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Home My WebLink About204-210MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, April 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-210 PRUDHOE BAY UN ORIN V-210 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/22/2025 V-210 50-029-23231-00-00 204-210-0 G SPT 4314 2042100 1500 1125 1130 1125 1125 171 177 180 180 4YRTST P Brian Bixby 3/16/2025 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-210 Inspection Date: Tubing OA Packer Depth 58 1844 1787 1772IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB250317153821 BBL Pumped:3 BBL Returned:1.6 Tuesday, April 22, 2025 Page 1 of 1          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y Samantha Carlisle at 9:27 am, Dec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tate of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg p� P.1. Supervisor Kt 6'�� Kt DATE: Friday, March 19, 2021 SUBJECT: Mechanical Integrity Tests Permit Number: 204-210-0 Hilcorp Nooh Slope, LLC IDSA Num: miU121031615I I l4 V-210 FROM: Jeff Jones PRUDHOE BAY UN ORIN V-210 Petroleum Inspector Sre: Inspector Reviewed By: P.L Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-210 API Well Number 50-029-23231-00-00 Inspector Name: Jeff Jones Permit Number: 204-210-0 Inspection Date: 3/14/2021 IDSA Num: miU121031615I I l4 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-210 Type Inj c -TVD 4314 - Tubing 1529 1536 - 1523• 1526 - PTD 2042100 Type Test SPT' Test psi 1500 IA 78 2307 2251 2238 BBL Pumped: 3.1 -BBL Returned: 2.2 OA 160 - ns vs - ns , Interval 4YRTST P/F P ✓ Notes: I well inspected, no exceptions noted. Friday, March 19, 2021 Page I of 1 i 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday,April 14,2017 P.I.Supervisor 0 SUBJECT: Mechanical Integrity Tests \�. BP EXPLORATION(ALASKA)INC. �"`— \`1' V-210 A` FROM: Jeff Jones /� n PRUDHOE BAY UN ORIN V-210 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Nala NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-210 API Well Number 50-029-23231-00-00 Inspector Name: Jeff Jones Permit Number: 204-210-0 Inspection Date: 3/7/2017 Insp Num: mitJJ170307161603 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-210 Type Inj W 1TVD 4314 Tubing 1515 1511 1514 1520 PTD 2042100 Type Test SPT Test psi 1500 ✓ IA 604 2348 2312 2310 .-- BBL Pumped: I BBL Returned: 1.2 OA 261 274 277 278 Interval 4YRTST P/F P Notes: 1 well inspected,no exceptions noted. SCANNED AUS 1 5 201( Friday,April 14,2017 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,March 13,2017 TO: PI. gg Supervisor `Gz'7 �I,i 3I 1 7 SUBJECT:Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. V-210 FROM: Jeff Jones PRUDHOE BAY UN ORIN V-210 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J��.'---- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-210 API Well Number 50-029-23231-00-00 Inspector Name: Jeff Jones Permit Number: 204-210-0 Inspection Date: 3/6/2017 Insp Num: mitJJ170307161603 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well V-210 Type Inj W' TVD 4314 Tubing 1515 1511 - 1514 - 1520 PTD 2042100 Type Test SPT Test psi 1500 - IA 604 2348 ' 2312 - 2310 - BBL Pumped: I ' BBL Returned: 1.2 OA 261 274 - 277 - 278 Interval l 4YRTST " P/F P _ Notes: 1 well inspected,no exceptions noted. SCANNED AUG 2 4 2017. Monday,March 13,2017 Page 1 of 1 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~O ~ - ~lQ Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed III 111m III/II 1111 R~CAN ¢ Color Items: o Greyscale Items: DIGITAL DATA vð'oiskettes, No. , o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: o Other: OVERSIZED (Non-Scannable) o Logs of various kinds: NOTES: Date / ~OC, o Other:: BY: ..~ /5/ MP BY: Date: 11111111111111 11111 /5/ tl1P + ~ = TOTAL PAGES S l./- (Count does not include cover sheet) /5/ Project Proofing BY: ~ Date: 1J-/ /à / D (p , I -L- X 30 = 3 f) Scanning Preparation Production Scanning 111111/11/11/111111 Stage 1 Page Count from Scanned File: .!; 6 (Count does include cover shec\) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date: /à J 1;;"/010 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO /5/ mp NO BY: Maria Date: /5/ 1/111111111I1111111 Scanning is complete at this point unless rescanning is required. ReScanned 11111111I/111111111 BY: Maria Date: /5/ Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc ~~h[tunt~~rger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # LOO Descrintinn s - ~~b ~. , NO. 5447 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 J ~~r • ~~• ~,,,ncai ua~a venter LR2-1 Alaska Data 8 Consultin Services 900 E. Benson Blvd. c~.' g +ti3Y„g: f~ : ,iA~~~ ~_ ~ 2525 Gambell Street, Suite 400 4 ~1 ~ ~ t ! 1 K Anchorage, AK 99503-2838 ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~y,. y"~r- { ., ~/ F(~~;(5!~ ~q _ ~ ~ ~:9~W%Y {Yl~~G~~ ~\! !~~ -1~ ~ 'V ~ Y V YJ August 14, 2009 • bp ~~~~' ~~ ~ OCT 0 5 20Q9 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, ~ Oil ~ Gas Cons. Gammi~~inn Anchor~p~ ~,bt~~~~f~ ~v ~ j-~ ~,10 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 Vo4. ot 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 t7 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 50029230830100 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-109 2022020 50029231200000 NA 12 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233000000 NA 1.5 NA 15.3 5110I2009 V-t13 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-122 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 V-201 2012220 5002923054000o SC leak NA 4 NA 90.6 8/7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11l2009 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-21~ 2042100 50029232310000 MA 2 (VA 18.7 7l11/2009 V-211 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 v-212 2051500 50029232790000 NA 1.2 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 50029233510000 NA 2.8 NA 30.6 6J30l200S 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 50029233830~0~ NA 1.75 NA ~ 3!9l2008 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 MEMORANDUM To: Jim Regg ~ P.I. Supervisor ~C~jq ~Z7,~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, Mazch 24, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC V-210 PRUDHOE BAY iJN GRIN V-210 Src: Inspector t`rnnl_r•nt~rRmF.NTT A T . Reviewed By: rj~_ P.I. Suprv~_ Comm Well Name: PRLIDHOE BAY LJN ORIN ~'-210 API Well Number 50-029-23231-00-00 • Inspector Name: Bob Noble Insp Num: mitRCN090321145318 204-210-0 ,- permit Number: Inspection Date: 3/17/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well V-210 Type Inj. W TVD 4314 ~ ~ 540 4000 ~ 3960 3960 ~- p•.I.• 2oazloo TypeTest sPT Test psi aooo ~ OA lso 210 2to 210 Interval 4YRTST P/F P `~ Tubing 1120 1140 1140 1140 Notes' IA was taken to 4000 psi at BPX request ~'1 ~~ '~} R1~2 SS ~v-e, ~ ~Zl c~~ Tuesday, March 24, 2009 Page 1 of 1 03/18/09 ~~~~~~~~ NO.5133 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~; > i `1'i "'' Attn: Christine Mahnken ATTN: Beth ~ ~.:.~ L~ ~ ~~.s~ ::; F',~ ~" r. J l~ _r 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Wnll -i,.r. ~ ~/~~ )t---... ~~` _~ •. ~ q fir,,. y~ ~ ~~,. ,.~"" J-27A AY3J-00010 -~ -~~~.. ..-.. CBL - j Yo.v 02/21/09 YL vVIV1 1 VV 1 S-107 AWJB-26 MEM L L V ~ '.}• 02/25!09 1 1 09-34A V-210 AZ4D-00005 AWJB-00025 USIT (REVISED) - INJECTION PROFILE 02/07/09 02/23/09 1 1 1 1 MPB-22A AXBD-00005 MEM SCMT & TEMP PROFILE . _ (p '' 12/23/08 1 1 V-219 12103700 USIT (REVISION #2) - ~ ( 11/21/08 1 1 11-18 BOCV-00006 PRODUCTION LOG / G/ 03/02!09 1 1 B-25 AVY5-00023 USIT - / t / ~ 03/06/09 1 1 N-18A AYKP-00013 PRODUCTION LOG `~- j~}5 j- 03/11/09 1 1 F-18 AVY5-00022 USIT / ,- O"%^ _ ''3- 03/04/09 1 1 3-19/R-28 AZ4D-00009 LDL G/ _ ~ - 03!06/09 1 1 V-117 BOOR-00003 MEM PRODUCTION PROFILE ~p - ( ~ 03/12/09 1 1 V-2i1 AY3J-00014 (PROF/RST WFL -;~ 03/16/09 1 1 V-214 AY3J-00013 (PROF/RST WFL - L 03/15/09 1 1 K-06B AWJI-00017 MCNL ~ 01/28/09 1 1 L5-15 12113027 RST ~ /O •'~ j • • 12/09/08 1 1 07-18 12071915 RST ~j 12!01/08 1 1 15-15C AWJI-00015 MCNL - ~ j 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 / - c71 U `~- 12/03/08 1 1 - q ~- ~~ owc.~ wnvu~.~n era..-..~ w~,..~ .... ........ .... ...- ~-_..--...._ .-.- BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ....Y .,L, v....u.~a v..c vvr . crwn ~ v. Alaska Data & Consulting Services 2525 Gambell Sir~gtyite l00 Anchorage, AK ;99503=238 I ATTN: Beth Received by: ~,~ pt ~ ~ `' ~ l r'at I'Td'6'd~; fix'.. •., ~,: , i ~ c ~ -?~ ! A- - ~ ~ Co ~~ r~ct et, ec~l 3 dal o`j` u 08/25/08 ~.,`~ ~J 3~ ..~ ~ a ~AS~a ~t~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Jnh # N0.4826 Company: State of Alaska ~~~~~~ ~ r° ~ ~ ~ '~~~~ Alaska Oil & Gas Cons Comm L Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 I nn nesrrinfinn oafs RI Cnlnr Cn A-02 12086677 RST ~ - [ 07/23/08 1 1 A-24 12034903 RST - 06/18/08 1 1 A-13 12086676 RST d ~f 07/23/08 1 1 G-02A 11968945 RST s ~ 06/08/08 1 1 B-19A 12017500 RST / ~~ 06/14/08 1 1 15-18A 12005216 MCNL - ~ (~ - 06/24/08 1 1 C-02 11982437 RST / Q 06/19/08 1 1 X-14A 11978452 CH EDIT PDC-GR (MEMORY DDL) - G ~ 04/21/08 1 1 B-37 12034907 CH EDIT PDl3-GR 06/10/08 1 V-207 11999031 MDT 07/23/08 1 1 V-207 11999031 MDT OUICKLOOK "~ 07/23/08 1 1 V-210 ~ 12096908 MEM INJ PROFILE 08/08/08 1 1 L-116 12071885 SBHP SURVEY /Ip 08/16/08 1 1 C-37A 12005221 MEMORY CBL (REVISED) b 07/28/08 1 1 B-18 11978471 USIT _~ /(Q ~ ~ 08/04/08 1 1 05-31A 12057635 LDL '~ 6 ^ 07/21/08 1 1 13-29L1 11962614 LDL ~ -d ~ 07/30/08 1 1 13-29L1 11966271 USIT J(p '.} 08/05/08 1 1 H-11 12017507 USIT 08/04/08 1 1 w t f LCN.IC WVRrv~lWLCUIaC fi Cl:C1Y1 13T ,Ila1V11Vta AIVU FICI Ufi1V11Vti VIVO I:VYT CAl:tl 1U: BP Exploration (Alaska) Ina -- t Petrotechnical Data Center LR2-1 , ~ ' ~ ~ va 900 E. Benson Blvd. - `° Anchorage, Alaska 99508 Y~ Date Delivered: t"~~~~~$ ~~' ~ ~~~"hrj ~, ~~.;; ,,;.~ _.:.,~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503-283 ATTN: Beth Received by: • • n;L~ ,, MICROFILMED 03/01 /2008 DO NOT PLACE • w~~_<= ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Mac~er.doc 12/28/07 ~chlumberger NO. 4542 Alaska Data 8~ Consulting Services {~(~~4} Com an State of Alaska 2525 Gambell Street, Suite 400 -~ ~ ~ ~viJLj p y~ ~~~~ '~E~ Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~ Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Lisburne, Orion Wnll _Inh if ~ ,... n..~.. ..K.... n..a., of .~_~__ Z-15 11968824 PROD PROFILE 12117/07 1 L1-02 11982424 PROD PROFILE 12112/07 1 GNt-04 N/A DIGITAL SHEAR SONIC TOOL (~~- 11108/07 1 N-27 11962771 SCMT ~ - ( 11/28/07 1 A-12 11975740 USIT (~ - (~ 12/03/07 1 03-36A 40015115 OH MWD/LWD EDIT ~ ~-~ (~ (~ 04/30/07 2 1 V-210 11963075 MEMORY INJECTION PROFILE 12/18/07 1 r LGMJC ra.n~w YYLGVVG RCli 011'1 6T JIb1V1NV AIVU Kt1UK1V11Vti VIVt IiVYY tAliti IU: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: u L~~l i4 c3 -~?~'i } l~f.. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • • 11/14/06 11/17/06 Sclllum~erger NO, 4040 Schlumberger·DCS 2525 Gambell St, Su~e 400 Anchorage, AK 99503·2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Well Job # Log Description Date BL Color CD L·201L1 PB1 40010303 OH EDIT OF MWDILWD 04/09/04 2 1 L·201L3 PB1 40010303 OH EDIT OF MWD/LWD 04/25/04 2 1 V·210 40011161 OH EDIT OF MWD/LWD 11/05104 2 1 c..----' . 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 Q !,~ Schlumberger·DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503.283ïL_ ATTN Beth tv _ ~ Received by L~- ~ ~,i, [1\{ (,~ n ')1-1 (Jf" tJ'~~ .'~ t;" (I) {,,/tJ Date Delivered: . li -L c..- éJCf-l- 8/0 -ti-JLIf} fc (¿ ~ ~ PBU Orion V-2l0 . . Andy, No open hole logging data was submitted for PBU Orion V-21 0 API 50-029-23231-00. Please send over bluelines, reproduceables, and digital logging data for this well. TNX Howard 1 of 1 11/28/20063:35 PM J I D~·c- DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Permit to Drill 2042100 Well NamelNo. PRUDHOE BAY UN ORIN V-210 Operator BP EXPLORATION (ALASKA) INC .> C{ J ') / 01 J.. c \ V' API Nlso.029.23231.00-00 ~-,-_._~~- ~ ._~----_:=::::-'.- MD 8280 ~ TVD 4794~ Completion Date 11/11/2004 Completion Status WAGIN Current Status WAGIN -'---'--~'---~-~-'.~'- REQUIRED INFORMATION --~- Directional surv~ ~ -- .~ ---~-'--- Mud Log No Samples No _.-.-,.-~-.-~ DATA INFORMATION Types Electric or Other Logs Run: MWD / GR, MWD I GR 1 RES 1 DEN 1 NEU 1 PWD, USIT Well Log Information: (data taken from Logs Portion of Master Well Data Maint Logl Data Type ~t f;E C Pds 11789 Lo 11789 --~~ Electr Digital Dataset MedlFrmt Number D Asc Name Directional Survey Directional Survey GB,","","R"ay C, .._c....; r:~",t GamFRo Ray t.-..Jt- f5~.../ Log Log Run Interval OHI Scale Media No Start Stop CH Received -------.---- ._~ 0 8280 11/24/2004 0 8280 11/24/2004 4900 8168 11/23/2004 Col 4900 8168 11/23/2004 Comments .- I [ USIT/GRlCCL I USIT/GR/CCUDSN 11789 J' ----_..~-_._-~._------ --~----~. Well CoreslSamples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? yG> Daily History Received? ðN &N . Chips Received? ~ Formation Tops Analysis ~ Received? Comments: ~~mPllan'e Review,. B~' .~... .~ ~ Date: J:.1{ ~~ ;{ .~(Q MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg --V-'l 31u (.-- P.I. Supervisor J -Y:::fl D.J. DATE: Wednesday, March 23, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA)!NC V-21O PRT,JDHOE BAY UN ORIN V-21O FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: p.r. Suprv ~Jßß.- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN ORIN V-210 API Well Number: 50-029-23231-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS050317141433 Permit Number: 204-210-0 Inspection Date: 3/17/2005 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well V-210 Type Inj. S I TVD I 4300 ¡ IA I 100 I 1810 I 1730 1730 i i ¡ P.T. 2042100 TypeTest SPT I Test psi I 1075 i OA I 180 I 340 f 340 340 I i I I Interval !NIT AL P/F P Tubing I 620 I 620 i 620 I 620 ! I Notes: Pre test pressures were observed and found stable. Well demonstrated good mechanical integrity. Wednesday, March 23, 2005 Page I of I RECEIVED _ STATE OF ALASKA A ALAS~ AND GAS CONSERVATION COM~ION MAR 1 0 2005 WELL COMPLETION OR RECOMPLETION REPORT AND L~~ska Oil & Gas Cons..Commission Revised: 0311 Wftfih_n Injection 1a. Well Status: 0 Oil o Gas o Plugged o Abandoned o Suspended ~WAG 1b. Well Class: 20AAC 25.105 20AAC 25,110 o Development o Exploratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic ~ Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 11/11/2004 204·210 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 10/31/2004 50- 029-23231-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 11/5/2004 PBU V-210i 4823' NSL, 1833' WEL, SEC. 11, T11N, R11E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 5173' NSL, 2689' WEL, SEC. 02, T11 N, R11 E, UM 81.1 Prudhoe Bay Field 1 Orion Schrader Bluff Total Depth: 9. Plug Back Depth (MD+ TVD) 405' NSL, 2828' WEL, SEC. 35, T12N, R11E, UM 8179 + 4731 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 590468 y- 5970070 Zone- ASP4 8280 + 4794 Ft ADL 028238 ~._- --- ~~-~ 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 589539 y- 5975688 Zone- ASP4 Total Depth: x- 589393 y- 5976198 Zone- ASP4 (Nipple) 3670 MD ------- - -- - -- --- -- ~- ---- . ._ ____u____ -- 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey ~Yes DNo N/A MSL 1900' (Approx.) 21. Logs Run: MWD 1 GR, MWD / GR I RES I DEN I NEU I PWD, US IT 22. CASING, liNER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING EPTH TVD HOLE ...... >A""OUN'r SIZE WT. PERFT. GRADE lOP I::SOTTOM lOP II::SOTTOM SIZE PULLED 20" x 34" 215.5# A53 Surface 108' Surface 108' 42" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 29' 3888' 29' 2620' 12-1/4" 603sx Arcticset Lite, 379 sx 'G' 7" 26# L-80 26' 8264' 26' 4784' 8-3/4" 370 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter, 5 spf 4-1/2",12.6#, L-80 7577' 7517' MD TVD MD TVD 3-1/2",9.2#, L-80 7577' - 7931' 7664' & 7799' & 7873' 7598' - 7648' 4366' - 4398' 25. ACID, FRActURE, CEMENTSaueEZE,E!C. 7692' - 7736' 4425' - 4453' .. 