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Home My WebLink About203-076New Plugback Esets 7/31/2024 Well Name API Number PTD Number ESet Number Date CD2-15 PB1 50-103-20386-70-00 201-159 T39326 4-26-2002 CD2-15 PB2 50-103-20386-71-00 201-159 T39327 4-26-2002 1D-42L1 PB1 50-029-22979-70-00 205-078 T39328 8-3-2005 2N-304 PB1 50-103-20382-70-00 201-130 T39329 9-12-2001 Mitre 1 PB1 50-103-20409-70-00 202-026 T39330 7-23-2002 C-26L1 PB1 50-029-22634-70-00 203-076 T39331 9-17-2003 C-26L1 PB2 50-029-22634-71-00 203-076 T39332 9-17-2003 C-26L1 PB3 50-029-22634-72-00 203-076 T39333 9-17-2003 MPU E-32 PB1 50-029-23261-70-00 205-065 T39334 7-7-2005 S-04L1 PB1 50-029-23148-70-00 203-053 T39335 7-14-2005 S-04L1 PB2 50-029-23148-71-00 203-053 T39336 7-14-2005 MPU S-05 PB1 50-029-23100-70-00 202-137 T39337 6-2-2003 B-03 PB1 50-883-20095-70-00 198-059 T39338 11-6-2003 07-28B PB1 50-029-21770-70-00 209-037 T39339 6-29-2009 16-23A PB1 50-029-22050-70-00 201-054 T39340 6-2-2003 W-34A PB1 50-029-21867-70-00 203-058 T39341 2-6-2004 SP30-W01 PB1 50-629-23476-70-00 212-142 T39342 11-14-2012 V-207L4 PB1 50-029-23390-71-00 208-070 T39343 9-11-2008 W-215 PB1 50-029-23172-70-00 203-131 T39344 9-12-2003 C-26L1 PB1 50-029-22634-70-00 203-076 T39331 9-17-2003 C-26L1 PB2 50-029-22634-71-00 203-076 T39332 9-17-2003 C-26L1 PB3 50-029-22634-72-00 203-076 T39333 9-17-2003 /Image PI Jject Well History File Cc. .br Page 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 Jf the file. c2 03 - {J f Ie? Well History File Identifier D Two-sided 111111111I111111111 Production Scanning Stage 1 Page Count from Scanned File: (J ~ (Count does include co~eet) Page Count Matches Number in Scanning Preparation: l/' YES f NO ¡ Date: C{ ~ ()."S /5/ YES NO XHVZE Organizing (done) RESCAN o Color Items: o Greyscale Items: o Poor Quality Originals: o Other: NOTES: BY: Helen ~ Project Proofing BY: Helen ~ Scanning Preparation BY: Helen ""~ BY: Heien c(Maria ) Stage 1 DIG~L DATA [r:;t6iskettes, No·1 o Other, NolType: 3 x 30 =C¡D o Rescan Needed 1- OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSI,ZED (Non-Scannable) o Logs of various kinds: o Other:~, I Date: q ¡;.q () S- 151 j , rt1P III Date: ~ ~ jes/sI VVl JD + N = TqTAL P.~GES a 7 , (Count ?1.s "ot incl de cover sh/et) lAAÍJ Date: . d-C¡ OS/sl , r t, . . I . m{J BY: Helen Maria If NO in stage 1, page(s) discrepancies were found: Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: Date: 151 III 11111111111 1111I 1111111111111111111 I n Date: 151 Quality Checked 11I1111111111111111 • • .-F.'` "„ "~ - '' r~ - MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE.. F:\LaserFiche\CvrPgs_Inserts\Microfilm_Marker. doc DATA SUBMITTAL COMPLIANCE REPORT 9/21/2005 Permit to Drill 2030760 MD 8545 / Well Name/No. MILNE PT UNIT KR C-26L 1 ìVD 7065""-- Completion Date 7/18/2003 / REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: Memory GR, CCL, RES Well Log Information: Log/ Data Digital ,Ty~ Med/Frmt f1=D C Lis ! i ~ i ! Rpt I~c I I I FC Pdf ¡ ~ i ~ ~C Pdf !~ I ED D Pdf i ¡ Rpt i ED D Pdf i ; i Rpt ! I ED D Pdt Rpt ED D Pdf Electr Dataset N~r Name 12572 Induction/Resistivity Lis ~59 I nd uction/Resistivity LIS Verification Pdf ~59 Induction/Resistivity rt2059 I nd uction/Resistivity 1.2659 I nd uction/Resistivity tf2Ô59 I nd uction/Resistivity -1'2059 Gamma Ray 1 ~9 Gamma Ray Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Directional Survey Operator BP EXPLORATION (ALASKA) INC Completion Status 1-OIL Samples No Log Log Scale Media Run No Current Status 1-OIL S¡;c.uJ. ~J~ ~3 API No. 50-029-22634-60-00 UIC N -------- Directional s~CYes 2-.- (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop OH/ CH Received 7/15/2004 7105 8545 Open 8/26/2003 7105 8545 Open 8/26/2003 25 7125 8545 Open 8/26/2003 25 7125 8545 Open 8/26/2003 25 Blu 7125 8545 Open 8/26/2003 25 Blu 7125 8545 Open 8/26/2003 25 7125 8545 Open 8/26/2003 25 Blu 7125 8545 Open 8/26/2003 6970 8545 9/17/2003 6970 8545 9/17/2003 6926 7640 9/17/2003 6926 7640 9/17/2003 6970 7490 9/17/2003 6970 7490 9/17/2003 6970 7916 9/17/2003 Comments INTEQ META, LlS-TIF, GRAPHICS MWD - Multiple Propagation Resistivity, Gamma Ray - MD MWD - Multiple Propagation Resistivity, Gamma Ray - ìVD MWD - Multiple Propagation Resistivity, Gamma