0.00 O.OOG 0.00 O.OOG 4460.00 4523.00 4525.00 4564.00 4612.00 4765.06 4847.06 4721.42 4448.42 -1585.38 0.00 O.OOG Plan V Slot (N-E)\V-214\Plan V-214\V-214 (P10) -3.y/ U.l3 5yl41"LL.4U btSyU'LU./y N /U.33yUtStS'Ll W 14y .17/64"L74 -3.96 0.87 5974174 .12 588986.49 N 70.33923062 W 149 .27791603 -3.96 1.01 5974206. 56 588965.61 N 70.33931991 W 149. 27808230 -3.95 1.12 5974221 .72 588956.05 N 70.33936165 W 149 .27815844 -3.95 1.17 5974226. 26 588953.21 N 70.33937414 W 149. 27818099 -3.95 1.29 5974258. 98 588933.19 N 70.33946417 W 149. 27834033 -3.94 1.44 5974264 .96 588929.61 N 70.33948064 W 149 .27836877 -3.93 1.59 5974289. 15 588915.49 N 70.33954718 W 149. 27848107 -3.93 1.73 5974290 .00 588915.00 N 70.33954951 W 149 .27848492 -4.00 0.00 5974303 .59 588907.24 N 70.33958688 W 149 .27854661 -4.00 0.00 5974312. 05 588902.40 N 70.33961017 W 149. 2 -4.00 0.00 5974320. 20 588897.74 N 70.33963257 W 149. 7 27 -4.00 0.00 5974331. 72 588891.16 N 70.33966426 W 149. 27867434 -4.00 0.00 5974333. 73 588890.01 N 70.33966978 W 149. 27868345 -4.00 0.00 5974336 .85 588888.23 N 70.33967837 W 149 .27869763 -4.00 0.00 5974350. 01 588880.71 N 70.33971457 W 149. 27875738 -4.00 0.00 5974361. 22 588874.30 N 70.33974540 W 149. 27880827 -4.00 0.00 5974364 .44 588872.46 N 70.33975426 W 149 .27882290 -4.00 0.00 5974366 .43 588871.33 N 70.33975972 W 149 .27883192 0.00 0.00 5974377. 00 588865.28 N 70.33978881 W 149. 27887994 0.00 0.00 5974387. 10 588859.52 N 70.33981658 W 149. 27892578 0.00 0.00 5974401. 48 588851.30 N 70.33985614 W 149. 27899109 0.00 0.00 5974413. 60 588844.37 N 70.33988946 W 149. 27904609 0.00 0.00 5974429. 50 588835.29 N 70.33993319 W 149. 27911828 0.00 0.00 5974430 .00 588835.00 N 70.33993458 W 149. 27912057 0.00 0.00 5974439. 84 588829.38 N 70.33996165 W 149. 27916526 0.00 0.00 5974451. 96 588822.45 N 70.33999497 W 149. 27922026 0.00 0.00 5974490.58 588800.38 N 70.34010122 W 149.27939565 Generated 1/17/2006 1:17 PM Page 2 of 2 by • Schlumberger 'NELL V-214 (P10) FIELD Prudhoe Bay Unit - WOA STRUCTURE V-Pad Magnellc Paramelen Surlace L n~bn NAD2] NaaMa S~a~e Planes. Zune [b. US Fml Mscellare ouv Motlar. BGGM 1005 Dlp H Dare. May 05. 1008 lar N]019 d0 B16 nM1irg 59 ]OOF101 SUS Gntl Dnnv ~0 F90FFJ21" SbT. PMnV SIOI (N~E~ ND RaI RMary TaUle IF]OOM1 abova MSLI Mag Dec. ad 180' FS: 5]5801 nT Lon. W1d9 ~5595tfi Eaaunq. 59(M391'ItUS Scale Fad 099990929 rd PMn V~216 IP 101 Srvy Darn Jarxary l] 200fi 2500 3000 °ov 3500 u'> C N f0 U ~ 4000 4500 5000 3000 3500 4000 4500 2000 2500 ~._.._.._.._.._.._.._.._...t.._.._.._.._.._.._.._.._..r.._.._.._.._.._.._.._.._..~.._.._.._.._.._.._.._.._.~_.._.._.._.._.._.._.._.. _.; .~a._.._.._.._.._ ~.~..~..-..-..-..-..~..-..r..~..~..~..~..-..-..-..-..*..-..-..-..-..~..~..~..~..~..~..~..~..~..~..-..-..-.j... ~..-..~..-.. ~..-.. ~.. ~.} •. .-..-..-..-.. B6" i.-..-..-..-..-..-.._.._..~.._.._.._.._.._.._.._.._.....-..-.._.._.._........-.....-..-..-..-.._.._.._.._.:_.._.._.._.._.._..-....._.i_.. t ~a.._.. Tug t.. . . ... ... .. ~'.~.._.._..~..~..~..~..~. ~.._.._.._.._.._..- ~- - -..~..~.._.._.._..~..~ _.._.._.._.._..~. ~..~ .~..~. ~..~..~..~..~.._ _.._ _ ~e~ .._.._.._ ~i.-.....-..-..-..-..-.....-i..-..-..-..~..~..~..-..-..: Bf .. BfBase V-214pB2 V-214 (P70 TD I T' Csg 2000 2500 3000 3500 4000 4500 Vertical Section (ft) Azim = 339.17°, Scale = 1(in):500(ft) Origin = 0 N/-S, 0 Fr-V 2500 3000 3500 4000 4500 5000 b , y Schlumberger WELL V-214 (P10) FIELD Prudhoe Bay Unit - WOA STRUCTURE V-Pad Mayneu~ Pa,amela~: s~na~a L o~oon NnD2r aasw slala PMrea. zone a. us Faal ruxellanaws Motel BGGM 2005 Di0 8086)' OMe MaY 05. 3008 Lal N)0'9 a06t6 NoltNng 6910083 of M1U9 GrM DOnV. ~0.69p6fiJ22' Slol: PIanV 9bl (N-Ei NO Ren. Rosary Ta51e 1830011 a0ova MSLI Mag Oec. v26 360° FS 5]560 3 ni Lon Wt<9 15 59.516 Easang: 590aJ9.1t MIS 9~'ale Fact: 0 99990929~a Plan V~31<IP i01 Srvy Dale January l], 3008 -1800 -1500 -1200 -900 -600 -300 4500 4200 3900 3600 n n Z 0 0 M ~ 3300 u a~ v v ~ 3000 2700 2400 2100 TD/7" c ................................ cry u~oo :....... .......... ........... 4500 4200 3900 3600 3300 3000 2700 2400 2100 300 -1500 -1200 -900 -600 -300 c« W Scale = 1(in):300(ft) E »> • BP Alaska Anticollision Report -- - - - 'i Company: BP Amoco Date: 1/17/2006 Time:. 11:15:38 ' Field: Prudhoe Bay Keference Site: PB V Pad Ca-ordinate(NE) Reference: Reference Well: V-214 Vertical (T'VDj Reference:: i Reference Wellpath: Plan V-214 r NO GLOBAL SCAN. Using user defined selection & scan criteria Reference: Interpolation Method: MD Interval: 20.00 ft Error Model: ' Depth Range: 3900.00 to 7420.46 ft Scan Method: ' Maximum Radius:10000.00 ft i-__ - - _ Error Surface: Survey Program for Definitive Wellpath Date: 1/17/2006 Validated: No Planned From To Survey ' ft ft ~ --___ __ i 103.20 173.20 _._-- _ ___ - - V-214PB1 GyroData (103.20-954. I, 267.20 454.20 V-214P62 GyroData (267.20-454. 491.15 3807.21 V-214P62 IIFR (491.15-7312.15) 3807.21 7420.46 Planned: Plan #10 V1 Casing Points MD TV17 Diameter Hole Size Name ft ft in in ' 3761.20 2643.66 9.625 12.250 9 5/8" 7420.46 4847.07 7.000 8.750 7" Summary -. - -- - - - _ <_.___s - -Offset Wellpath _ -------> Site Weli Wellpath F -- - - PB V Pad - -- - -- Plan V-112 (S-A) .- - -- __: __ Plan V-112 V2 Plan: PI PB V Pad Plan V-203 (N-A) Plan V-203L1 OBd V4 PI PB V Pad Plan V-203 (N-A) Plan V-203L2 OBb V2 PI PB V Pad Plan V-203 (N-A) Plan V-203L3 Oba V2 PI j PB V Pad Plan V-203 (N-A) Plan V-203L4 OA V2 Pla PB V Pad Plan V-203 (N-A) V-203 V14 Plan: Plan # ', PB V Pad Plan V-205 (S-P) Plan V-205 V2 Plan: PI PB V Pad Plan V-206 (S-S) Plan V-206 V1 Plan: PI I PB V Pad Plan V-3a06 (S-U) Plan V-3a06 V1 Plan: P PB V Pad V-01 V-01 V15 ~~, PB V Pad V-02 V-02 V12 PB V Pad V-03 V-03 V7 PB V Pad V-100 V-100 V7 PB V Pad V-101 V-101 V7 PB V Pad V-102 V-102 V5 ' P8 V Pad V-103 V-103 V6 PB V Pad V-104 V-104 V13 PB V Pad V-105 V-105 V13 ~I PB V Pad V-106 V-106 V10 I PB V Pad V-106 V-106A V9 !, PB V Pad V-106 V-106AP81 V6 PB V Pad V-106 V-106AP62 V2 !, PB V Pad V-106 V-106AP63 V2 ~ PB V Pad V-107 V-107 V5 j PB V Pad V-108 V-108 V7 PB V Pad V-109 V-109 V2 PB V Pad V-109 V-109P81 V5 PB V Pad V-109 V-109P62 V2 PB V Pad V-111 V-111 V25 ' PB V Pad V-111 V-111PB1 V8 PB V Pad V-111 V-111 P82 V2 PB V Pad V-111 V-111 PB3 V6 PB V Pad V-113 V-113 V6 PB V Pad V-114 V-114 V5 ', PB V Pad V-114 V-114A V4 PB V Pad V-114 V-114APB1 V4 ' PB V Pad V-114 V-114APB2 V2 PB V Pad V-115 V-115 V5 ', PB V Pad V-115 V-115PB1 V4 PB V Pad V-117 V-117 V9 ~PB V Pad V-117 V-117PB1 V6 Offset Ctr-Ctr No-Go 111owable MD Distance Area Deviation Warning' ft - ft ft ; ft : ~ 5580.00 3303.17 79.34 3223.83 Pass: Major Risk 8920.00 1210.61 No Offset Errors 8840.00 1245.00 138.25 1106.75 Pass: Major Risk ' 8820.00 1248.17 137.84 1110.33 Pass: Major Risk 8840.00 1251.37 134.99 1116.38 Pass: Major Risk 8920.00 1216.88 143.54 1073.34 Pass: Major Risk Out of range Out of range Out of range Out of range Out of range 7200.00 4783.28 63.$3 4719.45 Pass: Major Risk Out of range 4860.00 2528.60 93.16 2435.43 Pass: Major Risk 4020.00 613.79 65.24 548.55 Pass: Major Risk 4500.00 1542.65 96.81 1445.85 Pass: Major Risk 4760.00 2253.94 87.23 2166.71 Pass: Major Risk ', 4740.00 1495.35 69.$3 1425.52 Pass: Major Risk !, 4520.00 1400.81 86.24 1314.57 Pass: Major Risk ', 4300.00 1122.52 71.77 1050.75 Pass: Major Risk 4300.00 1122.52 71.79 1050.74 Pass: Major Risk 4300.00 1122.52 71.77 1050.76 Pass: Major Risk j 4300.00 1122.52 71.77 1050.75 Pass: Major Risk 5580.00 3102.73 58.13 3044.60 Pass: Major Risk 6460.00 4817.90 101.08 4716.82 Pass: Major Risk Out of range Out of range- '~ Out of range ~~, 7040.00 4267.79 56.04 4211.75 Pass: Major Risk 6700.00 4082.01 51.78 4030.23 Pass: Major Risk 6660.00 4091.58 50.00 4041.57 Pass: Major Risk 7040.00 4267.79 56.04 4211.75 Pass: Major Risk ', 5460.00 3342.77 95.08 3247.69 Pass: Major Risk Out of range Out of range ' Out of range Out of range Out of range ', Out of range Out of range Out of range Version: 1 Well: V-214, True North V-214 Plan 82.0 Page: t Dh: Oracle Principal Plan i3< PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing _._ _- _', Toolcode Tool Name GYD-CT-DMS Gyrodata cont.drillpipe m/s GYD-CT-DMS Gyrodata cont.drillpipe m/s ' MWD+IFR+MS MWD +IFR + Multi Station ' MWD+IFR+MS MWD +IFR + Multi Station .Reference MD ft 3900.00 7394.64 7268.45 7242.13 7176.60 7327.77 4138.15 3900.00 3908.37 4113.22 3900.00 3930.56 3900.06 3905.73 3905.73 3905.73 3905.73 3900.00 3900.00 3922.16 3910.11 3909.51 3922.16 3900.00 BP Alaska Anticollision Report Company:. BP Amoco _- Date: 1/1.1/2006 Time: 11:15:38 - - Pale: 2 - Field: Prudhoe Bay Reference Site:: , PB V Pad Co-ordinute(NE) Reference: Well: V-214, True North R'eferenceWell: V-214 Verrical('fVD)Reterence: V-214P{6n82.0 Reference Wellpath: Plan V-214 Dh: Oracle Summary <~---- -Offset Wellpath - ~ Reference Offset CtrCtr Vo-Go Allorva~le 'i Site Well. Wellpath MD MD Distance .Area Deviation Warning ft ft ft ft ft ', PB V Pad V-117 V-117PB2 V6 Out of range ', PB V Pad V-119 V-119 V13 Out of range PB V Pad V-120 V-120 V5 4150.00 4760.00 2359.41 97.60 2261.81 Pass: Major Risk PB V Pad V-201 V-201 V8 12899.06 5271.40 2421.11 94.08 2327.04 Pass: Major Risk ! PB V Pad V-202 V-202 V9 5432.82 6620.00 1418.72 75.11 1343.61 Pass: Major Risk PB V Pad V-202 V-202L1 V5 5429.72 6680.00 1276.48 75.12 1201.36 Pass: Major Risk PB V Pad V-202 V-202L2 V5 5401.45 6660.00 1235.57 74.15 1161.43 Pass: Major Risk 'i PB V Pad V-204 V-204 V2 4200.00 7460.00 2797.66 83.79 2713.87 Pass: Major Risk PB V Pad V-204 V-204L1 V2 4150.00 7500.00 2819.64 85.01 2734.62 Pass: Major Risk i PB V Pad V-204 V-204L1 P61 V6 4150.00 7500.00 2819.64 85.01 2734.62 Pass: Major Risk ', PB V Pad V-204 V-204L2 V2 4148.05 7320.00 2725.80 84.47 2641.33 Pass: Major Risk PB V Pad V-204 V-204L2P61 V5 Out of range PB V Pad V-204 V-204L3 V3 4140.60 7360.00 2672.97 84.44 2588.53 Pass: Major Risk PB V Pad V-204 V-204PB1 V9 Out of range ' PB V Pad V-204 V-204PB2 V2 4200.00 7460.00 2797.66 83.79 2713.87 Pass: Major Risk PB V Pad ' V-210 V-210 V9 4701.98 4620.00 119.23 80.37 38.85 Pass: Major Risk ~ PB V Pad V-211 V-211 V5 3900.00 4000.00 1348.79 101.13 1247.66 Pass: Major Risk ' PB V Pad V-212 V-212 V7 Out of range PB V Pad V-213 V-213 V5 4165.59 5640.00 3206.57 95.68 3110.89 Pass: Major Risk PB V Pad V-213 V-213PB1 V5 4170.93 5920.00 3543.58 101.09 3442.49 Pass: Major Risk PB V Pad V-214 V-214P61 V2 Out of range !, PB V Pad V-214 V-214PB2 V3 3963.56 3960.00 2.75 102.85 -100.10 FAIL: Major Risk PB V Pad V-214 V-214PB3 V5 4043.36 4040.00 3.09 101.63 -98.54 FAIL: Major Risk PB V Pad V-214 V-214P64 V2 3943.60 3940.00 1.49 100.16 -98.67 FAIL: Major Risk PB V Pad ~ V-216 V-216 V8 3943.21 4200.00 1207.35 90.57 1116.78 Pass: Major Risk ' PB V Pad V-221 V-221 V6 4126.11 4500.00 1668.67 101.17 1567.50 Pass: Major Risk Field: Prudhoe Bay I' Site: PB V Pad Well: V-214 Wellpath: Plan V-214 -158 100 0 l00 n Travelling Cylinder Azimu[h (TF'O+AL1) [deg vs Centre to Centre Separation [100Nin~ • TERRIE L NUBBLE BP EXPLORATION. AK INC "Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 PAY TO THE ORDER OF ( l.J lRJ a First ational Bank Alaska Anchorage/, AK 99501 MEMO V ~~ as-sip zsz 268 DATE ~~^lj'7~ ti0 $-~~'~ ~~" ° ~~, ~: L 25 200060:99 i4~~~6 2 27~~~ ~ 55611' 0 268 • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ f~~~~l PTD# „2 s6s f ~ `~ Development ~ ervice Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception, assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of welly until after (Compan~Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~Com any Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C: \j ody\transmittal_checkl ist .WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, ORION SCHR BL OIL640135 _ _ Well Name: PRUDHO_E BAY_UNGRIN V-2.14. __Program SER __ _____ Well bore seg ,___. PTD#:2051340 Company BP EXPLORATION_(ALASKA~ INC ______ _______- ___ __ __ Initial ClasslType _SER /_W_AGIN_ GecArea 890 ___ _ Unit 11650.__.., _. _ _ On1Off Shore On_____. Annular Disposal ~~ '. Administration 11 Permit fee attached _ Yes ~2 Lease.numper appropriate - Yes 3 Unique well-name and number _ Yes i4 Well located in a defined pool.... - - - -- - - - . Yes ~,5 Well located proper distance from-drilling unit_boundary- - Yes 16 Well located proper distance from_ other wells. _ _ _ _ - _ - Yes '7 Sufficient acreage available ndrilling. unit_ _ - .. - _ _ _ Yes 8 If deviated, is-wellbore plat_included _ _ ___ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 19 Operator only affected party- - - - - - - - - _ Yes I10 Operator has appropriate bond in force _ Yes 11 Permit_can be issued without conservation order_ - - Yes 12 Permit_can be issued without administ[aiiv_e_approyal - - - Yes ~( ~(`''~~ ^ /f Appr Date ,13 Can permit be approved before 15-day wait_ Yes ~~,, ~, V ~ `F~ ' / RPC 515!2006 14 Well located within area and strata authorized by Injection Order# (put 10~ in_comments)_(For Yes ~~~ J '15 All wells within 1/4_mile area of review identified (For service welt only) ll l Yes V-102 / ~ 16 on y) _P_re-produced injector: duration of pre production less than_ 3 months-(For service we NA Ida i ACMPfindmg of Consistency-has been issued_fo[this project- - NA_ 18 1 Conductor stung provided _ _ _ _ _ Yes ----_ - -- _-- 20" @102' Engineering , 19 X Surface casing protects all known_ USDWs Yes 120 CMT_vol_adequate to circulate on conducto[& surf_csg - Yes Adequate excess. 29 CMT_vol_ adequate_to tie-in long string to surf csg_ No_ '~22 CMT will cover all known produciiye horizons_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ___ _ _ Yes _ 23 Casing designs adequate for C, T, B &_permafrost_ _ - - _ _ _ _ _ _ _ _ Yes 24 Adequate tankage or reserve pit _ _ Yes Nabors 9E$.- I 25 If a-re~lrill, has_a 10-403 for abandonment been approved NA_ Suspended well....... I ' 26 Adequate wellbore separationp[oposed _ Yes i '27 If diverter required., does it inset regulations.. Yes ',28 Drilling fluid program schematic & equip list adequate Yes Max MW 9,5 ppg. Appr Date 'i29 BOPEs, do they meet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - WGA 5/512006 ~I,30 BOPE_press rating appropriate; test t_o_(put prig in comments)_ - - . - - - Yes Test to 4000_ psi. M$P 1575 psi.. 31 Choke.manifold complies wlAPl RP-53 (M_ay 84)- _ - . - _ _ _ _ Yes _ _ '32 Work will occur without op@ration shutdow_n_ _ - _ _ - - _ _ _ _ _ _ _ _ _ . - - _ _ _ _ _ _ Yes ',33 Is presence_of H2S gas_probable Yes - 110_Ppm, _ _ '3~ Mechanical conddion of wells within AOR yerifed (For semce well only) Yes All wells within AOR reviewed. 35 Permit-can be issued wlo hydrogen sulfide measures - _ Yes Geology {,36 Data_presented on potential overpressure zones NA j37 Seismic analysis_of shallow gas zones_ _ _ - NA_ - _ Appr Date 38 Seabed condition survey_(if off-shore) - - - - - - NA. RPC 5!5!2006 i39 Contact namelphone for weekly.plogress reports_[explorakoryouly] NA_ Geologic Engineering Commissioner: ~ (~ Dater Commissioner: S J ~ ~ CPF P Date C issio Date ,~'' ~ ".- Q~ • i ~cEivE~~ STATE OF ALASKA ALAS IL AND GAS CONSERVATION COM~ION FEB 0 7 2006 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas Cons. Corr~r>ASS`iol't Anchorage 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned 2oAAC2s.,os ^ GINJ ^ WINJ ^ WDSPL No. of Completions ®Suspended ^ WAG 20AAC25.110 Zero Other 1b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 12/1/2005 12. Permit to Drill Number 205-134 305-370 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/29/2005 13. API Number 50-029-23275-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 11/11/2005 14. Well Name and Number: PBU V-2141 4816 FSL, 1862 FEL, SEC. 11, T11 N, R11 E, UM Top of Productive Horizon: 3764' FSL, 3421' FEL, SEC. 02, T11 N, R11 E, UM g, KB Elevation (ft): 78.8' 15. Field /Pool(s): Prudhoe Bay Field / Orion Schrader Bluff Total Depth: 3903' FSL, 3526' FEL, SEC. 02, T11 N, R11 E, UM 9. Plug Back Depth (MD+TVD) 3541 + 2547 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 590439 y- 5970062 Zone- ASP4 10. Total Depth (MD+TVD) 7380 + 4858 Ft 16. Property Designation: ADL 028240 _ TPI: x- 588825 y- 5974271 Zone- ASP4 Total Depth: x- 588718 Y- 5974408 Zone- ASP4 11 • Depth where SSSV set None MD 17. Land Use Permit: - -------- k f P f 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL ness o erma rost 20. Thic 1900' (Approx.) 21. Logs Run: MWD / GR, MWD / GR / RES /DEN / NEU / PWD 2. ASING, LINER AND EMENTING RECORD CASING ErnNCi EPTH MD ETTINO EPTN TVD .HOLE AMOUNT $IZE WT. PER FT. GRADE OP TTOM OP TTOM SIZE CEMENTING RECORD PULLED 20" 215.5# A-53 Surface 102' Surface 102' 42' 60 sx Arctic Set A rox. 9-5/8" 40# L-80 27' 3757' 27' 2640' 12-1/4" 82 sx AS Lite, 682 sx Class 'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) None 3-1/2", 9.2#, L-80 Kill String 2752' None MD TVD MD ND 25: ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 3820' Plugs #1-#3: 116 Bbls, 95 Bbls, 33 Bbls of Class 'G' 3800' Plu s #4-#5: 50 Bbls, 70 Bbls of Class 'G' 3541' Plu #6: 22 Bbls Class 'G' Freeze Protect w/ 200 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Suspended Well Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of Submit core chips; None -":_ 5. ..'^ yy ~~ .ii t a lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). if none, state "none". ~,l ._.. _ t S ~F~ ~~~ 0 ~ 2QQ~ `~ ~ . O 1 ~~ z Form 10-407 Revised ~ 1212003 ~ ~ ~ ~ ~ ! ~~TINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS 29' , OAMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 4229' 2842' None Ugnu MA 6403' 3953' Ugnu MBi 6447' 3990' Ugnu MB2 6522' 4055' Ugnu MC 6597' 4121' Schrader Bluff NA 6661' 4179' Schrader Bluff NB 6684' 4200' Schrader Bluff NC 6721' 4234' Schrader Bluff OA 6826' 4333' Schrader Bluff OBa 6890' 4394' Schrader Bluff OBb 6933' 4434' Schrader Bluff OBc 6992' 4490' Schrader Bluff OBd 7044' 4539' Schrader Bluff OBe 7110' 4602' Schrader Bluff OBf 7154' 4643' Base Schrader Bluff 7204' 4691' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore ing is true and correct to the best of my knowledge. /~ Signed Terris Hubble ~ Title Technical Assistant Date V ~Z O PBU V-2141 205-134 305-370 Prepared ey Name/Number.• Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Dolling Engineer: MaftMarl`yn, 564-4101 INSTRUCTIONS GeNeaA~: 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 28: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 12!5/2005 11:08:51 AM BP EXPLORATION Operations Summary Report Legal Well Name: V-214 Page 1 of 24 Common Well Name: V-214 Spud Date: 10/29/2005 Event Name: DRILL+COMPLETE Start: 10/25/2005 End: 12/1/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: Date From - To Hours ' Task Code I NPT I Phase ! Description of Operations 10/26/2005 10:00 - 17:30 7.50 MOB P Secure Derrick, Move Rig Off of Mats and Clear Area. Move Doyon 16 From S-Pad to V-Pad. 17:30 - 18:30 1.00 MOB P Remove Rear Booster Assembly 18:30 - 00:00 5.50 BOPSU P Nipple Up BOPE and Stand on Cellar Pedestal 10/27/2005 00:00 - 03:30 3.50 MOB P Lay Mats and Herculite Around V-214. Prep Derrick to Raise 03:30 - 06:00 2.50 MOB P Hold PJSM for Raising Derrick, Drawworks Powering Out, Troubleshoot Drawworks/SCR. Raise Derrick. 06:00 - 08:00 2.00 MOB P Set Surface Hydril onto Conductor. 08:00 - 09:30 1.50 MOB P Spot Rig on Well V-214. Level Rig 09:30 - 12:00 2.50 MOB P R/U Floor Tighten Bolts on Surface Hydril 12:00 - 15:00 3.00 MOB P Spot #4 Motor Module in Place. Spot #2 Mud Pump Module in Place 15:00 - 17:00 2.00 MOB P Drill Site Maintenance Removed Ladder and Moved 3 Wellhouses for clearance for Divertor Line and Pits Module 17:00 - 18:00 1.00 MOB P Spot Mud Pits Module and Cuttings Tank 18:00 - 22:00 4.00 MOB P R/U Divertor Line Onto Surface Hydril. Install Weight System/Stand on Divertor Line. 22:00 - 00:00 2.00 MOB P Bridal Down and Hang Bridal Lines in Derrick 10/28/2005 00:00 - 12:00 12.00 MOB P Hook Up Lines To Modules, Hook Up Top Drive and Compensator. Chip Ice Out of Pits and C/O Pits, Put #2 Mud Pump Together. Lower Riser Down Through Rotary Table and Air Up Boots. Chain Riser Down To Hydril, Put Turn Buckles On. Work on Top Drive, Install Bails. Rig Accepted C 09:00 Hrs. 12:00 - 16:00 4.00 MOB P Continue To Work On Top Drive. Install Clamps On Bails. 16:00 - 17:00 1.00 MOB P Test Surface Lines In Pits, Install Shaker Screens. 17:00 - 18:00 1.00 MOB P Replace Air Fitting on Low Drum Clutch for Drawworks. 18:00 - 20:00 2.00 MOB P Function Test Diverter System, Perform Accumulater Test. Test Observed by John Spalding, AOGCC. 20:00 - 21:00 1.00 MOB P Test Mudlines and Pumps. 21:00 - 22:00 1.00 DRILL P Install Mousehole in Table and R/U to Pickup and Rack Back 4" Drill Pipe. 22:00 - 00:00 2.00 DRILL P Pickup 4" Drillpipe From Pipeshed. 10/29/2005 00:00 - 05:00 5.00 DRILL P SURF Continue to Pick Up 4" Drillpipe From Pipeshed and Stand Back In Derrick. 05:00 - 08:00 3.00 DRILL P SURF P/U 20 Joints of HWDP, Jars and 3 Flex Collars 08:00 - 12:00 4.00 DRILL P SURF M/U BHA. BHA= Bit (Hughes MXL-1, 3x18 1x16), 8" Sperry Drill Lobe 6/7, Sleeve Type Stablizer, 8" DGWD 650 System, NM Float Sub, NM UBHO Sub. 12:00 - 12:30 0.50 DRILL P SURF Upload MWD Tool. 12:30 - 13:30 1.00 DRILL P SURF R / U Gyro Survey Equipment. 13:30 - 14:00 0.50 DRILL P SURF Fill Riser and Check for Leaks, Held Pre-Spud meeting with Co-Man, Toolpusher, Rig Crew and Service Personnel 14:00 - 00:00 10.00 DRILL P SURF Tag @ 102'. Drill 12 1/4" Hole From 102' To 580'. Run Gyro Survey Every Connection. Up Wt. 70,000, Dn Wt. 65,000 Rot Wt. 65,000, 40-70 RPM, Torque 2500 fUlbs off bottom, 3000 ft/Ibs on bottom 550 gpm 1400 psi on bottom 1320 psi off bottom. WOB 10,000 Ibs - 17,000 lbs. 10/30/2005 00:00 - 07:30 7.50 DRILL P SURF Drill 12.25" Hole from 580' to 1006'. Up Wt. 72,000, Dn Wt. 67,000 Rot Wt. 67,000, 40-70 RPM, Torque 2500 ft/Ibs off bottom, 3000 ft/Ibs on bottom 500 gpm 1400 psi on bottom 1320 psi off bottom. WOB 10,000 Ibs - 17,000 Ibs. Motor not yielding required build rates, slowed pump rate from 550 gpm Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Page 2 of 24 Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date ~ From - To Hours ~' Task ~ Code ~ NPT 10/30/2005 00:00 - 07:30 ( 7.50 DRILL P 07:30 - 10:30 3.00 DRILL N DPRB 10:30 - 12:00 1.50 DRILL N DPRB 12:00 - 14:30 2.50 DRILL N DPRB 14:30 - 15:30 1.00 DRILL N DPRB 15:30 - 17:00 1.50 DRILL N DPRB 17:00 - 17:30 0.50 DRILL N DPRB 17:30 - 18:30 1.00 DRILL N DPRB 18:30 - 19:00 0.50 DRILL N DPRB 19:00 - 21:00 2.00 DRILL N DPRB 21:00 - 00:00 3.00 DRILL N DPRB 10/31/2005 ~ 00:00 - 01:00 ~ 1.00 ~ DRILL ~ N ~ DPRB 01:00 - 01:30 0.50 DRILL N DPRB 01:30 - 03:30 2.00 DRILL N DPRB 03:30 - 05:00 1.50 DRILL N DPRB 05:00 - 06:30 1.50 DRILL N DPRB 06:30 - 08:00 1.50 DRILL N DPRB 08:00 - 09:30 I 1.501 DRILL I N I DPRB 09:30 - 11:30 2.00 DRILL N DPRB 11:30 - 15:00 3.50 DRILL N DPRB 15:00 - 17:00 I 2.001 DRILL I N I DPRB 17:00 - 17:30 0.50 DRILL N DPRB 17:30 - 19:00 1.50 DRILL N DPRB 19:00 - 19:30 0.50 DRILL N DPRB 19:30 - 20:30 1.00 DRILL N DPRB 20:30 - 22:00 1.50 DRILL N DPRB 22:00 - 00:00 2.00 DRILL N DPRB 11/1/2005 00:00 - 03:00 3.00 DRILL N DPRB 03:00 - 03:30 0.50 DRILL N DPRB 03:30 - 04:00 0.50 DRILL N DPRB 04:00 - 06:00 2:00 DRILL N DPRB Spud Date: 10/29/2005 Start: 10/25/2005 End: 1211 /2005 Rig Release: 12/1/2005 Rig Number: Phase Description of Operations SURF to 450 gpm. Increased slide rate percentage from 60' to 80' per stand. Motor yielding 2.5 degree doglegs. Approaching Anti-colision hard line. Discision was made to POOH and Plug back SURF Circulate Hole Clean SURF POOH from 1006' to 166' SURF Stand back BHA, Break bit, Download MWD, Clear rig floor SURF M/U Muleshoe and RIH with 4" DP to 1006' SURF M/U Top Drive and circulate bottoms up @ 10 bpm and 320 psi SURF PJSM, M/U Cement head and test lines to 2000 psi SURF Pump 15 bbl. of water, 102 bbl of 16# Articset 1 Cement and 1.6 bbl of water. Initial rate 2 bpm at 180 psi. final rate 4 bpm at 421 psi. Cement in place at 1800 hours. SURF POOH to 196' SURF Flush Drillpipe at 10 bpm and 130 psi (2 stands at a time) SURF MIU BHA #2 to 280', Run Gyro for toolface to kick off cement plug. SURF Wash from 280' to 359' 250 gpm C~ 500 psi. Took 2k C 359' Picked up. When went back down saw no indication of firm cement. Started seeing green cement returns. SURF Circulate out Cement at reduced rate 100 gpm C~ 180 psi, to handle returns at shakers. SURF Continue to wash down looking for cement plug. Tag cement @ 804'. Set down 2K, 60 psi pressure increase. SURF Circulate and condition hole. 360 gpm @ 740 psi SURF POH to BHA SURF Stand back HW DP, jars and flex collars, lay down MWD, break bit and lay down motor. SURF RIH with 4" Drillpipe and Tag Cement C~ 798'. 75K Up Wt., 75K Dn Wt. SURF PJSM, R / U to circulate and pump cement SURF Circulate C~3 5 bpm and 100 psi. Wait on cement trucks, caught behind 4ES rig move. SURF PJSM with all personnel involved in operation. Pump 5 bbl of water, test lines to 2600 psi, pump 190 bbl (1094 sx) of 16.2# ArticSet 1 Cement. Trace cement returns to surface. Initial pumpimg rate 2 bpm @ 165 psi. Final Circulating rate 3.2 bpm 430 psi. SURF POOH slowly to 120' SURF Circulate welt at 120'. 10 bbls of cement returns back to surface. Flush Drillpipe stands one at a time. 6 bpm @ 75 psi SURF P/U stack flushing tool and flush diverter C~? 8 bpm and 75 psi. SURF Clean and Clear rig floor and drip pan, SURF P/U and M/U BHA #3 /Load MWD tool. SURF Wait on Cement. Schlumberger Dowell recommendation not to drill cement till 03:00, discussed with Anchorage. Decision was made to wait on cement till 03:00. SURF Clean Rig and wait on Cement. SURF RIN tag ~ 158'. Set 10K down. P/U and pump at 5 bpm at 270 psi. 2-3K WOB. Wash down to 170'. SURF Circulate out cement and clabbered mud. 2 bpm C~ 100 psi. SURF RIH tag @ 210' 15K Dn Wt. Drill From 210' to 265'. Up Weight 60,000 lbs. Down Weight 50,000 lbs. Rotating Weight 55,000 Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-214 V-214 DRILL+COMPLETE DOYON DRILLING INC. DOYON 16 Start: 10/25/2005 Rig Release: 12/1/2005 Rig Number: Date ': From - To I Hours I Task I Code I NPT Phase - - ~- 11/1/2005 04:00 - 06:00 2.00 DRILL N 06:00 - 10:00 4.00 DRILL N 10:00 - 12:00 2.001 DRILL N 12:00 - 00:00 I 12.001 DRILL I N 11/2/2005 i 00:00 - 01:30 ~ 1.50 ~ DRILL ~ N 01:30 - 12:00 I 10.501 DRILL I P SURF 12:00 - 12:30 I 0.501 DRILL I N I SFAL ISURF 12:30 - 16:30 I 4.001 DRILL I P I ISURF 16:30 - 17:00 1 0.501 DRILL I P I ISURF 17:00 - 18:30 1.50 DRILL P SURF 18:30 - 19:30 1.00 DRILL P SURF 19:30 - 20:30 1.00 DRILL P SURF 20:30 - 22:00 1.50 DRILL P SURF 22:00 - 22:30 0.50 DRILL P SURF 22:30 - 00:00 I 1.501 DRILL I P I {SURF DPRB SURF DPRB SURF DPRB ISURF DPRB ISURF DPRB ISURF Page 3 of 24 Spud Date: 10/29/2005 End: 12/1 /2005 Description of Operations lbs. WOB 5,000 - 7,000 Ibs, 10 RPM at 2500 ft/Ibs Torque. Clean Cement From Under Shakers and From Troughs. Clean Pit #3. Wait on Guzzlers Drill 12 1/4" Hole From 265' to 334'. Up Weight 65,000 Ibs. Down Weight 55,000 Ibs. Rotating Weight 60,000 Ibs. 8.9 BPM at 600 PSI On Bottom, 560 PSI Off Bottom. Weight On Bit 5,000 - 8,000 lbs. Drill 12 1/4" Hole From 265' to 873'. Up Weight 75,000 Ibs. Down Weight 73,000 Ibs. Rotating Weight 73,000 Ibs, 20 RPM at 2,500 fUlbs Torque Off Bottom, 3,000 ft/Ibs Torque On Bottom. WOB 10,000 - 16,000 Ibs. Pump Rate 11 BPM at 1,020 PSI Off Bottom, 1,100 PSI On Bottom Pressure. Total ART 1.08 Hours, Total AST 7.92 Hours. Drilled 12-1/4" Directional Hole by Rotating and Sliding from 873' to 1,006'. WOB Sliding 10,000# - 15,000#, WOB Rotating 5,000# - 10,000#, RPM 20, Motor RPM 114, Torque Off Bottom 2,500 ft /Ibs - On Bottom 3,000 ft /Ibs, Pump Rate 440 gpm, SPP Off Bottom 1,020 psi, On Bottom 1,100 psi. String Weight Up 65,000#, String Weight Down 60,000#, String Weight Rotating 62,000#. Drilled 12-1/4" Directional Hole by Rotating and Sliding from 1,006' to 1,575'. WOB Sliding 15,000# - 20,000#, WOB Rotating 5,000# - 10,000#, RPM 20, Motor RPM 156, Torque Off Bottom 3,000 ft /Ibs - On Bottom 3,000 ft /Ibs, Pump Rate 600 gpm, SPP Off Bottom 2,150 psi, On Bottom 2,290 psi. String Weight Up 80,000#, String Weight Down 78,000#, String Weight Rotating 80,000#. Joint on Piping to Mud Cleaner Pulled Apart, Spilling 5 bbls of Mud into Secondary Containment of #1 Pump Room. Shut Down Drilling Operation, Circulated and Reciprocated Drill String at 1,575' While Crew Cleaned Up Mud. Drilled 12-1/4" Directional Hole by Rotating and Sliding from 1,575' to 1,776'. WOB Sliding 15,000# - 20,000#, WOB Rotating 5,000# - 10,000#, RPM 50, Motor RPM 156, Torque Off Bottom 3,000 ft !Ibs - On Bottom 3,000 ft /Ibs, Pump Rate 600 gpm, SPP Off Bottom 2,150 psi, On Bottom 2,290 psi. String Weight Up 80,000#, String Weight Down 79,000#, String Weight Rotating 80,000#. Pumped and Circulated Around 20 bbl 10.5 ppg Weighted Sweep. Pump Rate 600 gpm, 2,300 psi. Rotated and Reciprocated Pipe While Circulating, RPM 100. POOH from 1776' to 74'. Drain Motor. Change Bit (Hughes MX-C1, 3 x 18, 1 x 16 Jets). Adjust Bend in Motor from 1.83 Degrees to 1.5 Degrees. Download Data and Initialize MWD. Clean and Clear Floor. RIH to 1,680'. Work Through Tight Spot from 1,168' to 1,228'. Make Up Top Drive and Wash from 1,680' to 1,776'. Pump Rate 400 gpm, SPP 1,400 psi. Drilled 12-1/4" Directional Hole by Rotating and Sliding from 1,776'to 1,872'. WOB 15,000#- 17,000#, WOB Rotating 5,000# - 10,000#, RPM 20, Motor RPM 107, Torque Off Bottom 3,000 ft /Ibs - On Bottom 3,000 - 3,500 ft /Ibs, Pump Rate 411 gpm, SPP Off Bottom 1,430 psi, On Bottom 1,480 psi, String Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Page 4 of 24 Operations Summary Report Legal Well Name: V-214 Common W ell Name: V-214 Spud Date: 10/29/2005 Event Nam e: DRILL+C OMPLE TE Start : 10/25/2005 End: 12/1/2005 Contractor Name: DOYON DRILLIN G INC . Rig Release: 1211!2005 Rig Name: DOYON 16 Rig Number: Date From - To ' ~ Hours ~ Task Code ~ NPT Phase ~ Description of pperations 1112!2005 22:30 -00:00 1.50 DRILL P SURF Weight Up 81,000#, String Weight Down 75,000#, Rotating Weight 76,000#, ART for Day 3.57 Hours, AST for Day 7.10 Hours. 11/3/2005 00:00 - 01:00 1.00 DRILL P SURF Drilled 12-1/4" Directional Hole by Sliding from 1,872' to 2,015'. WOB 15,000# - 17,000#, Motor RPM 107, Pump Rate 430 gpm, SPP Off Bottom 1,450 psi, On Bottom 1,500 psi, String Weight Up 81,000#, String Weight Down 75,000#, Rotating Weight 76,000#. 01:00 - 01:30 0.50 DRILL P SURF Circulated Bottoms Up, Uable to Get Necessary Build Rates With Motor Adjusted to 1.5 Degrees. Discussed Options With Engineer in Anchorage, Decision Made to POOH and Adjust Motor to 2.12 Degrees. 