7754' - 7780' 4465' - 4481' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7842' - 7862' 4520' - 4533' 7920' - 7995' 4569' - 4616' 2200' Freeze Protect with 102 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): February 19, 2005 Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + O'l-BBl GAs-McF W A TER-BSl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 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". RBDMS 8FL MAR .I 4 2005 None (,V Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28..- GEOLOGIC MARKERS 29. RMATION 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 4359' 2833' None Ugnu MA 6896' 3988' Ugnu MB1 6983' 4029' Ugnu MB2 7113' 4090' Ugnu MC 7239' 4150' Schrader Bluff NA 7356' 4214' Schrader Bluff NB 7396' 4238' Schrader Bluff NC 7459' 4277' Schrader Bluff OA 7599' 4367' Schrader Bluff OBa 7692' 4425' Schrader Bluff OBb 7755' 4465' Schrader Bluff OBc 7842' 4520' Schrader Bluff OBd 7921' 4570' Schrader Bluff OBe 8016' 4629' Schrader Bluff OSf 8088' 4675' Base Schrader Bluff 8163' 4721' 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. Signed Terrie Hubble ~ Title Technical Assistant PSU V-210i Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Rob Tirpack, 564-4166 204-210 Permit No. I A roval No. 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 1212003 Submit Original Only ., . STATE OF ALASKA a ALASKA' AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ITE:C ']::/1,_ 1a. Well Status: D Oil DGas D Plugged D Abandoned D Suspended iii WAG 1b. Well~" . V'/r5.~ 20AAC 25,105 20AAC 25.110 4/@ievelopelt ß$ra ry DGINJ DWINJ D WDSPL No. of Completions One Other ~~.~hiC ce 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. perm~'OTiÚ~~er BP Exploration (Alaska) Inc, 11/11/2004 204-2 ChafRh.· 011rní..: 3. Address: 6. Date Spudded 13. API Number .... '''''' P.O. Box 196612, Anchorage, Alaska 99519-6612 10/31/2004 50- 029-23231-00-00 4a, Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 11/5/2004 PBU V-21Oi 4823' NSL, 1833' WEL, SEC. 11, T11 N, R11 E, UM 8. KB Elevation (ft): 15. Field 1 Pool(s): Top of Productive Horizon: 5173' NSL, 2689' WEL, SEC. 02, T11N, R11E, UM 81.1 Prudhoe Bay Field 1 Orion Total Depth: 9. Plug Back Depth (MD+ TVD) Schrader Bluff 405' NSL, 2828' WEL, SEC. 35, T12N, R11 E, UM 8179 + 4731 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 590468 y- 5970070 Zone- ASP4 8280 + 4794 Ft ADL 028238 TP/: x- 589539 y- 5975688 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit; Total Depth: x- 589393 y- 5976198 Zone- ASP4 (Nipple) 3670 MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey iii Yes DNa N/A MSL 1900' (Approx.) 21. Logs Run: MWD I GR, MWD I GR I RES I DEN / NEU I PWD, US IT 22. CASING, liNER AND CEMENTING RECORD CASING Se:'TTING I:PTH MD ··SE'TTING[ I:PTH 1VD HO(..E .............. SIZE WT. PER Fr. GRADE Top tsOTTOM TOP SIZE .~. ..-". PULLED BOTTOM ....... iii'·· 20" x 34" 215,5# A53 Surface 108' Surface 108' 42" 260 sx Arctic Set lApprox.) 9-5/8" 40# L-80 29' 3888' 29' 2620' 12-1/4" 603 sx Arcticset Lite, 379 sX 'G' 7" 26# L-80 26' 8264' 26' 4784' 8-3/4" 370 sx Class 'G' 23. Perforations open to Production (MD + TVD of TOE and 24. TuBIJ\lGRECORD ..·.·i Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter, 5 spf 4-1/2", 12.6#, L-80 7577' 7517' MD TVD MD TVD 3-1/2",9.2#, L-80 7577' - 7931' 7664' & 7799' & 7873' 7598' - 7648' 4366' - 4398' 25. AciD, . vEMEI\I ,.",,,,4,,, 7692' - 7736' 4425' - 4453' 7754' - 7780' 4465' - 4481' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7842' - 7862' 4520' - 4533' 7920' - 7995' 4569' - 4616' 2200' Freeze Protect with 102 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection Yet N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF W A TER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... OIL-BBL GAs-McF W A TER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 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". ;-...,...... . --.. ". RBDMS BFl DEC .2 (1 70D4 ¡ ¡ None 11f1fJpJ \~ ft, ¡~"~,¡i.::n";r! ,~, " M¡~U : '.,..... --~¡ \;; \-:-."..-". "'" Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28.. GEOLOGIC MARKERS 29. ORMATION TESTS Include and briefly summarize test results, List intervals tested, NAME MD TVD ànd attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 4359' 2833' None Ugnu MA 6896' 3988' Ugnu MB1 6983' 4029' Ugnu MB2 7113' 4090' Ugnu MC 7239' 4150' Schrader Bluff NA 7356' 4214' Schrader Bluff NB 7396' 4238' Schrader Bluff NC 7459' 4277' Schrader Bluff OA 7599' 4367' Schrader Bluff OBa 7692' 4425' Schrader Bluff OBb 7755' 4465' Schrader Bluff OBc 7842' 4520' Schrader Bluff OBd 7921' 4570' Schrader Bluff OBe 8016' 4629' Schrader Bluff OBf 8088' 4675' Base Schrader Bluff 8163' 4721' 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. Signed Terrie Hubble Title Technical Assistant Date ~/ID ID PBU V-210i Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Rob Tirpack, 564-4166 204-210 Permit No. I A roval No. 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 5/2004 9:55:05 AM 1 Printed: 525 (psi 9.00 (ppg) (ft 2,526.0 3,901.0 (ft) LOT 11/4/2004 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-210 V-210 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 10/30/2004 11/11/2004 Spud Date: 10/31/2004 End: 10/30/2004 17:00 - 23:00 i 6.00 I MOB P PRE PJSM. Pull pits away from rig. Move rig from V-1 06a to V-21 Oi. Tie onto surface stack and riser with bridge crane. Spot rig over V-210i. Spot pits and cuttings tank. I Accept rig at 23:00 hrs, October 30,2004 I 23:00 - 00:00 1,00 I RIGU 'p PRE RU diverter. 10/31/2004 00:00 - 06:00 6.00 I RIGU Ip PRE Take on fresh water. Prepare cellar. Install diverter. Install riser. I Mix Spud Mud. Bring BHA tools to floor. I 06:00 - 08:30 2.50 I RIGU P PRE PU 27 Jts DP, 24 Jts HWDP out of pipe shed stand back in I derrick. 08:30 - 09:30 1.00' BOPSU P PRE Function test diverter. Witness of test by Lou Girmaldi , (AOGCC). 09:30 - 12:00 I 2.50 DRILL P SURF PU BHA #1, MU Bit, Motor, MWD, and Oreint MWD. 12:00 - 12:30 0.50 DRILL P SURF Held pre-spud safety meeting with all crew and service personnel. 12:30 - 13:00 0.50 DRILL P SURF RU Gyro Data on e-line. 13:00 - 15:30 2.50 DRILL P SURF Fill all surface lines and check for leaks. Spud well at 13:00 hours. Drill from 108' to 452' 550 GPM - 750 - 800 PSI, WOB 10 - 20k, Up WI 56k - On WI 55k. 15:30 - 16:00 0.50 DRILL P SURF Circulate Btms - Ups 672 GPM - 725 PSI. 16:00 - 17:00 1.001 DRILL P SURF POOH from 452' to PU jars. 17:00 - 22:30 5.50 DRILL P SURF Gyro survey at 452' and continue drilling directionally from 452' t01191' 690 GPM - 2040 PSI, WOB 30 - 35K, Up WI 85k - On WI 70 - Rt WI 75k. ART 1.93 lAST 3.77 22:30 - 00:00 1.50 DRILL P SURF Circulate Btms - Ups 660 GPM - 1900 PSI. RIH with final Gyro survey at 1191', 11/1/2004 00:00 - 00:30 0.50 DRILL P SURF RD and release Gyro-Data after final survey. 00:30 - 03:30 3,00 DRILL P SURF Continue drilling from 1191' to 1564" (1459' TVD) GPM 665 1950 PSI. WOB 30 -35K Up WI 75k, On WI 75k, RT WI 75k, 50 RPM, Torque 3 - 5k. ART 1.71/ ART1.1 03:30 - 04:00 0.50 DRILL P SURF CBU at 665 GPM 2045 PSI, Rotate and reciprocate pipe during circulation. 04:00 - 05:00 1.00 DRILL P SURF POOH from 1564'. 05:00 - 06:00 1.00 DRILL P SURF Stand back BHA. LD UBHO and bit. 06:00 - 07:00 1.00 DRILL P SURF Install new MXC1 121/4" Bit. 07:00 - 07:30 0.50 DRILL P SURF Service Top Drive. 07:30 - 08:30 1.00 DRILL P SURF RIH to 1564', Hole had 18' fill. No tight spots. 08:30 - 22:30 14.00 DRILL P SURF Drill rotate & slide F/1564' - T/ 3902' (TVD 2624") TO. GPM 651 - 3250 PSI. WOB 30 -35k. Up WI 104k, On WI 58k, Rt WI 79k. RPM 80, DH RPM 224. Torque 3 - 5k. Survey every 90', Back ream every stand. AST:4.64 - ART:5.80 22:30 - 00:00 1.50 DRILL P SURF Circulate Btms - Ups for short trip, GPM 651 - 3250 PSI, Rotate and reciprocate pipe 20' during circulation, 11/2/2004 00:00 - 00:30 0.50 DRILL P SURF Circulate Btms - Ups for short trip, GPM 651 - 3250 PSI, Rotate and reciprocate pipe 20' during circulation. 00:30 - 03:00 2.50 DRILL P SURF Shot trip, POH F/3902" - T/ 1090' to HWDP, No problems or tight spots. Monitor well. 03:00 - 05:00 2.00 DRILL P SURF TIH F/ 1090' - T/3902', No problems or tight spots. Printed: 11/15/2004 9:55:11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-210 V-210 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 10/30/2004 11/11/2004 Spud Date: 10/31/2004 End: 11/212004 05:00 - 06:00 1.00 DRILL P SURF Circulate Btms - Ups to condition hole for casing run, GPM 651 - 3250 PSI. Rotate and reciprocate pipe during circulation, 06:00 . 09:00 3.00 DRILL P SURF POH to run 95/8" casing. Max WI 125k. 09:00 - 11 :30 2.50 DRILL P SURF LD BHA #2, LD tools off rig floor, Clean rig floor. 11:30 - 13:00 1.50 I CASE P SURF RU Casing equipment to 9 5/8" L-80 40#, MU franks tool, Make I dummy run with casing hanger & mark landing joint. 13:00 - 13:30 0.50 CASE P SURF MU shoe track & check floats. 13:30 - 20:00 . 6.50 CASE P SURF RIH with 95/8" 40# L-80 Casing, Filling every joint, Dope I Casing with 2000 NM. Make up torque 8.6k 20:00 - 20:30 0.50 CASE P SURF RD fill - up tool. MU CMT head, 20:30 - 22:30 2.00 CASE P SURF Circ & Condo mud, Stage pumps up to 336 GPM @ 493 PSI. Flow 35%. Reciprocate casing 15'. Pu WI 184k - Dn WI 75k. Drop Vis from 300 to 75. Total mud loss for tour 275 Bbls. Held PJSM with crews. Dowell pump 5 Bbls water, Test cement lines to 3500 PSI. 22:30 - 00:00 1.50 CEMT P SURF Drop bottom plug, Pump 75 Bbls mud push 10.1 ppg, Pump Lead Slurry 10.7 ppg 478 Bbls (603 sks) 20.7 gps water, Yield 4.45 cf/ft. 7 BPM @ 720 PSI. Pump Tail Slurry 15.8 ppg, 80 (383 sks) 5.085 gps water, Yield 1.17, 5.8 BPM @ 1340 PSi. (Had to stop reciprocating pipe after pumping 390 Bbls, Due to 1.001 CEMT taking weight) 11/3/2004 00:00 - 01 :00 I P SURF Drop top plug with rig pumps and displace cement with 283 Bbls (4049 stks) 9.6 ppg mud at 325 GPM @ 560 PSI (7.2 BPM). Reduce rate to 2 BPM last 10 Bbls. Bump plug Pressure up to 1500 PSI. Had 35% flow returns during cement job. Got back 285 Bbls of cement to surface. (Cement in place @ 01 :00) Check floats. Floats was not holding. (320 PSI on lines) 02:00 - 03:00 1.00 CEMT P SURF Close valve on cement head to hold cement in place. LD casing equipment, Clean rig floor. Start rigging down lines to nipple down surface hydril. 03:00 - 09:00 6.00 CEMT P SURF Open valve on cement head and check floats @ 03:30, Floats holding. Nipple down surface Hydril Diverter, Install FMC 11" through bore Gen 5 wellhead system. Test seals to 1000 PSI. 09:00 - 12:00 3.00 CEMT P SURF NU 135/8" 5M BOP's and all related equipment. (Note: Cement 2" down below 4" outlets) 12:00 - 17:00 5.00 CEMT P SURF RU and test BOP's to BP and AOGCC regulations (250 psi Lo - 4000 psi Hi). Witness of test waived by AOGCC Rep. John Spaulding. 17:00· 17:30 0.50 CEMT P SURF RD test equipment, Blow down all lines. 17:30 - 18:00 0.50 CEMT P SURF Install wear bushing 9 7/8" ID 18:00 - 18:30 0.50 CEMT P SURF Service Top Drive and Crown. 18:30 - 21 :00 2.50 DRILL P PROD1 PU 60 Joints of drill pipe single in hole. 21 :00 - 22:00 1,00 DRILL P PROD1 Cut and Slip 65' of drilling line. 22:00 - 23:00 1.00 DRILL P PROD1 POH, and stand back in derrick 20 stands. 23:00 - 00:00 1.00 DRILL P PROD1 Clean & Clear rig to start picking up BHA #3. 11/4/2004 00:00 - 02:00 2.00 DRILL P PROD1 PU BHA #3, Bit, Motor, NMSTB, LWD, MWD and orient same. Load sources, MU collar and jar stand. Shallow test MWD, OK. 02:00 - 06:00 4.00 DRILL P PROD1 RIH by singling in to 3600' Tested casing to 1000 PSI at 1100' after passing through TAM collar. Test Casing to 4000 PSI for 30 minutes on chart @ 3600'. 06:00 - 06:30 0.50 DRILL P PROD1 RIH to 3600', Test 9 5/8" L-80 #40 BTC to 4000 PSI on chart for 30 minutes. Printed: 11/15/2004 9:55;11 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-210 V-210 DRlll+COMPlETE NABORS ALASKA DRilLING I NABORS 9ES Start: Rig Release: Rig Number: 10/30/2004 11/11/2004 Spud Date: 10/31/2004 End: 11/412004 06:30 - 08:30 2.00 DRILL Ip IPROD1 Drill soft cement from 3651' to 3802', Drill float collar and hard cement, Tag and drill float shoe at 3887'. Drill rat hole to 3901' and 20' new hole to 3921'. Displace mud system to 9.0 ppg LSND mud. 08:30 - 09:00 0.50 DRILL 'P PROD1 Perform LOT to 12.8 EMW. 09:00 - 09:30 0.50 DRILL \p I PROD1 Circulate to establish baseline parameters. GPM 583 . 1606 psi. Calculated ECD 9.66 ppg. 09:30 - 00:00 14.50 DRILL P PROD1 Drill from 3921' to 5894' Backream and survey each stand. Up wt 11 Ok - On wt 62k - Rt wt 80k. GPM 580 - 2953 psi, RPM 101 - Dh RPM 400, Torque off 11 ,8k - on 12.5k, Cal ECD 9.93 - Act ECD 10.38 AST:1.72 ART:4.80 11/5/2004 00:00 - 18:00 18.00 DRILL P PROD1 Continue drilling 8.75" production section from 5894' to 8280' I TO (4793' TVD). GPM 575 - 3057 psi. Up wt 120k - On wt 67k- Rt wt 85k. RPM 101 - Dh RPM 400. Torque 4.5 - 7k. Cal ECD= 9.97, Actual ECD= 10.35 AST: 4.75 ART: 12.98 18:00 - 20:00 2.00 DRILL P PROD1 CBU x3 MW = 9.2, GPM 580 - 3816 PSI. 100 RPM. Pump sweep. Monitor well for flow. Cal ECD= 10.11 Actual ECD= 10.42 20:00 - 21 :00 1,00 DRILL P PROD1 POOH from 8280' to 7738', Tight spot 25k over. 21 :00 - 22:00 1.00 DRILL P PROD1 MU Top Drive, Backream from 7738' to 7483'. GPM 523 - 3150 PSI, 100 RPM. Reaming EDC=10.63 22:00 - 00:00 2.00 DRILL P PROD1 CBU to condition hole, Continue POH from 7483' to 6436'. Drop ECD from 10.63 to 10.42 ppg. 11/6/2004 00:00 - 00:30 0,50 DRILL P PROD1 Continue POH from 6436' to 4450', Overpull 10 - 20k. Pulled tight at 4450', Make two attempts to pull with no pumps. 00:30 - 04:00 3.50 DRILL P PROD1 MU top drive, Stage up pumps to 300 GPM - 1420 PSI, Flow 26%,60 RPM, Torque 6 -10k, Experienced high torque and packing off to 4300', Continue backreaming at 490 GPM - 1950 PSI, Flow 44%, 80 RPM, Torque 6k. Continue POH to shoe with bit. 04:00 - 05:00 1.00 DRILL P PROD1 CBU at shoe, GPM 510 - 1971 PSI, Flow 46%, RPM 75. 05:00 - 06:30 1.50 DRILL P PROD1 RIH, Up wt 118k - On wt 61k. Taking weight at 6145', Fill pipe, Attempt to ream torque up and packing off. 06:30 - 07:30 1.00 DRILL P PROD1 Stage up pumps, to 47% flow, Pumping 520 GPM - 2610 PSI, Torque 5k. Recovered large amount of sand & clay balls. 07:30 - 08:00 0.50 DRILL P PROD1 Ream in the hole from 6145' to 6500', Pumping 400 GPM - 1900 PSI, RPM 40, Torque 5k. 08:00 - 09:00 1.00 DRILL P PROD1 Continue to RIH with no pumps to 8195, No problems. 09:00 - 13:00 4.00 DRILL P PROD1 Stage up pumps, wash down last stand to 8280'. Pumping at 565 GPM - 3140 PSI, RPM 100, Torque 10 - 12k. Continue to Circ & Cond hole. Added Lub Tex to the system, Actual: ECD 10.14 Cal: ECD 10.00 13:00 - 15:00 2.00 DRILL P PROD1 POOH from 8280' to 4492', Well started swabing. 15:00 - 15:30 0.50 DRILL P PROD1 Backreaming from 4492' to 4400', 430 GPM - 1595 PSI, RPM 85, Torque 5 - 6k. Recovered large amount of sticky clay balls. 15:30 - 16:00 0.50 DRILL P PROD1 RIH from 4400' to 4679', No problems. Printed: 11/15/2004 9:55:11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-210 V-210 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 10/30/2004 11/11/2004 Spud Date: 10/31/2004 End: 11/6/2004 16:00 - 17:30 1,50 DRILL P PROD1 Backreaming from 4679' to 3887',527 GPM - 1695 PSI, RPM 92, Torque 5 -8k. 17:30 - 18:00 0.50 DRILL P PROD1 Circulate & Condition hole, 527 GPM - 1695 PSI, RPM 92, Torque 5 - 8k. ¡Actual: ECD 10.13 ppg Cal: ECD 10.00 ppg 18:00 - 20:00 2.00 DRILL P PROD1 POOH from 3887', LD ghost reamers #1 - #2. 