Ray - MD MWD - Multiple Propagation Resistivity, Gamma Ray - ìVD MWD - Gamma Ray - MD MWD - Gamma Ray - MD ~~~ PB1 PB1 PB2 PB2 PB3 DATA SUBMITTAL COMPLIANCE REPORT 9/21/2005 Permit to Drill 2030760 Well Name/No. MILNE PT UNIT KR C-26L 1 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22634-60-00 MD 8545 ìVD 7065 Completion Date 7/18/2003 . Completion Status 1-01L Current Status 1-01L UIC N JRPt ~--- Directional Survey 6970 7916 9/17/2003 PB3 I.EÓ C 12304 Rate of Penetration 2 6984 7640 Open 12/11/2003 Multiple Propagation Resistivity/Gamma Ray L~ Rate of Penetration 2 Blu 6984 7640 Open 12/11/2003 Multiple Propagation Resistivity/Gamma Ray J¡Ð C 12304 Induction/Resistivity 2 6984 7640 Open 12/11/2003 Multiple Propagation Resistivity/Gamma Ray ttfg Induction/Resistivity 2 Blu 6984 7640 Open 12/11/2003 Multiple Propagation Resistivity/Gamma Ray !~ C 12304 Gamma Ray 2 6984 7640 Open 12/11/2003 Gamma Ray i iL.øQ Gamma Ray 2 Blu 6984 7640 Open 12/11/2003 Gamma Ray ~ C Las 12304 Gamma Ray 2 6984 7640 Open 12/11/2003 Wireline Gamma Ray ¡t;D C Las 12304 Induction/Resistivity 2 6984 7640 Open 12/11/2003 Wireline Multiple Propagation ! Resistivity/Gamma Ray I E9- C Las 12304 Rate of Penetration 2 6984 7640 Open 12/11/2003 Wire line Multiple i Propagation Resistivity/Gamma Ray I:Ôg Gamma Ray Blu 6984 7490 Open 4/29/2004 PB2 I i,Jd>g Induction/Resistivity Blu 6984 7490 Open 4/29/2004 PB2 ~g Induction/Resistivity Blu 6984 7490 Open 4/29/2004 PB2 i ED C Lis ./ See Notes 12502 6951 7490 4/29/2004 RWD-MPRlGRlDIR PB2 ! i Rpt 12502 LIS Verification 6951 7490 4/29/2004 lED /' I C Lis 12572 I nd uction/Resistivity 7103 7916 Open 7/15/2004 PB3, INTEQ META, LlS- I TIF, GRAPHICS L~ I nd uction/Resistivity 25 Blu 7125 7916 Open 7/15/2004 DSN 12572, Log./ Induction/Resistivity 25 Blu 7125 7916 Open 7/15/2004 DSN 12572, Log/ Gamma Ray 25 Blu 7125 7916 Open 7/15/2004 DSN 12572, ; I ! Rpt-/ LIS Verification Open 7/15/2004 DSN 12572, i Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Permit to Drill 2030760 MD 8545 ìVD 7065 ADDITIONAL INFORMATION Well Cored? Y ® Chips Received? ~Y / N Analysis Received? ~ Comments: Compliance Reviewed By: ./ DATA SUBMITTAL COMPLIANCE REPORT 9/21/2005 Well Name/No. MILNE PT UNIT KR C-26L 1 Operator BP EXPLORATION (ALASKA) INC Completion Date 7/18/2003 Completion Status 1-01L Current Status 1-01L Daily History Received? ~N Gffi Formation Tops ,~ Date: API No. 50-029-22634-60-00 UIC N -- _0- __~_ :2 ¿ r¡i-~- > ----=. . Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: MPC-26LIPB3 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary ~o 3> /0 7 ç~, i2..51¿ '&1. BAKER HUGHES Anchorage GEOScience Center ) 1 blueline - GR/Directional Measured Depth Log 1 blue line - MPR Measured Depth Log 1 blueline - MPR True Vertical Depth Log LAC Job#: 498151 SentBy:~~?¡]el I L / Received ~W·, MAat/bJ ::::: ~(/vf PLEASE ACKNOWLEÌ>GE 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 ....--~. .~~--_.. ~~-----._-_.. -----."--" lL__:::.~_'::::J~ --~ .. .... .., ...... .. ~. - . "I ... - .... - -.... - .. ., _. .."... .'.... ... ." ,.'j .... ....... -,;,. -:" - -............ -.......- :'....~.;.... ¡ =:=I~ :::::'~~ ---------.----.---------.-- .....I':"'f JIIdI' IiA .., '.:.1 ......................................,.... " 11>I"',1" fII'~"'~1 ~ ~ .... -----,---.-------_._----------- ~~.,'"..~ ,~.. _~., .1'....1..,: -',II .., !:~:t.n -. ". ." -,,".,,¡. .--.--------,,---------------_.._------_... ,,¡:' i~ Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: MPC-26LIPB2 .x D ~ - 0 ìf.tJ Contains the following: '&1. BAKER HUGHES Anchorage GEOScience Center 1 LDWG Compact Disc -# / 1. )0 À (Includes Graphic Image files) 1 LDWG lister summary L-- 1 blueline - GR/Directional Measured Depth Log '-- 1 blue line - MPR Measured Depth Log c..--- 1 blueline - MPR True Vertical Depth Log LAC Job#: 498151 Sent By: Glen Horel Received By: ~ O~ Date: Apr 20, 2004 Date: ;) '1 fLpÀI~'vf 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 1a\I.:'~-;ta:-.J:tti1.""'OJJ ,..------··~~..~·-~';'ï\.;;..7i,;,.--'--; _"'I __ u ., .,..' . -' . '.1 _ , - .... _. , ------1 ~",' I "!~~ , .;-; ~ ;: :;. ~\ ~~:-j _"'" __ ..r ..-....... _.._~ I ~.. ¡ ::::::'::¡ ::~=,~ ~-----:~j7,:;;::~~:---~:.