01:30 - 04:00 2.50 DRILL P SURF POOH from 2,015' to BHA 04:00 - 05:00 1.00 DRILL P SURF Adjusted Bend in Motor to 2.12 Degrees, Offset 254.61. Initialized MWD, Cleaned Floor. 05:00 - 06:00 1.00 DRILL P SURF Held PJSM, RIH with BHA #5, 12-1/4" HTC MXC-16it, Ser# 5082061, Dressed w/ 1x16, 3x18 jets, 8" SperryDrill Lobe 4/5 5.3 stg Motor w/ 2.12 deg Bend, 12.00" Undergauge Sleeve Stabilizer, MWD, NM Float Sub, UBHO Sub, 3 x NM Flex Drill Collars, XO, Drilling Jars, XO, 20 Jts 4" HWDP. Total BHA Length - 815.67'. RIH to 1,950'. 06:00 - 06:30 0.50 DRILL P SURF M / U Top Drive, Engaged Pumps, Rate 400 gpm, 1,400 psi. Precautionary Wash and Ream from 1,950' to 2,015'. No Fill. 06:30 - 14:30 8.00 DRILL P SURF Drilled 12-1/4" Directional Hole by Rotating and Sliding from 2,015' to 2,545'. WOB Sliding 5,000# - 20,000#, WOB Rotating 5,000# - 10,000#, RPM 30, Motor RPM 156, Torque Off Bottom 3,000 ft /Ibs - On Bottom 4,500 ft /Ibs, Pump Rate 600 gpm, SPP Off Bottom 2,800 psi, On Bottom 2,900 psi. String Weight Up 88,000#, String Weight Down 77,000#, String Weight Rotating 82,000#. 14:30 - 15:30 1.00 DRILL P SURF Pumped and Circulated Around 20 bbl 10.8 ppg Weighted Sweep. 600 gpm, 2,750 psi. First 30 Minutes, Reciprocated and Rotated Drill String, 40' Off Bottom, 30 RPM. Second 30 Minutes, POOH 1 Stand, Reciprocated 90' Off Bottom, Rotated 30 RPM. 15:30 - 18:00 2.50 DRILL P SURF POOH w/ 4" DP. POOH w/ BHA to Motor. 18:00 - 19:30 1.50 DRILL P SURF Clean Up BHA, Download Data and Upload MWD. Adjust Motor to 1.813 Degrees. Orient MWD and Motor, 232.76 Offset. 19:30 - 20:00 0.50 DRILL P SURF Service Top Drive and Drawworks. 20:00 - 22:00 2.00 DRILL P SURF RIH w/ BHA #6, 12 1/4" HTC MXC-1 Bit, Ser # 5082061, Dressed wf 3 x 18, i x 16 Jets, 8" Sperry Drill Lobe 4/5 - 5.3 stg. Motor w/ 1.813 bend, 12" Undergauge Sleeve Stablizer, MWD, NM Float Sub, UBHO Sub, 3 x NM Flex Drill Collars, XO, Drilling Jar, XO, 20 x 4" HWDP, Total BHA Lenght = 815.67. RIH to 2,449'. Work Through Tight Spots from 1,962' to 2,140'. Oriented BHA to High Side and Were Unable to Work Through. Brought Pump Rate to 120 gpm at 350 psi, Rotary to 10 RPM and Slacked Off at Rapid Rate, Worked Through. 22:00 - 23:00 1.00 DRILL N RREP SURF Work on Top drive, Main Control Valve Bank is Leaking. Appears to be Blown Seal in Middle of Bank. Unable to Operate Top Drive Due to Hydraulic Leak, Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Event Name: DRILL+COMPLETE Start: 10/25/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task ~ Code NPT Phase i 11/3/2005 23:00 - 00:00 1.00 DRILL N RREP SURF 11/4/2005 00:00 - 01:00 1.00 DRILL N RREP SURF 01:00 - 02:00 1.00 DRILL N RREP SURF 02:00 - 12:00 10.00 DRILL N RREP SURF 12:00 - 13:00 1.00 DRILL N 13:00 - 14:30 1.50 DRILL N 14:30 - 15:00 0.50 DRILL N 15:00 - 15:30 15:30 - 00:00 11/5/2005 00:00 - 05:00 05:00 - 08:00 08:00 - 10:00 10:00 - 12:00 12:00 - 13:00 13:00 - 20:30 20:30 - 00:00 0.50 DRILL P 8.50 DRILL P 5.00 DRILL P 3.00 DRILL P 2.00 DRILL P 2.00 DRILL P 1.00 DRILL P 7.50 DRILL P 3.50 DRILL P RREP I SURF RREP SURF RREP SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF Page 5 of 24 Spud Date: 10/29/2005 End: 12/1 /2005 Description of Operations POOH w/ 4" DP from 2449, to 1,584'. No Problems. POOH from 1,584' w/ 4" DP. POOH w/ BHA to MWD L / D MWD and Motor. Repaired Main Control Valve Bank on Top Drive. Reinstalled Control Valve Bank and Tested, OK. Held PJSM, M / U 12-1/4" HTC MXC-1 Bit, Ser# 5082061, Dressed w/ 1x16, 3x18 jets, 8" SperryDrill Lobe 4/5 5.3 stg Motor w/ 1.83 deg Bend, 12.00" Undergauge Sleeve Stabilizer, MWD, NM Float Sub, 3 x NM Flex Drill Collars, XO, Drilling Jars, XO, 20 Jts 4" HWDP. Total BHA Length - 815.67'. Oriented Motor &MWD 228.60 Offset. Initialized MWD. RIH w/ BHA on 4" DP to 1,100', M / U Top Drive, Engaged Pumps, Circulated Bottoms Up, 500 gpm, 1,600 psi. Shut Down Pumps, Blew Down Top Drive. RIH to 1,980', Tagged Up on Dogleg Ledge. M / U Top Drive, Oriented Tool Face HS, Worked Bit from 1,980' to 2,060', Reamed Out Dogleg Ledge. Pump Rate 500 gpm, 1,550 psi. Shut Down Pumps, Ran Through Hole from 1,980' to 2,060' without Problems. RIH to 2,450', M / U Top Drive, Performed Precautionary Wash and Ream from 2,450' to 2,545', Pump Rate 500 gpm, 1,600 psi. No Fill. Drilled 12-1/4" Directional Hole by Rotating and Sliding from 2,545' to 3,309'. WOB Sliding 15,000# - 20,000#, WOB Rotating 9,000# - 18,000#, RPM 55, Motor RPM 156, Torque Off Bottom 5,000 ft /Ibs - On Bottom 6,500 ft /Ibs, Pump Rate 600 gpm, SPP Off Bottom 3,070 psi, On Bottom 3,210 psi. String Weight Up 90,000#, String Weight Down 70,000#, String Weight Rotating 77,000#. AST 2.47 Hours, ART 2.43 Hours. Drilled 12-1/4" Directional Hole by Rotating and Sliding from 3,309' to 3,774'. WOB Sliding 15,000# - 20,000#, WOB Rotating 9,000# - 18,000#, RPM 55, Motor RPM 156, Torque Off Bottom 5,000 ft /Ibs - On Bottom 6,500 ft /Ibs, Pump Rate 600 gpm, SPP Off Bottom 3,070 psi, On Bottom 3,210 psi. String Weight Up 92,000#, String Weight Down 72,000#, String Weight Rotating 78,000#. AST 1.58 Hours, ART 1.50 Hours. Pumped and Circulated Around 20 bbt 10.9 ppg Weighted Sweep. Circulated Sweep w/ 1 Pump, 400 gpm. Second Pump Back on Line, Circulated 3 x Bottoms Up, 650 gpm, 3,500 psi. Pulled and Stood Back 1 Stand Every 30 Minutes. POOH f/ Wiper Trip, Average Drag 20,000#. Encounterd 50,000# - 60,000# Overpull at 3,060'. Worked Drill String Through Tight Spot, Attempted to RIH, Stacked Out at 3,040'. Worked Drill String Down Hole from 3,040' to 3,100'. Stacked Out at 3,100'. M / U Top Drive, Engaged Pumps, Oriented Tool Face HS, Washed Down from 3,100' to 3,775'. Pump Rate 400 gpm, 1,550 psi. Circulated w/ #2 Pump While C / O Swab on #1 Pump. 400 gpm, 1,550 psi. Backreamed Out of the Hole from 3,775' to 800'. rpm 80, Pump Rate 600 gpm, 3,100 psi. RIH from 800' to 3,775'. Tight Spots at 885', 1,860', and 2,015'. Printed: 12/5/2005 71:08:31 AM BP EXPLORATION Operations Summary Report Page 6 of 24 Legal Well Name: V-214 Common Well Name: V-214 Spud Date: 10!29/2005 Event Name: DRILL+COMPLETE Start: 10/25/2005 End: 12/1/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: Date ~ From - To Hours Task Code NPT Phase Description of Operations 11/5/2005 20:30 - 00:00 3.50 DRILL P SURF No Fill on Bottom. 11/6/2005 00:00 - 02:00 2.00 DRILL P SURF Pump 20 bbl 10.9 ppg weighted sweep. Circulate 3 x Bottoms Up. 650 gpm, 3,500 psi. Pull and Stand Back One Stand Every 30 Minutes. 02:00 - 04:30 2.50 DRILL P SURF POOH with 4" DP to 810', POOH with HWDP to 164'. 20,000# Overpull at 2,410 and 1,980', No Indication of Taking Weight When Slacking Off. 04:30 - 07:00 2.50 DRILL P SURF Lay Down NM Flex Drill Collars, MWD and Motor. 07:00 - 07:30 0.50 DRILL P SURF Clear and Clean Rig Floor 07:30 - 10:30 3.00 CASE P SURF PJSM and Rig Up 9 5!8" Handling Equipment. R!U Franks Fill Up Tool. 10:30 - 19:00 8.50 CASE P SURF Run 9 5/8", L-80, 40#, BTC Casing to 3,755' 19:00 - 20:00 1.00 CASE P SURF R / D Franks Fill Up Tool and R / U Cementing Head. 20:00 - 23:00 3.00 CASE P SURF Stage Pumps Up from 211 gpm and 470 psi to 450 gpm and 1,290 psi. Held PJSM for Cement Job With All Personnel ~ Involved. 23:00 - 00:00 1.00 CASE P SURF With Schlumberger / Dowell Pump 5 bbl Water, Test Lines to 3,500 psi, Pump 70 bbls 10 ppg. Mud Push. No Losses 11/7/2005 00:00 - 02:30 2.50 CEMT P SURF Switched to Dowell, Pumped 5 bbls Water, 3 bpm, 100 psi. Shut in Cement Manifold, Tested Lines to 3,500 psi, OK, Bled Down Pressure. Dropped Bottom Plug, Pumped 75 bbls 10 ppg Mudpush 5 bpm / 150 psi. Mixed and Pumped 380 bbls (480 sks) 10.6 ppg ArcticSet Lite Cement, Followed by 141 bbls (660 sxs) 15.8 ppg Premium Class G Cement w/ 0.300 %bwoc Dispersant, 0.600 %bwoc Accelerator, 0.200 gal / sk Antifoam, 0.40 %bwoc Fluid Loss. Pumped Cement at the Following Rates: Pumped Rate Pressure 50.0 bbls 7.50 bpm 550 psi 100.0 bbls 6.00 bpm 300 psi 150.0 bbls 7.00 bpm 540 psi 200.0 bbls 5.00 bpm 150 psi 250.0 bbls 4.50 bpm 130 psi 300.0 bbls 8.50 bpm 800 psi 380.0 bbls 6.00 bpm 415 psi Tail Cement 400.0 bbls 5.00 bpm 850 psi 450.0 bbls 4.75 bpm 560 psi 500.0 bbls 5.00 bpm 600 psi 521.0 bbls 5.00 bpm 660 psi Dropped Top Wiper Plug> Pumped 5.0 bbls Water 5.50 bpm, 140 psi Switched to Rig Pumps and Displaced Cement w/ 272 bbls of Mud at the Following Rates: Pumped Rate Pressure 50.0 bbls 8.50 bpm 650 psi 100.0 bbls 8.50 bpm 700 psi 150.0 bbls 8.20 bpm 900 psi 200.0 bbls 8.20 bpm 1,030 psi 250.0 bbls 3.00 bpm 630 psi 272.0 bbls 3.00 bpm 800 psi 277.0 bbls Total Displacement Pumped. Pressured up to 1,300 psi to Bump Plug. Bled Down Pressure and Checked Floats, Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Event Name: DRILL+COMPLETE Start: 10/25/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: Date From - To ~ NPT ~ Phase Hours Task Code 11/7/2005 100:00 - 02:30 2.50 CEMT P ~ SURF 02:30 - 05:00 I 2.501 CEMT I P 05:00 - 11:00 I 6.001 DIVRTR I P 11:00 - 12:30 1.50 DIVRTR P 12:30 - 14:00 1.50 P 14:00-15:00 1.00 15:00 - 20:30 5.50 20:30 - 22:00 1.50 22:00 - 00:00 2.00 11 /8/2005 100:00 - 04:00 I 4.00 04:00 - 05:00 I 1.00 05:00 - 07:30 I 2.50 07:30 - 08:30 1.00 08:30 - 10:00 1.50 10:00-11:00 I 1.00 11:00 - 12:00 1.00 12:00 - 18:30 I 6.50 P P P P P SURF SURF SURF PRODi PROD1 PROD1 PROD1 PROD1 PROD1 P PROD1 P PRODi P PROD1 P PROD1 P PROD1 P PROD1 N RREP PROD1 Page 7 of 24 Spud Date: 10/29/2005 End: 12/1 /2005 Description of Operations Floats Held. Cement in place at 0200 hrs. No Losses During Pumping Cement and Displacing with Rig Pumps. 90 bbls Cement Back to Surface Flushed Riser and Diverter, R / D Cement Head. B / O and L / D Landing Joint. R / D and Cleared 9 5/8" Handling Equipment Off Rig Floor. Held PJSM, R / D Diverter Line and Knife Valve. N / D Diverter and Spool and Set Back in Cellar. Held Safety Stand Down w/ Entire Rig Crew. N / U FMC Gen 5 11" x 5M Wellhead and Tubing Spool. Tested Metal to Metal Seal to 1,000 psi f/ 10 Minutes, OK. N / U Secondary Annulus Valve. N / U BOPE: 13-5/8" 5M GK Annular Preventer, 13-5/8" 5M Upper Rams w/ 3-1/2" x 6" Variable Rams, 13-5/8" 5M Blind Shear Rams, Mud Cross w/ Kill /Choke Lines, 13-5/8" Lower Pipe Rams with 2-7/8" x 5" Variable Rams, 13-5/8" x 11" DSA. Function Test BOP's, M / U BOP Test Assembly Test BOPE to 250 psi Low Pressure, 4,000 psi High Pressure. Test Hydril to 250 psi Low Pressure, 3,500 psi High Pressure. Witness of BOP Test Waived By Chuck Scheve of AOGCC. Test #1, Hydril, Choke Valves 1, 12, 13, 14, Dart, Kill HCR. Test #2, Upper Rams, Choke Valves 1,12, 14, Dart, Kill HCR. Upper IBOP Test #3, Upper Rams, Choke Valves 9, 11, Lower IBOP, TIW, Manual Kill. Test # 4, Upper Rams, Choke Valves 5, 8, 10, TIW, Manual Kill. Continued Testing BOPE. Test #5, Upper Rams, Choke Valves 4, 6, 7, TIW, Manual Kill. Test #6, Upper Rams, Choke Valve 2, TIW, Manual Kill. Test #7, Upper Rams, Choke HCR, TIW, Manual Kill. Test #8, Upper Rams, Manual Choke, TIW, Manual Kill. Test #9, Lower Rams, TIW. Test #10, Blind Rams, Choke Valve #3. Accumulater Test. 3,000 psi Starting Pressure, 1,700 psi After Actuation. 200 psi Increase in 17 Seconds, Pressure Back to 3,000 psi in 1 Minute 21 Seconds. Test Witnessed By Bill Burson WSL, Andrew Honea Doyon Toolpusher. R / D BOP Test Equipment, Pulled Test Plug. Ran and Installed Wear Bushing. PJSM. P / U and RIH w/ 39 Joints of 4" Drillpipe from Pipeshed. POOH and Stood Back 13 Stands. C / O Elevators and Equipment to Run BHA. M / U 8-3/4" Hycalog DSX 619 PDC Bit Ser# 113158, w/ 6 x 14 Jets to 7" SperryDrill Lobe 7/8 6.0 Stg Mud Motor w/ 1.5 deg Bend. M / U MWD Hung Off in Rotary Table. Initialized MWD. M ! U Top Drive and Tested MWD, 425 gpm, 860 psi, 450 gpm, 980 psi, Good Pulse. B / O and Blew Down Top Drive. Held PJSM on Radioactive Sources. Cleared Rig Floor, Sperry Installed Radioactive Sources In Tools. RIH to 141'. Top Drive Valve Control Block Began Leaking. Shut Down Top ,Drive. Repaired Top Drive Valve Control Block. Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Page 8 of 24 Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Spud Date: 10/29/2005 Event Name: DRILL+COMPLETE Start: 10/25/2005 End: 12/1/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task I Code ! NPT Phase ~ Description of Operations - 11/8/2005 18:30 - 21:00 2.50 P - PROD1 Held PJSM; P / U 3 x Non-Mag Flex DC's, XO, 15 x 4" HWDP, XO, Drilling Jar, XO, 5 x 4" HWDP, 9 x 4" HT38 DP, Ghost Reamer, 30 x 4" HT38 DP, Ghost Reamer. Total BHA Length = 2,114.91' 21:00 - 22:30 1.50 P PROD1 RIH Picking Up 4" HT38 DP from Pipeshed 1 x 1 t/ 3,364' 22:30 - 00:00 1.50 P PROD1 Held PJSM; Slipped and Cut Drilling Line 11/9/2005 00:00 - 00:30 0.50 P PROD1 RIH Picking Up 4" DP from Pipshed 1 x 1. Tagged Cement Stringer at 3,638' 00:30 - 01:00 0.50 P PROD1 M ! U Top Drive and Established Parameters, String Weight Up 112,000#, String Weight Down 76,000#, Rotary String Weight 83,000#, Rotary 40 rpm, 7,000 ft/Ibs Torque, Pump 4 bpm, 600 psi. Washed Down f/ 3,638' to Float Collar at 3,672'. 01:00 - 02:00 1.00 P PROD1 Circulated 1-1l2 Times Bottoms Up at 6 bpm, 1330 psi. Rotary 20 rpm. Reciprocated Pipe While Circulating. Took Contaminated Returns to Cuttings Tank 02:00 - 03:00 1.00 P PRODi B / O Top Drive and Blew Down Same. M / U Circulating Head, Hoses, Test Chart. Closed Upper Pipe Rams and Opened Kill Llne. Pumped Down DP and Kill Line at 1/2 bpm with the Following Strokes and Pressures. Strokes Pressure 3 230 psi 6 530 psi 9 820 psi 12 1,030 psi 15 1,240 psi 18 1,470 psi 21 1,700 psi 24 1,960 psi 27 2,220 psi 30 2,500 psi 33 2,800 psi 36 3,100 psi 39 3,500 psi Shut In Circulating Head and Monitor for Pressure Loss. Minutes Pressure 5 3,475 psi 10 3,465 psi 15 3,460 psi 20 3,460 psi 25 3,460 psi 30 3,460 psi Bled Pressure Down on all Lines. Opened Rams. R / D Circulating Head and Lines. 03:00 - 05:30 .2.50 P PROD1 M ! U Top Drive and Established Parameters. String Weight Up 112,000#, String Weight Down 76,000#, Rotary String Weight 83,000#, Pump 4 bpm, 600 psi. Torque Off Bottom 7,000 fUlbs. Torque On Bottoms 8,500 fUlbs. 3,000-5,000 WOB. Drill Float Collar at 3,672' and Clean Out to Casing Shoe at 3,758'. Drill Cement and Cleaned Out Rathole f/ 3,759' - U 3,775'. 05:30 - 06:00 0.50 P PROD1 Circulate and Condition Mud in Wellbore Prior to Displacement. 06:00 - 08:30 2.50 P PROD1 Held PJSM w/ Rig Crew, Truck Drivers, Mud Engineer, Tool Pusher and Drilling Supervisor. Cleaned Pits #3 and #4. 08:30 - 09:00 0.50 P PROD1 Took on Mud into Pit #3 and #4. Printed: t2/5/2005 11~.08:3t AM BP EXPLORATION Operations Summary Report Page 9 of 24 Legal Well Name: V-214 Common W ell Name: V-214 Spud Date: 10/29/2005 Event Nam e: DRILL+C OMPLE TE Start : 10/25/2005 End: 12/1/2005 Contractor Name: DOYON DRILLIN G INC . Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: Date From - To I, Hours ~, Task Code ~, NPT Phase ~ Description of Operations 11/9/2005 09:00 - 10:00 1.00 P PROD1 RIH to 3,775', Displaced Wellbore to 8.9 ppg LSND Mud. Pump Rate 575 gpm, 1,930 psi. Reciprocated and Rotated Drill String While Pumping, RPM 80. 10:00 - 10:30 0.50 P PROD1 Drilled 8-3/4" Directional Hole by Sliding from 3,775' to 3,795'. WOB Sliding 10,000#, Pump Rate 600 gpm, SPP Off Bottom 2,000 psi, On Bottom 2,100 psi. String Weight Up 115,000#, String Weight Down 80,000#. 10:30 - 11:00 0.50 P PRODi Circulated Bottoms Up, Pump Rate 575 gpm, 1,950 psi. POOH, Stood Back 1 Stand to Place Bit Inside Casing Shoe. Blew Down Top Drive. 11:00 - 11:30 0.50 P PROD1 R / U Head Pin and Lines, Closed Pipe Rams. Performed LOT, Pumped Down DP and Kill Line at 1/2 bpm with the Following Strokes and Pressures. Strokes Pressure 2 50 psi 4 90 psi 6 150 psi 8 220 psi 10 250 psi 12 290 psi 14 340 psi 16 390 psi 18 430 psi 20 480 psi 22 500 psi 24 500 psi Shut In, Monitored for Pressure Minutes Pressure 1 500 psi 2 460 psi 3 440 psi 4 410 psi 5 400 psi 6 380 psi 7 370 psi 8 360 psi 9 360 psi 10 350 psi Surface Pressure 480 psi Shoe TVD 2,634' MW 8.9 PP9 LOT = 12.40 ppg EMW Bled Pressure Down on all Lines. Opened Rams. R / D Circulating Head and Lines. 11:30 - 14:00 2.50 P PROD1 C 1 O 2 Swabs and 1 Liner on #2 Mud Pump. 14:00 - 14:30 0.50 P PROD1 Engaged Pumps and Took SPR's: #1 30 stks - 260 psi 40 stks - 350 psi #2 30 stks - 250 psi 40 stks - 340 psi Established Clean Hole ECD: MW 8.9 ppg, 600 gpm, 2,100 psi, RPM 100 - C2lculated ECD 9.9 ppg, Actual ECD 9.5 ppg. 14:30 - 00:00 9.50 P PROD1 Drilled 8-3/4" Directional Hole by Rotating and Sliding from 3,795' to 4,706'. WOB Sliding 10,000# - 15,000#, WOB Rotating 8,000# - 10,000#, RPM 80, Motor RPM 198, Torque Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Event Name: DRILL+COMPLETE Start: 10/25/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: Date ~ From - To Hours Task Code j NPT 11 /9/2005 14:30 - 00:00 9.50 P 11/10/2005 00:00 - 12:00 12.00 P 12:00 - 00:00 I 12.00 I I P Page 10 of 24 Spud Date: 10/29/2005 End: 12/1 /2005 Description of Operations Off Bottom 6,000 ft /Ibs - On Bottom 7,500 ft /Ibs, Pump Rate 600 gpm, SPP Off Bottom 2,100 psi, On Bottom 2,250 psi. String Weight Up 115,000#, String Weight Down 90,000#, String Weight Rotating 90,000#. Pumped 20 bbls 1.5 ppg Over MW Weighted Sweep Every 400'. AST 2.18 Hours, ART 2.75 Hours. Drilled 8-3/4" Directional Hole by Rotating and Sliding from 4,706' to 5,954'. WOB Sliding 7,000#-10,000#. WOB Rotating 5,000#-7,000#. RPM 80, Motor RPM 198. Torque Off Bottom 9,000 ft/Ibs, On Bottom 10,000 fUlbs. Pump Rate 600 gpm, SPP Off Bottom 2,920 psi, On Bottom 3100 psi. String Weight Up 145,000#, String Weight Down 80,000#, String Weight Rotating 100,000#. Pumped 20 bbl 1.5 ppg Over MW Weighted Sweep Every 400'. AST 2.37, ART 3.78, Calc. ECD 9.55 Act. ECD 9.8 Drilled 8-3/4" Directional Hole by Rotating and Sliding from 5,954' to 6,914'. WOB Sliding 5,000#-7,000#, WOB Rotating 5,000#. RPM 80, Motor RPM 198, Torque Off Bottom 13,000 ft/Ibs, Torque On Bottom 12,000 ft/Ibs, Pump Rate 600 gpm, SPP Off Bottom 3,490 psi, On Bottom 3,640 psi, String Weight Up 200,000#, String Weight Down 89,000#, String Weight Rotating 115,000#, Pumped 20 bbl 1.5 ppg Over MW Weighted Sweep Every 400'. AST 3.46, ART 2.55, Calc ECD 9.60, Act ECD 10.0 Drilled 8-3/4" Directional Hole by Rotating and Sliding from 6,914' to 7,380'. WOB Sliding 7,000#-8,000#, WOB Rotating 5,000#, RPM 80, Motor RPM 198, Torque Off Bottom 14,000 ft/Ibs, Torque On Bottom 13,000 ft/Ibs, Pump Rate 625 gpm, SPP Off Bottom 3,810 psi, On Bottom 3,950 psi, String Weight Up 215,000#, String Weight Down 90,000#, String Weight Rotating 120,000#. Pumped 20 bbl 1.5 ppg Over MW Weighted Sweep Every 400'. AST .76, ART 2.55, Calc. ECD 9.89, Act ECD 10.1. Pumped and Circulated Around 40 bbl Weighted Sweep, Followed by 2 x Bottoms Up, 600 gpm, 3,850 psi. Rotated 100 rpm, Reciprocated Drill String While Circulating. POOH f/Wiper Trip from 7,380' to 4,550', Placed Upper Ghost Reamer 1300' Inside 9-5/8" Casing. Average Drag 15,000#. RIH to 7,290', M / U Top Drive Washed and Reamed as Precaution from 7,290' to 7,380', No Fill. Circulated 2 x Bottoms Up, 600 gpm, 3,800 psi. POOH to 7,220', M / U Top Drive, Performed MAD Pass from 7,220' to 6,540'. 40 rpm, 575 gpm, 3,450 psi, Trip Speed 250 ' / hr. Top Drive Hydraulic Directional Block Failed. B / O and Blew Down Top Drive. POOH w/ 4" DP to 9-5/8" Shoe at 3,758'. Tight Hole at 4,289', Pulled 45,000# Over Up Weight and Set Off Jars. Unable to Go Down. M / U Top Drive and Established Circulation at 2 bpm, 475 psi. Rotate String to Right and Slump Drill String. Work Pipe Down From 4,289' to 4,306'. Increase Pump Slowly to 9 bpm, 1250 psi. Work String from 4,306' to 4,210'. Circulated Bottoms Up. Start Act ECD 12.86, Finish Act ECD 9.68, Calc ECD 9.54 POOH from 4,206' to 3,758'. Average Overpull 25,000#. I Phase PROD1 PROD1 PRODi 11/11/2005 ~ 00:00 - 05:30 i 5.50 ~ ~ P PROD1 05:30 - 07:00 I 1.501 I P I I PROD1 07:00 - 11:00 I 4.001 I P ( I PROD1 11:00 - 12:30 1.50 P PROD1 12:30 - 17:00 4.50 P PROD1 17:00 - 19:30 I 2.501 I N I RREP I PROD1 19:30 - 20:30 I 1.001 I P I I PROD1 20:30 - 21:30 I 1.001 (N I RREP I PRODi Printed: 72/5/2005 11:08:31 AM BP EXPLORATION Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Event Name: DRILL+COMPLETE Start: 10/25/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code NPT Phase 11/11/2005 20:30 - 21:30 1.00 N RREP PRODi 21:30 - 00:00 2.50 N RREP PROD1 11/12/2005 00:00 - 04:00 4.00 N RREP PROD1 04:00 - 05:30 1.50 N RREP PRODi 05:30 - 06:00 0.50 P PROD1 06:00 - 07:30 1.50 P PRODi 07:30 - 08:30 1.00 P PROD1 08:30 - 10:00 1.50 P PROD1 10:00 - 11:00 1.00 P PRODi 11:00 - 12:30 1.50 P PROD1 12:30 - 14:00 1.50 P PRODi 14:00 - 16:00 2.00 P PROD1 16:00 - 17:30 1.50 P PROD1 17:30 - 18:00 0.50 P PROD1 18:00 - 18:30 0.50 P PROD1 18:30 - 19:30 1.00 P PROD1 19:30 - 20:00 0.50 P PROD1 20:00 - 22:30 I 2.501 I P I I PROD1 22:30 - 00:00 I 1.501 I P I I PROD1 11/13/2005 ~ 00:00 - 05:30 ~ 5.50 ~ ~ P ~ PROD1 05:30 - 06:00 I 0.501 I P I I PROD1 06:00 - 08:30 I 2.501 I N I DPRB I PROD1 Page 11 of 24 Spud Date: 10/29/2005 End: 12/1 /2005 Description of Operations Monitor Well, Clear Floor Repair Top Drive Hydraulic Block Repaired Top Drive Hydraulic Valve Directional Block and Function Tested Same. RIH w/ 4" DP to 6,550'. RIH w/ 4" DP from 6,550' to 7,290'. M / U Top Drive, Washed and Reamed as a Precaution from 7,290' to 7,380'. No Fill. Pumped and Circulated Around 40 bbl Hi-Vis Weighted Sweep. 600 gpm, 4,030 psi. Rotated 100 rpm, Reciprocated Drill String. Circulated 3 x Bottoms Up, 600 gpm, 3,900 psi, Calculated ECD 9.75 ppg, Acutal ECD 9.9 ppg. Displaced Wellbore w/ 290 bbls Clean 9.0 ppg LSND Mud w/ 4% Lubes, 600 gpm, 3,400 psi. Pumped Slug, Monitored Well, Static. B / O and Blew Down Top Drive. POOH w/ 4" DP to 3,765', Average Drag 20,000#, No Tight Spots. M ! U Top Drive, Engaged Pumps, Circulated Bottoms Up at 9-5/8" Casing Shoe, 600 gpm, 900 psi. Rotated 100 rpm, Reciprocated Drill String. Pumped Slug, Monitored Well, Static. B / O and Blew Down Top Drive. POOH w/ 4" DP to 400'. POOH, B / O and L / D 4" HW DP and Jars. Held PJSM, Sperry Removed Radioactive Sources From Tools. Installed Cable and Dowioaded MWD Data. POOH, B / O and L / D Directional BHA. Clear Floor of Excess BHA Components. Clean Floor Drain BOP Stack. P / U Test Joint and Pull Wear Ring. Install Test Plug in Lower Wellhead. L / D Test Joint Install 7" Rams in Bottom Ram Cavity R / U BOPE Test Equipment. Close Blind Rams and Perform Body Test to 250 psi low / 4,000 psi high. Test Witnessed by BP Drilling Supervisor. R / D Test Equipment and Pull Test Plug. P ! U Mandrel Hanger on Landing Joint and Make Dummy Run to Wellhead. Mark Joint and Pull Mandrel Hanger /Landing Joint and U D. Held PJSM, C / O Bails and R / U Casing Equipment. Held PJSM, Installed Franks Fill-Up Tool Held PJSM, P / U 7" 26# L-80 BTC-mod Casing, Shoe Joint, 1 Joint Casing, Float Joint. Bakerlok All Connections Through Float Collar. Make Up Connections to Base of Triangle. Fill Pipe and Check Floats. RIH w/ 7" 26# L-80 BTM Casing. Filling Every Joint, Utilizing Best-o-Life 2000NM Thread Dope on All Connections. Torque Connections to Base of Triangle. Make Up Torque Averaged 8,500 ft/Ibs. Recorded Pick Up and Slack Off Weight Every 10 Joints. Broke Circulation at 2,000' 252 gpm, 350 psi. Broke Circulation at 3,730', 4 bpm / 260 psi, 6 bpm / 410 psi. Circulate 1 Bottoms Up, 105 bbls. String Weight Up 110,000# String Weight Down 82,000#, Continued to RIH w/ 7" 26# L-80 BTM Casing to 3,823'. Stacked Out on Bridge at 3,823'. Attempted to Work 7" Casing Past 3,823'. Circulated 4 bpm, 300 psi - 6 bpm, 400 psi. String Weight Up 120,000#, String Weight Down 87,000#. Stacked Out on Solid Bridge at 3,823', Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Page 12 of 24 Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Spud Date: 10/29/2005 Event Name: DRILL+COMPLETE Start: 10/25/2005 End: 12/1/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: Date From - To Nours ~ Task ~~ Code NPT ~~ Phase ~ Description of Operations __ ~- --- 11l13l2005 106:00 - 08:30 I 2.50 ~ , N ~ DPRB ~ PRODi 08:30 - 10:30 I 2.001 I N I DPRB I PROD1 10:30 - 13:30 3.00 N DPRB PROD1 13:30 - 14:00 0.50 N RREP PRODi 14:00 - 18:00 4.00 N DPRB PROD1 18:00 - 19:00 1.00 N DPRB PROD1 19:00 - 20:00 1.00 N DPRB PRODi 20:00 - 21:00 I 1.001 I N I DPRB I PROD1 21:00 - 23:30 I 2.501 I N I DPRB I PROD1 23:30 - 00:00 0.50 N 11/14/2005 00:00 - 01:30 1.50 CASE N 01:30 - 02:30 1.00 CASE N 02:30 - 04:00 1.50 CASE N 04:00 - 06:00 2.00 CASE ~ N 06:00 - 08:00 2.00 CASE N 08:00 - 18:00 10.001 CASE N DPRB I PROD1 DPRB I PRODi Clean Pick Up, No Overpull or Drag. Pump Pressure Increased 100 psi on Stack Out. 100% Returns, No Losses. No Packing Off. Decision Made to POOH, L ! D 7" Casing f! Clean Out Run. Broke Out and L / D Jt #92. R / D 350T Elevators and Spiders. R / U 7" YT Slip Type Elevators and Hand Slips. POOH, B / O and L / D 7" Casing. Repaired Pipe Skate. POOH, B / O and L / D 7" Casing. Held PJSM, Heat Bakerloked Connections, B / O and L / D Shoe Track R/D Casing Equipment, Clear and Clean Rig Floor Held PJSM, P/U Test Joint and Set Test Plug, C/O Lower Rams to 2-718" x 5" Varibles. R / U Test Manifold, Test 2-7/8" x 5" Varible Rams to 250 psi low / 4,000 psi high. Test Witnessed by BP Drilling Supervisor. Remove Test Plug, Install Wear Ring, L / D Test Joint. Held PJSM, P / U and M / U 8-3/4" Clean Out BHA. Hycalog DSX 619 PDC Bit Ser# 113158 w/ 6 x 14 Jets, 7" Sperry Sun Lobe 7/8 6.0 Stg Mud Motor w/ 1.5 deg Bend, NM Float Sub, Integral Blade Stabilizer, Sperry Sun MWD, (Initialized MWD), 3 x NM Flex DC's, XO. M / U Top Drive and Flow Test MWD w/ 420 gpm, 680 psi. Good Pulse, B / O Top Drive and Blew Down Same Continued to M / U 8-3/4" Clean Out BHA. 15 x 4" HWDP, XO, Drilling Jar, XO, 5 x 4" HWDP, 6 x 4" HT38 DP, Ghost Reamer, BHA Length = 1,018.19' DPRB PROD1 RIH w/ 8-3/4" BHA on 4" DP to 3,730' DPRB PROD1 M / U Top Drive, Established Parameters. String Weight Up 102,000#, String Weight Down 72,000#, String Weight Rotating 85,000#, Pump 150 gpm, 310 psi, Torque Off Bottom 6,000 ft / Ibs, RPM 40. RIH Dry and Tagged at 3,820', P / U 10', Broke Circulation and Reamed Down w/ 5-10 rpm, from 3,810' to 3,855, Recriprocating String Every 10', W0B 12,000#-15,000#, Torque 6,000 ft /Ibs. Oriented Tool Face and Slid from 3,855' to 3,875', WOB 5,000#, Pump 465 gpm, 1,960 psi Off Bottom, 2,100 psi On Bottom. DPRB PROD1 Reamed Down with Orginial Drilling Parameters, Pump 550 gpm, 2,550 psi, 60 RPM, Torque 7,500 fUlbs. from 3,875 to 3,935. Survey at 3,866', Inc. 65, Azmth 345. Orginal Survey Inc. 65, Azmth 341, Drilled from 3,935 to 3,989', Survey Depth 3,924', Inc. 66, Azmth 344. DPRB PROD1 POOH to 3,758', Circulated at 9-5/8" Casing Shoe. 600 gpm, 1,100 psi. DPRB PROD1 RIH to 3,990'. Drilled 8-3/4" Sidetrack Directional Hole by Rotating and Sliding from 3,990' to 4,685'. WOB Sliding 5,000#-8,000#, WOB Rotating 5,000#. RPM 80, Motor RPM 198, Torque Off Bottom 6,500 fUlbs, Torque On Bottom 8,000 ft/Ibs, Pump Rate 600 gpm, SPP Off Bottom 2,400 psi, On Bottom 2,550 psi, String Weight Up 120,000#, String Weight Down 70,000#, String Weight Rotating 85,000#. ART .95, AST 1.69. ECD 9.68. Attempted to Enter Old Wellbore Through Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Event Name: DRILL+COMPLETE Start: 10/25/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: ~ i Date ', From - To ~ Hours i Task ~, Code i NPT ! Phase - -_ - ~_ 11/14/2005 08:00 - 18:00 ~ 10.00 ~ CASE ~ N ~ DPRB ~ PROD1 18:00 - 20:30 I 2.501 CASE I N I DPRB I PROD1 20:30 - 21:30 1.00 CASE N DPRB PROD1 2i :30 - 22:30 1.00 CASE N DPRB PROD1 22:30 - 00:00 1.50 CASE N DPRB PROD1 11!15/2005 00:00 - 02:30 2.50 CASE N DPRB PROD1 02:30 - 04:00 1.50 CASE N DPRB PROD1 04:00 - 06:00 2.00 CASE N DPRB PROD1 06:00 - 09:30 I 3.501 CASE I N I DPRB I PROD1 09:30 - 11:00 1.50 CASE N DPRB PROD1 11:00 - 12:00 1.00 CASE N DPRB PROD1 12:00 - 12:30 I 0.501 CASE I N I DPRB I PROD1 12:30 - 15:30 3.00 ~ CASE ~ N ~ DPRB ~ PROD1 15:30 - 16:00 0.50 CASE N DPRB PROD1 16:00 - 20:00 4.00 CASE N DPRB PROD1 20:00 - 20:30 0.50 CASE N DPRB PROD1 20:30 - 00:00 3.50 DRILL N DPRB PROD1 11/16/2005 100:00 - 05:30 ( 5.501 DRILL I N I DPRB I PROD1 Page 13 of 24 Spud Date: 10/29/2005 End: 12/1 /2005 Description of Operations Sidetrack at Approximately 4,700' .After Confering with Anchorage Personnel. Decided to POOH to 9-5/8" Shoe. Blew Down Top Drive, Monitor Well-Static POOH to 9-5/8" Shoe at 3,758'. Tight Hole, Work Pipe from 4,270' to 4,208'. String Weight Up 150,000#. Backream from 4,208' to 3,800'. String Weight Up 90,000#-110,000#, String Weight Down 70,000#, Pump 580 gpm, 2,490 psi. 80 rpm, Toruge 10,000 fUlbs-15,00 ft/Ibs. Service Top Drive, C / O Dies in Pipe Grabber RIH to 3,803'. M / U Top Drive, Established Parameters. String Weight Up 105,000#, String Weight Down 72,000#, String Weight Rotating 85,000#, Broke Circulation with 520 gpm, 1900 psi and Orient Tool Face 40 deg Left of High Side. Shut Down Pumps. Slide from 3,803' to 3,893'. No Excess Drag Through Kick-Off Point. Circulate Survey Up at 550 gpm / 1,910 psi. Survey Depth 3,826', Inc. 65.02, Azim. 346.01. RIH to 3,933', Survey Depth 3,866', Inc. 65.29, Azim 344.10. Orginal Survey Inc. 65.67, Azim 340.41. Unable to Enter Orginal Hole. POH to 9-5/8" Shoe. Confering with Anchorage on Plan Forward Confering with Anchorage Personnel, Monitoring Well With Hole Fill Tank POOH with 4" DP POOH with 8-3/4" Clean Out BHA. B / O and L / D Ghost Reamer. Stand Back HWDP and Flex Collars. Download MWD, B / O and L / D MWD. Pull Motor and B / O Bit P / U and M / U, Hughes MXL-1 and New MWD. Bit, Mud Motor w/ 1.5 deg Bend, NM Float Sub, Srablizer, MWD, 3 x NM Flex DC's, XO. (Flow Test MWD, 520 gpm, 1,150 psi, Good Pulse), 15 x 4" HWDP, XO, Drilling Jar, XO, 5 x 4" HWDP, 5 x 4" HT38 DP, Ghost Reamer. BHA Total Length = 985.56' RIH w/ 8-3/4" Directional BHA on 4" DP Circulate Bottoms Up at 3,706', 630 gpm / 3,000 psi, Blow Down Top Drive RIH from 3,706' to 4,685', Work Through Tight Area from 4,050' to 4,180'. String Weight Up 120,000#, String Weight Down 70,000# M/U Top Drive, Established Parameters, String Weight Up 122,000#, String Weight Down 73,000#, String Weight Rotating 86,000#, Pump 470 gpm / 2,080 psi. POH Taking Survey's AS Per Directional Driller to 3,758' Circulate 2 x Bottoms Up at 3,707', 620 gpm / 3,020 psi Confering with Anchorage on Plan Forward RIH w/ 4" DP from 3,707' to 4,666' M/U Top Drive, Established Parameters, String Weight Up 122,000#, String Weight Down 72,000#, String Weight Rotating 85,000#, Pump 457 gpm. On Bottom 2,020 psi, Off Bottom 1,970 psi. RPM 60, Torque On Bottom 8,500 ft/Ibs, Off Bottom 8,000 fUlbs. Directional Drill by Sliding and Rotating As Per Sperry Sun Plan Forward for Hole Intersection. Drill from 4,685' to 4.854'. AST .78, ART .68, ECD 9.81 Directional Drill As Per Sperry Sun Plan Forward from 4,854' to 5,143'. Unable to intersect original wellbore at the planned Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Page 14 of 24 Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Spud Date: 10/29/2005 Event Name: DRILL+COMPLETE Start: 10/25/2005 End: 12/1!2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: Date From - To NPT Phase Description of Operations j Hours Task ~ Code 11/16/2005 00:00 - 05:30 1 5.50~DRILL N DPRB PRODi depth of 5,215', decision was made to pull back and revise the directional plan. 05:30 - 06:30 1.00 DRILL N DPRB PROD1 Circulate 20 bbl high vis sweep around @ 420 gpm, 1,550 psi. 40 rpm ,torque 6k, reciprocating slowly. No increase in cuttings at bottoms up. 06:30 - 08:00 1.50 DRILL N DPRB PROD1 POH from 5,145' to 3,706'. No problems pulling to shoe. 08:00 - 10:00 2.00 DRILL N DPRB PROD1 Revise directional plan and plan forword to intersect original Wellbore at 5,310' or drill ahead to 3,705' tvd, 6,100' md. 10:00 - 11:00 1.00 DRILL N DPRB PROD1 RIH from 3,706' to 5,048', no problem. 