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Home My WebLink About204-251MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, May 14, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Y-06A PRUDHOE BAY UNIT Y-06A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/14/2025 Y-06A 50-029-20431-01-00 204-251-0 W SPT 8325 2042510 2081 576 576 577 577 284 465 484 498 4YRTST P Brian Bixby 4/10/2025 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 UNIT Y-06A Inspection Date: Tubing OA Packer Depth 222 2345 2297 2285IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB250411042917 BBL Pumped:5.7 BBL Returned:5.1 Wednesday, May 14, 2025 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.05.14 11:11:11 -08'00' MEMORANDUM TO: Jim ReggO�q °5(61I'LOZ I P.I. Supervisor FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 5, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC Y -06A PRUDHOE BAY UNIT Y -06A Sre: Inspector Reviewed By: P.I. Sup" Zliz Comm Well Name PRUDHOE BAY UNIT Y -06A API Well Number 50-029-20431-01-00 Inspector Name: Bob Noble Permit Number: 204-251-0 Inspection Date: 4/17/2021 Insp Num: mitRCN210420095631 Rel Insp Num: Wednesday, May 5, 2021 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min -- Well - Y -06A 'IType --- Inj w TVD s3 -'S Tubing 731 732 - 732 731 I PTD 1 2042510 -Type Test , SP'I Test psi -041 IA 125 2361 - 2311 2298 - - BBL Pumped: 5.5 BBL Returned: OA -- - 127 - 156 171 -- Interval 4YRrsr P/F Notes: Wednesday, May 5, 2021 Page I of I • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 4-1 DATE: Wednesday,May 03,2017 P.I.Supervisor �t� 417 SUBJECT: Mechanical Integrity Tests [ BP EXPLORATION(ALASKA)INC. Y-06A FROM: Matt Herrera PRUDHOE BAY UNIT Y-06A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT Y-06A API Well Number 50-029-20431-01-00 Inspector Name: Matt Herrera Permit Number: 204-251-0 Inspection Date: 4/28/2017 Insp Num: mitMFH170428163506 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Y-06A Type Inj W -1TVD 8221 ' Tubing 602 603 • 603 - 604 PTD 2042510 Type Test SPT Test psi 2055 IA 256 2316 ' 2299 - 2292 • BBL Pumped: 5 — BBL Returned: 5 - OA 26 77 109 - 158 - Interval 4YRTST P/F P Notes: 2300 PSI IA pressure test per Operator A4644[444— 1 c re-sstu.e SCANNED AUG 1 0 201 r, Wednesday,May 03,2017 Page 1 of 1 • • _ e 1 LtEoSo o �<a§§sgA4LE I�IIIII lerrpnnure 11, , g S 1 ,$ 1 g 4 4 o ► N o 00 CNI ll, O O ti IA M N l0 � I 00 (NI : .', O. _ . Q o 2 >- E D I cu cc e o a C V O Q V C —C U 1 C p O v H CC • • Regg, James B (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, May 11, 2017 3:18 PM To: Regg, James B (DOA) Subject: RE: PBU Y-06A (PTD 2042510) TIOs attached. Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 4,1 t3,500 - - ■ 3,000 - 2,500 - z000- 1,500 - 1,000 - --. _ . 02111117 17 0211 1e 02251117 03104117 0111117 03/18/17 1 • r _ 600 500 4DD 3D0 200 1000 2111117 0218/1 7 02.=25117 03/0417 011117 03118117 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, May 11, 2017 1:53 PM To: AK, GWO Well Integrity Engineer Subject: PBU Y-06A (PTD 2042510) Please send TIO pressure plot (past 90days) for PBU Y-06A (PTD 2042510). Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. 2 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ Q l.} - ~.$ J Well History File Identifier Organizing (done) o Two-sided "I /I 11111111I11 11/ o Rescan Needed 11I1111111111111111 RES CAN ~Olor Items: o Greyscale Items: DI~AL DATA \r(Diskettes, No. , o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: BY: 0:;J o Other:: /5/ mP 11I/1111111111 ,,1/1 Project Proofing BY: ~ /5/ mP Scanning Preparation BY: Date: + J ß' = TOTAL PAGES~ (Count does not i~~~ude cover sheet) iP Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date:3!/S/07 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 1111111111111111111 NO /5/ Wl P NO BY: Maria Date: /5/ 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned III "111111I11 1111I BY: Maria Date: /5/ Comments about this file: Quality Checked 1111/1111111 111111/ 10/6/2005 Well History File Cover Page.doc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,May 06,2013 TO: Jim Regg ()k �l i P.I.Supervisor 1 l Pte` ' i3 SUBJECT: Mechanical Integrity Tests l( BP EXPLORATION(ALASKA)INC Y-06A FROM: Jeff Turkington PRUDHOE BAY UNIT Y-06A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT Y-06A API Well Number 50-029-20431-01-00 Inspector Name: Jeff Turkington Permit Number: 204-251-0 Inspection Date: 5/2/2013 Insp Num: mitJAT130502155751 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ' Y-06A ,Type Inj W TVD 8221 , IA 50 2506 2484 . 2475 - PTD T Type Test Test psi 1-. 2042510 SPT - -- I YP � p � 19 � 45 73 i s3a 2055 � OA I Interval TYRTST IP/F P 'Tubing 538 538 538 Notes: SCANNED FEB 2 0 2014 Monday,May 06,2013 Page 1 of 1 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 AN ZU� `, December 20, 201 Mr. Tom Maunder '' Alaska Oil and Gas Conservation Commission s Jed '? , 333 West 7 Avenue NOV:* Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Y Pad d Dear Mr. Maunder, ( � it Enclosed please find multiple copies of a spreadsheet with a list of wells from Y 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, Jerry Murphy, 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: 12 /20/10 Corrosion Well Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal Y -01 B 2010760 50029203940200 NA 2.5 NA 8.50 4/11/2010 Y -02A 2011730 50029203950100 NA 0.1 NA 0.85 4/11/2010 Y - 03A 2042350 50029204110100 ‘ NA 2.2 NA 18.70 4/16/2010 Y - 04 1791050 50029204230000 NA 1 NA 5.10 4/11/2010 Y -05B 2081380 50029204360200 NA 3.3 NA 20.40 4/15/2010 ¥-08A 2042510 50029204310100 NA 0.7 NA 3.40 4/16/2010 Y -07A 2071050 50029205600100 14.5 2.0 0.3 NA 1.70 8/4/2010 Y -08A 1880560 50029205720100 NA 4 NA 15.30 8/5/2010 Y -09A 1970830 50029205790100 19 1.5 3.6 NA 17.00 8/4/2010 Y -10A 2042500 50029205870100 19 3.0 8.75 NA 54.40 8/6/2010 Y - 11C 2051640 50029205130300 NA 0.1 NA 0.90 4/14/2010 Y -13 1811120 50029206340000 NA 0.4 NA 3.40 4/15/2010 Y -14B 2011010 50029218320200 NA 3.8 NA 20.40 4/10/2010 Y -15A 2010890 50029209400100 NA 2.1 NA 11.90 4/10/2010 Y - 16 1830490 50029209320000 18.8 2.0 1.7 NA 10.20 8/4/2010 Y -18 1830290 50029209160000 NA 0.8 NA 5.10 4/9/2010 Y -19 1880960 50029218570000 NA 0.2 NA 0.85 4/15/2010 Y - 20A 2010250 50029215870100 NA 1.5 NA 11.90 4/14/2010 Y -21A 1950370 50029215740100 NA 0.1 NA 1.70 4/13/2010 Y - 22A 1881150 50029215580100 NA 0.5 NA 3.40 8/4/2010 Y - 23B 2031640 50029215900200 NA 1.2 NA 6.80 4/13/2010 Y - 24 1861130 50029216080000 NA 1 NA 6.80 4/12/2010 Y - 25A 2081400 50029218830100 NA 0.3 NA 1.70 4/18/2010 Y - 26A 2010430 50029221910100 NA 0.3 _ NA 1.70 4/15/2010 Y - 27 1900280 50029220190000 NA 0.5 NA 3.40 4/14/2010 Y -28 1910650 50029221690000 NA 3.5 NA 28.90 4/12/2010 Y - 29A 1960910 50029221230100 NA 0.2 NA 1.70 4/13/2010 - Y - 30 1910150 50029221350000 NA 0.5 NA 2.60 4/13/2010 Y - 31 1910560 50029221610000 NA 0.5 NA 3.40 4/12/2010 Y - 32 1910410 50029221490000 NA 0.3 NA 1.70 4/18/2010 Y -33 1910300 50029221440000 NA 0.9 NA 6.80 4/12/2010 Y - 34A 1990040 50029221780100 NA 0.9 NA 5.10 4/11/2010 Y - 35A 2022370 50029221860100 NA 1.5 NA 10.20 4/15/2010 Y - 36 1931310 50029224000000 NA 0.9 NA 5.95 4/10/2010 Y - 37A 2020460 50029224030100 NA 0.8 NA 6.00 4/14/2010 MEMORANDUM To: Jim Regg P.I. Supervisor ~p,.~ L~'1(~(Zt~~`j FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Cac C'onscrvation Commission llA'CF,: UVednesday> April 15, 2009 SUBJE(_T: Meehanicallntegrity'I'~sts $P EXPLORA'CION (ALASF:A) INC Y-06A PR[II~FIOF. F3AY l1N(T ~'-()6A Sre: Inspector NON-CONFIDENTIAL Keviewed By: P.I. Suprv ~Z Comm ___ Well Name: PxuvxoF I3AY UNIT r-o~A API Well Number: So-029-20431-01-00 Inspector Name: I3ob Noble Insp Num• mitRCN090413060133 Permit Number: zoo-251-0 ~ Inspection Date: 4~1ot2oo9 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ r>~A Type Inl w ~ TVD -- - -- -- P T zt"r'Sx~ Ty eTest sPT Test sI inten~al 4YRIST Is~F P s"I ~ II ~ ~ OA Tubing o l (>t) ~ .u>„~, ~ ,1 .uxw _.._ 6ix~ ~ •uux~ 1 -~ -- - -. to ~~ Notes: \~VeJnesday. April 15, 20(19 Page 1 of 1 • • ~~~ ._ MICROFILMED 03/01 /2008 DO NOT PLACE ,. Nom. ±.::. , ANY NEW MATERIAL UNCIER THIS PAGE F:tLaserFicl~\CvrPgs_InsertstMicrofilm Matfcer.doc ECE~\¡ED ScblumblPger APR 2 U Z007 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ;~{a Oil & Gas Cons. Commis$iQn Anclmrage sCANNED APR 2 5 2007 (jI~ 8G<-(-;;)5l Well Job# Log Description Date BL 02-15 11661130 MEM PROD PROFILE 02/25/07 1 U-06B 11469946 MEM PROD PROFILE 02/24/07 1 P-09L 1 11676933 LEAK DETECTION LOG 03/18/07 1 U-12A 11649941 MEM PROD PROFILE 02/17/07 1 Z-32BL 1 11661128 MEM PROD PROFILE 02/19/07 1 L-04 11649945 MEM SPINITEMP/PRESS LOG 02/18/07 1 DS 16-22 11676935 LEAK DETECTION LOG 03/22/07 1 DS 12-31 11594485 LEAK DETECTION LOG 03/23/07 1 DS 07-35 11676932 LEAK DETECTION LOG 03/17/07 1 06-07 11637114 LEAK DETECTION LOG 03/16/07 1 L5-28AL 1 11660526 MEM PROD PROFILE 02/08/07 1 03-33B 11661131 MEM TEMP/PRESS SURVEY 03/01/07 1 Z-19A 11649953 STATIC PRESS & TEMP LOG 03/21/07 1 F-11 B 11649954 MEM PROD PROFILE 03/22/07 1 P2-37 A 11628754 MEM DEPTH CONTROL LOG 02/11/07 1 P2-58 11661129 MEM STATIC PRESS SURVEY 02/24/07 1 Y -06A 11628751 MEM INJECTION PROFILE 02/09/07 1 Z-35 11628753 DEPTH CONTROL LOG 02/10/07 1 P2-40 11637320 PROD PROFILE 02/25/07 1 05-20B 11649952 MEM DEPTH DETERMINATION 03/20/07 1 03-36 11649951 MEM STATIC PRESS & TEMP 03/18/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: c9( 04/16/07 NO 4214 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color CD ( ( Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: :2. ç ¡:=,J, DATA SUBMITTAL COMPLIANCE REPORT 1/30/2007 Permit to Drill 2042510 Well Name/No. PRUDHOE BAY UNIT Y-06A Operator BP EXPLORATION (ALASKA) INC MD 12600 Completion Date 1/25/2005 Completion Status WAGIN Current Status WAGIN ---., --_.-._._----~.,.._._----~--,.._- -~-~_._,-~_._._--_._~--~-.,-_..~._-- ~~._--_.._-------,---_._--_.._....._----------_. .- -----'.'----- -. ~--~~--~._-.---------.------------- UIC Y TVD 9064 ---~---_...- ._.~-------~-------~-- -..---- ._------~----~----_...--_._---------_.-_.------~----- REQUIRED INFORMATION Mud Log No Samples No API No. 50-029-20431-01-00 ---------------_._----------~_.._- _._-~~- ---~-------------- .----------------.-.--------------.-- Directional Survey Yes ____________m________________.______________._______.__ _ _ ___~___ -----~._~-_._"--------_..~._~--~ -----_._--_._-----_.._.-._---~-~..---_._------------.-_.._---~~.._--- ._------~--- .- ----~---- -----------'"'-- DATA INFORMATION Types Electric or Other Logs Run: GR I ROP I PRESSURE I SCMT-CA I PBMS-A Well Log Information: (data taken from Logs Portion of Master Well Data Maint Received Comments 2/8/2005 IIFR 2/8/2005 IIFR 2/8/2005 MWD 2/11/2005 SLIM CEMENT BOND/JEWELRY LOG/SCMT-CAlPBMS-A Logl Electr Data Digital Dataset TJ~ Med~Frm!_~Number _!'lame __ ~D- D Asc Directional Survey I il5Pt, Directional Survey ~ / Directional Survey V Cement Evaluation ~Pt/ ~ Log Log Scale Media Run No Interval OHI Start Stop CH 0 12600 Open 0 12600 Open 1 0773 12562 Open 9957 10900 Case ---~--~-----'~.------- 5 Blu 9962 10722 Open 8/7/2006 25 Blu fib 9962 10722 Open 8/7/2006 25 Blu f'l\.D 9962 1 0722 Open 81712006 2 Blu ÎV-P 9962 1 0722 Open 81712006 9962 1 0722 Open 8/7/2006 2 Blu M~ 9962 10722 Open 8/7/2006 25 Blu rllO 9962 10722 Open 81712006 LIS Verification Gamma Ray ~ C c;, ;:::~ :::::::::::::::~ '.ylog 14007 Gamma Ray t~~______~1_~~07 Gamma Ray ---~_._~---_.~~~------- --.------------------ - ----~---~-_... . ---'" --- -_..._-----~, GR, ROP w/graphics GR 17-Jan-2005 plus graphics MPR, GR MPR, GR Lis WI Graphics PB1 GR 17-Jan-2005 PB1 GR 17-Jan-2005 PB1 . ------------~-~------'"------------- Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received DATA SUBMITTAL COMPLIANCE REPORT 1/30/2007 Permit to Drill 2042510 Well Name/No. PRUDHOE BAY UNIT Y-06A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20431-01-00 MD 12600 TVD 9064 Completion Date 1/25/2005 Completion Status WAGIN Current Status WAGIN UIC Y ADDITIONAL INFORMATION Well Cored? Y Q Chips Received? ~ Daily History Received? GIN ã/N Formation Tops Analysis Received? ~- "~------~-- -'--~-----._.~._._~--- . Comments: ~~cc=,c= I \ _._. .__=:::::='---'-_---=---____======'-------=====:-: Compliance Reviewed By: ___~ ~ -.. -- -----~----,_.- ______~=Tf1ßT(=~ '7 Date: . . . Transmittal Form r&11I BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage,Alaska R·.·.·ECEIVED 99501 ~ , Attention: AUG 0 '7 2006 __ ÐII & Gas Cons. eomm\ssion Anchorage Robin Deason Reference: Y-06APBl Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GRlDirectional Measured Depth Log 1 blueline __ GRlDirectional TVD Log , 't;¡ \ ~AC Job#: 828864 Sent By: Deepa Joglekar c;JL f .. Received By: , ... /\.__-,. Date: Aug.03,2006 Date: 1<l--+((j(/; I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~, ~ \ DòL( - .9"){ 1M!."~Jr! -,.. ~_..",,-., ,....;.; --!Ë{ -----~~;------------ ~;IX>': _"" _ ~.o; ... ,..~: -·f,-~;-··-·--~~···:-"-'·".-i _'" _'I!:¢~!.>iJ~t.~ ._:-: ':::::.. ~::""~ ;i. -'(""'~..,¡¡. _ 'OJ! ... ,'""-:-: ...." .,,,,,,. 'O. ~ u ¡¡:U:"..f':~1 _iii _ '0" iII'I ......:-: _·u,~· ~f.."" '. . ."'!' ". i "..~. :; . . Transmittal Form '&ill BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 RECEf'JED c f ~ co Ç) Ç) "-.; ..... l:-- ~I w c: >,., 0 ::) (9< 1 -<:( að , õ L j Attention: Robin Deason !Aly" ~y 'ìPf16 '\ \ AIIiIIII & \.:; / .,pt, ,;I omission '-.. Anr:IlOf8Qe Reference: Y -06A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDW'G lister summary 1 blueline - GRlDirectional Measured Depth Log 1 blueline - MPRlDirectional TVDLog 1 blueline - MPRlDirectional Measured Depth Log .. , LAC 828864 Sent By: Deepa Joglekar Date: Aug.03,2006 Re<eived By: {!. j t ---=- Date: 1f/'?¡O~ Qtl rì¿f!' &1 e {h6Jll1 k e¿\ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~Ó</-dt)1 ~ \ ~t.\'\';[· _ u ... ....'0- em. :~¡ :::: ,.. re-~¡~., _II! _ ~. ... '.X ~;f"-"- .~,~- ..---~:----:----;---;.. _E _eM:('~'... I_:~ ,..-..".. "".......;«>:. .- ,. .:fiX .'''.,;'tA '" ,_ '. '...." .".... '" ~.. ,.:»'~......,.;.">:i.... ...:~ -..... ::,,....., "., ..... -_._-_.~ ~,'¡,~ ..:¡.'>';"''Î, ~ -,1'1>,"1 l}0þ;~, MEMORANDUM ~ . k~1 4121/0:;' State of Alaska TO: Jim Regg P.I. Supervisor Alaska Oil and Gas Conservation commi.' DATE: Wednesday, April 13, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC Y -06A PRUDHOE BAY UNIT Y-06A FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT Y-06A API Well Number: 50-029-20431-01-00 Inspector Name: Chuck Scheve Insp Num: mitCS050409175454 Permit Number: 204-251-0 Inspection Date: 4/912005 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Y-06A IType Inj. i P I TVD I 822\ i IA I 0 I 2300 I 2270 I 2260 I ! i I I I P.T. 2042510 ITypeTest I SPT ¡ Test psi I 2055.25 lOA I 0 I 200 I 200 I 200 i I I Tubing I ! I 1 I Interval INITAL P 900 900 900 900 I i P/F I ! Notes: Pre-test pressures observed and found stable. Wednesday, April 13, 2005 Page I of I .- a STATE OF ALASKA . ALAS~IL AND GAS CONSERVATION COM SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED Revised: O~f2PfJt ~Dd~ection /'" 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended IS! WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: GR / ROP / PRESSURE / SCMT-CA / PBMS-A CASING, LINER AND CEMENTING RECORD S~ING DEPTH MD S~ING DEPTH TVD HOLE TOp I BoTTOM TOp I BoTTOM SIZE CEMENTING. RECORD Surface 110' Surface 110' 36" 12 cu yds Arcticset Concrete Surface 2689' Surface 2689' 17-1/2" 3854 cu ft Permafrost Surface 10467' Surface 8722' 12-1/4" 1518 cu ft Class 'G', 130 cu ft PF 9962' 10776' 8362' 8947' 8-1/2" 460cu ft Class 'G' 9961' 12600' 8361' 9064' 3·3I4"x4·1/8" 185 CU ft Class 'G' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1318' SNL, 5055' WEL, SEC. 34, T11N, R13E, UM Top of Productive Horizon: 1738' NSL, 3401' WEL, SEC. 28, T11N, R13E, UM Total Depth: 2521' NSL, 2025' WEL, SEC. 28, T11 N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- _~~039 _ y- 5948942 Zone- ASP4 TPI: x- 641349 y- 5951928 Zone- ASP4 Total Depth: x- 642708 y- 5952738 Zone- ASP4 ______ __ - - ___________n. 18. Directional Survey IS! Yes 0 No 2. CASING SIZE 20" x 30" 13-3/8" 9-5/8" WT. PER FT. Insulated 72# 47# 29# 8.81 # / 6.2# GRADE Conductor L-80 L-80 L-80 L-80 7" 3-1/2" x 3-3/16" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 6 spf MD TVD MD TVD 12200' - 12250' 8969' .. 8969' 12300' - 12350' 8972' - 8980' , 26. Date First Production: March 16, 2005 Date of Test Hours Tested One Other 5. Date Camp., Susp., or Aband. 1/25/2005 6. Date Spudded 1/18/2005 7. Date TD. Reached 1/20/2005 8. KB Elevation (ft): 83.3' 9. Plug Back Depth (MD+ TVD) 12560 + 9049 10. Total Depth (MD+TVD) 12600 + 9064 11. Depth where SSSV set (Nipple) 2065' MD 19. Water depth, if offshore N/ A MSL 24. SIZE 4-1/2", 12.6#, L-80 1 b. )(IIeIlIrCIéf.~: D~!ð@~þWI~ß~ _rGOJJJrissil n o StratigraphicAn.Mä~e 12. Permit to Drill Number 204-251 13. API Number 50- 029-20431-01-00 14. Well Name and Number: PBU Y-06A 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028287 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 10019' PACKER SET (MD) 9772' & 9912' 25. ACIp,FRACTURE, CEMENTSOUEEZE,etC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED WATER-BBL GAs-McF WATER-BBL CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) 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". ~-r"" ".- <- PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection PRODUCTION FOR OIL-BBL GAs-McF TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED + OIL-BBL Press. 24-HoUR RATE None lj1 ..... .~.;~ ~. .. VE- J...,. ...... .~¡ ... -.. -~ ~ ~ , I ¡ , , 1 I..._i Form 10-407 Revised 12/2003 ....,. , CONTINUED ON REVERSE SIDE RBDMS 8Ft MAR 3 1 2005 GF .- 28~ GEOLOGIC MARKE 29. ORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None Penetrated None Ivishak (From Y -06) 10752' 8929' 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 03/ os PBU Y -06A Well Number 204-251 Permit NO.1 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. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Ted Stagg, 564-4694 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 · STATE OF ALASKA _ ALASK L AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: D Oil DGas D Plugged D Abandoned D Suspended !HI WAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 D Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic !HI Service 2. Operator Name: 5. Date Camp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 1/25/2005 204-251 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 1/18/2005 50- 029-20431-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 1/20/2005 PBU Y-06A 1318' SNL, 5055' WEL, SEC. 34, T11N, R13E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 1738' NSL, 3401' WEL, SEC. 28, T11N, R13E, UM 83.3' Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2521' NSL, 2025' WEL, SEC. 28, T11 N, R13E, UM 12560 + 9049 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 645039 y- 5948942 Zone- ASP4 12600 + 9064 Ft ADL 028287 ~---- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 641349 y- 5951928 Zone- ASP4 Total Depth: x- 642708 y- 5952738 Zone- ASP4 (Nipple) 2065' MD - - - ---- ---- -- - -- 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey !HI Yes DNa N/A MSL 1900' (Approx.) 