~- 1~~~~~~~~~~1~~:~~~ ï¡cia:i"-'¡-~=',:'_ I ! n ·'1 ~l Transmittal Form INTEQ d03 -O'~9-(c ".. BAKER NUGHIS Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: MPC-26LIPBl II Contains the following: II ) o)::l j II 1 LDWG Compact Disc ~O !I (Includes Graphic Image file ) ,I 1 LDWG lister summary :1 1 blueline - GR/Directional Measured Depth Log 1 blueline - MPR Measured Depth Log 1 blueline - MPR True Vertical Depth Log I Ii I I II LAC Job#: 498151 Sent By: Glen Borel Received BY~~ ~~'9..s1'- "Nt--~ Date: RtièË1VE[) Date: DEC 11 2003 ---_._----~-._------, l!J1J,Tk."'· ~·!U.1I1JJt'«J ----.-.;,;.,;, ::.- -:,'::..;..:.....~.- -'.... - .. .. .... , .. -- .... .." .-: -- þ~'" ..... -. ..1 ...... ....~.. ..--------.---------- _..... _ .... I":. ',.,r >#'_......, .........- _.,.," ~,'" ; J"," :,)11(' *"'II <11;, ...." ""'1_ .. .... ... ~.. ~"J..1' [ ""';]I:, 11..~1 1IIIID:I ..;. ''1: .""1" , . '. - -. ... " .. ,.. - ._-,"'..' -.'.", . . ....._..~._-,--,-_.__.__.-..- !t!.'J: : ~ ."""- ,-,.. ....,.......'h'" AI_a OU & Gas Cons. COmm~n PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & ~ING 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 ~~~'D,\\ .~J> ;:[¿:::~~: ; _ ,,"r..._ -..... ~,...,..._._._--"_. -.'. Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: MPC-26L1 ~C3rO 7-(p r&i. BAKER HUGHES Anchorage GEOScience Center 1·-··------·---·-- !I Contains the following: il P"C-. C\ II 1 LDWG Compact Disc \ ~ð CU II (Includes Graphic Image files) III LDWG lister summary III' 1 blue line - GR/Directional Measured Depth Log I 1 blueline - MPR Measured Depth Log ¡II' 1 blueline - MPR True Vertical Depth Log I, I Î' I, II I! II It_~!-c Job#: 498151 Sent By: Glen Borel Received BY:~~- 'l.~C.LO-:'~ Date: Aug 22, 2003 Date: 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 ~~~M~ ,: ECEIVED AUG 26 2003 Ala$ka O¡~ i.~ GHS Certs. Commiasion AV}chof8ge - --------.._"_.__._.,----~"-_.. -----~_._."'--_.__. 1m.I.1"1.'l"·1f*-~~Y¡1"Q:J .....~ - ......... "" .""'" I I " STATE OF ALASKA i ALAS~ JIL AND GAS CONSERVATION COr{ .3SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 1m Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 One Other 5. Date Comp., 9~p., or A~and. 7~003 pD 6. Date Spudded 6/20/2003 o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1086' NSL, 2419' WEL, SEC. 10, T13N, R10E, UM Top of Productive Horizon: 2174' NSL, 2791' WEL, SEC. 10, T13N, R10E, UM Total Depth: 1678' NSL, 1677' WEL, SEC. 10, T13N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558041 y- 6029367 Zone- ASP4 TPI: x- 557659 y- 6030453 Zone- ASP4 Total Depth: x- 558778 y- 6029965 Zone- ASP4 18. Directional Survey 1m Yes 0 No No. of Completions 21. Logs Run: Memory GR, CCL, RES 7. Date T. D. Reached 7/13/2003 ' 8. Elevation in feet (indicate KB, DF, etc.) KBE = 46.3' 9. Plug Back Depth (MD+ TVD) 8545 + 7065 10. Total Depth (MD+TVD) 8545 + 7065 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 1 b. Well Class: 1m Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-076 13. API Number 50- 029-22634-60-00 14. Well Number M PC-26L 1 15. Field and Pool Milne Point Unit I Kuparuk River Sands Ft Ft 16. Lease Designation and Serial No. ADL 047471 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) 77¿J~~ v:r7b'/?7þ I I, '". I ,'I ';'I,:.,rf¡.~),,~~~',:IF,¡r;, 91.1# 40# 26# 14.9# 8.81# /6.2# / 6.16# CASING, LINER AND CEMENTING RECORD '.sE-rTING,O~P!hli"';',;,,','ti~~E,'} ,:"::\:i,I,;',:'::,;":',: ,', ,",'i 'I,": ,.'1, ,'. '. ',,' , !!,:"a~iI1W(!\IM'I:~""I,'" ")":I",:'~I~~"',"";,'II ::~;~~ft:l1'I/'jI~,,~eG~~!!!:i ,':':1",',', I'I"!' " ,',: 32' 112' 24" 260 sx Arctic Set (Approx.) 31' 4704' 12-1/4" 924 sx PF 'E', 250 sx 'G', 150 sx PF 'E' 28' 6882' 8-1/2" 170 sx Class 'G' 6727' 6970' 8-1/2" 115 sx Class 'G' 6987' 8545' 3-3/4" Uncemented Slotted Liner 22. CASING, '., I"')::"""$IZE,,',,," 20" 9-5/8" ~ , I' '. '" 'I 'I " I": " :' ,I ",' I ,:,~, :I"I:I'I:,II,,:,;}P,RÄ,~I~:,:,:,.:,':,,'I:,I: ,.\ II' I '~""" " H-40 L-80 L-80 NT13Cr80 L-80 7" 5" * 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-7/8" Slotted Section MD TVD MD TVD 7396' - 7749' 7034' - 7034' 7809' - 7969' 7038' - 7054' 8062' - 8512' 7065' - 7068' 26. Date First Production: August 12, 2003 Date of Test Hours Tested , " , ' , ,: ,AMOUNT'PULLE!Q,:'!" ¡'.'