11:00 - 15:30 4.50 DRILL N DPRB PROD1 Make up topdrive, break circulation, establish parameters, up wt = 128k, do wt = 70k, rt wt = 90k, 400 gpm 1,660 psi off bottom, 1,920 psi on bottom, wob 5-10k. Drill from 5,143' to 5,334'. 15:30 - 18:00 2.50 DRILL N DPRB PROD1 POH to 5,030', Circulate at 508 gpm/ 2,180 psi. Sperry Sun Recalculating Survey's. RIH to 5,334' 18:00 - 00:00 6.00 DRILL N DPRB PROD1 Directional Drill from 5,334' to 5,527'. Up Wt = 130k, Dn Wt = 73k, Rt Wt = 92k, 474 gpm, 2,180 psi Off Btm, 2,210 psi On Btm, WOB 5-10k, 8,500 ft/Ibs Off Btm Torque, 9,500 fUlbs On Btm Torque. AST 2.14, ART 2.67, ECD 9.74 11/17/2005 00:00 - 11:00 11.00 DRILL N DPRB PROD1 Directional Drill from 5,527' to 5,914'. As Per Sperry Sun. Up Wt 145k, Dn Wt 72k, Rt Wt 95k, Pump 465 gpm, 2,130 psi Off Btm Pressure, 2,400 psi On Btm Pressure, Rotary 60 rpm, Off Btm Torque 10,000 ft/Ibs, On Btm Torque 11,000 fUlbs. AST 3.36, ART 2.28 11:00 - 12:00 1.00 DRILL N DPRB PROD1 Circulate 20 bbl Hi-Vis Sweep Around at 10 bpm / 2,000 psi. Reciprocate and Rotate Drill String While Circulating 12:00 - 20:00 8.00 DRILL N DPRB PRODi Directional Drill from 5,914' to 6,196'. Up Wt 157k, Dn Wt 76k, Rt Wt 100k, Pump 465 gpm, Off Btm Pressure 2,220 psi, On Btm Pressure 2,290 psi, Rotary 60 rpm, Off Btm Torque 9,500 fUlbs, On Btm Torque 10,000 ft/Ibs. AST 3.04, ART 1.0 20:00 - 22:00 2.00 DRILL N DPRB PROD1 Ream from 6,132' to 6,196' in Attempt to Enter Orginal Wellbore. Pump 570 gpm 13,210 psi 22:00 - 23:00 1.00 DRILL N DPRB PRODi Circulate 20 bbl Hi-Vis Sweep Around at 618 gpm / 3,480 psi. Reciprocate and Rotate Drill String While Circulating 23:00 - 23:30 0.50 DRILL N DPRB PRODi POH to 6,045' Bit Depth. MW 9.1+ 23:30 - 00:00 0.50 DRILL N DPRB PROD1 Circulate and Take Surveys at the Following Depths, 5,980', 5,970', 5,960', 5,950'. at 465 gpm / 2,220 psi. 11!18(2005 00:00 - 00:30 0.50 DRILL N DPRB PRODi Circulate and Take Surveys at the Following Depths, 5,940', 5,930', 5,920', 5,910', 5,900'. 00:30 - 03:00 2.50 DRILL N DPRB PROD1 Attempt to Intersect Orginal Wellbore by Sidetracking New Wellbore at 5,909' to 5,949'. Observed Mud rolling in Drilling Riser. Shut Down Pumps and Monitor Well-No Flow. 03:00 - 05:00 2.00 DRILL N DPRB PROD1 Brought Pumps Back On Line and Observed ECD of 12.53. Slowed Pump Rate to 125 gpm and Started Circulating Bottoms Up. Slowly Brought Pumps Back Up to 465 gpm as ECD's Decreased to 9.95. After 2 Bottoms Up, MW In 9.1, MW Out 9.3. Pumped 20 bbl 1 ppg Over MW Hi-Vis Sweep Around. MW In 9.1+, MW Out 9.2 Lost 102 bbls Mud. 05:00 - 11:00 6.00 DRILL N DPRB PROD1 Resume Attempt to Intersect Orginal Wellbore by Sidetracking New Wellbore f/ 5,909' - U 5,970'. Pump 563 gpm / 3,160 psi. 11:00 - 12:00 1.00 DRILL N DPRB PROD1 RIH t/ 6,198', CBU at 620 gpm / 3,720 psi 12:00 - 15:00 3.00 DRILL N DPRB PROD1 POH f/ 6,198' - U 5,800'. Circulate Out to 3,917', MW 9.2 ECD 9.8 Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Page 15 of 24 Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Spud Date: 10/29/2005 Event Name: DRILL+COMPLETE Start: 10/25/2005 End: 12/1/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: Date ;From - To Hours Task ;Code NPT '~ Phase 11/18/2005 15:00 - 16:30 1.50 ~ DRILL I N DPRB PROD1 16:30 - 18:00 1.50 DRILL N DPRB PROD1 18:00 - 19:00 1.00 DRILL N DPRB PROD1 19:00 - 19:30 0.50 DRILL N DPRB PROD1 19:30 - 20:30 1.00 DRILL N DPRB PROD1 20:30 - 22:00 1.501 EVAL N DPRB ~ PRODi 22:00 - 23:30 1.501 EVAL { N {DPRB { PROD1 23:30 - 00:00 0.50 EVAL N DPRB PROD1 11/19/2005 00:00 - 00:30 0.50 EVAL N DPRB PROD1 00:30 - 01:00 0.50 EVAL N DPRB PROD1 01:00 - 01:30 0.50 EVAL N DPRB PROD1 01:30 - 02:00 0.50 EVAL N DPRB PROD1 02:00 - 03:00 1.00 EVAL N DPRB PROD1 03:00 - 04:00 1.00 EVAL N DPRB PROD1 04:00 - 04:30 I 0.501 EVAL I N I DPRB I PROD1 04:30 - 05:30 1.00 EVAL N DPRB PROD1 05:30 - 08:00 2.50 EVAL N DPRB PRODi 08:00 - 08:30 0.50 EVAL N DPRB PROD1 08:30 - 12:00 3.50 EVAL N DPRB PROD1 12:00 - 12:30 0.50 EVAL N DPRB PROD1 12:30 - 13:30 1.00 EVAL N DPRB PROD1 13:30 - 15:00 1.50 EVAL N DPRB PROD1 15:00 - 15:30 I 0.501 EVAL I N I DPRB I PRODi 15:30 - 17:30 I 2.001 EVAL I N I DPRB I PROD1 17:30 - 18:00 0.50 EVAL N DPRB PROD1 18:00 - 19:30 1.50 EVAL N DPRB PROD1 19:30 - 20:30 1.00 EVAL N DPRB PROD1 20:30 - 21:00 0.50 EVAL N DPRB PRODi 21:00 - 00:00 3.00 DRILL N DPRB PROD1 Description of Operations Survey as Directed f/ 3,917 - U 3,857'. Survey Depths 3,851', 3,841', 3,531', 3,828', 3,811', 3,801', 3,791'. POH w/ 4" DP U 985' POH w/ 8-3/4" Directional BHA, B/O and L/D Ghost Reamer, Stand Back 4" HWDP, Jars and Flex DC's. Download MWD POH w/ BHA, B/O and L/D MWD, Stablizer and Float Sub. Beak Off Bit and L/D Motor Held PJSM, R/U Schlumberger E-Line Unit, Hang Sheave from Elevators and at Elevator Doorway. String E-line and M/U Tools R1H wl UBI !GPIT 1 GR / CL Logging Tools. Tools Stopped at 2,380', 2nd Attempt-2,385', 3rd Attempt 2,413'. Hole Angle 60 deg. POH w/ E-Line Remove GR / CL Tools. RIH w/ UBI /GPIT Tools U 2,295' POH w/ E-Line. B/O and L/D UBI /GPIT Logging Tools. R/D E-Line and Sheaves Clear and Clean Rig Floor Service Top Drive and Drawworks M!U Docking Head to E-Line. Load Pipeshed with Logging Tools. String E-Line Through Side Entry Sub Held PJSM with Rig Crew, E-Line Crew, Toolpusher, Co-Man, Mud Man P/U and M/U Schlumberger Logging BHA; UBI / AH-107 / DTA-A / AH-SFT /GPIT-H / AH-SFT /SGT-N /CAL-Y / DTC-H /ACTS-B1 / DWCH-A / XO, 18 x 4" HWDP. BHA Total Length 622.77'. M/U Docking Head to Downhole Logging Tools and Check E-Line Connection. RIH w/ UBI Logging BHA on 4" DP to 1,485' Circulate DP volume (17 bbls) 210 gpm, 130 psi, blow down topdrive. Continue RIH with UBI logging tools on 4" DP to 3,566' Circulate DP volume (38 bbls) at 210 gpm, 340 psi to clear any debris from docking head. blow down topdrive. Held PJSM, rig up side entry sub, hang top sheave. RIH with E-line to 2,765', pump wet connect down at 2 bpm, 220 psi, latch up to docking head and test logging tools, tested good. Install side door anchor. RIH from 3,566' to 3,910' attempt to energize UBI tool to begin logging, tool failed. POH from 3,910' to 3,566', remove side door anchor and remove side entry sub, POH with E-line, lay down side entry sub, rig down E-line and sheaves. Monitor well, pump dry job, blow down topdrive. POH from 3,566' logging tools. MW = 9.1 ppg. Connect wet connect to docking head to check tool operation, confirmed tool failure. Remove a-line and lay down logging tools. Clear and clean floor. Function test BOPE. Held PJSM, Makeup 4 3/4" BHA with Hughes HCM505 PDC bit, 5" Motor w/ ABI, NM float sub, stab, MWD, 3 4 3/4" NM flex collars, XO, 5 joints 4" HWDP, Make up topdrive and shallow Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Event Name: DRILL+COMPLETE Start: 10/25/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: Date ~ From - To Hours ~ ~ I Phase i Task Code NPT 11/19/2005 21:00 - 00:00 3.00 DRILL N DPRB PRODi 11/20/2005 00:00 - 00:30 0.50 DRILL N DPRB PROD1 00:30 - 01:00 0.50 DRILL N DPRB PROD1 01:00 - 01:30 0.50 DRILL N DPRB PRODi 01:30 - 02:00 0.50 DRILL N DPRB PROD1 02:00 - 02:30 0.50 DRILL N DPRB PROD1 02:30 - 05:30 3.00 DRILL N DPRB PROD1 05:30 - 07:30 I 2.001 DRILL I N I DPRB I PROD1 07:30 - 09:00 I 1.501 DRILL I N I DPRB I PROD1 09:00 - 15:30 I 6.501 DRILL I N I DPRB I PROD1 15:30 - 16:30 I 1.001 DRILL I N I DPRB I PROD1 16:30 - 20:00 3.50 DRILL N DPRB PROD1 20:00 - 21:30 1.50 DRILL N DPRB PROD1 21:30 - 22:00 0.50 DRILL N DPRB PROD1 22:00 - 23:30 1.50 DRILL N DPRB PROD1 23:30 - 00:00 0.50 DRILL N DPRB PROD1 11/21/2005 00:00 - 01:00 1.00 DRILL N DPRB PROD1 01:00 - 03:00 2.00 DRILL N DPRB PROD1 03:00 - 03:30 0.50 DRILL N DPRB PROD1 03:30 - 04:00 0.501 DRILL N DPRB PROD1 04:00 - 05:30 I i .501 REMCMTN I DPRB { PROD1 Page 16 of 24 Spud Date: 10/29/2005 End: 12/1 /2005 Description of Operations test MWD, 300 gpm ~ 1430 psi. Conrinue picking up BHA, make up 8 3/4" ghost reamer, 10 joints 4" HWDP, XO, jars, XO, 5 joints 4" HWDP. RIH with BHA #11 from 843' to 2,283' Fill DP and breack circulation at 2,283', 210 gpm at 1200 psi. RIH from 2,283' to 3,725' Fill DP and Test MWD, 295 gpm, 1720 psi, ok. RIH from 3,725' set down 25k at 4,054' worked string from 4,054' to 4174' with no pump or rotary, made up topdrive and break circulation, 300 gpm, 2140 psi, Up wt 110k, do wt 68k, orient string 60L, shut down pumps and worked string down from 4,174' to 4,180', 20k wob. Began circulating at 300 gpm 2150 psi and worked string down with no rotation from 4,180' to 4,195' 5-15k wob, 2,230 psi on bottom. Shut down pumps. POH to 4,106' Made up topdrive, and ream from 4,106' to 4,280', 200 gpm 1,060 psi, 50 rpm, torque 6k, taking weight intermittently, and slight increase in differential pressure. POH to 5,909' Circulating and Taking Surveys as per Sperry Sun. Orient Tool Face and Start Troughing from 5,909' to 5,970' at 8 bpm / 3,030 psi. Wash Down to 6,198'. Restart Troughing from 5,909' to 5,945', 7.5 bpm / 2,340 psi. Unable to Wash by 5,963'. Up Wt 130k, Dn Wt 76k, Rt Wt 95k, Torque 7,500 ftllbs. Circulate Aroung Hi-Vis Sweep. Monitor Well-Static. Final MW 9.0+ POH U 9-5/8" Shoe, Pump Dry Job, POH t/ 843' POH w/ 6-3/4" Directional BHA, Stand Back HWDP ,Jars and Flex DC's, Download MWD, B/O and L/D MWD, Mud Motor and Bit Clear and Clean Rig Floor P/U and M/U 4" Mule Shoe and RIH t/ 4,420' Circulate DP Volume, Blow Down Top Drive. RIH f! 4,420' - t/ 5,952'. Unable to Circulate and Rotate Past 5, 963' Circulate and Condition Mud. MW In 9.1, MW Out 9.1. Held PJSM with Rig Crew, Cementing Crew, Truck Drivers, Driling Supervisor, Mud Man B/O Top Drive and Blow Down Same, M/U Circulating Head Pin and Floor Safety Valve. M/U Cement Hose Pump 5 bbls Water, Pressure Test Lines to 3,500 psi. OK. Bled Down Pressure and Lined Up to Pump Cement. Pump 15 bbls Water Followed by 116 bbls 15.8 ppg Class "G" Cement at 4 bpm. BBLS Pressure 15 Water 1,000 10 Cmt 82 20 357 30 550 40 580 50 632 60 948 70 211 Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Event Name: DRILL+COMPLETE Start: 10/25/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task Code ' NPT Phase -- 11/21/2005 04:00 - 05:30 1.50 REMCM~N DPRB PROD1 06:00 07:30 07:45 - 09:00 09:00 - 09:30 09:30 - 12:30 10.50 REMCM~N DPRB PROD1 0.251 REMCMTN I DPRB I PROD1 1.251 REMCMTN I DPRB I PROD1 Page 17 of 24 Spud Date: 10/29/2005 End: 12/1 /2005 Description of Operations 80 380 90 458 100 545 110 475 116 435 3.7 Water 220 Switched to Rig Pump and Displaced at 7 bpm BBLS Pressure 5 200 10 420 15 1070 20 1020 25 1020 30 1020 35 1020 40 1020 Shut Down Pump, Bled Off Excess Pressure, B/O and L/D Circulating Head Pin. CIP at 0515 hrs POH slowly 10 Stand 4" Dp to 4,997' Break circulation, stage pumps up to 10 bpm, 900 psi, after 290 bbls pumped diverted returns to cuttings tank, very little interface dumped 20 bbls of contaminated mud and 30 bbls of sidewalk cement. Blow down topdrive, rig up circulating head and cement hose. Held PJSM for second cement plug. Pumped 5 bbls water, test lines to 3,500 psi, pumped remaining 15 bbls water followed by 95 bbls class G cement weighted to 15.8 ppg at 5.5 bpm. BBLs Pressure 10 577 20 1230 30 902 40 751 50 783 60 879 70 890 80 906 90 893 95 897 3.7 Water 355 Swithed to rig pumps and displace cement C~3 7 bpm BBLS Pressure 10 850 20 970 30 980 31 150 Shut down pumps, Break out and lay down circulating head. CIP at 08:48 0.50 REMCM N DPRB PROD1 POH slowly from 4,997' to 4,035' 3.00 REMCM N DPRB PROD1 Break circulation, stage pumps up to 8 bpm, 800 psi, 80 rpm, torque 4.5k. Cement contaminated mud back 184 bbls pumped, dumped a total of 160 bbls contaminated mud, no Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Page 18 of 24 Operations Summary Report Legal Well Name: V-214 Common W ell Name: V-214 Spud Date: 10!29/2005 Event Nam e: DRILL+C OMPLETE Start: 10/25/2005 End: 12/1/2005 Contractor Name: DOYON DRILLING INC . Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task j Code ' NPT Phase Description of Operations 11/21/2005 09:30 - 12:30 3.00 REMCM N DPRB PRODi sign of clean cement. Circulated 1.5 x bottoms up for additional clean up. Blow down topdrive, and made up circulating head and cement hose. Held PJSM for third plug 12:30 - 13:15 0.75 REMCM N DPRB PROD1 Pumped 5 bbls water, test lines to 3,500 psi, pumped remaining 15 bbls water followed by 33 bbls class G cement weighted to 15.8 ppg, followed by 3.7 bbls water behind @ 5.5 bpm. BBLs Pressure 15 W ater 320 5 Cement 751 10 1390 15 1044 20 998 25 957 30 966 33 980 3.7 Water 350 Switch over to rig and displacecement ~ 7 bpm BBLs Pressure 10 340 20 770 30 120 Shut down pump, break out and lay down head pin CIP 13:10 hrs. 13:15 - 13:30 0.25 REMCM N DPRB PROD1 POH slowly from 4,035' to 3,800' 13:30 - 15:30 2.00 REMCM N DPRB PROD1 Break circulation, stage pumps up to 8 bpm, 800 psi, 80 rpm, torque 4.5k. Cement contaminated mud back 135 bbls pumped, dumped a total of 155 bbls contaminated mud, 15 bbls sidewalk cement to surface. Circulated and condition mud 2x bottoms up. MW 8.9+. Monitor well pump dry job. 15:30 - 17:00 1.50 REMCM N DPRB PROD1 POH with 4" Mule Shoe and DP 17:00 - 17:30 0.50 BOPSU N DPRB PROD1 M/U BOPE Flushing Tool & Flush BOPE Stack, B/O and UD Flushing Tool 17:30 - 18:00 0.50 DRILL N DPRB PROD1 Clear and Clean Rig Floor 18:00 - 18:30 0.50 BOPSU N DPRB PROD1 P/U Test Joint, M/U Wear Ring Pulling Tool, Pull Wear Ring, M/U Test Plug and Set Same, RILDS, R/U Test Euipment 18:30 - 23:00 4.50 BOPSU N DPRB PROD1 Held PJSM, Test BOPE's and Choke Manifold to 250 psi low / 4,000 psi high, Annular to 250 psi low / 3,500 psi high, as per Doyon Procedure. All Tests held for 5 min each. Test Witnessed by Drilling Supervisor and Doyon Toolpusher. AOGCC Witness of Test was Waived by Jeff Jones. Test #1 -Annular Test #2 -Choke Valves 1,12,13,14, Upper Pipe Rams, HCR Kill, Upper IBOP & Dart Valve Test #3 -Choke Valves 9,11, Manual Kill, Floor Safety Valve, Lower IBOP Test #4 -Choke Valves 5,8,10 Test #5 -Choke Valves 4,6,7 Test #6 -Choke Valve 2 Test #7 -Choke Valve 3 Test #8 -HCR Choke Test #9 -Manual Choke Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Page 19 of 24 Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Spud Date: 10/29/2005 Event Name: DRILL+COMPLETE Start: 10/25!2005 End: 12!1!2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: Date I From - To ~ Hours Task Code NPT I! Phase Description of Operations _~ _ _ I - __ F~ - ~ _ 11/21/2005 18:30 - 23:00 4.50 BOPSU N DPRB PROD1 Test #10-Lower Pipe Rams Test #11-Blind Rams 23:00 - 23:30 0.501 BOPSUp N DPRB PROD1 23:30 - 00:00 0.50 DRILL N DPRB PROD1 11/22/2005 00:00 - 01:30 1.50 DRILL N DPRB PROD1 01:30 - 02:00 0.50 DRILL N DPRB PROD1 02:00 - 02:30 0.50 DRILL N DPRB PROD1 02:30 - 03:30 1.00 DRILL N DPRB PROD1 03:30 - 05:00 1.50 DRILL N DPRB PROD1 05:00 - 07:30 2.50 DRILL N DPRB PRODi 07:30 - 09:30 2.00 DRILL N DPRB PROD1 09:30 - 15:00 5.50 DRILL N DPRB PROD1 15:00 - 16:30 I 1.501 DRILL I N I DFAL I PROD1 16:30 - 18:00 1.50 DRILL N DFAL PRODi 18:00 - 20:00 2.00 DRILL N DFAL PROD1 20:00 - 21:30 1.50 DRILL N DFAL PROD1 21:30 - 22:30 1.00 DRILL N DFAL PROD1 22:30 - 00:00 1.50 DRILL N DFAL PROD1 11/23/2005 00:00 - 01:30 1.50 DRILL N DFAL PROD1 01:30 - 03:00 I 1.501 DRILL I N I DFAL I PROD1 03:00 - 04:00 1.00 DRILL N DPRB PRODi 04:00 - 05:00 1.00 DRILL N DPRB PROD1 05:00 - 07:00 2.00 DRILL N DPRB PROD1 07:00 - 08:00 1.00 DRILL N DPRB PROD1 08:00 - 10:00 2.00 DRILL N DPRB PROD1 10:00 - 11:00 1.00 DRILL N DPRB PROD1 11:00 - 12:30 1.50 DRILL N DPRB PROD1 12:30 - 14:30 2.00 DRILL N DPRB PROD1 14:30 - 16:00 1.50 DRILL N DPRB PROD1 16:00 - 18:30 2.50 DRILL N DPRB PROD1 R/D Test Manifold, Remove Test Plug, Install Wear Ring, RILDS, L/D Test Joint Service Top Drive M/U 8-3/4" Clean Out BHA; Bit, Bit Sub, NM DFlex DC, Stabilizer, 2 x NM Flex DC's, XO, 15 x 4" HWDP, XO, Drilling Jar, XO, 5x4" HWDP. BHA Total Length = 750.34' RIH w/ 4" DP U 2,200' M/U Top Drive, Break Circulation and Fill DP, Blow Down Top Drive. RIH w/ 4" DP U 3,727' M/U Top Drive, Established Parameters, Up Wt 98k, Dn Wt. 70k, Rt Wt. 85k, Rotary 50 rpm, 5,000 fUlbs Torque, Pump 10 bpm, 950 psi. Wash Down from 3,727' to 3,808'. Pump 20 bbl Hi-Vis Sweep Around. Monitor Well-Static, Pump Dry Job. Blow Down Top Drive, MW 9.1 POH w/ 8-3/4" Clean Out BHA Rig Up Schlumberger and Test Logging Tools. RIH with TCL on 4" Drillpipe to 3,417', Rabbiting Drillpipe. Break Circulation at 1,500 and 3,417'. Hang Wireline Sheave in Derrick, Make Up Side Entry Sub, RIH with E-Line and Latch into Tools, Test Conection, Install Clamps in Side Entry Sub. RIH to 3,733', Lost Communication with UBI Tool, Attempt to Establish Communication with UBI Tool. POOH to 3,417', Remove Clamp from Side Entry Sub, POOH with E-Line, Remove Side Entry Sub. POOH to Logging Tools. Change Out Logging Tools. Remove DTA-A and Re-configure Tool String. RIH with TLC on 4" Drillpipe to 1,494' RIH with TCL Tool on 4" Drillpipe to 3348'. Break Circulation at 1,502' and 3,325'. Rig Up Side Entry Sub, RIH with E-Line and Latch Up. Good Connection, Test Tools. Log Down to 3,418'. USRS on UBI Failed, Unable to Restart. POOH to 3,348', Remove Clamps on Side Entry Sub, POOH with E-Line, Rig Down Side Entry Sub. POOH with 4" Drillpipe to Wireline Tools. Clean and Lay Down Logging Tools. Change Out Saver Sub. Service Rig and Top Drive. Pick Up UBI Tool String and Confirm Proper Operation on Surface. Determined that High Viscosity Mud and Debris in Hole Not Allowing UBI Tool to Operate Properly. Rig Down Schlumberger Wireline. M/U 8 3/4" Bit, Bit Sub, Flex DC, NM String Stablizer, Flex DC, XO, Casing Scraper, XO, Flex DC, XO, 1 x HWDP, Ghost Reamer, 14 x HWDP, XO, Jars, XO, 5 x HWDP. Total BHA Length = 763.48' RIH with 4" DP to 3,739' Circulate and Condition Mud. 10 BPM at 740 PSI. Rotate at 80 Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC Rig Name: DOYON 16 Date 'From - To ~ Hours ' Task ~ Code li Page 20 of 24 Spud Date: 10/29/2005 Start: 10/25/2005 End: 12/1/2005 Rig Release: 12/1/2005 Rig Number: NPT ! Phase j Description of Operations _~ ~_ - __ 11/23/2005 16:00 - 18:30 2.50 DRILL N DPRB PROD1 18:30 - 20:30 2.00 DRILL N DPRB PRODi 20:30 - 22:00 1.50 DRILL N DPRB PROD1 22:00 - 23:00 1.00 DRILL N DPRB PROD1 23:00 - 00:00 1.00 DRILL N DPRB PROD1 11/24/2005 00:00 - 00:30 0.50 DRILL N DPRB PROD1 00:30 - 03:30 3.00 DRILL N DPRB PROD1 03:30 - 04:00 0.50 DRILL N DPRB PROD1 04:00 - 05:00 1.00 DRILL N DPRB PROD1 05:00 - 09:30 4.50 DRILL N DPRB PROD1 09:30 - 12:00 2.50 DRILL N DPRB PROD1 12:00 - 14:00 2.00 DRILL N DPRB PROD1 14:00 - 15:00 1.00 DRILL N DPRB PROD1 15:00 - 15:30 0.50 DRILL N DPRB PROD1 15:30 - 16:30 1.00 DRILL N DPRB PROD1 16:30 - 17:30 1.00 DRILL N DPRB PROD1 17:30 - 19:00 1.50 DRILL N DPRB PROD1 19:00 - 00:00 I 5.001 DRILL I N I DPRB f PROD1 11!25/2005 00:00 - 00:30 0.50 DRILL N DPRB PROD1 00:30 - 01:30 1.00 DRILL N DPRB PRODi 01:30 - 03:30 I 2.001 DRILL I N I DPRB I PRODi 03:30 - 05:00 ~ 1.50 ~ DRILL ~ N ~ DPRB ~ PROD1 05:00 - 14:00 I 9.001 DRILL I N I DPRB I PROD1 14:00 - 15:30 I 1.501 DRILL I N I DPRB I PROD1 15:30 - 16:30 1.00 DRILL N DPRB PROD1 16:30 - 19:00 2.50 DRILL N DPRB PROD1 19:00 - 00:00 5.00 DRILL N DPRB PROD1 11/26/2005 00:00 - 09:30 9.50 DRILL N DPRB PRODi 09:30 - 10:00 I 0.501 DRILL I N I DPRB I PROD1 RPM and Reciprocate Pipe. RIH to 3,808', Pump Spacer Pill and Displace Well to Water. 8 BPM at 740 PSI. While Displacing Open Hole, No Pipe Rotation. Pull Into Casing and Finish Displacing Well to Water. Up Weight 89,000 lbs. Down Weight 72,000 lbs. Monitor Well, POOH with 4" Drillpipe. Stand Back BHA, L/D Scraper, Reamers and Bit Sub. Hold PJSM, Rig Up Schlumberger Wireline Rig Up Schlumberger Wireline Run UBI to 3,770' and log up to 3,700' POOH with Wireline Rig Down Schlumberger Wireline M/U Directional BHA #14 Replace Pulser in MWD, Upload and Pulse Test. RIH with 4" Drillpipe U 3,724'. PJSM, Slip and Cut Drilling Line. Service Drawworks. Displace Well to 8.8 ppg LSND Mud. RIH Tag at 3808'. Kick Off and Drill 6 3/4" Hole f/ 3,808' t/ 3,915'. Intersect Original Wellbore. Up Weight 100,000 Ibs, Down Weight 75,000 lbs. Rotating Weight 88,000 lbs. 45 RPM, Off Bottom Torque 4,000 fUlbs, On Bottom Torque 5,000 fUlbs. Pump Pressure 1,460 PSI at 309 GPM. Wash and Ream t/ 4,067', Hole Packing Off, Work Pipe U 3,971', Circulate and Clean Hole. Wash and Ream to 4,183' Wash and Ream f/ 4,183' U 4,242'. Pump 20 BBL.High Vis Sweep. Rotate at 80 RPM and Reciprocate Pipe. 325 GPM at 1,430 PSI. Wash and Ream f/ 4,242' U 4,480'. 310 GPM at 1,590 PSI, 70 RPM at 5,000 ft/Ibs Torque. Up Weight 100,000 Ibs, Down Weight 75,000 Ibs, Rotating Weight 88,000 Ibs. Circulate 2 x Bottoms Up. 325 GPM at 1,450 PSI. Rotate at 80 RPM and Reciprocate Pipe. Monitor Well, Mud Weight 9.0 ppg. POOH from 4,480', Swabbing Hole, Unable to Clean Ball from BHA. Pump out of the Hole to 1,200'. 310 GPM at 1,050 PSI. POOH to 844'. POOH with BHA, Lay Down 8.750" String Mill/Hole Opener. Check 6.750" Bit and Make Up Pump Out Sub. Download Data and Upload MWD, Flow Test MWD. RIH with BHA #15 to 4,166'. Fill Pipe at 2,280' and 3,620' Wash and Ream Original Wellbore from 4,166' to 4,583'. Up Weight 105,000 Ibs, Down Weight 75,000 Ibs, Rotating Weight 85,000 Ibs. Torque 3,000 - 4,000 Ibs at 40 RPM. Pump Pressure 1110 PSI at 235 GPM. Wash and Ream Original Wellbore from 4,583' to 5,115'. Up Weight 105,000 Ibs, Down Weight 75,000 Ibs, Rotating Weight 85,000 Ibs. Torque 3,000 - 4,000 Ibs at 25 RPM. Pump Pressure 1110 PSI at 225 GPM. 2-5k wob. At 5,070' encountered coal stringer, hole angle climbed from 66 deg to 69 deg by 5,115' attempted back reaming and trenching to drop angle, no sucsess. Pulled back from 5,115' to 4,720 Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Page 21 of 24 Operations Summary Report Legal Well Name: V-214. Common Well Name: V-214 Spud Date: 10/29/2005 Event Name: DRILL+COMPLETE Start: 10/25/2005 End: 12/1/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: Date From - To ~ Hours ~~ Task ~ Code ~ NPT '~ Phase Description of Operations - _~__ _ _ T - _- 11/26/2005 10:00 - 18:30 8.50 DRILL N DPRB PROD1 Started trenching from 4,720' with a 180 deg Toolface, Up 18:30 - 19:00 0.50 DRILL N DPRB PROD1 19:00 - 00:00 5.00 DRILL N DPRB PROD1 11/27/2005 00:00 - 04:00 4.00 DRILL N DPRB PROD1 04:00 - 10:00 I, 6.00 DRILL N DPRB PROD1 10:00 - 12:30 2.50 DRILL N DPRB PROD1 12:30 - 13:30 1.00 DRILL N DPRB PROD1 13:30 - 14:00 0.50 DRILL N DPRB PROD1 14:00 - 15:30 1.50 DRILL N DPRB PROD1 15:30 - 16:30 1.00 DRILL N DPRB PROD1 16:30 - 17:30 1.00 DRILL N DPRB PROD1 17:30 - 21:30 4.00 DRILL N DPRB PROD1 21:30 - 00:00 2.50 DRILL N DPRB PROD1 11/28/2005 00:00 - 01:00 1.00 DRILL N DPRB PROD1 01:00 - 03:30 2.50 DRILL N DPRB PROD1 03:30 - 05:30 2.00 DRILL N DPRB PROD1 Weight 105,000 Ibs, Down Weight 75,000 Ibs, 260 GPM at 1,420 psi At 4,780' ABI had dropped from 65 deg to 63.4 in 10', started rotating at 20 rpm, reduced pump rate to 200 gpm 980 psi, no wob, 500 -600 fph, reamed to 5,000' encountered coal stringer, continued reaming, taking more WOB, 5-7k, reamed to 5,325'. Compared logs to original well and confirmed no longer in original well bore. Logs indicated we had deviated from PB2 at between 4,650' to 4,750' md. Pulled back from 5,325' to 4,770' Make Repeated attemps to re-enter original wellbore. Make repeated attempts to re-enter original wellbore from 4,770'. Unable to re-enter, discuss options with Anchorage. Decision was made to pull to 4,607' and attempt to re-enter original wellbore. Start troughing from 4,607' to 4,637' with toolface oriented to 180 degrees. Up Weight 105,000 Ibs, Down Weight 80,000 Ibs, Rotation Weight 90,000 Ibs. 225 gpm at 1,140 psi. Started taking 5-7,000 Ibs WOB, Orient toolface to 120 degrees right side. Attempt to trough wellbore. Wash and ream to 5,330'. 50 rpm at 6,000 ft/Ibs torque. 300 gpm at 1,590 psi. 0 - 4,000 Ibs WOB. Pump 20 bbl high vis sweep around. 325 gpm at 1,800 psi. Reciprocate pipe and rotate string at 60 rpm. Slight increase in returns with sweep. Monitor well, Mud weight 9.0 ppg. POOH from 5,330' to 4,870' hole not taking correct fill. Pump out of the hole from 4,870' to 3,719'. 300 gpm at 1,450 psi. 80 rpm. Drop dart and open circulating sub, sheared at 2,200 psi. Circulate bottoms up at 600 gpm, 1,600 psi. 40 % increase in cuttings returns. Fine sands and coal. Pump dry job, blow down Top Drive and POOH from 3,719' to 840' PJSM, Lay down BHA #15, flush smart tools and download MWD data. M/U cementing pup and RIH with 4" drillpipe to 4,945" No Problems. Up Weight 105,000 Ibs, Down Weight 70,000 Ibs. Break circulation and circulate and condition mud.RlH from 4,945' to 5,325'. No Problems Circulate and condition mud. 500 gpm at 1,400 psi. Pumped 5 bbls water, test lines to 3,500 psi, pumped remaining 15 bbls water followed by 50 bbls class G cement weighted to 15.8 ppg, followed by 3.7 bbls water behind ~ 5 bpm. BBLS Pressure 15 Water 860 5 Cmt. 1006 10 764 15 699 20 727 25 855 Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Page 22 of 24 Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Spud Date: 10/29/2005 Event Name: DRILL+COMPLETE Start: 10/25/2005 End: 12/1/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: Date ~~ From - To ~ Hours ~~~ Task 'Code NPT ~ Phase ~ Description of Operations 11/28/2005 ~ 03:30 - 05:30 ~ 2.00 ~ DRILL ~ N ~ DPRB PROD1 ~ 30 851 35 915 40 947 45 901 50 919 3.7 Water 233 Switched to rig pump and displace with mud C«? 