20:00 - 22:00 2.00 DRILL P PROD1 LD BHA, 5" HWDP, Jars, NMDC, and Remove source and contain same. LD MWD, LWD/CRD, NMSTB, Float sub, Motor, and Bit. 22:00 - 23:00 1.00 DRILL P PROD1 LD equipment from rig floor. Clean rig floor. 23:00 - 00:00 1.00 DRILL P PROD1 Flush with water and pull wearbushing, and install test plug in wellhead. 11/7/2004 00:00 - 02:00 2.00 CASE P PROD1 Change top rams to 7", Test door seals to 3500 PSI. Pull test plug. 02:00 - 03:00 1.00 CASE P PROD1 Make dummy run with FMC casing hanger on landing joint. RU to run 7" casing. 03:00 - 05:00 2.00 CASE P PROD1 PU 7" shoe track and check floats, OK. RIH with 7", 26#, L-80, BTC-M casing. Place floating centralizers on joints 4 - 46, Spot RIA marker joints after joints 17 & 32. 05:00 - 05:30 0.50 CASE P PROD1 Break Circulation at 1700', Circulate for 20 minutes, BPM 5 - 210 PSI, 23% flow. 05:30 - 09:00 3.50 CASE P PROD1 Contiue RIH, Started pushing mud away at 3100', CBU on next 3 joints. 09:00 - 09:30 0.50 CASE P PROD1 CBU 1.5x at shoe, Stage pumps up to 7 BPM - 630 PSI, 28% flow. Pu wt 117k - Dn wt 75k. 09:30 - 20:00 10,50 CASE P PROD1 Continue running into open hole with 7", 26#, L-80, BTC-M casing, CBU on the fly from 5500' to 8264'. Obtaining PU - SO weights every 10 joints, Break circulation every 15 joints. Wash down last 8 jts. Land 7" casing hanger. Up wt 275k - Dn wt 85k, (45 total centralizer run,) 20:00 - 20:30 0.50 CEMT P PROD1 LD fill up tool, RU cement head, cement hose and wash up line. 20:30 - 22:00 1.50 CEMT P PROD1 Circulate and condition hole. Start at 2 BPM - 287 PSI, Stage up to 7 BPM - 815 PSI, 27% flow. 22:00 - 23:30 1.50 CEMT P PROD1 Pump 5 Bbls water. Test lines to 4000 PSI. Pump 20 Bbls CW100. Pump 35 Bbls Mud Push spacer weighted to 10.2 ppg at 5 BPM, Release bottom plug. Pump 77 Bbls (369 sx) Class G cement @ 15.8 ppg @ 6 BPM - 1688 PSI. Wash up cement lines. Release top plug. Switch to rig pumps and displace cement with 313 Bbls seawater. Reciprocated till 35 bbls cement out of the shoe. Bumped plug. Cement in place at 23:30 hrs. TOC estimated at 6228'. (Had good returns during cement job 21%) 23:30 - 00:00 0.50 CEMT P PROD1 Pressure up casing to 4000 PSi for 30 minutes. Good Test. 11/8/2004 00:00 - 00:30 0.50 CEMT P PROD1 Bleed off pressure, Check floats, OK. RD cement head. LD landing joint. 00:30 - 01 :30 1.00 CEMT P PROD1 RD and LD casing tools. Change out bales. 01 :30 - 02:30 1.00 WHSUR P PROD1 Install packoff. Run in lock down pins. Test packoff to 5000 PSI, with 7" x 9 5/8" annulus open. Good test. 02:30 - 04:00 1.50 BOPSU P PROD1 Install test plug. Change top rams to 3,5" x 6" variables. Test Printed: 11/15/2004 9:55:11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-210 V-210 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 10/30/2004 11/11/2004 Spud Date: 10/31/2004 End: 19:00 - 20:00 1.00 PERFUB P I to 4000 PSI. Good test. I RD test equipment, Pull test plug and install wear bushing. Slip and Cut Drill Line, Service Top Drive, and Clean rig floor. PJSM. PU 41/2"(215') HSD PJ4505 Power Jet HMX, 5 spf, I Guns with 60deg phasing with spacer as needed, and BHA. OTHCMP I RIH to 1245' 1 minute per stand, Tested MWD, Test good. OTHCMP i Continue RIH, Log down from 7954' to 8179' (Float collar) to I, correlate and confirm depths. Displace well with 9.0 Brine. OTHCMP Log from 8179' at 100' FPH to 8081' OTHCMP I POOH to 7996' to place guns on depth. Top perfs set at 7598'. Up wt 170k -Dn wt 80k. OTHCMP PJSM, Fire perf guns following Schlumberger pressure schedule. i Perf Intervals: i 7598' - 7648' = 50 [' 7692' - 7736' = 44 7754' - 7780' = 26 7842' - 7862' = 20 17920' - 7995' = 75 Total Perfs: 215' Good surface and sonic indication of guns firing. OTHCMP POOH to 7550', Monitor well. Losses estimated at 6 BPH OTHCMP ! CBU. Monitor well. Losses 6 BPH. OTHCMP ! POOH laying down DP. OTHCMP Con't POOH wlperf guns I LD DP, OTHCMP PJSM wlall personnel prior to LD 4.5" perf guns, clean & clear floor of vendors equipment and working tools. OTHCMP RIH 25 stands DP flderrick & LD same, OTHCMP CO upper pipe rams to 7" f/wirieline lubricator, test door seals t/3500 psi f/5 min. OTHCMP PJSM and RU wireline wIT' lubricator, 5.937" gage ring/junk basket. OTHCMP RIH wlwireline junk basket run #1 to 8176', POOH w/2 gal debris (rocks/scale), OTHCMP RIH w/junk basket run #2, POOH w/1 gal debris (rocks/scale). OTHCMP RIH w/junk basket run #3, POOH w/1.5 gal debris (rocks/scale). OTHCMP RIH w/junk basket run #4 to 7900', POOH w/1.5 cups debris (scale). OTHCMP RD junk basket/RU US IT log. OTHCMP RIH w/USIT log. 1.50 BOPSU 0.50 BOPSU 1.00 DRILL P 4.00 PERFUB P 09:30 - 10:00 10:00 - 14:30 0.50 PERFUB P 4,50 PERFUB P 14:30 . 17:00 17:00 - 19:00 2,50 PERFUB P 2.00 PERFUB P 20:00 - 20:30 0.50 PERFUB P 20:30 - 22:00 1.50 PERFUB P 22:00 - 00:00 2.00 PERFUB P 11/9/2004 00:00 - 02:00 2.00 PERFUB P 02:00 - 06:30 4.50 PERFUB P 06:30 - 10:00 3.50 PERFUB P 10:00 - 11 :00 1.00 BOPSU P 11 :00 - 12:30 1.50 DHEQP P 12:30 - 14:30 2.00 DHEQP P I 114:30 - 16:00 1.50 DHEQP P 16:00 - 18:00 2.00 DHEQP P 18:00 - 20:00 2,00 DHEQP P 20:00 - 20:30 0.50 ZONISO P 20:30 - 00:00 3.50 ZONISO P 11/10/2004 00:00 - 01 :00 1.00 EVAL 01 :00 - 02:00 1.00 BOPSU 02:00 - 03:30 1.50 RUNCO 03:30 - 05:30 2.00 RUNCO 05:30 - 17:00 Total brine loss = 48 bbls f/day. OTHCMP Finish USIT log & rig-down wireline. OTHCMP Change out 7" rams to 3.5" x 6", test door seals to 4000 psi. RUNCMP RU 3.5" tbg equip & make dummy run. RUNCMP PJSM wlall personnel, PU 3.5" TC-II 9.2# tubing & jewlery, Baker lock 2 connections below 1 st packer, dope w/Jet-Lube, torque to 2300 ftllbs. RUNCMP RU 4.5" equip & run 4.5' TC-1I12,6# 1-80 tubing, dope w/jet-Iube, torque-turn to 3800 ftllbs, PU hanger & land w/105k up, 70k dn, RILDS. Printed: 11/15/2004 9:55: 11 AM RU SWS, log f/7800' up to 6850' to identify tubing & casing RA tags (space-out on lower casing tag and tubing tag at 96' - OK), RD SWS, RUNCMP Reverse inhibited 9,0 ppg brine below shear valve to top packer at 3 bpm - 200 psi. RUNCMP Drop ball & rod, pressure test to 4200 psi to set packers (4), hold f/30 min (bled down to 4000 psi), bleed tubing pressure down to 1500 psi & pressure annulus to 4000 psi, hold f/30 min (bled down to 3950 psi), bleed off annulus pressure to 0 psi, bleed off tubing pressure to 0 psi, re-pressure annulus to 2900 psi to shear DCK valve, circ 2 min. Blow down kill line,choke line and drain BOP's. Install TWC, attempt test (would not hold pressure), pull TWC (confirmed 0 pressure status below plug), repaired TWC, install TWC, test t/1 000 psi - OK. ND BOP's, NU adapter flange & tree, test to 5000 psi. RU DSM & pull TWC w/lubricator. RU hot oil, PSJS, pump 102 bbls 50 degree F. diesel down 7" x 4.5" annulus to freeze protect well to @ 2200' TVD at 2.5 bpm = ICP of 900 psi and FCP of 1450 psi. U-tube diesel flannulus to tubing across top of well, RD hoses. Install BPV w/DSM & test flbelow to 1000 psi. RD hot oil, remove annular valves and install VR plugs (DSM), secure tree and cellar. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-210 V-210 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES 11/10/2004 17:00 - 19:30 19:30 - 20:30 1.00 20:30 - 22:00 1.50 22:00 - 22:30 0.50 RUNCMP 22:30 - 00:00 1.50 RUNCMP 11/11/2004 00:00 - 04:00 4,00 BOPSU P OTHCMP 04:00 - 04:30 0.50 BOPSU P OTHCMP 04:30 - 06:00 1.50 WHSUR P OTHCMP 06:00 - 06:30 0.50 WHSUR P OTHCMP 06:30 - 07:00 0.50 WHSUR P OTHCMP 07:00 - 09:00 2.00 WHSUR P OTHCMP Start: Rig Release: Rig Number: 10/30/2004 11/11/2004 Spud Date: 10/31/2004 End: (release rig fN-210i at 09:00 hrs on 11/11/04) Printed: 11/15/2004 9:55:11 AM Ö V-210 Survey Report Schlumberger Report Date: 5·Nov-04 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 350,980° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 II, E 0,000 II Structure I Slot: V·Pad / Plan V-21 0 (N-G) TVD Reference Datum: Rotary Table Well: V-210 TVD Reference Elevation: 81,10 II relative to MSL Borehole: V-21 0 Sea Bed I Ground Level Elevation: 52.60 II relative to MSL UWI/API#: 500292323100 Magnetic Declination: 24.731 ° Survey Name I Date: V·210 / November 5,2004 Total Field Strength: 57593,991 nT Tort I AHD I DDII ERD ratio: 142,998° /6233,9411/6.187/1.300 Magnetic Dip: 80.798° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: October 31 , 2004 Location LatlLong: N 70,32796881, W 149.26629539 Magnetic Declination Model: BGGM 2004 . Location Grid N/E YIX: N 5970069.620 IIUS, E 590468.210 IIUS North Reference: True North Grid Convergence Angle: +0.69088622· Total Corr Mag North .) True North: +24.731 ° Grid Scale Factor: 0,99990930 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth NS EW DLS Latitude Longitude Depth ft RTE 0.00 N 70.32796881 W 149.26629539 First GYD GC SS 112,00 N 70.32796868 W 149.26629626 200.00 N 70.32796997 W 149.26629804 300,00 N 70.32797974 W 149.26629903 400.00 N 70,32800398 W 149.26630592 500.00 7.61 350,14 417,62 498.72 25.49 25.73 25.49 25,28 -3.31 0.80 5970094.85 590464.59 N 70.32803787 W 149,26632226 600.00 8.00 349.48 516.69 597.79 39.06 39.31 39,06 38,64 -5.72 0.40 5970108.19 590462.03 N 70.32807438 W 149.26634176 700.00 10.30 350.04 615.41 696.51 54.96 55.21 54,96 54.29 -8,54 2.30 5970123.80 590459.02 N 70.32811713 W 149.26636461 800,00 13,57 349.88 713.24 794.34 75.63 75.89 75.63 74.65 -12.14 3,27 5970144.11 590455.17 N 70.32817276 W 149.26639387 900.00 16,32 350.84 809.84 890.94 101,42 101,68 101.42 100.08 -16.44 2.76 5970169.48 590450.56 N 70.32824221 W 149.26642873 1000,00 19,21 351.39 905.07 986,17 131,93 132,19 131.93 130.22 -21.14 2.89 5970199,56 590445.50 N 70,32832456 W 149.2.5 Last GYD GC SS 1100.00 24.81 349.56 997.74 1078.84 169.38 169.64 169.38 167.15 -27.41 5.64 5970236.41 590438.79 N 70.32842545 W 149.2 9 First MWD IFR MS 1132.14 27.27 350.12 1026.62 1107.72 183.49 183.75 183.49 181.04 -29.90 7.69 5970250.27 590436.13 N 70,32846339 W 149.2 85 1225.47 32.64 350,96 1107.45 1188.55 230.07 230.34 230,07 226,99 -37.53 5.77 5970296.12 590427.95 N 70.32858893 W 149,26659972 1318.29 34.70 350,58 1184,70 1265.80 281.53 281.79 281.53 277,78 -45.79 2.23 5970346.80 590419.08 N 70.32872769 W 149,26666669 1412.22 37.89 349.49 1260,39 1341.49 337.11 337.39 337,12 332.53 -55.43 3.46 5970401.43 590408.78 N 70.32887726 W 149.26674486 1504.72 40,91 348.69 1331.86 1412.96 395.78 396.09 395.81 390.17 -66.55 3,31 5970458,93 590396.97 N 70.32903473 W 149,26683508 1599.27 44,73 348.54 1401,20 1482.30 459.98 460.35 460,04 453.16 -79,24 4,04 5970521.75 590383.52 N 70.32920681 W 149.26693796 1693.36 48.35 349.54 1465.91 1547.01 528.23 528.63 528,31 520,20 -92.20 3,92 5970588.63 590369.75 N 70.32938996 W 149,26704311 1787,23 51,63 350.58 1526.25 1607,35 600,10 600.52 600.20 591.01 -104.59 3.60 5970659.27 590356.51 N 70.32958341 W 149.26714362 1880.35 51.58 350,71 1584,09 1665.19 673.08 673.50 673,17 663.02 -116.46 0.12 5970731.13 590343.78 N 70,32978014 W 149.26723984 1972.77 53.23 349,92 1640.47 1721.57 746.30 746.72 746.40 735,21 -128.78 1.91 5970803.15 590330.58 N 70.32997732 W 149,26733980 2066.39 54.60 350,29 1695,61 1776.71 821.95 822.38 822,06 809.74 -141.78 1.50 5970877.51 590316.69 N 70.33018094 W 149.26744523 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) Plan V-21 0 (N-G)\V-21 0\V-21 0\V-21 0 Generated 11/23/2004 8:56 AM Page 1 of 3 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure (ft) (dea) (dea) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (dea/100 ft) (ftUS) (ftUS) 2160.38 56.79 350.52 1748.58 1829.68 899,58 900,02 899.69 886.29 -154.72 2.34 5970953.89 590302.83 N 70.33039006 W 149.26755017 2254.53 61,22 350,15 1797.05 1878.15 980.26 980.70 980,38 965.83 -168.27 4.72 5971033,26 590288,32 N 70.33060736 W 149.26766009 2347.92 62.79 350.67 1840.89 1921.99 1062,72 1063,16 1062.83 1047.13 -182.01 1.75 5971114.39 590273.61 N 70.33082948 W 149.26777150 2440.95 62.14 350,52 1883.89 1964.99 1145.21 1145.65 1145.32 1128,52 -195,49 0.71 5971195.59 590259,15 N 70,33105181 W 149,26788084 2535.23 63.49 349,76 1926.97 2008,07 1229.06 1229.52 1229.19 1211.14 -209.85 1,60 5971278.03 590243.79 N 70.33127753 W 149.26799736 2628.25 61.91 349.19 1969,63 2050.73 1311,69 1312.17 1311.84 1292.41 -224.95 1.78 5971359.10 590227.72 N 70.33149954 W 149,26811981 2722.06 61.25 349,18 2014.28 2095.38 1394.15 1394.68 1394.33 1373.44 -240.43 0.70 5971439.94 590211.26 N 70.33172093 W 149,26824539 2815.35 62.59 348.72 2058,19 2139,29 1476,41 1476,99 1476.62 1454.22 -256.20 1.50 5971520.52 590194.51 N 70.33194162 W 149.26837337 2909.48 63.32 348,30 2100.99 2182.09 1560.17 1560.82 1560.43 1536.38 -272.90 0,87 5971602.46 590176,83 N 70.33216606 W 149.26850885 3002,29 62.00 348.12 2143.61 2224,71 1642.51 1643.26 1642.84 1617.08 -289.75 1.43 5971682.94 590159.01 N 70.33238653 W 149.26864549 3095.61 63.42 347.82 2186.40 2267.50 1725,33 1726,19 1725.72 1698.19 -307.04 1.55 5971763.83 590140,75 N 70,33260811 W 149.26.3 3188,42 62.48 347.45 2228.60 2309.70 1807.84 1808.85 1808.33 1778.93 -324,73 1,07 5971844,34 590122,08 N 70.33282868 W 149.26 1 3281.40 63.42 347.13 2270.89 2351.99 1890.48 1891,66 1891.07 1859.71 -342.95 1.06 5971924.89 590102.89 N 70.33304936 W 149.26907712 3374.26 62.29 346,78 2313.25 2394.35 1972.91 1974.29 1973,62 1940.21 -361.60 1.26 5972005.15 590083,27 N 70.33326927 W 149.26922842 3467.01 64.29 347.48 2354.94 2436,04 2055.57 2057.14 2056.40 2020.98 -380.05 2,26 5972085.68 590063.85 N 70.33348992 W 149.26937810 3561.41 63.42 346,95 2396.54 2477.64 2140.12 2141.88 2141.08 2103.61 -398.80 1,05 5972168.08 590044,11 N 70.33371568 W 149.26953023 3655.43 62.85 347.26 2439.02 2520.12 2223.81 2225.75 2224,90 2185.37 -417.52 0.67 5972249.60 590024.41 N 70.33393903 W 149.26968209 3749.36 64.88 347,79 2480.40 2561.50 2307.97 2310.07 2309.19 2267.70 -435.73 2,22 5972331.69 590005.21 N 70.33416395 W 149.26982985 3843,79 65.84 348,87 2519.77 2600.87 2393.71 2395.90 2395,01 2351.76 -453.09 1.45 5972415,53 589986,84 N 70.33439358 W 149.26997069 3915.17 62.48 348.41 2550.87 2631,97 2457,89 2460,14 2459.24 2414.73 -465.74 4.74 5972478.34 589973.43 N 70.33456562 W 149.27007332 3952.75 62.44 348,54 2568,25 2649.35 2491.18 2493.46 2492.56 2447,38 -472,40 0.32 5972510,90 589966,38 N 70.33465481 W 149.27012734 4046,33 62,82 348.26 2611.27 2692,37 2574.20 2576.56 2575.66 2528.79 -489.11 0.49 5972592.10 589948.69 N 70.33487721 W 149,27026294 4139,29 63.08 351.68 2653.56 2734.66 2656.96 2659.35 2658.42 2610.30 -503.52 3.29 5972673.42 589933.30 N 70.33509988 W 149.27037990 4231.99 63.69 353.83 2695.09 2776.19 2739,79 2742,22 2741.13 2692.51 -513.97 2.18 5972755.49 589921.86 N 70.33532447 W 149,27046469 4325.44 63.57 354,94 2736.60 2817.70 2823.37 2825.95 2824.52 2775,83 -522.16 1.07 5972838,70 589912.67 N 70.33555209 W 149.27053119 4418.55 63,16 354.20 2778.34 2859.44 2906.43 2909.18 2907.41 2858.69 -530.04 0.84 5972921.44 589903.80 N 70.33577844 W 149.27059512 4512.05 60.58 355,25 2822.42 2903.52 2988.70 2991.62 2989,52 2940.78 -537.62 2.93 5973003.43 589895,22 N 70.33600272 W 149.27065673 4605.33 60.82 355,50 2868.07 2949.17 3069.81 3072.97 3070.47 3021.87 -544.18 0,35 5973084.42 589887,68 N 70.33622423 W 149.27070999 4698,58 62.42 355.09 2912.39 2993.49 3151.62 3155.01 3152.14 3103.63 -550.91 1.76 5973166.09 589879.97 N 70.33644760 W 149'2.r 4792.71 63.16 354.84 2955.43 3036.53 3235,13 3238,72 3235.54 3187.02 -558,26 0,82 5973249.38 589871.61 N 70.33667541 W 149.2 0 4885,19 63.36 354.50 2997.04 3078,14 3317.55 3321.31 3317.87 3269.25 -565.93 0.39 5973331.51 589862.95 N 70.33690006 W 149,27 659 4978.41 63.18 355.94 3038.98 3120.08 3400,58 3404,57 3400.81 3352.22 -572.87 1.39 5973414.37 589855.01 N 70,33712671 W 149.27094293 5071.81 61.79 356.32 3082.12 3163.22 3483,07 3487.40 3483.23 3434.86 -578.4 7 1.53 5973496.94 589848.43 N 70.33735249 W 149.27098835 5165.03 60.30 356.46 3127,25 3208.35 3564.28 3568.97 3564,36 3516.26 -583.60 1,60 5973578.27 