21. Logs Run: GR 1 ROP 1 PRESSURE 1 SCMT-CA / PBMS-A 22. CASING, LINER AND CEMENTING RECORD CASING 5ETTING DEPTH MD 5ETTING DEPTH TVD HOLE .. ·AMPVNT SIZE WT. PER FT. GRADE lOP ItJOTTOM Top BoTTOM SIZE PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 12 cu vds Arcticset Concrete 13-3/8" 72# L-80 Surface 2689' Surface 2689' 17-1/2" ~854 cu ft Permafrost 9-518" 47# L-80 Surface 10467' Surface 8722' 12-1/4" 1518 cu ft Class 'G', 130 cu ft PF 7" 29# L-80 9962' 10776' 8362' 8947' 8-1/2" ~60 cu ft Class 'G' 3-1/2" x 3-3/16" 8.81# 16.2# L-80 9961' 12600' 8361' 9064' 3-314" x 4-1/8" 185 CU ft Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUalNG RECORD -. Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 10019' 9772' & 9912' MD TVD MD TVD 12200' - 12250' 8969' - 8969' 25. ACID, FRACTURE. CEMENT SauEezg, EtC. 12300' - 12350' 8972' - 8980' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 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-BsL GAs-McF WATER-BsL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + OIL-BSL GAs-McF WATER-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". r----..- RBDMS 8FL MAR 0 1 None 2005 ~-r- O~ PIIJ\L "~Jf . '\ . ~ç "M@I ¡ ¡ "¡J 1-, rJ'- l ¡ Form 10-407 Re\lISéef"1212003 E E ID CONTINU D ON REVERS S E 28; GEOLOGIC MARKERS 29. RMATlON TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None Penetrated None Ivishak (From Y-06) 10752' 8929' 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 ~ÄB/QS PBU Y -06A Well Number 204-251 Permit NO.1 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. Prepared By NameINumber: Drilling Engineer: Terrie Hubble, 564-4628 Ted Stagg, 564-4694 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 1 0-407 Revised 12/2003 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-06 Y-06 WORKOVER NORDIC CALISTA NORDIC 2 Start: 1/2/2005 Rig Release: Rig Number: Spud Date: 1/5/2005 End: 1/15/2005 12/31/2004 17:00 - 18:00 1.00 MOB P PRE Continue to rig down. 18:00 - 18:40 0.67 MOB P PRE Pre tour safety meeting with the night tour. Discuss plan ahead for the evening. Hold PJSM for moving off well. 18:40 - 20:00 1.33 MOB P PRE Prep to move off well. 20:00 - 20:20 0.33 MOB P PRE Move Nordic 2 of of well L 1-01, and stage in the middle of L 1 pad. 20:20 - 21 :45 1.42 MOB P PRE Prep to lay down derrick and wind walls. 21:45 - 22:05 0.33 MOB P PRE Safety meeting Re: laying down derrick. 22:05 - 00:00 1.92 MOB P PRE Scope in windwalls. Lay derrick down. 1/1/2005 00:00 - 00:45 0.75 MOB P PRE Continue to lay down derrick. 00:45-01:10 0.42 MOB P PRE Hole PJSM with Toolpusher, Wellsite leader, security and rig hands prior to starting move. 01:1 0 - 06:00 4.83 MOB P PRE Move Nordic 2 from L 1 pad headed toward Y pad on the WOA. 06:00 - 15:00 9.00 MOB P PRE Continue move. Arrive on H-pad at 1500 hrs. 15:00 - 18:00 3.00 MOB P PRE Raise derrick and re-string blocks prior to moving onto Y -pad. 18:00 - 19:00 1.00 MOB P PRE Crew change and PJSM to discuss finish raising the derrick, and restringing drilling line. 19:00 - 22:30 3.50 MOB P PRE Move injector out of the way. Hang blocks. Restring drilling line. 22:30 - 00:00 1.50 MOB N PRE Ready to move again. Security now escorting Nabors 4ES on a rig move, so are unavailable. Wait on security to arrive. 1/2/2005 00:00 - 00:15 0.25 MOB P PRE Continue to standby waiting for security. 00:15 - 00:30 0.25 MOB P PRE Safety meeting with security and rig crew prior to moving from H to Y pads. 00:30 - 02:40 2.17 MOB P PRE Move Nordic 2 from H to Y pad. 02:40 - 15:00 12.33 MOB N WAIT PRE Waiting on Y pad for pad preparation to be completed. Needed 80yds of gravel to level out. 15:00 - 15:20 0.33 MOB P PRE Hold PJSM and review move onto well.! 15:20 - 17:00 1.67 MOB P PRE Set cellar mats. Dig out fill in cellar to access OA valves. 17:00 - 18:00 1.00 MOB P PRE Move over well. rig accepted at 1700 hrs. 1-2-2005 18:00 - 18:30 0.50 RIGU P PRE Crew changeout and Pretour safety meeting with rig hands, valve crew, and cameron hands. Discussed the plan forward for tonight, hazards and mitigation to hazards. 18:30 - 23:15 4.75 RIGU P PRE Check pressure on tree. Found 90 psi. Bleed off pressure to bleed trailor. Got pressure down to 20 psi. Attempt to set TWC. Hanging up in the Swab valve. Steam swab to melt ice. Still can't get TWC thru it. Visual examination shows swab appears to be damaged and sticking into bore 1/4". With shut master valve, ND 7" quick union and swab valve. NU 7" union to top of flow cross. 23: 15 - 00:00 0.75 RIGU N WAIT PRE Valve crew had to run over and pull a TWC at Nabors 9ES. Stand by on valve crew. 1/3/2005 00:00 - 00:15 0.25 RIGU N WAIT PRE Continue to wait on valve crew to set TWC. Bled tubing pressure to 0 psi while we wait. 00:15 - 01:00 0.75 RIGU P PRE Valve crew back on location. Set TWC. 01 :00 - 05:00 4.00 RIGU P PRE Bleed lAP to 0 psi. Cycle lower lockdown screws. Nipple down production tree. 05:00 - 06:00 1.00 RIGU P PRE Clean furmanite material from void space around upper lock down screws. Cycle upper lock down screws. 06:00 - 06:15 0.25 BOPSU P PRE PJSM meeting with oncoming crews. review plan forward. 06:15 - 15:30 9.25 BOPSU P PRE NU 13-5/8" BOP's. Notify AOGCC rep of pending test. 15:30 - 16:30 1.00 BOPSU N SFAL PRE Make a full body test. Annular not holding, function several Printed: 1/31/2005 8:02:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-06 Y-06 WORKOVER NORDIC CALISTA NORDIC 2 Start: 1/2/2005 Rig Release: Rig Number: Spud Date: 1/5/2005 End: 1/15/2005 times. Take accumulator up to 1500psi but conitnues to leak badly. 16:30 - 18:00 1.50 SFAL PRE Remove test jt make visual inspection of element. Annular bag is damaged and needs to be replaced. No spare element is available. Arrange to get 13-5/8" annular from Nordic 3. Contact Shane at Nordic 3, arrange trucking. Standing by on new bag. 18:00 - 22:30 4.50 RREP PRE Remove defective 13-5/8" annular while waiting on new bag from Kuparuk. 22:30 - 00:00 1.50 RREP PRE Nipple up new 13-5/8" stack. 1/412005 00:00 - 04:15 4.25 RREP PRE Continue to NU replacement 13-5/8" annular. Nipple up riser. Check the choke and kill lines. Air up boot on riser. 04:15 - 09:15 5.00 PRE Perform initial BOP test for 13-5/8" BOP's. Test good. Continue testing 250psi low / 350psi high. AOGCC waived witnessing test. 09:15 - 12:15 3.00 EVAL P DECOMP RIU lines to test IAlTbg. PU 24' of 7" lubricator. Pull TWC with DSM lubricator. RD our 7" lubricator. 12:15 - 13:15 1.00 EVAL P DECOMP Pressure up tubing to 2000 psi. Pressure test IA to 4000 psi. Hold for 1/2 hour and chart. Initial IA pressure = 4000 psi 15 min IA pressure = 3959 psi 30 min IA pressure = 3933 psi Good MIT test. Bleed down IA followed by the tubing, rig down testing equipemnt. 13:15 - 14:45 1.50 PULL P DECOMP Back out lockdowns. Rig up 5" OP to pull tubing. 14:45 - 15:00 0.25 PULL P DECOMP Safety meeting prior to pulling on tubing. 15:00 - 15:50 0.83 PULL P DECOMP Check IA. It has a small amount of pressure. Bleed off to bleed trailer. 15:50 - 16:15 0.42 PULL P DECOMP Pick up on tubing string. Unseated tubing hanger at 95 klbs. Pick up in 20 klb increments to 230 klbs. 15' of stretch. Did not release from PBR. Slack off weight and cycle back up to 230 klbs 4 more times. No movement. Unable to pull from PBR. Need to chemical cut. 16:15-19:30 3.25 PULL N WAIT DECOMP Call for slickline unit for drift and tag. Notify Schlumberger to have chemical cutter BHA ready. 19:30 - 20:00 0.50 PULL P DECOMP Hold PJSM with SLB s-line and rig crews. Discuss pressure control equipment rig up. 20:00 - 22:30 2.50 PULL P DECOMP Spot SLB slick line unit. RU s-line sheaves & tools. MU 3.75" od drift. Would not pass XO on landing joint. Discuss downsizing chemical cutter with SLB e-liners. MU 3.5" gauge ring. Drift to 9950' SLM. 22:30 - 00:00 1.50 PULL P DECOMP Re-spot SLB slick line unit to improve rig up. Discuss downsizing chemical cutter with SLB e-liners. MU 3.5" gauge ring. Drift to 9950' SLM. POOH. 1/5/2005 00:00 - 01 :00 1.00 PULL P DECOMP Rig down SLB slick line unit & equipment. 01 :00 - 02:00 1.00 PULL N WAIT DECOMP Wait on SLB e-line crew, delayed by rig move in progress on Spine Rd. 02:00 - 02:20 0.33 PULL P DECOMP Hold PJSM with SLB & rig crews before beginning rig up. 02:20 - 03:15 0.92 PULL P DECOMP Rig up SLB e-line equipment. 03:15 - 04:30 1.25 PULL P DECOMP Run in hole with tbg punch & CCL. Log tie in pass. Perftbg from 9813 to 9815. Well flowing from tbg, u-tubing with IA fluids. 04:30 - 05:30 1.00 PULL P DECOMP POOH with e-line tools. Printed: 1/31/2005 8:02:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-06 Y-06 WORKOVER NORDIC CALISTA NORDIC 2 Start: 1/2/2005 Rig Release: Rig Number: Spud Date: 1/5/2005 End: 1/15/2005 There should be 17' of stub sticking up from above the PBR, and 14.4' of stub below the SS. DECOMP Circulate down the IA recovering the diesel freeze protect. Then swap to circulate down the tubing taking returns from the IA. Taking the crude to the tiger tank. Circulate 1150 bbls of hot seawater. Tubing + IA vol = 680 bbls. The last 300 bbls of returns were pretty clean. Pull tubing hanger to the floor. Rig up to recovering control line onto spooler. Begin pulling tubing. Hold PJSMfTL mtg with rig crew & service hands. Discuss handling jointed pipe, spill prevention, job assignments. Pull and lay down tubing. Stuff absorb into joint ends to prevent possible spill of well bore fluids. Control lines and stainless cable pulling ok, but plastic coating is shredded and coming off in pieces. Recovered 26 rubber and 6 stainless control line bandslcentralizers (none lost in hole). Run and set Howco 9-5/8" RTTS at 35' below floor. Test same to 1000 psi from top. Release from packer and stand back drill pipe. Hold PJSM with rig crew before begining ND procedure. Discuss rig up for lifting BOPs, apd removing tubing spool with loader etc. ND and remove riser. Loosen bolts on tbg spool, upper & lower. Crew change and PJSM re: lifting 13-5/8" stack, double securing stack, changing tubing hanger and 9-518" packoff. Disconnect hydraulic hoses from stack. Pump into OA to confirm we have good communication to OA. Bleed OA to 0 psi. Pull stack with blocks and secure in cellar with additional secondary sling. Pull tubing hanger spool. DECOMP Replace 9-5/8" casing packoffs. WAIT DECOMP The lower plate for the 9-5/8" packoff can not be removed. There are also 10 broken cap screws. To get a new packoff assembly installed the broken cap screws must be removed, or we must pull the 9-5/8" slips. The Cameron hands suggest spearing the 9-5/8" casing, pulling and changing the slips. This will require more pull than the Nordic 2 derrick can provide. 1/5/2005 05:30 - 08:15 2.75 PULL P DECOMP 08:15 - 08:35 0.33 PULL P DECOMP 08:35 - 09:10 0.58 PULL P DECOMP 09:10 -12:00 2.83 PULL P DECOMP 12:00 - 17:00 5.00 PULL P 17:00 - 18:00 1.00 PULL P DECOMP 18:00 - 18:30 0.50 PULL P DECOMP 18:30 - 00:00 5.50 PULL P DECOMP 1/6/2005 00:00 - 02:30 2.50 PULL P DECOMP 02:30 - 02:45 0.25 BOPSU P DECOMP 02:45 - 06:00 3.25 BOPSU DECOMP 06:00 - 06:50 0.83 BOPSU DECOMP 06:50 - 10:30 3.67 BOPSU DECOMP 10:30 - 14:00 14:00 - 17:30 3.50 BOPSU 3.50 BOPSU Lay down tubing puncher. All shots fired properly. PU string shot and RIH. Fire string shot 9846'-9859'. Good indication of fire, POOH. Safety meeting Re: chemical cutter. Discussed hazards and techniques to mitigate hazards. Rig up chemical cutter. Rig floor clear of non essential personnel. I RIH with 3.375" chemical cutter. Make full tie in pass over jewalry. Position CC head in middle of full joint below SS, at 9858' ELM. Fire chemical cutter. Good indication of fire from wire line unit and on rig floor. POOH with chemical cutter. Ref log for all eline runs was the Camco Jewalry log of 12-09-90. There is 14' difference between ELM and Drillers depths. Chemical cut with ref to drillers depth is 9872'. Printed: 1/31/2005 8:02:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-06 Y-06 WORKOVER NORDIC CALISTA NORDIC 2 Start: 1/2/2005 Rig Release: Rig Number: Spud Date: 1/5/2005 End: 1/15/2005 Call town and discuss plan forward. After discussion with town the plan is to attempt to fabricate a pulling tool similar to a gear puller, and thread the lower packoff plate and attempt to pull it. Send the Cameron hands to round up the parts to do this. 19:00-21:00 DECOMP Tap 2 holes in each lower c-plate. Rig a simple puller using 3/4" all thread, nuts, and washers. Pull c-plates free from casing head. Dress 3 dutchman protruding from 9-5/8" slip assembly. 21 :00 - 00:00 DECOMP Install new lower 9-5/8" pack-off assembly. Energize same with lock down screws. Install new upper 9-5/8" packoff. NU new tubing head. Activate upper pack off with graphite sealant. 1/712005 00:00 - 01 :30 1.50 DECOMP Continue to NU tbg spool. Inject packoff graphite sealant. Test packoffs & flange to 3500 psi for 15 min. Test good. 01 :30 - 02:30 DECOMP NU 13-5/8" BOPs to tbg spool. Attach hydraulic lines. 02:30 - 06:00 DECOMP NU riser between floor and BOPs. 06:00 - 06:45 DECOMP PJSM re: plan forward for today. 06:45 - 09:45 DECOMP Finish nippling up riser, set test plug. Body test BOP stack 5 minutes low and high pressure. All passed ok. 09:45 -10:10 0.42 DECOMP Pull test plug. 10:10 -10:25 0.25 DECOMP Safety meeting re: Pulling RTTS. 10:25 - 12:00 1.58 DECOMP Pull RTTS and lay down. 12:00 - 13:00 1.00 DECOMP Rig up hose to top of 4-1/2" completion and circulate to warm well. Pump at 5 bpm. Got more of the rubber coating from the control line out of the hole during this circulation. 13:00 - 13:10 0.17 PULL P DECOMP Toolbox talk on tripping tubing OOH. 13:10 - 15:30 2.33 PULL P DECOMP Pull old tubing string OOH. Got 40 jts and 1 GLM OOH. 15:30 - 15:45 0.25 PULL P DECOMP Hold PJSM re: Crane lifts. Need to pull HES control line spooler off of rig floor. Need to pick up Nabors casing crew tongs. 15:45 - 16:30 0.75 PULL P DECOMP Make crane lifts. Note - If we had a jib crane on the rig floor these lifts could have been made off of the critial path, which would have saved 2 hours of rig time. It also would have been unnecessary to use a rental crane from Peak in Deadhorse. 16:30 - 18:00 1.50 PULL P DECOMP Resume pulling old tubing string OOH. 18:00 - 21 :00 3.00 PULL P DECOMP Continue to POOH with old completion, after rig crew change out. Approx. 180 jts to go. 21 :00 - 23:00 2.00 PULL N RREP DECOMP Foot throttle failed on draworks. Call for rig electrician. Repair throttle. 23:00 - 00:00 1.00 PULL P DECOMP Continue to pull 4-1/2" completion. 1/8/2005 00:00 - 03:15 3.25 PULL P DECOMP Continue to POOH with 4-1/2" completion. Chemical cut looks very good. 100% cut. Stub is round. 03:15 - 03:45 0.50 RUNCO RUNCMP Hold PJSM with SLB slick line crew. Spot unit to allow acess to pipe shed. 03:45 - 06:00 2.25 RUNCO RUNCMP Run 8.5" gauge ring I junk basket on slickline. 06:00 - 08:00 2.00 RUNCO RUNCMP Continue RIH. Basket falling slowly. SL operator says it looks as if he is pushing something. Hole deviation is only 45 deg. Basket should fall cleanly. Tag tubing stub at 9856' SLM. (ELM cut depth was 9858') POOH slow. Swabbing on way OOH, so have to pull slow. 08:00 - 08:40 0.67 RUNCO RUNCMP Dump junk basket. Basket is full of what looks like chunks of Printed: 1/31/2005 8:02:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-06 V-06 WORKOVER NORDIC CALISTA NORDIC 2 Start: 1/2/2005 Rig Release: Rig Number: Spud Date: 1/5/2005 End: 1/15/2005 12:45 - 13:00 0.25 control line rubber, parafin, and particulate matter like sand. 90% of debris appeared to be control line rubber. Top half of basket packed full. Got about 1.5 gallons in a 5 gallon bucket of debris on this run. Clean out junk basket, and rig up to rerun. RUNCMP Rerun junk basket gauge ring. Made it to 9944' (?) slickline measured depth on this run. RUNCMP Back at surface. Junk basket full of debris again. Got slightly more debris than last time. Debris consisted of a few big chunks of rubber about 6" long, and lots of fine broken up pieces. Still about 2 gallons in volume. RUNCMP Make 3rd guage ring/junk basket run. Tag up at same depth, 9944' SLM. Hard tag. POOH. RUNCMP We were just notified that the weather conditions are now phase 3. We will continue coming OOH with the junk basket, get to surface, secure the well and dry watch the rig. Continue to POOH. RUNCMP Tag up at surface. Dump junk basket. Got more than last time. About 2+ gallons of debris. A few big pieces of rubber and lots of fine particulate rubber. Leave slickline rigged up. Tie back junk basket. WAIT RUNCMP Hold safety meeting Re: phase 3 weather conditions. We have 17 Souls on location. We have the rig crew, 3 slickline hands, 3 service coil hands from a service unit on Y-10. Discuss the BP protocol for phase 3 weather. No work is to be done except what is needed to keep the rig warm and lit. 2 hands must drywatch the rig at all times. All outside travel must be in parties of 2 or greater with at least 1 radio. The other hands are welcome to bunk in the tech limits camp. We have plenty of diesel and rig water. The weather conditions are expected to be phase 3 thru Sunday night. Standby on phase 3 weather. Continue to wait on Phase 3 weather. Fuel and rig water levels ok. Continue to wait on weather. Temp -11, winds 37 gusting 42, windchill -60. Outlook for tonight blizzard conditions, winds to 55 mph. The generator on the Schlumberger slickline unit failed. The crew at location is unable to get it repaired, even with the assistance of the rig motor man. The SLB mechanic in Deadhorse does not want to attempt further field repairs. The slickline unit will not be available to use when the weather moderates. We will have to get another unit to finish our cleanout. Continue to wait on weather. Current winds 36-44 mph, temp=-16 degf, windchill=-76 degf. 08:40 - 12:45 4.08 13:00 - 16:45 3.75 16:45 - 17:00 0.25 17:00 - 17:15 17:15 - 17:35 17:35 - 00:00 6.42 RUNCO WAIT RUNCMP 1/9/2005 00:00 - 06:00 6.00 RUNCO WAIT RUNCMP 06:00 - 15:00 9.00 RUNCO WAIT RUNCMP 15:00 - 00:00 9.00 RUNCO WAIT RUNCMP Continue to standby waiting on weather. 1/1 0/2005 00:00 - 03:30 03:30 - 03:45 3.50 RUNCO 0.25 RUNCO WAIT RUNCMP Continue to standby. Weather conditions Phase 3. WAIT RUNCMP Convoy arrived with Nordic crew. Change Nordic crews. Send SLB service coil and slick line crews off location, to BOC. Rig SLB crews no changeout since Saturday morning. Printed: 1/31/2005 8:02:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-06 Y-06 WORKOVER NORDIC CALISTA NORDIC 2 Start: 1/2/2005 Rig Release: Rig Number: Spud Date: 1/5/2005 End: 1/15/2005 Continue to wait on Phase 3 weather. Winds at 28 mph, gusting to 40 mph. Temp -22 deg f. 06:00 - 15:15 9.25 WAIT RUNCMP Continue to wait on Phase 3 weather. Current winds 24 mph gusting to 30 mph. Temp -22, Wind chill = -75 deg. Forcast is for winter storm warnings until 6 PM today with winds 20-30 mph, temperatures to -30, wind chills in excess of -60 degf. Discussed phase 3 protocol with new Nordic crew. Dry watch the rig. No unneccessary work to per performed. Only do tasks needed to keep the rig warm and the lights on. Rotate the crew members so that they can get sleep, with 1 SLB and 1 Nordic hand on duty at all times. Current head count is 10 souls on the rig. Continue to wait on weather. 