6 bpm BBLS Pressure 17 360 22 410 26 440 30 170 33 110 CIP @ 05:30 05:30 - 06:00 0.50 DRILL N DPRB PROD1 06:00 - 08:00 2.00 DRILL N DPRB PROD1 08:00 - 09:30 I 1.501 DRILL I N I DPRB I PROD1 09:30 - 10:00 0.50 DRILL N DPRB PROD1 10:00 - 14:00 4.00 DRILL N DPRB PROD1 14:00 - 17:30 ~ 3.50 ~ DRILL ~ N (DPRB (PROD1 POOH with 4" Drillpipe slowly to 4,456' Circulate 8 bpm at 400 psi. Approximately 100 bbls of Contaminated mud back. PJSM with all personnel involved. M/U cementing assembly. Pumped 5 bbls water, test lines to 3,500 psi, pumped 15 bbls water followed by 70 bbls i 5.8 class G cement at 5 bpm. BBLS Pressure 15 Water 768 10 Cement 768 20 814 30 915 40 1111 50 1052 60 1034 70 260 5 Water 187 Switched to rig pumps and displace with mud at 6 bpm. BBLS Pressure 10 320 20 280 29 340 CIP at 08:40 POOH slowly with 4" drillpipe to 3,391' Circulate at 7 bpm at 270 psi. Reciprocate pipe and rotate at 80 rpm. 3,000 ft/Ibs torque. Approximately 50 bbls of contaminated mud back to surface. Monitor well (Mud Weight 8.9) Pump Dry job and lay down 4" Printed: 12!5(2005 11.08:31 AM BP EXPLORATION Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Event Name: DRILL+COMPLETE Start: 10/25/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 1211/2005 Rig Name: DOYON 16 Rig Number: Date __ From - To __ Hours I _ _ Task Code NPT ' Phase L - - -- 11/28/2005 14:00 - 17:30 3.50 DRILL N DPRB PROD1 17:30 - 18:30 1.00 DRILL N DPRB PROD1 18:30 - 21:00 2.50 DRILL N DPRB PROD1 21:00 - 21:30 0.50 DRILL N DPRB PROD1 21:30 - 22:00 ~ 0.50 ~ DRILL N ~ DPRB ~ PRODi 22:00 - 22:30 0.50 DRILL N DPRB PROD1 22:30 - 00:00 1.50 DRILL N DPRB PROD1 11/29/2005 100:00 - 03:30 I 3.501 DRILL I N I DPRB I PROD1 03:30 - 04:00 0.50 DRILL N DPRB PROD1 04:00 - 05:30 1.50 DRILL N DPRB PROD1 05:30 - 06:00 0.50 DRILL N DPRB PRODi 06:00 - 18:00 12.00 DRILL N DPRB PROD1 18:00 - 18:30 0.50 DRILL N DPRB PROD1 18:30 - 19:30 1.00 DRILL N DPRB PROD1 19:30 - 22:00 I 2.501 DRILL I N I DPRB I PRODi 22:00 - 00:00 I 2.001 DRILL I N I DPRB I PROD1 Page 23 of 24 Spud Date: 10/29/2005 End: 12/1 /2005 Description of Operations Drillpipe from 3,191' to 383' RIH with 4" Drillpipe from the derrick to 3,160' Circulate 6 bpm at 230 psi. Riciprocate pipe and rotate at 20 rpm with 3,000 ft/Ibs torque. RIH to tag top of cement plug. Found top of cement plug at 3,800' (Witness of plug waived by Chuck Sheave AOGCC). Monitor well (Mud Weight 8.9). POOH to 3,160'. Discuss options with Anchorage. RIH to 3,725' Circulate 6 bpm at 280 psi. Riciprocate pipe and rotate at 20 rpm with 3,000 ftllbs torque. Up Weight 76.000 lbs. Down Weight 68,000 lbs. Circulated 6 bpm at 280 psi. Reciprocated Pipe and Rotated at 20 rpm with 3,000 ft/Ibs Torque. Up Weight 76.000 lbs. Down Weight 68,000 lbs. RIH to 3,790' Made Up Cement Assembly Broke Circulation, Held PJSM with All Personnel Involved. Pump 5 bbl Water, Test Lines to 3,500 psi, Pump 5 bbl Water, 22 bbl of 15.8 ppg Class G Cement, 2 bbls Water at 4.5 bpm. BBLS Pressure 5 Water 630 5 Cement 526 10 512 15 791 20 498 2 278 2 Water 170 Switch to Rig Pumps and Displace with 34 bbls of Mud at 5 bpm. BBLS Pressure 10 Mud 230 20 300 30 320 32 320 CIP at 05:15, Rig Down Cementing Assembly. POOH Slowly with 4" Drillpipe to 3,195' Circulate and Condition Mud, 252 gpm at 200 psi. 40 rpm with 3,000 ft /Ibs Torque. Up Weight 76,000 lbs. Down Weight 65,000 Ibs. 20 bbls of Contaminated Mud Back to Surface. Wait on Cement. RIH with 4" Drillpipe to 3,541'. Tag Cement Plug. Set 10,000 Ibs Weight on Cement Plug. Pull Up to 3,491' Close Pipe Rams, Rig Up and Pressure Test Plug to 1,000 psi for 10 Minutes. Test Was Witnessed by Lou Grimaldi, AOGCC. Displace Wellbore to 8.6 ppg Seawater. Flush Both Pumps with Seawater. Pump 20 bbl High Viscosity Spacer Sweep. Pump at 420 gpm and 800 psi. Up Weight 75,000 Ibs. Down Weight 65,000 Ibs. POOH to 2,016'. Laying Down 4" Drillpipe. Printed: 12/5/2005 11:08:31 AM BP EXPLORATION Operations Summary Report Legal Well Name: V-214 Common Well Name: V-214 Event Name: DRILL+COMPLETE Start: 10/25/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 12/1/2005 Rig Name: DOYON 16 Rig Number: Date '' From - To Hours Task 11/30/2005 00:00 - 03:00 3.00 DRILL 03:00 - 03:30 0.50 RUNC( 03:30 - 05:00 1.50 RUNCC 05:00 - 11:00 6.00 11:00 - 13:00 2.00 13:00 - 14:00 I 1.00 DPRB PROD1 POOH from 2,016', Laying Down 4" Drillpipe. DPRB SURE Pull Wear Bushing DPRB SURE Hold PJSM, Rig Up 3.5" Tubing Handling Equipment, Make Page 24 of 24 Spud Date: 10/29/2005 End: 12/1 /2005 Code I NPT Phase 'I Description of Operations N Dummy Run with Tubing Hanger. DPRB SURE Run 3.5", 9.2#, NSCT, L-80 Tubing to 2,724'. DPRB SURE Make Up Hanger, Drain BOP Stack, Land Hanger and Run in Lock Downs. Tubing String Set at 2,752'. Up Weight 55,000 lbs. Down Weight 55,000 lbs. DPRB SURE Install TWC and Test from Below to 500 psi. Blow Down Hole Fill, Choke, Kill and Bleed Off Lines. DPRB SURE Nipple Down BOPE and Secure to BOP Stand. Clean Up Well Head Assembly. DPRB SURE Install Adaptor Flange and Test to 5,000 psi for 15 minutes. DPRB SURE Nipple Up Tree and Test to 5,000 psi for 10 Minutes. DPRB SURE Rig Up Drill Site Maintenance Lubricator and Pull TWC. DPRB SURE PJSM, Rig Up Little Red and test Surface Lines to 3,000 psi. Pump 200 bbls of Diesel Freeze Protect Down Annulus. Initial Circulating Pressure 500 psi at 2 bpm. Final Circulating Pressure 600 psi at 2 bpm. DPRB SURE Line Up and U -Tube Freeze Protect. DPRB SURE U-Tube Freeze Protect. Install BPV and Test from Below to 1,000 psi. DPRB SURE Rig Down Hoses, Remove Secondary Annulus Valve. Secure Tree and Secure Cellar. Rig Released at 01:30 hrs. 14:00 - 16:00 I 2.001 BOPSUR N 16:00 - 18:00 2.00 WHSUR N 18:00-19:30 1.50 WHSUR N 19:30 - 20:30 1.00 WHSUR N 20:30 - 23:30 3.00 WHSUR N 23:30 - 00:00 0.50 WHSUR N 12/1/2005 00:00 - 00:30 0.50 WHSUR N 00:30 - 01:30 1.00 ~ W HSUR ~ N Printed: 12/5/2005 11:08:31 AM Halliburton Global Company: BP Amoco llate: 12/20/2005 Time: 06:14:46 Pa ;e: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: V-214, True North ii Site: PB V Pad Vertical (TVD) Refer ence: V-214:78.8 Well: V-214 Section (VS) Reference: Well (O.OON,O.OOE,10.54Azi) Wellpath: V-214PB1 Sur~ev Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 19 27 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Syste m: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: V-214 Slot Name: Well Position: +N/-S 101.27 ft Northing: 5970061.76 ft Latitude: 70 19 40.614 N +E/-W -330.35 ft Easting : 590439.13 ft Longitude: 149 15 59.515 W Position Uncertainty: 0.00 ft Wellpath: V-214P61 Drilled From: Well Ref. Point 500292327570 Tie-on Depth: 25.70 ft Current Datum: V-214: Height 78.80 ft Above System Datum: Mean Sea Level Magnetic Data: 10/28/2005 Declination: 24.46 deg Field Strength: 57579 n T Mag Dip Angle: 80.84 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 25.70 0.00 0.00 10.54 Survey Program for Definitive Wellpath Date: 12/19/2005 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 100.00 951.50 V-214PB1 GyroData (100.00-951.50) GYD-CT-DMS Gyrodata cont.drillpipe m/s Survey ~' iVID [ncl Azim TVD Svs"fVD N/S E/W D~lapN MapE "fool ft deg deg ft ft ft ft ft ft 25.70 0.00 0.00 25.70 -53.10 0.00 0.00 5970061.76 590439.13 TIE LINE 100.00 0.19 285.15 100.00 21.20 0.03 -0.12 5970061.79 590439.01 GYD-CT-DMS 170.00 0.27 317.17 170.00 91.20 0.18 -0.34 5970061.94 590438.78 GYD-CT-DMS 263.00 0.50 350.92 263.00 184.20 0.74 -0.56 5970062.50 590438.57 GYD-CT-DMS 356.00 1.55 13.41 355.98 277.18 2.37 -0.33 5970064.12 590438.77 GYD-CT-DMS 447.00 2.52 15.29 446.92 368.12 5.50 0.48 5970067.26 590439.55 GYD-CT-DMS 541.00 3.64 11.89 540.79 461.99 10.41 1.64 5970072.19 590440.65 GYD-CT-DMS 633.00 4.97 9.83 632.52 553.72 17.19 2.93 5970078.99 590441.85 GYD-CT-DMS 723.00 6.54 8.32 722.07 643.27 26.11 4.33 5970087.92 590443.15 GYD-CT-DMS 816.00 7.94 7.41 814.32 735.52 37.72 5.93 5970099.54 590444.60 GYD-CT-DMS 856.00 9.05 9.30 853.88 775.08 43.56 6.79 5970105.40 590445.40 GYD-CT-DMS 915.00 9.61 11.06 912.10 833.30 52.98 8.49 5970114.83 590446.98 GYD-CT-DMS 951.50 10.27 16.37 948.06 869.26 59.09 9.99 5970120.96 590448.41 GYD-CT-DMS 1006.00 10.27 16.37 1001.68 922.88 68.41 12.73 5970130.31 590451.03 BLIND Halliburton Global Company: BP Amoco llatc: 12/20!2005 'l'ime: 06:17:02 N~gc: 1 Field: Prudhoe Bay Co-ordinate(NE) Keference: Well: V-214, True N orth Site: PB V Pad Well: V-214 Wellpath: V-214PB2 Vertical ("TVD) Reference: V-214:78.8 Section (VS) Keference: Well (O.OON,O.OOE,339.17Azi) Survev Calculation Method: Minimum Curvature Db: Oracle - ~- - Field: Prudhoe Bay - - - - - - - - _ - _ North Slope UNITED STATES Map System:US State Pla ne Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Syste m: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: V-214 Slot Name: Well Position: +N/-S 101.27 ft Northing : 5970061.76 ft Latitude: 70 19 40.614 N +E/-W -330.35 ft Easting : 590439.13 ft Longitude: 149 15 59.515 W Position Uncertainty: 0.00 ft Wellpath: V-214PB2 Drilled From: V-214P61 500292327571 Tie-on Depth: 170.00 ft Current Datum: V-214: Height 78.80 ft Above System Datum: Mean Sea Level Magnetic Data: 1 0/28/2005 Declination: 24.46 deg Field Strength: 57579 nT Mag Dip Angle: 80.84 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 25 .70 0.00 0.00 339.17 Survey Program for Definitive Wellpath Date: 12/19/2005 Validated: Y es Version: 3 Actual From To Survey Toolcode Tool Name ft ft 100.00 170.00 V-214P61 GyroData (100.00-951.50) (10) GYD-CT-DMS Gyrodata cont.drillpipe m/s 264.00 451.00 V-214P62 GyroData (264.00-451.00) GYD-CT-DMS Gyrodata cont.drillpipe m/s 487.95 7308.95 V-214P62 IIF R (487.95-7308.95) MWD+IFR+MS MWD +IFR + Multi Station Survey -- A1D Inc! ;~zim TVD Sys TVD \/S E/~~' MapN MapE Tool ft deg deg ft ft ft ft fi ft 25.70 0.00 0.00 25.70 -53.10 0.00 0.00 5970061.76 590439.13 TIE LINE 100.00 0.19 285.15 100.00 21.20 0.03 -0.12 5970061.79 590439.01 GYD-CT-DMS 170.00 0.27 317.17 170.00 91.20 0.18 -0.34 5970061.94 590438.78 GYD-CT-DMS 264.00 1.14 344.20 263.99 185.19 1.25 -0.75 5970063.00 590438.37. GYD-CT-DMS 357.00 2.94 357.67 356.93 278.13 4.52 -1.10 5970066.27 590437.98 GYD-CT-DMS 451.00 4.06 10.31 450.75 371.95 10.20 -0.60 5970071.95 590438.41 GYD-CT-DMS 487.95 4.62 10.87 487.60 408.80 12.95 -0.08 5970074.71 590438.89 MWD+IFR+MS 535.11 5.97 12.95 534.56 455.76 17.21 0.82 5970078.97 590439.75 MWD+IFR+MS 578.17 7.59 13.67 577.31 498.51 22.15 2.00 5970083.93 590440.86 MWD+IFR+MS 627.40 8.81 13.85 626.04 547.24 28.97 3.67 5970090.77 590442.45 MWD+IFR+MS 670.56 9.84 11.62 668.63 589.83 35.79 5.20 5970097.61 590443.90 MWD+IFR+MS 716.67 10.85 8.60 713.99 635.19 43.94 6.64 5970105.78 590445.24 MWD+IFR+MS 761.11 12.20 5.91 757.53 678.73 52.75 7.75 5970114.60 590446.25 MWD+IFR+MS 808.62 13.16 1.72 803.88 725.08 63.15 8.43 5970125.00 590446.80 MWD+IFR+MS 856.65 14.81 356.48 850.49 771.69 74.74 8.22 5970136.59 590446.45 MWD+IFR+MS 905.10 16.39 354.19 897.15 818.35 87.73 7.15 5970149.56 590445.22 MWD+IFR+MS 952.38 17.22 355.25 942.41 863.61 101.34 5.89 5970163.15 590443.80 MWD+IFR+MS 1002.30 19.56 355.86 989.78 910.98 117.04 4.68 5970178.83 590442.40 MWD+IFR+MS 1048.65 21.49 355.00 1033.19 954.39 133.24 3.38 5970195.01 590440.90 MWD+IFR+MS 1099.58 21.69 355.05 1080.54 1001.74 151.90 1.75 5970213.66 590439.05 MWD+IFR+MS 1143.50 22.25 354.66 1121.27 1042.47 168.27 0.28 5970230.01 590437.38 MWD+IFR+MS 1196.30 24.80 353.41 1169.68 1090.88 189.23 -1.92 5970250.93 590434.93 MWD+IFR+MS 1241.42 26.06 354.74 1210.43 1131.63 208.50 -3.92 5970270.18 590432.70 MWD+IFR+MS 1285.76 25.71 354.24 1250.32 1171.52 227.76 -5.78 5970289.42 590430.61 MWD+IFR+MS 1336.46 27.03 354.02 1295.75 1216.95 250.17 -8.08 5970311.79 590428.04 MWD+IFR+MS 1387.95 27.84 353.68 1341.44 1262.64 273.75 -10.62 5970335.34 590425.21 MWD+IFR+MS 1429.50 28.31 354.33 1378.10 1299.30 293.20 -12.66 5970354.76 590422.93 MWD+IFR+MS 1479.69 30.05 354.40 1421.92 1343.12 317.55 -15.07 5970379.08 590420.24 MWD+IFR+MS Halliburton Global Company: BP Amoco Date: 12/20/2005 Time: 06:17:02 --- Page: 2 ~ ~ Field: Pru dhoe Bay Co-ord inate(~]E) Reference: Well: V-214, True North I Site: PB V Pad Vertical (PVD) Refer ence: V- 214:78.8 VI'ell: V-214 Section (VS) Reference: Well (O.OON,O.OOE,339.17Azi) ~~~ ~ellp~th: V-214PB2 Survev Calculation M ethod: M inimum Curvatu re Db: Oracle Sur~~e~~ l~iD Incl Azim TVD Sys't'VD V~/S E/~y' >V1apN MapE Tool ft deg deg ft ft ft ft ft ft 1529.95 34.70 355.50 1464.36 1385.56 344.35 -17.42 5970405.85 590417.56 MWD+IFR+MS 1581.07 37.35 357.08 1505.70 1426.90 374.35 -19.35 5970435.82 590415.27 MWD+IFR+MS 1626.92 37.63 356.84 1542.08 1463.28 402.22 -20.83 5970463.66 590413.46 MWD+IFR+MS 1674.59 38.90 354.72 1579.51 1500.71 431.65 -23.01 5970493.07 590410.92 MWD+IFR+MS 1721.84 39.14 353.92 1616.22 1537.42 461.25 -25.95 5970522.63 590407.62 MWD+IFR+MS 1771.09 36.21 353.32 1655.20 1576.40 491.17 -29.29 5970552.49 590403.92 MWD+IFR+MS 1818.03 36.58 352.82 1692.98 1614.18 518.81 -32.66 5970580.10 590400.23 MWD+IFR+MS 1866.76 39.51 353.37 1731.35 1652.55 548.62 -36.26 5970609.86 590396.26 MWD+IFR+MS 1912.91 41.05 354.46 1766.56 1687.76 578.29 -39.42 5970639.48 590392.75 MWD+IFR+MS 1960.74 41.60 357.20 1802.48 1723.68 609.79 -41.71 5970670.94 590390.08 MWD+IFR+MS 2006.58 45.17 357.48 1835.79 1756.99 641.23 -43.17 5970702.37 590388.24 MWD+IFR+MS 2054.97 50.38 355.13 1868.30 1789.50 676.97 -45.51 5970738.07 590385.47 MWD+IFR+MS 2104.63 51.50 355.61 1899.60 1820.80 715.41 -48.62 5970776.46 590381.90 MWD+IFR+MS 2150.44 51.42 356.15 1928.14 1849.34 751.15 -51.19 5970812.17 590378.89 MWD+IFR+MS 2199.16 53.62 354.82 1957.78 1878.98 789.68 -54.24 5970850.66 590375.38 MWD+IFR+MS 2247.01 55.59 353.58 1985.50 1906.70 828.49 -58.19 5970889.41 590370.96 MWD+IFR+MS I 2297.88 57.32 350.48 2013.61 1934.81 870.46 -64.08 5970931.31 590364.57 MWD+IFR+MS 2343.84 58.23 350.25 2038.12 1959.32 908.80 -70.59 5970969.56 590357.60 MWD+IFR+MS 2394.56 60.66 350.34 2063.90 1985.10 951.84 -77.95 5971012.51 590349.72 MWD+IFR+MS 2441.99 62.99 350.10 2086.29 2007.49 993.04 -85.05 5971053.62 590342.12 MWD+IFR+MS 2490.15 64.73 350.54 2107.51 2028.71 1035.66 -92.32 5971096.14 590334.34 MWD+IFR+MS 2538.37 63.60 349.98 2128.52 2049.72 1078.43 -99.66 5971138.82 590326.49 MWD+IFR+MS i I 2582.34 63.64 350.61 2148.06 2069.26 1117.26 -106.30 5971177.56 590319.38 MWD+IFR+MS ~ 2630.19 63.10 350.41 2169.51 2090.71 1159.45 -113.35 5971219.66 590311.82 MWD+IFR+MS 2677.29 62.10 349.99 2191.18 2112.38 1200.66 -120.47 5971260.77 590304.21 MWD+IFR+MS 2725.82 62.28 350.58 2213.83 2135.03 1242.97 -127.71 5971302.98 590296.46 MWD+IFR+MS 2774.94 64.95 353.98 2235.66 2156.86 1286.56 -133.61 5971346.50 590290.04 MWD+IFR+MS 2822.83 68.11 356.33 2254.73 2175.93 1330.32 -137.31 5971390.21 590285.81 MWD+IFR+MS 2871.39 67.85 356.96 2272.94 2194.14 1375.26 -139.94 5971435.11 590282.64 MWD+IFR+MS 2918.40 67.47 356.41 2290.81 2212.01 1418.67 -142.45 5971478.48 590279.60 MWD+IFR+MS 2967.16 67.89 353.12 2309.33 2230.53 1463.58 -146.57 5971523.33 590274.94 MWD+IFR+MS i 3018.50 67.14 353.06 2328.96 2250.16 1510.67 -152.28 5971570.35 590268.67 MWD+IFR+MS 3063.93 66.70 352.82 2346.77 2267.97 1552.15 -157.41 5971611.76 590263.03 MWD+IFR+MS 3109.82 66.41 352.94 2365.03 2286.23 1593.93 -162.63 5971653.47 590257.31 MWD+IFR+MS 3158.42 66.07 353.01 2384.61 2305.81 1638.07 -168.07 5971697.54 590251.34 MWD+IFR+MS 3207.44 65.26 351.94 2404.81 2326.01 1682.35 -173.92 5971741.74 590244.96 MWD+IFR+MS 3255.30 64.48 351.21 2425.14 2346.34 1725.21 -180.27 5971784.52 590238.10 MWD+IFR+MS 3300.74 64.40 350.88 2444.74 2365.94 1765.71 -186.65 5971824.93 590231.23 MWD+IFR+MS 3350.74 63.84 351.07 2466.57 2387.77 1810.13 -193.71 5971869.26 590223.64 MWD+IFR+MS 3397.36 63.67 351.62 2487.18 2408.38 1851.47 -200.00 5971910.52 590216.85 MWD+IFR+MS 3448.07 65.25 352.08 2509.04 2430.24 1896.76 -206.48 5971955.72 590209.82 MWD+IFR+MS 3495.07 66.00 352.13 2528.44 2449.64 1939.17 -212.36 5971998.05 590203.43 MWD+IFR+MS 3542.93 65.37 349.39 2548.15 2469.35 1982.21 -219.36 5972041.00 590195.91 MWD+IFR+MS 3592.51 65.09 348.32 2568.92 2490.12 2026.38 -228.06 5972085.06 590186.68 MWD+IFR+MS i 3640.22 64.55 346.82 2589.22 2510.42 2068.54 -237.36 5972127.10 590176.88 MWD+IFR+MS 3721.02 63.84 344.16 2624.40 2545.60 2138.96 -255.57 5972197.29 590157.82 MWD+IFR+MS 3804.01 65.75 344.05 2659.74 2580.94 2211.17 -276.14 5972269.24 590136.38 MWD+IFR+MS 3866.45 65.87 341.07 2685.33 2606.53 2265.50 -293.21 5972323.36 590118.66 MWD+iFR+MS 3960.64 65.62 337.72 2724.04 2645.24 2345.87 -323.42 5972403.35 590087.49 MWD+IFR+MS 4056.34 64.09 335.70 2764.70 2685.90 2425.44 -357.66 5972482.49 590052.29 MWD+IFR+MS 4152.85 63.19 332.38 2807.56 2728.76 2503.18 -395.50 5972559.76 590013.52 MWD+IFR+MS 4249.56 63.74 328.85 2850.78 2771.98 2578.55 -437.95 5972634.61 589970.17 MWD+IFR+MS Halliburton Global I Company: BP Amoco Date: 12/20/2005 Time: 06:17'02 - -- Page: 3 Field: Pru dhoe Bay Co-ord inate(~E) Reference: Well: V 214, True North Sitr. PB V Pad Vertical (TVD) Refer ence: V- 214:78.8 V1'cll: V-214 Section (VS) Reference: Well (O.OON,O.OOE,339.17Azi) i i _ Weltpath: V-214PB2 _- __ __ - - - _ Survey _.._ Calculation h ___ 1ethod: M __ inimum Curvature Ub: Oracle _- - _ -- -_I Sunco~ 1VID Incl Azim 1'VD Sys TVD N/S E/W MapN MapE Too] ft deg deg ft ft ft ft ft ft J 4345.46 _ 63.82 327.87 2893.15 2814.35 2651.79 -483.08 5972707.29 589924.17 MWD+IFR+MS 4442.70 63.40 328.38 2936.37 2857.57 2725.76 -529.08 5972780.70 589877.28 MWD+IFR+MS 4538.58 64.24 326.23 2978.68 2899.88 2798.16 -575.56 5972852.53 589829.94 MWD+IFR+MS 4634.38 65.27 324.56 3019.53 2940.73 2869.47 -624.77 5972923.23 589779.88 MWD+IFR+MS 4728.45 64.84 325.46 3059.21 2980.41 2939.35 -673.68 5972992.51 589730.13 MWD+IFR+MS 4825.39 65.13 324.96 3100.20 3021.40 3011.49 -723.80 5973064.04 589679.15 MWD+IFR+MS 4922.12 65.59 325.46 3140.53 3061.73 3083.70 -773.97 5973135.63 589628.12 MWD+IFR+MS 5018.49 65.76 325.88 3180.23 3101.43 3156.22 -823.49 5973207.54 589577.73 MWD+IFR+MS 5114.20 66.48 326.41 3218.97 3140.17 3228.89 -872.24 5973279.61 589528.11 MWD+IFR+MS 5210.65 67.48 326.09 3256.69 3177.89 3302.70 -921.56 5973352.82 589477.91 MWD+IFR+MS 5306.55 66.66 327.16 3294.05 3215.25 3376.46 -970.15 5973425.97 589428.44 MWD+IFR+MS 5401.71 65.73 324.62 3332.46 3253.66 3448.54 -1018.96 5973497.45 589378.77 MWD+IFR+MS 5498.53 64.91 324.09 3372.89 3294.09 3520.03 -1070.23 5973568.31 589326.65 MWD+IFR+MS 5594.46 61.87 324.55 3415.86 3337.06 3589.69 -1120.25 5973637.36 589275.79 MWD+IFR+MS 5690.69 59.05 325.19 3463.30 3384.50 3658.15 -1168.43 5973705.23 589226.80 MWD+IFR+MS 5786.80 55.64 325.55 3515.15 3436.35 3724.72 -1214.41 5973771.23 589180.02 MWD+IFR+MS 5883.08 51.54 325.98 3572.28 3493.48 3788.76 -1258.00 5973834.74 589135.67 MWD+IFR+MS 5979.10 48.04 326.64 3634.26 3555.46 3849.76 -1298.68 5973895.23 589094.26 MWD+IFR+MS 6074.51 44.36 327.19 3700.29 3621.49 3907.44 -1336.27 5973952.45 589055.98 MWD+IFR+MS 6170.77 41.83 326.06 3770.58 3691.78 3962.36 -1372.43 5974006.93 589019.16 MWD+IFR+MS 6266.24 39.02 325.66 3843.25 3764.45 4013.60 -1407.17 5974057.74 588983.82 MWD+IFR+MS 6362.45 35.94 326.97 3919.59 3840.79 4062.29 -1439.65 5974106.03 588950.75 MWD+IFR+MS 6459.07 31.26 327.02 4000.04 3921.24 4107.12 -1468.77 5974150.50 588921.10 MWD+IFR+MS 6555.47 27.63 326.38 4083.98 4005.18 4146.73 -1494.77 5974189.79 588894.62 MWD+IFR+MS 6651.48 24.94 325.00 4170.05 4091.25 4181.85 -1518.71 5974224.62 588870.26 MWD+IFR+MS 6747.01 20.81 322.63 4258.05 4179.25 4211.85 -1540.57 5974254.35 588848.04 MWD+IFR+MS 6843.49 17.37 321.45 4349.21 4270.41 4236.74 -1559.96 5974279.01 588828.36 MWD+IFR+MS 6939.62 19.09 321.22 4440.51 4361.71 4260.22 -1578.75 5974302.26 588809.29 MWD+IFR+MS 7035.87 19.36 321.10 4531.40 4452.60 4284.91 -1598.62 5974326.70 588789.12 MWD+IFR+MS 7131.78 18.33 324.24 4622.17 4543.37 4309.52 -1617.42 5974351.08 588770.03 MWD+IFR+MS 7227.75 17.70 323.61 4713.43 4634.63 4333.51 -1634.89 5974374.85 588752.27 MWD+IFR+MS 7308.95 17.81 322.98 4790.76 4711.96 4353.36 -1649.69 5974394.52 588737.23 MWD+IFR+MS 7380.00 17.81 322.98 4858.41 4779.61 4370.71 -1662.78 5974411.71 588723.94 BLIND • Halliburton Global Company: BP Amoco Date: 12!20/2005 ' l'ime: 06.17:43 Page: 1 i Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: V-214, True Noah '~ Site: PB V Pad Vertical (TVD) Reference: V-214:78.8 Well: V-214 Section (VS) Reference: Well (OAON,O.OOE,340.83Azi) Wellpath: V-214P63 ~-_ __ Sur.~ev Calculation Method: - Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: V-214 Slot Name: Well Position: +N/-S 101.27 ft Northing: 5970061.76 ft Latitude: 70 19 40.614 N +E/-W -330.35 ft Fasting : 590439.13 ft Longitude: 149 15 59.515 W Position Uncertainty: 0.00 ft Wellpath: V-214PB3 Drilled From: V-214P62 500292327572 Tie-on Depth: 3721.02 ft Current Datum: V-214: Height 78.80 ft Above System Datum: Mean Sea Level Magnetic Data: 10/28/2005 Declination: 24.46 deg Field Strength: 57579 nT Mag Dip Angle: 80.84 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 25.70 0.00 0.00 340.83 Survey Program for Definitive Wellpath Date: 12/19/2005 Validated: Yes Version: 5 Actual From To Survey Toolcode T oot Name ft ft 100.00 170.00 V-214P61GYR0 (100.00-170.00) 264.00 451.00 V-214PB2GYR0 (264.00-451.00) 487.95 3721.02 V-214PB2 IIFR (487.95-7308.95) (11) 3803.18 6129.52 V-214PB3 (3803.18-6129.52) Survey MD Inc! Azim IVD Sys"PVD !, ft deg deg ft ft 25.70 0.00 100.00 0.19 170.00 027 264.00 1.14 357.00 2.94 451.00 4.06 487.95 4.62 535.11 5.97 578.17 7.59 627.40 8.81 670.56 9.84 716.67 10.85 761.11 12.20 808.62 13.16 856.65 14.81 905.10 16.39 952.38 17.22 1002.30 19.56 1048.65 21.49 1099.58 21.69 1143.50 22.25 1196.30 24.80 1241.42 26.06 1285.76 25.71 1336.46 27.03 1387.95 27.84 1429.50 28.31 0.0 285.1 317.1 344.2 357.6 10.3 10.8 12.9 13.6 13.8 11.6 8.6 5.9 1.7 356.4 354.1 355.2 355.8 355.0 355.0 354.6 353.4 354.7 354.2 354.0 353.6 354.3 25.70 -53.10 100.00 21.20 170.00 91.20 263.99 185.19 356.93 278.13 450.75 371.95 487.60 408.80 534.56 455.76 577.31 498.51 626.04 547.24 668.63 589.83 713.99 635.19 757.53 678.73 803.88 725.08 850.49 771.69 897.15 818.35 942.41 863.61 989.78 910.98 1033.19 954.39 1080.54 1001.74 1121.27 1042.47 1169.68 1090.88 1210.43 1131.63 1250.32 1171.52 1295.75 1216.95 1341.44 1262.64 1378.10 0 5 7 0 7 1 7 5 7 5 2 0 1 2 8 9 5 6 0 5 6 1 4 4 2 8 3 1299.30 GYD-CT-DMS Gyrodata cont.drillpipe m!s GYD-CT-DMS Gyrodata cont.drillpipe m/s MWD+IFR+MS MWD +IFR + Multi Station MWD+IFR+MS MWD +IFR + Multi Station V/S H:/W ~'IapN ft ft ft 0.00 - _ 0.00 5970061 --- .76 0.03 -0.12 5970061 .79 0.18 -0.34 5970061 .94 1.25 -0.75 5970063 .00 4.52 -1.10 5970066 .27 10.20 -0.60 5970071 .95 12.95 -0.08 5970074 .71 17.21 0.82 5970078 .97 22.15 2.00 5970083 .93 28.97 3.67 5970090 .77 35. 79 5.20 5970097 .61 43. 94 6.64 5970105 .78 52. 75 7.75 5970114 .60 63. 15 8.43 5970125 .00 74. 74 8.22 5970136 .59 87. 73 7.15 5970149 .56 101. 34 5.89 5970163 .15 117. 04 4.68 5970178 .83 133. 24 3.38 5970195 .01 151. 90 1.75 5970213 .66 168. 27 0.28 5970230 .01 189. 23 -1.92 5970250 .93 208. 50 -3.92 5970270 .18 227. 76 -5.78 5970289 .42 250. 17 -8.08 5970311 .79 273. 75 -10.62 5970335 .34 293. 20 -12.66 5970354 .76 ____ - MapE _ -- "Pool ft -- 590439.13 - __-- TIE LINE 590439.01 GYD-CT-DMS 590438.78 GYD-CT-DMS 590438.37 GYD-CT-DMS 590437.98 GYD-CT-DMS 590438.41 GYD-CT-DMS 590438.89 MWD+IFR+MS 590439.75 MWD+IFR+MS 590440.86 MWD+IFR+MS 590442.45 MWD+IFR+MS 590443.90 MWD+IFR+MS 590445.24 MWD+IFR+MS 590446.25 MWD+IFR+MS 590446.80 MWD+IFR+MS 590446.45. MWD+IFR+MS 590445.22 MWD+IFR+MS 590443.80 MWD+IFR+MS 590442.40 MWD+IFR+MS 590440.90 MWD+{FR+MS 590439.05 MWD+IFR+MS 590437.38 MWD+IFR+MS 590434.93 MWD+IFR+MS 590432.70 MWD+IFR+MS 590430.61 MWD+IFR+MS 590428.04 MWD+IFR+MS 590425.21 MWD+IFR+MS 590422.93 MWD+IFR+MS v Halliburton Global ~ Company: BP Amoco Datc: 12/20/2005 'I'imc: 06:17:43 Pale: 2 Field: Pru dhoe Bay Co-ord inate(NE) Reference: Well: V-214, True North Site: PB V Pad Vertica l (f VD) Refer ence: V -214:78.8 Hell: V-2 14 Section (VS) Reference: Well (O.OON,O.OOE,340.83Azi) Welipath: V-2 14PB3 Surrey Calculation M efhod: M inimum Curvature llb: Oracle Survc~~ MD Incl Azim I'VD Sys 'fell N/S E/fib' MapN t~'IapE Tool ft deg deg ft ft ft ft ft ft ~ 1479.69 30.05 354.40 1421.92 1343.12 317.55 -15.07 5970379.08 590420.24 MWD+IFR+MS 1529.95 34.70 355.50 1464.36 1385.56 344.35 -17.42 5970405.85 590417.56 MWD+IFR+MS 1581.07 37.35 357.08 1505.70 1426.90 374.35 -19.35 5970435.82 590415.27 MWD+IFR+MS 1626.92 37.63 356.84 1542.08 1463.28 402.22 -20.83 5970463.66 590413.46 MWD+IFR+MS 1674.59 38.90 354.72 1579.51 1500.71 431.65 -23.01 5970493.07 590410.92 MWD+IFR+MS 1721.84 39.14 353.92 1616.22 1537.42 461.25 -25.95 5970522.63 590407.62 MWD+IFR+MS 1771.09 36.21 353.32 1655.20 1576.40 491.17 -29.29 5970552.49 590403.92 MWD+IFR+MS 1818.03 36.58 352.82 1692.98 1614.18 518.81 -32.66 5970580.10 590400.23 MWD+IFR+MS 1866.76 39.51 353.37 1731.35 1652.55 548.62 -36.26 5970609.86 590396.26 MWD+IFR+MS 1912.91 41.05 354.46 1766.56 1687.76 578.29 -39.42 5970639.48 590392.75 MWD+IFR+MS 1960.74 41.60 357.20 1802.48 1723.68 609.79 -41.71 5970670.94 590390.08 MWD+IFR+MS 2006.58 45.17 357.48 1835.79 1756.99 641.23 -43.17 5970702.37 590388.24 MWD+IFR+MS 2054.97 50.38 355.13 1868.30 1789.50 676.97 -45.51 5970738.07 590385.47 MWD+IFR+MS 2104.63 51.50 355.61 1899.60 1820.80 715.41 -48.62 5970776.46 590381.90 MWD+IFR+MS 2150.44 51.42 356.15 1928.14 1849.34 751.15 -51.19 5970812.17 590378.89 MWD+IFR+MS 2199.16 53.62 354.82 1957.78 1878.98 789.68 -54.24 5970850.66 590375.38 MWD+IFR+MS 2247.01 55.59 353.58 1985.50 1906.70 828.49 -58.19 5970889.41 590370.96 MWD+IFR+MS 2297.88 57.32 350.48 2013.61 1934.81 870.46 -64.08 5970931.31 590364.57 MWD+IFR+MS 2343.84 58.23 350.25 2038.12 1959.32 908.80 -70.59 5970969.56 590357.60 MWD+IFR+MS 2394.56 60.66 350.34 2063.90 1985.10 951.84 -77.95 5971012.51 590349.72 MWD+IFR+MS 2441.99 62.99 350.10 2086.29 2007.49 993.04 -85.05 5971053.62 590342.12 MWD+IFR+MS 2490.15 64.73 350.54 2107.51 2028.71 1035.66 -92.32 5971096.14 590334.34 MWD+IFR+MS 2538.37 63.60 349.98 2128.52 2049.72 1078.43 -99.66 5971138.82 590326.49 MWD+IFR+MS 2582.34 63.64 350.61 2148.06 2069.26 1117.26 -106.30 5971177.56 590319.38 MWD+IFR+MS 2630.19 63.10 350.41 2169.51 2090.71 1159.45 -113.35 5971219.66 590311.82 MWD+IFR+MS 2677.29 62.10 349.99 2191.18 2112.38 1200.66 -120.47 5971260.77 590304.21 MWD+IFR+MS 2725.82 62.28 350.58 2213.83 2135.03 1242.97 -127.71 5971302.98 590296.46 MWD+IFR+MS 2774.94 64.95 353.98 2235.66 2156.86 1286.56 -133.61 5971346.50 590290.04 MWD+IFR+MS 2822.83 68.11 356.33 2254.73 2175.93 1330.32 -137.31 5971390.21 590285.81 MWD+IFR+MS 2871.39 67.85 356.96 2272.94 2194.14 1375.26 -139.94 5971435.11 590282.64 MWD+IFR+MS 2918.40 67.47 356.41 2290.81 2212.01 1418.67 -142.45 5971478.48 590279.60 MWD+IFR+MS 2967.16 67.89 353.12 2309.33 2230.53 1463.58 -146.57 5971523.33 590274.94 MWD+IFR+MS 3018.50 67.14 353.06 2328.96 2250.16 1510.67 -152.28 5971570.35 590268.67 MWD+IFR+MS 3063.93 66.70 352.82 2346.77 2267.97 1552.15 -157.41 5971611.76 590263.03 MWD+IFR+MS 3109.82 66.41 352.94 2365.03 2286.23 1593.93 -162.63 5971653.47 590257.31 MWD+IFR+MS 3158.42 66.07 353.01 2384.61 2305.81 1638.07 -168.07 5971697.54 590251.34 MWD+IFR+MS 3207.44 65.26 351.94 2404.81 2326.01 1682.35 -173.92 5971741.74 590244.96 MWD+lFR+MS 3255.30 64.48 351.21 2425.14 2346.34 1725.21 -180.27 5971784.52 590238.10 MWD+IFR+MS 3300.74 "64.40 350.88 2444.74 2365.94 1765.71 -186.65 5971824.93 590231.23 MWD+IFR+MS 3350.74 63.84 351.07 2466.57 2387.77 1810.13 -193.71 5971869.26 590223.64 MWD+IFR+MS 3397.36 63.67 351.62 2487.18 2408.38 1851.47 -200.00 5971910.52 590216.85 MWD+IFR+MS 3448.07 65.25 352.08 2509.04 2430.24 1896.76 -206.48 5971955.72 590209.82 MWD+IFR+MS 3495.07 66.00 352.13 2528.44 2449.64 1939.17 -212.36 5971998.05 590203.43 MWD+IFR+MS 3542.93 65.37 349.39 2548.15 2469.35 1982.21 -219.36 5972041.00 590195.91 MWD+IFR+MS 3592.51 65.09 348.32 2568.92 2490.12 2026.38 -228.06 5972085.06 590186.68 MWD+IFR+MS 3640.22 64.55 346.82 2589.22 2510.42 2068.54 -237.36 5972127.10 590176.88 MWD+IFR+MS 3721.02 63.84 344.16 2624.40 2545.60 2138.96 -255.57 5972197.29 590157.82 MWD+IFR+MS 3803.18 64.94 345.22 2659.92 2581.12 2210.41 -275.13 5972268.50 590137.40 MWD+IFR+MS 3867.24 65.31 343.42 2686.86 2608.06 2266.37 -290.84 5972324.25 590121.02 MWD+iFR+MS 3924.32 65.96 342.29 2710.41 2631.61 2316.05 -306.17 5972373.74 590105.09 MWD+IFR+MS 3970.18 65.97 340.24 2729.09 2650.29 2355.71 -319.62 5972413.23 590091.17 MWD+IFR+MS 4021.27 65.83 337.85 2749.96 2671.16 2399.26 -336.30 5972456.57 590073.97 MWD+IFR+MS 4068.74 65.56 336.35 2769.50 2690.70 2439.11 -353.13 5972496.22 590056.66 MWD+IFR+MS • Halliburton Global Company: BP Amoco Date: 12/20!2005 'Time: 06:17:43 Patie: 3 Field: Pru dhoe Bay Co-ord inate(NE) Reference. Well: V-214, True North Site: PB V Pad Vertical (TVD) Refer ence: V-214:78.8 WeII: V-2 14 Section (V$) Reference: Well (Q_OON,O.OOE,340.83Azi) VVcllpath: V-2 14PB3 Survey Calculation Method: Minimum Curvature Db: Oracle Sur~~ev D1D Inc! ALim TVD S_vsTVD N/S E/~V MapN Nlipti Tool ft deg deg ft ft ft ft ft ft 4116.98 64.76 334.28 2789.76 2710.96 2478.89 -371.41 5972535.76 590037.90 MWD+IFR+MS 4164.47 63.43 332.66 2810.51 2731.71 2517.10 -390.49 5972573.75 590018.37 MWD+IFR+MS 4212.32 63.42 329.87 2831.92 2753.12 2554.62 -411.06 5972611.01 589997.35 MWD+IFR+MS 4259.28 63.85 328.11 2852.78 2773.98 2590.68 -432.73 5972646.80 589975.24 MWD+IFR+MS 4308.02 63.85 325.71 2874.26 2795.46 2627.33 -456.62 5972683.16 589950.92 MWD+IFR+MS 4322.78 63.46 325.21 2880.81 2802.01 2638.23 -464.12 5972693.96 589943.29 MWD+IFR+MS 4355.25 61.98 325.22 2895.69 2816.89 2661.93 -480.58 5972717.46 589926.54 MWD+IFR+MS 4387.12 62.04 323.95 2910.65 2831.85 2684.87 -496.89 5972740.20 589909.96 MWD+IFR+MS 4454.17 61.71 322.74 2942.26 2863.46 2732.30 -532.19 5972787.20 589874.10 MWD+IFR+MS 4501.15 62.89 321.16 2964.10 2885.30 2765.05 -557.83 5972819.64 589848.07 MWD+IFR+MS 4554.63 64.00 320.49 2988.00 2909.20 2802.14 -588.05 5972856.35 589817.40 MWD+IFR+MS 4596.96 65.91 320.84 3005.92 2927.12 2831.80 -612.35 5972885.72 589792.74 MWD+IFR+MS 4616.54 66.25 321.49 3013.86 2935.06 2845.74 -623.58 5972899.52 589781.36 MWD+IFR+MS 4655.99 66.39 323.62 3029.71 2950.91 2874.42 -645.54 5972927.93 589759.05 MWD+IFR+MS 4692.68 65.84 324.23 3044.56 2965.76 2901.54 -665.30 5972954.80 589738.97 MWD+IFR+MS 4740.34 65.22 325.85 3064.31 2985.51 2937.09 -690.15 5972990.05 589713.69 MWD+IFR+MS 4781.71 64.49 326.33 3081.89 3003.09 2968.17 -711.04 5973020.87 589692.43 MWD+IFR+MS 4834.84 63.22 327.38 3105.30 3026.50 3008.10 -737.12 5973060.48 589665.87 MWD+IFR+MS 4883.70 64.56 328.75 3126.80 3048.00 3045.33 -760.33 5973097.43 589642.22 MWD+IFR+MS 4931.39 65.69 329.09 3146.86 3068.06 3082.38 -782.66 5973134.21 589619.45 MWD+IFR+MS 4980.36 66.31 328.66 3166.78 3087.98 3120.68 -805.78 5973172.22 589595.86 MWD+IFR+MS 5026.06 66.92 328.29 3184.92 3106.12 3156.43 -827.72 5973207.70 589573.50 MWD+IFR+MS 5075.56 67.32 327.98 3204.16 3125.36 3195.17 -851.79 5973246.14 589548.96 MWD+IFR+MS 5094.43 67.93 328.44 3211.35 3132.55 3210.00 -860.99 5973260.86 589539.59 MWD+IFR+MS 5122.73 68.19 328.03 3221.92 3143.12 3232.32 -874.80 5973283.00 589525.51 MWD+IFR+MS 5172.01 67.64 327.09 3240.45 3161.65 3270.85 -899.30 5973321.24 589500.55 MWD+IFR+MS 5219.94 66.78 327.28 3259.01 3180.21 3307.99 -923.25 5973358.08 589476.16 MWD+IFR+MS 5266.87 66.05 327.60 3277.79 3198.99 3344.24 -946.39 5973394.05 589452.58 MWD+IFR+MS 5314.70 67.24 325.70 3296.75 3217.95 3380.92 -970.53 5973430.43 589428.00 MWD+IFR+MS 5360.08 68.97 323.21 3313.68 3234.88 3415.17 -995.01 5973464.38 589403.12 MWD+IFR+MS 5411.17 68.44 324.44 3332.23 3253.43 3453.59 -1023.11 5973502.46 589374.56 MWD+IFR+MS 5452.60 66.10 323.31 3348.24 3269.44 3484.46 -1045.63 5973533.04 589351.67 MWD+IFR+MS 5507.25 63.70 324.82 3371.42 3292.62 3524.52 -1074.68 5973572.75 589322.14 MWD+IFR+MS 5556.24 61.44 323.02 3393.99 3315.19 3559.66 -1100.28 5973607.58 589296.13 MWD+IFR+MS 5603.15 61.54 324.22 3416.38 3337.58 3592.85 -1124.73 5973640.46 589271.28 MWD+IFR+MS 5651.24 60.28 325.10 3439.76 3360.96 3627.13 -1149.04 5973674.44 589246.56 MWD+IFR+MS 5696.29 59.00 323.65 3462.53 3383.73 3658.72 -1171.67 5973705.76 589223.55 MWD+IFR+MS 5748.04 56.50 323.79 3490.14 3411.34 3694.00 -1197.57 5973740.72 589197.23 MWD+IFR+MS 5795.51 54.65 325.85 3516.98 3438.18 3726.00 -1220.13 5973772.44 589174.29 MWD+IFR+MS 5844.15 53.50 327.69 3545.52 3466.72 3758.94 -1241.72 5973805.12 589152.31 MWD+IFR+MS 5892.62 51.57 328.07 3575.00 3496.20 3791.52 -1262.18 5973837.45 589131.46 MWD+IFR+MS 5940.54 51.40 330.06 3604.84 3526.04 3823.68 -1281.45 5973869.37 589111.80 MWD+IFR+MS 5991.61 47.83 330.54 3637.93 3559.13 3857.46 -1300.72 5973902.91 589092.12 MWD+IFR+MS 6002.85 46.74 329.89 3645.55 3566.75 3864.63 -1304.83 5973910.03 589087.94 MWD+IFR+MS 6032.57 44.79 327.89 3666.29 3587.49 3882.86 -1315.82 5973928.12 589076.72 MWD+IFR+MS 6084.33 44.50 324.63 3703.12 3624.32 3913.10 -1336.02 5973958.11 589056.17 MWD+IFR+MS 6129.52 44.23 323.49 3735.42 3656.62 3938.68 -1354.56 5973983.47 589037.32 MWD+IFR+MS 6196.00 44.23 323.49 3783.06 3704.26 3975.95 -1382.15 5974020.40 589009.28 BLIND Halliburton Global Company: BP Amoco Date: 1 212 0/2 0 0 5 'l'ime: 06:20:03 Page: 1 ~ Field: P rudhoe Bay Co-ordinate(NE) Reference. Well: V-214, True North ~ Site: P B V Pad Vertical (TVD) Refer ence: V-214:78.8 Yell: V -214 Section (VS) Reference: Well (O.OON,O.OOE,343.87Azi) Wellpath: V -214PB4 Survey Calcalation Method: Minimum Curvature Db: Oracle Field: - - Prudhoe Bay -- _. -- North Slope UNITED STATES Map System:US State Pla ne Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 {Clarke 1866) Coordinate Syste m: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: V-214 Slot Name: Well Position: +N/-S 101.27 ft Northing : 5970061.76 ft Latitude: 70 19 40.614 N +E/-W -330.35 ft Easting : 590439.13 ft Longitude: 149 15 59.515 W Position Uncertainty: 0.00 ft Wellpath: V-214PB4 Drilled From: V-214P63 5002923273 Tie-on Depth: 3721.02 ft Current Datum: V-214: Height 78.80 ft Above System Datum: Mean Sea Level Magnetic Da ta: 1 2/19/2005 Declination: 24.40 deg Field Strength: 57580 nT Mag Dip Angle: 80.84 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 25 .70 0.00 0.00 343.87 Survey Program for Definitive Wellpath Date: 12/1 9/2005 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 100.00 170.00 V-214P61GYR0 (100.0 0-170.00) (12) GYD-CT-DMS Gyrodata cont.drillpipe m/s 264.00 451.00 V-214P62GYR0 (264.0 0-451.00) (12) GYD-CT-DMS Gyrodata cont.drillpipe m/s 487.95 3721.02 V-214P62 IIFR (487.95- 7308.95) (11) MWD+IFR+MS