!) .., 'It 3-1/2", x 3-3/16" x 2-7/8" SIZE 3-1/2",9.3#, L-80 PACKER SET (MO) N/A DEPTH SET (MD) 6652' DEPTH INTERVAL (MD) 2500' ?:5/::' '..' "",':::' "':,,\,:' ACln' ,FRAC!URE,."CEMENT:SQUe'EiE, . ETC.', , ~"""", 1'1,,":: I:.' ,I,·', : ,'., I ;.' "'" "; r:)I' ','" ,:I I,..,,' " ,,' ," ',",,' '," "':, ' ',' I I ' ""I II 1'""",'1, ",1"",,, ,1,1",1"11,,,,11,,,,,,111,,,: ''II,JII,I,'",'I, , ',I, ,11..,'"',,,'Ilpl, 1,,1' ,1",,,,,1,, "I" , I" I ,I', 11,,1'1 ,11111' ,', ""': AMOUNT & KIND OF MATERIAL USED Freeze Protect with 90 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Hydraulic Pump Oll-Bsl GAs-McF 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;--,:-'-------. ¡ C' /:v1 :~¡r:-rION ( J ' , öArt ~ !~"!loRIGINAL PRODUCTION FOR TEST PERIOD -+ Flow Tubing Casing Pressure CALCULATED ~ Oll-Bsl Press. 24-HoUR RATE""" 27. None Form 10-407 Revised 2/2003 W A TER-Bsl GAs-McF W A TER-Bsl CHOKE SIZE GAS-Oil RATIO Oil GRAVITy-API (CORR) CONTINUED ON REVERSE SIDE RlBlDMS 6Ft, AUG 2 8 Kuparuk A3 GEOLOGIC MARK~' NAME MD TVD 6974' 6875' 7155' 7008' 7180' 7021' 7262' 7036' 7668' 7034' 8474' 7071' 29. (' Include and briellY summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". FORMATION TESTS 28. Kuparuk 86 None Kuparuk A Kuparuk A3 Kuparuk A2 Kuparuk A2 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~. rt,ß~ Title Technical Assistant Date Oe:rt9·Q3 MPC-26L 1 203-076 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Mark Johnson, 564-5666 Permit NO.1 Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". " ') ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 nRlh'~Jl\ , ( f BP Operations Summary Report Page 1 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-26 MPC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12/29/1995 End: 7/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/15/2003 00:00 - 09:00 9.00 MOB P PRE Move rig from MPL-01A to MPC-26. Position rig mats, pull rig over well. Plover bird stayed on nest during noisy positioning. Accept rig 09:00 hrs 6-15-2003. 09:00 - 11 :00 2.00 MOB P PRE Rig up. Spot cuttings tank. Shim rig (Pad not level). lAP = 260 psi. No pressure above BPV. RU BPV lubricator and pull BPV. 11 :00 - 12:00 1.00 KILL P DECOMP RU kill line to tubing and choke line to IA. 12:00 - 12:30 0.50 KILL P DECOMP Crew change safety meeting. 12:30 - 15:30 3.00 KILL N HMAN DECOMP Wait on berm crew and flowback tanks. 15:30 - 16:00 0.50 KILL P DECOMP PT lines in cellar. 16:00 - 16:45 0.75 KILL P DECOMP Walk lines, spot trucks. 16:45 - 17:00 0.25 KILL P DECOMP Safety meeting. Review kill operational plan. 17:00 - 20:30 3.50 KILL P DECOMP Circulate 300 bbls 150deg SW around at 5 bpm holding 400 psi on choke. Lost 39 bbls to formation. Follow with 9.3ppg formate brine. Lost 60 bbls to formation during kill. Wellhead and IA Opsi. OA 220 psi. 20:30 - 21 :15 0.75 WHSUR P DECOMP Set TWC. Test from below to 100 psi. Pressure bled off quickly but no flow up through TWC. 21 : 15 - 21 : 30 0.25 WHSUR P DECOMP PJSM. Review N/D procedures. 21 :30 - 22:30 1.00 WHSUR P DECOMP ND 2 9/16" tree. Set-up to occasionally pump down IA while ND/NU. 22:30 - 22:45 0.25 BOPSUR P DECOMP PJSM review NU of 13 5/8" 5K BOP stack. 22:45 - 00:00 1.25 BOPSUR P DECOMP Start NU BOPE. (base line: filllA took 3 bbls, will check each hour) 6/16/2003 00:00-05:15 5.25 BOPSUR P DECOMP Continue NU of 13 5/8" 5K BOP stack. FilllA wi 3 bbls @ 0100hrs, 4 bbls @0300hrs Started testing choke manifold same time during NU. 05:15 - 06:00 0.75 BOPSUR P DECOMP Pressure test BOPE. Witness waived by AOGCC's John Crisp. 06:00 - 06:30 0.50 BOPSURP DECOMP Crew change safety meeting. 06:30 - 08:00 1.50 BOPSURP DECOMP Hook up koomey lines, MU test joint, RU hose to fill well. Well took 14 bbls (after not filling for 3 hours). 08:00 - 10:30 2.50 BOPSURP DECOMP Test BOPE. Well taking about 5 - 7 BPH. 10:30 -11:30 1.00 BOPSURN SFAL DECOMP Failed test on kill line HCR. Replace. Small annular flange leak -- tighten. 11 :30 - 12:30 1.00 BOPSUR N DECOMP Flange leak on annular-- nuts kinda loose -- maybe need some torque wrench calibration or training. Also, found some other loose nuts -- tighten. 