15:15 - 15:30 0.25 RUNCO WAIT RUNCMP Convoy to rig with potable water and sewage truck. Extra rig team members head to BOC with return convoy. Continue to wait on weather. 15:30 - 20:00 4.50 RUNCO WAIT RUNCMP Continue to wait on Phase 3 weather. Call AOGCC to discuss BOP test. Extension granted by J. Spaulding to run completion before weekly test. 20:00 - 20:30 0.50 RUNCO WAIT RUNCMP Convoy from Dead horse arrives to change out SLB CTD crew. Continue in Phase 3 weather. 20:30 - 00:00 3.50 RUNCO WAIT RUNCMP Continue to dry watch rig. Still in Phase 3 conditions. Weather slowly improving. 1/11/2005 00:00 - 05:45 5.75 RUNCO WAIT RUNCMP Continue to wait on Phase 3 weather. 05:45 - 06:00 0.25 RUNCO WAIT RUNCMP Discuss weather restrictions with IMT. Phase 2 on main roads, phase 3 on small access roads. Well site leader discretion to assess acessability to location. Hold PJSM with rig team & loader operator. Plan to use 3 vehicle convoy to evaluate access to GC-2. 06:00 - 08:30 2.50 RUNCO WAIT RUNCMP Wait on Phase 3 weather. 08:30 - 09:45 1.25 RUNCO WAIT RUNCMP Convoy out to GC2 to evalute access to Y-Pad. Road passable for pick ups only. 09:45 - 10:00 0.25 RUNCO RUNCMP Hold PJSM with rig crew to discuss loading pipe shed with completion. Heavy equipment widened access path to pad using snow blower. 10:00 - 15:00 5.00 RUNCO RUNCMP Continue to load pipe shed with 4-1/2" tbg. Arrange for SLB crew change. Call for SLB slick line mechanics & crews to convoy to location to repair slickline unit. 15:00 - 17:00 2.00 RUNCO RUNCMP RU SLB slick line unit. Run 8.5" drift with junk basket 17:00 - 18:30 1.50 RUNCO DPRB RUNCMP Unable to get slickline through well head. Suspect ice plug. Run steam hose into well. Put Tioga heater on cellar for additional heat. 18:30 - 19:00 0.50 RUNCO RUNCMP Crew change on location. Change out and hold on Tour TL and PJSM mtg for night ops. Phz 2/3 19:00 - 22:00 3.00 RUNCO RUNCMP Pull steam hose from well head. RIH with GR/junk basket. No obstruction. RIH to 9858' WLM. Recovered 2-1/2 gallons of 1/2 plastic control line coating and MI mung 22:00 - 00:00 2.00 RUNCO RUNCMP Run 8.5" GR/JB again to 9858' WLM 1/12/2005 00:00 - 01 :00 1.00 RUNCO RUNCMP POOH wI GR/JB and no recovery Printed: 1/31/2005 8:02:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-06 Y-06 WORKOVER NORDIC CALISTA NORDIC 2 Start: 1/2/2005 Rig Release: Rig Number: Spud Date: 1/5/2005 End: 1/15/2005 RIH wI 4.5" LIB to 9858' and no marks WAIT WO pump bailer Wind is down to 10-15 mph, still Phz 2/3 04:30 - 06:00 1.50 RUNCMP RIH wI 3" x 10' pump bailer Phz 1/2. Out of hole with bailer. Recovered 1/2 bailer of MI mung and had clear impact marks on bottom of bailer indicating contact with tbg stub (we think). 06:00 - 06:45 0.75 RUNCMP RD SLB slick line. 06:45 - 07:00 0.25 RUNCMP Hold PJSM & TL mtg in dog house with rig crews. Discuss plan forward. 07:00 - 09:00 2.00 RUNCMP Rig up floor to run 4-1/2" TCII completion. 09:00 - 09:15 0.25 RUNCMP Hold PJSM with Nabors, Nordic, SLB, Baker hands to discuss assignments, hazards, procedures for running completion. 09:15 -10:30 1.25 RUNCMP MU tail pipe over shot, x nipple & packer assembly. Baker lock connections below packer. 10:30 - 14:00 3.50 RUNCMP Torque turn 4-1/2" TCII tubing. First 12-15 jts hanging up in wellhead. Suspect TCII collars hitting some thing. Problem went away as string weight increased. 85 joint in hole at 1400 hrs. 14:00 - 18:00 4.00 RUNCMP Continue to RIH with completion to jt #143 18:00 - 18:15 0.25 RUNCMP Safety mtg re: TUcrew changelrun tubing Phz 1/2 18:15 - 22:20 4.08 RUNCMP Torque turn 4-1/2" 12.6# L-80 TC11 R-3 tubing to jt #233 22:20 - 23:30 1.17 RUNCMP Pickup 2 extra jts and RIH washing thru overshot at 2.0/40 and pressure increased by 200 psi before getting to shear pins (at 2.6' in). SD pump and stack wi on shear pins until sheared at -6k. RIH 6.5' until set down of OS bottoming out. PU 2' and circ 1.5/350 psi, but acts like fill 23:30 - 00:00 SFAL RUNCMP Rig up to reverse and found cellar lines frozen. Thaw 1/13/2005 00:00 - 00:40 SFAL RUNCMP Fin thaw cellar lines 00:40 - 01 :30 RUNCMP Close annular and begin rev circ corr inhib SWat 2.75/225 with OS above stub. Wash down to just over top of tubing stub and pressure increased and packed off. Assume more control line rubber (after 50 bbls of returns had recovered one chunk of CL rubber 1.8' long from tubing). Will have to reverse in SW and diesel with OS above stub and hanger below annular before landing hanger 01 :30 - 04:15 RUNCMP LD 3 jts. Add spacer pups. Add a jt. Install hanger. RU landing jt on XO's and circ head. RIH 23' to put hanger below annular and OS about 2' above stub. Close bag Note: ran 232 jts 4-1/2" tubing 04:15 - 06:30 RUNCMP Reverse in thru kill line w/ 400 bbls SW w/ corrosion inhibitor at 2.75/230 (pump rate limited by packer specs). After one tubing volume surface lines started packing off with control line rubber and also got MI mung water back 06:30 - 06:45 RUNCMP Hold PJSM with Little Red. 06:45 - 07:15 RUNCMP RU pump truck to IA valve in cellar. Pressure test same. 07:15 - 08:00 RUNCMP Pump 120 bbls warm diesel down IA to freeze protect same. 2.5 bpm @ 300-450 psi. 08:00 - 08:30 RUNCMP Shut in IA. RD Little Red. 08:30 - 09:30 RUNCMP Land tubing. Depth discrepency noted on landing joint. Re-evaluate the numbers. Believe we are landed correctly. IA Printed: 1/31/2005 8:02:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-06 Y-06 WORKOVER NORDIC CALISTA NORDIC 2 Start: 1/2/2005 Rig Release: Rig Number: Spud Date: 1/5/2005 End: 1/15/2005 09:45 - 10:45 10:45 - 11 :45 11 :45 - 14:30 14:30 - 23:00 23:00 - 00:00 1/14/2005 00:00 - 00:30 I 00:30 - 04:00 holding pressure. RILDS. Hold PJSM with SLB slick line & rig crews. Discuss job, hazards, comms, safe area and more. RUNCMP RU SLB slick line unit with 0.125" wire. RUNCMP RIH and recover RHC plug from 9782'. RUNCMP RIH with 3.77" and drift to 10,000' (original tubing tail). POOH RUNCMP RIH and set equalizing plug in X nipple at 9795' WLM. POOH and still had plug. Change shear pin and rerun. Slow runs due to wellbore full of fluid and tight tolerance of plug DFAL RUNCMP RU landing jt wI circ head. lAP 250 psi. Bleed off approx 2 bbls diesel to cuttings box until no returns. Leave IA valve open and pressure tubing to set packer. Got to 700 psi wI 1.4 bbls and had a good diesel flow from IA. SD pump and monitor as pressure bled off on tubing-plug is leaking. SI IA valve after tubing pressure was bled off and imbalance continued to flow diesel DFAL RUNCMP RD landing jt wI circ head. RU WL DFAL RUNCMP RIH wi equalizing prong and knock watermelon off seat RIH wI pulling tool and recover 'X' plug. Packing looked new and no marks on tool. Assume watermelon may have not seated when tool was set RIH wI 'X' RHC plug and set in nipple at 9782' Stand back DP landing/pump in assembly. MU 1 jt TCII. Drop ball & rod assembly. Remove TCII. MU drill pipe landing joint. Open IA. Pressure tbg to 4000 psi to set pkr & test tbg. Record same for 30 min. Test good. Bleed tbg to 1500 psi. Pressure IA to 4000 psi. Record for 30 min. Good test. RIH with slick line to recover ball & rod from RHC plug. POOH. RIH. Recover RHC plug assembly. POOH. Begin cleaning hauling off fluids. Clean pits. RD SLB slickline unit. Set two way check valve in tbg hanger. Hold PJSM to discuss crane picks from rig floor with crew and operator. Use crane to lift Nabors power tongs, thread protector bags, other. Break down landing joint on floor. Round up other mise equipment to ship out. ND 13-5/8" BOPS and load out Safety mtg re: where to set 7" BOP's to be out of the way of 7" tree Hang 7" BOP's 180 deg out on hook in cellar Fin set 7" BOP's in cellar Install tree adaptor. Test packoff to 5000 psi Load pits wI 2 ppb biozan Safety mtg re: get 7" tree inside cellar wi 7" BOP (tite fit) Bring tree into cellar and set on adaptor flange studs. Thaw out tree. NU 7" BOP's on top of swab. Rotate all 180 deg using blocks to assumed correct orientation to fit S-riser wlo modification. Set tree on adaptor flange Note: to fit the prior S-riser, the wing valve must face 90 deg to the right (parallel to Pad) when looking toward the reserve pit. This is the first well we have done that is this far off 1.00 1.00 2.75 8.50 0.50 RUNCO 3.50 RUNCO 04:00 - 05:45 1.75 RUNCO RUNCMP 05:45 - 06:45 1.00 RUNCO RUNCMP 06:45 - 07:30 0.75 RUNCO RUNCMP 07:30 - 08:15 0.75 RUNCO RUNCMP 08:15 - 11 :00 2.75 RUNCO RUNCMP 11 :00 - 13:00 2.00 RUNCO RUNCMP 13:00 - 13:30 0.50 RUNCO RUNCMP 13:30 - 14:00 0.50 WHSUR P RUNCMP 14:00 - 14:15 0.25 WHSUR P RUNCMP 14:15 - 15:15 1.00 WHSUR P RUNCMP 15:15 - 22:15 7.00 WHSUR P RUNCMP 22:15 - 22:30 0.25 WHSUR P RUNCMP 22:30 - 00:00 1.50 WHSUR P RUNCMP 1/15/2005 00:00 - 00:15 0.25 WHSUR P RUNCMP 00:15 - 02:30 2.25 WHSUR P RUNCMP 02:30 - 02:50 0.33 WHSUR P RUNCMP 02:50 - 06:00 3.17 WHSUR P RUNCMP Printed: 1/31/2005 8:02:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-06 V-06 WORKOVER NORDIC CALISTA NORDIC 2 Start: 1/2/2005 Rig Release: Rig Number: Spud Date: 1/5/2005 End: 1/15/2005 1/15/2005 06:00 - 15:00 9.00 WHSUR P RUNCMP NU BOPS. Tighen flanges. MU hydraulic hoses. Install riser to rig floor. MU kill and choke lines. Test tree to 5000 psi. Printed: 1/31/2005 8:02:45 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-06 Y-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 1/15/2005 Rig Release: Rig Number: Spud Date: 1/5/2005 End: 1/15/2005 00:00 - 00:15 0.25 WHSUR P RUNCMP Fin set 7" BOP's in cellar 00:15 - 02:30 2.25 WHSUR P RUNCMP Install tree adaptor. Test packoff to 5000 psi Load pits wi 2 ppb biozan 02:30 - 02:50 0.33 WHSUR P RUNCMP Safety mtg re: get 7" tree inside cellar wi 7" BOP (tite fit) 02:50 - 06:00 3.17 WHSUR P RUNCMP Bring tree into cellar and set on adaptor flange studs. Thaw out tree. NU 7" BOP's on top of swab. Rotate all 180 deg using blocks to assumed correct orientation to fit S-riser wlo modification. Set tree on adaptor flange Note: to fit the prior S-riser, the wing valve must face 90 deg to the right (parallel to Pad) when looking toward the reserve pit. This is the first well we have done that is this far off 06:00 - 15:00 9.00 WHSUR P RUNCMP NU BOPS. Tighen flanges. MU hydraulic hoses. Install riser to rig floor. MU kill and choke lines. Test tree to 5000 psi. 15:00 - 19:45 4.75 BOPSU WEXIT Test BOP equipment. Test witness waived by C. Scheve with AOGCC. 19:45 - 23:00 3.25 BOPSU SFAL WEXIT Blind/shear rams leaked. Replace seals and retest (four times) wlo success (slow bleed off by horseshoe seal) 23:00 - 00:00 1.00 BOPSU WEXIT RU DSM and pull TWC while wlo SWS to get more seals and new inserts 1/1612005 00:00 - 01 :00 1.00 BOPSU N SFAL WEXIT Replace blindlshear seals and retest against swab valve, ok 01:00 - 04:15 3.25 STWHIP P WEXIT Prep injector. Move injector over well and install packoff, gooseneck, etc. Install internal grapple and pull CT from reelhouse thru packoff, -43F ambient 04:15 - 05:20 1.08 STWHIP P WEXIT Fill CT wI FW at 2.25/1050 reversing. Then reverse slack back at 4.513250. Blow CT back wI air 05:20 - 08:00 2.67 STWHIP P WEXIT RU cutter and cut back CT to find slack. Head up e-coil. Test same for pressure, pull, and continuity. 08:00 - 10:00 2.00 STWHIP P WEXIT MU BHA #1 (3.8" parabolic with 2-7/8" extreme mtr). Trouble getting swab valve open. DSO opened bleed port, able to then open swab. 10:00 - 11 :30 1.50 STWHIP N DPRB WEXIT Ice plug at 28' below floor. PU 2 jts PH6 dp and thaw same. 11 :30 - 12:35 1.08 STWHIP P WEXIT Complete BHA. Stab coil. Get on well. 12:35 - 13:30 0.92 STWHIP N SFAL WEXIT RIH with milling assembly. Lubricator o-ring leaking. POOH. Get off well. Unstab coil. Change o-ring (s). Stab coil. Get on well. 13:30 - 15:15 1.75 STWHIP P WEXIT Run in hole with milling assembly. 15:15 - 20:10 4.92 STWHIP P WEXIT Tag XN at 9984' (9970 ELM). PU and begin time milling @ 0.10 per 5 minutes 2130 psi @ 2.5 bpm. Got thru after 4 stalls 20: 10 - 20:20 0.17 STWHIP P WEXIT Ream and backream wI no motor work 20:20 - 20:35 0.25 STWHIP P WEXIT RIH looking for cement and tagged at 10621' CTD 20:35 - 00:00 3.42 STWHIP P WEXIT Drill cement from 10620' 2.58/2230 at avg 25'/hr 2-3k wob, 150 psi diff. Dump 20 bbls of crude cut fluid on first BU and plugged MM wI CL rubber. Penetration rate picked up to 45'/hr after stall at 10667' 1/17/2005 00:00 - 01:15 1.25 STWHIP P WEXIT Continue drilling cement from 10720' 2.55/2230 at avg 55'/hr wi 3-4k wob 150 psi diff to stall at 10790' CTD 01:15 - 01:40 0.42 STWHIP P WEXIT Wiper back to TOC, 45k. Wiper to EOT 01:40-03:15 1.58 STWHIP P WEXIT POOH for window mill. Overpull at 10620'. Plugged MM with more CL rubber (3 times) 03: 15 - 03:50 0.58 STWHIP P WEXIT LD D331 in gauge wI minor chipped diamonds on shoulder. Add 3.80" window mill and 3.79" SR 03:50 - 05:25 1.58 STWHIP P WEXIT RIH wI BHA #2 Printed: 1/31/2005 8:02:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-06 V-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 1/15/2005 Rig Release: Rig Number: Spud Date: 1/5/2005 End: 1/17/2005 05:25 - 05:40 0.25 STWHIP P WEXIT Precautionary ream/backream XN nipple and no motor work. Plugged MM again wI more rubber 05:40 - 05:50 0.17 STWHIP P WEXIT Resume RIH 05:50 - 06:15 0.42 STWHIP P WEXIT Precautionary ream cement sheath area to pinch point at 10807' CTD 06:15 - 09:00 2.75 STWHIP P WEXIT Milling window. TOWhip:10772'. Pinch Point: 10776'. Several stalls getting started. 2420 psi @ 2.68 bpm. WOB: 3.52k#. 09:00 - 15:00 6.00 STWHIP P WEXIT Continue milling window. 2250 psi @ 2.65 bpm fs. 200-600 dpsi. WOB: 6.5k#. PU off btm. 45k#up, 22k#dn wt. Re-zero DH WOB. Tag at 10782'. Resume time milling. 15:00 - 16:15 1.25 STWHIP P WEXIT Continue to time mill. Stall and pick up. Appear to be out of casing. Drill ahead. Line up to swap to flo pro. Top of whipstock: 10,772' Top Window: 10776' Btm Window: 10783' 16:15 - 17:00 0.75 STWHIP P WEXIT Drill ahead to 10793'. Begin displacement to flopro. Ream and back ream window 3 passes. Drift dry. 17:00 - 19:00 2.00 STWHIP P WEXIT POOH for build assembly. Got more rubber back at mud/bio interface 19:00 - 19:40 0.67 STWHIP P WEXIT LD milling BHA. Mill 3.80", SR 3.79" (same as before RIH). Mill had center wear 19:40 - 20:50 1.17 DRILL P PROD1 MU drilling BHA 20:50 - 22:20 1.50 DRILL P PROD1 RIH w/ BHA #3 (3.0 geg, HC bi bit) 1.4/2300 thru EDC 22:20 - 00:00 1.67 DRILL P PROD1 Close EDC. Log tie-in down from 10650' to correct to mother WB 0.4/1340/3R. Corr -35' and relog to TD. Tag at 10794' w/o pump. PUH 45k and start pump PVT 386 1/18/2005 00:00 - 01 :30 1.50 DRILL P PROD1 Drill build from 10793' 2.57/3200/5R slowly while working to get orientor to work. Started 0.2 bpm losses at 10815' PVT 378 01 :30 - 02:15 0.75 DRILL P PROD1 Drill ahead 2.7/2.5/3200/30R wI 0.5k wob, 100 psi diff 9.82 ECD at 20-30'/hr PVT 366 02:15 - 02:40 0.42 DRILL P PROD1 Wiper to 10590'. Overpull/MW at 10606'. RBIH, clean 02:40 - 03:45 1.08 DRILL P PROD1 Drill ahead from 10846' 2.7/2.4/3200/35R and losses increased to 1.0 bpm in the next 4'. Slow penetration rate of 23'/hr and frequent stalls ECD 9.7 Max loss rate was 1.3 bpm 03:45 - 05:00 1.25 DRILL P PROD1 Drill ahead from 10875' 2.7/1.6/3000/55R ECD 9.7 and losses are slowly healing due to cuttings. Penetration rate is 30'/hr and increasing wI few stalls PVT 200 05:00 - 05:45 0.75 DRILL P PROD1 Drill ahead 2.66/1.5213000/60R at 55'/hr and have first survey (NBI=78 deg) and on the line. Get into some ratty drilling at 10945' w/ several stalls and losing more returns 2.66/1.4/300060R, PVT 143 05:45 - 06: 10 0.42 DRILL P PROD1 Wiper to EOT while wo mud. Clean to window, clean to above TOC. Wiper to 10500' at 2.5/1.8 PVT 100 06:10 - 07:30 1.33 DRILL N WAIT PROD1 Reduce rate while PUH slow and WO mud. 1.6 in/1.4 out 07:30 - 08:30 1.00 DRILL N WAIT PROD1 Off load 290 bbls flopro. RIH to resume drilling ahead. 08:30 - 11 :30 3.00 DRILL P PROD1 Continue to drill build section. 3100 psi fs @ 2.6 in/1.8 out. WOB: 1.4 k#. ROP: 60-80 fpm. InclAz/ Tf: 821354/11 Or. Whp/Bhp/Ecd: 2614480/9.7 ppg. IA/OA/Pvt: 4/0/300 bbls Build complete, all dog leg in turn. Lost all returns at 11027'. Continue to drill ahead. KCL and more mud on the way. IA has gone on a vacuum. TD build and turn at 11150 11 :30 - 13:30 2.00 DRILL P PROD1 Circulate OOH. Call for Little Red to MIT IA with diesel. Printed: 1/31/2005 8:02:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-06 Y-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 1/15/2005 Rig Release: Rig Number: Spud Date: 1/5/2005 End: 1118/2005 13:30 - 16:30 3.00 DRILL P PROD1 At surface. Get off well. Unstab coil. Change out motor. Rerun bit. Upload res tool, but decide not to run it this trip due to hole conditions. MU MWD assy. Fill hole at 1.2 bpm wI KCI wI no returns 16:30 - 18:10 1.67 DRILL P PROD1 RIH wI BHA #4 (1.2 deg) at 1.2140 18:10-18:50 0.67 DRILL P PROD1 Log tie-in down to RA tag, -32' corr 18:50 - 19:10 0.33 DRILL P PROD1 Wiper back to TD 2.75/0/1030. Work to get orientor to HS (10 min). Took 20 bbls to fill CT after pumping 1.2 bpm during RIH trip. Initial ECD is 7.72! before 11027' and 7.75 at 11150' (tag) 19:10 - 20:00 0.83 DRILL P PROD1 Drill ahead from 11150' 2.54/0/1050/50R wi 300 psi diff, 3k wob 60-120'/hr ECD 7.75 Pumping 100 bbls KCL followed by 30 bbls mud and more frequent smaller sweeps when drilling fast Drill to 11250' PJSM wi LRS. FilllA w/5.1 bbls diesel and PT to 2000 psi for 5 min wI no loss. Bleed IA to 200 psi. RDMO LRS 20:00 - 20:20 0.33 DRILL P PROD1 Wiper to window wi sweep at bit 45k, 26k. Clean both ways 20:20 - 21 :05 0.75 DRILL P PROD1 Drill ahead from 11250' to 11365' pump 30 bbl flo-pro sweep each 50' drilled. 21 :05 - 21 :30 0.42 DRILL P PROD1 Wiper trip to window 21 :30 - 22:25 0.92 DRILL P PROD1 Drill ahead f/11365' to 11482' pumping 2% KCL at 2.4 bpm 1400psi wo returns. 22:25 - 23:30 1.08 DRILL P PROD1 Wiper trip to TT. No problems. 23:30 - 00:00 0.50 DRILL P PROD1 Drill ahead f/11482' to 11517'. 1/19/2005 00:00 - 01 :00 1.00 DRILL P PROD1 Drill f/11517' to 11620' pumping at 2.5 bpm wo returns. annular psi=3610 01 :00 - 01 :45 0.75 DRILL P PROD1 Wiper trip to window. 01:45 - 03:10 1.42 DRILL P PROD1 Drill ahead fl 11620' to 11775 03:10 - 04:00 0.83 DRILL P PROD1 Wiper trip to TT. Back to window. 04:00 - 04:15 0.25 DRILL P PROD1 Log tie-in to RA tag. -14' correction. 