MWD +IFR + Multi Station 3807.00 5182.70 V-214PB4 IIFR (3807.00-5182.70) MWD+IFR+MS MWD +IFR + Multi Station Survey Mll Intl Azim TVD Sys "1'VD N/S E/W MapN b1apE _- Tool ft deg deg ft ft ft ft ft ft 25.70 0.00 0.00 25.70 -53.10 0.00 0.00 5970061.76 590439.13 TIE LINE 100.00 0.19 285.15 100.00 21.20 0.03 -0.12 5970061.79 590439.01 GYD-CT-DMS 170.00 0.27 317.17 170.00 91.20 0.18 -0.34 5970061.94 590438.78 GYD-CT-DMS 264.00 1.14 344.20 263.99 185.19 1.25 -0.75 5970063.00 590438.37 GYD-CT-DMS 357.00 2.94 357.67 356.93 278.13 4.52 -1.10 5970066.27 590437.98 GYD-CT-DMS 451.00 4.06 10.31 450.75 371.95 10.20 -0.60 5970071.95 590438.41 GYD-CT-DMS 487.95 4.62 10.87 487.60 408.80 12.95 -0.08 5970074.71 590438.89 MWD+IFR+MS 535.11 5.97 12.95 534.56 455.76 17.21 0.82 5970078.97 590439.75 MWD+IFR+MS 578.17 7.59 13.67 577.31 498.51 22.15 2.00 5970083.93 590440.86 MWD+IFR+MS 627.40 8.81 13.85 626.04 547.24 28.97 3.67 5970090.77 590442.45 MWD+IFR+MS 670.56 9.84 11.62 668.63 589.83 35.79 5.20 5970097.61 590443.90 MWD+IFR+MS 716.67 10.85 8.60 713.99 635.19 43.94 6.64 5970105.78 590445.24 MWD+IFR+MS 761.11 12.20 5.91 757.53 678.73 52.75 7.75 5970114.60 590446.25 MWD+IFR+MS 808.62 13.16 1.72 803.88 725.08 63.15 8.43 5970125.00 590446.80 MWD+IFR+MS 856.65 14.81 356.48 850.49 771.69 74.74 8.22 5970136.59 590446.45 MWD+IFR+MS 905.10 16.39 354.19 897.15 818.35 87.73 7.15 5970149.56 590445.22 MWD+IFR+MS 952.38 17.22 355.25 942.41 863.61 101.34 5.89 5970163.15 590443.80 MWD+IFR+MS 1002.30 19.56 355.86 989.78 910.98 117.04 4.68 5970178.83 590442.40 MWD+IFR+MS i 1048.65 21.49 355.00 1033.19 954.39 133.24 3.38 5970195.01 590440.90 MWD+IFR+MS 1099.58 21.69 355.05 1080.54 1001.74 151.90 1.75 5970213.66 590439.05 MWD+IFR+MS 1143.50 22.25 354.66 1121.27 1042.47 168.27 0.28 5970230.01 590437.38 MWD+IFR+MS 1196.30 24.80 353.41 1169.68 1090.88 189.23 -1.92 5970250.93 590434.93 MWD+IFR+MS 1241.42 26.06 354.74 1210.43 1131.63 208.50 -3.92 5970270.18 590432.70 MWD+IFR+MS 1285.76 25.71 354.24 1250.32 1171.52 227.76 -5.78 5970289.42 590430.61 MWD+IFR+MS 1336.46 27.03 354.02 1295.75 1216.95 250.17 -8.08 5970311.79 590428.04 MWD+IFR+MS 1387.95 27.84 353.68 1341.44 1262.64 273.75 -10.62 5970335.34 590425.21 MWD+IFR+MS 1429.50 28.31 354.33 1378.10 1299.30 293.20 -12.66 5970354.76 590422.93 MWD+IFR+MS Halliburton Global ~ ~ Company: BP Amoco Date: 12/20/2005 Time: 06:20:03 Patie: 2 '~ Field: Pru dhoe Bay Co-ord inate(~E) Reference: Well: V-214, True North Site: PB V Pad Vertical ('CVD} Refer ence: V- 214:78.8 ' Nell: V-214 1'1 cllpath: V 214PB4 Section (VS) Reference: Well (O.OON,O.OOE,343.87Azi) Snrr~ey Calculation Method: Minimum Curvature Db: Oracle ~ ~ Surve~~ h1D lncl Azim TVD Sps'fVD N/S E/~V A1apr MapF, Tool ft deg deg ft ft ft ft ft ft 1479.69 30.05 354.40 1421.92 1343.12 317.55 -15.07 5970379.08 590420.24 MWD+IFR+MS 1529.95 34.70 355.50 1464.36 1385.56 344.35 -17.42 5970405.85 590417.56 MWD+IFR+MS 1581.07 37.35 357.08 1505.70 1426.90 374.35 -19.35 5970435.82 590415.27 MWD+IFR+MS 1626.92 37.63 356.84 1542.08 1463.28 402.22 -20.83 5970463.66 590413.46 MWD+IFR+MS 1674.59 38.90 354.72 1579.51 1500.71 431.65 -23.01 5970493.07 590410.92 MWD+IFR+MS 1721.84 39.14 353.92 1616.22 1537.42 461.25 -25.95 5970522.63 590407.62 MWD+IFR+MS 1771.09 36.21 353.32 1655.20 1576.40 491.17 -29.29 5970552.49 590403.92 MWD+IFR+MS 1818.03 36.58 352.82 1692.98 1614.18 518.81 -32.66 5970580.10 590400.23 MWD+IFR+MS 1866.76 39.51 353.37 1731.35 1652.55 548.62 -36.26 5970609.86 590396.26 MWD+IFR+MS 1912.91 41.05 354.46 1766.56 1687.76 578.29 -39.42 5970639.48 590392.75 MWD+IFR+MS 1960.74 41.60 357.20 1802.48 1723.68 609.79 -41.71 5970670.94 590390.08 MWD+IFR+MS 2006.58 45.17 357.48 1835.79 1756.99 641.23 -43.17 5970702.37 590388.24 MWD+IFR+MS 2054.97 50.38 355.13 1868.30 1789.50 676.97 -45.51 5970738.07 590385.47 MWD+IFR+MS 2104.63 51.50 355.61 1899.60 1820.80 715.41 -48.62 5970776.46 590381.90 MWD+IFR+MS 2150.44 51.42 356.15 1928.14 1849.34 751.15 -51.19 5970812.17 590378.89 MWD+IFR+MS 2199.16 53.62 354.82 1957.78 1878.98 789.68 -54.24 5970850.66 590375.38 MWD+IFR+MS 2247.01 55.59 353.58 1985.50 1906.70 828.49 -58.19 5970889.41 590370.96 MWD+IFR+MS 2297.88 57.32 350.48 2013.61 1934.81 870.46 -64.08 5970931.31 590364.57 MWD+IFR+MS 2343.84 58.23 350.25 2038.12 1959.32 908.80 -70.59 5970969.56 590357.60 MWD+IFR+MS 2394.56 60.66 350.34 2063.90 1985.10 951.84 -77.95 5971012.51 590349.72 MWD+IFR+MS 2441.99 62.99 350.10 2086.29 2007.49 993.04 -85.05 5971053.62 590342.12 MWD+IFR+MS 2490.15 64.73 350.54 2107.51 2028.71 1035.66 -92.32 5971096.14 590334.34 MWD+IFR+MS 2538.37 63.60 349.98 2128.52 2049.72 1078.43 -99.66 5971138.82 590326.49 MWD+IFR+MS 2582.34 63.64 350.61 2148.06 2069.26 1117.26 -106.30 5971177.56 590319.38 MWD+IFR+MS 2630.19 63.10 350.41 2169.51 2090.71 1159.45 -113.35 5971219.66 590311.82 MWD+IFR+MS 2677.29 62.10 349.99 2191.18 2112.38 1200.66 -120.47 5971260.77 590304.21 MWD+IFR+MS 2725.82 62.28 350.58 2213.83 2135.03 1242.97 -127.71 5971302.98 590296.46 MWD+IFR+MS 2774.94 64.95 353.98 2235.66 2156.86 1286.56 -133.61 5971346.50 590290.04 MWD+IFR+MS 2822.83 68.11 356.33 2254.73 2175.93 1330.32 -137.31 5971390.21 590285.81 MWD+IFR+MS 2871.39 67.85 356.96 2272.94 2194.14 1375.26 -139.94 5971435.11 590282.64 MWD+IFR+MS 2918.40 67.47 356.41 2290.81 2212.01 1418.67 -142.45 5971478.48 590279.60 MWD+IFR+MS 2967.16 67.89 353.12 2309.33 2230.53 1463.58 -146.57 5971523.33 590274.94 MWD+IFR+MS 3018.50 67.14 353.06 2328.96 2250.16 1510.67 -152.28 5971570.35 590268.67 MWD+IFR+MS 3063.93 66.70 352.82 2346.77 2267.97 1552.15 -157.41 5971611.76 590263.03 MWD+IFR+MS 3109.82 66.41 352.94 2365.03 2286.23 1593.93 -162.63 5971653.47 590257.31 MWD+IFR+MS 3158.42 66.07 353.01 2384.61 2305.81 1638.07 -168.07 5971697.54 590251.34 MWD+IFR+MS 3207.44 65.26 351.94 2404.81 2326.01 1682.35 -173.92 5971741.74 590244.96 MWD+IFR+MS 3255.30 64.48 351.21 2425.14 2346.34 1725.21 -180.27 5971784.52 590238.10 MWD+IFR+MS 3300.74 64.40 350.88 2444.74 2365.94 1765.71 -186.65 5971824.93 590231.23 MWD+IFR+MS 3350.74 63.84 351.07 2466.57 2387.77 1810.13 -193.71 5971869.26 590223.64 MWD+IFR+MS 3397.36 63.67 351.62 2487.18 2408.38 1851.47 -200.00 5971910.52 590216.85 MWD+IFR+MS 3448.07 65.25 352.08 2509.04 2430.24 1896.76 -206.48 5971955.72 590209.82 MWD+IFR+MS 3495.07 66.00 352.13 2528.44 2449.64 1939.17 -212.36 5971998.05 590203.43 MWD+IFR+MS 3542.93 65.37 349.39 2548.15 2469.35 1982.21 -219.36 5972041.00 590195.91 MWD+IFR+MS 3592.51 65.09 348.32 2568.92 2490.12 2026.38 -228.06 5972085.06 590186.68 MWD+IFR+MS 3640.22 64.55 346.82 2589.22 2510.42 2068.54 -237.36 5972127.10 590176.88 MWD+IFR+MS 3721.02 63.84 344.16 2624.40 2545.60 2138.96 -255.57 5972197.29 590157.82 MWD+IFR+MS 3804.01 65.75 344.05 2659.74 2580.94 2211.17 -276.14 5972269.24 590136.38 MWD+IFR+MS 3807.00 64.64 343.90 2661.00 2582.20 2213.78 -276.89 5972271.84 590135.60 MWD+IFR+MS 3819.00 63.84 343.50 2666.21 2587.41 2224.15 -279.92 5972282.18 590132.45 MWD+IFR+MS 3869.00 68.00 341.50 2686.61 2607.81 2267.67 -293.66 5972325.52 590118.19 MWD+IFR+MS 3883.00 66.50 340.50 2692.02 2613.22 2279.88 -297.86 5972337.68 590113.84 MWD+IFR+MS 3934.47 65.02 337.79 2713.16 2634.36 2323.73 -314.56 5972381.32 590096.61 MWD+IFR+MS Halliburton Global it Company: BP Amoco Ffcld: Pr udhoe Bay Site: PB V Pad Wetl: V-214 ~Wellpath: V-214PB4 Sun~ev NiD Incl ft deg 4033.90 65.53 4114.49 63.57 4130.84 63.81 4226.55 62.86 4322.80 63.37 4417.40 62.69 4511.16 63.49 4607.35 63.29 4655.15 65.36 4701.64 65.64 4796.24 62.25 4893.82 63.31 4990.20 64.61 5086.27 65.34 5113.10 65.38 5182.70 66.99 5336.00 66.99 Azim TVD SvsTVD deg ft ft 336.27 2754.75 2675.95 332.04 2789.39 2710.59 333.80 2796.64 2717.84 330.82 2839.60 2760.80 327.13 2883.13 2804.33 327.68 2926.04 2847.24 326.86 2968.47 2889.67 325.82 3011.56 2932.76 325.29 3032.27 2953.47 326.15 3051.55 2972.75 326.85 3093.09 3014.29 325.31 3137.73 3058.93 325.96 3180.04 3101.24 325.72 3220.68 3141.88 326.01 3231.86 3153.06 325.40 3259.96 3181.16 325.40 3319.89 3241.09 Date: 12/20/2005 Cin~e: 06:20:03 Page: 3 Co-ordinafe(NE) Reference: Well: V-214, True North Vertical (TV D) Reference: V-214:78.8 Section (VS) Reference: Well (O.OON,O.OOE,343.87Azi) Surcev Calculation (Method: Minimum Curvature Db: Oracle N/S E/~~' nlapN MapE Tool ft ft ft ft i 2406.88 2472.36 2485.41 2561.13 2634.68 2705.71 2776.04 2847.62 2883.15 2918.10 2988.95 3060.95 3132.44 3204.47 3224.65 3277.25 3393.40 -349.81 5972464.03 -381.50 5972529.12 -388.17 5972542.08 -427.90 5972617.32 -472.14 5972690.32 -517.56 5972760.79 -562.76 5972830.56 -610.43 5972901.56 -634.80 5972936.78 -658.62 5972971.45 -705.53 5973041.72 -753.95 5973113.13 -802.83 5973184.01 -851.71 5973255.44 -865.40 5973275.45 -901.27 5973327.61 -981.40 5973442.78 590060.37 MWD+IFR+MS 590027.90 MWD+IFR+MS 590021.07 MWD+IFR+MS 589980.43 MWD+IFR+MS 589935.31 MWD+IFR+MS 589889.04 MWD+IFR+MS 589843.00 MWD+IFR+MS 589794.48 MWD+IFR+MS 589769.69 MWD+IFR+MS 589745.44 MWD+IFR+MS 589697.69 MWD+IFR+MS 589648.40 MWD+IFR+MS 589598.67 MWD+IFR+MS 589548.93 MWD+IFR+MS 589535.01 MWD+IFR+MS 589498.50 MWD+IFR+MS 589416.99 PROJECTED to TD V-2141 Suspe CeOar Elevation =53.1' !Munn 1 fi RKR = 74 S' ^'2( 101' 3-1 /2", 9.2#/ft, NSCT, Kill String 2,752` Comp{etion 9-5/8", 40 #/ft, L-80, BTC 3,758` 3,808` ,,_. 3,820` ._ ... r TREE 4-1/16" 5M WELLh__ D: FMC Gen 5 System 11 ", SM csg.head w/ 7" mandrel hanger & packoff 11 " x 11", 5M, tbg spool w/ 11" x 4-1 /2" tubing hanger 11" X 4-1/16" Adaptor Flange 20" X 34" 215.5 Ib/ft, A53 ERW Insulated PB#1 TD at 1006' 2,740` 3-1/2", X-Nip, ID = 2.813 2,752` 3-1/2", WLEG 3,915` 8 3/4", TD (PB#3 -Unintentional Sidetrack & 1st intersection attempt) / 4,750` 6,196` 5,336` 6 3/4", TD (PB#4 -Successful Intersection & P&A) 7,380` 8 3/4", TD (PB#2, Original Injector Mainbore) Date Rev By Comments 30-Nov-05 MJM Suspended Completion 3,f .~ ~ as~<r' WELL: V-2141 API NO: 50-029-23275 • • 03-Jan-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well V-214 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 25.70' MD Window /Kickoff Survey: 951.50' MD (if applicable) Projected Survey: 1,006.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. n / Anchorage, AK 99518 ~// ~ ~~ ~~ / Date ~~ow.~.158 ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) al,o~ ~ (3`~ ~~~-e~ • • 03-Jan-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well V-214 PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 170.00' MD Window /Kickoff Survey: 7,308.95' MD (if applicable) Projected Survey: 7,380.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Owe 6 Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • C, 03-Jan-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well V-214 PB3 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 3,721.02' MD Window /Kickoff Survey: 6,129.52' MD (if applicable) Projected Survey: 6,196.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 5 _~~~ ~~~ • C. 03-Jan-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well V-214 PB4 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 3,721.02' MD Window /Kickoff Survey: .5,182.70' MD (if applicable) Projected Survey: 5,336.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date G ati Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~ ~ s'_ ~ ~ ~ a~l~ Re: PBU V-2141 Sundry Number: 305-370 Dear Mr. Tirpack: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this J day of December, 2005 Encl. • STATE OF ALASKA F /L~s ALASKA OIL AND GAS CONSERVATION COMM SION % ~~C ~ ~ ~~~ APPLICATION FOR SUNDRY APPROVAL Ahaka n;~ $ Gas Cons. Come 20 AAC 25.280 Anchorage 1. Type Of Request: ^ Abandon ®Suspend ^ Operation Shutdown ^ Perforate ^ Other __ ^ Alter Casing ^ Repair Wefl ^ Plug Pertorations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 205-134 ~ ress: ^ Stratigraphic ®Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 ; 50-029-23275-00-00 7. KB Elevation (ft): 78 8' 9. Well Name and Number: PBU V-2141 8. Property Designation: 10. Field /Pool(s): ADL 028240 Prudhoe Bay Field / Orion Schrader Bluff it. PRESENT WELL CO NDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7380 ~ 4858 3541 2547 3541 None Casin Len th Size MD TVD Burst Colla se I 102' 20" 102' 102' 3730' 9-5/8" 3757' 2640' 5750 3090 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None None 3-1/2", 9.2# 2752' (Kill String) / Packers and SSSV Type: None Packers and SSSV MD (ft): N/A 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Senrice ^ Detailed Operations Program ~, 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November 2005 ^ Oil ^ Gas ®Plugged ^ Abandoned 18. Verbal Approval: Date: 11/27/205 ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Re resentative: Winton Aubert ,/ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Martyrs, 564-4101 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/NUmber: T i H bbl 564 4628 ~~ err - e u e, Si nature ~ ~ Phone 564-4166 Date ~ ~ ~ Commission Use Only Sundry Number: - '~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: '~(~{S ~(~ SEC 0 6 2005 ubsequent F rm quired - 7 , ' APPROVED BY ~ j Appro ed By COMMISSIONER THE COMMISSION Date ~f~ 0 Form 1d~403~P~j~d 0 005 -(-~ t ~~ ~~ Sut~nit Ir~Duplicate • by To: Winton Aubert - AOGCC From: Matt Martyn - BPXA GPB Rotary Drilling Subject: V-214i P&A for Well Suspension Reference: API # 50-029-23275 • Date: November 30, 2005 Over the weekend BP obtained verbal approval for suspension of operations of the planned injection well V-2141. Attached is the wellbore schematic of the V-2141 suspended completion. As this is not the standard completion schematic, I'll explain a bit of how this came to be. Doyon-16 cased surface hole w/ 9-5/8" casing, and drilled 8-3/4" production hole as planned. When attempting to run 7" production casing, the casing shoe would not pass 3,820' MD. While attempting to clean out the obstruction with an 8-3/4" bit, we unintentionally sidetracked the well at 3,820' MD (the wellbore exiting to the right on the schematic). We continued drilling 8-3/4" hole, unsuccessfully trying to intersect the original wellbore before 6200' MD. Unable to re-enter the original wellbore, we filled the sidetrack with cement to 3,808' MD and drilled 6-3/4" hole out of open hole at 3,808' MD (the wellbore. exiting to the left on the schematic). We succeeded in re-entering our original wellbore at 3,915' MD and washed and reamed to 5,530' MD before realizing from log comparison that we had likely exited the original wellbore at 4,750' MD. ~ After several attempts to re-enter the wellbore again from our sidetrack point 4,750' MD the decision was made to suspend the well for further review with the intent of drilling V-214Ai to a similar target pending regulatory approvals. Matt Martyn Operations Drilling Engineer 564-4101 desk 632-3862 cell V-2141 Application for Sundry I V-214i Suspension Completion Cegar Elevation =53.1' Doyen 16 RKB = 74.5' -20 101' 3-1/2", 9.2#/ft, NSCT, Kill String 2,752` 9-5/8", 40 #/ft, L-80, BTC 3,758' :~ 4 3,808` /I 3,915` / 4,750` 5,330` 6 3/4", TD (PB#3 -Successful Intersection & P&A) TREE: 4-1/16" SM WELL :FMC Gen 5 System 11", 5M csg.head w/ 7" mandrel hanger & packoff 11"x 11", SM, tbg spool w/ 11 " x 4-1 /2" tubing hanger 11" X 4-1/16" Adaptor Flange ~ 20" X 34" 215.5 Ib/ft, A53 ERW Insulated 2,740` 3-1/2", X-Nip, ID = 2.813 2,752` 3-1/2", WLEG Date ~ Rev By ~ Comments 30-Nov-05 MJM Suspended Completion cw • " d .• 8 3/4", TD (PB#2 -Unintentional Sidetrack & 1st intersection attempt) 6,196 ` ~ p~ a f~ r I '~ r r a '1 ~~ 8 a y r WELL: V-2141 API NO: 50-029-23275 7,380` 8 3/4", TD (Original Injector Mainbore) V-214iSundry C7 Subject:-V-2141 Sundry From: "Martyrs, Matthew" <Matthew.Martyn@bp.com> Date: Fri, 02 bec 2005 12:05:00 -0900 To: winton_auhert@admin.state.ak.us CC: "Tirpack; Robert B" <TirpacRB~a bp.com>; "Hubble. Terrie L" <HubbleTL@bp.com> Winton, Got your message. Thanks for the call. The information you requested for V-214 P&A is as follows: For the P&A of the 8-3/4" hole that is shown on the schematic to the right of the borehole, we pumped a total of, 44 BBLS of 15.8# class G cement in three plugs and circulated back up from 3800' MD (Assuming a 30% excess, 8.75" open hole volume from 6,196 to 3,760' MD is 236 BBLS). On following trip in, we tagged up at 3,808' MD w/ 10,000 lbs. before kicking off and attempting our second intersection. For the P&A and suspension of the 6-3/4" hole (shown exiting to the left on the re schematic) we pumped 120 BBLS of 15.8# class G cement in two plugs (30% excess 6.75" OH volume i 91 BB S. 400' of 9-5/8"x40# casing capacity is 30 BBLS) and circulated up contaminated mud from 3,191' MD. next trip in hole, witnes waived by Chuck Sheave and we tagged up on Cement top at 3800' MD.~IVe followed that up with another plug 22 LS 15.8# G cement (290' of Casing Capacity) and Lou Grimaldi of the AOGCC witnessed the 10,000# tag an 000 psi pressure test of the cement plug at 3,541' MD. If you have any other question, please don't hesitate to call. Matt Marlyn Operations Drilling Engineer GPB Rotary -Prudhoe Bay, Alaska 900 E. Benson Blvd. Anchorage, AK 99519 (907) 564-4101 -office (907) 632-3862 -cell (907)564-4040-fax 1 of 1 12/5/2005 7:30 AM • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission n TO: Jim Regg Petroleum Engineer C G I ~~~p5 DATE: November 29, 2005 THRU: FROM: Lou Grimaldi, Petroleum Inspector SUBJECT: Plug Verification BPX PBU V-214 R`TD 20~-~34 Tuesday, November 29, 2005; f witnessed verification of plug integrity for the suspension of operations on this well. I arrived to find the rig hanging approximately 500' from the estimated top of cement. The rig tripped in the hole to 3541.87 where the cement was tagged with approximately 10K of down force. The pipe was pulled up one stand and a 1000 psi pressure test was applied for 15 minutes with no loss of pressure observed. 11 was reported to me that the casing shoe was at 3758' which should place the top of cement approximately 217' inside the casing. NON-CONFIDENTIAL 2005-1129_P&A_pl ug_verify_P BU_V-214_Ig. doc r • 3 ~~, ' ~~ { ~ ~ <, ~ ' ~ ' ~~. ~ ~ FRANK H. MURKOWSK/, GOVERNOR .~ ~ L~ °~-~~ OI~ ~ ~7 333 W. 7TM AVENUE, SUITE 100 C011TSE`RQA'1`I011T COMIrIISSIOrIT ANCHORAGE, ALASKA 99501-3539 PHONE (907j 279-1433 FAX (907) 276-7542 Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe V-2141 BP Exploration (Alaska) Inc. Permit No: 205-134 Surface Location: 4816' FSL, 1862' FEL, SEC. 11, T 11 N, R 11 E, UM Bottomhole Location: 3892' FSL, 3516' FEL, SEC. 02, 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 approvals 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. Please provide at least twenty- four (24) hours notice for a representative of the mission to witness any required test. Contact the Commission's petrole m fi d inspector at (907) 659- 3607 (pager). ,,,.,,~ l,..dohr~K~i Chairman DATED this- day of September, 2005 cc: Department of Fish 8~ Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. t'~G~} '~ r~~~~s STATE OF ALASKA ALASKA UIL AND GAS CONSERVATION COMMtSS1C3N ° ~°- PERMIT TO DRILL ' `~°~ 20 AAC 25.005 ~~~~~ ~~ ~~ ~=~~ '~~' 1a. Type of work ®Drill ^Redrill ^ Re-Entry 1b. Current Well Class ^ Explorato ^ Development pil ^ Multiple Zone ^ Stratigraphic Test ®Service ~ ^ Development ~as~,=^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. WeII ~Jatn~'i Number: PBU V-2141 ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 7346 TVD 4830 12. Field /Pool(s): Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): Surface: 4816' FSL 1862' FEL SEC 11 T11 N R11 E UM ' 7. Property Designation: ADL 028240 Schrader Bluff , , . , , , Top of Productive Horizon: 3683' FSL, 3367' FEL, SEC. 02, T11N, R11E, UM 8. Land Use Permit: 13. Approximate Spud Date: September 15, 2005 Total Depth: 3892' FSL, 3516' FEL, SEC. 02, T11 N, R11 E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 12175' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 590439 y- 5970062 Zone- ASP4 ~ 10. KB Elevation (Height above GL): 74.6 feet 15. Distance to Nearest Well Within Pool 1340' away from V-102 16. Deviated Wells: Kickoff Depth: 300 feet Maximum Hole Angle: 65.2 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2030 Surface: 1575 ~ 1 asing Program: Size Specifications Setting Depth To Bottom Quantity of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42' 20" 215.5# A-53 Welded 80' 22' 22' 102' 102' 60 sx Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BTC 3728' 22' 22' 3750' 2634' 565 sx AS Lite, 365 sx Class 'G' 8-3/4" 7" 26# L-80 BTC-M 7324' 22' 22' 7346' 4830' 257 sx Class 'G' ~ 19. PRESENT WELL CONDITION SUMM ARY (To be comptetedfioi• 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): Casing Length Size Cement Volume MD TVD n Pr ti n Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Martyr, 564-4101 Printed Name Robert Tirpack Title Senior Drilling Engineer ~~ Prepared By Name/Number: Si nature ~ /~' Phone 564-4166 Date c/ Sondra Stewman, 564-4750 Commission Us® Only Permit To Drill Number: 2t'd~ ~- 3 API Number: 50- t%L~/ - Z ~ 2 j ~ Permit A pro I Date: ~ ~~~ See cover letter for other requirements Conditions of Approval: Samples eq fired ^ Yes .~ No ~ .~:,~A/lud Log Required ^ Yes o ,~ ,,~ H dro n S fide Measures ^ Yes ~No ~' iZ' jDirectionlal Survey Required Yes ^ No'q 12 ~ ~ Other: ~"t'Sf R~ F '~'~ a Pl6~ • M ~ T ~ C.~.rt ,ems ~ ~ ct~;.L,, j'C4i ~ `~ (^p y tc,~ vw?~ . ~$ ~' S ° ~~ Ch) C~ ), ~-(E~y~~'~ f3G'nl~~. ~l~S~ I~~rc°r~d~~,~-~ i< ~j~ro~ ~, APPROVED BY A roved B ~ r THE COMMISSION Date Form 10-401 Revised 0 04 ~~Y`>, ~~,,~~~~ ~~~~~° ~~+'- r Submit In Duplicate • • Variance Request i Issue Compliance with AOGCC testing requirements for BOP rams after they have been used in the normal coarse of operations. Request The AOGCC is in the process of developing a guideline document clarifing the intent of the ~...... regulations pertaining to function pressure testing ram type BOP's. BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have i compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. Background AOGCC regulations require rams that have been used in the course of primary drilling & completion, workover and through tubing drilling operations be function pressure tested before the next wellbore entry. This is not a new regulation. The intent of this regulation is to ensure that ram type equipment has integrity after it has been utilized in a wellbore...for example; to ensure integrity if a ram was closed on a tool joint. The exact regulation language is: "if BOP sealing ram type equipment has been used, it must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Drill, using anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure;" The pertinent sections are: 20 AAC 25.035 (e)(10)C PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285 (f)(2) TUBING WORKOVERS; 20 AAC 25.286(e)(1) WORKSTRING SERVICE OPERATIONS This issue has been discussed with Winton Aubert at the AOGCC. The test requirement in the regulation is intended to apply to ram type equipment only. The AOGCC understands that ram type BOP's are utilized for purposes other than well control in the normal coarse of operations. The regulations allowing a variance are at 20 AAC 25.035(h) PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036(f) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285(h) TUBING WORKOVERS; 20 AAC 25.286(g) WORKSTRING SERVICE OPERATIONS...which says generally: 20 AAC 25.035(h)... Upon request of the operator, the commission will, in its discretion, ~ approve a variance (1) from the BOPE requirements in (e) of this section if the variance provides at least an equally effective means of well control; V214i Well Plan Summary Page • • Well Name: V-2141 Last Revision: 9/1/05 Well Plan Summary T e of Well roducer or injector : USH Injector Surface Location: 4816' FS 1 62' FEL, Sec. 11, Ti 1 N, R11 E Slot NE As Built X = 59 39 3 Y = 5,970,061.76 Shallow Target 1492' F 2086' FEL, Sec. 2, T11 N, R11 E Coordinates o SV1 : X = 590,190 Y = 5,972,015 Z = -2542' TVDss Target Start ASP 3683' FSL, 3367' FEL, Sec. 2, T11 N, R11 E Coordinats To OA : X - 88,838 5,974,246 Z = -4245' TVDss BHL ASP Coordinates:~~~ L FSL, FEL, Sec. 2, T11 N, R11 E ~ ` ' ' = b88,72 = 5,97u4 ~9$ , TVDss Z~= -4755 ~,~I~ 1~IGl~- AFE Number: ORD5M3585 Ri Doyon 16 GL: 53.1' KB: 21.5' Estimated Start Date: September 15 , 2005 O eratin da s to com lete: 14 TD: 7,346' MD TVD: 4,830' Max Inc: 65.2° KBE: 74.6' Well Design: USH Grassroots Schrader Injector 3-%2" TCII 4-Packer Com letion. Current Well Information General Distance to Nearest Property: 12,175' to PBU boundary Distance to Nearest Well in Pool: 1,340' to V-102 at top Na API Number: 50-029-XXXXX Well Type: Development -Orion Schrader Injector Current Status: New well, 20" X 34" insulated conductor Conductor: 20" X 34", 215.5 Ib/ft, A53 ERW set at 101' RKB BHP: 2030 psi -Top of OBf Sand (8.6 ppg Cad 4560' TVDss) BHT: 85°F C~ 4,550' TVDss estimated '/a Mile Wellbore Near Wellbore Mechanical Integrity Summary: / There are no other wells within 1/a mile of this injector at its penetration at the Top Na structure. No Near W ellbore integrity issues. ~ - t ~ Z . Anti-Collision Issues: On a Global Scan, all wells pass BP's major risk assessment V214i Well Plan Summary Page Formation Markers V-2141 (Based on soR) • Commercial Est. Form. Top Hydrocarbon Est. Pore Est. Pore Bearin Press. Press. Formation (MD) (TVD-kb) (TVDss) (Yes/No) (Psi) ( EMW) Gl 314 314 -240 No 108 8.7 SV6 964 954 -880 No 396 8.7 SV5 1728 1620 -1545 No 695 8.7 1905 1750 Poss. Gas SV4 -1675 H drates 754 8.7 Base Permafrost 1941 1775 -1700 No 765 8.7 2621 2160 Poss. Gas SV3 -2085 H drates 938 8.7 Fault 1 ("V Pad Fault") 3026 2329 -2255 3026 2329 Poss. Gas SV2 (Faulted To) -2255 H drates 1015 8.7 3516 2534 Poss. Hydrates SVl -2460 or Free Gas 1107 8.7 UG4 4218 2834 -2760 Thin coal 1242 8.7 4300 2869 Heavy Oil betty 2825 and 3030' UG4A -2795 SS 1258 8.7 5077 3194 Heavy Oil betty 3110 and 3200' UG3 -3120 ss 1404 8.7 6017 3654 Heavy Oil betty UGl -3580 3710 - 3850' SS 16 t 1 8.7 6373 3929 Heavy Oil betty Ma -3855 3850 - 3890' SS 1735 8.7 6420 3969 Heavy Oil betty Mbl -3895 3900 - 3940' SS 1753 8.7 6494 4034 Heavy Oil betty Mb2 -3960 3970-3990' SS 1782 8.7 6556 4089 Heavy Oil betty Mc -4015 4035-4060' ss 1820 8.7 Na 6626 4154 -4080 No 1845 8.7 Nb 6653 4179 -4105 Yes 1850 8.7 Nc 6701 4224 -4150 Yes 1870 8.7 OA 6802 4319 -4245 Yes 1670 7.6-8.3 OBa 6866 4379 -4305 Yes 1885 8.0-8.3 OBb 6909 4419 -4345 Yes 1900 8.4-8.6 OBc 6973 4479 -4405 Yes 1935 8.6-8.8 OBd 7026 4529 -4455 Yes 1750 7.6-8.3 OBe 7095 4594 -4520 Yes 2010 8.6 OBf -4560 Yes 2030 8.6 OBf Base -4605 No 2050 8.6 T.D. 7345 4830 -4755 ~, 2 ~, 2 V214i Well Plan Summary Page • • Casinq/Tubinq Program Hole Size Csg / Tb O.D. WUFt Grade Conn Burst si Collapse si Length Top MD /TVDrkb Bottom MD /TVDrkb 42" 20" 215.5# A-53 Welded 80' 22' / 22' 102' / 102' 12-~/a" 9-5/e" 40# L-80 BTC 5,750 3,090 3,728' 22' / 22' 3,750' / 2,634' 8-3/a" 7" 26# L-80 BTC-M 7,240 5,410 7,324' 22' / 22' 7,346' / 4,830' Tubin 4'/z" 12.6# L-80 TCII 8,430 7,500 20' 22' / 22' 42' / 42' Tubin 3'/z" 9.30# L-80 TCII 10,160 10,530 7008' 43' / 43' 7,051 MD _Mud Program: ~ 12 ~/a" Surface Hole Mud Properties: Spud -Freshwater Mud Interval Densit Funnel Vis PV YP FL Chlorides PH 0-1,850' Base Perm 8.8 - .2 250-300 20-45 50-70 NC-8.0 <1000 9.0-9.5 1,850-3,757 TD 9. -9. 200-250 20-40 40-50 8.0-7.0 <1000 9.0-9.5 8 3/a" Production Hole Mud Properties: Freshwater Mud (LSND) Interval Densi Funnel Vis PV YP FL H Chlorides MBT Surface shoe to TD 8.8 - 9.3 38-50 10-16 18-24 4.0-6.0 9.0-9.5 <600 < 20 Survev and Loaaina Proaram: 12-'/a" Hole Section: Surface Gyro will be needed (run to 1200' or as conditions dictate) O en Hole: MWD / GR Cased hole: None 8-3/a" Hole Section: MWD / GR / Res /Den / Neu / PWD (All real-time) Cased Hole: USIT PDC mode /dual packer MDT Bit Recommendations BHA Hole Size De the MD Bit T e Nozzles K-Revs Hours Surface 12-'/a" 0' -1800' Hu hes MXC-1 18/18/18/16 Surface 12-'/a" 1800 - 3750' Hu hes MXC-1 18/18/18/16 Production 8-3/a 3750' - 7346' H calo DSX147GNVW-D2 6x14 Motors and Required Doglegs BHA Motor Size and Motor Re uired Flow Rate RPMs Re uired Do le s 1 8" Sperrydrill 4/5 ml, 5.3 stg perf motor set @ 1.83° 425 - 600 40-65 1.5°/100' initial build w/ 12 1/8" sleeve stabilizer & 12 1/8" strin stab m 4.0°/100' final build 2 8" Sperrydrill 4/5 ml, 5.3 stg pert motor set (~ 1.5° w/ 425 - 700 60-100 4.0°/100' Build 12 1/8" sleeve stabilizer & 12 1/8" strin stab m 3 7" Sperrydrill 7/8 ml, 6.0 stg perf motor set C~ 1.5° w/ 500 - 700 60-100 4.0°/100' Drop 8.625" sleeve stabilizer & 8 1/2" strin stab m V214i Well Plan Summary Page Surface and Anti-Collision Issues Surface Shut-in Wells: Nearb Well V-202 V-101 Distance to V-214i 14.61 15.01 V-202 & V-101 will require surface shut-in and wellhouse removal in order to move over well V-2141. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. Cement Calculations: Casin Size: 9-s/e-in 4 - /ft L-80 BTC -Single Basis: Lead: 250% xces over gauge hole in per Lead TOC• Surfa Tail: 1,000 en hole with 30% excess, Tail TOC: 2760' MD Total Cement Volume: Spacer 75 bbls of Viscos Lead 445 bbls, 2500cu Tail 75 bbls, 421 cuft Temp BHST ~ 48° F, B 30% excess over gauge :er weighted to 10.0 ppg (~ 10.7 Ib/gal ASL (G + adds 15.8 Ib/gal Class G + adds F estimated by Schlumberc k In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casin Size: 7" 26 Ib/ft L-80 BTC-M -Single Stage Basis: Lead: None Lead TOC: N/A Tail: 1,572' en hole with 30% excess, plus 80' shoe track Tail TOC• ,77 MD 500' MD above tanned Ma to at 6,374' MD Total Cement Vol Wash 15 bbls CW100 S acer 30 bbls of Viscosif' S acer Mud ush II Desi n 1 above mudwei ht Tail 55 bbls, 309 cuf , 25 15.8 Ib/ al G + Gasblok 1.2 uft/sk Temp BHST =100° F, 80° F estimated by Schlu _ er Centralizer Recommendations: 9 5/e" Casing Centralizer Placement a) Run (25) 9-5/6" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 2,750' MD (1,000' MD above the shoe). b) Run 2Bow-spring centralizers on either side of the TAM Port Collar (if run). 7" String Centralizer Placement a) Place 2 rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. b) With the exception stated above, run one centralizer per joint, floating across the entire joint up to 5,774' MD (500' MD above Ma sand). Zonal isolation with cement is required across the Ma sands. The centralizer program is subject to change pending modeling and hole conditions. V214i Well Plan Summary Page 4 • • Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi. Due to test pressures not exceeding S,000psi it will not be necessary to have two sets of pipe rams installed at all times. BOP regular test frequency for V-2141 will be 14 days. Below is an excerpt from the permit application requesting a variance to the requirements of 20 AAC 25.035 (e)(10)C PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285 (f)(2) TUBING WORKOVERS: or, 20 AAC 25.286(e)(1) WORKSTRING SERVICE OPERATIONS "BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, exce t when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment." Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 7" Casing Test: • Integrity Test - 8-3/4" hole: Kick Tolerance: • Planned completion fluid: Disposal 20 si -Top of OBf Sand (8.6 ppg ~ 4560' TVDss) ,57 psi -Based on a full column of gas C~ 0.10 psi/ft 00 psi/250 psi Rams % 2,500 psi/250 psi Annular 4,000 psi 10.7 ppg minimum EMW LOT 20' from 9-5/8" shoe 51.8 bbls with an 10.7 ppg EMW LOT Estimated 9.0 ppg Brine (w/6.8 ppg Diesel freeze protect) • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. V214i Well Plan Summary Page 5 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in the Polygon 2 fault block is expected to be normal to sub-normally pressured at 7.6-8.8 ppg EMW. II. Hydrates and Shallow gas A. Gas Hydrates are present at V-pad and have been encountered in wells as close as V-100 and V-111 and throughout the SV4, SV3, SV2, and SV1. Setting casing through the SVi should keep hydrate exposure from extending past the surface hole. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Both offset wells to V-100 and V-111 had to have the mud treated and were able to drill to section TD. In V-100 the hydrates came from the SV1. Occasionally hydrates are encountered below the SV1. III. Lost Circulation/Breathing A. Lost circulation is not expected due to the benign nature of V Pad fault and the second fault in the Ugnu Ma. In addition the faults will be crossed at high angle and move away quickly. • Note: Massive losses were encountered on L pad at L-118 due to high penetration rates (1100-1300 fph) and inadequate hole cleaning strategy. B. We do not expect breathing on this well. IV. Kick Tolerance/Integrity Testing A. The 9 5/e" casing will be cemented to surface. B. The 7" casing will be cemented with 15.8 Ib/ga i cement to 600' MD above the Ma sand 5,774' MD. C. The Kick Tolerance for the surface casing is 1.8 bls with 9.0 ppg mud, 10.7 ppg LOT, and an 8.8 ppg pore pressure. D. Integrity Testing Test Point Test De th Test t e EMW 1b/ al 9 5/6-in shoe 20-ft minimum from 9 $/8--in shoe LOT 10.7 minimum V. Stuck Pipe A. We do not expect stuck pipe if the hole is kept adequately clean. VI. Hydrogen Sulfide V Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: o Adjacent producers at Surface: o Adjacent producers at TD: V-102 10 ppm V-102 10 ppm V-101 10 ppm V-201 110 ppm VII. Faults A. One fault is expected to be crossed in V-214i. No losses are expected to be associated with this fault. Details are listed below for reference: Fault 1 ("V" Pad Fault -SV3): 3026' MD 2330' ND -2255' TVDss Throw: 125' SW VIII. Anti-Collision Issues All wells pass Major Risk criteria. Gyro will need to be run within 1200' of surface or as conditions dictate for clean directional measurements due to the surface proximity to neighboring wellbores. CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION V214i Well Plan Summary Page 6 • • V-214i -Drill and Comalete Procedure Summar Pre-Rig Work: 1. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Prepare neighboring wells for the rig move and simops production. Shut in V-101 and V-202 and remove well houses as necessary. Rig Operations: 1. MIRU Doyon 16. 2. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 12-'/a" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3,750' MD. The actual surface hole TD will be 100' TVD below the top of the SV1 sands. 4. Run and cement the 9 5/8", 40.0-Ib/ft. surface casing back to surface. A TAM Port Collar will be run in the% casing string only i hole conditions dictate. 5. ND diverter spool and NU casing /tubing head. NU BOPE and test to ,00~}'psi. 6. MU 8-3/a" drilling assembly with MWD/GR/Res/Den(realtime)/Neu(real~iim--e'')/PWD and RIH to float collar. Test the 9 5/a" casing to 4,000 psi for 30 minutes. /'" 7. Drill shoe track and displace over to new 9.0 ppg mud 8. Drill new formation to 20' below 9 $/a" shoe and perform LOT (Notify ODE if 10.7 ppg LOT is not obtained). 9. Drill ahead to Polygon 2 Target TD at 7,346' MD, (250' MD below Top OBe marker). ./r 10. Circulate and condition hole, POOH to run casing. Perform wiper trip if hole conditions dictate. 11. Run and cement the 7" production casing as required to cover all significant hydrocarbon intervals. Displace the casing with seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Freeze protect the 7" x 9-$/e" annulus. 12. PU DPC guns and RIH w/ 150' of 4.5" Power Jet 5 spf, perf guns (total assembly length to be 300') with Schlumberger LWD GR for gun correlation. Tag PBTD. 13. Circ hole over to 9.0 brine. 14. Space out utilizing GR and RA tags in 7" casing. Once spaced out correctly, confirm cement compressive o strength is at least 2,000 psi. Perforate OA, OBa, OBb, OBc, and OBd. 15. RU Schlumberger E-line. RIH with gage ring and junk basket to recover any pert debris. Repeat until clean. Note: t is imperative that we have a clean wellbore so we don't damage the MDT packers while RIH. 16. Run SI /GR log following Primary Depth Control procedures as USIT log will be primary depth control for futur ell work. Obtain high resolution repeat section over OBb interval (approx. 6,820'-6,920' MD on directional plan) 17. Transmit High-Res USIT pass to town as soon as possible for MDT Cased Hole OBb sample depth picking. 18. If cement integrity found to be suitable for MDT sampling needs, RIH w/ MDT configured with the optical fluid analyzer, pump out subs, and dual packers sized to fit in 7" cased hole. Sample chambers should include a one gallon chamber and the 6 pack MPSR module. Obtain fluid sample from OBb Sand. Depths TBD based on cement evaluation. 19. RD E-Line. Run the 3-%z", L-80 TCII completion with a 7" x 3-%z" straddle packer assembly and injection mandrels. 20. Run in the lockdown screws and set the packers. Test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCK shear valve. 21. Install FMC TWC. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 22. Freeze protect the well to 2,500' TVD. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-'h" annulus valve and secure the well. Assure that IA/OA are both protected with two barriers. 23. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC from the tailpipe. 2. Replace the DCK shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. 5. Install wellhouse and flowlines. V214i Well Plan Summary Page 7 V-214i Proposed Completion Cellar Elevatbn =53.1' Doyen 16 RKB = 74.5' Max Deviation 65 Deg .".50` 101' 3,615` 9-5/8", 40 #/ft, L-80, BTC 3,750' 6,724` ~ Camco 3-1/2" x 1-1/2" MMG-W GLM 7" Short Joint & RA Tag (2-pips) Top Ma sand (6,307') Camco 3-1/2" x 1-1/2" MMG-W GLM 6,555` w/ DCK Shear Valve pinned to 2,500 6,644' 3-1 /2" 'X' Landing Nipple with 2.813" seal bore. 6,665' 7" x 3-1/2" Baker'PRM' Production Packer Short Joint & RA Tag ove Top OA (6,730`) Tag in 3-1 /2" 6,840` 3-1/2" 'X' Landing Nipple with 2.813" seal bore. 6,850` 7" x 3-1/2" Baker `PRM' Production Packer OBa 6.873 Camco 3-1/2" x 1-1 /2" MMG-W GLM 6,816` 6,901 ` 6,925 3-1/2" 'X' Landing Nipple with 2.813" seal bore. 6,936` 7" x 3-1/2" Baker `PRM' Production Packer 6,953` Camco 3-1 /2" x 1-1/2" MMG-W GLM OBc 7,001 ` 3-1/2" `X' Landing Nipple with 2.813" seal bore. OBd 7,051 ` 7,012` 7" x 3-1/2" Baker `PRM' Production Packer 7'028` 3-1 /2" `X' Landing Nipple with 2.813" seal bore. 7, 040 ` TREE. C 4-1/16" SM WELLH AD: FMC Gen 5 System 11 ", 5M csg.head w/ 7" mandrel hanger & packoff 1 1" x 1 1", 5M, tbg spool w/ / 11" x 4-1 l2" tubing hanger 11" X 4-1/16' Adaptor Flange 13-1/2" x 4-1/2" XO w/ 20' x 4-1/2" pup to hanger 20" X 34" 215.5 Ib/ft, A53 ERW Insulated 3-1/2" `X' Landing Nipple with 2.813" seal bore. 4-1 /2", 12.6 Ib/ft, L-80, TCII Drift / ID : 3.833"/3.958" 3-1 /2", 9.3 Ib/ft, L-80, TCII Drift / ID : 2.867"/2.992" 3-1/2" WireLine Entry Guide 7,266` ~44Y4 7", PBTD 7,346` ~~ 7", 26 #/ft, L80, BTC-ModO(~)O 7", 26 #/ft, L80, BTC-Mod 8 3/4", TD (Injector Mainbore) Date Rev By Comments 31-Aug-05 MJM Proposed Completion for wp06 Zone MD TVDss Inc. Perf Int. Fee OA 6803 -4245 20 6803-6843 40 OBa 6867 -4305 20 6867-6897 30 OBb 6909 -4345 20 6909-6924 15 OBc 6973 -4405 20 6973-6990 17 ~~dl~~",,~1~1r~~~f~' t4~~' WELL: V-2141 API NO: --------- E 5,172 GR1p I I 15'00'00" I I I I I PLANT I I I I ^ V-120 ^ V-115 I I I ^ V-03 ^ V-213i I I ^ V-110 ^ V-100 I ^ V-111 ( 203i ^ V-117 V I I - ^ I I ^ SLOT S-R I ^ V-106 I I I ^ V-1051 ^ V-01 I I I I I ^ V-221 i I I I I ,°~ ^ V-102 ^ V-SPARE (sLOr s-L) I I ~ ^ V-201 I ^ V-107 ^ SLOT S-J Iz ^ V-02 0l I, ^ V-104i ^ V-204 ml ^ V-210i ^ V-114 ~ V-202 ^ V-119 z I V-2141 ~- ^ v-1o9 V-101 I ^ V-211 i ^ V-113 ^ V-108 I ^ V-203 I ~// SO WOP ~,PPO ~ --, ,, , NOTES I I I \~ V PAD TO gpINE ROAD ~~ - - LEGEND -~- AS-BUILT CONDUCTOR ^ EXISTING CONDUCTOR 1. DATE OF SURVEY: JULY 17 & 18, 2004. 2. REFERENCE FIELD BOOK: W004-11 PGS. 19-26. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD-27. 4. BASIS OF HORIZONTAL CONTROL IS V-PAD OPERATOR MONUMENTATION. 5. BASIS OF ELEVATION IS KUPARUK PIPELINE CONTROL. ELEVATIONS ARE BP MEAN SEA LEVEL DATUM. 6. THE MEAN SCALE FACTOR FOR V-PAD IS 0.999909334. .b O Q AO OL-PAD ¢° ~ ~ ~ Q 34p o s~ Qop o ~~ 4. Q~° ~ d u V~ oon °~Blo~ ~ b ~8 a 1L .~ o.Q ~aa .~Qaq ov;. T ~a "~ yyyy~EST ~ o~ dl o, °o KSTA~UK s. 'o.. ~ e ~ ` 2 ° ~ ~ c 1 " .o U 03_1 o t~ 3 '~o PROJECT~° ~ BI .ti ,~' AREA °o° 10 °6.°. °a ;~ ~ d . VICINITY MAP N.T.S. WELL V--2141 RE-NAME NOTE THIS AS-BUILT DRAWING IS A RE-ISSUE OF A PREVIOUS CONDUCTOR AS-BUILT FOR WELL V-SPARE (SLOT V-NE) DATED 7/22/04. V SPARE (SLOT V-NE) IS BEING RE-NAMED WELL V-2141. ~P,~E °~F ° A~ ~a °° ~'°° Richard F. Allison 10608 °°° ~°,q~~,~~~~ °°°~ ""'*t3SI0NP~- ~ SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF APRIL 22, 2005. LOCATED WITHIN PROTRACTED SEC. 11, T. 11 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS * V-2141 Y= 5,970,061.76 N=10,179.73 70'19'40.614" ' 70.3279483' 1' 53 4,816' FSL ' X= 590,439.13 E= 4,690.07 149'15 59.515" 149.2665319' . 1,862 FEL * PREVIOUSLY NAMED V-SPARE (SLOT V-NE) r. rcooerr. ",."'.~NnE CHECKF,D: ~P 0 HANLEY I.i O O DATE:4/22/05 °~~ DRAWING: SHEET: yy~~ FReas wov os-oo GREATER PRUDHOE BAY V-PAD ®19J~~~~o cos ND. AS-BUILT CONDUCTOR 0 4 22 O RE-NAMED WELL V-SPARE SLOT V-NE TO V-21M JMF LOH °1OM~ "XD W° A'"`~~ SCALE: 1 OF 1 NO. GATE REVISION BV GiK ~ w a.~•u~v: uo~ 1"=150' WELL V-214i S err -Sun P Y BP Planning Report Company;. BP AmOCO Date: 8/31)/2005 Time: 15:50:02 Page:. 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan V-214 (N-E), True North Site: PB V Pad Vertical (TVD) Reference: 21.5-~8-F+53.174.6 Well: Plan V-214 (N-E} Section (VS)Reference: Well (O.OON,O.OOE,326.OOAzi) Wellpath: Plan V-214 Survey Calculation Method: Minimum Curvature Db; -.Oracle Plan: V-214 wp06 Date Composed: 6/3/2005 Version: 19 Principal: Yes Tied-to: From Well Ref. Point Field: Ptudhce Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB V Pad TR-12-12 UNITED STATES :North Slope Site Position: Northing: 5969964.50 ft Latitude: 70 19 39.618 N From: Map Easting: 590770.65 ft Longitude: 149 15 49.871 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.69 deg Well: Plan V-214 (N-E) Slot Name: Well Position: +N/-S 101.27 ft Northing: 5970061.76 ft Latitude: 70 19 40.614 N +E/-W -330.35 ft Easting : 590439.13 ft Longitude: 149 15 59.515 W Position Uncertainty: 0.00 ft Casing Points MD T'W Diameter Hole Size Name ft ft in in 3751.13 2634.60 9.625 12.250 9 5/8" 7346.00 4829.64 7.000 8.750 7" Formations MD TVD Formations Lithology I)ip Angle Dip Direction ft ft ,deg deg...: 314.60 314.60 G 1 0.00 0.00 963.70 954.60 SV6 0.00 0.00 1727.69 1619.60 SV5 0.00 0.00 1905.15 1749.60 SV4 0.00 0.00 1940.57 1774.60 Base Permafrost 0.00 0.00 2620.64 2159.60 SV3 0.00 0.00 3026.39 2329.60 Fault 1 ("V Pad Fault") 0.00 0.00 3026.39 2329.60 SV2 (Faulted Top) 0.00 0.00 3515.68 2534.60 SV1 0.00 0.00 4217.73 2834.60 UG4 0.00 0.00 4300.63 2869.60 UG4A 0.00 0.00 5077.60 3194.60 UG3 0.00 0.00 6017.96 3654.60 UG1 0.00 0.00 6373.94 3929.60 Ma 0.00 0.00 6420.70 3969.60 Mb1 0.00 0.00 6494.85 4034.60 Mb2 0.00 0.00 6556.08 4089.60 Mc 0.00 0.00 6626.92 4154.60 Na 0.00 0.00 6653.79 4179.60 Nb 0.00 0.00 6701.76 4224.60 Nc 0.00 0.00 6802.91 4319.60 OA 0.00 0.00 6866.80 4379.60 OBa 0.00 0.00 6909.39 4419.60 OBb 0.00 0.00 6973.28 4479.60 OBc 0.00 0.00 7026.52 4529.60 OBd 0.00 0.00 7095.73 4594.60 OBe 0.00 0.00 0.00 0.00 OBf 0.00 0.00 0.00 0.00 OBf_Base 0.00 0.00 7345.95 4829.60 Formation 30 0.00 0.00 S er -Sun P rY BP Planning Report Company: BP Amoco Date: 8!30/2005 Time: 15:50'02 Page: 2 .Field: Prudhoe Bay Co-ordinate(NE) Refetence: Well: Plan V-214 (N-E), True North Site: PB V Pad Vertical (TVD) Reference: 1+.5 -~&.~+53.1=74.6 Well: Plan V-214 (N-E)' Section (VS)Referenee: Well {O.OON,O.QOE,326.OOAzi ) Wellpath: Plan V-214 Survey Calculation Methods Minimum Curvature Db: Oracle Targets Map Map <-- Latitude ---> <- Longitude -~ Name' Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min. Sec 1)ip. Dir. - ft ft ft ft ft V-214 SV1 Tgt 2534.60 1956.28 -225.59 5972015.00 590190.00 70 19 59.854 N 149 16 6.102 W -Circle (Radius: 100) -Plan hit target V-214 Flt 1 2574.60 3135.40 -1381.56 5973180.00 589020.00 70 20 11.449 N 149 16 39.864 W -Polygon 1 2574.60 3135.40 -1381.56 5973180.00 589020.00 70 20 11.449 N 149 16 39.864 W -Polygon 2 2574.60 2333.88 -851.14 5972385.00 589560.00 70 20 3.567 N 149 16 24.370 W -Polygon 3 2574.60 1371.39 -242.64 5971430.00 590180.00 70 19 54.101 N 149 16 6.600 W -Polygon 4 2574.60 389.38 740.68 5970460.00 591175.00 70 19 44.443 N 149 15 37.891 W -Polygon 5 2574.60 -219.14 1853.53 5969865.00 592295.00 70 19 38.456 N 149 15 5.407 W -Polygon 6 2574.60 389.38 740.68 5970460.00 591175.00 70 19 44.443 N 149 15 37.891 W -Polygon 7 2574.60 1371.39 -242.64 5971430.00 590180.00 70 19 54.101 N 149 16 6.600 W -Polygon 8 2574.60 2333.88 -851.14 5972385.00 589560.00 70 20 3.567 N 149 16 24.370 W -Plan out by 1581.77 at 2574.60 2041.21 -239.32 5972099.75 590175.25 70 20 0.689 N 149 16 6.503 W Top NA 4154.60 4153.25 -1516.02 5974196.06 588873.30 70 20 21.459 N 149 16 43.796 W -Plan hit target V-214 Tgt 4319.60 4203.45 -1551.02 5974245.82 588837.70 70 20 21.953 N 149 16 44.819 W -Circle (Radius: 150) -Plan hit target Plan Section Information MD Inch Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 21.50 0.00 0.00 21.50 0.00 0.00 0.00 0.00 0.00 0.00 292.60 0.00 10.00 292.60 0.00 0.00 0.00 0.00 0.00 10.00 392.60 1.50 10.00 392.59 1.29 0.23 1.50 1.50 0.00 10.00 592.60 6.50 10.00 592.04 15.02 2.65 2.50 2.50 0.00 0.00 1889.96 45.10 353.00 1738.87 564.70 -42.34 3.00 2.98 -1.31 340.75 1989.96 45.10 353.00 1809.46 635.01 -50.97 0.00 0.00 0.00 0.00 2565.29 65.23 352.38 2136.41 1100.95 -111.08 3.50 3.50 -0.11 -1.65 3515.68 65.23 352.38 2534.60 1956.28 -225.59 0.00 0.00 0.00 0.00 V-214 SV1 Tgt 3750.64 64.57 344.62 2634.39 2164.57 -267.93 3.00 -0.28 -3.30 -97.00 3770.64 64.57 344.62 2642.98 2181.99 -272.72 0.00 0.00 0.00 0.00 4341.78 65.28 325.71 2886.85 2648.45 -488.86 3.00 0.12 -3.31 -91.70 5545.00 65.28 325.71 3390.08 3551.39 -1104.64 0.00 0.00 0.00 0.00 6626.92 22.00 325.50 4154.60 4153.25 -1516.02 4.00 -4.00 -0.02 -179.89 Top NA 6674.87 20.09 325.05 4199.34 4167.40 -1525.83 4.00 -3.99 -0.94 -175.37 6802.91 20.09 325.05 4319.60 4203.45 -1551.02 0.00 0.00 0.00 0.00 V-214 Tgt 7346.41 20.09 325.05 4830.03 4356.46 -1657.97 0.00 0.00 0.00 0.00 Survey MD Inel Azim TVD SysTVD N/S E/W DLS MapN- MagE" Tool/Comme t ft deg deg ft ft ft ft- deg/100ft ft ft 0.00 0.00 0.00 0.00 -74.60 0.00 0.00 0.00 5970061.76 590439.13 OBf_Base 21.50 0.00 0.00 21.50 -53.10 0.00 0.00 0.00 5970061.76 590439.13 GYD-GC-SS 100.00 0.00 10.00 100.00 25.40 0.00 0.00 0.00 5970061.76 590439.13 GYD-GC-SS 200.00 0.00 10.00 200.00 125.40 0.00 0.00 0.00 5970061.76 590439.13 GYD-GC-SS 292.60 0.00 10.00 292.60 218.00 0.00 0.00 0.00 5970061.76 590439.13 Start Dir 1.5/1 300.00 0.11 10.00 300.00 225.40 0.01 0.00 1.50 5970061.77 590439.13 GYD-GC-SS 314.60 0.33 10.00 314.60 240.00 0.06 0.01 1.50 5970061.82 590439.14 G1 392.60 1.50 10.00 392.59 317.99 1.29 0.23 1.50 5970063.05 590439.34 Start Dir 2.5/1 400.00 1.68 10.00 399.99 325.39 1.49 0.26 2.50 5970063.25 590439.37 GYD-GC-SS 500.00 4.18 10.00 499.85 425.25 6.53 1.15 2.50 5970068.31 590440.20 GYD-GC-SS 592.60 6.50 10.00 592.04 517.44 15.02 2.65 2.50 5970076.81 590441.60 Start Dir 3/100 600.00 6.71 9.37 599.39 524.79 15.86 2.79 3.00 5970077.65 590441.73 GYD-GC-SS 700.00 9.60 3.62 698.37 623.77 29.95 4.27 3.00 5970091.76 590443.04 GYD-GC-SS 800.00 12.54 0.53 796.50 721.90 49.14 4.90 3.00 5970110.95 590443.44 GYD-GC-SS 900.00 15.51 358.60 893.51 818.91 73.36 4.67 3.00 5970135.17 590442.92 GYD-GC-SS 963.70 17.40 357.71 954.60 880.00 91.40 4.08 3.00 5970153.19 590442.11 SV6 • S er -Sun P rY BP Planning Report Company: BP Amoco Date: 8130/2005 Time: 15:50:02 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeIL Plan V-214 (N-E), True North Site: PB V Pad Vertical (TVD) Reference: z ~s •256+53.114.6 Well: Plan V-214 (N-E) Section (VS) Reference: Well (O,OON,O:OOE,326.OOAzi) Wellpath Plan V-214 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TdD Sys TVD N/S` E7W DLS MapN , MapE ' ToollComme t ft deg deg ft ft ft ft deg/100ft ft ft 1000.00 18.48 357.28 989.13 914.53 102.56 3.60 3.00 5970164.35 590441.49 GYD-GC-SS 1100.00 21.46 356.32 1083.11 1008.51 136.66 1.67 3.00 5970198.42 590439.15 GYD-GC-SS 1200.00 24.45 355.58 1175.18 1100.58 175.56 -1.10 3.00 5970237.28 590435.91 MWD+IFR+MS 1300.00 27.44 354.99 1265.09 1190.49 219.16 -4.71 3.00 5970280.82 590431.78 MWD+IFR+MS 1400.00 30.43 354.51 1352.60 1278.00 267.33 -9.14 3.00 5970328.93 590426.76 MWD+IFR+MS 1500.00 33.42 354.11 1437.46 1362.86 319.94 -14.39 3.00 5970381.48 590420.88 MWD+IFR+MS 1600.00 36.42 353.77 1519.45 1444.85 376.86 -20.44 3.00 5970438.31 590414.15 MWD+IFR+MS 1700.00 39.41 353.47 1598.33 1523.73 437.91 -27.27 3.00 5970499.27 590406.58 MWD+IFR+MS 1727.69 40.24 353.40 1619.60 1545.00 455.53 -29.30 3.00 5970516.87 590404.34 SV5 1800.00 42.41 353.21 1673.90 1599.30 502.95 -34.87 3.00 5970564.21 590398.20 MWD+IFR+MS 1889.96 45.10 353.00 1738.87 1664.27 564.70 -42.34 3.00 5970625.86 590389.99 End Dir :1889 1900.00 45.10 353.00 1745.96 1671.36 571.76 -43.21 0.00 5970632.91 590389.04 MWD+IFR+MS 1905.15 45.10 353.00 1749.60 1675.00 575.39 -43.65 0.00 5970636.53 590388.55 SV4 1940.57 45.10 353.00 1774.60 1700.00 600.29 -46.71 0.00 5970661.39 590385.19 Base Permafro 1989.96 45.10 353.00 1809.46 1734.86 635.01 -50.97 0.00 5970696.05 590380.51 Start Dir 3.5/1 2000.00 45.45 352.99 1816.53 1741.93 642.09 -51.84 3.50 5970703.12 590379.56 MWD+IFR+MS 2100.00 48.95 352.85 1884.46 1809.86 714.89 -60.89 3.50 5970775.80 590369.63 MWD+IFR+MS 2200.00 52.45 352.73 1947.79 1873.19 791.65 -70.60 3.50 5970852.43 590359.00 MWD+IFR+MS 2300.00 55.95 352.63 2006.28 1931.68 872.08 -80.93 3.50 5970932.73 590347.70 MWD+IFR+MS 2400.00 59.45 352.53 2059.71 1985.11 955.89 -91.85 3.50 5971016.38 590335.77 MWD+IFR+MS 2500.00 62.95 352.43 2107.88 2033.28 1042.75 -103.32 3.50 5971103.09 590323.26 MWD+IFR+MS 2565.29 65.23 352.38 2136.41 2061.81 1100.95 -111.08 3.50 5971161.19 590314.79 End Dir :2565 2600.00 65.23 352.38 2150.95 2076.35 1132.19 -115.27 0.00 5971192.38 590310.24 MWD+IFR+MS 2620.64 65.23 352.38 2159.60 2085.00 1150.76 -117.75 0.00 5971210.92 590307.53 SV3 2700.00 65.23 352.38 2192.85 2118.25 1222.19 -127.31 0.00 5971282.21 590297.11 MWD+IFR+MS 2800.00 65.23 352.38 2234.75 2160.15 1312.19 -139.36 0.00 5971372.05 590283.97 MWD+IFR+MS 2900.00 65.23 352.38 2276.65 2202.05 1402.18 -151.41 0.00 5971461.89 590270.84 MWD+IFR+MS 3000.00 65.23 352.38 2318.54 2243.94 1492.18 -163.46 0.00 5971551.73 590257.71 MWD+IFR+MS 3026.39 65.23 352.38 2329.60 2255.00 1515.93 -166.64 0.00 5971575.43 590254.25 SV2 (Faulted T 3100.00 65.23 352.38 2360.44 2285.84 1582.18 -175.51 0.00 5971641.56 590244.58 MWD+IFR+MS 3200.00 65.23 352.38 2402.34 2327.74 1672.17 -187.55 0.00 5971731.40 590231.45 MWD+IFR+MS 3300.00 65.23 352.38 2444.23 2369.63 1762.17 -199.60 0.00 5971821.24 590218.32 MWD+IFR+MS 3400.00 65.23 352.38 2486.13 2411.53 1852.17 -211.65 0.00 5971911.07 590205.19 MWD+IFR+MS 3500.00 65.23 352.38 2528.03 2453.43 1942.16 -223.70 0.00 5972000.91 590192.06 MWD+IFR+MS 3515.68 65.23 352.38 2534.60 2460.00 1956.28 -225.59 0.00 5972015.00 590190.00 V-214 SV1 Tgt 3600.00 64.95 349.60 2570.12 2495.52 2031.80 -237.56 3.00 5972090.36 590177.12 MWD+IFR+MS 3610.57 64.92 349.26 2574.60 2500.00 2041.21 -239.32 3.00 5972099.75 590175.25 V-214 Flt 1 3700.00 64.68 346.30 2612.69 2538.09 2120.28 -256.44 3.00 5972178.60 590157.17 MWD+IFR+MS 3750.64 64.57 344.62 2634.39 2559.79 2164.57 -267.93 3.00 5972222.75 590145.16 End Dir :3750 3751.13 64.57 344.62 2634.60 2560.00 2164.99 -268.04 0.00 5972223.17 590145.03 9 5/8" 3770.64 64.57 344.62 2642.98 2568.38 2181.99 -272.72 0.00 5972240.10 590140.16 Start Dir 3/100 3800.00 64.55 343.65 2655.59 2580.99 2207.49 -279.96 3.00 5972265.51 590132.61 MWD+IFR+MS 3900.00 64.52 340.33 2698.60 2624.00 2293.33 -307.87 3.00 5972351.00 590103.66 MWD+IFR+MS 4000.00 64.56 337.00 2741.59 2666.99 2377.42 -340.72 3.00 5972434.68 590069.81 MWD+IFR+MS 4100.00 64.68 333.69 2784.46 2709.86 2459.51 -378.40 3.00 5972516.31 590031.15 MWD+IFR+MS 4200.00 64.88 330.38 2827.08 2752.48 2539.40 -420.82 3.00 5972595.67 589987.77 MWD+IFR+MS 4217.73 64.92 329.79 2834.60 2760.00 2553.31 -428.83 3.00 5972609.49 589979.59 UG4 4300.00 65.14 327.08 2869.33 2794.73 2616.85 -467.87 3.00 5972672.55 589939.80 MWD+IFR+MS 4300.63 65.15 327.06 2869.60 2795.00 2617.34 -468.18 3.00 5972673.02 589939.48 UG4A 4341.78 65.28 325.71 2886.85 2812.25 2648.45 -488.86 3.00 5972703.88 589918.43 End Dir :4341 4400.00 65.28 325.71 2911.20 2836.60 2692.13 -518.66 0.00 5972747.20 589888.11 MWD+IFR+MS 4500.00 65.28 325.71 2953.03 2878.43 2767.18 -569.83 0.00 5972821.62 589836.04 MWD+IFR+MS 4600.00 65.28 325.71 2994.85 2920.25 2842.22 -621.01 0.00 5972896.03 589783.96 MWD+IFR+MS S err -Sun P Y BP Planning Report Company: '. BP Amoco Date: 8/30!2005 .Time: 15:50:02 Page: 4 Field: Prutlhoe Bay Co-ordinate(NE);Reference: Well: Plan V-214 (N-E), True North Site: PB V Pad Vertical (TVI)) Reference:2~. 5 2~+53.1=74.6 Well: Plan V-214 (N-E) Section (VS) Reference:. Well: (O.OON,O.OOE,326.OOAzi) Wellpath: Plan V-214 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inc! 'Azim I TVD ' Sys TVD N/S E/W DLS MapN" MapE Tool/Comme t ft deg deg ft ft ft ft deg/100ft ft ft 4700. 00 65.28 325. 71 3036.67 2962.07 2917.27 -672.19 0.00 5972970.45 589731.89 MWD+IFR+MS 4800 .00 65.28 325. 71 3078.50 3003.90 2992.31 -723.37 0.00 5973044.86 589679.81 MWD+IFR+MS 4900. 00 65.28 325. 71 3120.32 3045.72 3067.35 -774.54 0.00 5973119.28 589627.74 MWD+IFR+MS 5000. 00 65.28 325. 71 3162.14 3087.54 3142.40 -825.72 0.00 5973193.69 589575.67 MWD+IFR+MS 5077. 60 65.28 325. 71 3194.60 3120.00 3200.64 -865.44 0.00 5973251.44 589535.26 UG3 5100. 00 65.28 325. 71 3203.97 3129.37 3217.44 -876.90 0.00 5973268.11 589523.59 MWD+IFR+MS 5200. 00 65.28 325. 71 3245.79 3171.19 3292.49 -928.08 0.00 5973342.52 589471.52 MWD+IFR+MS 5300. 00 65.28 325. 71 3287.61 3213.01 3367.53 -979.26 0.00 5973416.94 589419.44 MWD+IFR+MS 5400. 00 65.28 325. 71 3329.44 3254.84 3442.58 -1030.43 0.00 5973491.35 589367.37 MWD+IFR+MS 5500. 00 65.28 325. 71 3371.26 3296.66 3517.62 -1081.61 0.00 5973565.77 589315.30 MWD+IFR+MS 5545. 00 65.28 325. 71 3390.08 3315.48 3551.39 -1104.64 0.00 5973599.25 589291.86 Start Dir 4/100 5600 .00 63.08 325. 70 3414.04 3339.44 3592.29 -1132.54 4.00 5973639.81 589263.48 MWD+IFR+MS 5700. 00 59.08 325. 69 3462.39 3387.79 3664.58 -1181.85 4.00 5973711.49 589213.30 MWD+IFR+MS 5800. 00 55.08 325. 68 3516.73 3442.13 3733.89 -1229.16 4.00 5973780.23 589165.17 MWD+IFR+MS 5900. 00 51.08 325. 67 3576.79 3502.19 3799.91 -1274.23. 4.00 5973845.69 589119.31 MWD+IFR+MS 6000 .00 47.08 325. 66 3642.29 3567.69 3862.29 -1316.84 4.00 5973907.54 589075.96 MWD+IFR+MS 6017. 96 46.36 325. 66 3654.60 3580.00 3873.08 -1324.21 4.00 5973918.25 589068.45 UG1 6100. 00 43.08 325. 64 3712.89 3638.29 3920.73 -1356.78 4.00 5973965.50 589035.32 MWD+IFR+MS 6200 .00 39.08 325. 63 3788.26 3713.66 3974.96 -1393.86 4.00 5974019.27 588997.59 MWD+IFR+MS 6300 .00 35.08 325. 61 3868.02 3793.42 4024.71 -1427.90 4.00 5974068.60 588962.96 MWD+IFR+MS 6373. 94 32.12 325. 59 3929.60 3855.00 4058.46 -1451.01 4.00 5974102.07 588939.44 Ma 6400 .00 31.08 325. 58 3951.80 3877.20 4069.73 -1458.73 4.00 5974113.24 588931.59 MWD+IFR+MS 6420 .70 30.25 325. 58 3969.60 3895.00 4078.43 -1464.69 4.00 5974121.87 588925.52 Mb1 6494. 85 27.28 325. 56 4034.60 3960.00 4107.87 -1484.87 4.00 5974151.06 588904.99 Mb2 6500. 00 27.08 325. 55 4039.15 3964.58 4109.80 -1486.20 4.00 5974152.98 588903.64 MWD+IFR+MS 6556 .08 24.83 325. 53 4089.60 4015.00 4130.04 -1500.08 4.00 5974173.05 588889.51 Mc 6600. 00 23.08 325. 51 4129.73 4055.13 4144.74 -1510.18 4.00 5974187.62 588879.24 MWD+IFR+MS 6626. 92 22.00 325. 50 4154.60 4080.00 4153.25 -1516.02 4.00 5974196.06 588873.30 Top NA 6653. 79 20.93 325. 26 4179.60 4105.00 4161.34 -1521.61 4.00 5974204.08 588867.61 Nb 6674 .87 20.09 325. 05 4199.34 4124.74 4167.40 -1525.83 4.00 5974210.09 588863.32 End Dir :6674 6700. 00 20.09 325. 05 4222.95 4148.35 4174.47 -1530.77 0.00 5974217.10 588858.29 MWD+IFR+MS 6701. 76 20.09 325. 05 4224.60 4150.00 4174.97 -1531.12 0.00 5974217.59 588857.94 Nc 6800 .00 20.09 325. 05 4316.86 4242.26 4202.63 -1550.45 0.00 5974245.01 588838.28 MWD+IFR+MS 6802. 91 20.09 325. 05 4319.60 4245.00 4203.45 -1551.02 0.00 5974245.82 588837.70 V-214 Tgt 6866. 80 20.09 325. 05 4379.60 4305.00 4221.43 -1563.59 0.00 5974263.66 588824.91 OBa 6900. 00 20.09 325. 05 4410.78 4336.18 4230.78 -1570.13 0.00 5974272.92 588818.27 MWD+IFR+MS 6909. 39 20.09 325. 05 4419.60 4345.00 4233.42 -1571.97 0.00 5974275.54 588816.39 OBb 6973. 28 20.09 325. 05 4479.60 4405.00 4251.41 -1584.54 0.00 5974293.38 588803.60 OBc 7000. 00 20.09 325. 05 4504.70 4430.10 4258.93 -1589.80 0.00 5974300.83 588798.25 MWD+IFR+MS 7026. 52 20.09 325. 05 4529.60 4455.00 4266.40 -1595.02 0.00 5974308.24 588792.95 OBd 7095. 73 20.09 325. 05 4594.60 4520.00 4285.88 -1608.64 0.00 5974327.55 588779.10 OBe 7100. 00 20.09 325. 05 4598.61 4524.01 4287.09 -1609.48 0.00 5974328.75 588778.24 MWD+IFR+MS 7200. 00 20.09 325. 05 4692.53 4617.93 4315.24 -1629.16 0.00 5974356.66 588758.23 MWD+IFR+MS 7300. 00 20.09 325. 05 4786.44 4711.84 4343.39 -1648.83 0.00 5974384.57 588738.21 MWD+IFR+MS 7345. 95 20.09 325. 05 4829.60 4755.00 4356.33 -1657.88 0.00 5974397.39 588729.02 Formation 30 7346. 00 20.09 325. 05 4829.64 4755.04 4356.34 -1657.89 0.00 5974397.41 588729.01 7" 7346. 41 20.09 325. 05 4830.03 4755.43 4356.46 -1657.97 0.00 5974397.52 588728.92 MWD+IFR+MS • Schlumber r • ge Anticollision Report • • Company: BP Amoco Date: 6/6!2005 Timep 15:55:13 Page: 1 Field: Prudhoe Bay Reference Site: PB V Pad Co-ordinate(NE) Re ference: Well: Plan V-214 (N-E), True North Reference Well: . Plan V-214 (N-E) Vertical (TVI)) Refe rence: V-214 Pla n N-E 82.0 Reference Wellpat~lan V 214 Db: Sybase NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan 8~ PLANNED PROGRAM Interpolation Meth odMD + Stations Interval: 50.