589842.31 N 70.33757488 W 149.27103008 5257.83 62,68 355.16 3171.54 3252.64 3645.53 3650.51 3645.57 3597.58 -589.57 2.84 5973659.50 589835.36 N 70.33779703 W 149.27107854 5351.27 63.43 354.71 3213.89 3294.99 3728.62 3733.81 3728.64 3680.55 -596.92 0.91 5973742.37 589827.01 N 70.33802370 W 149.27113827 5445.47 64.04 354.67 3255.57 3336.67 3812.92 3818.28 3812.93 3764.66 -604,74 0.65 5973826.37 589818.18 N 70.33825348 W 149.27120175 5538.92 63.74 354.64 3296.70 3377.80 3896.66 3902.19 3896,66 3848.21 -612.56 0.32 5973909.81 589809.35 N 70.33848173 W 149,27126522 5632.40 62.54 355.10 3338.93 3420.03 3979,86 3985.59 3979.86 3931,27 -620,02 1.36 5973992.77 589800.90 N 70.33870863 W 149.27132579 5725.41 63,02 354.68 3381.48 3462.58 4062.38 4068.30 4062,39 4013.65 -627.38 0,65 5974075.04 589792.54 N 70.33893369 W 149,27138562 5820.34 63.79 354.06 3423.97 3505.07 4147,11 4153,18 4147.14 4098,13 -635.71 1.00 5974159,40 589783.19 N 70,33916446 W 149.27145325 SurveyEditor Ver 3.1 RT-SP3,03-HF5.00 Sld( do31 rt-546 ) Plan V-21 0 (N-G)\V-21 0\V-21 0\V-21 0 Generated 11/23/2004 8:56 AM Page 2 of 3 Comments Latitude Longitude N 70.33939213 W 149.27151999 6007,92 63.73 354.46 3508.97 3590.07 4314.02 4320,39 4314.09 4264.56 -651.83 1.49 5974325.62 589765.07 N 70.33961914 W 149.27158414 6099.95 64.43 354.84 3549,20 3630.30 4396.62 4403.16 4396.72 4346.97 -659,55 0.85 5974407.92 589756.36 N 70,33984428 W 149.27164681 6193.79 64.24 354.44 3589.84 3670.94 4481,03 4487.75 4481.17 4431.18 -667.45 0.43 5974492,02 589747.44 N 70.34007434 W 149.27171098 6286.54 64.15 355.06 3630,22 3711,32 4564.35 4571.25 4564.53 4514,33 -675.09 0.61 5974575.07 589738.80 N 70.34030149 W 149,27177303 6380.60 64.56 354.87 3670.93 3752.03 4648.94 4656.04 4649.17 4598.80 -682.53 0.47 5974659.43 589730.34 N 70.34053225 W 149.27183348 6474.63 62,86 353.70 3712,57 3793.67 4733.09 4740.34 4733,38 4682,68 -690.92 2.12 5974743.20 589720.95 N 70.34076140 W 149.27190160 6568,12 62.75 349.94 3755.31 3836.41 4816.22 4823.49 4816.51 4764.97 -702.75 3.58 5974825,33 589708,13 N 70,34098620 W 149.27199763 6660.74 62.46 349.52 3797,93 3879.03 4898.43 4905.72 4898.70 4845.88 -717.41 0.51 5974906.05 589692.49 N 70.34120725 W 149,27211666 6755.15 62.24 349,37 3841.74 3922.84 4982.03 4989.35 4982.27 4928.10 -732.73 0,27 5974988.07 589676.19 N 70,34143185 W 149.27224102 6849.89 62.27 350.03 3885.85 3966.95 5065,86 5073.20 5066.08 5010.59 -747,72 0.62 5975070.37 589660,20 N 70.34165721 W 149.27.4 6942.67 62,12 350.16 3929.13 4010.23 5147.92 5155.27 5148.12 5091.44 -761,84 0.20 5975151.03 589645.11 N 70.34187807 W 149,27 6 7036,07 62.29 349.53 3972.68 4053,78 5230.52 5237,89 5230.71 5172.77 -776.40 0.62 5975232,17 589629.57 N 70.34210025 W 149.27259564 7129.20 62.40 350,06 4015,91 4097.01 5312.99 5320.38 5313,16 5253,95 -791.02 0,52 5975313.17 589613.98 N 70,34232203 W 149.27271430 7221,85 60,54 351.16 4060.16 4141.26 5394,39 5401.78 5394.55 5334.25 -804,31 2.26 5975393.29 589599.72 N 70.34254141 W 149,27282218 7315.76 55.74 351,58 4109.71 4190,81 5474.12 5481.51 5474.29 5413,09 -816.28 5.13 5975471.97 589586.80 N 70.34275677 W 149.27291941 7409,22 51.56 350.10 4165.10 4246.20 5549,38 5556,77 5549.54 5487.39 -828,23 4.65 5975546.11 589573.95 N 70.34295974 W 149.27301648 7501.46 50.30 345.64 4223.25 4304.35 5620.85 5628.37 5620.98 5557,37 -843.25 3,99 5975615.91 589558.10 N 70,34315094 W 149.27313840 7595.12 50,54 345.39 4282.93 4364.03 5692.71 5700.55 5692.80 5627.26 -861,30 0.33 5975685,57 589539.20 N 70.34334187 W 149.27328500 7688.72 50.77 345.80 4342,27 4423.37 5764.78 5772.94 5764,83 5697,37 -879.31 0.42 5975755.45 589520.35 N 70.34353340 W 149.27343119 7781.29 50,87 345,23 4400.75 4481.85 5836.21 5844.69 5836.23 5766.85 -897.26 0.49 5975824.70 589501.57 N 70.34372319 W 149,27357691 7876.16 50.98 345.45 4460,55 4541.65 5909.50 5918.34 5909.51 5838,10 -915.90 0,21 5975895.71 589482.07 N 70,34391784 W 149.27372825 7968.29 51,15 344,78 4518.45 4599.55 5980.79 5990.01 5980.79 5907.36 -934,31 0.60 5975964.74 589462.83 N 70.34410704 W 149,27387772 8062,29 51.23 344.26 4577.36 4658.46 6053.57 6063.26 6053.57 5977.95 -953.86 0.44 5976035,08 589442.43 N 70,34429988 W 149.27403645 8155.38 51.59 343.81 4635.43 4716.53 6125.80 6136.02 6125,81 6047.90 -973.87 0.54 5976104.78 589421.58 N 70.34449098 W 149,27419894 Last MWD IFR MS 8206,23 51.84 343,39 4666.93 4748.03 6165.38 6175.93 6165.41 6086.19 -985.14 0.81 5976142.93 589409,85 N 70,34459558 W 149.27429044 TD ( Projected) 8280.00 51.84 343.39 4712.51 4793,61 6222.88 6233.94 6222.93 6141,78 -1001.72 0,00 5976198.30 589392.60 N 70,34474743 W 149.27442507 Survey Type: Definitive Survey . NOTES: GYD GC SS - ( Gyrodata - gyro single shots -- Gyrodata gyro orientation surveys. ) MWD + IFR + MS - ( In-field referenced MWD with mult-station analysis and correction applied in post-processing.) Leaat DescriDtion: Northina (VI mUS1 Eastina (XI rftUS1 Surface: 4823 FSL 1833 FEL S11 T11N R11E UM 5970069,62 590468.21 BHL: 405 FSL 2829 FEL S35 T12N R11 E UM 5976198.30 589392.60 SurveyEditor Ver 3,1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) Plan V-210 (N-G)\V-21 0\V-21 0\V-21 0 Generated 11/23/2004 8:56 AM Page 3 of 3 TREE = W8..LH~D = A~TOR= KB. 8..EV = B K Max Da Da 4-1/16" CIVV FMC NA 81.1' FROM DRL~RAFT V -21 0 i SAÆTY NOTES: GLM'S @ STA #1- #5 ARE ·112" X 1·112" MMG-W WHICH ARE ATERROOD MANDRELS. F. 8.EV = 52.6' OP= 200' /l 4-1/2" HES X NIP, D = 3.813" I Angle = 660 @ 6584' 3670' tum MD = xxxx' IV tumlVD= xxxx' SS . WA TERFLOOD MANDR8.S ST MD lVD DEV TYPE VLV LATCH PORT DATE 6 7386 4233 67 KBG2 DC!< BEl< YES 38302 I 9-5/8" CSG, 40#, L-80, ID = 8.835" I 3888' I ~ 5 7588 4360 67 MMG-W DUM RK 11/11/04 L 4 7617 4378 68 MMG-W DUM RK 11/11/04 3 7691 4424 68 MMG-W DUM RK 11/11/04 Minimum ID = 2.813" 2 7751 4463 68 MMG-W DUM RK 11/11/04 1 7825 4510 68 MMG-W DUM RK 11/11/04 3-1/2" HES X NIPPLE 17" MARKER JOINT W/ RA TAG I 6895' I .. I . . 7496' 4-1/2" HES X NIP, D = 3.813" I i . [8 Iov -I 7517' 1-1 7" X 4-1/2" BKR PREMIER PKR, D = 3.87" I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3,958" 7577' ~ --¡ 7577' H 4-1/2" X 3-1/2" XO. ID = 2.990" I L L 1 ~ 7644' 3-112" HES X NIP, D = 2.813" I I 3-1/2"1BG W/ RA MARKERI-I 7635' ~ -'. .......... :8 ..,....,. 7664' LJ 7" X 3-1/2" BKR PREMIER PKR, D = 2.89" 6 17" MARKER JOINT WI RA TAG I 7540' ~r I~ 7778' H 3-1/2" HES X NIP. ID - 2.813" I 3-1/2"1BG, 9.2#, L-80, .0087 bpf, D = 2.992" I 8264' k I:::: 1\ ~ 7799' LJ 7" X 3-1/2" BKR PREMIER PKR, ID = 2.89" ¿:: PERFORATION SUMMARY L REF LOG: SWS COR-NEUTRON 11/05/04 ANGLE AT TOP PERF: 66° @ 7341' !\ ~ 7852' H 3-1/2" HES X NIP. D - 2.813" I Note: Refer to A"oduction DB for historical perf data I......... SIZE SPF INTERVAL Opn/Sqz DATE . 7873' LJ 7" X 3-1/2" BKR PREMIER PKR, ID - 2.89" ~ ..,....,. 4.5" 5 7598' - 7648' Open 11/08/04 ¡.c, 4.5" 5 7692' - 7736' Open 11/08/04 . 3-1/2" HES X NIP, ID = 2.813" I 4.5" 5 7754' - 7780' Open 11/08/04 . 789T LJ 4.5" 5 7842' - 7862' Open 11/08/04 . 1- 4.5" 5 7920' - 7995' Open 11/08/04 --...¡ 7914' H 3-1/2" HES X NIP, D = 2.813" I - -- ---r 7931' 3-1/2" WLEG, D = 3.00" I I I PBID 8179' I 7" CSG, 26#, L-80, D = 6.276" 8264' ~8 DA TE REV BY COMMENTS 11/11/04 TA ORIGINAL COMPLETION DA TE REV BY COMMENTS ORION UNIT W8.L: V-210i PERMIT No: 204-210 API No: 50-029-23231-00 SEe 11, T11N, R11E, 4823' NSL & 1833' W8. BP Exploration (Alaska) SCRLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Orion Well. . . . . . . . . . . . . . . . . . . . .: V-210 API number...............: 50-029-23231-00 Engineer.................: St.Amour Rig:.....................: Nabors 9ES State: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS. . . . . . . . . . .: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Drill Floor GL above permanent.......: 52.15 ft KB above permanent. . . . . . . : N/A (Topdrive) DF above permanent.......: 81.10 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 rotary table to target: 350.98 degrees [(c)2004 IDEAL ID8_1C_02] 5-Nov-2004 20:45:05 Spud date........... .....: Last survey date. ........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 5 31 Oct 2004 05-Nov-04 91 0.00 ft 8280.00 ft . ----- Geomagnetic data ---------------------- Magnetic model...... .....: BGGM version 2004 Magnetic date....... .....: 31-0ct-2004 Magnetic field strength..: 1151.91 RCNT Magnetic dec (+E/W-).....: 24.73 degrees Magnetic dip.............: 80.80 degrees ----- MWD survey Reference Reference G........ ......: Reference R....... .......: Reference Dip... .........: Tolerance of G..... ......: Tolerance of R...........: Tolerance of Dip. ........: Criteria --------- 1002.68 mGal 1151.90 RCNT 80.80 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees . ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.73 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.73 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumherger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction ?- ~~-ÂlG SCHLUMBERGER Survey Report 5-Nov-2004 20:45:05 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 2 112.00 0.12 245.61 112.00 112.00 -0.03 -0.05 -0.11 0.12 245.61 0.11 Gyro 3 200.00 0.69 345.11 88.00 200.00 0.47 0.43 -0.33 0.54 322.47 0.82 Gyro 4 300.00 3.43 0.63 100.00 299.92 4.02 4.00 -0.45 4.02 353.60 2.77 Gyro 5 400.00 6.83 351.47 100.00 399.51 12.92 12.87 -1.30 12.94 354.24 3.49 Gyro 6 500.00 7.61 350.14 100.00 498.72 25.49 25.28 -3.31 25.49 352.53 0.80 Gyro . 7 600.00 8.00 349.48 100.00 597.79 39.06 38.64 -5.72 39.06 351.58 0.40 Gyro 8 700.00 10.30 350.04 100.00 696.51 54.96 54.29 -8.54 54.96 351. 07 2.30 Gyro 9 800.00 13.57 349.88 100.00 794.34 75.63 74.65 -12.14 75.63 350.76 3.27 Gyro 10 900.00 16.32 350.84 100.00 890.94 101. 42 100.08 -16.44 101. 42 350.67 2.76 Gyro 11 1000.00 19.21 351.39 100.00 986.17 131.93 130.22 -21.14 131.93 350.78 2.89 Gyro 12 1100.00 24.81 349.56 100.00 1078.84 169.38 167.15 -27.41 169.38 350.69 5.64 Gyro 13 1132.14 27.27 350.12 32.14 1107.72 183.49 181.04 -29.90 183.49 350.62 7.69 MWD IFR MS 14 1225.47 32.64 350.96 93.33 1188.55 230.07 226.99 -37.53 230.07 350.61 5.77 MWD IFR MS 15 1318.29 34.70 350.58 92.82 1265.80 281.53 277.78 -45.79 281. 53 350.64 2.23 MWD IFR MS 16 1412.22 37.89 349.49 93.93 1341.49 337.11 332.53 -55.43 337.12 350.54 3.46 MWD IFR MS 17 1504.72 40.91 348.69 92.50 1412.96 395.78 390.17 -66.55 395.81 350.32 3.31 MWD IFR MS 18 1599.27 44.73 348.54 94.55 1482.30 459.98 453.16 -79.24 460.04 350.08 4.04 MWD IFR MS 19 1693.36 48.35 349.54 94.09 1547.01 528.23 520.20 -92.20 528.31 349.95 3.92 MWD IFR MS 20 1787.23 51.63 350.58 93.87 1607.35 600.10 591.01 -104.59 600.20 349.96 3.60 MWD IFR MS 21 1880.35 51.58 350.71 93.12 1665.19 673.08 663.02 -116.46 673.17 350.04 0.12 MWD IFR MS . 22 1972.77 53.23 349.92 92 .42 1721.57 746.30 735.21 -128.78 746.40 350.06 1. 91 MWD IFR MS 23 2066.39 54.60 350.29 93.62 1776.71 821.95 809.74 -141.78 822.06 350.07 1. 50 MWD IFR MS 24 2160.38 56.79 350.52 93.99 1829.68 899.58 886.29 -154.72 899.69 350.10 2.34 MWD IFR MS 25 2254.53 61.22 350.15 94.15 1878.15 980.26 965.83 -168.27 980.38 350.12 4.72 MWD IFR MS 26 2347.92 62.79 350.67 93.39 1921.99 1062.72 1047.13 -182.01 1062.83 350.14 1. 75 MWD IFR MS 27 2440.95 62.14 350.52 93.03 1964.99 1145.21 1128.52 -195.49 1145.32 350.17 0.71 MWD IFR MS 28 2535.23 63.49 349.76 94.28 2008.07 1229.06 1211.14 -209.85 1229.19 350.17 1. 60 MWD IFR MS 29 2628.25 61.91 349.19 93.02 2050.73 1311.69 1292.41 -224.95 1311.84 350.13 1. 78 MWD IFR MS 30 2722.06 61. 25 349.18 93.81 2095.38 1394.15 1373.44 -240.43 1394.33 350.07 0.70 MWD IFR MS [(c)2004 IDEAL ID8 1C_02] SCHLUMBERGER Survey Report 5-Nov-2004 20:45:05 Page 3 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) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2815.35 62.59 348.72 93.29 2139.29 1476.41 1454.22 -256.20 1476.62 350.01 1. 50 MWD IFR MS 32 2909.48 63.32 348.30 94.13 2182.09 1560.17 1536.38 -272.90 1560.43 349.93 0.87 MWD IFR MS 33 3002.29 62.00 348.12 92.81 2224.71 1642.51 1617.08 -289.75 1642.84 349.84 1. 43 MWD IFR MS 34 3095.61 63.42 347.82 93.32 2267.50 1725.33 1698.19 -307.04 1725.72 349.75 1. 55 MWD IFR MS 35 3188.42 62.48 347.45 92.81 2309.70 1807.84 1778.93 -324.73 1808.33 349.65 1. 07 MWD IFR MS 36 3281.40 63.42 347.13 92.98 2351.99 1890.48 1859.71 -342.95 1891.07 349.55 1. 06 MWD IFR MS . 37 3374.26 62.29 346.78 92.86 2394.35 1972.91 1940.21 -361.60 1973.62 349.44 1.26 MWD IFR MS 38 3467.01 64.29 347.48 92.75 2436.04 2055.57 2020.98 -380.05 2056.40 349.35 2.26 MWD IFR MS 39 3561.41 63.42 346.95 94.40 2477.64 2140.13 2103.61 -398.80 2141.08 349.27 1. 05 MWD IFR MS 40 3655.43 62.85 347.26 94.02 2520.12 2223.81 2185.37 -417.52 2224.90 349.18 0.67 MWD IFR MS 41 3749.36 64.88 347.79 93.93 2561.50 2307.97 2267.70 -435.73 2309.19 349.12 2.22 MWD IFR MS 42 3843.79 65.84 348.87 94.43 2600.87 2393.71 2351.76 -453.09 2395.01 349.10 1.45 MWD IFR MS 43 3915.17 62.48 348.41 71.38 2631.97 2457.89 2414.73 -465.74 2459.24 349.08 4.74 MWD IFR MS 44 3952.75 62.44 348.54 37.58 2649.35 2491.18 2447.38 -472.40 2492.56 349.08 0.32 MWD IFR MS 45 4046.33 62.82 348.26 93.58 2692.37 2574.20 2528.79 -489.11 2575.66 349.05 0.49 MWD IFR MS 46 4139.29 63.08 351.68 92.96 2734.66 2656.96 2610.30 -503.52 2658.42 349.08 3.29 MWD IFR MS 47 4231.99 63.69 353.83 92.70 2776.19 2739.79 2692.51 -513.97 2741.13 349.19 2.18 MWD IFR MS 48 4325.44 63.57 354.94 93.45 2817.70 2823.37 2775.83 -522.16 2824.52 349.35 1. 07 MWD IFR MS 49 4418.55 63.16 354.20 93.11 2859.44 2906.43 2858.69 -530.04 2907.41 349.50 0.84 MWD IFR MS 50 4512.05 60.58 355.25 93.50 2903.52 2988.71 2940.78 -537.62 2989.52 349.64 2.93 MWD IFR MS 51 4605.33 60.82 355.50 93.28 2949.17 3069.81 3021.87 -544.18 3070.47 349.79 0.35 MWD IFR MS . 52 4698.58 62.42 355.09 93.25 2993.49 3151.62 3103.63 -550.91 3152.14 349.93 1. 76 MWD IFR MS 53 4792.71 63.16 354.84 94.13 3036.53 3235.13 3187.02 -558.26 3235.54 350.06 0.82 MWD IFR MS 54 4885.19 63.36 354.50 92.48 3078.14 3317.55 3269.25 -565.93 3317.87 350.18 0.39 MWD IFR MS 55 4978.41 63.18 355.94 93.22 3120.07 3400.58 3352.22 -572.87 3400.81 350.30 1. 39 MWD IFR MS 56 5071.81 61. 79 356.32 93.40 3163.22 3483.08 3434.86 -578.47 3483.23 350.44 1. 53 MWD IFR MS 57 5165.03 60.30 356.46 93.22 3208.35 3564.28 3516.26 -583.60 3564.37 350.58 1. 60 MWD IFR MS 58 5257.83 62.68 355.16 92.80 3252.64 3645.53 3597.58 -589.57 3645.57 350.69 2.84 MWD IFR MS 59 5351.27 63.43 354.71 93.44 3294.99 3728.62 3680.55 -596.92 3728.64 350.79 0.91 MWD IFR MS 60 5445.47 64.04 354.67 94.20 3336.67 3812.92 3764.66 -604.74 3812.93 350.87 0.65 MWD IFR MS [(c)2004 IDEAL ID8_1C_02J SCHLUMBERGER Survey Report 5-Nov-2004 20:45:05 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 5538.92 63.74 354.64 93.45 3377.80 3896.66 3848.21 -612.56 3896.66 350.96 0.32 MWD IFR MS 62 5632.40 62.54 355.10 93.48 3420.03 3979.86 3931.27 -620.02 3979.86 351.04 1. 36 MWD IFR MS 63 5725.41 63.02 354.68 93.01 3462.58 4062.38 4013.65 -627.38 4062.39 351.12 0.65 MWD IFR MS 64 5820.34 63.79 354.06 94.93 3505.07 4147.11 4098.13 -635.71 4147.14 351. 18 1. 00 MWD IFR MS 65 5914.27 62.35 354.68 93.93 3547.61 4230.71 4181.46 -643.93 4230.76 351.25 1. 64 MWD IFR MS 66 6007.92 63.73 354.46 93.65 3590.07 4314.02 4264.56 -651.83 4314.09 351.31 1.49 MWD IFR MS . 67 6099.95 64.43 354.84 92.03 3630.30 4396.62 4346.97 -659.55 4396.72 351.37 0.85 MWD IFR MS 68 6193.79 64.24 354.44 93.84 3670.94 4481.03 4431.18 -667.45 4481.17 351.43 0.43 MWD IFR MS 69 6286.54 64.15 355.06 92.75 3711.32 4564.35 4514.33 -675.09 4564.53 351.49 0.61 MWD IFR MS 70 6380.60 64.56 354.87 94.06 3752.03 4648.94 4598.80 -682.53 4649.17 351.56 0.47 MWD IFR MS 71 6474.63 62.86 353.70 94.03 3793.67 4733.10 4682.68 -690.92 4733.38 351.61 2.12 MWD IFR MS 72 6568.12 62.75 349.94 93.49 3836.41 4816.22 4764.97 -702.75 4816.51 351.61 3.58 MWD IFR MS 73 6660.74 62.46 349.52 92.62 3879.03 4898.43 4845.88 -717.41 4898.70 351.58 0.51 MWD IFR MS 74 6755.15 62.24 349.37 94.41 3922.84 4982.03 4928.10 -732.73 4982.27 351. 