12:30 - 14:00 1.50 BOPSUR P DECOMP Finish BOP test. Hole still taking about 7 BPH. 14:00 - 15:00 1.00 PULL P DECOMP Pull TWC. Fill well. 15:00 - 17:00 2.00 PULL P DECOMP RU landing joint. Screw into hanger. BO lock-down screws. Pull hanger to floor, smooth 50k up. 17:00 - 18:00 1.00 PULL P DECOMP POH laying down 2 7/8" completion string. 18:00 - 18:20 0.33 PULL P DECOMP Crew change PJSM 18:20 - 00:00 5.67 PULL P DECOMP Continue laying down completion string. Check NORM 1-4 micro rems. Hole taking +/- 20bbllhr. 147jts of 201 jts lid @ midnight. 6/17/2003 00:00 - 03:00 3.00 PULL P DECOMP Continue POH with 2 7/8" ESP completion string. Hole took 153 bbls during lid of tubing. Total estimate bbls lost formation since killing well is 233 bbls. 03:00 - 04:30 1.50 PULL P DECOMP LID Baker ESP motorlpump assembly. Clear floor. 04:30 - 06:00 1.50 BOPSURP DECOMP Set 11"x7" false bowl and FMC BVP. 06:00 - 06:30 0.50 BOPSUR P DECOMP Safety meeting. Printed: 7/22/2003 8:50:30 AM ( ( BP Operations Summary Report Page 2 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-26 MPC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12129/1995 End: 7/1912003 Date From - To Hours Task Code NPT Phase Description of Operations 6/17/2003 06:30 - 11 :30 5.00 BOPSUR P DECOMP ND 13 5/8" stack to the mud cross. Filling hole continuously (siphoning). Losses steady at 11 BPH. 11:30 - 15:00 3.50 BOPSUR P DECOMP NU XO spool, 7" full opening valve and 7" CTD BOP stack. 15:00 - 15:30 0.50 BOPSUR P DECOMP Confirm no pressure on IA. Pull BPV. 15:30 - 16:00 0.50 BOPSUR P DECOMP Set test plug. Rig up to pressure test. 16:00 - 20:30 4.50 BOPSUR P DECOMP Pressure test 7" BOPE. 250psi / 5min, 3500psi / 5min. AOGCC waived witnessing test. Filling hole continuously. 8-10 bbls/hr 20:30 - 21 :15 0.75 BOPSURP DECOMP Confirm no pressure on IA then pull test-plug. Hole took 8 bbls to fill. 21 :15 - 23:15 2.00 CLEAN P DECOMP Stab 2 3/8" coil to injector. Install SLB CTC. Pull test to 30k. PT to 3700psi 23: 15 - 00:00 0.75 CLEAN N SFAL DECOMP Problem with SLB PowerPak Priority Pump, only charging hydraulic system to 1/2 normal pressure and making chattering noise. Call out SLB mechanics. Monitoring hole. 6/18/2003 00:00 - 03:00 3.00 CLEAN N SFAL DECOMP Replace SLB priority pump on the hydraulic PowerPak unit. 03:00 - 04:05 1.08 CLEAN P DECOMP P/U cleanout BHA (56.3') 04:05 - 06:00 1.92 CLEAN P DECOMP RIH. Load pits with 9.3 ppg flopro. Prep to swap to Flo-Pro 06:00 - 07:30 1.50 CLEAN P DECOMP Clean out to 7300'. No solids or obstructions found. Begin swap to mud. 07:30 - 09:00 1.50 CLEAN P DECOMP POOH at 80%. Still appear to be losing 0.1 bpm on micro-motion, will confirm once done with mud swap. 09:00 - 09:45 0.75 CLEAN P DECOMP At surface. Well stable. Get off well and LD motor & mill. 09:45 -10:15 0.50 CLEAN P DECOMP RIH with 6.105 drift gauge ring assembly on coil. Tag obstruction at 4698'. Set down 5-10K#. No progress. Very solid tag. 10:15 -11:30 1.25 CLEAN N DPRB DECOMP POOH to check gauge ring. Order out 6.0 & 5.97 rings. 11:30 -12:00 0.50 CLEAN N DPRB DECOMP At surface. Ring shows clear dent which flattened lip. Looks like smaller ring might go. Minimum drift for packer specified by Baker is 6.0'. (Packer od is 5.968") 12:00 - 13:00 1.00 CLEAN N DPRB DECOMP Wait on gauges rings from WOA wireline shop. 13:00 - 13:15 0.25 CLEAN N DPRB DECOMP MU 6.0" gr on BHA. 13:15-14:30 1.25 CLEAN P DECOMP RIH with gr/jb. Tag top of liner at 6727'. No tight spots noted on run in and out. Flag pipe. 14:30 - 15:30 1.00 CLEAN P DECOMP POOH. 15:30 - 16:30 1.00 CLEAN P DECOMP At surface. LD GR/JB. MU Weatherford WS drift assemby. 16:30 - 18:30 2.00 CLEAN P DECOMP RIH and make dummy whipstock packer drift run with 4.05" drift to 7030'. TOH 18:30 - 19:10 0.67 CLEAN P DECOMP LID dummy WS drift. P/U Baker seal assembly to test 7" csg. Have lost 28 bbls Flo-pro to formation since swapping to mud. 19:10-21:10 2.00 CLEAN P DECOMP RIH to 6741' sting into 5" tie-back sleeve. (problem getting started below surface at 52'. Haven't figure what the problem was yet.) 21:10 - 21:45 0.58 CLEAN P DECOMP Test 7" csg to 3500psi for 30 min. Bled down to 3430psi and held. Good test 21 :45 - 22:50 1.08 CLEAN P DECOMP TOH 22:50 - 23: 1 0 0.33 WHIP P WEXIT PJSM with SWL review rig-up procedures. 23: 1 0 - 00:00 0.83 WHIP P WEXIT R/U SLW equipment and P/U WE packer assembly. 