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 28.50 to 7281.48 ft Scan Method: Trav Cylinder North Maximum Radiu9A000.00 ft Erro r Surface: Ellipse + Casing Survey Program fo r Definitive Wellpath Date: 3/15/2005 Validated: No Version: 2 Planned From To Survey Toolcode Tool Na me ft ft 28.50 1000.00 Planned: Plan #4 V1 GYD-GC-SS Gyrodata gyro single shots 1000.00 2400.00 Planned: Pla n #4 V1 MWD MWD -Standard 1000.00 7281.48 Planned: Pla n fl4 V1 MWD+IFR+MS MWD +I FR + Multi Station Casing Points MD -TVD Diameter Hole Size Name ft ft in _ in 3710.64 2622.00 9.625 12.250 9 5!8" 7281.48 4836.92 7.000 8.750 7" Summary --- ------- ---------- Offset Wellpath -------- -------------> Reference Offsef Ctr-Ctr No=Go Allowable Site WeII Wellpath MD MD Distaace Area Deviation Warning ft ft ft ft ft PB V Pad Plan V-212 (N-R) Plan V-212 V2 Plan: PI 710.94 700.00 235.44 13.46 221.98 Pass: Major Risk PB V Pad V-01 V-01 V15 299.49 300.00 252.17 5.42 246.74 Pass: Major Risk PB V Pad V-02 V-02 V12 600.28 600.00 52.36 10.25 42.10 Pass: Major Risk PB V Pad V-03 V-03 V7 905.44 900.00 306.51 14.90 291.61 Pass: Major Risk PB V Pad V-100 V-100 V7 494.97 500.00 347.66 8.34 339.31 Pass: Major Risk PB V Pad V-101 V-101 V7 399.56 400.00 12.63 6.85 5.78 Pass: Major Risk PB V Pad V-102 V-102 V5 1826.79 1850.00 53.11 30.27 22.84 Pass: Major Risk PB V Pad V-103 V-103 V6 814.19 800.00 242.17 14.28 227.89 Pass: Major Risk PB V Pad V-104 V-104 V13 698.94 700.00 35.22 11.83 23.39 Pass: Major Risk PB V Pad V-105 V-105 V13 702.26 700.00 171.65 12.22 159.43 Pass: Major Risk PB V Pad V-106 V-106 V10 1052.23 1050.00 202.50 17.86 184.64 Pass: Major Risk PB V Pad V-106 V-106A V9 1067.89 1050.00 220.19 19.75 200.44 Pass: Major Risk PB V Pad V-106 V-106AP61 V6 1067.89 1050.00 220.19 19.75 200.44 Pass: Major Risk PB V Pad V-106 V-106APB2 V2 1067.89 1050.00 220.19 19.75 200.44 Pass: Major Risk PB V Pad V-106 V-106APB3 V2 1067.89 1050.00 220.19 19.75 200.44 Pass: Major Risk PB V Pad V-107 V-107 V5 600.44 600.00 76.27 9.92 66.34 Pass: Major Risk PB V Pad V-108 V-108 V7 249.68 250.00 47.39 4.41 42.99 Pass: Major Risk PB V Pad V-109 V-109 V2 396.52 400.00 180.74 6.98 173.76 Pass: Major Risk PB V Pad V-109 V-109P61 V5 396.52 400.00 180.74 6.98 173.76 Pass: Major Risk PB V Pad V-109 V-109P62 V2 396.52 400.00 180.74 6.98 173.76 Pass: Major Risk PB V Pad V-111 V-111 V25 807.97 800.00 281.80 14.95 266.84 Pass: Major Risk PB V Pad V-111 V-111 PB1 V8 807.97 800.00 281.80 14.95 266.84 Pass: Major Risk PB V Pad V-111 V-111 PB2 V2 807.97 800.00 281.80 14.95 266.84 Pass: Major Risk PB V Pad V-111 V-111 P63 V6 807.97 800.00 281.80 14.95 266.84 Pass: Major Risk PB V Pad V-113 V-113 V6 347.79 350.00 182.46 5.51 176.95 Pass: Major Risk PB V Pad V-114 V-114 V5 300.18 300.00 184.31 5.18 179.12 Pass: Major Risk PB V Pad V-114 V-114A V4 300.18 300.00 184.31 5.18 179.12 Pass: Major Risk PB V Pad V-114 V-114APB1 V4 300.18 300.00 184.31 5.18 179.12 Pass: Major Risk PB V Pad V-114 V-114APB2 V2 300.18 300.00 184.31 5.18 179.12 Pass: Major Risk PB V Pad V-115 V-115 V5 348.61 350.00 373.68 5.88 367.79 Pass: Major Risk PB V Pad V-115 V-115P61 V4 348.61 350.00 373.68 5.88 367.79 Pass: Major Risk PB V Pad V-117 V-117 V9 347.48 350.00 320.58 6.16 314.42 Pass: Major Risk PB V Pad V-117 V-117PB1 V6 347.48 350.00 320.58 6.16 314.42 Pass: Major Risk PB V Pad V-117 V-117P62 V6 347.48 350.00 320.58 6.16 314.42 Pass: Major Risk PB V Pad V-119 V-119 V13 443.16 450.00 181.17 7.94 173.23 Pass: Major Risk PB V Pad V-120 V-120 V5 299.88 300.00 325.02 5.45 319.56 Pass: Major Risk PB V Pad V-201 V-201 V8 993.13 1000.00 44.58 17.23 27.35 Pass: Major Risk PB V Pad V-202 V-202 V9 449.63 450.00 15.63 8.21 7.42 Pass: Major Risk PB V Pad V-202 V-202L1 V5 449.63 450.00 15.63 8.16 7.47 Pass: Major Risk PB V Pad V-202 V-202L2 V5 449.63 450.00 15.63 8.16 7.47 Pass: Major Risk PB V Pad V-204 V-204 V2 724.33 750.00 158.47 12.93 145.55 Pass: Major Risk PB V Pad V-204 V-204L1 V2 724.33 750.00 158.47 12.93 145.55 Pass: Major Risk • Schlumber er • g Anticollision Report • • • Company: BP Amoco Date: 6/6/2005 Time: 15:55:13 Page: 2 Field: Prudhoe Bay Reference Site: PB V Pad Co-ordinat e(NE) Reference: Well: Plan V-214 (N-E), True North `Reference Well: Plan V-214 (N-E) Vertical (T VD) Reference: V-214 Plan N-E 82.0 Reference WellpatlPJan V-214 Db: Sybase Summary <- --------- --------- Offset Wellpath -------- -------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well - Wellpath MD MD - Dtstanc eArea Deviation Warning ft ft ft ft ft PB V Pad V-204 V-204L1 PB1 V6 724.33 750.00 158.47 12.93 145.55 Pass: Major Risk PB V Pad V-204 V-204L2 V2 724.33 750.00 158.47 12.93 145.55 Pass: Major Risk PB V Pad V-204 V-204L2PB1 V5 724.33 750.00 158.47 12.93 145.55 Pass: Major Risk PB V Pad V-204 V-204L3 V3 724.33 750.00 158.47 12.93 145.55 Pass: Major Risk PB V Pad V-204 V-204P61 V9 724.33 750.00 158.47 12.93 145.55 Pass: Major Risk PB V Pad V-204 V-204P62 V2 724.33 750.00 158.47 12.93 145.55 Pass: Major Risk PB V Pad V-210 V-210 V9 1060.35 1050.00 37.17 19.52 17.65 Pass: Major Risk PB V Pad V-211 V-211 V5 301.06 300.00 30.73 5.27 25.47 Pass: Major Risk PB V Pad V-213 V-213 V5 832.05 850.00 339.16 14.86 324.30 Pass: Major Risk PB V Pad V-213 V-213PB1 V5 832.05 850.00 339.16 14.86 324.30 Pass: Major Risk PB V Pad V-216 V-216 V8 614.06 600.00 272.96 11.31 261.64 Pass: Major Risk PB V Pad V-Z21 V-221 V6 658.90 650.00 166.16 13.90 152.25 Pass: Major Risk • ,50 50 loo Field: Prudhoe Bay Site: PB V Pad Well: Plan V-214 (N-E) Wellpath: Plan V-214 • Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre [o Centre Separation [SOft/in] • • SONDRA D STEWMAN:: BP EXPLORATlDN AK l~tC ,, ss-si,252 ' 131 PO BOX 196612 MB 7-5 Mastercard Check" ANCHORAGE, AK 99519-6612 DATE ~~ ~" PAY TO THE ~ ~ ORDER OF -~ ~~~ ~ _~-. First National B k Alaska DOLLARS Ancho e, AK199A501 l ~ ~: L 2 5 2 0D 0 6 0 ~: 9 9 14 ~~~ 6 2 2? •~~ 15 6 4,,• 0 L 3 1 S • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS} MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (PIT) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 Cljody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, ORION SCHR BL OIL •640135 Well Name: PRUDHOE BAY UN GRIN V-214 Program SER Well bore sag ^ PTD#:2051340 Company BP EXPLORATION (ALASKA) INC Initial Classlfype SER I WAGIN GeoArea Unit On1Off Shore On Annular Disposal ^ Administration 1 Permit-fee attaohed - - - - - - - - - Yes - - - - - - - - 2 Lease numberappropriate________________ ---__-._Yes___-. _ - - - - - - 3 Unique well-name andnumber____________________________ __________Yes__.____ .-___--.__-_-._____-_-_ --------------------------------------------- 4 Well located in a_tl_efined-pool-__________________________ ____ --__Yes____-_ __._____---___-_- - - - 5 Well located proper distance from drilling unit_bountlary_ _ _ - . _ Yes _ _ ----------------------------------------------------------------- 6 Well locatedpCOperdistancefromotherwells________________-_ -_-_____--_Yes__-___. - - - - 7 Sufficient acreageayail_ablein_drillingunit___________________- _____.-__-Yes____-__ -__ - -- - - 8 If deviated, is-we_Ilboreplat_included_________________________ __________Yes-_--__- .__-_--__--------.-___-___--._ - - - - 9 Operator only affectedparty_.------- __ -- - -- Yes------- ------------------- - -- - - - -- 10 Ope[atorhas.appropriafebondinforce--- ------ ------ --- ---- --- Yes---- -- --- ----------- -- - ---- ----- -- ---------- -- ---------- 11 Permit can be issued without conservation order Yes Appr Date 12 Permitcanbeissuedwithoutadministrativ_e_approval_______________ ___________Y_es_______ -______-___-_-__-_--__--_--__-___---_--__-__-__---_ ______---__-_- RPC 9!7/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Oder. # (put1O# in- comments).(For_ Yes - . - - - . AIO-22- _ . _ . _ _ - _ _ - _ - _ _ _ _ _ _ 15 All wells within 114_mile area of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ ... - - _ ----------------------------------------------------------------- 16 Pre-produced injector_ dpration-of pre production less than- 3 months-(For_service well Only) NA_ _ _ - - - . _ - - 17 ACMP_Finding of Consistency_h_as been issued-for this project_ - - _ - _ _ _ - _ - NA - - -- - - - - Engineering 18 Canductorstring-provided_______________________________ ___--.__-Yes___--_ 20'"@102',_--___--______-__--___-____-_-__---___-___._ -------------- 19 Surface casing_protects aII known USDWs - - - Yes - - - - - - - - 20 CMT-vol_adequate_tocircul_ate-on conductor&surf_csg____________ _____.-__Yes-___--- Adequate excess,-__-_-_______-_--___---__---___-___-__-__---__-______--__ 21 CMT_vol_adequ_ate-to tie-in long string to surfcsg__________________ ___,-___-No____-___ _-_-__-_-___-_- ---------------------------------------------------- 22 C(~T-willcoyer_allknow_n-productive horizons___________________ _____--__Yes____--_ ___---___-.-___--____-_-___-_-_-_____--__--___---__--____-___-._ 23 Casing designsadegaateforC,T,B&.permafrost---------------- ---_ ----Yes-.----- ---------------------------------------------.------------ 24 Adequatetan_kage_orreservepit___________________________ __________Yes_-_--__ Doyon16.-_-__--_-___--___-_--__---__---___- -------------------------- 25 If_a_re-drill,has_a_10-403 for abandonment been approved____________ ______--_ NA__--____ Newwell_-__-__-__-_-___--________.-__-_-_____-__---_________ __-._ 26 Adequatewellboreseparationproposed______________-__-____ _-_.---__-Yes__-____ . ------------------------------------------------------------------- 27 Ifdiverterrequi_red, does it meet regulations____________________ ______ ___Yes___---- __---_______,-__---_ --------------------------------------------- Appr Date 28 Drillingfluid-programschematic-&equiplistadequate_______________ __________Yes_____-_ MaxMW 9,5ppg,_-__-._.___-______.-__.-___..__-.___--.-__ WGA 91712005 29 B_OPES,_tlotheymeetregulation__________________________ --- ----__Yes-_____ --__.-__________-_-__-_-___-_-___---_---_ 30 BOPE_press rating app[opriate; test to-(put prig in comments)_ - _ _ _ _ _ _ _ - - _ _ -Yes _ _ _ . _ _ Test to 4000 psi. -M$P 1575 psi__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ - _ _ _ , - _ _ _ - - _ _ _ - 31 Choke_manifoldcomp_Iiesw/API-RP-53(May84)__________________ __________Yes____--_ _-__.__--___-____----___-___-__ ---------------------------------- 32 Work willocc_u[withoutoperationshutdown_-_____-__-_____ __--__--Yes------- --------------------------------------------------------------- --- 33 Is presence_of H2$gri-probable - - - - - Yes - - 110-ppm~ - - - - - 34 Mechanical condition of wells within AOR verified (Forservice well only) - _ - _ - -Yes . - - All wells within AOR reviewed. - - - - - - - - . - - - . . - - - Geology 35 Permit_ean be issued w!o h_ydrog@gsulfide measures - .. - - - - - - - - - _ - . - Yes _ - - _ - - - -- - - - 36 Data_presentedon_potentialoverpressurezones______________ ___________NA--_____- . ____--- -_.--- --------------------------------------------------- Appr Date 37 Seismic analysis-of shallow gas zones... - _ _ _ - - - NA - - -- - - - - - - - RPC 91812005 38 Seabedcgnditionsurvey_(ifoff-shore)____________________-__ ---____--NA____ 39 -Contact na_melphone forweekly progress.reports [exploratory only]- - _ _ - NA- Geologic Engineering Public Commissioner: Date: sioner: Date Co Co mm i s Date ~ ~ , ~ ~ • .7 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Wetl History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jan 09 08:14:43 2007 Reel Header Service name .............LISTPE Date .....................07/01/09 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................07/01/09 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Greater Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 1 JOB NUMBER: W-0003954016 LOGGING ENGINEER: E. QUAM OPERATOR WITNESS: B. BUZBY SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RECEIVED JAN 2 9 2007 /~7C1D VY~N7. "ice""' JD~M ~ !~ Scientific Technical Services Scientific Technical Services V-214 PB1 500292327570 BP Exploration (Alaska) Inc. Sperry Drilling Services 09-JAN-07 11 11N 11E 4816 1862 78.80 53.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 34.000 101.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY • • (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS 4. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. DORTCH (SAIL/BP) DATED 12/13/06. MWD DATA ARE CONSIDERED PDC. 5. MWD RUN 1 REPRESENTS WELL V-214 PB1 WITH API#: 50-029-23275-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 1006'MD/1001'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name ............ .STSLIB.001 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .07/01/09 Maximum Physical Record. .65535 File Type ............... .LO Previous File Name...... .STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 129.5 964.5 ROP 167.5 1006.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 129.5 1006.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....Down Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Ns am Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 129.5 1006 567.75 1754 129.5 1006 GR MWD API 15.61 89.12 43.1186 1671 129.5 964.5 ROP MWD FT/H 4.72 1350.87 160.75 1678 167.5 First Reading For Entire File..........129.5 Last Reading For Entire File...........1006 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/01/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 129.5 964.5 ROP 167.5 1006.0 LOG HEADER DATA DATE LOGGED: 30-OCT-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 1006.0 TOP LOG INTERVAL (FT) 167.0 BOTTOM LOG INTERVAL (FT) 1006.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 10.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 101.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 300.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3) 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 73.0 1006 • • MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....Down Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 129.5 1006 567.75 1754 129.5 1006 GR MWDO10 API 15.61 89.12 43.1186 1671 129.5 964.5 ROP MWDO10 FT/H 4.72 1350.87 160.75 1678 167.5 1006 First Reading For Entire File..........129.5 Last Reading For Entire File...........1006 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/01/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/O1/09 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................07/01/09 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services • • Physical EOF Physical EOF End Of LIS File • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jan 09 16:32:02 2007 Reel Header Service name ............ .LISTPE Date .................... .07/01/09 Origin .................. .STS Reel Name ............... .UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments ................ .STS LIS Writing Library Tape Header Service name ............ .LISTPE Date .................... .07f01/09 Origin .................. .STS Tape Name ............... .UNKNOWN Continuation Number..... .01 Previous Tape Name...... .UNKNOWN Comments ................ .STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Greater Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 1 JOB NUMBER: MW0003954016 LOGGING ENGINEER: E. QUAM OPERATOR WITNESS: B. BUZBY RECEIVED JAN 2 9 2007 A~6k8 ~ $c CAS CODS. C,p~(IIi1iSSiOf1 Andarage Scientific Technical Services Scientific Technical Services V-214 PB2 500292327571 BP Exploration (Alaska) Inc. Sperry Drilling Services 09-JAN-07 MWD RUN 3 MWD RUN 4 MW0003954016 MW0003954016 D. RICHARDSO D. RICHARDSO B. BUZBY B. BUZBY MWD RUN 5 MWD RUN 7 MWD RUN 8 JOB NUMBER: MW0003954016 MW0003954016 MW0003954016 LOGGING ENGINEER: E. QUAM D. RICHARDSO E. QUAM OPERATOR WITNESS: B. BURSON C. GALLOWAY C. GALLOWAY MAD RUN 8 JOB NUMBER: MW0003954016 LOGGING ENGINEER: E. QUAM OPERATOR WITNESS: C. GALLOWAY SURFACE LOCATION SECTION: 11 TOWNSHIP: 11N RANGE: 11E FNL: FSL: 4816 FEL: 1862 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 78.80 GROUND LEVEL: 53.10 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 34.000 101.0 t~ zc a~ --t~~t ~ i~~ ~ ~ • • 2ND STRING 8.750 9.625 3757.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE EXITS V-214 PB1 AT 265'MD/265'TVD VIA A CEMENT PLUG. 4. MWD RUNS 1 - 7 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUN 8 ALSO INCLUDED ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN) AZIMUTHAL LITHO-DENSITY (ALD), AND PRESSURE WHILE DRILLING (PWD) NO DATA WERE ACQUIRED ON MWD RUNS 2 AND 6. MAD PASS DATA WERE ACQUIRED OVER THE INTERVAL 7230'MD-6524'MD (BIT DEPTHS) WHILE POOH AFTER REACHING FINAL TD. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. DORTCH (SAIL/BP) DATED 12/13/06. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-8 REPRESENT WELL V-214 PB2 WITH API#: 50-029-23275-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7380'MD/4858'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.75" BIT MUD WEIGHT: 8.9 - 9.0 PPG MUD SALINITY: 200-400 PPM CHLORIDES FORMATION WATER SALINITY: 15000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation.......07/01/09 Maximum Physical Record..65535 File Type ........ ........LO Previous File Nam e.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 129.5 7343.5 ROP 167.5 7380.0 RPX 3750.0 7335.5 FET 3750.0 7335.5 FCNT 3750.0 7282.5 PEF 3750.0 7295.5 RPS 3750.0 7335.5 RPM 3750.0 7335.5 RPD 3750.0 7335.5 DRHO 3750.0 7295.5 RHOB 3750.0 7295.5 NCNT 3750.0 7282.5 NPHI 3750.0 7282.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP 1 129.5 3 265.0 4 1776.0 5 2014.0 7 2545.0 8 3775.0 REMARKS: MERGED MAIN PASS. MERGE BASE 265.0 1776.0 2014.0 2545.0 3775.0 7380.0 Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....Down Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 • • First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 129.5 7380 3754.75 14502 129.5 7380 FONT MWD CNTS 392 2856 771.187 7066 3750 7282.5 NCNT MWD CNTS 96366 179445 118884 7066 3750 7282.5 RHOB MWD G/CM 0.749 2.901 2.13239 7092 3750 7295.5 DRHO MWD G/CM -1.818 0.383 0.0399595 7092 3750 7295.5 RPD MWD OHMM 0.77 2000 32.3503 7172 3750 7335.5 RPM MWD OHMM 0.49 1666.21 23.4088 7172 3750 7335.5 RPS MWD OHMM 0.72 2000 18.9388 7172 3750 7335.5 RPX MWD OHMM 0.1 2000 15.1364 7172 3750 7335.5 FET MWD HOUR 0.13 104.4 1.28025 7172 3750 7335.5 GR MWD API 8.06 141.81 67.1379 14429 129.5 7343.5 PEF MWD BARN -1.86 11.66 2.27829 7092 3750 7295.5 ROP MWD FTfH 0.23 3816.27 189.168 14426 167.5 7380 NPHI MWD PU-S 7.33 119.48 37.2857 7066 3750 7282.5 First Reading For Entire File..........129.5 Last Reading For Entire File...........7380 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/01/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/01/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH NPHI 6426.0 FONT 6426.0 NCNT 6426.0 RHOB 6439.0 DRHO 6439.0 PEF 6439.0 RPX 6479.0 RPM 6479.0 RPS 6479.0 FET 6479.0 RPD 6479.0 GR 6487.0 RAT 6525.0 MERGED DATA SOURCE PBU TOOL CODE MWD all MAD runs merged using earliest passes. STOP DEPTH 7132.5 7132.5 7132.5 7145.5 7145.5 7145.5 7185.5 7185.5 7185.5 7185.5 7185.5 7193.5 7380.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 8 1 3738.0 7380.0 • REMARKS: MERGED MAD PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 FONT MAD CNTS 4 1 68 4 2 NCNT MAD CNTS 4 1 68 8 3 RHOB MAD G/CM 4 1 68 12 4 DRHO MAD G/CM 4 1 68 16 5 RPD MAD OHMM 4 1 68 20 6 RPM MAD OHMM 4 1 68 24 7 RPS MAD OHMM 4 1 68 28 8 RPX MAD OHMM 4 1 68 32 9 FET MAD HOUR 4 1 68 36 10 GR MAD API 4 1 68 40 11 PEF MAD BARN 4 1 68 44 12 RAT MAD FT/H 4 1 68 48 13 NPHI MAD PU-S 4 1 68 52 14 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 6426 7380 6903 1909 6426 7380 FONT MAD CNTS 23 86 29.6775 1414 6426 7132.5 NCNT MAD CNTS 3705 5755 4121.37 1414 6426 7132.5 RHOB MAD G/CM 2.008 2.748 2.27501 1414 6439 7145.5 DRHO MAD GfCM -0.062 0.239 0.0301874 1414 6439 7145.5 RPD MAD OHMM 2 53.74 7.57399 1414 6479 7185.5 RPM MAD OHMM 1.78 53.52 7.36836 1414 6479 7185.5 RPS MAD OHMM 1.78 51.21 6.99899 1414 6479 7185.5 RPX MAD OHMM 1.63 61.19 6.65448 1414 6479 7185.5 FET MAD HOUR 9.56 24.15 16.5701 1414 6479 7185.5 GR MAD API 38.13 236.71 83.9733 1414 6487 7193.5 PEF MAD BARN 0.65 5.43 2.08395 1414 6439 7145.5 RAT MAD FT/H -15 566 183.38 1711 6525 7380 NPHI MAD PU-S 11.5 44.7 33.8597 1414 6426 7132.5 First Reading For Entire File..........6426 Last Reading For Entire File...........7380 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/01/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name ........... ..STSLIB.003 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..07/01/09 Maximum Physical Record..65535 File Type .............. ..LO Previous File Name..... ..STSLIB.002 • • Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 129.5 223.5 ROP 167,5 265.0 LOG HEADER DATA DATE LOGGED: 30-OCT-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 265.0 TOP LOG INTERVAL (FT) 130.0 BOTTOM LOG INTERVAL (FT) 265.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 10.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLERS CASING DEPTH (FT) 101.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LBjG) 8.80 MUD VISCOSITY (S) 300.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3) 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 73.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ................. .0 Data Specification Block Type.... .0 Logging Direction ................ .Down Optical log depth units.......... .Feet Data Reference Point ............. .Undefined Frame Spacing .................... .60 .lIN Max frames per record ............ .Undefined Absent value ..................... .-999 Depth Units ...................... . Datum Specification Block sub-typ e...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 ROP MWDO10 FT/H 4 1 68 Name Service Unit Min Max DEPT FT 129.5 287 GR MWDO10 API 16.92 37.03 ROP MWDO10 FT/H 30.63 1350.87 First Reading For Entire File..........129.5 Last Reading For Entire File...........265 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/01/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header 4 2 8 3 • First Last Mean Nsam Reading Reading 208.25 316 129.5 265 25.5504 190 129.5 223.5 388.421 196 167.5 265 Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/01/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 224.0 1734.5 ROP 265.5 1776.0 LOG HEADER DATA DATE LOGGED: 02-NOV-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 1776.0 TOP LOG INTERVAL (FT) 265.0 BOTTOM LOG INTERVAL (FT) 1776.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 1.1 MAXIMUM ANGLE: 39.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 101.0 BOREHOLE CONDITIONS • MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 • Polymer 8.80 265.0 8.8 300 000 .0 000 95.0 000 .0 000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 ROP MWD030 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 224 1776 1000 3105 224 1776 GR MWD030 API 17.5 109.56 59.4639 3022 224 1734.5 ROP MWD030 FT/H 0.24 252.16 93.6773 3022 265.5 1776 First Reading For Entire File..........224 Last Reading For Entire File...........1776 File Trailer Service name .......... ...STSLIB.004 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...07/01/09 Maximum Physical Record..65535 File Type ............. ...LO Next File Name........ ...STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.....,.07/01/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record • FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 1735.0 1973.5 ROP 1776.5 2014.0 LOG HEADER DATA DATE LOGGED: 03-NOV-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 2014.0 TOP LOG INTERVAL (FT) 1776.0 BOTTOM LOG INTERVAL (FT) 2014.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 36.2 MAXIMUM ANGLE: 14.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT): 101.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 265.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 80.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD040 API 4 1 68 4 2 ROP MWD040 FT/H 4 1 68 8 3 ~ • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1735 2014 1874.5 559 1735 2014 GR MWD040 API 19.61 93.3 58.0333 478 1735 1973.5 ROP MWD040 FT/H 6.56 675.22 180.694 476 1776.5 2014 First Reading For Entire File..........1735 Last Reading For Entire File...........2014 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/01/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name ............ .STSLIB.006 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .07JO1/09 Maximum Physical Record. .65535 File Type ............... .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. SIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 1974.0 2504.0 ROP 2014.5 2545.0 LOG HEADER DATA DATE LOGGED: 03-NOV-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 2545.0 TOP LOG INTERVAL (FT) 2014.0 BOTTOM LOG INTERVAL (FT) 2545.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 45.2 MAXIMUM ANGLE: 64.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 101.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.00 • MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 • 285.0 8.8 300 9.0 000 .0 000 83.0 000 .0 000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWDO50 API 4 1 68 4 2 ROP MWDO50 FTjH 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1974 2545 2259.5 1143 1974 2545 GR MWDO50 API 30.7 97.38 70.4076 1061 1974 2504 ROP MWDO50 FT/H 3.94 453.82 178.076 1062 2014.5 2545 First Reading For Entire File..........1974 Last Reading For Entire File...........2545 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/01/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name ........... ..STSLIB.007 Service Sub Level Name.. . Version Number......... ..1.0.0 Date of Generation..... ..07jO1j09 Maximum Physical Record ..65535 File Type .............. ..LO Previous File Name..... ..STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 • • RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2504.5 3737.5 ROP 2545.5 3775.0 LOG HEADER DATA DATE LOGGED: O5-NOV-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 3775.0 TOP LOG INTERVAL (FT) 2545.0 BOTTOM LOG INTERVAL (FT) 3775.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 62.0 MAXIMUM ANGLE: 68.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 101.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.50 MUD VISCOSITY (S) 225.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 83 .5 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD070 API 4 1 68 4 2 ROP MWD070 FT/H 4 1 68 8 3 U First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2504.5 3775 3139.75 2542 2504.5 3775 GR MWD070 API 32.81 105.76 69.6565 2467 2504.5 3737.5 ROP MWD070 FT/H 0.36 1025.56 229.407 2460 2545.5 3775 First Reading For Entire File..........2504.5 Last Reading For Entire File...........3775 File Trailer Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/01/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF File Header Service name .............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/01/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3738.0 7343.5 DRHO 3750.0 7295.5 FCNT 3750.0 7282.5 NPHI 3750.0 7282.5 RPS 3750.0 7335.5 NCNT 3750.0 7282.5 PEF 3750.0 7295.5 RHOB 3750.0 7295.5 RPM 3750.0 7335.5 RPX 3750.0 7335.5 RPD 3750.0 7335.5 FET 3750.0 7335.5 ROP 3775.5 7380.0 LOG HEADER DATA DATE LOGGED: 11-NOV-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7380.0 TOP LOG INTERVAL (FT) 3775.0 BOTTOM LOG INTERVAL (FT) 7380.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 17.4 MAXIMUM ANGLE: 67.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124725 • EWR4 ELECTROMAG. RESIS. 4 121079 CTN COMP THERMAL NEUTRON 1844674407370955 ALD Azimuthal Litho-Den 143794 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT) 3757.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 8.90 MUD VISCOSITY (S) 45.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3) 5.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.050 80.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.060 122.0 MUD FILTRATE AT MT: 3.400 78.0 MUD CAKE AT MT: 2.900 78.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWDO80 CNTS 4 1 68 4 2 NCNT MWD080 CNTS 4 1 68 8 3 RHOB MWD080 G/CM 4 1 68 12 4 DRHO MWDO80 G/CM 4 1 68 16 5 RPD MWD080 OHMM 4 1 68 20 6 RPM MWD080 OHMM 4 1 68 24 7 RPS MWDO80 OHMM 4 1 68 28 8 RPX MWD080 OHMM 4 1 68 32 9 FET MWDO80 HOUR 4 1 68 36 10 GR MWDO80 API 4 1 68 40 11 PEF MWDO80 BARN 4 1 68 44 12 ROP MWD080 FT/H 4 1 68 48 13 NPHI MWD080 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3738 7380 5559 7285 3738 7380 FCNT MWD080 CNTS 392 2856 771.187 7066 3750 7282.5 NCNT MWD080 CNTS 96366 179445 118884 7066 3750 7282.5 RHOB MWDO80 G/CM 0.749 2.901 2.13239 7092 3750 7295.5 DRHO MWD080 GfCM -1.818 0.383 0.0399595 7092 3750 7295.5 RPD MWD080 OHMM 0.77 2000 32.3503 7172 3750 7335.5 RPM MWDO80 OHMM 0.49 1666.21 23.4088 7172 3750 7335.5 RPS MWD080 OHMM 0.72 2000 18.9388 7172 3750 7335.5 RPX MWD080 OHMM 0.1 2000 15.1364 7172 3750 7335.5 FET MWD080 HOUR 0.13 104.4 1.28025 7172 3750 7335.5 GR MWD080 API 8.06 141.81 70.7035 7212 3738 7343.5 • • PEF MWD080 BARN -1.86 11.66 2.27829 7092 3750 ROP MWD080 FT/H 0.23 3816.27 212.239 7210 3775.5 NPHI MWD080 PU-S 7.33 119.48 37.2857 7066 3750 First Reading For Entire File..........3738 Last Reading For Entire File...........7380 File Trailer Service name .......... ...STSLIB.008 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...07/01/09 Maximum Physical Record..65535 File Type ............. ...LO Next File Name........ ...STSLIB.009 Physical EOF File Header Service name .............STSLZB.009 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/01/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 8 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 6426.0 7132.5 FONT 6426.0 7132.5 NCNT 6426.0 7132.5 PEF 6439.0 7145.5 RHOB 6439.0 7145.5 DRHO 6439.0 7145.5 RPD 6479.0 7185.5 RPX 6479.0 7185.5 RPS 6479.0 7185.5 RPM 6479.0 7185.5 FET 6479.0 7185.5 GR 6487.0 7193.5 RAT 6525.0 7380.0 LOG HEADER DATA DATE LOGGED: 11-NOV-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7230.0 TOP LOG INTERVAL (FT) 6524.0 BOTTOM LOG INTERVAL (FT) 7230.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 17.4 MAXIMUM ANGLE: 67.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124725 EWR4 ELECTROMAG. RESIS. 4 121079 CTN COMP THERMAL NEUTRON 1844674407370955 7295.5 7380 7282.5 • • ALD Azimuthal Litho-Den 143794 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 3757.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 8.90 MUD VISCOSITY (S) 45.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3) 5.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.050 80.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.060 122.0 MUD FILTRATE AT MT: 3.400 78.0 MUD CAKE AT MT: 2.900 78.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical loq depth units...........Feet Data Reference Point ...............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MAD081 CNTS 4 1 68 4 2 NCNT MAD081 CNTS 4 1 68 8 3 RHOB MAD081 G/CM 4 1 68 12 4 DRHO MAD081 G/CM 4 1 68 16 5 RPD MAD081 OHMM 4 1 68 20 6 RPM MAD081 OHMM 4 1 68 24 7 RPS MAD081 OHMM 4 1 68 28 8 RPX MAD081 OHMM 4 1 68 32 9 FET MADO81 HOUR 4 1 68 36 10 GR MAD081 API 4 1 68 40 11 PEF MADO81 BARN 4 1 68 44 12 RAT MAD081 FT/H 4 1 68 48 13 NPHI MAD081 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6426 73.80 6903 1909 6426 7380 FCNT MAD081 CNTS 23 86 29.6775 1414 6426 713.2.5 NCNT MAD081 CNTS 3705 5755 4121.37 1414 6426 7132:5 RHOB MAD081 G/CM 2.008 2.748 2.27501 1414 6439 7145.5 DRHO MAD081 G/CM -0.062 0.239 0.0301874 1414 6439 7145.8 RPD MAD081 OHMM 2 53.74 7.57399 1414 6479 7185.5 RPM MADO81 OHMM 1.78 53.52 7.36836 1414 6479 7185.5 RPS MAD081 OHMM 1.78 51.21 6.99899 1414 6479 7185.5 RPX MADO81 OHMM 1.63 61..19 6.65448 1414 6479 7185.5 FET MADO81 HOUR 9.56 24.15 16.5701 1414 6479. 7185.5 GR MADO81 API 38.13 236.71 83.9733 .1414 6487 7193.5 PEF MADO81 BARN 0.65 5.43 2.08395 1414 6439 7145.5 RAT MAD081 FT/H -1S 566 183.38 1711 6525 7380 • • NPHI MAD081 PU-S 11.5 44.7 33.8597 1414 6426 7132.5 First Reading For Entire File..........6426 Last Reading For Entire File...........7380 File Trailer Service name .............STSLIB.009 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.010 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/01/09 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................07/01/09 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jan 10 08:34:32 2007 Reel Header Service name ....... ......LISTPE Date ............... ......07/O1/10 Origin ............. ......STS Reel Name .......... ......UNKNOWN Continuation Number ......01 Previous Reel Name. ......UNKNOWN Comments ........... ......STS LIS Writing Library Tape Header Service name ....... ......LISTPE Date ............... ......07/O1/10 Origin ............. ......STS Tape Name .......... ......UNKNOWN Continuation Number ......01 Previous Tape Name. ......UNKNOWN Comments ........... ......STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Greater Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 1 JOB NUMBER: ,. MW0003954016 LOGGING ENGINEER: E. QUAM OPERATOR WITNESS: B. BUZBY .7 ~EC~tVED JAN 2 9 2007 a 17~D ~A~Awpw"^"~M1 /'9M MP~~ Scientific Technical Services Scientific Technical Services V-214 PB3 500292327572 BP Exploration (Alaska) Inc. Sperry Drilling Services 10-JAN-07 MWD RUN 3 MWD RUN 4 MW0003954016 MW0003954016 D. RICHARDSO D. RICHARDSO B. BUZBY B. BUZBY MWD RUN 5 MWD RUN 7 MWD RUN 8 JOB NUMBER: MW0003954016 MW0003954016 MW0003954016 LOGGING ENGINEER: E. QUAM D. RICHARDSO E. QUAM OPERATOR WITNESS: B. BURSON C. GALLOWAY C. GALLOWAY MWD RUN 9 MWD RUN 10 JOB NUMBER: MW0003954016 MW0003954016 LOGGING ENGINEER: M. LEAFSTEDT N. WHITE OPERATOR WITNESS: C. GALLOWAY C. GALLOWAY SURFACE LOCATION SECTION: 11 TOWNSHIP: 11N RANGE: 11E FNL: FSL: 4816 FEL: 1862 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 78.80 GROUND LEVEL: 53.10 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 34.000 101.0 U ~.