04: 15 - 04:50 0.58 DRILL P PROD1 Finish wiper to bottom. No problems on wiper trip. 04:50 - 06:55 2.08 DRILL P PROD1 Drill ahead f/11775' 2.55bpm pp=2600 psi annular=3636psi. No returns 06:55 - 08:15 1.33 DRILL P PROD1 Wiper to window 2.6/2350, 47k. Temp immobile at 11820' and after two cycles resumed wiper. Overpull and MW at 11370'. Rest of hole was clean-no MW or OP's at loss zones. RBIH, clean to 11830' and set down 08:15 - 09:00 0.75 DRILL P PROD1 Had numerous set downs and overpulls from 11830-850'. Get back to TD. Backream to 11800' and shale was better. Ream back down wI motor work, but no set down to 11860'. Backream slower and had 10k overpulls and MW at 11832' and 11820'. Using mud for reaming since KCI trucks (3) are MT and in transit. Slow ream back down and getting lots of MW and only get to 11850' and set down. PUH w/15k over. Ream to 11850' and set down. Backream and now pulling 15k over with lots of MW-shale is getting worse 09:00 - 09:50 0.83 STKOH C PROD1 Wiper OOH 2.65/2080 from 11800' while discuss. Will OH sidetrack. Clean to above window and thru cement sheath 09:50 - 10:25 0.58 STKOH C PROD1 POOH at 1 O'lmin from 10600' in 7" while fill BS with 150 bbls mud (3% L T, 4 ppg KG) and flush any cuttings from 7' at 3.4 bpm/230 psi max whp wi 0.5/150 down CT to leave lubricated fluids in annulus for sidetracking 10:25 - 12:00 1.58 STKOH C PROD1 POOH for sidetracking assy 12:00 - 13:20 1.33 STKOH C PROD1 Change motor and bit Printed: 1/31/2005 8:02:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-06 Y-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 1/15/2005 Rig Release: Rig Number: Spud Date: 1/5/2005 End: 1119/2005 13:20 - 15:10 1.83 STKOH C PROD1 RIH wI BHA #5 (1.8 deg, R60ST bit) wI EDC open filling thru charge pump at 0.6 bpm 15:10 - 15:55 0.75 STKOH C PROD1 Work to get orientor HS. Log tie-in down to RA pip, corr -31'. Close EDC 15:55 - 16:30 0.58 STKOH C PROD1 RIH to KOP 47k, 28k 16:30 - 21:45 5.25 STKOH C PROD1 Cut 20' trough, but bit wants to driIl2.5/0/1950/150R. Begin time drilling from 11603' to 11610'. Pick-up drilling rate and conifrm from NB surveys of successful KO. Drill to 11650'. 21 :45 - 22:40 0.92 STKOH C PROD1 Backream up to 11575'. ream back to TD and up again to 11570'. 22:40 - 00:00 1.33 STKOH C PROD1 TOH 1/20/2005 00:00 - 00:15 0.25 STKOH C PROD1 Finish TOH 00:15 - 01:15 1.00 STKOH C PROD1 Change bits. Reset motor to a 1.2deg bend. 01:15 - 03:25 2.17 STKOH C PROD1 RIH wI BHA #6 03:25 - 04:35 1.17 STKOH C PROD1 Drill ahead f/11650' 2.55 bpm KCL ( treated with Klayguard) 2040psi annular=3595psi 7.79 ECD no returns. Pumping 30 bbl Flo-pro sweeps every 60' of hole drilled. Drilled to 11800'. 04:35 - 05:40 1.08 STKOH C PROD1 Wiper trip to window. No problems 05:40 - 06:15 0.58 STKOH C PROD1 Drill ahead f/11800' to 11875'. No returns 06:15 - 06:30 0.25 DRILL P PROD1 Drill to 11900' 06:30 - 07:15 0.75 DRILL P PROD1 Wiper to 10550', was clean 07:15 - 07:30 0.25 DRILL P PROD1 Log tie-in to RA pip, corr -4' 07:30 - 08:00 0.50 DRILL P PROD1 Wiper back to TD. Work to move orientor to right TF at critical junctures (10 min) 08:00 - 08:30 0.50 DRILL P PROD1 Drill from 11900' 2.66/0/2200/120L wI 3k wob, 250 psi diff at 80-140'/hr, ECD 7.88 wI DHP 3629 psi. Using KCI w/4ppb KG with sweeps of Flo Pro (3% L T, 14 ppg KG) 08:30 - 09:00 0.50 DRILL P PROD1 Found another sticky spot from 11920-11950'. Backream slow while circ mud to bit. Cleaned up using mud 09:00 - 09:45 0.75 DRILL P PROD1 Drill from 11949-12000' 09:45 - 11 :00 1.25 DRILL P PROD1 Wiper to window, clean both ways 11 :00 - 12:00 1.00 DRILL P PROD1 Drill from 12000-100' 2.58/0/2000/1 OOL. Swap to right side at 12050' 12:00 - 12:40 0.67 DRILL P PROD1 Wiper to window 12:40 - 12:50 0.17 DRILL P PROD1 Log tie-in to RA pip, corr -4' 12:50 - 13:20 0.50 DRILL P PROD1 Wiper to TD, clean 13:20-14:10 0.83 DRILL P PROD1 Drill from 12100' 2.5/0/2000/90R w/2-3k wob, 250 psi diff at 80-140'/hr, ECD 7.88 wI DHP 3630 psi 14:10 - 15:30 1.33 DRILL P PROD1 Wiper to window, clean both ways Check for ice in derrick and none found 15:30 - 16:20 0.83 DRILL P PROD1 Drill from 12209' 2.5/0/2000/120R w/2-3k wob, 300 psi diff at 100-140'/hr, ECD 8.08 wI DHP 3720 16:20 - 17:10 0.83 DRILL P PROD1 Wiper to 10600', clean 17:10-17:30 0.33 DRILL P PROD1 Log tie-in down to RA pip, corr -5' 17:30 - 18:10 0.67 DRILL P PROD1 Wiper to TD 18:10 - 19:00 0.83 DRILL P PROD1 Drill from 12350'. 2.56bpm 2100psi FS 3685psi annular 7.96 ECD No returns 19:00 - 20:00 1.00 DRILL P PROD1 Wiper trip to 10800' 20:00 - 20:50 0.83 DRILL P PROD1 Log tie-in minus 3' wiper trip to bottom. No problems 20:50 - 23:15 2.42 DRILL P PROD1 Drill ahead from 12475' 2.59bpm 1900 FS 3696 annular 8.02 ECD. Drilled to 12600' TD. 23:15 - 00:00 0.75 DRILL P PROD1 TOH for resistivity tool. 1/21/2005 00:00 - 02:15 2.25 DRILL P PROD1 Finish TOH. (hold PJSM review plans for BHA change and Printed: 1/31/2005 8:02:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-06 Y-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 1/15/2005 Spud Date: 1/5/2005 End: 1/21/2005 00:00 - 02:15 2.25 DRILL P PROD1 testing Crown-O-Matic) 02:15 - 02:45 0.50 DRILL P PROD1 UD BHA #6. 02:45 - 03:15 0.50 DRILL P PROD1 Setback injector. Lift blocks and test cutout for Crown-O-Matic. Tests fine. Reattach injector. 03:15 - 04:00 0.75 DRILL P PROD1 PU BHA #7 with resistivity tool. Surface test tools. 04:00 - 06:00 2.00 DRILL P PROD1 RIH wI BHA #7 (77.95') 06:00 - 06:20 0.33 DRILL P PROD1 Log tie-in down, corr -43' 06:20 - 12:45 6.42 DRILL P PROD1 Log MAD pass resistivity down at 300'/hr from 10800' 0.6/0/4. Incr rate at 11200' 2.010/1000. Tag at 12600' which is TD 12:45 - 13:30 0.75 DRILL P PROD1 Wiper OOH 50.7k at 2.5/0/2100 leaving fresh mud in OH. Minor overpulllMW at 11920'. Clean elsewhere. Pull thru window and cement sheath, clean 13:30 - 15:30 2.00 DRILL P PROD1 POOH for liner 15:30 - 16:15 0.75 DRILL P PROD1 LD drilling BHA 16:15 - 17:20 1.08 CASE P PROD1 Remove E-line head. Install E-line flow thru sub and attach e-line. RU BTT ball drop sub wI seat pinned for 1500 psi diff. Stab injector onto well. Fill CT wI KCI. Load 5/8" phenolic ball. Displace to seat. Did not pressure up, but heard fluid back-up exactly at calc displ. Pumped 16 bbls extra. Then, checked catcher and found ball. RD test equipment. Stab back on well. SI master 17:20 - 18:00 0.67 CASE N PROD1 Wait on fluids/N2 to corrosion inhibit the E-CT 18:00 - 19:30 1.50 CASE P PROD1 RU N2 equipment. Pup trailer with corrison inhibitor. RD BHi equipment. 19:30 - 19:45 0.25 CASE P PROD1 PJSM review plan forward to inhibit and clear reel with N2. 19:45 - 22:00 2.25 CASE P PROD1 Pump in coil 10bbl bleach followed by 60bbls FW then 5bbls methanol, 15bbls inhibited diesel. Blowdown with N2. Taking returns to Tiger Tank. Blowdown reel. 22:00 - 22:10 0.17 CASE P PROD1 PJSM review procedures for unstabbing coil from injector and securing to reel. 22:10 - 00:00 1.83 CASE P PROD1 Unstab injector from well. Install tree cap. Install internal grapplle to coil and remove from injector. Secure end of coil to reel. 1/22/2005 00:00 - 01 :00 1.00 CASE P PROD1 Finish securing end of coil to reel. Secure reel to bridge crane. Disconnect side drive plates. Open well no pressure on well. Start pumping 1 bpm 2% KCL down annulus. 01:00 - 01:15 0.25 CASE P PROD1 PSJM review liner running precautions and procedures. 01:15 - 05:00 3.75 CASE P PROD1 PU 84 jts of 3-3/16" 6.2# L-80 liner along with jewelry. Same time swap out coil reels. Continue filling annulus at 1 bpm 05:00 - 07:15 2.25 CASE P PROD1 MU inner reel piping. Install internal connector. Pull CT and stab coil into injector. Install BTT CTC. PT 40k 07:15 - 09:00 1.75 CASE P PROD1 Fill CT wI KCI and pump a dart after fixing a leak in hardline. Did not see dart hit, but recover dart. PT CTC and inner reel valve to 4200 psi. Continue filling BS at 1.0 bpm when possible 09:00 - 09:20 0.33 CASE P PROD1 Stab CT 09:20 - 09:30 0.17 CASE P PROD1 RIH wI liner on CT to 500'. Found formula error in BHA-have one joint too many which would have put TOL above tailpipe 'X' nipple. POOH Safety mtg re: LD one joint 09:30 - 10:30 1.00 CASE N HMAN PROD1 Set injector on legs. RU blocks and elevators. LD top joint of 3-3/16" TCII. MU BHA. Stab injector 10:30 - 11 :50 1.33 CASE P PROD1 RIIH wI liner on CT pumping KC11.0/150 wI no returns Printed: 1/31/2005 8:02:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-06 Y-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 1/15/2005 Rig Release: Rig Number: Spud Date: 1/5/2005 End: 1/22/2005 10:30 - 11 :50 1.33 CASE P PROD1 MIRU DS cementers 11 :50 - 12:40 0.83 CASE P PROD1 11600' 48.7k, 26k Swap to pumping down BS at 1.0 bpm to save mud in OH. Clean thru window, but saw every cementralizer go thru window. RIH at 50'/min. Set down at 11920' (uncorrected), but forge ahead, 20.2k. Set down at 12077', PUH 57k. Set down several more times and pickups were fairly clean. Max pull was 67k. Get to TD w/15k and tagged at 12637' CTD (drilled TD is 12600') which is a normal correction. PUH 67k and verify no more progress 12:40 - 13:20 0.67 CASE P PROD1 Swap to pumping down CT and caught fluid after 8 bbls and circ 2.4/0/1440. Load 518" aluminum ball and circ 2.510/1450 to seat slowing to 1.0/66 last 20 bbls. Ball seat sheared at 2850 psi. PUH 39.5k and released from liner Safety mtg re: cementing 13:20 - 14:00 0.67 CEMT P PROD1 Resume circ down CT wI no returns at 1.1/0/95. Cementers batch up and PT to 4600 psi 14:00 - 14:30 0.50 CEMT P PROD1 DS load CT wI 23.1 bbls 15.8 ppg 'G' cement wI latex at 2.0/1230. Load wiper dart 14:30 - 15:10 0.67 CEMT P PROD1 Rig displace cement wi 25 bbls biozan followed by KCI at 2.5/0/1760 IA 70. Red rate to 1.5/200 before latching up near calc displ and sheared at 2850 psi. Incr rate to 2.6/2100 for first 10 bbls, then red rate to 1.66/900 until LWP bumped at calc displ. Pressure up to 1500 psi and held. Unsting at 36.5k 15:10 - 16:35 1.42 CEMT P PROD1 POOH 1.010/125 16:35 - 17:00 0.42 CEMT P PROD1 LD BTT CTLRT. MU nozzle assy 17:00 - 18:40 1.67 CEMT P PROD1 RIH wi BHA #9 tagged TOL at 9984' (uncorrected coil depth) PU hole to 9950'. 18:40 - 20:45 2.08 CEMT P PROD1 Pumping down coil 1 bpm. RU Little Red and diesel transport while waiting on 2nd batch of cement. 20:45 - 20:55 0.17 CEMT P PROD1 PJSM review plan forward for loading annulus with diesel. 20:55 - 22:10 1.25 CEMT P PROD1 With LR preheating diesel, useing pump #1 to load annulus with diesel thru kill line, choke line closed. Pumping KCL at min rate down coil. R/U SWS cementers Start Rates/Pressures: DiesellAnnulus 2bpm Opsi Coil O.4bpm Opsi Final: annulus 286psi stabilized coil Opsi 22:10 - 22:25 0.25 CEMT P PROD1 PJSM review plan forward with all personnel. 22:25 - 23:00 0.58 CEMT P PROD1 Cementers batch up and PT lines to 4000psi 23:00 - 23:45 0.75 CEMT P PROD1 With end of CT at 9950' load with 33 bbls 15.8 ppg 'G' cement wladditives follow wi 5 bbls FW. (coil vol = 60bbls) After displacing 22 bbls of cement from coil using diesel seen increase in displacement pressure. Pressures as follows all at 1.5bpm rate 22 bbls away 135psi, 26 bbls/190. 27bbls/270, 29bbls/432, 31 bbls,560, 33bbls/674 pumped another 2 bbls of displacement to put TOC at +1- 10050' final pressure 71 Opsi 23:45 - 00:00 0.25 CEMT P PROD1 TOH displacing 1:1 to safety. 1/23/2005 00:00 - 00:35 0.58 CEMT P PROD1 TOH to safety at 7000'. Monitor pressures and WOC 00:35 - 05:00 4.42 CEMT P PROD1 WOC. Annulus pressure 31 Opsi @ 00:30 385psi @ 0400 and @ 0500 05:00 - 06:15 1.25 CEMT P PROD1 UCA on cement 800psi. RIH to 9950' loading coil with KCL. Displace well bore back to KCL. 06:15 - 07:30 1.25 CEMT P PROD1 POOH while fin circ well bore to KCI I i Printed: 1/31/2005 8:02:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-06 Y-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 1/15/2005 Rig Release: Rig Number: Spud Date: 1/5/2005 End: 1/23/2005 06:15 - 07:30 1.25 CEMT P PROD1 Rig evac drill when at 1200' 07:30 - 08:00 0.50 CEMT P PROD1 Tag up, hole is full. LD cementing assy 08:00 - 08:15 0.25 CEMT P PROD1 Safety mtg re: BHA and GR tool 08:15 - 09:00 0.75 CEMT P PROD1 RU floor tools. MU used 2.78" D331 mill, 2-1/8" motor, 2 jts CSH, GR carrier 09:00 - 11 :45 2.75 CEMT P PROD1 Pick up 821-1/4" CSH singles 11 :45 - 13:00 1.25 CEMT P PROD1 RIH wI cleanout assy (BHA #10) 13:00 - 13:15 0.25 CEMT P PROD1 9900' Sync wI SWS logger. 36k, 19.4k RIH 0.4/360 looking for cement and set down at 9998' CTD. PUH 40k, start motor 1.50/2800. Ream down from 9970' and stalled at 10000.0' (assume this is the TOL, but could be 'X' nipple-normal correction here would be 20-25', but log will determine) 13:15 - 14:00 0.75 CEMT P PROD1 Drill cement 1.5/1.5/2750-not sliding well. Add some biozan PVT 305 Make steady progress after two stalls and 20 min at 10000.0' 14:00 - 16:30 2.50 CEMT P PROD1 Stall at 10003.9' after getting greedy. Stalls at 10008.5', 10009.5', 10018.6', 10018.8', 10034' Ream to 10075' 1.52/2250 PVT 303 16:30 - 18:00 1.50 CEMT P PROD1 POOH to LD SWS logging tool before it is trash and to change to a smaller mill 18:00-18:10 0.17 CEMT P PROD1 PJSM with oncoming crews review standing back small tubulars. 18:10 - 20:10 2.00 CEMT P PROD1 Standback 41 stds of 1-1/4" CSH and UD SWS GR memory carrier. 20:10 - 22:00 1.83 CEMT P PROD1 P/U 2.74" D331 mill on BHA #11 (2659.41') RIH with CSH. Stab on injector. 22:00 - 23:45 1.75 CEMT P PROD1 RIH tagged at 10070'. 36.5k up 17k dwn 23:45 - 00:00 0.25 CEMT P PROD1 Drill cement fl1 0070' 1.5/1900 1/24/2005 00:00 - 03:00 3.00 CEMT P PROD1 Drilled cement f/1 0078' to 10260' full returns. 03:00 - 05:00 2.00 CEMT P PROD1 Cleanout down to 12525'. (uncorrected depth. Actual depth +1- 12495') Drilled cement to 12597.6' corrected depth +1- 12567' 05:00 - 07:45 2.75 CEMT P PROD1 Backream to TOL then ream to PBTD 07:45 - 10:45 3.00 CEMT P PROD1 Leave 20 bbls bleach in liner for perforating, then POOH displacing well bore to clean KCI. Load 5/8" steel ball when SD to swap trucks and circ to circ sub 1.51/2080 while fin displacement. Ball did not clear gooseneck (not enough rate-limited by motor) 10:45 - 12:45 2.00 CEMT P PROD1 OOH. Set back injector. Drop second 5/8" ball down CSH and open circ sub. Stand back CSH. LD motor and mill. Concurrently, circ thru bung hole at high rate and heard ball go over gooseneck 12:45 - 13:00 0.25 EVAL P PROD1 Safety mtg re: RU logging tools 13:00 - 16:00 3.00 EVAL P PROD1 Bring cement bond log tools to floor and RU (44'). RIH to 10950' where maximum deviation of 82 deg halted descent. Log up to 9500' to catch jewelry from new completion. All depths corrected to RA pip at 10783'. Found TOL at 9957' vs tally depth of 9961'. POOH 16:00 - 17:00 1.00 EVAL P PROD1 RU and pressure test liner at 3000 psi for 30 min wI KCI wI IA at 200 psi while evaluate log. Lost 130 psi on tubing and 10 psi on IA-DS CTDS has data 17:00 - 17:30 0.50 EVAL P PROD1 RD e-line unit 17:30 - 18:00 0.50 PERFO P OTHCMP WO perf guns 18:00 - 19:00 1.00 PERFO P OTHCMP Load and sort 2" perf guns in pipe shed. Printed: 1/31/2005 8:02:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Y-06 Y-06 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 1/15/2005 Rig Release: Rig Number: Spud Date: 1/5/2005 End: PJSM review perf gun handling procedures and hazards. P/U 174' of 2" 6spf 2006PJ'perf guns ( 100' loaded) wI RIH w/42 stds 1-1/4" CSH from derrick. (BHA #12 2788.32') 22:00 - 00:00 2.00 OTHCMP MU injector. RIH tagged at 12588' PU get weight back and correct depth to 12560'. Load coil with 10 bbls bleach followed by 10 bbls KCL water. 1/25/2005 00:00 - 01 :00 OTHCMP Load and lauch .500" steel ball. Pumping at 1.6bpm 2300 psi slow to 1 bpm after 50 bbls away. Ball on set at 60 bbls. Pressure up to 2600ps and guns fired while moving coil up hole. Good weight indicator flucuations when fired. Hole drank 5 bbls. Perf interval: 12200'-12250 12300'-12350' 6spf 01 :00 - 03:20 2.33 PERFO OTHCMP TOH filling hole through kill line to BHA. Standback injector. Trip sheet shows 1 bbllost. 03:20 - 06:00 2.67 PERFO OTHCMP UD 84jts 1-1/4" CSH 06:00 - 07:10 1.17 PERFO OTHCMP LD perf guns-all shots fired. Load out guns 07:10 - 07:30 0.33 RUNCO RUNCMP MU nozzle BHA and stab onto well 07:30 - 08:50 1.33 RUNCO RUNCMP RIH wi nozzle pumping diesel to 2500'. POOH FP wellbore wI 35 bbls recycled diesel. Send rest of diesel to GC2 slop oil tank MIRU DS N2. SI master 08:50 - 09: 10 0.33 RIGD P POST Safety mtg re: N2 blowdown 09:10 - 11 :00 1.83 RIGD P POST PT DS @ 4000. Blow down CT wi N2 and bleed off to tiger tank 11 :00 - 12:00 1.00 RIGD P POST Cut off CTC. Prep CT and pullback to reel and secure Fin clean pits 12:00 - 16:00 4.00 RIGD P POST Release Rig at 15:30. Further telex entries carried on the DIMS report for well 15-42. Printed: 1/31/2005 8:02:59 AM ObP . Baker Hughes INTEQ. Survey Report Map Coords iNTEQ Company: BP Amoco Date: 1/26/2005 Time: 14:06:03 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-06, True North Site: PB Y Pad Vertical (TVD) Reference: 8 : 06 2/2/1980 00:00 81.3 Well: Y-06 Section (VS) Reference: Well (0.OON,0.00E,57.00Azi) Wellpath: Y-06A Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska. Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: PB Y Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: 5948541.48 ft Latitude: 70 16 0.041 N From: Map Easting: 647748.73 ft Longitude: 148 48 18.991 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.12 deg Well: Y-06 Slot Name: 06 Y-06 Well Position: +N/-S 453.64 ft Northing: 5948941.98 ft Latitude: 70 16 4.498 N +E/-W -2701.55 ft Easting : 645039.00 ft Longitude: 148 49 37.627 W Position Uncertainty: 0.00 ft Wellpath: Y-06A . Drilled From: Y -06APB 1 50029:a9958e+ .;l. 0 '1. 