54 0.27 MWD IFR MS 75 6849.89 62.27 350.03 94.74 3966.95 5065.86 5010.59 -747.72 5066.08 351.51 0.62 MWD IFR MS 76 6942.67 62.12 350.16 92.78 4010.22 5147.92 5091. 44 -761.84 5148.12 351.49 0.20 MWD IFR MS 77 7036.07 62.29 349.53 93.40 4053.79 5230.52 5172.76 -776.40 5230.71 351.46 0.62 MWD IFR MS 78 7129.20 62.40 350.06 93.13 4097.02 5312.99 5253.94 -791.02 5313.16 351. 44 0.52 MWD IFR MS 79 7221.85 60.54 351.16 92.65 4141.27 5394.38 5334.25 -804.30 5394.54 351.43 2.26 MWD IFR MS 80 7315.76 55.74 351.58 93.91 4190.83 5474.12 5413.08 -816.28 5474.28 351.42 5.13 MWD IFR MS 81 7409.22 51.56 350.10 93.46 4246.21 5549.37 5487.38 -828.23 5549.53 351. 42 4.65 MWD IFR MS . 82 7501.46 50.30 345.64 92.24 4304.36 5620.84 5557.36 -843.25 5620.98 351.37 3.99 MWD IFR MS 83 7595.12 50.54 345.39 93.66 4364.04 5692.70 5627.26 -861.30 5692.79 351.30 0.33 MWD IFR MS 84 7688.72 50.77 345.80 93.60 4423.38 5764.77 5697.37 -879.31 5764.82 351.23 0.42 MWD IFR MS 85 7781.29 50.87 345.23 92.57 4481.86 5836.20 5766.84 -897.26 5836.23 351.16 0.49 MWD IFR MS 86 7876.16 50.98 345.45 94.87 4541.66 5909.49 5838.09 -915.90 5909.50 351.08 0.21 MWD IFR MS 87 7968.29 51. 15 344.78 92.13 4599.56 5980.78 5907.35 -934.31 5980.78 351.01 0.60 MWD IFR MS 88 8062.29 51. 23 344.26 94.00 4658.47 6053.56 5977.94 -953.86 6053.56 350.93 0.44 MWD IFR MS 89 8155.38 51. 59 343.81 93.09 4716.54 6125.79 6047.90 -973.87 6125.80 350.85 0.54 MWD IFR MS 90 8206.23 51.84 343.39 50.85 4748.04 6165.37 6086.19 -985.14 6165.40 350.81 0.81 MWD IFR MS [(c)2004 IDEAL ID8_1C_02J SCHLUMBERGER Survey Report -------- ------ ------- -------- ------ ------- Seq # Measured depth (ft) Incl angle (deg) Azimuth angle (deg) -------- ------ ------- -------- ------ ------- Projection to Total Depth: 91 8280.00 51.84 343.39 [(c)2004 IDEAL ID8 1C_02J 5-Nov-2004 20:45:05 5 of 5 Page ------ -------- -------- ---------------- --------------- ----- ------ ------ -------- -------- ---------------- --------------- ------ Course TVD Vertical Displ Displ Total At DLS Srvy Tool length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) ------ -------- -------- ---------------- --------------- ------ ------ -------- -------- ---------------- --------------- ------ 73.77 4793.62 6222.87 6141.77 -1001.72 6222.93 350.74 0.00 . . . . Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Helen Warman Well No V-210 Date Dispatched: 19-0ct-04 Installation/Rig Nabors 9ES Dispatched By: J. Bosse Data No Of Prints No of Floppies Surveys 2 1 ......1 , , Received By: YJL 1 ())) j Please sign and return to: Ä c.¡ M(v Drilling & Measurements LWD Division À Ó\J'1 2525 Gambell Street, Suite 400 Anchorage, Alaska 99503 nrosel@slb.com Fax: 907·561·8417 LWD Log DeliveryV1.1, 10-02-03 Schlumberger Private ;:z 0 '1 - Ál 0 ¡:,./. . 'J..,O '-I, ¡81 - :À€>'1-Z'0- . 11/22/04 Schlumbergep NO. 3272 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Well Job# Log Description Color Date CD BL Z-210 10912990 USIT (PDC) 10/30/04 1 1 V-210 10687711 USIT (PDC) 11/09/04 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Schlumberger -DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 :~:e::~¡tif~ Date Delivered: //~ /;1 / / . ~1f~1fŒ (ID~ ~~~~[K{~ . AIfASIiA. OILAlO) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7"" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay V-21Oi BP Exploration (Alaska) Inc. Permit No: 204-210 Surface Location: 4823' NSL, 1833' WEL, SEC. 11, T11N, R11E, UM Bottomhole Location: 375' NSL, 2801' WEL, SEC. 35, TI2N, RIlE, UM Dear Mr. Crane: 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 Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3 (pager). BY ORDER O~HE COMMISSION DATED this.1§day of October, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. \NbA- lo/-¿s.{z,oat ALASKA. AND ~~T~g~S~::~ON COIISSIO~ E ~ [) OCT 2 () 2004 PERMIT TO DRILL 20 MC 25 005 , SiO'l IU,'e'" n¡; [Ii L;:" Gijí:,}. l,mmms' ., 1a. Type of work II Drill o Redrill rb. Current Well Class o EXPIc;>ratO)/O DevelopmenþQ~hí\~~UltiPle Zone ORe-Entry o Stratigraphic Test II Service 0 Developmen ~as··' 'Ingle Zone 2. Operator Name: 5. Bond: !HI Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 PBU V-21Oi 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 8258 TVD 4796 Prudhoe Bay Field 1 Orion 4a. Location of Well (Governmental Section): 7. Property Designation: Schrader Bluff Surface: ADL 028238 4823' NSL, 1833' WEL, SEC. 11, T11N, R11E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 5185' NSL, 2703' WEL, SEC. 02, T11N, R11E, UM October 29,2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 375' NSL, 2801' WEL, SEC. 35, T12N, R11E, UM 2560 10220' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to NearestX'~~~hin Pool Surface: x- 590468 y- 5970070 Zone- ASP4 (Height above GL):Plan 81.1 feet V-202 i~a a top of OA 16. Deviated Wells: Kickoff Depth: 300 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.~) Maximum Hole Angle: 63 degrees Downhole: 2050 Surface: 1586 If.,.....,,...~ .~._." T!lp ,... ·¡:;¡nt·......; (_ata) Siit:è ': Hole CasinQ WeiQht Grade CouplinQ LenQth MD TVD MD TVD 42" 20" x 34" 215.5# A53 Welded 80' 29' 29' 109' 109' 260 sx Arctic Set (Approx,) 12-1/4" 9-518" 40# L-80 BTC 3912' 29' 29' 3941' 2631' 615 sx Arcticset Ute, 378 sx 'G' 8-3/4" 7" 26# L-80 BTC-M 8229' 29' 29' 8258' 4796' 346 sx Class 'G' 19. PRES5NT .WE;LLCQI\IDITION.SUMMABY(TQ becompt$tEi~forRedriIIANPiRe..entrYQ~I'ªtiqn?) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): I Effective Depth TVD (ft): Junk (measured): 'Casino ......... <i: ..·..e.·...··· ....i(SiZ$:::··.,.·· ."L·. ....,.// /././ ..........e· :'·yi/L.MO; ................. .... ..,.11'......./.:. Structural Conductor Surface Intermediate Production Uner Perforation Depth MD (ft): perfOration Depth TVD (ft): 20. Attachments 181 Filing Fee, $100 o BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis 181 Property Plat o Diverter Sketch o Seabed Report 181 Drilling Fluid Program 18120 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 Rob Tirpack, 564-4166 Printed Name ~<jtvell Crane ~ Title Senior Drilling Engineer Prepared By Name/Number: SiQnature·~ ~...-( .1Cé:_ 564-4089 )::/ Terrie 4"hhlo "'",. A""'O Phone Date . c<;2.ò- ",."" i.... ~<. 'i" .... o .i'·, ,i' iri ···ii··'···.... ........ .i.y.;....··.·.: i.' ... ..... ............. "'i' ,., .'i.... .. Permit To Drill I API Number: Permit Approval I ~ee cover letter for Number: Zo ç¡ - Z/O 50- 029- 2..~ 2.3/ Date: other requirements Conditions of Approval: Samples Required D Yes ~o Mud Log Required DYes )gNO Hydrogen Sulfide Measures DYes ~ No Directional Survey Required JIVes D No Other "T...·d· ß 1/ p~ 4000 f<: . ,till: m '/ ß ""-Út:¡ lor rf Ú "-"" w. d Date /Ð /'JSí t)'f Aooroved BV:,...-/I ~ 'A n 0 I ~ I t\llll APPROVED BY THE COMMISSION Form 10-401 ReviW06/2004 - .......i'u-...., .- ¥bmit ," Dupficate ~\.¡GA- . . Well Plan Summary I Well Name: I V-210i I Type of Well (producer or injector): I USH Injector 4,823' FSL, 1,833' FEL, Sec. 11, T11 N, R11 E ,/",. X = 590,468.21 Y = 5,970,069.62 5,185' FSL, 2,703' FEL, Sec. 2, T11N, R11E X = 589,525 Y = 5,975,700 Z = 4,270' TVDss 126' FSL, 2,749' FEL, Sec. 35, T12N, R11E X = 589,475 Y = 5,975,926 Z = 4,485' TVDss 374' FSL, 2,801' FEL, Sec. 35, T12N, R11E / X = 589,421 Y = 5,976,168 Z = 4,715' TVDss I AFE Number: I ORD5M3562 Estimated Start Date: I October 29'" 2004 t Operating days to complete: 114.3 Œ[] 8,258' f ~ 4,796' II Max Inc: ~ t GL: I 52.6' I Œ[] 28.5' II KBE: œTI Well Design: USH Grassroots Schrader Injector. 4-112" X 3-112" TCII Com letion. General Distance to Nearest Property: ~O' at top OA to the nearest PBU property line Distance to Nearest Well in POol:~~om V-210i to V-202 at the OA top ~,,~ .077 API Number: ~029-XXXXX Well Type: Development - Orion Schrader Injector Current Status: New well, 20" X 34" insulated conductor BHP: 2,050 psi @ 4,640' TVDss (8.5 ppg EMW). Normal pressure gradient. BHT: 100°F @ 4,640' TVDss estimated (from L-pad Temp Log) Mechanical Condition V-210i: Nabors 9ES: Conductor: Cellar Box above MSL = 52.6' - as built KB height = 28.5' 20" X 34", 215.5Ib/ft, A53 ERW set at 109' RKB % Mile Wellbore Near Wellbore Mechanical Integrity Summary: V-202 (An Orion producer) lies with in the % mile radius of V-2..10i. V-202 has a slotted liner completion across the Schrader. The 7-5/8" intermediate casing landed at the top of the Schrader was cemented without problems and had a planned TOC of -700' MD above the Ma. No cement bond logs were run. No near wellbore integrity issues. V-21Oi Permit to Drill Page 1 . . Formation Markers (Based on Schlumberger wp05) ^ SV6 976' 961' 880' 405 8.8 No SV5 1,801' 1,621' 1,540' 708 8.8 No SV4 2,035' 1,756' 1,675' 771 8.8 Poss. Gas Hydrates Base Permafrost 2,081' 1,781' 1,700' 782 8.8 No SV3 2,934' 2,171' 2,090' 961 8.8 Poss. Gas Hydrates Fault 1 3,241' 2,311' 2,230' 8.8 N/A SV2-Faulted Top 3,241' 2,311' 2,230' 1026 8.8 Poss. Gas Hydrates SV1 3,722' 2,531' 2,450' 1127 8.8 Poss. Gas Hydrates UG4 4,411' 2,846' 2,765' 1260 8.8 Thin coal UG4A 4,499' 2,886' 2,805' 1275 8.7 Heavy Oil-2805' to 3020' TVDss UG3 5,199' 3,206' 3,125' 1412 8.7 Thin coals UG1 6,259' 3,691' 3,610' 1625 8.7 Heavy Oil-3740' to 3910' TVDss Top Schrader/Ma Sand 6,828' 3,951' 3,870' 1760 8.7 Heavy Oil-3870' to 3900' TVDss Mb1 6,916' 3,991' 3,910' 1775 8.7 Heavy Oil-391 0' to 3950' TVDss Mb2 7,058' 4,056' 3,975' 1805 8.7 No Mc 7,211' 4,126' 4,045' 1825 8.7 No Na 7,332' 4,186' 4,105' 1855 8.7 No Nb 7,387' 4,216' 4,135' 1860 8.7 Yes Nc 7,455' 4,256' 4,175' 1880 8.7 Yes OA 7,596' 4,346' 4,265' 1795 8.1 Yes OBa 7,699' 4,416' 4,335' 1905 8.5 Yes OBb 7,758' 4,456' 4,375' 1955 8.6 Yes OBc 7,839' 4,511' 4,430' 1975 8.6 Yes OBd 7,920' 4,566' 4,485' 1925 8.3 Yes OBe 8,008' 4,626' 4,545' 2020 8.5 Yes OBf 8,074' 4,671' 4,590' 2040 8.5 Yes OBf Base 8,147' 4,721' 4,640' 2050 8.5 No T.D.** 8,257' 4,796' 4,715' ,/' **TD is based on 250' MD below the top OBe marker.** Mud Program 12 %" Surface Hole Mud F1roperties: I Spud - Freshwater Mud Interval Density Funnel vis YP PH FL Initial 8.5- 9.2 250-300 50-70 8.5-9.0 NC-8.0 Base Perm ~ rr- 9.5 >250 30-45 8.5-9.0 8.0 Interval TD /9.E I(max) >250 30-40 8.5-9.0 5.0-7.0 8 3,4" Intermediate Hole Muc:f'-llJroperties: I Freshwater LSND Mud PH: 9.0-9.5 <600 Chlorides Interval Density YP PV API Filtrate MBT 3,941' to 8,258' MD 9.2 20-28 12-18 4-6 <20 Survey and Logging Program 12-%" Hole Section: Surface Gyro will be needed (run to -1200' as conditions dictate) Open Hole: MVVD / GR Cased hole: None 8-3,4" Hole Section: MVVD / GR / Res / Qen / Neu / PWD (All realtime with recorded porosity) Cased Hole: USIT Bond LOQ -7 V-21Oi Permit to Drill Page 2 . . 29' / 29' 109' /109' 9-%" 5,750 3,090 29' / 29' 3,941' / 2,631' 7" 7,240 5,410 29' / 29' 8,258' / 4,796' 4 Y2" 8,430 7,500 29' / 29' 7,596' / 4,346' 3 Y2" 1 0, 160 10,530 7,596' /4,346' 7,920' / 4,566' Cement Calculations: Casin Size: 9-%-in 40-lb/ft l-80 BTC - Single Sta e Basis: lead: 250% e s ver gauge hole in permafrost, 30% excess over gauge hole below permafrost lead TOC: urfa Tail: 1,000' en hole with 30% excess, plus 80' shoe track Tail TOC: 2,941' MD Total Cement Volume: Spacer lead Tail Tem 75 bbls of Viscosified 469 bbls, 2633 cuf 79 bbls, 442 cuft, BHST = 60° F, B 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 Basis: Centralizer Recommendations 9-%" Casing Centralizer Placement a) Run (25) 9-%" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 2,941' MD (1,000' MD above the shoe). b) Run 2 Bow-spring centralizers on either side of the TAM Port Collar (contingency only). c) This centralizer program is subject to change due to actual hole conditions. 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 6,228' MD (600' MD above Ma sand). Zonal isolation with cement is required across the Ma sands. The centralizer program is subject to change pending modeling and hole conditions. V-210i Permit to Drill Page 3 . . Surface and Anti-Collision Issues Suñace Shut-in Wells: V-104 and V-202 will require surface shut-in and wellhouse removal in order to move over well V-210i. V-02 should be evaluated before the rig move as to whether it will require wellhouse removal and shut in for rig move. V-107 and V- 101 should not require well house removal, but should also be evaluated prior to the rig move for any potential interference. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. V-104 12.64-ft 499-ft 4.71-ft Use Travelin V-202 15.51-ft 399-ft 8.60-ft Use Trave/in V-02 24.74-ft 449-ft 17.25-ft Use Travelin V-101 43.23-ft 498-ft 35.31-ft Use Travelin V-107 46.35-ft 449-ft 39.64-ft Use Travelin V-201 46. 66-ft 794-ft 33.16-ft Use Travelin V -108 77.47-ft 249-ft 73.26-ft Use Travelin 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 5,OOOpsi it will not be necessary to have two sets of pipe rams installed at al/ times. BOP regular test frequency for V-21Oi will be 14 days. / Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section · Maximum anticipated BHP: · Maximum suñace pressure: · Planned BOP test pressure: ~,. ., si - Base of Schrader (8.5 ppg@4,640'TVDss) ,58 psi - Based on a full column of gas @ 0.10 psi/ft , 0 psi/250 psi Rams ,./ 2,500 psi/250 psi Annular 4,000 si 1 . P g EMW LOT 20' from 9-5/8" shoe o b s with an 11.7 ppg EMW LOT ,mated 9.0 ppg Brine /6.8 ppg Diesel · 7" Casing Test: · Integrity Test - 8-3/4" hole: · Kick Tolerance: · Planned completion fluid: Disposal · 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-210i Permit to Drill Page 4 .' . DrillinQ Hazards and ContinQencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in the Polygon 2 fault block is expected to be normal pressured at 8.5-8.8 ppg EMW. This pressure is estimated based on offset well pressures and material balance. II. Hydrates and Shallow gas A. Gas Hydrates are present at V-pad and have been encountered in wells as close as V-100 and V-111 and throughout the SV4, SV3, SV2, and SV1. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Both offset wells to V-100 and V-111 had to have the mud treated and were able to drill to section TD. In V-100 the hydrates came from the SV1. Occasionally hydrates are encountered below the SV1. /II. Lost Circulation/Breathing A. Lost circulation is not expected due to the benign nature of the V Pad fault. In addition the fault will be crossed at high angle and move away quickly. . Note: Massive losses were encountered on L pad at L-118 due to high penetration rates (1100-1300 fph) and inadequate hole cleaning strategy. B. We do not expect breathing on this well. IV. Kick Tolerancellntegrity Testing A. The 9-%" casing will be cemented to surface. B. The 7" casing will be cemented with 15.8 Ib/gal tail cement to 600' MD above the Ma sand -6,228' MD. C. The Kick Tolerance for the surface casing is 50 bbls with 9.3 ppg mud, 11.7 ppg LOT, and an 8.8 ppg pore pressure. D. Integrity Testing - 11.7 ppg EMW 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: Adjacent producers at Surface: Adjacent producers at TD: V-02 10 ppm V-102 10 ppm V-101 10 ppm V-106 15 ppm VII. Faults A. One fault is expected to be crossed at V-210i. The 'V-Pad Fault' and has been intersected in the surface hole by most wells drilled from V Pad to date. No losses are expected to be associated with this fault. Details are listed below for reference: Fault 1 (SV3): 3,241' MD 2,311' TVD 2,230' TVDss Throw: 150' West CONSULT THE V PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION V-210i Permit to Drill Page 5 · e, V-210i Drill and Complete Procedure Summar'l Pre-Ria Work: 1. The V-210i conductor has been set. See As-Built. 2. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. 