~ abs -13~t ~` 1~ ~~r 2ND STRING 8.750 9.625 3757.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE IS THE RESULT OF AN INADVERTENT SIDETRACK DURING A HOLEOPENER RUN IN V-214 PB2. IT EXITS V-214 PB2 AT 3821'MD/2668'TVD. 4. MWD RUNS 1 - 7 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUNS 8-11 ALSO INCLUDED ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) AND PRESSURE WHILE DRILLING (PWD) POROSITY DATA ACQUIRED DURING MWD RUN 8 ARE ONLY PRESENTED FOR V-214 PB2. NO DATA WERE ACQUIRED ON MWD RUNS 2, 6, AND 11. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. DORTCH (SAIC/BP) DATED 12/13/06. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-11 REPRESENT WELL V-214 PB3 WITH API#:50-029-23275-72. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6196'MD/3786'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY {DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name ........... ..STSLIB.001 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..07/O1/10 Maximum Physical Record..65535 File Type .............. ..LO Previous File Name..... ..STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 129.5 6159.5 ROP 167.0 6196.0 RPX 3750.0 6151.5 RPM 3750.0 6151.5 RPD 3750.0 6151.5 FET 3750.0 6151.5 RPS 3750.0 6151.5 BASELINE CURVE FOR SHIFTS: • CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 129.5 265.0 MWD 3 265.0 1776.0 MWD 4 1776.0 2014.0 MWD 5 2014.0 2545.0 MWD 7 2545.0 3775.0 MWD 8 3775.0 3821.0 MWD 9 3821.0 4685.0 MWD 10 4685.0 b196.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .1IN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 129.5 6196 3162.75 12134 129.5 6196 RPD MWD OHMM 0.56 2000 41.8778 4804 3750 6151.5 RPM MWD OHMM 0.49 1743.45 26.7383 4804 3750 6151.5 RPS MWD OHMM 2.16 2000 20.5718 4804 3750 6151.5 RPX MWD OHMM 0.1 1186.63 14.8802 4804 3750 6151.5 FET MWD HOUR 0.2 110.4 2.90006 4804 3750 6151.5 GR MWD API 12.77 134.82 65.6045 12061 129.5 6159.5 ROP MWD FT/H 0.09 1598.91 175.007 12059 167 6196 First Reading For Entire File..........129.5 Last Reading For Entire File...........6196 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... • • Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 129.5 223.5 ROP 167.0 265.0 LOG HEADER DATA DATE LOGGED: 30-OCT-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 265.0 TOP LOG INTERVAL (FT) 129.5 BOTTOM LOG INTERVAL (FT) 265.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 10.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 101.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S): 300.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3) 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 73.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 • ~ Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 129.5 287 208.25 316 129.5 287 GR MWDO10 API 16.92 37.03 25.5504 190 129.5 287 ROP MWDO10 FT/H 30.63 1350.87 386.806 197 167 265 First Reading For Entire File..........129.5 Last Reading For Entire File...........287 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB,003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/01/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 224.0 1734.5 ROP 265.5 1776.0 LOG HEADER DATA DATE LOGGED: 02-NOV-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 1776.0 TOP LOG INTERVAL (FT) 265.0 BOTTOM LOG INTERVAL (FT) 1776.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 1.1 MAXIMUM ANGLE: 39.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 101.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 265.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 95.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............... ...0 Data Specification Block Type.. ...0 Logging Direction .............. ...Down Optical log depth units........ ...Feet Data Reference Point ........... ...Undefined Frame Spacing .................. ...60 .lIN Max frames per record .......... ...Undefined Absent value ................... ...-999 Depth Units .................... ... Datum Specification Block sub-t ype...0 Name Service Order Units Size Nsam Rep Code Of fset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 ROP MWD030 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 224 1776 1000 3105 224 1776 GR MWD030 API 17.5 109.56 59 .4639 3022 224 1734.5 ROP MWD030 FT/H 0.24 252.16 93 .6773 3022 265.5 1776 First Reading For Entire File..........224 Last Reading For Entire File...........1776 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 • s Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 1735.0 1973.5 ROP 1776.5 2014.0 LOG HEADER DATA DATE LOGGED: 03-NOV-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 2014.0 TOP LOG INTERVAL (FT) 1776.0 BOTTOM LOG INTERVAL (FT) 2014.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 36.2 MAXIMUM ANGLE: 14.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 101.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 265.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 80 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ................. .0 Data Specification Block Type.... .0 Logging Direction ................ .Down Optical log depth units.......... .Feet Data Reference Point ............. .Undefined Frame Spacing .................... .60 .lIN Max frames per record ............ .Undefined Absent value ..................... .-999 Depth Units ...................... . Datum Specification Block sub-typ e...0 • s Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD040 API 4 1 68 4 2 ROP MWD040 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1735 2014 1874.5 559 1735 2014 GR MWD040 API 19.61 93.3 58.0333 478 1735 1973.5 ROP MWD040 FT/H 6.56 675.22 180.694 476 1776.5 2014 First Reading For Entire File..........1735 Last Reading For Entire File...........2014 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number........... 1.0.0 Date of Generation....... 07/O1/10 Maximum Physical Record.. 65535 File Type ................ LO Previous File Name....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 1974.0 2504.0 ROP 2014.5 2545.0 LOG HEADER DATA DATE LOGGED: 03-NOV-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 2545.0 TOP LOG INTERVAL (FT) 2014.0 BOTTOM LOG INTERVAL (FT) 2545.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 45.2 MAXIMUM ANGLE: 64.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 • DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • 101.0 Polymer 9.00 285.0 8.8 300 9.0 000 .0 000 83.0 000 .0 000 .0 Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....DOwn Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Name Service Order Units Size Ns am Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWDO50 API 4 1 68 4 2 ROP MWDO50 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1974 2545 2259.5 1143 1974 2545 GR MWDO50 API 30.7 97.38 70.4076 1061 1974 2504 ROP MWDO50 FT/H 3.94 453.82 178.076 1062 2014.5 2545 First Reading For Entire File..........1974 Last Reading For Entire File...........2545 File Trailer Service name .......... ...STSLIB.005 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...07/O1/10 Maximum Physical Record..65535 File Type ............. ...LO Next File Name........ ...STSLIB.006 Physical EOF File Header Service name .......... ...STSLIB.006 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...07/O1/10 Maximum Physical Record..65535 File Type ............. ...LO ~ • Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2504.5 3737.5 ROP 2545.5 3775.0 LOG HEADER DATA DATE LOGGED: OS-NOV-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 3775.0 TOP LOG INTERVAL (FT) 2545.0 BOTTOM LOG INTERVAL (FT) 3775.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 62.0 MAXIMUM ANGLE: 68.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 101.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.50 MUD VISCOSITY (S) 225.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 83.5 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD070 API 4 1 68 4 2 ROP MWD070 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2504.5 3775 3139.75 2542 2504.5 3775 GR MWD070 API 32.81 105.76 69.6565 2467 2504.5 3737.5 ROP MWD070 FT/H 0.36 1025.56 229.407 2460 2545.5 3775 First Reading For Entire File..........2504. 5 Last Reading For Entire File...........3775 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3738.0 3821.0 RPS 3750.0 3820.5 RPX 3750.0 3820.5 RPM 3750.0 3820.5 RPD 3750.0 3820.5 FET 3750.0 3820.5 ROP 3775.5 3821.0 LOG HEADER DATA DATE LOGGED: 11-NOV-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 3821.0 TOP LOG INTERVAL (FT) 3775.0 BOTTOM LOG INTERVAL (FT) 3821.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 17.4 MAXIMUM ANGLE: 67.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124725 EWR4 ELECTROMAG. RESIS. 4 121079 S BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLERS CASING DEPTH (FT) 3757.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 8.90 MUD VISCOSITY (S) 45.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3) 5.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.050 80.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.060 122.0 MUD FILTRATE AT MT: 3.400 78.0 MUD CAKE AT MT: 2.900 78.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWDO80 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3738 3821 3779.5 167 3738 3821 RPD MWD080 OHMM 5.43 2000 209.726 142 3750 3820.5 RPM MWD080 OHMM 0.49 50.68 13.5289 142 3750 3820.5 RPS MWDO80 OHMM 6.69 2000 52.9397 142 3750 3820.5 RPX MWD080 OHMM 0.1 14.13 10.8513 142 3750 3820.5 FET MWD080 HOUR 1.61 104.4 40.2961 142 3750 3820.5 GR MWD080 API 41.13 101.64 73.7082 167 3738 3821 ROP MWD080 FT/H 1.49 702.58 240.04 92 3775.5 3821 First Reading For Entire File..........3738 Last Reading For Entire File...........3821 File Trailer Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 • ~ File Type ................LO Next File Name...........STSLIB.008 Physical EOF File Header Service name .............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH .STOP DEPTH FET 3821.0 4640.5 RPX 3821.0 4640.5 RPS 3821.0 4640.5 RPM 3821.0 4640.5 RPD 3821.0 4640.5 GR 3821.5 4648.5 ROP 3821.5 4685.0 LOG HEADER DATA DATE LOGGED: 14-NOV-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4685.0 TOP LOG INTERVAL (FT) 3821.0 BOTTOM LOG INTERVAL (FT) 4685.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 61.7 MAXIMUM ANGLE: 66.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124725 EWR4 ELECTROMAG. RESIS. 4 121079 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.750 DRILLER'S CASING DEPTH (FT) 3757.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.20 MUD VISCOSITY (S) 45.0 MUD PH: .2 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3) 5.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.550 76.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.840 96.8 MUD FILTRATE AT MT: 3.500 75.0 MUD CAKE AT MT: 3.700 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): • • TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD090 OHMM 4 1 68 4 2 RPM MWD090 OHMM 4 1 68 8 3 RPS MWD090 OHMM 4 1 68 12 4 RPX MWD090 OHMM 4 1 68 16 5 FET MWD090 HOUR 4 1 68 20 6 GR MWD090 API 4 1 68 24 7 ROP MWD090 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3821 4685 4253 1729 3821 4685 RPD MWD090 OHMM 1.5 2000 80.5801 1640 3821 4640.5 RPM MWD090 OHMM 1.25 1743.45 54.8741 1640 3821 4640.5 RPS MWD090 OHMM 4.17 498.59 34.1955 1640 3821 4640.5 RPX MWD090 OHMM 4.21 193.59 23.6189 1640 3821 4640.5 FET MWD090 HOUR 0.2 110.4 0.953689 1640 3821 4640.5 GR MWD090 API 12.77 120.78 70.2576 1655 3821.5 4648.5 ROP MWD090 FT/H 22.61 1242.73 275.195 1728 3821.5 4685 First Reading For Entire File..........3821 Last Reading For Entire File...........4685 File Trailer Service name .............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.009 Physical EOF File Header Service name .............STSLIB.009 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 4641.0 6151.5 RPD 4641.0 6151.5 RPM 4641.0 6151.5 RPS 4641.0 6151.5 RPX 4641.0 6151.5 GR 4649.0 6159.5 ROP 4685.5 6196.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 17-NOV-OS Insite 66.37 Memory 6196.0 46fl5.0 6196.0 44.2 69.0 TOOL NUMBER 124725 121079 8.750 3757.0 Polymer 9.20 49.0 9.0 400 10.2 3.550 76.0 2.560 108.0 3.500 75.0 3.700 72.0 Data Format Specification Record Data Record Type ................. .0 Data Specification Block Type.... .0 Logging Direction ................ .DOwn Optical log depth units.......... .Feet Data Reference Point ............. .Undefined Frame Spacing .................... .60 .lIN Max frames per record ............ .Undefined Absent value ..................... .-999 Depth Units ...................... . Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD100 OHMM 4 1 68 4 2 RPM MWD100 OHMM 4 1 68 8 3 RPS MWD100 OHMM 4 1 68 12 4 RPX MWD100 OHMM 4 1 68 16 5 FET MWD100 HOUR 4 1 68 20 6 GR MWD100 API 4 1 68 24 7 ROP MWD100 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4641 6196 5418.5 3111 4641 6196 RPD MWD100 OHMM 0.56 2000 12.9876 3022 4641 6151.5 RPM MWD100 OHMM 0.6 1684.4 12.0901 3022 4641 6151.5 RPS MWD100 OHMM 2.16 2000 11.6575 3022 4641 6151.5 RPX MWD100 OHMM 2.8 1186.63 10.3272 3022 4641 6151.5 FET MWD100 HOUR 0.22 27.73 2.19914 3022 4641 6151.5 GR MWD100 API 13.53 134.82 67.4559 3022 4649 6159.5 ROP MWD100 FT/H 0.09 1598.91 137.004 3022 4685.5 6196 First Reading For Entire File..........4641 Last Reading For Entire File...........6196 File Trailer Service name .............STSLIB.009 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.010 Physical EOF Tape Trailer Service name ......... ....LISTPE Date ................. ....07/O1/10 Origin ............... ....STS Tape Name ............ ....UNKNOWN Continuation Number.. ....01 Next Tape Name....... ....UNKNOWN Comments ............. ....STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ......... ....LISTPE Date ................. ....07/O1/10 Origin ............... ....STS Reel Name ............ ....UNKNOWN Continuation Number.. ....01 Next Reel Name....... ....UNKNOWN Comments ............. ....STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed Jan 10 16:52:59 2007 Reel Header Service name ......... ....LISTPE Date ................. ....07/O1/10 Origin ............... ....STS Reel Name ............ ....UNKNOWN Continuation Number.. ....01 Previous Reel Name... ....UNKNOWN Comments ............. ....STS LIS Writing Library Tape Header Service name ......... ....LISTPE Date ................. ....07/O1/10 Origin ............... ....STS Tape Name ............ ....UNKNOWN Continuation Number.. ....01 Previous Tape Name... ....UNKNOWN Comments ............. ....STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Greater Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA RECENED JAN 2 9 2001 ~a~ ~~'? Scientific Technical Services Scientific Technical Services V-214 PB4 500292327573 BP Exploration (Alaska) Inc. Sperry Drilling Services 10-JAN-07 MWD RUN 1 MWD RUN 3 MWD RUN 4 JOB NUMBER: MW0003954016 MW0003954016 MW0003954016 LOGGING ENGINEER: E. QUAM D. RICHARDSO D. RICHARDSO OPERATOR WITNESS: B. BUZBY B. BUZBY B. BUZBY MWD RUN 5 MWD RUN 7 MWD RUN 8 JOB NUMBER: MW0003954016 MW0003954016 MW0003954016 LOGGING ENGINEER: E. QUAM D. RICHARDSO E. QUAM OPERATOR WITNESS: B. BURSON C. GALLOWAY C. GALLOWAY MWD RUN 13 MWD RUN 14 JOB NUMBER: MW0003954016 MW0003954016 LOGGING ENGINEER: D. RICHARDSO D. RICHARDSO OPERATOR WITNESS: B. BUZZBY B. BUZBY SURFACE LOCATION SECTION: 11 TOWNSHIP: 11N RANGE: 11E FNL: FSL: 4816 FEL: 1862 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 78.80 GROUND LEVEL: 53.10 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 34.000 101.0 ~C dn~ v~3~t ~ `'t ~~ LJ • 2ND STRING 8.750 9.625 3757.0 3RD STRING 6.750 9.625 3757.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE IS AN OPENHOLE SIDETRACK, EXITING V-214 PB2 AT 3808'MD/2662' TVD. 4. MWD RUNS 1 - 7 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUNS 8,12-17 ALSO INCLUDED ELECTRO- MAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) AND PRESSURE WHILE DRILLING (PWD). POROSITY DATA ACQUIRED DURING MWD RUN 8 ARE ONLY PRESENTED FOR V-214 PB2. NO DATA WERE ACQUIRED ON MWD RUNS 2, 6, AND 12. MWD RUNS 15-17 WERE FAILED ATTEMPTS TO SIDETRACK INTO ORIGINAL WELLBORE - NO DATA ARE PRESENTED. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. DORTCH (SAIC/BP) DATED 12/13/06. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-7,8-14 REPRESENT WELL V-214 PB4 WITH API#: 50-029-23275-73. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5336'MD/3321'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 129.5 5279.5 ROP 167.0 5336.0 RPD 3750.0 5286.5 FET 3750.0 5286.5 RPS 3750.0 5286.5 RPX 3750.0 5286.5 RPM 3750.0 5286.5 • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 129.5 265.0 MWD 3 265.0 1776.0 MWD 4 1776.0 2014.0 MWD 5 2014.0 2545.0 MWD 7 2545.0 3775.0 MWD 8 3775.0 3808.0 MWD 13 3808.5 4489.0 MWD 14 4489.0 5336.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 129.5 5336 2732.75 10414 129.5 5336 RPD MWD OHMM 0.36 2000 50.709 2964 3750 5286.5 RPM MWD OHMM 0.35 2000 29.4258 2964 3750 5286.5 RPS MWD OHMM 0.52 2000 24.7265 2964 3750 5286.5 RPX MWD OHMM 0.1 157.02 16.2741 2964 3750 5286.5 FET MWD HOUR 0.04 364.57 6.01872 2964 3750 5286.5 GR MWD API 14.63 138.41 62.9129 10208 129.5 5279.5 ROP MWD FT/H 0.24 23517.6 358.419 10339 167 5336 First Reading For Entire File..........129.5 Last Reading For Entire File...........5336 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF • ~ File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 129.5 223.5 ROP 167.0 265.0 LOG HEADER DATA DATE LOGGED: 30-OCT-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 265.0 TOP LOG INTERVAL (FT) 129.5 BOTTOM LOG INTERVAL (FT) 265.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 10.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 101.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 300.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 500 FLUID LOSS (C3) 7.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 73.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined • ~ Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 129.5 287 208.25 316 129.5 287 GR MWDO10 API 16.92 37.03 25.5504 190 129.5 287 ROP MWDO10 FT/H 30.63 1350.87 386.806 197 167 265 First Reading For Entire File..........129.5 Last Reading For Entire File...........287 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name ............ .STSLIB.003 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .07/O1/10 Maximum Physical Record. .65535 File Type ............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 224.0 1734.5 ROP 265.5 1776.0 LOG HEADER DATA DATE LOGGED: 02-NOV-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 1776.0 TOP LOG INTERVAL (FT) 265.0 BOTTOM LOG INTERVAL (FT) 1776.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 1.1 MAXIMUM ANGLE: 39.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER • • DGR DUAL GAMMA RAY 216261 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 101.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 265.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 95.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Of fset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 ROP MWD030 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 224 1776 1000 3105 224 1776 GR MWD030 API 17.5 109.56 59 .4639 3022 224 1734.5 ROP MWD030 FT/H 0.24 252.16 93 .6773 3022 265.5 1776 First Reading For Entire File..........224 Last Reading For Entire File...........1776 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 • • Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..07/O1/10 Maximum Physical Record ..65535 File Type .............. ..LO Previous File Name..... ..STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 1735.0 1973.5 ROP 1776.5 2014.0 LOG HEADER DATA DATE LOGGED: 03-NOV-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 2014.0 TOP LOG INTERVAL (FT) 1776.0 BOTTOM LOG INTERVAL (FT) 2014.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 36.2 MAXIMUM ANGLE: 14.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 101.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 265.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 80.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined • • Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD040 API 4 1 68 4 2 ROP MWD040 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1735 2014 1874.5 559 1735 2014 GR MWD040 API 19.61 93.3 58.0333 478 1735 1973.5 ROP MWD040 FT/H 6.56 675.22 180.694 476 1776.5 2014 First Reading For Entire File..........1735 Last Reading For Entire File...........2014 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name ........... ..STSLIB.005 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..07/O1/10 Maximum Physical Record ..65535 File Type .............. ..LO Previous File Name..... ..STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 1974.0 2504.0 ROP 2014.5 2545.0 LOG HEADER DATA DATE LOGGED: 03-NOV-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 2545.0 TOP LOG INTERVAL (FT) 2014.0 BOTTOM LOG INTERVAL (FT) 2545.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 45.2 MAXIMUM ANGLE: 64.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 • • BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 101.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 285.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3) 9.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE : .000 83.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............... ...0 Data Specification Block Type.. ...0 Logging Direction .............. ...DOwn Optical log depth units........ ...Feet Data Reference Point ........... ...Undefined Frame Spacing .................. ...60 .lIN Max frames per record .......... ...Undefined Absent value ................... ...-999 Depth Units .................... ... Datum Specification Block sub-t ype...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWDO50 API 4 1 68 4 2 ROP MWDO50 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 1974 2545 2259.5 1143 1974 2545 GR MWDO50 API 30.7 97.38 70.4076 1061 1974 2504 ROP MWDO50 FT/H 3.94 453.82 178.076 1062 2014.5 2545 First Reading For Entire File..........1974 Last Reading For Entire File...........2545 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 • • Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2504.5 3737.5 ROP 2545.5 3775.0 LOG HEADER DATA DATE LOGGED: OS-NOV-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 3775.0 TOP LOG INTERVAL (FT) 2545.0 BOTTOM LOG INTERVAL (FT) 3775.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 62.0 MAXIMUM ANGLE: 68.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216261 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 101.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.50 MUD VISCOSITY (S) 225.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 . 83.5 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type..... 0 Logging Direction ................. Down Optical log depth units........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... • • Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD070 API 4 1 68 4 2 ROP MWD070 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2504.5 3775 3139.75 2542 2504.5 3775 GR MWD070 API 32.81 105.76 69.6565 2467 2504.5 3737.5 ROP MWD070 FT/H 0.36 1025.56 229.407 2460 2545.5 3775 First Reading For Entire File..........2504.5 Last Reading For Entire File...........3775 File Trailer Service name .......... ...STSLIB.006 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...07/O1/10 Maximum Physical Record..65535 File Type ............. ...LO Next File Name........ ...STSLIB.007 Physical EOF File Header Service name ........... ..STSLIB.007 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..07/O1/10 Maximum Physical Record ..65535 File Type .............. ..LO Previous File Name..... ..STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3738.0 3808.0 FET 3750.0 3808.0 RPS 3750.0 3808.0 RPD 3750.0 3808.0 RPM 3750.0 3808.0 RPX 3750.0 3808.0 ROP 3775.5 3808.0 LOG HEADER DATA DATE LOGGED: 11-NOV-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 3808.0 TOP LOG INTERVAL (FT) 3775.0 BOTTOM LOG INTERVAL (FT) 3808.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 17.4 MAXIMUM ANGLE: 67.5 TOOL STRING (TOP TO BOTTOM) • VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............... ...0 Data Specification Block Type.. ...0 Logging Direction .............. ...DOwn Optical log depth units........ ...Feet Data Reference Point ........... ...Undefined Frame Spacing .................. ...60 .lIN Max frames per record .......... ...Undefined Absent value ................... ...-999 Depth Units .................... ... Datum Specification Block sub-type...0 TOOL NUMBER 124725 121079 8.750 3757.0 Polymer 8.90 45.0 8.9 400 5.6 • 3.050 80.0 2.060 122.0 3.400 78.0 2.900 78.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3738 3808 3773 141 3738 3808 RPD MWD080 OHMM 5.43 2000 251.316 117 3750 3808 RPM MWD080 OHMM 0.49 50.68 13.4135 117 3750 3808 RPS MWD080 OHMM 6.69 2000 61.3357 117 3750 3808 RPX MWDO80 OHMM 0.1 13.12 10.3685 117 3750 3808 FET MWD080 HOUR 1.61 104.4 48.5392 117 3750 3808 GR MWD080 API 41.13 101.64 72.8971 141 3738 3808 ROP MWD080 FT/H 1.49 702.58 196.079 66 3775.5 3808 First Reading For Entire File..........3738 Last Reading For Entire File...........3808 File Trailer Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF File Header Service name .............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 3808.5 4489.0 GR 3808.5 4432.5 FET 3808.5 4439.5 RPX 3808.5 4439.5 RPD 3808.5 4439.5 RPS 3808.5 4439.5 RPM 3808.5 4439.5 LOG HEADER DATA DATE LOGGED: 26-NOV-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4489.0 TOP LOG INTERVAL (FT) 3808.0 BOTTOM LOG INTERVAL (FT) 4489.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 64.0 MAXIMUM ANGLE: 65.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 90518 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 3757.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 47.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.550 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.330 75.0 MUD FILTRATE AT MT: 3.500 70.0 MUD CAKE AT MT: 3.700 70.0 NEUTRON TOOL • MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD MWD130 OHMM 4 1 68 4 2 RPM MWD130 OHMM 4 1 68 8 3 RPS MWD130 OHMM 4 1 68 12 4 RPX MWD130 OHMM 4 1 68 16 5 FET MWD130 HOUR 4 1 68 20 6 GR MWD130 API 4 1 68 24 7 ROP MWD130 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3808.5 4489 4148.75 1362 3808.5 4489 RPD MWD130 OHMM 1.14 870.46 69.829 1153 3808.5 4439.5 RPM MWD130 OHMM 3.08 457.53 43.7925 1153 3808.5 4439.5 RPS MWD130 OHMM 4.39 273.88 29.1371 1153 3808.5 4439.5 RPX MWD130 OHMM 5.12 110.23 18.7361 1153 3808.5 4439.5 FET MWD130 HOUR 0.04 364.57 7.1718 1153 3808.5 4439.5 GR MWD130 API 18.11 100.68 63.988 1156 3808.5 4432.5 ROP MWD130 FT/H 2.24 23517.6 1307.23 1362 3808.5 4489 First Reading For Entire File..........3808.5 Last Reading For Entire File...........4489 File Trailer Service name .............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/O1/10 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.009 Physical EOF File Header Service name ........... ..STSLIB.009 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..07/01/10 Maximum Physical Record ..65535 File Type .............. ..LO Previous File Name..... ..STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD • • Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4433.0 5279.5 FET 4440.0 5286.5 RPD 4440.0 5286.5 RPM 4440.0 5286.5 RPX 4440.0 5286.5 RPS 4440.0 5286.5 ROP 4489.5 5336.0 LOG HEADER DATA DATE LOGGED: 25-NOV-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5336.0 TOP LOG INTERVAL (FT) 4489.0 BOTTOM LOG INTERVAL (FT) 5336.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 62.3 MAXIMUM ANGLE: 67.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 90518 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 3757.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 8.90 MUD VISCOSITY (S) 10.0 MUD PH: 9.8 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3) 5.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.500 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.250 78.0 MUD FILTRATE AT MT: 4.000 72.0 MUD CAKE AT MT: 4.500 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............... ...0 Data Specification Block Type.. ...0 Logging Direction .............. ...Down Optical log depth units........ ...Feet Data Reference Point ........... ...Undefined Frame Spacing .................. ...60 .lIN Max frames per record .......... ...Undefined Absent value ................... ...-999 Depth Units .................... ... Datum Specification Block sub-t ype...0 Name Service Order Units Size Nsam Rep Code Offset Channel • • DEPT FT 4 1 68 0 1 RPD MWD140 OHMM 4 1 68 4 2 RPM MWD140 OHMM 4 1 68 8 3 RPS MWD140 OHMM 4 1 68 12 4 RPX MWD140 OHMM 4 1 68 16 5 FET MWD140 HOUR 4 1 68 20 6 GR MWD140 API 4 1 68 24 7 ROP MWD140 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4433 5336 4884.5 1807 4433 5336 RPD MWD140 OHMM 0.36 2000 23.8398 1694 4440 5286.5 RPM MWD140 OHMM 0.35 2000 20.7533 1694 4440 5286.5 RPS MWD140 OHMM 0.52 1565.39 19.196 1694 4440 5286.5 RPX MWD140 OHMM 0.89 157.02 15.0063 1694 4440 5286.5 FET MWD140 HOUR 0.04 16.69 2.29711 1694 4440 5286.5 GR MWD140 API 14.63 138.41 58.5284 1694 4433 5279.5 ROP MWD140 FT/H 0.75 2370.65 421.214 1694 4489.5 5336 First Reading For En tire File... .......4433 Last Reading For Ent ire File.... .......5336 File Trailer Service name ..... ........STSLIB.009 Service Sub Level Name... Version Number... ........1.0. 0 Date of Generation.......07/01/10 Maximum Physical Record..65535 File Type ........ ........LO Next File Name... ........STSLIB.010 Physical EOF Tape Trailer Service name .............LISTPE Date .................... .07/O1/10 Origin .................. .STS Tape Name ............... .UNKNOWN Continuation Number..... .01 Next Tape Name.......... .UNKNOWN Comments ................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............ .LISTPE Date .................... .07/O1/10 Origin .................. .STS Reel Name ............... .UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments ................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