6/19/2003 00:00 - 00:15 0.25 WHIP P WEXIT Continue P/U WeatherfordlTlW whipstock packer assembly w/ SWL tools. 00: 15 - 02:45 2.50 WHIP P WEXIT RIH with whipstock packer to 7030'. Log CCLlgr up to 6600' make +1' correction. RIH stacked out at 6700', didn't see this Printed: 7/22/2003 8:50:30 AM { BP Operations Summary Report Page 3 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-26 MPC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12/29/1995 End: 7/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/19/2003 00: 15 - 02:45 2.50 WHIP P WEXIT on first pass through. Work 5 times before working past 6700' no drag on pick-ups. RIH to 7030' get on depth with bottom of packer at 6984'. Fire setting tool. Saw tool stroke but not shear off. P/U to check if free. Cannot P/U. Cycled to 6K four times. (Socket good for +/- 8K) Came free on last attempt. Tools still with us. RIH tagged packer at 6980'. P~S tool indicates mule shoe setting at 133L of highside. 02:45 - 03:30 0.75 WHIP P WEXIT POH 03:30 - 04:00 0.50 WHIP P WEXIT R/D SWL 04:00 - 06:00 2.00 WHIP N HMAN WEXIT Weatherford has the wrong XO to fit Latch Assembly to Sperry tools. Need 2 7/8" PACp x 1 1/2" MTb and they brought 2 3/8" PAC. No 2 7/8" PAC on rig inventory. WO tools from Deadhorse. Hole took 10 bbls to fill since 0100 hrs. 06:00 - 07:45 1.75 WHIP P WEXIT MU Sperry survey tool and whipstock latch BHA assembly. Get on well. 07:45 - 09:30 1.75 WHIP P WEXIT RIH with BHA. Check up weight: 28K#. Tag packer at 7008'. Set down 5K#. Pull up to 32K#. Allow ESS tool to record for several minutes. PU to 34K# to shear from packer. 09:30 - 10:30 1.00 WHIP P WEXIT POOH. 10:30 - 12:00 1.50 WHIP P WEXIT At surface. LD BHA and recover ESS tool. Found TF reading of 226 deg, which is within 1 deg of SLB P~S tool reading of 133L. 12:00 - 12:45 0.75 WHIP P WEXIT MU Weatherford whipstock assy on anchor. Orient lug offset to 176 degress from face. MU running BHA. 12:45 - 13:45 1.00 WHIP P WEXIT RIH. Up wt at 6950': 25K#.. RIH Sting into packer. PU to 33K#. Shear off WS. 13:45 - 15:00 1.25 WHIP P WEXIT POOH. 15:00 - 15:45 0.75 WHIP P WEXIT At surface. LD whipstock running BHA. MU one step window milling assembly wI 3.8" HCC mill and W-ford carbide string reamer. 15:45 - 17:00 1.25 STWHIP P WEXIT RIH with milling assembly. 17:00 - 19:00 2.00 STWHIP P WEXIT Tag WS at 6984'. PU and establish FS at 2500 psi@2.6 bpm. Slack off until contact with tray. Begin slowly milling ahead. 19:00 - 22:00 3.00 STWHIP P WEXIT Milling window at 6986.5' 2.63bpm in / 2.57bpm out 9.36ppg FS = 2540psi 2-300psi motor work. Cleaning magnets often. Milled window to 6990'. (all depths are uncorrected) Corrected window depths after logging RA tag: 6976', TOW: 6970', BOW: 6976'. 22:00 - 22:35 0.58 STWHIP P WEXIT Drilled formation f/6990' to 7000'. Clean pick-up through window. 22:35 - 23:10 0.58 STWHIP P WEXIT Ream down/up through window and to TD. 23:10 - 23:15 0.08 STWHIP P WEXIT P/U to 6970'. RIH wo pump. Dry tag at TD looked good. P/U dry - clean through window. Formation sample caught - sand/cement. 23:15 - 00:00 0.75 STWHIP P WEXIT TOH for build assembly. Paint EOP flag at 6500'. 6/20/2003 00:00 - 00:45 0.75 STWHIP P WEXIT Continue TOH with milling assembly. 00:45 - 01 :20 0.58 STWHIP P WEXIT Set back injector and lId BHA. Mill is in gauge 3.80" string mill 3.69" 01 :20 - 01 :30 0.17 DRILL P PROD1 PJSM review next BHA 01 :30 - 02:20 0.83 DRILL P PROD1 P/U BHA #7 (60.08') Same time make repairs to mud pump #1 02:20 - 03:45 1.42 DRILL P PROD1 RIH to 1050', shallow-hole test tools - ok, continue, RIH to EOP flag correct +1.5' RIH to 6735'. Printed: 7/22/2003 8:50:30 AM ( BP Operations Summary Report Page 4 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-26 MPC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12129/1995 End: 7/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/20/2003 03:45 - 05:25 1.67 DRILL P PROD1 Log tie-in Bit> gr= 20.25' (Kalubic shale marker @ 6735') -17' correction. Top of 5" liner at 6927' is causing attentuation of GR values. This may not be a good place to tie-in if needed in the future. 05:25 - 05:35 0.17 DRILL P PROD1 RIH tagged bottom at 6984'. 05:35 - 06:00 0.42 DRILL P PROD1 Orienting 06:00 - 09:00 3.00 DRILL P PROD1 Begin drilling build section. 