4. Prepare neighboring wells for the rig move and simops production. Shut in V-100 and V-115 and remove well houses as necessary. ~:ia ~:~~~~Ol and tunction test diverte,. PU 4" DP as required and stand back in derrick. 3. MU 12-14" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3,941' MD. Thy- actual surface hole TD will be +/-100' TVD below the top of the SV1 sands. 4. Run and cement the 9-%", 40.0-lb/ft. surface casing back to surface. A TAM Port Collar should be on location. Cement was not circulated to surface on V-103 and V-106 1st stage surfac;Y6ement job. Therefore a port collar will be run in the casing string if hole conditions dictate. / 5. ND diverter spool and NU casing / tubing head. NU BOPE and test to 4,000 psi. / 6. MU 8-%" drilling assembly with MWD/GR/Res/Den/Neu(recorded)/PWD and RIH to float collar. Test th;ß~%" casing to 4,000 psi for 30 minutes. 7. Circulate and condition cement contaminated mud. Displace over to new 9.0 ppg mud 8. Drill new formation to 20' below 9-%" shoe and perform LOT (If a 11.7 ppg EMW is not obtained contact ODE). /. 9. Drill ahead to Polygon 2 Target TD at 8,258' MD, (250' below top OBe marker). / 10. Circulate and condition hole, make a short trip, POOH to run casing. 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-%" annulus. 12. PU DPC guns and RIH w/ -200' of 4.5" Power Jet 5 spf perf guns (total assembly length to be -400') with Schlumberger LWD GR. Tag PBTD. 13. Circ hole over to 9.0 brine. 14. Space out utilizing GR and RA tags in 7" casing. Once spaced out correctly, confirm cement compressive strength ~- is at least 2,000 psi. Perforate OA, OBa, OBb, and OBd. 15. RU Schlumberger E-fine. RIH with gage ring and junk basket to recover any p9Jf debris. Repeat until clean. 16. Run USIT/GR log. USIT will be primary depth con~r 0 future well work. / 17. Run the 4-%" X 3-%", L-80 TCII completion with a "x 3 W' straddle packer assembly and injection mandrels. / 18. Run in the lockdown screws and set the packers. st the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCK shear valve. 19. Install FMC TWC. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 20. Freeze protect the well to -2,500' TVD. Install BPV in tubing hanger. Install a VR plug in the 7"x 4-W' annulu~ valve and secure the well. Assure that IAlOA are both protected with two barriers. 21. Rig down and move off. Post-Ria Work: 1. R/U Sfickline 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. V-210i Permit to Drill Page 6 . . V-210i Detailed Drilling Procedure Job 1: MIRU Critical Issues: ~ Ensure the starting head has been welded on the conductor at the right height and there is adequate space to NU the diverter and subsequently the BOP once the rig is spotted (LL on W-212i). Confirm this requirement prior to the rig moving over the well. Verify that the Diverter does not require any additional spacer spools as well. ~ Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. ~ V-104 and V-202 will have to be shut in and require well house removal before rig can be moved over the well. All surface flowlines and gas lift lines will need to be depressurized to header pressure. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. ~ 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: Adjacent producers at Surface: V-02 10 ppm V-101 10 ppm Adjacent producers at TO: V-102 10 ppm V-10B 15 ppm Reference SOP .:. "Drillingl Work over Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: Drill 12%" Surface Hole Critical Issues: ~ At V-Pad, no significant surface hole drilling problems are present. Tight hole, bridging, and obstructions have been encountered while drilling the Permafrost and particularly at ± 900-1000'. In several wells reaming and tight hole have been present with a few examples of lost circulation while cementing. ~ Close Approach: The V-104 and V-202 are required to be shut in and have their wellhouses removed due to surface location proximity to the V-210i. In addition there are several close tolerance wells in the surface interval. Follow the traveling cylinder I no-go plot per established procedures. A gyro should be run to at least 900'-1200'. ~ Directional: Every effort should be made to ensure a 'smooth' well profile that will benefit torque I drag in the later hole sections and allow for easier 9 5/8" casing running. A graduated build profile is planned. It is preferred that DLS are not pushed ahead of plan on the suñace hole, so as to minimize the chance for hole irregularity or obstructions that could cause problems while running casing. V-210i Permit to Drill Page 7 . . ~ Hole Cleaning: Good hole cleaning practices will be critical to the success of the well. Surface rotary speeds should be maximized wherever possible. The BHA is limited to 60 to 80-rpm while drilling because of the 1.83° motor bend. Vary flowrates 400-650 GPM to achieve the required directional response. However it will be possible at TD to raise the rotary speed to + 1 OO-rpm prior to POOH to run casing. At this time flowrates should be increased to 650 - 700 GPM to increase hole cleaning. Before pulling out of the hole for the final time, make sure that the hole is clean, full returns are observed, and that the pipe pulls without significant overpull. Lost circulation is possible while cementing if these conditions are not satisfied. ~ Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. Consider back-reaming across initial tight spots only if washing does not alleviate the problem. If tight spot is thought to be cuttings, run back in the hole at least the length of the BHA and circulate and condition the hole for a minimum of 30 minutes at max RPM's and GPM's. ~ Critical LWD Tools: It is critical for the landing of this hole section to have the GR to pick the base of the SV1 sand. If this tool fails, it will require an immediate trip out of the hole to replace. It is imperative that the surface casing isolates all of the SV1 sands. Reference RPs: .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations Job 3: Run 9-%11 Surface Casina Critical Issues ~ Casing to bottom: It is imperative the casing is set in the shale below the SV1 sands to ensure wellbore integrity for the intermediate interval. Hydrates are prevalent on V-pad all the way into the SV1. It may be desirable to stop and roll the mud over half way in the hole to break the gels and reduce surging intensity on the SV sands. This will also help to ensure circulation is attained at TD at the desired cementing rates without losses. Make sure that the hole is clean and obstructions are minimized before running casing as higher doglegs and aggressive directional work could make casing running more difficult. ~ Casing drift: 9-%" 40# special drift casing is being used (8.835" ID, 8.75" drift). Ensure that casing equipment is properly drifted to ensure adequate ID for the 8-%" bit: float equipment, casing hanger, TAM Port Collar, etc. ~ Cement to surface: A single-stage job will be done on this well using 250% excess in the permafrost and 30% excess below the permafrost. A TAM Port collar should be placed at 1,000-ft MD as a contingency, if hole conditions warrant. Several V-pad wells with similar directional plans and in this quadrant have required secondary cementing on surface due to losses during the primary job. ~ Losses during cement job: At V-Pad lost circulation has been experienced while running and cementing surface casing on past wells. The expected frac gradient for the shale below the SV1 sands is at least 12.7- Ib/gal EMW. Follow the Schlumberger recommended pumping rates as they have modeled the expected ECD's during the entire cement job to help mitigate the potential for breaking down the formations. Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar Procedure" V-210i Permit to Drill Page 8 . . Job 4: Drill 8-%" Intermediate Hole Critical Issues ~ Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period of time across the permeable Schrader Sands. ~ LOT: Perform a LOT (minimum 11.7 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based upon the aX'expected Schrader reservoir pressure of 8.8 ppg and 9.3 ppg mud, a 11.7 ppg leak-off will provid 50 s of kick tolerance. Contact Anchorage personnel if LOT is less than 11.7 ppg. Based upon drilling data on V-Pad, a minimum leak-off of 13 ppg is expected at the 9-%" shoe. ~ Penetration Rate: Penetration rates should not exceed 600 fph instantaneous. This should allow for EGDs not to exceed 0.6ppg above calculated. If EGDs are sustained above this threshold, it is advised that drilling should be stopped and the hole circulated before continuing. EGD should not exceed 11.0 ppg once the M sand has been penetrated. ~ Torque: Use lubricants as per the MI program as necessary. If weight transfer problems are encountered during sliding, attempt to circulate and rotate for a minimum of 2 bottoms up to test if lubricants are truly needed or if the hole is loading up with cuttings. ~ Screen Blinding: Add BDF-263 as per MI mud program while drilling the Ugnu/heavy oil sands. ~ Critical LWD Tools: It is critical to have the GR tool in order to pick the landing points for the intermediate hole sections. As mentioned above in the landing point discussion, the landing of this well depends on picking the base of the OBf and OBd sands using the Gamma Ray. Therefore if the GR tool is lost, a trip will have to be made to change it out. ~ Faults: One fault is expected to be crossed at V-210i. The 'V-Pad Fault' and has been intersected in the surface hole by most wells drilled from V Pad to date. INo losses are expected to be associated with this fault. Details are listed below for reference: Fault 1 (SV3): 3,241 J MD 2,311 J TVD 2,230' TVDss Throw: 150' West ~ 7" casing landing point: The 7/1 casing setting point will be determined by depth based on changes in GR/Res curves associated with the top OBe marker. After seeing the top OBe, TD will be picked based on drilling 250' MD past this marker. This footage is critical for future well work. If tops are coming in 100' or more out from proposed, then conduct a short trip and notify town. A Rigsite Geologist will be required on site to pick casing point. ~ Directional Constraints: It is important to keep the wellbore smooth and the tangent angle close to plan to facilitate casing running and slickline access. It is important to design a BHA to minimize inclination walking tendencies thus minimizing wellbore tortuousity. DLS should be kept as close as possible to ~1 0 over planned. Dogleg will take priority over angle as long as mainbore tangent angle does not approach 68 degrees. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. "ERD Operating Practices" Job 6: Run and Cement 7" Intermediate CasinQ Critical Issues ~ Tight hole, packing off and lost circulation have been experienced while drilling though this interval. Good hole cleaning, mud conditioning, and drilling practices are required for trouble free drilling. In numerous cases tight hole has made backreaming necessary with stuck pipe and lost returns on only two wells. V-210i Permit to Drill Page 9 . . ~ Cement Job: It is imperative to achieve a good cement job on this well to achieve zonal isolation and effective injection control. Therefore reciprocate pipe as long as possible while cementing. A USIT log will be run to confirm the quality of the cement job above the Ma sand. Keep cementing ECD's below 12.5 ppg EMW during the displacement. ~ Freeze Protection: Ensure the lower production cement has reached at least a 500 psi compressive strength prior to freeze protecting. After freeze protecting the 7" x 9-%" casing outer annulus with 72 bbls of dead crude (2,570' MD, 2,200'TVD), the hydrostatic pressure will be 8.0 ppg vs. 8.8 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be over 100 psi underbalance to the open hole. ~ Centralization/Differential Sticking: See centralizer strategy in the Well Plan Summary. Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. ~ RA Tags: There will need to be 2 RA tags placed in the 7" casing for depth control. Placement strategy is: o Pip #1: Top Ma Sand o Pip #2: 40-60' above top OA sand ~ Mud Requirements: Thin the mud as per Ml's Mud Program. The thinner the mud the better displacement is achieved and the better the cement job will be. Extra time spent circulating is warranted to ensure optimum mud properties and hole cleaning prior to the cement job. ~ Franks Casing Fill-up tool: Make sure that a casing fill up tool is on location prior to PU 7" casing. ~ TIW Valve: Ensure that a TIW valve with a cross over to 7" BTC casing is on the rig floor before running casing. Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Freeze Protecting an Outer Annulus" Job 7: DPC Perforate Well Critical Issues ~ Barriers: A wireline BOP with double downward rams should be used in conjunction with a packoff or stuffing box attached to a riser joint for wireline operations. While running DPC guns the well will be contain kill weight fluid and BOPs will be in place. After perforating, up to freeze protecting this will be adequate to provide two barriers. ~ The well will be perforated ±130 psi over-balanced. Ensure all personnel are well briefed on Shlumberger's perforating procedures and that all responsibilities are understood. ~ It should be stressed that while picking up and running the perforating string, only essential personnel should be on the rig floor. Normally "essential personnel" will consist of the driller, floorhands, Schlumberger perforating crew. All other personnel will stay off the rig floor and out of the cellar until the perforating string is at least 100-ft below the rotary table. ~ Contact Schlumberger to prepare for approximately 190' of 4-1/2" Power Jet guns at 5 spf to be run on DP. Exact perforation depths will be provided after reviewing the LWD logs. ~ Be prepared for fluid losses to the formation after perforating. Have ample seawater and brine on location and be prepared with LCM if necessary. Losses are not expected to be severe based on past perforation jobs. It is expected that the formation will take a little drink due to the extra pressure induced by the detonation of the perf guns. V-210i Permit to Drill Page 10 . . > It is planned to utilize LWD GR to correlate to the formation and casing RA tags to position the perforation assembly. The GR tool will be placed above the perforating assembly, the assembly is then RIH past the perf depth, the well will be logged up to correlate DP depth, and then the guns can be brought on depth and fired. The LWD GR tool requires a 150-260 gpm flowrate to establish a signal. Modeling indicates a maximum pressure of 2,400 psi will be seen when pumping @250 gpm. The previous USIT/GR will be used as the primary depth control. Reference RPs .:. "Wireline Pressure Control SOP" .:. "Alaska Wells Group Standard Operating Procedure: Perforating" .:. Follow Schlumberger perforating practices and recommendations Job 8: Run 4-%" Completion Critical Issues > Barriers: o The well will have the OA, OBa, OBb, and OBd production intervals open with an 8.6 ppg EMW formation pressure during completion operations. o Completion will be run with BOPs in place and kill weight fluid for annulus side barriers. Tubing side barriers will be provided via TIW and kill weight fluid. o Once packers are set the annulus above the packer will be tested to 4,000 psi to verify packer/annulus integrity. Kill weight fluid and the tubing hanger provide additional annulus side barriers. At this point the ball and rod with kill weight fluid and a TIW valve comprise the tubing side barriers. o Since it is not feasible to test the lower packer/annulus integrity, when the DCK valve is sheared a casing annulus valve must be in place along