31 - ()I-O\) Tie-on Depth: 11529.62 ft Current Datum: 8 : 06 2/2/1980 00:00 Height 81.30 ft Above System Datum: Mean Sea Level Magnetic Data: 1/19/2005 Declination: 24.84 deg Field Strength: 57620 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 32.30 0.00 0.00 57.00 Annotation MD TVD ft ft 11564.55 8997.43 TIP 10773.00 8945.15 KOP 12600.00 9063.51 TO - Projected Depth Survey: Start Date: Company: Engineer: Tool: Tied-to: Survey MD Incl Azim TVD SSTVD NIS EIW MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 32.30 0.00 0.00 32.30 -49.00 0.00 0.00 5948941.98 645039.00 0.00 0.00 100.00 0.22 82.04 100.00 18.70 0.02 0.13 5948942.00 645039.12 0.12 0.32 200.00 0.27 109.56 200.00 118.70 -0.03 0.54 5948941.96 645039.54 0.43 0.13 300.00 0.37 96.80 300.00 218.70 -0.15 1.08 5948941.85 645040.08 0.83 0.12 400.00 0.42 118.92 400.00 318.70 -0.37 1.72 5948941.65 645040.73 1.25 0.16 500.00 0.38 146.57 499.99 418.69 -0.82 2.23 5948941.20 645041.24 1.42 0.20 600.00 0.38 82.10 599.99 518.69 -1.05 2.74 5948940.98 645041.76 1.72 0.41 700.00 0.37 93.74 699.99 618.69 -1.03 3.39 5948941.02 645042.41 2.28 0.08 800.00 0.25 89.58 799.99 718.69 -1.05 3.93 5948941.01 645042.95 2.73 0.12 900.00 0.45 99.44 899.99 818.69 -1.11 4.54 5948940.96 645043.55 3.20 0.21 1000.00 0.32 155.45 999.98 918.68 -1.43 5.04 5948940.65 645044.06 3.45 0.38 1100.00 0.37 155.68 1099.98 1018.68 -1.98 5.29 5948940.11 645044.32 3.36 0.05 1200.00 0.53 134.44 1199.98 1118.68 -2.59 5.75 5948939.50 645044.80 3.41 0.23 1300.00 0.62 152.57 1299.97 1218.67 -3.40 6.33 5948938.71 645045.39 3.46 0.20 1400.00 0.57 134.56 1399.97 1318.67 -4.23 6.93 5948937.89 645046.01 3.51 0.19 1500.00 0.37 126.86 1499.96 1418.66 -4.77 7.55 5948937.36 645046.63 3.73 0.21 1600.00 0.42 141.68 1599.96 1518.66 -5.25 8.03 5948936.89 645047.13 3.88 0.11 :z. 0\../- ~~-( ObP . Baker Hughes INTEQ. Survey Report Map Coords BíI. IIAKD. IIUGHIS INTEQ Company: BP Amoco Date: 1/26/2005 Time: 14:06:03 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-06, True North Site: PB Y Pad Vertical (TVD) Reference: 8: 062/2/198000:0081.3 Well: Y-06 Section (VS) Reference: Well (0.00N,O.00E,57.00Azi) Wellpath: Y -06A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S EIW MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/1000 1700.00 0.25 107.86 1699.96 1618.66 -5.61 8.47 5948936.54 645047.57 4.05 0.25 1800.00 0.23 120.92 1799.96 1718.66 -5.78 8.85 5948936.38 645047.95 4.27 0.06 1900.00 0.37 114.62 1899.96 1818.66 -6.01 9.31 5948936.15 645048.42 4.54 0.14 2000.00 0.40 99.68 1999.96 1918.66 -6.21 9.95 5948935.97 645049.06 4.97 0.10 2100.00 0.47 89.40 2099.95 2018.65 -6.26 10.71 5948935.93 645049.82 5.57 0.10 2200.00 0.32 71.22 2199.95 2118.65 -6.17 11.38 5948936.03 645050.49 6.19 0.19 2300.00 0.03 272.98 2299.95 2218.65 -6.08 11.62 5948936.13 645050.73 6.43 0.35 2400.00 0.97 51.52 2399.95 2318.65 -5.55 12.25 5948936.67 645051.35 7.26 0.99 2500.00 0.37 46.52 2499.94 2418.64 -4.80 13.15 5948937.44 645052.24 8.42 0.60 2600.00 0.82 54.28 2599.93 2518.63 -4.16 13.97 5948938.09 645053.04 9.45 0.46 2700.00 0.30 76.28 2699.93 2618.63 -3.68 14.80 5948938.59 645053.87 10.41 0.55 2800.00 0.77 165.63 2799.92 2718.62 -4.27 15.22 5948938.01 645054.30 10.44 0.82 2900.00 0.67 182.40 2899.92 2818.62 -5.50 15.37 5948936.78 645054.46 9.89 0.23 3000.00 1.63 291.80 2999.90 2918.60 -5.56 14.02 5948936.69 645053.12 8.73 1.96 3100.00 3.95 290.74 3099.78 3018.48 -3.81 9.48 5948938.35 645048.55 5.87 2.32 3200.00 6.08 300.56 3199.39 3118.09 0.10 1.70 5948942.12 645040.69 1.48 2.29 3300.00 7.93 298.86 3298.64 3217.34 6.12 -8.91 5948947.93 645029.97 -4.13 1.86 3400.00 10.25 299.56 3397.38 3316.08 13.84 -22.69 5948955.38 645016.05 -11.49 2.32 3500.00 12.33 301.86 3495.44 3414.14 23.87 -39.50 5948965.08 644999.05 -20.13 2.13 3600.00 14.97 304.62 3592.61 3511.31 36.85 -59.20 5948977.68 644979.10 -29.58 2.72 3700.00 17.65 305.68 3688.57 3607.27 53.03 -82.15 5948993.41 644955.85 -40.01 2.70 3800.00 20.33 307.44 3783.12 3701.82 72.44 -108.26 5949012.31 644929.37 -51.34 2.74 3900.00 23.42 307.74 3875.91 3794.61 95.17 -137.77 5949034.47 644899.42 -63.72 3.09 4000.00 26.20 308.74 3966.67 3885.37 121.15 -170.72 5949059.81 644865.99 -77.19 2.81 4100.00 29.13 308.98 4055.23 3973.93 150.28 -206.86 5949088.24 644829.29 -91.64 2.93 4200.00 32.67 309.44 4141.02 4059.72 182.75 -246.64 5949119.93 644788.90 -107.32 3.55 4300.00 35.20 308.98 4223.98 4142.68 218.03 -289.90 5949154.37 644744.97 -124.38 2.54 4400.00 35.38 307.92 4305.61 4224.31 253.95 -335.14 5949189.41 644699.05 -142.76 0.64 4500.00 37.07 304.62 4386.28 4304.98 288.87 -382.79 5949223.40 644650.74 -163.70 2.58 4600.00 38.40 303.74 4465.37 4384.07 323.25 -433.42 5949256.79 644599.46 -187.44 1.43 4700.00 39.47 303.74 4543.15 4461.85 358.15 -485.68 5949290.68 644546.54 -212.26 1.07 4800.00 40.28 303.86 4619.90 4538.60 393.82 -538.95 5949325.31 644492.60 -237.52 0.81 4900.00 40.97 304.56 4695.80 4614.50 430.43 -592.80 5949360.87 644438.06 -262.73 0.83 5000.00 41.47 305.44 4771.01 4689.71 468.22 -646.77 5949397.62 644383.37 -287.42 0.77 5100.00 42.30 304.86 4845.46 4764.16 506.66 -701.36 5949434.99 644328.06 -312.27 0.92 5200.00 43.67 305.44 4918.61 4837.31 545.91 -757.10 5949473.16 644271.57 -337.64 1.43 5300.00 44.78 305.44 4990.27 4908.97 586.36 -813.93 5949512.50 644213.98 -363.27 1.11 5400.00 44.92 305.98 5061.17 4979.87 627.52 -871.19 5949552.55 644155.94 -388.87 0.41 5500.00 44.98 305.80 5131.94 5050.64 668.94 -928.43 5949592.85 644097.92 -414.32 0.14 5600.00 45.47 305.92 5202.37 5121.07 710.52 -985.96 5949633.32 644039.60 -439.92 0.50 5700.00 45.33 305.80 5272.59 5191.29 752.23 -1043.67 5949673.91 643981.11 -465.60 0.16 5800.00 45.52 305.92 5342.77 5261.47 793.96 -1101.40 5949714.51 643922.59 -491.29 0.21 5900.00 45.72 305.68 5412.72 5331.42 835.77 -1159.37 5949755.19 643863.83 -517.13 0.26 6000.00 45.27 305.62 5482.81 5401.51 877.34 -1217.32 5949795.63 643805.09 -543.10 0.45 6100.00 45.67 305.68 5552.94 5471.64 918.89 -1275.25 5949836.06 643746.38 -569.05 0.40 6200.00 45.75 305.56 5622.77 5541.47 960.58 -1333.44 5949876.61 643687.40 -595.15 0.12 6300.00 45.75 304.86 5692.55 5611.25 1001.87 -1391.96 5949916.78 643628.10 -621.74 0.50 6400.00 45.65 304.80 5762.39 5681.09 1042.75 -1450.71 5949956.51 643568.58 -648.74 0.11 6500.00 45.62 304.98 5832.31 5751.01 1083.64 -1509.35 5949996.26 643509.17 -675.65 0.13 6600.00 45.50 304.74 5902.33 5821.03 1124.45 -1567.93 5950035.93 643449.81 -702.56 0.21 6700.00 45.17 305.50 5972.63 5891.33 1165.37 -1626.11 5950075.71 643390.86 -729.06 0.63 6800.00 44.97 305.44 6043.25 5961.95 1206.45 -1683.77 5950115.67 643332.43 -755.05 0.20 6900.00 44.40 305.98 6114.35 6033.05 1247.49 -1740.87 5950155.61 643274.55 -780.58 0.68 ObP . Baker Hughes INTEQ. Survey Report Map Coords B¡¡. BAKUt IIUGMIS INTEQ Company: BP Amoco Date: 1/26/2005 Time: 14:06:03 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-06, True North Site: PB Y Pad Vertical (fVD) Reference: 8: 062/2/198000:0081.3 Well: Y-06 Section (VS) Reference: Well (0.00N,O.OOE,57.00Azi) Wellpath: Y -06A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD loci Azim TVD SSTVD N/S EIW MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/10Oft 7000.00 43.90 306.56 6186.10 6104.80 1288.70 -1797.02 5950195.72 643217.61 -805.24 0.64 7100.00 43.45 306.86 6258.43 6177.13 1329.98 -1852.38 5950235.92 643161.47 -829.18 0.50 7200.00 42.87 307.50 6331.37 6250.07 1371.31 -1906.89 5950276.19 643106.19 -852.38 0.73 7300.00 43.25 307.74 6404.44 6323.14 1412.99 -1960.97 5950316.82 643051.32 -875.03 0.41 7400.00 43.42 308.56 6477.17 6395.87 1455.38 -2014.93 5950358.16 642996.55 -897.21 0.59 7500.00 43.95 308.98 6549.49 6468.19 1498.63 -2068.78 5950400.36 642941.88 -918.81 0.60 7600.00 44.37 309.98 6621.23 6539.93 1542.93 -2122.55 5950443.61 642887.28 -939.78 0.81 7700.00 44.78 310.80 6692.46 6611.16 1588.41 -2176.00 5950488.05 642832.96 -959.84 0.71 7800.00 44.97 312.50 6763.33 6682.03 1635.30 -2228.72 5950533.91 642779.35 -978.52 1.21 7900.00 44.75 312.62 6834.21 6752.91 1683.00 -2280.68 5950580.60 642726.49 -996.11 0.24 8000.00 44.50 312.80 6905.38 6824.08 1730.65 -2332.29 5950627.24 642673.97 -1013.44 0.28 8100.00 43.47 313.50 6977.33 6896.03 1778.14 -2382.96 5950673.75 642622.40 -1030.07 1.14 8200.00 42.75 314.81 7050.34 6969.04 1825.74 -2431.99 5950720.39 642572.47 -1045.27 1.15 8300.00 42.17 315.68 7124.11 7042.81 1873.68 -2479.52 5950767.40 642524.02 -1059.03 0.83 8400.00 41.42 317.45 7198.67 7117.37 1922.06 -2525.35 5950814.89 642477.28 -1071.10 1.40 8500.00 40.10 311.98 7274.44 7193.14 1967.99 -2571.67 5950859.91 642430.08 -1084.94 3.81 8600.00 39.92 306.44 7351.06 7269.76 2008.60 -2621.44 5950899.55 642379.54 -1104.56 3.57 8700.00 40.32 305.44 7427.53 7346.23 2046.42 -2673.62 5950936.36 642326.65 -1127.72 0.76 8800.00 40.57 306.80 7503.63 7422.33 2084.66 -2726.01 5950973.58 642273.53 -1150.84 0.92 8900.00 41.12 309.74 7579.29 7497.99 2125.17 -2777.34 5951013.08 642221.44 -1171.83 2.00 9000.00 42.03 311.56 7654.10 7572.80 2168.40 -2827.68 5951055.33 642170.28 -1190.50 1.51 9100.00 42.37 312.56 7728.18 7646.88 2213.40 -2877.55 5951099.36 642119.56 -1207.81 0.75 9200.00 42.15 313.62 7802.19 7720.89 2259.34 -2926.66 5951144.34 642069.57 -1223.98 0.75 9300.00 42.02 314.68 7876.40 7795.10 2306.02 -2974.75 5951190.09 642020.60 -1238.88 0.72 9400.00 42.42 315.51 7950.46 7869.16 2353.62 -3022.18 5951236.75 641972.26 -1252.74 0.69 9500.00 43.08 314.86 8023.89 7942.59 2401.77 -3070.03 5951283.97 641923.50 -1266.64 0.79 9600.00 43.90 315.56 8096.44 8015.14 2450.61 -3118.51 5951331.87 641874.09 -1280.70 0.95 9700.00 43.65 317.51 8168.65 8087.35 2500.82 -3166.10 5951381.14 641825.54 -1293.27 1.37 9800.00 42.65 319.75 8241.61 8160.31 2552.13 -3211.30 5951431.57 641779.36 -1303.24 1.83 9900.00 41.68 322.51 8315.74 8234.44 2604.37 -3253.43 5951482.99 641736.24 -1310.12 2.09 10000.00 42.93 318.75 8389.71 8308.41 2656.36 -3296.13 5951534.14 641692.55 -1317.61 2.82 10100.00 44.62 315.62 8461.92 8380.62 2707.08 -3343.16 5951583.94 641644.56 -1329.43 2.75 10200.00 44.98 315.98 8532.88 8451.58 2757.60 -3392.28 5951633.50 641594.47 -1343.11 0.44 10300.00 44.87 317.92 8603.68 8522.38 2809.19 -3440.48 5951684.15 641545.29 -1355.43 1.37 10400.00 44.77 319.56 8674.62 8593.32 2862.18 -3486.97 5951736.23 641497.80 -1365.56 1.16 10500.00 44.45 320.86 8745.81 8664.51 2916.14 -3531.91 5951789.31 641451.83 -1373.87 0.97 10600.00 43.67 324.98 8817.69 8736.39 2971.58 -3573.83 5951843.93 641408.85 -1378.83 2.97 10700.00 42.25 325.81 8890.87 8809.57 3027.67 -3612.54 5951899.25 641369.07 -1380.74 1.53 10773.00 41.68 325.93 8945.15 8863.85 3068.07 -3639.93 5951939.12 641340.91 -1381.71 0.79 10800.89 47.03 333.64 8965.10 8883.80 3084.92 -3649.67 5951955.78 641330.85 -1380.70 27.20 10832.29 56.27 340.58 8984.57 8903.27 3107.60 -3659.14 5951978.26 641320.95 -1376.29 34.12 10864.52 64.62 346.46 9000.47 8919.17 3134.46 -3667.02 5952004.97 641312.55 -1368.27 30.37 10890.70 71.31 354.43 9010.30 8929.00 3158.36 -3671.00 5952028.78 641308.10 -1358.60 38.05 10931.75 81.92 354.39 9019.79 8938.49 3198.04 -3674.89 5952068.39 641303.46 -1340.24 25.85 10963.26 87.37 5.30 9022.73 8941.43 3229.36 -3674.96 5952099.69 641302.78 -1323.25 38.56 11004.03 90.05 20.63 9023.66 8942.36 3268.95 -3665.84 5952139.45 641311.14 -1294.03 38.16 11032.05 87.50 31.11 9024.26 8942.96 3294.12 -3653.63 5952164.85 641322.85 -1270.09 38.48 11068.83 85.07 42.93 9026.65 8945.35 3323.38 -3631.58 5952194.52 641344.34 -1235.66 32.74 11102.78 85.73 54.64 9029.38 8948.08 3345.63 -3606.17 5952217.26 641369.31 -1202.22 34.44 11135.41 86.06 65.95 9031.72 8950.42 3361.73 -3577.95 5952233.90 641397.22 -1169.79 34.59 11168.61 87.87 69.58 9033.48 8952.18 3374.28 -3547.26 5952247.03 641427.65 -1137.22 12.20 11199.62 90.63 73.06 9033.89 8952.59 3384.20 -3517.90 5952257.52 641456.82 -1107.19 14.32 ObP . Baker Hughes INTEQ. Survey Report Map Coords Biií. II.AKU. HUGIll. INTEQ Company: BP Amoco Date: 1/26/2005 Time: 14:06:03 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-06, True North Site: PB Y Pad Vertical (TVD) Reference: 8 : 062/2/198000:0081.3 Well: Y-06 Section (VS) Reference: Well (0.ooN,0.00E,57.00Azi) Wellpath: Y-06A Snrvey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 11233.91 92.87 77.10 9032.84 8951.54 3393.03 -3484.79 5952266.98 641489.75 -1074.61 13.47 11262.16 93.49 80.69 9031.27 8949.97 3398.46 -3457.11 5952272.94 641517.31 -1048.45 12.88 11297.19 95.27 86.54 9028.60 8947.30 3402.34 -3422.42 5952277.50 641551.92 -1017.23 17.41 11326.28 94.26 89.15 9026.18 8944.88 3403.43 -3393.45 5952279.14 641580.86 -992.35 9.59 11362.09 95.59 85.83 9023.10 8941.80 3404.99 -3357.82 5952281.39 641616.46 -961.61 9.96 11393.99 95.67 83.53 9019.97 8938.67 3407.94 -3326.21 5952284.94 641648.00 -933.50 7.18 11429.89 97.01 81.52 9016.01 8934.71 3412.58 -3290.83 5952290.26 641683.27 -901.30 6.70 11461.27 98.63 78.42 9011.74 8930.44 3417.99 -3260.23 5952296.26 641713.77 -872.68 11.06 11491.34 97.96 77.28 9007.40 8926.10 3424.25 -3231.14 5952303.08 641742.73 -844.88 4.36 11529.62 97.39 70.13 9002.28 8920.98 3434.89 -3194.75 5952314.42 641778.90 -808.57 18.57 11564.55 98.58 65.41 8997.43 8916.13 3447.97 -3162.74 5952328.12 641810.65 -774.59 13.81 11602.61 100.64 61.91 8991.07 8909.77 3464.62 -3129.11 5952345.40 641843.95 -737.33 10.56 11632.01 96.01 65.66 8986.81 8905.51 34 77.46 -3103.03 5952358.74 641869.78 -708.46 20.18 11666.04 93.73 69.37 8983.93 8902.63 3490.42 -3071.70 5952372.30 641900.85 -675.13 12.76 11699.33 94.15 73.70 8981.64 8900.34 3500.94 -3040.21 5952383.43 641932.13 -642.99 13.04 11730.85 93.00 69.89 8979.67 8898.37 3510.76 -3010.33 5952393.83 641961.81 -612.58 12.60 11760.77 94.20 65.58 8977.79 8896.49 3522.07 -2982.70 5952405.66 641989.21 -583.25 14.93 11791.59 96.09 63.72 8975.03 8893.73 3535.21 -2954.97 5952419.34 642016.69 -552.83 8.59 11822.27 95.95 61.87 8971.81 8890.51 3549.16 -2927.83 5952433.80 642043.55 -522.47 6.01 11852.55 94.82 58.89 8968.97 8887.67 3564.06 -2901.63 5952449.20 642069.46 -492.38 10.48 11887.59 94.39 53.89 8966.15 8884.85 3583.39 -2872.55 5952469.09 642098.16 -457.47 14.28 11916.79 92.72 51.71 8964.34 8883.04 3601.01 -2849.34 5952487.15 642121.02 -428.41 9.39 11947.62 91.18 50.64 8963.29 8881.99 3620.32 -2825.34 5952506.92 642144.65 -397.76 6.08 11980.17 88.88 49.83 8963.27 8881.97 3641.14 -2800.32 5952528.22 642169.26 -365.44 7.49 12013.43 87.00 46.25 8964.47 8883.17 3663.36 -2775.61 5952550.91 642193.54 -332.61 12.15 12049.90 87.99 44.18 8966.07 8884.77 3689.03 -2749.75 5952577.06 642218.89 -296.94 6.29 12083.75 87.19 47.68 8967.49 8886.19 3712.54 -2725.45 5952601.04 642242.73 -263.76 10.60 12119.08 88.63 52.31 8968.78 8887.48 3735.23 -2698.41 5952624.25 642269.32 -228.73 13.72 12153.44 90.08 55.80 8969.16 8887.86 3755.40 -2670.60 5952644.94 642296.74 -194.42 11.00 12184.35 90.32 59.07 8969.06 8887.76 3772.03 -2644.56 5952662.08 642322.46 -163.52 10.61 12216.83 90.72 63.91 8968.76 8887.46 3787.53 -2616.03 5952678.12 642350.68 -131.15 14.95 12251.10 87.96 68.15 8969.16 8887.86 3801.45 -2584.72 5952692.64 642381.71 -97.31 14.76 12284.98 85.65 71.50 8971.05 8889.75 3813.11 -2552.98 5952704.91 642413.22 -64.34 12.00 12313.18 82.35 74.13 8973.99 8892.69 3821.40 -2526.19 5952713.71 642439.84 -37.36 14.93 12348.09 78.03 75.27 8979.94 8898.64 3830.48 -2493.02 5952723.42 642472.83 -4.60 12.79 12380.08 74.16 76.45 8987.63 8906.33 3838.06 -2462.92 5952731.59 642502.78 24.78 12.62 12414.52 70.89 79.32 8997.97 8916.67 3844.96 -2430.81 5952739.11 642534.75 55.47 12.38 12444.37 70.51 83.23 9007.84 8926.54 3849.24 -2402.97 5952743.91 642562.50 81.15 12.43 12470.42 68.81 87.79 9016.90 8935.60 3851.15 -2378.63 5952746.30 642586.79 102.61 17.66 12499.74 69.19 91.58 9027.41 8946.11 3851.30 -2351.26 5952746.98 642614.15 125.64 12.14 12534.28 69.13 96.05 9039.70 8958.40 3849.16 -2319.06 5952745.45 642646.38 151.47 12.10 12562.06 68.66 99.10 9049.71 8968.41 3845.74 -2293.38 5952742.53 642672.13 171.16 10.38 12600.00 68.66 99.10 9063.51 8982.21 3840.15 -2258.48 5952737.62 642707.12 197.38 0.00 ~ .'4!> ObP . Baker Hughes 1NTE?e Survey Report Map Coords Ríí. BAKER HUGHES INTEQ Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe Bay PB Y Pad Y-06 Y -06A Date: 2/3/2005 Time: 13:44:43 Page: 1 Co-ordinate(NE) Reference: Well: Y-06, True North Vertical (TVD) Reference: 14: 107/5/1981 00:0085.7 Section (VS) Reference: Well (0.00N,O.00E,57.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: PB Y Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948541.48 ft 647748.73 ft Latitude: 70 16 Longitude: 148 48 North Reference: Grid Convergence: 0.041 N 18.991 W True 1.12 deg Well: Y-06 Slot Name: 06 Y-06 Well Position: +N/-S 453.64 ft Northing: 5948941.98 ft Latitude: 70 16 4.498 N +E/-W -2701.55 ft Easting : 645039.00 ft Longitude: 148 49 37.627 W Position Uncertainty: 0.00 ft Wellpath: Y -06A Drilled From: Y-06APB1 50029~ "ð4Ji-ð1-l:\ð Tie-on Depth: 11529.62 ft Current Datum: 8 : 06 2/2/1980 00:00 Height 81.30 ft Above System Datum: Mean Sea Level Magnetic Data: 1/19/2005 Declination: 24.84 deg Field Strength: 57620 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 32.30 0.00 0.00 57.00 Annotation 11564.55 9001.83 TIP 10773.00 8949.55 KOP 12600.00 4.40 TD - Projected Depth Survey: MWD Start Date: 1/26/2005 Company: Baker Hughes Incorporated Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Survey MD Incl Azim TVD SSTVD NIS EIW MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/10Oft 10773.00 41.68 325.93 8949.55 8863.85 3068.07 -3639.93 5951939.12 641340.91 -1381.71 0.00 10800.89 47.03 333.64 8969.50 8883.80 3084.92 -3649.67 5951955.78 641330.85 -1380.70 27.20 10832.29 56.27 340.58 8988.97 8903.27 3107.60 -3659.14 5951978.26 641320.95 -1376.29 34.12 10864.52 64.62 346.46 9004.87 8919.17 3134.46 -3667.02 5952004.97 641312.55 -1368.27 30.37 10890.70 71.31 354.43 9014.70 8929.00 3158.36 -3671.00 5952028.78 641308.10 -1358.60 38.05 10931.75 81.92 354.39 9024.19 8938.49 3198.04 -3674.89 5952068.39 641303.46 -1340.24 25.85 10963.26 87.37 5.30 9027.13 8941.43 3229.36 -3674.96 5952099.69 641302.78 -1323.25 38.56 11004.03 90.05 20.63 9028.06 8942.36 3268.95 -3665.84 5952139.45 641311.14 -1294.03 38.16 11032.05 87.50 31.11 9028.66 8942.96 3294.12 -3653.63 5952164.85 641322.85 -1270.09 38.48 11068.83 85.07 42.93 9031.05 8945.35 3323.38 -3631.58 5952194.52 641344.34 -1235.66 32.74 11102.78 85.73 54.64 9033.78 8948.08 3345.63 -3606.17 5952217.26 641369.31 -1202.22 34.44 11135.41 86.06 65.95 9036.12 8950.42 3361.73 -3577.95 5952233.90 641397.22 -1169.79 34.59 11168.61 87.87 69.58 9037.88 8952.18 3374.28 -3547.26 5952247.03 641427.65 -1137.22 12.20 11199.62 90.63 73.06 9038.29 8952.59 3384.20 -3517.90 5952257.52 641456.82 -1107.19 14.32 11233.91 92.87 77.10 9037.24 8951.54 3393.03 -3484.79 5952266.98 641489.75 -1074.61 13.47 11262.16 93.49 80.69 9035.67 8949.97 3398.46 -3457.11 5952272.94 641517.31 -1048.45 12.88 11297.19 95.27 86.54 9033.00 8947.30 3402.34 -3422.42 5952277.50 641551.92 -1017.23 17.41 .~ DLI-)ç l '...ObP . Baker Hughes INTEO~ Survey Report Map Coord~ Bíi. BAKER HUGHES INTEQ Company: BP Amoco Date: 2/3/2005 Time: 13:44:43 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-06, True North Site: PB Y Pad Vertical (TVD) Reference: 14: 107/5/198100:0085.7 Well: Y-06 Section (VS) Reference: Well (0.00N,O.00E,57.00Azi) Wellpath: Y -06A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S EIW MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/10OO 11326.28 94.26 89.15 9030.58 8944.88 3403.43 -3393.45 5952279.14 641580.86 -992.35 9.59 11362.09 95.59 85.83 9027.50 8941.80 3404.99 -3357.82 5952281.39 641616.46 -961.61 9.96 11393.99 95.67 83.53 9024.37 8938.67 3407.94 -3326.21 5952284.94 641648.00 -933.50 7.18 11429.89 97.01 81.52 9020.41 8934.71 3412.58 -3290.83 5952290.26 641683.27 -901.30 6.70 11461.27 98.63 78.42 9016.14 8930.44 3417.99 -3260.23 5952296.26 641713.77 -872.68 11.06 11491.34 97.96 77.28 9011.80 8926.10 3424.25 -3231.14 5952303.08 641742.73 -844.88 4.36 11529.62 97.39 70.13 9006.68 8920.98 3434.89 -3194.75 5952314.42 641778.90 -808.57 18.57 11564.55 98.58 65.41 9001.83 8916.13 3447.97 -3162.74 5952328.12 641810.65 -774.59 13.81 11602.61 100.64 61.91 8995.47 8909.77 3464.62 -3129.11 5952345.40 641843.95 -737.33 10.56 11632.01 96.01 65.66 8991.21 8905.51 3477.46 -3103.03 5952358.74 641869.78 -708.46 20.18 11666.04 93.73 69.37 8988.33 8902.63 3490.42 -3071.70 5952372.30 641900.85 -675.13 12.76 11699.33 94.15 73.70 8986.04 8900.34 3500.94 -3040.21 5952383.43 641932.13 -642.99 13.04 11730.85 93.00 69.89 8984.07 8898.37 3510.76 -3010.33 5952393.83 641961.81 -612.58 12.60 11760.77 94.20 65.58 8982.19 8896.49 3522.07 -2982.70 5952405.66 641989.21 -583.25 14.93 11791.59 96.09 63.72 8979.43 8893.73 3535.21 -2954.97 5952419.34 642016.69 -552.83 8.59 11822.27 95.95 61.87 8976.21 8890.51 3549.16 -2927.83 5952433.80 642043.55 -522.47 6.01 11852.55 94.82 58.89 8973.37 8887.67 3564.06 -2901.63 5952449.20 642069.46 -492.38 10.48 11887.59 94.39 53.89 8970.55 8884.85 3583.39 -2872.55 5952469.09 642098.16 -457.47 14.28 11916.79 92.72 51.71 8968.74 8883.04 3601.01 -2849.34 5952487.15 642121.02 -428.41 9.39 11947.62 91.18 50.64 8967.69 8881.99 3620.32 -2825.34 5952506.92 642144.65 -397.76 6.08 11980.17 88.88 49.83 8967.67 8881.97 3641.14 -2800.32 5952528.22 642169.26 -365.44 7.49 12013.43 87.00 46.25 8968.87 8883.17 3663.36 -2775.61 5952550.91 642193.54 -332.61 12.15 12049.90 87.99 44.18 8970.47 8884.77 3689.03 -2749.75 5952577.06 642218.89 -296.94 6.29 12083.75 87.19 47.68 8971.89 8886.19 3712.54 -2725.45 5952601.04 642242.73 -263.76 10.60 12119.08 88.63 52.31 8973.18 8887.48 3735.23 -2698.41 5952624.25 642269.32 -228.73 13.72 12153.44 90.08 55.80 8973.56 8887.86 3755.40 -2670.60 5952644.94 642296.74 -194.42 11.00 12184.35 90.32 59.07 8973.46 8887.76 3772.03 -2644.56 5952662.08 642322.46 -163.52 10.61 12216.83 90.72 63.91 8973.16 8887.46 3787.53 -2616.03 5952678.12 642350.68 -131.15 14.95 12251.10 87.96 68.15 8973.56 8887.86 3801.45 -2584.72 5952692.64 642381.71 -97.31 14.76 12284.98 85.65 71.50 8975.45 8889.75 3813.11 -2552.98 5952704.91 642413.22 -64.34 12.00 12313.18 82.35 74.13 8978.39 8892.69 3821.40 -2526.19 5952713.71 642439.84 -37.36 14.93 12348.09 78.03 75.27 8984.34 8898.64 3830.48 -2493.02 5952723.42 642472.83 -4.60 12.79 12380.08 74.16 76.45 8992.03 8906.33 3838.06 -2462.92 5952731.59 642502.78 24.78 12.62 12414.52 70.89 79.32 9002.37 8916.67 3844.96 -2430.81 5952739.11 642534.75 55.47 12.38 12444.37 70.51 83.23 9012.24 8926.54 3849.24 -2402.97 5952743.91 642562.50 81.15 12.43 12470.42 68.81 87.79 9021.30 8935.60 3851.15 -2378.63 5952746.30 642586.79 102.61 17.66 12499.74 69.19 91.58 9031.81 8946.11 3851.30 -2351.26 5952746.98 642614.15 125.64 12.14 12534.28 69.13 96.05 9044.10 8958.40 3849.16 -2319.06 5952745.45 642646.38 151.47 12.10 12562.06 68.66 99.10 9054.11 8968.41 3845.74 -2293.38 5952742.53 642672.13 171.16 10.38 . BP-GDB Baker Hughes INTEQ Survey Report . Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: PB Y Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948541.48 ft 647748.73 ft Latitude: 70 16 Longitude: 148 48 North Reference: Grid Convergence: 0.041 N 18.991 W True 1.12 deg Well: Y-06 Slot Name: 06 Y-06 Well Position: +N/-S 453.64 ft Northing: 5948941.98 ft Latitude: 70 16 4.498 N +E/-W -2701.55 ft Easting : 645039.00 ft Longitude: 148 49 37.627 W Position Uncertainty: 0.00 ft Wellpath: Y-06A 500292095801 Current Datum: 8 : 06 2/2/1980 00:00 Magnetic Data: 1/19/2005 Field Strength: 57620 nT Vertical Section: Depth From (TVD) ft 32.30 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Y-06APB1 11602.61 ft Mean Sea Level 24.84 deg 80.81 deg Direction deg 57.00 Height 81.30 ft Survey Program for Definitive Wellpath Date: 2/10/2005 Validated: No Actual From To Survey ft ft 100.00 10700.00 10773.00 11564.55 11602.61 12600.00 Version: Toolcode 4 Tool Name 1 : Sperry-Sun BOSS gyro multi (100.00-118i1D~YRO Survey (10773.00-11875.00) (1) MWD MWD (11602.61-12600.00) MWD Sperry-Sun BOSS gyro multishot MWD - Standard MWD - Standard Annotation TIP KOP TD - Projected Depth Survey: MWD Start Date: 1/16/2005 Company: Baker Hughes Incorporated Tool: MWD:MWD - Standard Engineer: Tied-to: From: Definitive Path . BP-GDB Baker Hughes INTEQ Survey Report . 11564.55 98.58 65.41 8997.43 8916.13 3447.97 -3162.74 5952328.11 641810.65 -774.60 0.00 MWD 11602.61 100.64 61.91 8991.07 8909.77 3464.62 -3129.12 5952345.40 641843.95 -737.33 10.56 MWD 11632.01 96.01 65.66 8986.82 8905.52 3477.45 -3103.03 5952358.74 641869.78 -708.46 20.18 MWD 11666.04 93.73 69.37 8983.93 8902.63 3490.42 -3071.70 5952372.30 641900.85 -675.13 12.76 MWD 11699.33 94.15 73.70 8981.64 8900.34 3500.93 -3040.21 5952383.42 641932.13 -642.99 13.04 MWD 11730.85 93.00 69.89 8979.67 8898.37 3510.76 -3010.33 5952393.82 641961.81 -612.58 12.60 MWD 11760.77 94.20 65.58 8977.79 8896.49 3522.07 -2982.71 5952405.66 641989.21 -583.25 14.93 MWD 11791.59 96.09 63.72 8975.03 8893.73 3535.21 -2954.97 5952419.33 642016.69 -552.83 8.59 MWD 11822.27 95.95 61.87 8971.81 8890.51 3549.16 -2927.83 5952433.80 642043.55 -522.48 6.01 MWD 11852.55 94.82 58.89 8968.97 8887.67 3564.06 -2901.63 5952449.20 642069.46 -492.39 10.48 MWD 11887.59 94.39 53.89 8966.15 8884.85 3583.39 -2872.55 5952469.08 642098.16 -457.4 7 14.28 MWD 11916.79 92.72 51.71 8964.34 8883.04 3601.00 -2849.34 5952487.15 642121.02 -428.41 9.39 MWD 11947.62 91.18 50.64 8963.29 8881.99 3620.32 -2825.34 5952506.92 642144.65 -397.76 6.08 MWD 11980.17 88.88 49.83 8963.28 8881.98 3641.14 -2800.32 5952528.22 642169.26 -365.44 7.49 MWD 12013.43 87.00 46.25 8964.47 8883.17 3663.36 -2775.61 5952550.90 642193.54 -332.61 12.15 MWD 12049.90 87.99 44.18 8966.07 8884.77 3689.02 -2749.75 5952577.06 642218.89 -296.95 6.29 MWD 12083.75 87.19 47.68 8967.49 8886.19 3712.54 -2725.45 5952601.04 642242.73 -263.76 10.60 MWD 12119.08 88.63 52.31 8968.78 8887.48 3735.23 -2698.42 5952624.25 642269.32 -228.73 13.72 MWD 12153.44 90.08 55.80 8969.17 8887.87 3755.40 -2670.61 5952644.94 642296.74 -194.42 11.00 MWD 12184.35 90.32 59.07 8969.06 8887.76 3772.03 -2644.56 5952662.07 642322.45 -163.52 10.61 MWD 12216.83 90.72 63.91 8968.76 8887.46 3787.53 -2616.03 5952678.12 642350.68 -131.15 14.95 MWD 12251.10 87.96 68.15 8969.16 8887.86 3801.45 -2584.73 5952692.63 642381.71 -97.32 14.76 MWD 12284.98 85.65 71.50 8971.05 8889.75 3813.11 -2552.98 5952704.91 642413.22 -64.34 12.00 MWD 12313.18 82.35 74.13 8973.99 8892.69 3821.40 -2526.19 5952713.71 642439.84 -37.36 14.93 MWD 12348.09 78.03 75.27 8979.94 8898.64 3830.48 -2493.02 5952723.42 642472.83 -4.60 12.79 MWD 12380.08 74.16 76.45 8987.63 8906.33 3838.06 -2462.92 5952731.59 642502.78 24.78 12.62 MWD 12414.52 70.89 79.32 8997.97 8916.67 3844.96 -2430.81 5952739.10 642534.74 55.47 12.38 MWD 12444.37 70.51 83.23 9007.84 8926.54 3849.24 -2402.97 5952743.91 642562.49 81.14 12.43 MWD 12470.42 68.81 87.79 9016.90 8935.60 3851.15 -2378.63 5952746.30 642586.79 102.60 17.66 MWD 12499.74 69.19 91.58 9027.41 8946.11 3851.30 -2351.26 5952746.97 642614.15 125.64 12.14 MWD 12534.28 69.13 96.05 9039.70 8958.40 3849.16 -2319.06 5952745.45 642646.38 151.47 12.10 MWD 12562.06 68.66 99.10 9049.71 8968.41 3845.74 -2293.38 5952742.53 642672.13 171.15 10.38 MWD 12600.00 68.66 99.10 9063.51 8982.21 3840.15 -2258.48 5952737.61 642707.12 197.37 0.00 MWD ---~--~-- --_.,,~--- --~_._----~-_..._- . BP-GDB Baker Hughes INTEQ Survey Report . Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: PB Y Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Positiou Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948541.48 ft 647748.73 ft Latitude: 70 16 Longitude: 148 48 North Reference: Grid Convergence: 0.041 N 18.991 W True 1.12 deg Well: Y-06 Slot Name: 06 Y-06 Well Position: +N/-S 453.64 ft Northing: 5948941.98 ft Latitude: 70 16 4.498 N +E/-W -2701.55 ft Easting : 645039.00 ft Longitude: 148 49 37.627 W Position Uncertainty: 0.00 ft Wellpath: Y-06APB1 500292095870 Current Datum: 8 : 06 2/2/1980 00:00 Magnetic Data: 12/7/2004 Field Strength: 57616 nT Vertical Section: Depth From (TVD) ft 32.30 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Y-06 10700.00 ft Mean Sea Level 24.89 deg 80.81 deg Direction deg 57.00 Height 81.30 ft Survey Program for Definitive Wellpath Date: 11/17/2004 Validated: No Actual From To Survey ft ft 100.00 10700.00 10773.00 11875.00 Version: Toolcode 2 Tool Name 1: Sperry-Sun BOSS gyro multi (100.00-11a¡ro~YRO Survey (10773.00-11875.00) MWD Sperry-Sun BOSS gyro multishot MWD - Standard Annotation TIP KOP TD - Projected Depth Survey: Survey Start Date: 1/16/2005 CoilTrak Company: Baker Hughes Incorporated Engineer: Tool: MWD;MWD - Standard Tied-to: From: Definitive Path Survey 10700.00 42.25 325.81 8890.87 8809.57 3027.67 -3612.54 5951899.25 641369.07 -1380.74 0.00 MWD 10773.00 41.68 325.93 8945.15 8863.85 3068.07 -3639.93 5951939.12 641340.91 -1381.71 0.79 MWD 10800.89 47.03 333.64 8965.10 8883.80 3084.92 -3649.67 5951955.78 641330.85 -1380.70 27.20 MWD 10832.29 56.27 340.58 8984.57 8903.27 3107.60 -3659.14 5951978.26 641320.94 -1376.29 34.12 MWD 10864.52 64.62 346.46 9000.47 8919.17 3134.46 -3667.02 5952004.96 641312.54 -1368.28 30.37 MWD 10890.70 71.31 354.43 9010.30 8929.00 3158.35 -3671.00 5952028.78 641308.10 -1358.60 38.05 MWD 10931.75 81.92 354.39 9019.79 8938.49 3198.04 -3674.89 5952068.38 641303.45 -1340.24 25.85 MWD 10963.26 87.37 5.30 9022.73 8941.43 3229.36 -3674.96 5952099.69 641302.78 -1323.25 38.56 MWD 11004.03 90.05 20.63 9023.66 8942.36 3268.95 -3665.84 5952139.45 641311.13 -1294.03 38.16 MWD 11032.05 87.50 31.11 9024.26 8942.96 3294.12 -3653.64 5952164.85 641322.85 -1270.09 38.48 MWD 11068.83 85.07 42.93 9026.65 8945.35 3323.38 -3631.58 5952194.52 641344.33 -1235.66 32.74 MWD . BP-GDB Baker Hughes INTEQ Survey Report . 11102.78 85.73 54.64 9029.38 8948.08 3345.63 -3606.17 5952217.26 641369.31 -1202.23 34.44 MWD 11135.41 86.06 65.95 9031.73 8950.43 3361.73 -3577.95 5952233.90 641397.22 -1169.79 34.59 MWD 11168.61 87.87 69.58 9033.48 8952.18 3374.28 -3547.27 5952247.03 641427.65 -1137.22 12.20 MWD 11199.62 90.63 73.06 9033.89 8952.59 3384.20 -3517.90 5952257.52 641456.82 -1107.19 14.32 MWD 11233.91 92.87 77.10 9032.84 8951.54 3393.03 -3484.79 5952266.98 641489.75 -1074.62 13.4 7 MWD 11262.16 93.49 80.69 9031.27 8949.97 3398.46 -3457.12 5952272.94 641517.31 -1048.45 12.88 MWD 11297.19 95.27 86.54 9028.60 8947.30 3402.34 -3422.42 5952277.49 641551.92 -1017.24 17.41 MWD 11326.28 94.26 89.15 9026.18 8944.88 3403.43 -3393.46 5952279.14 641580.86 -992.35 9.59 MWD 11362.09 95.59 85.83 9023.10 8941.80 3404.99 -3357.82 5952281.39 641616.45 -961.61 9.96 MWD 11393.99 95.67 83.53 9019.97 8938.67 3407.94 -3326.21 5952284.94 641648.00 -933.50 7.18 MWD 11429.89 97.01 81.52 9016.01 8934.71 3412.58 -3290.84 5952290.26 641683.27 -901.30 6.70 MWD 11461.27 98.63 78.42 9011.74 8930.44 3417.99 -3260.23 5952296.26 641713.77 -872.69 11.06 MWD 11491.34 97.96 77.28 9007.40 8926.10 3424.25 -3231.14 5952303.08 641742.73 -844.88 4.36 MWD 11529.62 97.39 70.13 9002.28 8920.98 3434.89 -3194.75 5952314.42 641778.90 -808.57 18.57 MWD 11564.55 98.58 65.41 8997.43 8916.13 3447.97 -3162.74 5952328.11 641810.65 -774.60 13.81 MWD 11602.61 100.64 61.91 8991.07 8909.77 3464.62 -3129.12 5952345.40 641843.95 -737.33 10.56 MWD 11641.56 100.99 57.86 8983.76 8902.46 3483.81 -3096.03 5952365.22 641876.66 -699.13 10.25 MWD 11680.53 99.86 52.45 8976.70 8895.40 3505.70 -3064.59 5952387.72 641907.67 -660.84 13.96 MWD 11714.69 99.33 49.80 8971.01 8889.71 3526.84 -3038.37 5952409.35 641933.4 7 -627.34 7.80 MWD 11752.78 100.06 55.76 8964.59 8883.29 3549.54 -3008.49 5952432.63 641962.91 -589.91 15.54 MWD 11792.23 99.05 66.64 8958.02 8876.72 3568.24 -2974.45 5952451.98 641996.58 -551.18 27.32 MWD 11831.48 98.69 70.57 8951.97 8870.67 3582.39 -2938.35 5952466.82 642032.40 -513.20 9.94 MWD 11875.00 98.69 70.57 8945.39 8864.09 3596.70 -2897.78 5952481.91 642072.68 -471.38 0.00 MWD , . . TREE = 6" WCBl OY WELLHEAD = WCBlOY Y -06A SAÆTYNOTES: MAX IA PRESSURE = 2500 PSI ACn.lð.TOR= Olls DRAFT DUE TO GUIBERSON POLAR PKR. goo @ 11200' KB. ELEV = 81.26' BF. ELEV = 51.76' KOP= 3400' · · J4-1/2" X NP, 10 = 3.813" I Max Angle = 101 @ 11603' · 2065' Datum MD = 10687' DatumTVD = 8800' 55 ~ = --I 2596' H9-518" OJ A<R I 113-318" CSG, 72#, L-80, ID = 12.347" H 2689' 1~ ~ · · 9752' 4-1/2" X NP,ID = 3.813" I · tz Ið I 9772' 9-518" X 4-1/2" BKRS-3 PKR, D = 3.875" I · · 9797' 4-1/2" X NP, 10 = 3.813" I 4-1/2"TBG, 12.6#, L-80, .0152 bpf, 10 =3.958" 9859' N 9869' L 4-1fl" LNIQUEOVERSI-OT 1 II Minimum ID = 2.786" @ 10010' I 9889' L JGUIB PBRSEAL Assv-I 3-1/2" X 3-3/16 XO 8 b 9912' I J9-5/8" X4-1/2"GRJIB PKR,ID =3.833" I · I 9953' L -14-1/2" OTS X NIP, 10 = 3.813"·' ITOPOF 7" L~ 9962' I II I 9961' LJ3-1fl" BKRDER..OY SLV, 10=3.00" I . I I 9980' I 3-1fl" X NP, D = 2.813 I I 9985' I- 4-1/2" OTS XN NP, MUED 10 = 3.80" I (BEHlt>I) cr RPE01fl6¡Q5) 3-1/2" L~, 8.81#, L-80, .0087 bpf, 10 = 2.992" 10010' 10010' I- 3-1fl" X 3-3/16" XO, 10 = 2.786" 1 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" 10019' I 10019' 4-1fl"1BGTAIL, 10= 3.958"1 (BEHINJ cr APE01flM5) 9-518" CSG, 47#, L-80, ID= 8.681" 10467' .... I 10005' H ELM:> TT LOGGBJ 12/10/90 I PERFORATION SUMl.1ARY 10518' MA.RKER.x>1NT 1 REF LOG: SWS - BI-CSiGR ON 03104/80 II ANGLE AT TOP PERF: XX @ 12200' Note: Refer 10 A"oducoon DB for historical perf data I I SIZE SA" INTERVAL OpnlSqz [)!I.1E "'- MLLOUTWNJOW 10776' - 10783' 2" 6 12200 - 12250 0 01/24/05 2" 6 12300 - 12350 0 01/24/05 TOP OF WHPSTOCK 10772' ELM r . I I Ail. Rr OF 4-1 fl" MA. GA RA t\GE PlUG 10905' ~ 11593' I I 7" L~, 29#, l-80, .0371 bpf, 10 = 6.184" 11637' ~ 12560' ,Y 13-3116"l~, 6.2#,l-80, .0076 bpf, ID= 2.81" 12600' DATE REV BY COMfl.ENTS [)!I.1E RBI BY COMIvENl5 PRUDI-OE BAY LNIT 03112180 Le.1QN: CRIGlNAL COMPLETION WEll: Y -06A 01/26105 /TLH CTD SIDTRACK (Y-06A) PERMT No: XXXXXXX API No: 50-029-20431-01 Sa:; 34, T11 N. R13E, BP Exploration (Alaska) ~tDÁ Schlumbergel' Alaska Data & Consulting Services 2525 Gambe( Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth aB Well L5-05 02-07A L5-09 OWDW-SE L5-09 L5-09 Y -06A Y-03A - Job # 10861913 10866591 10772244 10672350 10672381 10679071 10893030 10913004 10877803 MCNL RST RST RST RST RST RST SCMT US IT LOQ Description 1 ,C¡ - rJ #0( l- 1':1',/- Of/Jq r /c¡";'- 107 I!..{ /? - 2. '-f 1f'V - :{..~ 11 iCfo",/2.. /9t)- /2, '2.n'l:- ~/ .z.i:J~- ~G" Date 06/05/04 09/05/04 04/07/04 01/25/04 05/03/04 04/06/04 09/12/04 01/24/05 12/13/04 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, Alaska 99508 Date Delivered: 7- Þ !o6~ / 0/ Blueline ~6) ¥- 2..~ / 02/11/05 NO. 3340 Company: State of Alaska Alaska Oil & Gas Cons Comm Altn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503 2838 ATTN: Beth Ted, I'll add this information to the Y-06A file; no additional filing is necessary. The completion report should close the info loop, as you suggest. Winton 793-1231 Stagg, Ted 0 (ORBIS) wrote: Winton, I made an error in my application for a Permit to Drill on Y-06Ai. This Permit, 204-251, has been granted and the rig is now testing BOP's on the well. The job involves swapping tubing ahead of a sidetrack. The well is an injector. I listed the planned new tubing string to have 5GLM's and a TRSSSV. This is wrong. We plan to run 41/2" tubing with zero GLM's and an injection check valve rather than a TRSSSV. I believe this is the only error. Shall we re-submit The program attachment to Form 10-401 or wait for the completion report to sort things out? Ted 564-4694 or cell 240-8074 · . ~lr~lrŒ (ID~ ~~~~æ~ / AIßASIiA. OILAlft) GAS / CONSERVATION COMMISSION ( FRANK H. MURKOWSKI, GOVERNOR 333 W. ¡n< AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Y -06A BP Exploration (Alaska) Inc. Permit No: 204-251 Surface Location: 1318' SNL, 5055' WEL, SEC. 34, TUN, R13E, UM Bottomhole Location: 2518' NSL, 2137' WEL, SEC. 28, TIIN, R13E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above service well. This permit to redrill 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. lease provide at least twenty-four (24) hours notice for a representative of the Commis . n t witness any required test. Contact the Commission's petroleum field inspector at 07) 59-3 (pager). DATED this ~ay of December, 2004 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. \.:..i 4 .f LIt 7/ Z-c.1d:( I STATE OF ALASKA . ALAS OIL AND GAS CONSERVATION mMMISSION PERMIT TO DRILL 20 MC 25.005 o Drill iii Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1318' SNL, 5055' WEL, SEC. 34, T11N, R13E, UM Top of Productive Horizon: 1738' NSL, 3401' WEL, SEC. 28, T11 N. R13E, UM Total Depth: 2518' NSL, 2137' WEL, SEC. 28, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 645039 y- 5948942 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 10772 feet Maximum Hole Angle: 101 deQrees 1b. Current Well Class 0 Exploratory 1] Development Oil 0 Multiple Zone I 0 Stratigraphic Test iii Service /0 Development Gas 0 Single Zone 5. Bond: !HI Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 PBU Y-06A <·z./I; 6. Proposed Depth: 12. Field / Pool(s): MD 12500 TVD 894055 Prudhoe Bay Field / Prudhoe Bay 7. Property Designation: Pool ADL 028287 8. Land Use Permit: 13. Approximate Spud Date: January 1, 2005 14. Distance to Nearest Property: 17,800' 9. Acres in Property: 2560 Hi. c;asln9Si z~",.. ... Hole Casina 3-3/4' x 4-1/8' 3-3/16" Weiaht 6.2# S~ifi~tions Grade CouDlina Lenath L-80 TCII 2525' 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 83.3' feet Y-33, 810' away 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 3300 Surface: 2420 ../ TO:etting~ QU(~:~~ MD TVD MD TVD ""'~cludin ~ 9975' 8290' 12500' 8940' 191f: a ,.....-: - V'-IJ UJ..-r -rI ... .{ ¡ ¿WILl. "uai Ka Oil R. f". _ .-.... l.Iuns. r~_ 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry 0 Total Depth MD (ft): Total Depth TVD (ft): 11643 9621 !=:trllr.h m:~1 Conductor - . Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft):1 None I 11593 I 9581 Size ... -.v., Junk (measured): 10905 IVU 13-3/8" 9-5/8" 12 cu vds Arcticset 3854 cu ft Permafrost 1518 cu ft Class 'G', 130 cu ft Permafrost 110' 2689' 10467' 110' 2689' 8722' 110' 2689' 10467' 20" x 30" Prnnllction Liner 1675' 7" 60 cu ft Class 'G' 9962' - 11637' 8362' - 9616' 20. Attachments !HI Filing Fee, $100 !HI BOP Sketch o Property Plat 0 Diverter Sketch IperfOration Depth TVD (ft): 8835' - 9056' !HI Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report !HI Drilling Fluid Program !HI 20 MC 25.050 Requirements Perforation Depth MD (ft): 10622' - 10920' 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Stagg, 564-4694 Printed Name Ted Stagg Title CT Drilling Engineer / Prepared By Name/Number: Sianature~2 ~~ Phone 564-4694 Date 1~~Æj.; Terrie Hubble, 564-4628 IIXj>"II>..'~"'I" ~IIII>"illl'>i····· /1>1',11" 11.!,,,;~I;i>..>I>"i >.> ......I·i!.I.: Permit To Drill API Number: Permit Approyal, See cover letter for Number: 2C>'7- 2.5/ 50-029-20431-01-00 Date: / ~/5l8/¿.'(./ other requirements Conditions of APprOV~I: Sa es Required 0 Yes ~No Mud Log Required ( 0 Yes '"Ø.No , drc~en .Sulfide Measu:es )ªYes 0 No . Directio. ~al Survey Required %Yes 0 No Othe, T~"O [. Co ~ÇOD (J$" MT:T, UWc~ Za..t.'1¡ /oe¡ '1 "".,d ' AoD"'Vj~l y¿fJv¡' ^ ~~~J~'~'ON Date I t/ð¡ orf Form 10-401~se'ð"~04 '-- 0 R t G I ~\J A L GfY1 f./Jd!JV;S ::If '--,Submit In Dut licate .' . BP Y-06A RWO/CTD Sidetrack Summary of ODerations: Well Y-06 is scheduled for a through tubing sidetrack with coiled tubing. Prior to CTD sidetracking, the existing 4 Yz" tubing will be recovered and new 4 Yz" tubing and packer will be installed per the proposed schematic. The sidetrack, Y -06A, will kick off from a window milled from a mechanical whipstock set in Zone /' 4 and will target Zone 4. All existing Y -06 perforations will be cement squeezed prior to sidetracking. Y -06A is to be a water and MI injector designed to improve ZAB pattern conformance. Y -06A will be completed with a fully cemented 33/16" liner and selectively perforated. Injection zone conformance will be initially evaluated by running a memory SCMT log from approx. 100 feet below the window to the top of the planned 33/16" liner. This will document cement quality in the interval that isolates the new Zone 4 injection interval from the parent well. Pre-rig work: See Sundry 10-403 filed for this job. Nordic 2 RWO - Tubing swap: Estimate start on Dec. 24, 2004 1. RU Nordic 2 with 11" BOPE. Test stack. 2. Pull existing 4 W' tubing. 