2650 psi fs @ 2.7 bpm. Drill to 7023'. Lots of stalls, slow but steady drilling. Orienter working well. Drilling with 4-1/4" Hycalog. Logged RA tag at 6976'. TOW is revised to 6970', BOW is 6976'. 09:00 - 14:45 5.75 DRILL P PROD1 Drill ahead. 2670 psi fs at 2.71 bpm. ROP: 20-30 fph. Initial build rate: 43 per 100. Dropped off to 35 per 100. Decide to pull for motor adjustment and 4-1/8" bit. Drilled to 7095'. 14:45 - 16:00 1.25 DRILL P PROD1 POOH. Hold PJSM for BHA change out at 2000'. 16:00 - 16:45 0.75 DRILL P PROD1 At surface. Get off well. Change motor AKO from 3.0 to 3.28 16:45 -18:10 1.42 DRILL P PROD1 RIH. Test MWD at 1250'. Test good. Continue to RIH to flag, correct -14'. RIH tagged TD at 7097' correct to 7095'. 18: 1 0 - 18:45 0.58 DRILL P PROD1 Orienting. Have a little trouble getting in sync with MWD. 18:45-21:15 2.50 DRILL P PROD1 Drill ahead f/7095' at 2.63bpm 2700fs. Drilled to 7180'. 21:15 - 22:05 0.83 DRILL P PROD1 Wiper trip to the window and orient. 22:05 - 00:00 1.92 DRILL P PROD1 Drill ahead f/ 7180'. Landed out at +/- 7180' (6557'tvd). Orient to 90R drill ahead to 7230' at 40'/hr wI 9k WOB. Starting to have good weight transfer. 6/21/2003 00:00 - 01 :30 1.50 DRILL P PROD1 Continue drilling ahead fl 7230'. 2.65bpm 2725psi FS 9-1 Ok WOB 400-600psi motorwork 30'/hr. Drill to 7270' with 90R TF 01 :30 - 02:00 0.50 DRILL P PROD1 Orient to 80R and wiper to 7000'. 02:00 - 03:05 1.08 DRILL P PROD1 Continue drilling ahead f/7270'. 2.65bpm 2745psi FS 9-1 Ok WOB 400-600psi motorwork 20'hr. Drilled to 7300'. Have lost 17 bbls mud to formation since 1800 hrs. Regularly cleaned ditch magnets lastnight. Very little metal remains in system. 03:05 - 05:00 1.92 DRILL P PROD1 TOH to change motor setting for lateral section and pick-up resistivity. Pump rate 2.8bpm paint EOP flag at 6500'. 05:00 - 07:30 2.50 DRILL P PROD1 Setback injector. Swap motor and p/u resistivity tools. Program tools. Stab on. Get on well. 07:30 - 09:30 2.00 DRILL P PROD1 RIH. Shallow test. Unable to sync up with mwd. POOH. 09:30 - 15:00 5.50 DRILL N DFAL PROD1 LD BHA. Pull MWD probes from collars. LD same. Probe broke in half while laying down on catwalk. (PJSM procedure had every one out from under load area). Prep replacement tool. Surface test and program same. Stab BHA. Get on well. 15:00 - 15:30 0.50 DRILL N DFAL PROD1 RIH. Shallow test MWD. Good. 15:30 - 16:15 0.75 DRILL P PROD1 RIH to tie in bit depth of 6730'. 16:15 - 16:45 0.50 DRILL P PROD1 Log gr tie in. 16:45 - 19:05 2.33 DRILL P PROD1 RIH. Some trouble getting past 7070'. PU and orient. Get down to 7135'. Same problem. Having to work through high dogleg areas. Work to 7200'. Back ream to 7050'. RIH W/R to 7228'. Backream to window. W/R down to 7258'. Motor stalling sticky on p/u. Backreaming. This is getting ugly. Working hole from 7100'-7250'. RIH w/ min pump to 7272'. P/U cleaner wo pump. Looking better. Work down to 7300'. 19:05 - 20:30 1.42 DRILL P PROD1 Orient to 60L 20:30 - 21 :25 0.92 DRILL P PROD1 Drill ahead f/7300' 2.62bpm 2900 FS. 50-100 psi motorwork. Stacking wt. drill to 7318'. Decide to swap mud for possible better weight transfer. Will hang on to used mud until beyond Printed: 7/22/2003 8:50:30 AM ~ BP Operations Summary Report Page 5 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-26 MPC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12/29/1995 End: 7/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/21/2003 20:30 - 21 :25 0.92 DRILL P PROD1 1 st fault zone. 21 :25 - 22:35 1.17 DRILL P PROD1 Circulate and clear up hole with new Flo-Pro. Much better hole conditions. Orient same time. 22:35 - 00:00 1.42 DRILL P PROD1 Drill ahead f/ 7318'. Much better weight transfer 2.68bpm 2900psi FS 5k WOB 60'/hr 400 psi motorwork. ROP > 100'/hr by 7400'. Crossed 1st fault at 7363' with no mud losses. Released old mud. Drilled to 7420'. Plan to drop down to 6965' tvdss based on throw of 1 st fault. 6/22/2003 00:00 - 01: 1 0 1.17 DRILL P PROD1 Directionally drill ahead f/7420' to 7515'. Crossed several step faults. No losses. 01: 1 0 - 01 :55 0.75 DRILL P PROD1 Wiper trip to 7000'. Tight spots at 7160'-80'. Clean going back in hole. 01 :55 - 04:25 2.50 DRILL P PROD1 Drill ahead f/7515' to 7554'. Good P-rate until 7554'. Maybe up against another fault. No trouble drilling through previous faults other than kicking angle up. Took off drilling again. 