with kill weight fluid to provide sufficient annular barriers. Tubing side barriers are still kill weight fluid on ball and rod and a TIW. o A TWC will be installed and tested from above to 1,000 psi for 30 minutes prior to nippling down the BOP's. With the DCK valve sheared the TWC in addition to kill weight fluid provide the tubing side barrier. The annular side is provided by a casing annulus valve and kill weight fluid. With the TWC in place BOPs can be nippled down and the tree nippled up. o With the tree nippled up freeze protecting removes the kill weight fluid as a barrier. We then count on the tree for tubing side barriers, and two casing annulus valves for annulus side protection. o Before rigging down a BPV tested from below to 1,000 psi will be left in the tubing hanger to provide an additional tubing side barrier once the rig is off. Since the DCK valve is still open it will be necessary to leave one casing annulus valve and a VR plug for annular barriers. Make sure that a lubricator is used to install the VR plug while both casing annulus valves are still in place. > Thread Dope: Jet Lube is the BP approved thread compound for Premium Carbon API connections. All TCII pipe should arrive on location with Jet Lube thread compound. It would still be good practice to look over each connection in the pipe shed prior to incorporating them into the tally. > Torque Turn: Injectors will be used for MI injection and therefore must have all connections torque turned and charted to help reduce risk of leaks. ~ Shear Valve: We will be using a DCK-2 shear valve due to the RP shear valve failure on numerous wells. The DCK-2 shear valve has had good success due to the locking mechanism that keeps the sleeve from migrating back down over the ports after the tool is sheared open. This valve does require a higher differential pressure to open. ~ Injection Mandrels: Remove the check valves from the MMGW waterflood mandrels. This will allow us the flexibility to circulate between mandrels and clean up the tubing/casing annulus later in the well life. V-210i Permit to Drill Page 11 . . Reference RPs .:. "Completion Design and Running" RP .:. "Tubing Connections" RP Job 9: ND/NU/Release Ria Critical Issues > See Job 1 for adjacent well spacing. Identify hazards in a pre-move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. > Diesel: Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RPs .:. "Freeze Protecting an Inner Annulus" RP V-21Oi Permit to Drill Page 12 bp o V-210 (P5) Proposal Schlumberger Report Date: October 13, 2004 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA StnIcture/ Slot: V-Pad / Plan V-210 (N-G) -I-ty stu Well: Plan V-210 (N-G) F sib. I Borehole: Plan V-210 .. UWUAP.: 50029 Survey Neme / Date: V-210 (P5) / October 13. 2004 Tort/AHD/DDI/ERDrallo: 78,641°/6189.24 fI/5,923/1,290 Grid Coordinate System: NAD27 Alaska Stale Planes, Zone 04, US Feet Location LatILong: N 70.32796881, W 149.26629539 Location Grid HIE Y/x: N 5970069,620 flUS, E 590468.210 flUS Grid Convvgence Angle: -I(),69088622° Grid Scele FICIor: 0.99990930 SlHvey / DLS Computation Method: Minimum Curvature / Lubinski Vertical SeetJon AzlmutI1: 350,980° Vertical SeetJon OrIgIn: N 0.000 II. E 0,000 fI TVD Reference Dllum: Rofaly Table TVD Reference EllVIIIon: 81.10 fI relative to MSL Sea Bed / Ground Level Elevetfon: 52.60 fI relative to MSL Magnetic DectInatIon: 24.723° Total Field Strength: 57594,679 nT Magnetic DIp: 80.799° Dectlnallon Date: November 07, 2004 Magnellc Dectlnallon 1IodeI: BGGM 2004 North Reference: True North Total Corr Mag North .) True North: +24.723° Local CoordInates Referenced To: Well Head . 700.00 12.00 351.26 616.39 697.49 36.52 36,52 36,10 -5.55 3.50 0.000 3,50 0.00 5970105.64 590462.23 N 70.32806742 W 149.26634039 800,00 15.50 351.26 713.51 794.61 60.28 60.29 59.59 -9.16 3,50 O.OOG 3.50 0.00 5970129.09 590458.33 N 70.32813159 W 149.26636968 900.00 19.00 351.26 809.00 890.10 89.93 89.94 88.89 -13.67 3.50 O,ooG 3.50 0.00 5970158.33 590453.47 N 70,32821165 W 149.26640621 975.72 21,65 351.26 880.00 961.10 116.23 116.23 114.89 -17.66 3,50 O.DOG 3.50 0.00 5970184.27 590449.16 N 70.32828267 W 149.26643862 1000.00 22,50 351.26 902.50 983.60 125.36 125,36 123,90 -19.05 3.50 O.OOG 3.50 0.00 5970193.27 590447.67 N 70.32830730 W 149.26644987 1100.00 26.00 351.26 993,66 1074.76 166.42 166.42 164,49 -25.29 3,50 O.ooG 3.50 0.00 5970233.78 590440.94 N 70.32841819 W 149.26650047 1200.00 29.50 351.26 1082.14 1163.24 212.98 212.98 210.51 -32.36 3.50 O.OOG 3.50 0.00 5970279,70 590433.31 N 70.32854389 W 149.26655784 1300.00 33.00 351,26 1167.62 1248.72 264.84 264,85 261.77 -40.25 3.50 O.ooG 3.50 0.00 5970330.86 590424.81 N 70.32868395 W 149.2666_ 1400.00 36.50 351.26 1249,77 1330.87 321.83 321.84 318.10 -48.91 3.50 O,ooG 3.50 0.00 5970387,08 590415.48 N 70,32883783 W 149.2666 1500.00 40.00 351.26 1328,29 1409.39 383.73 383.74 379.28 -58.31 3.50 0.000 3.50 0.00 5970448.14 590405.33 N 70.32900498 W 149.2667 1600,00 43.50 351,26 1402.89 1483.99 450.31 450,32 445.09 -68.43 3.50 O.OOG 3,50 0.00 5970513.81 590394.43 N 70.32918475 W 149.26685033 1700.00 47.00 351.26 1473,28 1554.38 521.32 521.32 515.27 -79,22 3.50 O.ooG 3,50 0.00 5970583.85 590382,79 N 70,32937648 W 149.26693784 1800.00 50,50 351.26 1539.20 1620.30 596,49 596.50 589,57 -90.64 3.50 O.ooG 3.50 0.00 5970658.00 590370.47 N 70.32957946 W 149.26703048 1801.25 50.54 351,26 1540.00 1621.10 597.46 597.46 590.53 -90.79 3.50 O.OOG 3.50 0.00 5970658,95 590370.31 N 70,32958207 W 149.26703168 1900,00 54.00 351.26 1600.42 1681.52 675.54 675.55 667.71 -102.66 3.50 O.ooG 3,50 0.00 5970735.98 590357.52 N 70,32979293 W 149,26712792 2000.00 57.50 351,26 1656.69 1737.79 758.19 758.20 749.39 -115,22 3.50 O.ooG 3.50 0,00 5970817,50 590343.98 N 70,33001609 W 149.26722978 2034.66 58.71 351.26 1675.00 1756.10 787.62 787.63 778.48 -119.69 3,50 O.OOG 3.50 0.00 5970846.53 590339.16 N 70.33009555 W 149.26726805 2084.03 60.44 351,26 1700,00 1781.10 830.19 830.20 820.56 -126.16 3,50 O.OOG 3.50 0.00 5970888.52 590332.18 N 70.33021050 W 149.26731852 2100.00 61.00 351.26 1707.81 1788.91 844,12 844.13 834,32 -128.27 3.50 O.ooG 3,50 0,00 5970902.26 590329.90 N 70,33024811 W 149.26733568 2151.34 62.80 351.26 1731.99 1813.09 889.40 889.41 879.08 -135.15 3.50 O.OOG 3.50 0.00 5970946.93 590322.48 N 70.33037038 W 149.26739150 Comments RTE KOP Bid 1.5/100 Bid 3,51100 SV6 SV5 SV4 Base Perm End Bid Well Design Ver 3.1 RT -SP3.03-HF5.oo Bld( d031 rt-546 ) Plan V-21 0 (N-G)\Plan V-210 (N-G)\Plan V-210IV-210 (P5) Generated 10/13/2004 9:09 AM Page 1 of2 Comments SV3 Fault SV2 Faulted Top SV1 9-518" Csg Pt UG4 4411.02 62.80 351.26 2765.00 2846.10 2899.12 2899.15 2865.49 -440.56 0.00 O.OOG 0.00 0.00 5972929.32 589993.18 N 70.33579703 W 149.26986925 UG4A 4498.52 62.80 351.26 2805.00 2886.10 2976.94 2976.98 2942,40 -452.38 0.00 O.OOG 0.00 0.00 5973006.08 589980.43 N 70.33600716 W 149.26996522 UG3 5198.52 62.80 351.26 3125.00 3206.10 3599.50 3599.54 3557.74 -546.99 0.00 O.OOG 0,00 0,00 5973620.18 589878.42 N 70.33768819 W 149.27073305 UG1 6259.44 62.80 351.26 3610.00 3691.10 4543.07 4543.12 4490.36 -690.37 0.00 O.OOG 0.00 0.00 5974550.91 589723.81 N 70.34023599 W 149.27189702 Ma 6828.19 62.80 351.26 3870.00 3951.10 5048.90 5048.96 4990.32 -767.24 0.00 O.OOG 0.00 0.00 5975049.86 589640.93 N 70.34180182 W 149.27252112 Mb1 6915.68 62.80 351.26 3910.00 3991.10 5126.72 5126.78 5067.24 -779.07 0.00 O.OOG 0.00 0.00 5975126.63 589628.18 N 70.34181195 W 149.2726_ Mb2 7057.87 62.80 351.26 3975.00 4056.10 5253, 17 5253.24 5192.23 -798.28 0.00 O.OOG 0.00 0.00 5975251,36 589807.46 N 70.34215341 W 149.2727 Drp 4/100 7207,33 62,80 351.26 4043.33 4124.43 5386.10 5386.16 5323.61 -818.48 0.00 -171.73G 0.00 0,00 5975382.48 589585.68 N 70.34251234 W 149.27293 Me 7210.99 62.65 351.24 4045.00 4126.10 5389.35 5389.41 5326.82 -818.98 ,4.00 -171.72G -3,96 -0,65 5975385.69 589585.14 N 70.34252110 W 149.27294123 7300.00 59,13 350.64 4088.30 4169.40 5467.11 5467.17 5403.61 -831.22 /4.00 -171.43G -3,96 -0.67 5975462.32 589571,98 N 70.34273088 W 149.27304064 Na 7331.97 57.87 350.41 4105.00 4186.10 5494.35 5494.43 5430.50 -835.70 4.00 -171.31G -3.95 -0.70 5975489.14 589567.17 N 70,34280432 W 149.27307706 Nb 7386.73 55.70 350.01 4135,00 4216,10 5540.17 5540.24 5475.64 -843.49 4.00 -171.09G -3.95 -0.73 5975534.19 589558.84 N 70.34292766 W 149.27314029 7400.00 55,18 349.91 4142.53 4223.63 5551,10 5551.17 5486.40 -845.39 4.00 -171,03G -3,95 -0.75 5975544.92 589556.81 N 70.34295705 W 149.27315575 Ne 7455.36 52,99 349.48 4175.00 4256.10 5595.92 5596.00 5530.51 -853.41 4.00 -170.78G -3.95 -0.78 5975588.93 589548.26 N 70.34307756 W 149.27322084 7500.00 51.23 349.11 4202.41 4283.51 5631.13 5631.23 5565,13 -859.95 4.00 -170.56G -3.95 -0.82 5975623.46 589541.30 N 70,34317211 W 149,27327395 OA 7596,06 47.44 348.26 4265.00 4346.10 5703.92 5704.08 5636.56 -874.23 4.00 -170.00G -3.94 -0.89 5975694.71 589526.17 N 70.34336727 W 149.27338987 7600,00 47,29 348.22 4267.67 4348.77 5706.82 5706.97 5639.40 -874.82 4.00 -169,97G -3.94 -0.95 5975697.54 589525.54 N 70.34337502 W 149.27339466 End Drp / Target 1 7603.43 47.15 348.19 4270,00 4351.10 5709.33 5709.49 5641,87 -875.33 4.00 O.OOG -3.94 -0.95 5975700.00 589525.00 N 70.34338176 W 149.27339885 OBa 7699.01 47.15 348.19 4335.00 4416.10 5779.32 5779,57 5710.46 -889.67 0.00 O.OOG 0.00 0.00 5975768.40 589509.83 N 70.34356913 W 149.27351531 OBb 7757.83 47.15 348.19 4375.00 4456.10 5822.39 5822.69 5752.66 -898.50 0,00 O.OOG 0,00 0.00 5975810.50 589500.50 N 70.34368444 W 149.27358697 OBe 7838.70 47.15 348.19 4430.00 4511.10 5881.61 5881,98 5810.70 -910.64 0.00 O.OOG 0.00 0.00 5975868,38 589487.66 N 70.34384298 W 149.27368552 Target2 7912.22 47.15 348.19 4480.00 4561.10 5935,45 5935,88 5863.46 -921.67 0.00 O.OOG 0.00 0.00 5975921.00 589476.00 N 70.34398712 W 149.27377511 OBd 7919.57 47.15 348.19 4485,00 4566.10 5940.83 5941.27 5868.74 -922. 77 0.00 O.OOG 0.00 0.00 5975926.26 589474.83 N 70.34400153 W 149.27378407 8007,80 47,15 348.19 4545.00 4626,10 6005.44 6005,95 5932.05 -936.01 0.00 O.OOG 0.00 0.00 5975989.40 589460,83 N 70.34417449 W 149.27389157 OBa 8007.81 47.15 348.19 4545.01 4626.11 6005.45 6005.96 5932.06 -936.01 0.00 O.OOG 0.00 0.00 5975989.41 589480.83 N 70.34417452 W 149.27389159 OBf 8073.97 47.15 348.19 4590.00 4671.10 6053.89 8054.46 5979.53 -945.94 0.00 O.OOG 0.00 0.00 5978036.76 589450.33 N 70.34430421 W 149.273_ OBf Base 8147.49 47.15 348.19 4640.00 4721.10 6107.73 6108.36 8032.29 -956,98 0.00 O.OOG 0.00 0.00 5978089.38 589438.66 N 70.34444834 W 149.274 TD /7" Lnr 8257.80 47.15 348,19 4715,02 4796,12 6188.51 6189.24 6111,45 -973,53 0,00 O.OOG 0,00 0.00 5976168.32 589421.16 N 70.34466459 W 149.2741 Leaal DescrlDtlon: NorthinG (VI rftUS! Eastlna /XI fftUS! Surface 4823 FSL 1833 FElS11 T11N R11E UM 5970069.62 590468.21 Target 1 5185 FSl2703 FEl 52 T11N R11E UM 5975700.00 589525,00 Target 2 126 FSl2749 FEl S35 T12N R11E UM 5975921.00 589476.00 BHl 374 FSl2801 FEl S35 T12N R11E UM 5976168.32 589421.16 Well Design Ver 3.1RT ..sP3.03-HF5.00 Bld( d031rt-546 ) Generated 10/13/20049:09 AM Page 2 of2 Plan V-210 (N-G)\Plan V-210 (N-G)\Plan V-210IV-210 (P5) STRUC11JRE V-Pad WOA FIELD SurfacølooaliDn La! 1'4701940.688: LQfI W149 15 5ßß63 2400 2"''' NoYlm"loor07, 57594.7nT - 's· 00:700' +24.72:)' o (P5) \filEt GrldCoov: +0.60068622' ~F1'!Ct:O.9999092914 1600 800 o o 6400 5600 4800 4000 3200 o 800 1600 800 1600 2400 2400 II Q) -¡¡¡ Q cr;¡ a ~ 3200 3200 4000 4000 4800 6400 5600 4800 o :::0 ::: (fI) 1600 o 4800 V-210 (P5) FIELD Prudhoe Bay Unit - WOA STRUCTURE V-Pad 80.799' +24.723' Sutfacølooafum Dale N!m¡~r 01, 2004 !...at: Nl0 19 40.600 FS 57594-.7nT Lor¡: W149i556$63 597W89.62 ftUS SOO466,21 fiU$ -2400 -1600 -800 o 800 TO 11" tnr 5600 5600 4800 4800 4000 4000 ^ ^ ^ z iE' Õ 0 ~ 3200 3200 §: ~ II <!> ro (,) (f) (f) V V 2400 2400 V 800 1600 1600 800 o Bid 3.51100 KOP Bid 1.51100 RTE o -2400 -1600 -800 0 «< W Scale = 1(in):800(ft) E »> 800 . Schlumberger Anticollision Report . Company: BP Amoco Date: 10/13/2004 Time: 09:04:44 Page: 1 Field: Prudhoe Bay Reference Site: PB V Pad Co-ordinate(NE) Reference: Well: Plan V-210 (N-G), True North Reference WeD: Plan V-210 (N-G) Vertical (TVD) Reference: V-210 Plan N-G 81,1 Reference WeDpath: Plan V-210 Db: Sybase NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 8257.80 ft Scan Method: Trav Cylinder North Maximum Radius: 10000.00 ft Error Suñace: Ellipse + Casing Survey Program for Definitive Wellpath Date: 8/19/2002 Validated: No Venlon: 5 Planned From To Survey Toolcode Tool Name ft ft 28.50 1400.00 Planned: Plan #5 V1 MWD MWD - Standard 29.90 8257.80 Planned: Plan #5 V1 MWD+IFR+MS MWD + IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 3940.72 2631.10 9.625 12.250 9 5/8" 8257.80 4796,12 7.000 8.750 7" Summary < Offset WeDpath > Reference Offset Ctr-Ctr No-Go ADowable Site Well Wellpath MD MD Distance Area Deviation Wa~g ft ft ft ft ft PB V Pad Plan V-112 (S-A) PlanV-112V1 Plan: PI 346.32 350.00 201.65 6.39 195.26 Pass: Major Risk PB V Pad Plan V-203 (N-A) Plan V-203 VO Plan: V 398.87 400.00 91.13 8.47 82.67 Pass: Major Risk PB V Pad Plan V-205 (S-P) Plan V-205 V2 Plan: PI 346.61 350.00 251.25 6.45 244.81 Pass: Major Risk PB V Pad Plan V-206 (S-S) Plan V-206 V1 Plan: PI 346.66 350.00 284.50 6.45 278.05 Pass: Major Risk PB V Pad Plan V-211 (N-C) Plan V-211 V2 Plan: PI 400.05 400.00 60.86 6.99 53.87 Pass: Major Risk PB V Pad Plan V-212 (S-D) Plan V-212 VO Plan: V 394.54 400.00 186.48 8.53 177.94 Pass: Major Risk PB V Pad Plan V-214 (N-R) Plan V-214 V3 Plan: V 598.23 600.00 205.45 11.21 194.24 Pass: Major Risk PB V Pad Plan V-2a06 (N-M) Plan V-2a06 VO Plan: V 998.34 1000,00 133.90 24.03 109.87 Pass: Major Risk PB V Pad Plan V-3a06 (S-U) Plan V-3a06 V1 Plan: P 395.23 400.00 308.84 8.49 300.35 Pass: Major Risk PB V Pad V-01 V-01 V15 248.60 250.00 231.32 4.34 226.97 Pass: Major Risk PB V Pad V-02 V-02 V12 449.29 450.00 24.74 7.49 17.25 Pass: Major Risk PB V Pad V-03 V-03 V7 601.29 600.00 284.68 9.57 275.11 Pass: Major Risk PB V Pad V-100 V-100 V7 345,64 350.00 320.89 5.69 315.20 Pass: Major Risk PB V Pad V-101 V-101 V7 498.43 500.00 43.23 7.92 35.31 Pass: Major Risk PB V Pad V-102 V-102 V5 746.82 750.00 72.52 14.17 58.36 Pass: Major Risk PB V Pad V-103 V-103 V6 703.39 700.00 219.49 12.18 207.31 Pass: Major Risk PB V Pad V-104 V-104 V13 498.71 500.00 12.64 7.92 4.71 Pass: Major Risk PB V Pad V-105 V-105 V13 548.25 550.00 146.47 9.03 137.44 Pass: Major Risk PB V Pad V-106 Plan V-106A V6 Plan: P 748.95 750.00 196.58 13.12 183.46 Pass: Major Risk PB V Pad V-106 Plan V-106APB1 V4 Plan 748.95 750.00 196.58 13.12 183.46 Pass: Major Risk PB V Pad V-106 V-106 V10 845.70 850.00 189.88 14.50 175.38 Pass: Major Risk PB V Pad V-107 V-107 V5 448.63 450.00 46.35 6.71 39.64 Pass: Major Risk PB V Pad V-108 V-108 V7 248.78 250.00 77.47 4.21 73.26 Pass: Major Risk PB V Pad V-109 V-109 V2 395.25 400.00 183.38 6.64 176.75 Pass: Major Risk PB V Pad V-109 V-109PB1 V5 395.25 400.00 183.38 6.64 176.75 Pass: Major Risk PB V Pad V-109 V-109PB2 V2 395.25 400.00 183.38 6.64 176.75 Pass: Major Risk PB V Pad V-111 V-111 V25 550.90 550.00 256.14 9.94 246,19 Pass: Major Risk PB V Pad V-111 V-111PB1 V8 550,90 550.00 256.14 9.94 246.19 Pass: Major Risk PB V Pad V-111 V-111PB2V2 550.90 550.00 256.14 9.94 246.19 Pass: Major Risk PB V Pad V-111 V-111PB3 V6 550.90 550.00 256.14 9.94 246.19 Pass: Major Risk PB V Pad V-113 V-113V6 346.83 350.00 189.76 5.22 184.54 Pass: Major Risk PB V Pad V-114 V-114 V5 299.29 300.00 181.78 4.94 176.84 Pass: Major Risk PB V Pad V-114 V-114A V4 299.29 300.00 181.78 4.94 176.84 Pass: Major Risk PB V Pad V-114 V-114APB1 V4 299.29 300.00 181.78 4.94 176.84 Pass: Major Risk PB V Pad V-114 V-114APB2 V2 299.29 300.00 181.78 4.94 176.84 Pass: Major Risk PB V Pad V-115 V-115 V5 298.09 300.00 346.78 4.89 341.88 Pass: Major Risk PB V Pad V-115 V-115PB1 V4 298,09 300.00 346.77 4.89 341.88 Pass: Major Risk PB V Pad V-117 V-117 V9 345.41 350.00 296.26 5.86 290.41 Pass: Major Risk PB V Pad V-117 V-117PB1 V6 345.41 350.00 296.26 5,86 290.41 Pass: Major Risk PB V Pad V-117 V-117PB2 V6 345.41 350.00 296.26 5.86 290.41 Pass: Major Risk PB V Pad V-119 V-119V13 394.92 400.00 180.62 6.75 173.87 Pass: Major Risk PB V Pad V-120 V-120 V5 298.98 300.00 294.93 5.21 289.72 Pass: Major Risk PB V Pad V-201 V-201 V8 793.85 800.00 46.66 13.50 33.16 Pass: Major Risk . . Schlumberger Anticollision Report Company: BP Amoco Date: 10/13/2004 Time: 09:04:44 Page: 2 Field: Prudhoe Bay Reference Site: PB V Pad Co-ordinate(NE) Reference: Well: Plan V-210 (N-G), True North Reference WeB: Plan V-210 (N-G) Vertical (TVD) Reference: V-210 Plan N-G 81.1 Reference WeBpath: Plan V-210 Db: Sybase Summary < Offset WeBpath > Reference Offset Ct....Ctr No-Go ADowable Site WeB WeBpath MD MD Distance Area Deviation W~ ft ft ft ft ft PB V Pad V-202 V-202 V9 398.66 400.00 15.51 6.95 8.55 Pass: Major Risk PB V Pad V-202 V-202l1 V5 398.66 400.00 15,51 6.91 8.60 Pass: Major Risk PB V Pad V-202 V-202l2 V5 398.66 400.00 15,51 6.91 8.60 Pass: Major Risk PB V Pad V-204 V-204 V2 622.57 650,00 159.73 10.66 149.07 Pass: Major Risk PB V Pad V-204 V-204l1 V2 622.57 650.00 159.73 10.66 149.07 Pass: Major Risk PB V Pad V-204 V-204l1PB1 V6 622,57 650.00 159.73 10.66 149.07 Pass: Major Risk PB V Pad V-204 V-204l2 V2 622.57 650.00 159.73 10.66 149.07 Pass: Major Risk PB V Pad V-204 V-204l2PB1 V5 622.57 650.00 159.73 10.66 149.07 Pass: Major Risk PB V Pad V-204 V-204l3 V3 622.57 650.00 159.73 10.66 149.07 Pass: Major Risk PB V Pad V-204 V-204PB1 V9 622.57 650.00 159.73 10.66 149.07 Pass: Major Risk PB V Pad V-204 V-204PB2 V2 622.57 650.00 159.73 10.66 149.07 Pass: Major Risk PB V Pad V-213 V-213 V5 672.58 700.00 322.42 11,83 310.58 Pass: Major Risk PB V Pad V-213 V-213PB1 V5 672.58 700.00 322.42 11.83 310.58 Pass: Major Risk PB V Pad V-216 V-216 V8 249.47 250.00 236.91 4.47 232,43 Pass: Major Risk Field: Prudhoe Bay Site: PB V Pad Well: Plan V-210 (N-G) Wellpath: Plan V-210 94 . 