3. Install 4 Y2" tubing with packer, 5 GLMs, TRSSSV and 4 1/16" tree. 4. PT completion. ~ry~t~· S~ ¡Jf~. vJ6A- .J Nordic 2 CTD· Mill window, Drill and Complete sidetrack: Estimated start Jan. 1,2005 / 1. NU 7-1/16" CTD BOPE. Test. / 3. Mill 3.80" window in 7" liner. 4. Directionally drill -1,728' of 3.75"-4 1/8" open hole (planned TD 12,500' MD, 8940ss). 7. Run 3 3/16" from TD to approx. 9,975' MD (8290'ss). PT liner and lap to 2500 psi. / 8. Run memory SCMT log from approx. 100 feet outside the window to top of 3 3/16" liner. 9. Perforate for Zone 4B injection. 10. RD Nordic 2. Mud Program: · RWO: 2% KCI and 2ppb Biozan. · CTD: PIo-Pro (8.6 - 8.7 ppg)./ Disposal: · All drilling and completion fluids and all other Class IT wastes will go to Grind & Inject or Pad 3. · All Class I wastes will go to Pad 3 for disposal. Casing Program: ~ · 2,525ft of 33/16" cemented liner. A minimum of.. bls of cement will be used assuming that the majority of the open hole will be drilled with a 4 1/ bi-center bit. ./ Well Control: · BOP diagrams are attached. · Pipe rams, blind rams and the CT pack-off will be pressure tested to 400 psi and to 3500 psi. /~ · The annular preventer will be tested to 400 psi and 2500 psi. Directional / Distances · See attached directional plan. Max. planned hole angle is approx. -101 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · Nearest property line is 17,800 ft away. Nearest well in pool is Y-33, 810 feet away. . . Logging · MWD Gamma Ray 1 Resistivity logs will be run over the entire open hole section. Hazards · Y Pad is not considered an H2S Pad. Most wells on Y Pad measure between 20 and 50 ppm H2S in producednüíds. Y-30Ll measured 120 ppm H2S on 2/8/04. · Lost circulation risk is considered moderate if isolation from the Shublik is achieved during the perf squeeze. Drilling may be done with viscosified water if losses are total. Reservoir Pressure · Pore pressure for this injection well is estimated to be 3300 psi at 88ooss. · Maximum surface pressure with gas (0.1 psi/ft) to surface is 2420 psi. / TREE = 6" tvÇEVOY I I WELLHEAD - tvÇEVOY Y-06 SAFETY NOTES ACTUA TOR- OTIS KB. ELEV- 81.26' BF. ELEV - 5176' KOP- 3400' r U4-1f2" OTISSSSV NIP, ID= 3.813" I Max Anqle = 46 @ 6700' I 2026' Datum MD = 10687' . Datum TVD = 8800' SS = = --I 2596' H9-518" OJ A<R I I 13-318" CSG, 72#, L-80. ID = 12347" 2689' ~ ~ GAS LIFT Ml\NDRELS ST IVD TVD DEV TYft LATCH VLV 5 2947 2866 1 tvÇMY RK 1-1/2" L 4 5339 4937 45 tvÇMY RK 1-1/2" 3 8045 6856 45 tvÇMY RK 1-1/2" 2 9463 7916 42 tvÇMY RK 1-1/2" 1 9626 8034 44 tvÇMY RK 1-1/2" Minimum ID = 3.725" @ 9985' 4-1/2" OTIS XN NIPPLE fOTls XA SLIDING SLEEVE ID 3.813" I I I 9853' l I 9889' jGUIB PBR SEAL ASSY I ) :8J I.-, 9912' j9-518" x 4-1/2" GRUIB PKR, ID - 3.833" I P I I 9953' j4-112" OTIS X NIP, ID = 3.813" I I TOP OF 7" LNR 9962' 1-1 . I 9985' 4-112" OTISXN NIp, ID= 3.7251 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 10019' I 10019' 4-112" TBG TAIL, 0 = 3.958"1 I 10005' H ELIVD TT LOGGED 12/10/90 I I 9-5/8" CSG, 47#, L-80, ID = 8.681" 1 0467' 1----.4 ~ 10518' -1 Ml\ RKER JOIf\fr I PERFORATION SUrvtv1ARY [] Re= LOG: SWS - BHCSlGR ON 03104180 A NGLEA T TOP ftRF: 44 @ 10622' I] Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 6 10622 - 10657' 0 04/03189 I] 3-1/8" 6 10760 - 10772' 0 08101180 3-118" 6 10782 - 10800' 0 08101180 3-1/8" 6 10820 - 10840' 0 08101180 I] 3-1/8" 4 10850 - 10920' 0 06104185 ~I I 10905' PARr OF 4-1/2" Ml\GARANGE A..UG I PBTD 11593' I I 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 11637' I DATE REV BY COMM:f\frS DATE REV BY COMfllENTS FRUDHOE BA Y UNIT 03/12/80 LEWOINE ORIGINAL COrvPLErION WELL: Y-06 02!27/01 SIS-QAA CONVERTED TO CANV AS ÆRI'v1IT No: 80-0020 03103/01 SIS-MD RNAL API No: 50-029-20431-00 06!24/oo RN'TP CORRECTIONS Sec. 34, T11N.R13E BP Exploration (Alaska) TREE '" 6" MCEVOY 1 0622 - 1 0657' 10760 - 10772' 10782 - 10800' 10820 10840' 10850 - 10920' WELL: PERMIT No: API No: Sac. 34, SF . . Bit. RA_ ....... lNTEQ ObP BP-GDB Baker Hughes INTEQ Planning Report Company: BP Amoco Date: 121712004 Time: ·12:52:11 Page: Field: Prudhoe E3¡¡y Co-ordinate(NE) Referenee: Well: Y.:06. True North Site: PB Y Pad Vertical (TVD) Refereøee: System: Mean Sea Level WeD: y,Q6 Seetioø (VS) Referenee: Well (Q.ooN,Q·OOE.57·ooAziI . Oracle WeDpath: PIan#2 Y.:06A Snney CaleuJatioø .MethQd: Minimum Curvature .. . .. Db: Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Goo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: PB Y Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: 5948541.48 ft Latitude: 70 16 0.041 N From: Map Easting: 647748.73 ft Longitude: 148 48 18.991 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.12 deg Well: Y-06 Slot Name: 06 Y-06 Well Position: +N/-S 453.64 ft Northing: 5948941.98 ft Latitude: 70 16 4.498 N +EI-W -2701.55 ft Easting : 645039.00 ft Longitude: 148 49 37.627 W Position Uncertaiøty: 0.00 ft Wellpath: Plan#2 Y -OGA Drilled From: Y-06 500292095801 Tie-on Depth: 10700.00 ft Current Datum: 8: 06 2/2/1980 00:00 Height 81.30 ft Above System Datum: Mean Sea Level Magnetic Data: 121712004 Declination: 24.89 deg Field Strength: 57616 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +EI-W Direction ft ft ft deg 32.30 0.00 0.00 57.00 Targets Map Map <---Latitude ---> <-Longitude .....;. Name DescrIption TVD +N/-S +EI-W Northing Eastiøg Deg>Min Sec Deg Miø Sec Dip. Dir. ft ft ft ft ft Y-06A Polygon1.1 0.00 3376.53 -3769.93 5952244.99 641205.00 70 16 37.697 N 148 51 27.410 W -Polygon 1 0.00 3376.53 -3769.93 5952244.99 641205.00 70 16 37.697 N 148 51 27.410 W -Polygon 2 0.00 4008.61 -2312.37 5952904.99 642650.00 70 16 43.919 N 148 50 44.970 W -Polygon 3 0.00 3781.03 -2181.72 5952679.99 642785.00 70 1641.681 N 148 5041.163 W -Polygon 4 0.00 3167.12 -3543.91 5952039.99 641435.00 70 1635.638 N 148 51 20.825 W Y-06A Fault 1 0.00 3513.79 -3522.22 5952386.99 641450.00 70 16 39.048 N 148 51 20.198 W -Polygon 1 0.00 3513.79 -3522.22 5952386.99 641450.00 70 16 39.048 N 148 51 20.198 W -Polygon 2 0.00 3283.35 -3346.62 5952159.99 641630.00 70 16 36.782 N 148 51 15.081 W Y-06A Fault A 0.00 3376.75 -4560.13 5952229.99 640415.00 70 16 37.695 N 148 51 50.421 W -Polygon 1 0.00 3376.75 -4560.13 5952229.99 640415.00 70 16 37.695 N 148 51 50.421 W -Polygon 2 0.00 3642.34 -3289.68 5952519.99 641680.00 70 16 40.313 N 148 51 13.428 W Y-OGA T1.4 8850.00 3695.10 -2705.52 5952583.99 642263.00 70 1640.834 N 148 50 56.416 W Y-OGA T1.1 8926.70 3170.58 -3671.87 5952040.99 641307.00 70 16 35.672 N 148 51 24.551 W Y-06A T1.3 8947.00 3471.25 -3234.97 5952349.99 641738.00 70 16 38.631 N 1485111.832W Y-OGA T1.2 8950.00 3400.09 -3487.40 5952273.99 641487.00 70 16 37.930 N 148 51 19.182 W Y-06A T1.5 8950.00 3854.59 -2365.36 5952749.99 642600.00 70 16 42.404 N 148 50 46.512 W Annotation MD TVD ft ft 10700.00 8809.57 TIP 10772.00 8863.10 KOP 10792.00 8877.85 end 9 DLS I begin 34 DLS . . _íi. ..... ObP BP-GDB Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco Date: 121712004 Time: 12:52:11 Page: Field: Prudhoe Bay Co-ordinate(NE) Reference: Well:Y-06, TrueNorth Site: PB Y Pad Vertical (TVD) Referenc:e: System: Mean Sea Level , WeD: Y,..()6 Seedon (VS) Referenœ: Well (0,O()N.0.OOE.57.OOAzi) WeDpath: PIan#2 Y-06A Survey Calculation Method: MinimurnCurvature Db: Oracle Annotation MD TVD ft ft 10925.83 8935.48 4 11190.43 8950.16 end 34 DLS / begin 12 DLS 11266.00 8950.17 6 11466.00 8950.18 7 11566.00 8942.19 8 11666.00 8924.60 9 11946.00 8874.03 10 12056.00 8856.65 11 12206.00 8856.83 12 12266.00 8869.76 13 12500.00 8940.45 TO Plan: Plan #2 Date Composed: 1217/2004 Version: 3 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD Inel Adm TVD +N/-S +EI-W DLS ,BuDd , Turo TFO Target ft deg deg ft ft ft deg/100ft degJ100ft deg/100ft deg 10700.00 42.25 325.81 8809.57 3027.67 -3612.54 0.00 0.00 0.00 0.00 10772.00 41.69 325.93 8863.10 3067.52 -3639.55 0.79 -0.78 0.17 171.89 10792.00 43.26 327.24 8877.85 3078.80 -3646.99 9.00 7.83 6.57 30.00 10925.83 85.00 348.22 8935.48 3188.44 -3687.56 34.00 31.19 15.67 30.00 11190.43 90.00 78.18 8950.16 3387.16 -3556.97 34.00 1.89 34.00 90.00 11266.00 90.00 87.25 8950.17 3396.73 -3482.09 12.00 0.00 12.00 90.00 11466.00 90.00 63.25 8950.18 3447.27 -3290.09 12.00 0.00 -12.00 -90.00 11566.00 99.16 71.03 8942.19 3485.95 -3198.42 12.00 9.16 7.78 40.00 11666.00 101.03 83.07 8924.60 3508.00 -3102.67 12.00 1.87 12.04 80.00 11946.00 99.17 48.98 8874.03 3618.46 -2854.84 12.00 -0.66 -12.18 -90.00 12056.00 98.93 62.34 8856.65 3679.59 -2765.35 12.00 -0.22 12.15 90.00 12206.00 80.93 62.34 8856.83 3748.92 -2633.04 12.00 -12.00 0.00 180.00 12266.00 74.17 59.79 8869.76 3777.24 -2581.78 12.00 -11.26 -4.26 200.00 12500.00 71.38 89.08 8940.45 3836.86 -2369.37 12.00 -1.19 12.51 100.00 Survey MD Incl Adm SSTVD NIS E/W MapN MapE VS DLS Toolfac:e Tool ft deg deg ft ft ft ft ft ft deg¡10Oft deg 10700.00 42.25 325.81 8809.57 3027.67 -3612.54 5951899.25 641369.07 -1380.74 0.00 0.00 TIP 10725.00 42.06 325.85 8828.10 3041.55 -3621.96 5951912.95 641359.38 -1381.09 0.79 171.89 MWD 10750.00 41.86 325.89 8846.69 3055.38 -3631.34 5951926.60 641349.74 -1381.42 0.79 171.86 MWD 10754.44 41.83 325.90 8850.00 3057.84 -3633.00 5951929.02 641348.03 -1381.47 0.79 171.83 Y -06A 10772.00 41.69 325.93 8863.10 3067.52 -3639.55 5951938.58 641341.29 -1381.69 0.79 171.82 KOP 10775.00 41.92 326.13 8865.34 3069.18 -3640.67 5951940.22 641340.14 -1381.73 9.00 30.00 MWD 10792.00 43.26 327.24 8877.85 3078.80 -3646.99 5951949.71 641333.64 -1381.79 9.00 29.85 end 9 [fL 10800.00 45.63 329.15 8883.56 3083.56 -3649.94 5951954.41 641330.60 -1381.67 34.00 30.00 MWD 10825.00 53.21 334.22 8899.82 3100.27 -3658.89 5951970.95 641321.33 -1380.08 34.00 28.64 MWD 10850.00 60.97 338.37 8913.40 3119.48 -3667.29 5951989.99 641312.56 -1376.66 34.00 25.33 MWD 10875.00 68.83 341.93 8924.00 3140.76 -3674.95 5952011.12 641304.50 -1371.49 34.00 23.07 MWD 10882.94 71.34 342.98 8926.70 3147.87 -3677.20 5952018.18 641302.11 -1369.50 34.00 21.56 Y -o6A 10900.00 76.77 345.13 8931.39 3163.65 -3681.70 5952033.86 641297.31 -1364.69 34.00 21.20 MWD 10925.00 84.74 348.12 8935.40 3187.63 -3687.39 5952057.73 641291.15 -1356.40 34.00 20.61 MWD 10925.83 85.00 348.22 8935.48 3188.44 -3687.56 5952058.54 641290.97 -1356.10 33.94 20.13 4 10950.00 85.05 356.47 8937.58 3212.28 -3690.77 5952082.31 641287.30 -1345.80 34.00 90.00 MWD 10975.00 85.21 5.00 8939.70 3237.17 -3690.45 5952107.20 641287.14 -1331.98 34.00 89.28 MWD 11000.00 85.48 13.52 8941.73 3261.74 -3686.44 5952131.84 641290.68 -1315.24 34.00 88.56 MWD 11025.00 85.84 22.04 8943.63 3285.45 -3678.84 5952155.69 641297.82 -1295.95 34.00 87.87 MWD 11050.00 86.30 30.55 8945.35 3307.79 -3667.80 5952178.24 641308.43 -1274.52 34.00 87.22 MWD 11075.00 86.84 39.05 8946.85 3328.27 -3653.57 5952198.98 641322.26 -1251.44 34.00 86.64 MWD . . ... BA_ IUGIIØ lNTEQ ObP BP-GDB Baker Hughes INTEQ Planning Report COInpany: BPAmOCO Date: 12/712004 Time: 12:52:11 Page: Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y-06, True North Site: PBY Pad Vertic:al (TVD) Reference: System: MENln Sea Level WeD: Y,..Q6 Seetion (VS) Reference: Well (0.ooN,O.ooE,5?(()Azj) WeDpath: Plan#2 Y-06A Survey Calculation. Method: Minimum Curvature Db: Oracle Survey MD Inel Axim SSTVD NIS EIW MapN MapE VS DLS ToOlface .'côol .... ft deg deg ft ft ft ft ft ft degl100ft deg 11100.00 87.44 47.53 8948.10 3346.42 -3636.46 5952217.47 641339.01 -1227.20 34.00 86.13 MWD 11125.00 88.11 56.02 8949.07 3361.87 -3616.86 5952233.28 641358.31 -1202.35 34.00 85.70 MWD 11150.00 88.81 64.49 8949.74 3374.25 -3595.18 5952246.08 641379.75 -1177.42 34.00 85.37 MWD 11175.00 89.54 72.96 8950.10 3383.32 -3571.91 5952255.59 641402.84 -1152.97 34.00 85.14 MWD 11190.43 90.00 78.18 8950.16 3387.16 -3556.97 5952259.72 641417.70 -1138.35 34.00 85.02 end 34 11200.00 90.00 79.33 8950.16 3389.02 -3547.58 5952261.77 641427.05 -1129.46 12.00 90.00 MWD 11225.00 90.00 82.33 8950.17 3393.01 -3522.90 5952266.23 641451.64 -1106.59 12.00 90.00 MWD 11250.00 90.00 85.33 8950.17 3395.69 -3498.05 5952269.39 641476.44 -1084.29 12.00 90.00 MWD 11266.00 90.00 87.25 8950.17 3396.73 -3482.09 5952270.73 641492.38 -1070.33 12.00 90.00 6 11275.00 90.00 86.17 8950.17 3397.24 -3473.10 5952271.42 641501.35 -1062.52 12.00 270.00 MWD 11300.00 90.00 83.17 8950.17 3399.56 -3448.21 5952274.22 641526.19 -1040.38 12.00 270.00 MWD 11325.00 90.00 80.17 8950.17 3403.18 -3423.48 5952278.31 641550.85 -1017.66 12.00 270.00 MWD 11350.00 90.00 77.17 8950.17 3408.09 -3398.97 5952283.70 641575.26 -994.43 12.00 270.00 MWD 11375.00 90.00 74.17 8950.17 3414.28 -3374.75 5952290.35 641599.35 -970.75 12.00 270.00 MWD 11400.00 90.00 71.17 8950.18 3421.72 -3350.89 5952298.25 641623.06 -946.68 12.00 270.00 MWD 11425.00 90.00 68.17 8950.18 3430.41 -3327.44 5952307.38 641646.33 -922.30 12.00 270.00 MWD 11450.00 90.00 65.17 8950.18 3440.31 -3304.49 5952317.72 641669.09 -897.65 12.00 270.00 MWD 11466.00 90.00 63.25 8950.18 3447.27 -3290.09 5952324.95 641683.35 -881.78 12.00 270.00 7 11475.00 90.82 63.95 8950.11 3451.27 -3282.02 5952329.11 641691.34 -872.84 12.00 40.00 MWD 11500.00 93.12 65.88 8949.25 3461.86 -3259.40 5952340.14 641713.75 -848.10 12.00 40.00 MWD 11525.00 95.42 67.82 8947.39 3471.66 -3236.48 5952350.38 641736.48 -823.54 12.00 40.07 MWD 11550.00 97.70 69.77 8944.54 3480.64 -3213.33 5952359.80 641759.45 -799.23 12.00 40.22 MWD 11566.00 99.16 71.03 8942.19 3485.95 -3198.42 5952365.40 641774.25 -783.83 12.00 40.44 8 11575.00 99.35 72.11 8940.74 3488.76 -3189.99 5952368.37 641782.62 -775.24 12.00 80.00 MWD 11600.00 99.85 75.11 8936.57 3495.72 -3166.34 5952375.78 641806.13 -751.62 12.00 80.17 MWD 11625.00 100.32 78.12 8932.20 3501.41 -3142.40 5952381.93 641829.96 -728.43 12.00 80.67 MWD 11650.00 100.76 81.14 8927.62 3505.84 -3118.23 5952386.82 641854.04 -705.75 12.00 81.20 MWD 11666.00 101.03 83.07 8924.60 3508.00 -3102.67 5952389.28 641869.55 -691.53 12.00 81.75 9 11675.00 101.03 81.97 8922.87 3509.14 -3093.91 5952390.60 641878.29 -683.55 12.00 270.00 MWD 11700.00 101.01 78.92 8918.09 3513.22 -3069.71 5952395.14 641902.40 -661.04 12.00 269.79 MWD 11725.00 100.95 75.86 8913.33 3518.58 -3045.77 5952400.95 641926.24 -638.04 12.00 269.21 MWD 11750.00 100.86 72.81 8908.60 3525.20 -3022.13 5952408.03 641949.74 -614.61 12.00 268.62 MWD 11775.00 100.74 69.76 8903.92 3533.08 -2998.88 5952416.36 641972.83 -590.81 12.00 268.05 MWD 11800.00 100.60 66.71 8899.29 3542.19 -2976.06 5952425.91 641995.47 -566.72 12.00 267.47 MWD 11825.00 100.42 63.66 8894.73 3552.51 -2953.76 5952436.65 642017.57 -542.39 12.00 266.91 MWD 11850.00 100.22 60.62 8890.25 3564.00 -2932.01 5952448.56 642039.08 -517.90 12.00 266.35 MWD 11875.00 99.98 57.58 8885.86 3576.64 -2910.90 5952461.60 642059.95 -493.31 12.00 265.81 MWD 11900.00 99.72 54.55 8881.58 3590.39 -2890.46 5952475.74 642080.11 -468.68 12.00 265.28 MWD 11925.00 99.43 51.52 8877.42 3605.21 -2870.77 5952490.94 642099.52 -444.09 12.00 264.76 MWD 11946.00 99.17 48.98 8874.03 3618.46 -2854.84 5952504.49 642115.19 -423.52 12.00 264.25 10 11950.00 99.17 49.47 8873.39 3621.04 -2851.85 5952507.13 642118.13 -419.60 12.00 90.00 MWD 11975.00 99.16 52.50 8869.41 3636.58 -2832.67 5952523.03 642137.00 -395.06 12.00 90.08 MWD 12000.00 99.11 55.54 8865.44 3651.07 -2812.70 5952537.91 642156.69 -370.41 12.00 90.56 MWD 12025.00 99.05 58.58 8861.49 3664.50 -2791.99 5952551.73 642177.14 -345.73 12.00 91.04 MWD 12050.00 98.95 61.62 8857.58 3676.80 -2770.58 5952564.44 642198.30 -321.08 12.00 91.52 MWD 12056.00 98.93 62.34 8856.65 3679.59 -2765.35 5952567.33 642203.47 -315.17 12.00 92.00 11 12075.00 96.65 62.34 8854.07 3688.32 -2748.68 5952576.38 642219.98 -296.43 12.00 180.00 MWD 12100.00 93.65 62.34 8851.83 3699.88 -2726.63 5952588.36 642241.80 -271.64 12.00 180.00 MWD 12125.00 90.65 62.34 8850.89 3711.48 -2704.50 5952600.38 642263.70 -246.77 12.00 180.00 MWD 12150.00 87.65 62.34 8851.26 3723.08 -2682.36 5952612.40 642285.61 -221.88 12.00 180.00 MWD 12175.00 84.65 62.34 8852.94 3734.65 -2660.27 5952624.40 642307.47 -197.05 12.00 180.00 MWD 12200.00 81.65 62.34 8855.93 3746.17 -2638.29 5952636.34 642329.22 -172.34 12.00 180.00 MWD 12206.00 80.93 62.34 8856.83 3748.92 -2633.04 5952639.19 642334.42 -166.44 12.00 180.00 12 . . ... BAKU IIUGIIIS INTEQ ObP BP-GDB Baker Hughes INTEQ Planning Report Compauy: BP Amoco Date: 1217/2004 Time: 12:52:11 Page: Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Y -06, True North Site: PBY Pad Vertic:al (fVD) Refel'enee: System: Mean Sea Level WeD: Y-06 Sedion (VS) Reference: Well (0.00N,0.ooE,57.ooAzi) WeDpatb: Plan#2 y-06A Survey Calcnladon Metbod: Minimum Curvature Db: Oracle Survey MD Incl ADm SSTVD N/S EIW MapN MapE VS DLS Toolfaee Tool ft deg deg ft ft ft ft ft ft døgl1000 deg 12225.00 78.79 61.55 8860.18 3757.72 -2616.53 5952648.31 642350.75 -147.80 12.00 200.00 MWD 12250.00 75.97 60.49 8865.64 3769.54 -2595.19 5952660.53 642371.86 -123.47 12.00 200.14 MWD 12266.00 74.17 59.79 8869.76 3777.24 -2581.78 5952668.48 642385.11 -108.04 12.00 200.37 13 12275.00 73.99 60.90 8872.23 3781.52 -2574.26 5952672.91 642392.55 -99.40 12.00 100.00 MWD 12300.00 73.51 63.98 8879.23 3792.62 -2552.99 5952684.42 842413.61 -75.51 12.00 99.70 MWD 12325.00 73.07 67.08 8886.42 3802.54 -2531.20 5952694.76 642435.20 -51.83 12.00 98.83 MWD 12350.00 72.68 70.19 8893.79 3811.24 -2508.95 5952703.89 642457.27 -28.43 12.00 97.94 MWD 12375.00 72.33 73.32 8901.30 3818.71 -2486.31 5952711.78 642479.76 -5.38 12.00 97.02 MWD 12400.00 72.04 76.45 8908.95 3824.91 -2463.34 5952718.43 642502.61 17.27 12.00 96.09 MWD 12425.00 71.80 79.60 8916.71 3829.84 -2440.09 5952723.81 642525.76 39.45 12.00 95.13 MWD 12450.00 71.61 82.75 8924.56 3833.48 -2416.64 5952727.90 642549.13 61.10 12.00 94.15 MWD 12475.00 71.47 85.91 8932.48 3835.82 -2393.05 5952730.69 642572.67 82.16 12.00 93.16 MWD 12500.00 71.38 89.08 8940.45 3836.86 -2369.37 5952732.19 642596.32 102.58 12.00 92.16 TO PM f'jan, f'jan #2 ('(-4)_n#2 Y -4)6A) aMi PCltnis Date: 121712:004 _t.U04'ffl ØÐ,/W,$ ~'f4M&A !i&&Ø1~ 1I'__t 11'#...0.111«1:1 Y'" Tie e# MIh 'I01'OOM RløJ: "__2 lit..,. htu_ a f" 'Itf1tif4fl¡ &IIi. &1.JQft V"'"= ~ ~ 51..., OM è.D u.jfè REFERENCE INFORMATlQN Well~: Y..Q6, True North WELL D!:'TAlLS Name- NOf'thing Easting witlide Loogi¡1.I!k S!r;¡ y-% 4:H.M ·21úU5 5948:94L98 M5{lJ')J){) 7{)"¡j'Ö4.498.N !48"4-9'31,62-7W !J6 326 . 300 ·250 200 150 100 50 o 2 50 100 150 200 --250 -300 326 ANT¡.çoLLlSJON SETTINGS C-OMMNY 001' AiLS B!>AfJ.1iJC't! Oe¢fIFm!':k1¡:rthTø SurveyfPkm 10100.00 11500.00 Manru.>d;Þ1an#1 V3 SURVEY PROGRAM o ISO ~~._~-~- Travelling Cy!índer i\.zìmutb (TFO+AZI) [deg] vs Centre ill Centre Separnion [100ft/in] -~---- ,¿Ç ,.~ ~ ^~ 3 ,,' ~y'~ , </// . .....~. . . ~. A#J" . '; · ~,.o' - $. ~~~.~ ' ....; . ^/,/ -~. .':":' . / ~<- ' . ':":", " / >.~; / .->~//."/ ///~-. . -.' '.'. \ ;' . / / "//~.' m '. \.\ '/ I';> ;%9 '·i~~·;'" I'\,~ !.. I . . >/ ... . '. . "<. \ . .'. I! ',:1f í¡;Jt:: 1~~)<'~/ . ,~~ "\" "1,:\' '{f}% " ¡(If:;; , ~\~\>\. Y\}:/::, ; ',' ",' ",',' 'I:>:':;" "'~~"i\,. /1'\1 i, ,',' " 'I '¡ I 'f, / ", ~i~ ' ' ; I . . . I 90 I . . \.. .' I I HI ,"'J, \', '/~< ). '¡," ,I)", u, ' I' II".~ . ,. ',', /:'f!fJ" ¿j, ~..., ¡//J ~\ ,"H\ I: \; ,..",,,,:: . ;;:}~ :;,/~,< I, I, t"I¡ ( , '. 1\ I' ...~, ~3~f '" ß! . . '. /./ /</// .'. > - (! .- : '. ./ . / '.' '. / 24th. \ '.' / :. // /.' / /1'120 . 1;/< // " . <'<'i// '.' '. ~~%:~~1 iê >ç~<~~~::Æ/~/ '\nTEt~j , 'v" '<>-'" ...... - . . / . ./// 2~"- "<. '.C·c.. '~_~.__.--._.../" .v~....._-..c_c >__--. ~ .- A-"'" ~~~--" WELLPATH DETAJLS Tool Phm#2 Y,.{J6A 500192(19$8(11 MWD PatemWd!¡nUh: Y-IJ<) Tie on MD W100,OO Rig:' N&dk2 Rtf )¡¡rum 8,06 2/2119-0000:00 SI.30ft V_S~ 0rißin smug Angre +W-W Frj)Jj.TYÛ 57.00~ 0.00 0.00 32.30 LEGEND Y-04 Y-06 Y-23 Y-23 Y-23 Y-23 Y-23 Y-31 Y-33 Plan #2 R~~"_,~_.~ D#w.~ PM top of bag bttm of bag middle of slips middle of pipes of flow cross middle of blind/shears middle of aI'S ######## L- CD (f) ....... a: Flow Y -1 OAi and Y -06Ai drilling permits . . «Y-10ALgeodisplays.ZIP» Bob Thanks for calling - let me know if you need anything else. Wells within 1/4mi ofY-10Ai map attached vY-19 1000ft r~~o~~ vV-30 977ft 1q,r1IS Y -30L 1 950ft Z &1 {r,fI ~-31 1111ft ¡q{OSf." Wells within 1/4mi of Y-06Ai map attached ./y-04 ~1' /7q {O'5 Y-19 .895' ¡{-f094 vY-33 I: I q I 0 ~ 0 Y-31 1180' Mary S. Endacott Coil Tubing Drlg Engr 907-564-4388 741 endacoms@bp.com Content-Description: Y -1 OAi_geodisplays.ZIP Content-Type: application/x -zip-compressed Content-Encoding: base64 1 of 1 12/21/20044:52 PM . . TERRIEI..;I-UjBBLE BP EXPLORATION AI< 'II\IC POBOX19ß612MB7~5 ANCHORAGE"AK99519~6612 " MastEn'card,Check" , ....... ", - "'00" " ',_'" _;,.,_.. '_: .. _'" "0 _ _' .....,,_.,~. - .. ",,', .._ ", .. _._,'_ _ .. - ""'_ " '_ "_'_'_ ....0.......:. .::_. _.... .._.__....'...._. __....... __',..,_ _.... .......... ..·..··..n ,',_, '_'. _" ...... ,', ~~p¡RJrE~~ I~~ -O~ ,.....& .'. . ." '.' F· J'. I B AI k . . .... . Irst. atu;ma ank as a ' . . . Anchorage; AK 99501 ME~O '{-7Jort 89-6/1252166 __._::,....... ,....'.._00-.:,.- DATE\ ~ lite It) L¡ .. .,'" ,......, .' -." '" $ ~oO~ 'éb .... DOLL~ --..:-.-,........' '-',- ,-- --- .,' '-.. _: I. 2 5 2000 b 0 -: ~ ~ 1.1. II' b2 2 711.1. 5 5 b II- 0 I.b b . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME nbt Yo~ ,/ PTD# 20LJ -.7 . ç- / Development >< Service , Exploration Stratigraphic CHECK WHAT ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI Tbe permit is for a new weUboresegment of LA TERAL existing weD . Permit No, API No. . (If API num ber Production. sbould continue to be reponed as last two. (2) digits a function ·of tbe original API number. stated are between 60-69) above. PILOT HOLE In accordance witb 20 AAC 25.005(1), an (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) .' and API num ber (SO - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION compliance witb 20 AAC 25..0S5~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:J ception. (Company Name) assumes tbe liability of any protest to the spacinge:xception tbat may occur. DRY DITCH AU dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from wbere samples are first caught aDd ] 0' sample h:ite:r:vals througb target zones. .. . . D D Well bore seg Annular Disposal PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT Y-06A ~ Program SER ALASKAUNC Initial ClasslType SER 11WINJ GeoArea 890 Unit 11650__ On/Off Shore On Administration pe I1T) it fee attached Y_es - - - - - - - - - - - - - - - 2 _Leas_e_number _appropriate_ - - - - - - _ Yes - - - - - - - 3 Vn[que weltn_arne_and oumb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 4 Well IQc¡¡ted in a define_dppol_ - - - - - - _ _ _ Yes 5 WelUQcated pr_oper_d[stance from drilling unitb9und_a[J'_ _ _ Yes - - - - - - - - - - - - - - - 6 WelUQcated pr_oper _distance_ from Qtber welJs _ _ _ _ _ _ _ _Yes 7 _S_ufficienacreage_ayailable indJilliog unjl _ _ _ _ _ _ _ _ _ Yes 8 Jtd_eviated, js weJlbQre platiocJu_ded _ _ _ - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - 9 _Qperator Only affected party _ _ - - - - - - _ Yes - - - - - - - - 10 _Qperator bas_apprppr[ate_ bond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 P_ermit Gan be issued wjtbQut conservatioo order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes Appr Date 12 Permit Gan be issued wjtbQut administrative_appr_oval _ _ _ Yes - - - - - - - - - - - - - - - - - - - RPC 12/21/2004 13 Can permit be approved before 15-day wait Yes 14 WelUQcated within area and strata authorized by_lnjectioo Order # (put 10# jn_ c_ornments)_ (For_ Yes _ _ _,11.10-3 - - - - - - - - - - - 15 AJI WeUsJ,,{ithtnJl4_mile_aJea_of reyiew id_eot[fied (For seJVj~J¡\(ell oolYL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y_es _ _ _ _ _ Y-04,Y:19,Y,33.Y:-3t _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 PJe-produ_ced injector; _duratiQnof pre-productioo less than:3 montbs_ (FQr_servlce well QnJy) _ _ _NA - - - - - - - - - - - - - 17 ACMP f'indingof CQn_ststency_ h_as bee_nJssued_ for tbis Project _NA - -.- Engineering 18 _Conductor stringpJQvided _ _ _ _ _ _ _ _ _ _ _ NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - 19 _S_urfa~casingprQtects alLknown USDWs _ _ _ _ _ _ _ _ _ _NA 20 CMT v_ol adequate to circulate oncooductor 8. surf CJ>g _ _NA 21 _CMT v_oladeQuate to tie-[nIQng _string to_SJJrf csg_ _ _ _ _ _ _ _NA - - - - - - 22 CMT will coyer_aJlI<OQwnpJQductiye bQrizQns_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - - - - - - - - - - - 23 Casing designs ad_equa_te tor C, 1, B _& permafrost _ _ _ _ _ _ _ Yes 24 AJ:!equate_tan_kage_or reserye pit _ _ _ _ _ Yes _ _ _ _CTDU. 25 Jtare-J:Irill, has a to-403 fQr abandonment be_eo apprQved _ _ _Y_es _ 12Jt3/2004. _ 26 AdequatewellboJe separatjo_n_proposeJ:!_ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - -- 27 Jfdjverter Je(LuiJed, dQe.s jtmeet reguJations_ ... NA . . _ Sidetrack.. . . . . . . . . . . . . . . _ _ _ _ Appr Date 28 Drilliog fJujdprQgram sGhematic_& eq.uiplistadequate_ _ _ Yes - - - - Max MW_8.7: ppgc . . . . . . . . . . _ _ WGA 12/27/2004 29 BQP_Es,_d_oJhey meet reguJatioo . ....... Yes - - - - - - - - 30 B_QPEpJess ratiog appropriate;_test to_(pu_t psig in_comrneots) _ Yes _ Test to 350Q psLMSF' 2420 psi._ 31 _C_hoke manifold cQmplies w/API ßF'-5:3 (May 84)_ _ . _ _ Yes 32 WQrk will pcc_ur withpuloperatjon _sbutdown_ . .... Yes - - - - - - - - - 33 Is presence_ Qf H2S gas_ probable. _. Yes . . . . . 120ppm. . 34 Mes::banicalcooditionot wells within AOß yerified (For_ s_ervice welJ only) Yes _ Cmtng JecorJ:!s indicate mech_ iotegrity QfaU AOR welJs. ------- Geology 35 P_ermit Gan be issued wlQ hyd(ogen sulfide meas_ure.s _ _ No_ 36 _D_ata_ PJes!!oted on pote_ntial 9verpressure _zone_s_ ...... .NA Appr Date 37 _S_elsmic_analysjs_ Qf .sballow 9as_z_ooes_ _ _ _ _ _ _ _ _ NA RPC 12/21/2004 38 _Seabed _condjtjoo survey _(if off-sh_ore) . NA 39 CQnta_ct namelphoneforweekly prpgressreports [expIQratO[J'_onIYl ...... .NA - - Geologic Date: Engineering Date Date Commissioner: Commissioner: ~~J£ '2.-( <9-' (1- Û'tf . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . **** REEL HEADER ,\*** MWD 06/08/03 BHI 01 RECE\VED AUG 0 7 2006 I\Iaska 011 & Ga& eons. CQnUIII&8iOn Anchof8gØ LIS Customer Format Tape **** TAPE HEADER **** MWD 05/01/21 . 82"a'864 01 3" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: ldwg.las ~Version Information VERSo WRAP. ~Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 10772.0000: STOP.FT 12600.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: ~ , TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: ~Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- 1.20 : NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. Y-06A Prudhoe Bay 70 deg 16' 4.498" N 148 deg 49' 37.627" W North Slope Borough Alaska Baker Hughes INTEQ 3" CTK 21-Jan-05 500292043101 ------------------------------- Description SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F OSl . ~Remarks " ' 34 llN 13E MSL o "RKB 81.3 KB 81.3 N/A o N/A DIRECTIONAL section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 UTC -b, ',- dCY-1 ' ;:;51 Il./ üG"") . . _. .. ,(1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data presrnted is real time data. (4) Baker Hughes INTEQ util}zed CoilTrak downhole tools and the Advantage surface system to fog this well. (5) Tools ran in the stringl included Casing Collar Locator, an Electrical Disconnect and Cif,culating Sub, a Drilling Performance Sub (Inner and 0fter Downhole Pressure, and Downhole Weight on Bit), a Dr'rectional and Gamma Sub, and a Hydraulic O.rienting Sub, w:th a Near Bit Inclination Sensor. (6) Data presented here is inal and has not been adjusted to a PDC (Primary Depth Control log. The INTEQ MWD Gamma Ray is the PDC for well Y-06A. (7) The sid~ track was drilled from Y-06 through a milled window in 7" liner. f Top of Window 10776 ft.MD ( 866.0 ft.SSTVD) Bottom of Window 10783 ft.MD (8871.2 ft.SSTVD) (8) The interval from 125651 ft.MD to 12600 ft.MD (8969.5 ft SSTVD to 8981.9 ft.SSTVD) was not log~ed due to bit to sensor offset. (9) Tied to Y-06 at 10622 ft.MD (8752.3 ft.SSTVD) (10) This wellbore Y-06A was kicked off the plugback wellbore Y-06APB1 at 11602 ft.MD (8910 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT ..' 10800.8, 10799.7, -1.03906 Tape Subfile: 1 70 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 ','\. 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN C8'JN .. , STAT Y-06A 5.xtf 150 BP Exploration (Alaska) Inc. Y-06A, Prudhoe Bay Unit North Slope Borough Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by SWS, 02-Mar-03 . *** INFORMATION TABLE: CIFO MNEM CBAN DIMT CNAM . ---------------------------------------------------- ODEP GR GR GRAX 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) ... - Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 2 ROP MWD 68 3 RAD MWD 68 4 RAS MWD 68 5 RPD MWD 68 6 RPS MWD 68 ~ \ Total Data Records: Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units **** FILE TRAILER **** 1 1 1 1 1 1 4 4 4 4 4 4 AAPI F/HR OHMM OHMM OHMM OHMM 4 4 4 4 4 4 ------- 24 111 10612.000000 12600.000000 0.500000 feet Tape Subfile: 2 124 records... Minimum record length: Maximum record length: **** FILE HEADER **** MWD .002 1024 " . 54 bytes 4124 bytes .. . . . *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT Y-06A.xtf 150 BP Exploration (Alaska) Y - 0 6A, Prudhoe Bay Unit North Slope Boro Alaska " *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO ~TBM,., CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 ROPS ROPS ROPA 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction 'fs down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: .. , Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROPS MWD 68 1 F/HR 4 4 3 RACL MWD 68 1 OHMM 4 4 4 RACH MWD 68 1 OHMM 4 4 5 RPCL MWD 68 1 OHMM 4 4 6 RPCH MWD 68 1 OHMM 4 4 ------- 24 Total Data Re~ords: 221 Tape File Start Depth Tape File End Depth Tape File Level Spacing 10612.000000 12600.000000 0.250000 . Tape File Depth Units **** FILE TRAILER **** . feet Ta¡JèS'Ubfile: 3 234 records... Minimum record length: Maximum record length: **** TAPE TRAILER **** MWD 05/01/21 828864 01 "" **** REEL TRAILER **** MWD 06/08/03 BHI 01 1¡¡ \ Tape Sub file: 4 Minimum record length: Maximum record length: " , 54 bytes 4124 bytes 2 records... 132 bytes 132 bytes . . Tape Subfile 1 is type: LIS ~ ~ " ' .. , ~ , . . Tape Subfi1e 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 10612.0000 94.5200 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10612.5000 ' ~~ 94.5200 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10700.0000 123.3900 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10800.0000 51. 0600 37.0800 17.7800 19.5800 9.6900 8.1800 10900.0000 37.3500 53.2200 5.0700 5.5000 5.2700 5.6000 11000.0000 39.9800 82.9000 6.2900 6.6200 6.0000 6.1000 11100.0000 32.6900 97.7400 6.3400 6.3100 -. ~ \ 5.5800 5.2200 11200.0000 34.4300 142.0400 7.1000 7.2900 6.7200 6.8300 11300.0000 37.1312 161. 4400 6.2800 6.1700 5.6600 5.5000 11400.0000 32.9800 151.9100 5.3000 5.2400 4.8200 4.6100 11500.0000 57.1800 157.8800 7.2300 7.4700 6.8200 6.7700 11600.0000 33.7390 174.5500 5.9300 5.6600 5.0200 4.7700 11700.0000 28.7500 133.3300 5.5000 5.2900 5.1600 5.6500 11800.0000 35.0500 78.8900 8.4600 7.7900 6.3700 5.6500 11900.0000 50.7500 211.7600 9.9200 9.9900 8.3900 7.6700 12000.0000 46.6400 143.6000 8.4000 6.7400 ~. 0",6.0000 5.5000 12100.0000 32.7300 153.7000 6.1700 4.9600 4.3300 3.6500 12200.0000 34.0200 182.4400 7.1000 6.0700 4.9200 4.0000 12300.0000 30.7400 166.2800 5.6000 4.8300 4.1300 3.3500 12400.0000 85.7700 150.3000 5.9600 5.5100 5.2700 5.0100 12500.0000 29.0800 117.0200 3.4900 3.3000 · . 3.2700 3.2500 12600.0000 -999.2500 -999.2500 -999.2500 Tape File Start Depth T~pe File End Depth Tape File Level Spacing Tape File Depth Units " '\, t¡, \ -'-"",^ " ' -999.2500 -999.2500 -999.2500 10612.000000 12600.000000 0.500000 feet . . Tape Subfile 3 is type: LIS DEPTH GRAX ROPS RACL RACH RPCL RPCH 10612.0000 94.5200 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10612.2500 94.5200 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10700.0000 123.3900 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10800.0000 51. 0600 37.0800 17.7800 19.5800 9.6900 8.1800 > .. \. 10900.0000 37.3500 53.2200 5.0700 5.5000 5.2700 5.6000 11000.0000 39.9800 82.9000 6.2900 6.6200 6.0000 6.1000 11100.0000 32.6900 97.7400 6.3400 6.3100 5.5800 5.2200 11200.0000 34.4300 142.0400 7.1000 7.2900 6.7200 6.8300 11300.0000 "'- 37.1312 161. 4400 6.2800 6.1700 5.6600 5.5000 11400.0000 32.9800 151.9100 5.3000 5.2400 4.8200 4.6100 11500.0000 57.1800 157.8800 7.2300 7.4700 6.8200 6.7700 11600.0000 33.7390 174.5500 5.9300 5.6600 5.0200 4.7700 11700.0000 28.7500 133.3300 5.5000 5.2900 5.1600 5.6500 - 11,¡3.00.0000 35.0500 78.8900 8.4600 7.7900 6.3700 5.6500 11900.0000 50.7500 211. 7600 9.9200 9.9900 8.3900 7.6700 12000.0000 46.6400 143.6000 8.4000 6.7400 6.0000 5.5000 12100.0000 32.7300 153.7000 6.1700 4.9600 4.3300 3.6500 12200.0000 34.0200 182.4400 7.1000 6.0700 4.9200 '., 4.0000 12300.0000 30.7400 166.2800 5.6000 4.8300 4.1300 3.3500 12400.0000 85.7700 150.3000 5.9600 5.5100 5.2700 5.0100 12500.0000 29.0800 117.0200 3.4900 3.3000 " . · . ",3.2700 3.2500 12600.0000 -999.2500 -999.2500 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units "--\. " ' " ' -999.2500 -999.2500 -999.2500 10612.000000 12600.000000 0.250000 feet . . Tape Subfile 4 is type: LIS .. , .. ' .. . . . **** REEL HEADER **** MWD 06/08/01 BHI 01 RECEIVED AUG 0 7 2006 .\JaIka 0It & Gal Cons. CommiI&iOn Anchorage . 1,4'3, Customer Format Tape **** TAPE HEADER **** MWD 05/01/19 828864 01 3" CTK *** LIS COMMENT RECORD !!! !! ! ! ! ! ! !!!!!!! ! ! !! ! !! ! ! ! ! ! !!!!!! ! ! ! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 10772.0000: STOP.FT 11875.0000: ~,STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- *** Remark File Version 1.000 Extract File: ldwg.1as 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. Y-06APB1 Prudhoe Bay 70 deg 16' 4.498" N 148 deg 49' 37.627" W North Slope Borough Alaska Baker Hughes INTEQ 3" CTK 19-Jan-05 500292043170 ----------------------------- Description SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKB .F EDF .F EGL .F CASE.F ~ OSl . -Remarks 34 llN 13E MSL o RKB 81.3 KB 81.3 N/A o N/A DIRECTIONAL Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 U Ie- d()f-{ <)£:/ It: 1"-( DC'1- . . (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data presented is real time data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well. (5) Tools ran in the string included casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub, with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been adjusted to a PDC (Primary Depth Control) log. The INTEQ MWD Gamma Ray is the PDC for well Y-06APB1. (7) The side track was drilled from Y-06 through a milled window in 7" liner. Top of Window 10776 ft.MD (8866.0 ft.SSTVD) Bottom of Window 10783 ft.MD (8871.2 ft.SSTVD) (8) The interval from 11841 ft.MD to 11875 ft.MD (8869.2 ft SSTVD to 8864.1 ft.SSTVD) was not logged due to bit to sensor offset. (9) Tied to Y-06 at 10622 ft.MD (8752.3 ft.SSTVD) ~(10) The we1lbore Y-06A was kicked off this plugback wellbore Y-06APB1 at 11602 ft.MD (8910 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 10800.8, 10799.7, -1.03906 Tape Subfile: 1 70 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** ~ , INFORMATION TABLE: CONS VALU MNEM ------------------------------------- WDFN LCC CN WN FN COUN STAT Y-06APB1 5.xtf 150 BP Exploration (Alaska) Inc. Y-06APB1 Prudhoe Bay Unit North Slope Borough Alaska *** LIS COMMENT RECORD *** !!! ! ! ! ! ! !!!!!!!!! !! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by SWS, 02-Mar-03 . . *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP -~,~-~~--------------------------------------------- GRAX ROPA GRAX ROPA GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames p~r record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GRAX MWD ROPA MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ~ -. ------- 8 Total Data Records: 31 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10611.000000 11874.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 40 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 1,) ;, *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN Y-06APB1.xtf 150 BP Exploration (Alaska) . . WN Y-06APB1 FN Prudhoe Bay Unit COUN North Slope Boro STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!! ! !!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *~* JNFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPA GRAX ROPA GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing unit~: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1., GRAX 2 ROPA MWD MWD 68 68 1 1 AAPI F/HR 4 4 4 4 ------- 8 Total Data Records: 61 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 10611.000000 11874.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 70 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 05/01/19 828864 01 . , ": ' . **** REEL TRAILER **** MWD 06/08/01 BHI 01 Tape Sub file: 4 Minimum record length: Maximum record length: '\I, ' ,,~. . 2 records... 132 bytes 132 bytes . . rape Subfile 1 is type: LIS io¡ \ ;,¡ . 1, . . . rape Subfile 2 is type: LIS DEPTH GRAX ROPA 10611.0000 -999.2500 -999.2500 10611. 5000 97.7200 -999.2500 10700.0000 123.3900 -999.2500 10800.0000 51. 0600 37.0800 10900.0000 37.3500 53.2200 11000.0000 39.9800 82.9000 11100.0000 32.6900 97.7400 11200.0000 34.4300 142.0400 11300.0000 37.1312 161.4400 11400.0000 32.9800 151.9100 11500.0000 57.1800 157.8800 11600.0000 33.7390 174.5500 1 h7{) 0 . 0000 23.9814 174.3100 11800.0000 87.2200 54.2400 11874.0000 -999.2500 -999.2500 Tape File Start Depth 10611.000000 Tape File End Depth 11874.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet ~ ' ~ .. 1;; .. . Tape Subtile 3 is type: LIS DEPTH 10611.0000 10611.2500 10700.0000 10800.0000 10900.0000 11000.0000 11100.0000 11200.0000 11300.0000 11400.0000 11500.0000 11600.0000 11700.0000 11800.0000 11874.0000 GRAX -999.2500 90.1400 123.3900 51.0600 37.3500 39.9800 32.6900 34.4300 37.1312 32.9800 57.1800 33.7390 23.9814 87.2200 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth units 1~, " 1;¡ " . ROPA -999.2500 -999.2500 -999.2500 37.0800 53.2200 82.9000 97.7400 142.0400 161.4400 151.9100 157.8800 174.5500 174.3100 54.2400 -999.2500 10611.000000 11874.000000 0.250000 teet . . Tape Subfile 4 is type: LIS ~ ~ " ' " '