200 100 27 V.o3 (V.o3) 100 . 200 94 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [100ft/in] · Site: PB V Pad Drilling Target Conf.: 95% Description: Map Northing: 5975700.00 ft Map Easting : 589525.00 ft Latitude: 70020'36.174N Shape: Circle Target: V- 210 OA Tgt 1 .ell: Plan V-210 (N-G) Based on: Planned Program Vertical Depth: 4270.00 ft below Mean Sea Level Local +N/-S: 5641.86 ft Local +E/-W: -875.33 ft Longitude: 149°16'24.236W Radius: 150 ft 000 5900 5800 I / 5100 5500 5500 54-00 0 CJ CJ CJ CJ CJ CJ o 0 CJ CJ CJ CJ CJ CJ o 0 ~ CJ 0- m I LD Ln o 0 J J I I I I I o ~ J N J J · .ell: Plan V-21O (N-G) Based on: Planned Program Vertical Depth: 4480.00 ft below Mean Sea Level Local +N/-S: 5863.45 ft Local +E/-W: -921.66 ft Longitude: 149°16'25.590W Radius: 150 ft Target: V- 210 OBd Tgt 2 Site: PB V Pad Drilling Target Conf.: 95% Description: Map Northing: 5975921.00 ft Map Easting : 589476.00 ft Latitude: 70020'38.354N Shape: Circle 200 o o 0 o 0 ( o 0 ~ J o ~ J J J J CJ CJ CJ CJ CJ CJ CJ 0- I 5100 5000 I / 5900 5800 5100 5500 CJ CJ CO I CJ CJ I I CJ CJ LO I c--------------- . II E 5,172 I I I I 1 I 1 I I I I I I GRID 15'00'00"( PLAN T · V-118 · V-03 · V-ll0 · V-lll · V-l03 · V-l06 · V-l05i · SLOT N-M o '" '" ò · V-102 · V- 201 · V-107 v_:::~î· ;~~ / V-10l V-211i V-108 V-203 Z V-PAD --------- I ~Z- I · V-115 · V-2l3i · V-l00 · V-117 · SLOT S-R · V-01 · V-SPARE (SLOT S-L) · SLOT S-J · V-204 · V-114 · V-119 · V-109 · V-1l3 o 10 '" ";1 zl I I I I I I I l \ '\. 10 Sl'INE RO^O --- --- NOTES 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. ,I j., /. '., '/ ~ ·~''-':..,2.ti .:\~ ~ '... . ,Vµ . '... ·\tr~:~:,\,'~t B2; '0 ~> \TifN '. .'_ 0" ~'}.: "., -i·: Í' ;-, .: :~ ':\~.: ~ VICINITY MAP N.T.S. LEGEND -+- AS-BUILT CONDUCTOR . EXISTING CONDUCTOR 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 JULY 18, 2004. LOCATED WITHIN PROTRACTED SEC. 11, T. 11 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINA TES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS V-203 Y=5,970,046.49 N=10,180.05 70'19' 40.471" 70.32799086' 52.7' 4,801' FSL X= 590,380.87 E= 4,629.84 149'16'01.221" 149.2670058' 1,920' FEL V-21Oi Y=5,970,069.62 N=10,179.79 70'19'40.688" 70.3279689' 52.6' 4,823' FSL X= 590,468.21 E= 4,720.20 149'15'58.663" 149.2662953' 1,833' FEL V-211i Y=5,970,054.32 N=10,180.08 70'19'40.544" 70.3279289' 52.4' 4,809' FSL X= 590,410.00 E= 4,660.00 149'16'00.368" 149.2667689' 1,891' FEL V-SPARE Y= 5,970,061.76 N=10,179.73 70'19' 40.614" 70.3279483' 53.1' 4,816' FSL (SLOT N-E) X= 590,439.13 E= 4,690.07 149'15'59.515" 149.2665319' 1,862' FEL _. ----~.-¥_-_._- -----. -..-..-. _. -- .. RE\o1S1ON F. RObelt rmm iillill "" ¡ ~[]J[~o K~ MlO BY 0iK (tON(ÐtS N«J UIoNO SIIM:'IOtS _OJII(ST~lJWII[ ~Al.A$I(A~1 ORA'^"'-!: HACKLEMAN CHECKED: ONEIL O"TE: ' 7/22/01; , ORAWlNG: FRB04 WOV 07-00 J08 NO: SCALE: 1--150' ObP GREATER PRUDHOE BAY V-PAD AS-BUILT WELL CONDUCTORS V-203, V-210i, V-211i ond V-SPARE (SLOT N-E) SHEET: 1 Of 1 V-210i Pro osed Com TREE: FMC 4-1/16" 5M WELLHEAD: FMC Gen 5 System 11", 5M csg.head wI 7" mandrel hanger & packott 11"x 11", 5M, tbg spool wI 11" x 4-112" tubing hanger 11" X 4-1116" Adaptor Flange Cellar Elevation = 52.6' Nahan; 9ES RKB = 81.1' 9-5/8", 40 #/ft, L-80, BTC 13,941' I 7" Short Joint & RA Tag Top Ma sand (6,828') 4-1/2" X 3-1/2" TCII X 7" Short Joint & RA Tag- Above Top OA (7,596') RA Tag in 31/2" 4-1/2", 12.6 Ibltt, L-80, TCII Drift 110: 3.833"/3.958" 3-1/2", 9.3 Ib/ft, L-80, TCII Drift 110: 2.867"/2.992" Date 10/11/04 Rev By TomS 83/4", TD (Injector Mainbore) I 8,257' MD Comments Proposed Completion 20" X 34" 215.5Ib/ft, A53 ERW Insulated 114' 4-112" 'X' Landing Nipple with 3.813" seal bore. 1 2,500' TVD I Cameo gas lift mandrel 4-112" x 1" KBG2 With DCK Shear Valve pinned to 2,500 4-1/2"'X' Landing Nipple with 3.813" seal bore. 7" x 3-1/2" Baker 'PRM' Production Packer / 3-1/2" 'X' Landing Nipple with 2.813" seal bore. 2 Jts. above 41/2'" x-nipple amco 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' Landing Nipple with 2.813" seal bore. Cameo 3-1/2" x 1-1/2" MMG-W GLM OBa & OBb sand Perfs: TBD 3-1/2" 'X' Landing Nipple with 2.813" seal bore. / 7" x 3-1/2" Baker 'PRM' Production Packer / 3-1/2" 'X' Landing Nipple with 2.813" seal bore. Cameo 3-1/2" x 1-1/2" MMG-W GLM OBc sand Perfs: TBD 3-1/2" 'X' Landing Nipple with 2.813" seal bore. 7" x 3-1/2" Baker 'S-3' Production Packer 3-1/2" 'X' Landing Nipple with 2.813" seal bore. 3-1/2" WireLine Entry Guide (-50' above the top OBd perf) Bd sand Perfs: TBD 7", PBTD I 8,175' MD I 7", 26 #/ft, L80, BTC-Mod I 8,257' MD I WELL: V-210i API NO: . . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME fltA ~ !/-2/o¡ , PTD# 2CJ~--2-/ò Exploration Stratigraphic x Development Service CHECK WßA T ADD-ONS ~'CLUE ". APPLIES (OPTIONS) MULTI Tbe permit is for a new wellboresegment of LATERAL e:xisting weD . Permit No, API No. . (If API number Production.sbould continue to be reported as last two. (2) digits a function ·of tbe original API Dumber. stated are between 60-69) above. PILOT HOLE In accordance witb . 20 AAC 25.005(1), all (PH) records, data and logs acquired .for tbe pilot bole must be dearly differentiated ID botb name (name on permit plus PH) .' and API Dumber (50 - 70/80) from records, data and Jogs acquired for we)) (name on permit). SPACING Tbe permit is approved su bj ect ·to fuD EXCEPTION ,. compliance witb 20 AAC 2S..055~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:J cep1ion. (CompanY Name) assumes tbe liability of any protest to tbe spaciDg ,exception tbat mey occur. DRY DITCH AU dry ditcb sample sets submiued to tbe SAMPLE Commission must be iD no greater 1ban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and ] 0' sample iIiter:vals tbrough target zones. .' Field & Pool PRUDHOE BAY, ORION SCHR BL OIL - 640135 Well Name: PRUDHOE BAY UN ORIN V-21Oi Program SER Well bore seg 0 PTD#: 2042100 Company BP EXPLORATION (ALASKA) INC Initial ClassfType SER 11WINJ GeoArea Unit On/Off Shore On Annular Disposal 0 Administration 1 Permittee attache.d_ _ _ Yes. _ _ . . . _ _ _. _...... _ _ _ _ . . _ . _ _ 2 _Lease _number appropriate Xes _ _ _ _ _ . . . . . _ _ _ . . . _ . . _ . _ . . . _ _ . . . . . . _ _ . _ . _ _ _ _ . . _ . _ _ _ 3 _U_nlque weltnarne_a!ld Ol!mb.er _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . _ _ . _ _ _ _ _ _ _ _ _ _ . _Yes _ _ _ _ _ _ _ . . _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ . _ _ . _ _ _ _ _ _ . _ _ . . . _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ . . _ 4 WellJQcated in_a_define.d'pool . . . _ _ . _ _ . . Yes. . . . . . . _ _ . . . . . . . .. _ . . . . . _ . _ _ _ _ _ . . . . . . . . . . 5 WelUQcated proper _dlstance_ from driJling unitb9und_ary _ . . . . Yes _ _ _ _ _ _ _ _ . . . . _ _ . _ . . . . . . . _ . _ _ _ . . . _ . _ _ _ _ . _ _ . . . . . . . _ _ . . _ _ _ _ 6 WelUQcated pr.oper _dlstance_ from Qther welJs . . . _ _ _ . . . . . . . . . . . _ Xes _ . _ _ . . . . _ . _ . . . _ _ _ _ . _ . . . . . . . . . _ _ _ _ . _ . . _ . _ _ _ _ . _ _ . . . . . . _ . . 7 _S_ufficient acrea9.e_ayailable lndrilJiog l!njt. _ _ _ . . Yes . _ . . . . . _ . . _ _ _ . _ . . . . . _ _ _ _ . . . . . . _ . . . _ . . . _ . _ _ _ _ . _ ..... _ _ . . _ _ _ . _ . 8 Jtdeviated,.is weJlbQre platincJu_ded . . _ . . _ _ . . . . . Yes _ _ . . . . . . . . . . . . . . . _ . . . . . . . . _ . _ _ _ _ _ . . _ _ _ _ 9 .O.perator onl~ affected party _ _ _ _ _ _ _ . . . _ . . . . . . . . . . . . . . . . _ _ . Yes. _ _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ _ . _ . . _ _ . . _ _ . _ _ _ . . . . . . . . _ 10 _O'p~H_ator has_appropriate. Qond lnJQrce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ . : . _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ . . . . _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ . . _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ . . . . _ _ _ _ _ _ _ _ _ . . 11 Permit c_a!l be lSSl!ed wjthQut COMervation order _ _ _ _ . _ . . . _ _ _ . . Yes _ . . . . . . . . _ _ . . . . . . . _ _ . . . . . . _ _ . _ _ _ _ . _ . . _ _ _ _ _ . _ _.... _ . . _ _ _ _ . _ _ Appr Date 12 Permit c_al1 be lSSl!ed wjthQut admioistratille_approvaJ . . . . . _ _ _ . . . . . . Yes _ _ _ _ _ . . _ _ . . . _ _ _ . . _ . . _ _ . . . . _ _ _ . _ _ _ _ _ _ _ . . . . . . . . _ _ _ _ _ ...... RPC 10/21/2004 13 Can permit be approved before 15-day wait Yes . 14 WelUQcated wlthio area and strata authorlzed by_ll1jectioo Order # (puUOtI inc_omm.el1tsHFor Yes _ _ _ _ _ _ . .A.1024; V-202_ISTHEQNLYWELLWITHlN THE .A.OFLRPC 15 .AJI welJs.witþtnJl4JDile_area_of reyiew jdel1tified (For servjcewell onl~L _ _ . _ _ . _ . . _ _ _ _ _ Yes _ . . . _ _ _ _ _ _ _ . _ _ . . _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . _ _ _ _ _ _ _ _ _ . _ . _ . _ _ _ _ _ _ 16 Pre-produçed i!ljector; .duratiQn_of pre-.pro.ductioo less_ than_ 3. months (Forservtce well QnJy) _ .NA . _ . _ _ . . . . . . . _ _ _ _ _ _ _ _ _ _ . _ . . . _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ 17 _AÇMPJ=indjngof CQnsi.ste!lcy.h_as bee_nJssued_ forJhis project . . . _ . . . . . . . NA _ _ _ _ _ . . . _ . . . _ . . . . . _ . _ _ _ . . _ . . . _ _ . _ _ _ _ _ _ _ _ . . . . . _ _ _ _ _ _ _ _C9l1ductor stringprQvided _ _ . . . _ _ . _ _ _ _ . . _ _ . _ _ _ _....... .Yes _ _ _ . . . .20" ><-34"_@109'. . . . . . _ . . . _ _ _ _ _ _ _ . . . . _ . . S_urfacecasiog.pJQtec.ts alLknown_ USDWs _ . _ _ _ _ . . . . . . . . . . _ Yes _ _ _ _ . . . . . _ _ _ _ . . . _ . . . _ _ _ . . . . _ _ _ _ _ _ _ _ . . . . . . . . _ _ _ _ _ _ _ _ . . . . . . _ _ _ _ _ . _ . _ . . . . . _ . _CMT. vol adeQu_ateJo circ_ulate_on _cond_uctor. 8. sUJfcsg _ . . _ _ . _ _ . . . . . . . . . _ _ Xes _ _ _ _ . _ . .A.de~uate excess, . _ . _ . . _ . . _ . _ _ _ _ _ . . . _ . . . _ _ _ _ _ . _ _ . _ _ . . . .. . _ _ _ _ _ _ . . . _ _ _CMT. v_ol adeQuateJo tie-tnJQng _stri!lg to.surf çsg_ _ _ . . . . . . . No_ _ _ _ _ _ . . . . . . . _ . . _ _ _ . _ _ . . . . _ . _ _ . . . . . . . . . _ _ _ _ _ _ _ . _ . _ . . . . . _ _ _ _ _ _ _ . . . . _ _ . CMT.will coyer_aU koown_pro_ductiye hQrizQns_ . . _ . . _ _ _ _ _ . . . . _ . . _ _ _ . . Yes _ _ . _ _ _ _ _ _ . . . . . . _ _ _ _ _ . . _ . . . . . _ _ _ _ _ _ _ _ . _ _ . _ _ . . _ _ . .C.asil1g de_sigl1s adequa_te for C,T~ B&perruafr9st _ _ _ . . . . _ . . _ _ _ . . Yes _ _ _ _ _ _ _ . . . _ . . _ _ _ ... _ . . . _ _ .. _ . . . _ . . . _ _ _ . _ . _ _ . _ _ . . . . . . . . _ _ _ _ _ A.dequatetankage_oJ re_serve pit. . _. _ _ _ . _ _ _ . . . _ _ . _ . _ _ . . . _ _ . . . . . . . Yes _ . f'oIab9rs9ES. . . _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ _ . . _ . . . _ _ _ _ _ _ _ _ . _ . _ _ _ _ . _ _ _ . . . _ _ . JtaJe-.drilt has_a to-403 fQr abandon.ment beel1 apPJQved . . . . . . _ . _ . . . . . . . _NA _ _ _ _ . . . f'oIew welt _ _ _ _ . . . _ _ _ . _ _ _ _ . . . . . . . . _ _ _ _ _ _ _ _ _ _ . . . . . _ _ _ _ _ _ . . . . . . _ A.dequatewellbore separatjo.n-Pfo'pose~:L . . . _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ Yes _ . . _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ . _ . . _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ . _ . . _ _ _ _ _ _ _ _ _ _ _ . . . . _ _ _ _ _ _ _ Jtdjvecter reCLuired, dQes jtmeet reguJatioos_ _ _ . _ _ _ _ _ _ _ . . _ Yes _ _ _ _ _ _ . . . . . . . _ _ _ . . _ _ . . _ . . . . _ _ . _ _ _ _ _ . _ _ . _ . _ _ _ _ _ _ _ . _ . . . . . _ _ . _ _ _DrilJil1g fJujd_prQgram sc.hematic& eCLuipJistadequate_ _ _ . _ . . . . . . . _ _ _ . _ _ _ _ . . Yes _ _ _ _ . . Max MW.9J:i ppg. _ _ . . . _ . _ _ _ _ _ _ _ _ _ _ _BOPEs, do they meetreguJatioo . . . . _ . _ _ _ _ . . . . . _ _ . . . _ _ _ _ _ _ _ . . . . . . _ Yes _ _ _ _ _ . . . _ . _ _ _ . . . . . . _ _ _ _ . . _ . . _ _ _ . _ _ _ _ _ . _ _ . . . . . _ _ _ _ _ _ . . . . _ _ _ . . _ BOPE_press ra_til1g appropriate; test to (pu_t psig in_commeots)_ . _ . . Yes . _ _ _ . _ Test to AOOO_ psi. _MSF' 15.86 psi.. _ . _ . . _ . . . . _ _ _ . . . . _ _ _ . _ _ _ . _ . . _ _ . . . . _ . . _ . _ _ _ . .CMke.ruanjfold cQmpJies w/APtRF'-53. (May 64)_ _ _ _ _ _ _ _ . . . . . . _ _ _ . . _ _ _ _ _ _ . . . Yes _ _ _ _ _ _ . . _ _ . . . . _ _ _ . . _ _ . _ _ _ _ _ _ . . . . . . _ _ _ . _ _ _ _ _ _ _ . . . . . . _ _ . . _ _ _ WQrk wiU occ_ur withoytoperatjonshl!tdQwn_ _ _ _ _ . . . Yes _ . . . _ . _ . _ . . . _ . _ _ . _ . . . _ _ _ . _ _ _ _ _ . . . . . _ . _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . . . . . . . Js presence_ Qf H2S 9as_ prob_able. . . . . . _ . _ _ _ _ _ _ . . . . . . No _ _ _ _ _ _ . f'oIQtal1 H2S pad. . . . _ _ _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ _ . . _ _ _ _ _ _ MechanicaLcoodJUo!l of wells wlthin .A.OR verified (for.s_ervice welJ onJy) _ . . _ . . . _ _ . . _ _ . Xes _ _ . _ _ _ _ Cmtn9 recor.ds lndiÇé!te rnech.a!lical jnie.grity _of.A.QR well. . _ _ _ _ . _ 18 19 20 21 22 23 24 25 26 27 Date 28 10/25/2004 29 30 31 32 33 34 Engineering Appr WGA Appr RPC 35 36 Date 37 10/21/2004 38 39 Geology Geologic Commissioner: DìJ' . Pel11Jit cal1 be issu.ed wlQ hydrogen_ s_ulfide l)1eas~res . . . . _ _ . _ _ _ _ _ _ . _ . . . . . _ _ _ Xes _ _ _ _ _ . . _ . . . . . . . . . _ _ _ _ _ _D_ata_preseoted Qn_ pote_ntial oveJpresSure _zones _ _ _ _ _ . . . . _ . . _ _ _ _ _ _ . _ _NA _ _ _ _ Sei.smicanalys.is_ Qf shaJlow gas.zooes_ _ _ _ . . _ . . . _ . . . . _ _ . _ . . . . . _ _ _ _NA _ . . . _ . _ _ _ _ _ _ _Seabedcondjtioo su.rvey(if off-shore) . . . . _ _ _ . _ _ _ . . . _NA _ _ _ _ CQnta_ct namelpÞoneJor_weekly progress reports [exploratory 9!lly] _ . . _ _ _ _ .NA _ . _ _ _ _ _ _ _ . . . . . _ _ _ _ _ _ . . . _ _ _ _ ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Date: Engineering Commissioner: Date Public cJ:;ooe, Date /0/ <s /4,..; /~~