2.6/2.61 gpm 2850psi FS 2-300psi motor work 10-11 K wob 40-50'/hr Drilled to 7641'. 04:25 - 06:45 2.33 DRILL P PROD1 Wiper trip to 7000'. Working past ledge at 7204' and orienting same time to 70L stacked out 7205', pick-up RIH wo pump stacked again. PU and orient highside stacked again. Orient to 60R still stacked out. Tried all combinations. Decide sidetrack option is likely. Discuss plan with town. 06:45 - 08:45 2.00 DRILL N DPRB PROD1 MADD pass OH above 7204' to get better GR data after mud swap. Repeat section showed no GR shift after mud swap. 08:45 - 09:15 0.50 DRILL N DPRB PROD1 Orient to 90R. 09:15-10:15 1.00 DRILL N DPRB PROD1 Drill ahead at 7204'. 2800 psi fs@2.6 bpm. 150 dpsi mtrwork. Taking weight, appear to be sidetracking. ROP: 30-50 fph. Drill to 7230'. 10:15 - 10:30 0.25 DRILL N DPRB PROD1 Wiper trip to 7150'. Hole smooth up and down. 10:30 - 15:00 4.50 DRILL N DPRB PROD1 Drill ahead. 2800 psi fs @ 2.6 bpm. 100-300 dpsi on motor. Getting 15 deg/1 00 turn. Plan to continue with 1.2 deg mtr. ROP:50-75 fph. ROP slowed at 7310'. Suspect possible fault. Drill & orient to 7333'. 15:00 - 18:00 3.00 DRILL N DPRB PROD1 Drill ahead to 7356'. Turn rate at 11-13 deg/1 00. Decide to pull for stronger motor. 18:00 - 20:10 2.17 DRILL N DPRB PROD1 TOH 65-70'/min 2.7bpm flag EOP at 6500'. 20:10 - 21:50 1.67 DRILL N DPRB PROD1 Change motor setting from 1.2 to 2.6deg and download resitivity tool. 21 :50 - 00:00 2.17 DRILL N DPRB PROD1 RIH shallow hole test. RIH to 6500' correct to EOP flag -19.5' correction. 6/23/2003 00:00-00:15 0.25 DRILL N DPRB PROD1 Log tie-in at 6735'. Correct +3' 00: 15 - 02:00 1.75 DRILL N DPRB PROD1 RIH. Set downs at 7005,7036',7067' . RIH make it to bottom 7356'. P/U to orient but unable to RIH to bottom. Backream from 7250-7150'. RIH work past 7170-7180' still unable to get past 7300. Orient to 90R rih tagged at 7299' P/U rih at 120R tag at 7319'. P/U 38-30k rih stacked out at 7339' p/u RIH to bottom. 02:00 - 02:30 0.50 DRILL N DPRB PROD1 Orient around to 90R get back on bottom. 02:30 - 02:35 0.08 DRILL N DPRB PROD1 Drill ahead f/ 7356' 2.56bpm 2800 FS stacking weight work pipe. Rolled over to 135R 02:35 - 03: 15 0.67 DRILL N DPRB PROD1 Orient back around to 90L. Getting about 50% on the clicks. Makes it difficult to get correct TF. At 90 Put 1 click into orienterto get to 135. Printed: 7/22/2003 8:50:30 AM { ( BP Operations Summary Report Page 6 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-26 MPC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12/29/1995 End: 7/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/23/2003 03: 15 - 04:45 1.50 DRILL N DPRB PROD1 Drill ahead with 120TF 2-300psi motor work. 1 0-12k wob. Slow drilling 20-30'/hr. Drill to 7392'. 04:45 - 04:55 0.17 DRILL N DPRB PROD1 Short wiper trip back to 7300'. 04:55 - 05:20 0.42 DRILL N DPRB PROD1 Orient around to 90-1 OOR 05:20 - 13:00 7.67 DRILL N DPRB PROD1 Drill ahead f/7392' w/110R TF. 2730 psi fs @ 2.65 bpm. 200-300 dpsi mtr work. ROP:15-20 fph. Very slow. Continue to hold 85 deg while turning east. Drill to 7484'. 13:00 - 14:30 1.50 DRILL N DFAL PROD1 Short trip up into 7" casing to 5750'. Pulled tight at 7175'. Work pipe and clean up hole. RIH. Work past 7070'. Stop at 7204'. Orient to 130R. RIH no problem. MWD failed, tool sending up bad data. 14:30 - 17:00 2.50 DRILL N DFAL PROD1 POOH at 90% for MWD. Getting a lot of cuttings across shaker with bit at 1200'. 17:00 - 20:45 3.75 DRILL N DFAL PROD1 At surface. Get off well. LD MWD probe. Motor, Orienter. Download resistivity. P/U new motor, mwd, orienter. 20:45 - 21 :45 1.00 DRILL N DFAL PROD1 RIH, shallow test at 1523', something wrongTOH. 21:45 - 22:35 0.83 DRILL N DFAL PROD1 Reprogram MWD to send Fat pulses. 22:35 - 22:55 0.33 DRILL N DFAL PROD1 RIH test at 600' - ok 22:55 - 00:00 1.08 DRILL N DFAL PROD1 Continue RIH to EOP at 6200'. Correct -17' RIH 6/24/2003 00:00 - 00:35 0.58 DRILL N DFAL PROD1 Log tie-in at 6735' +3' correction. 00:35 - 01 :25 0.83 DRILL N DFAL PROD1 RIH tagged at 7001' pu went through. (tried to orient several clicks - no response) RIH to (2.65 bpm 2900 fs) tagged at 7388', work to bottom w/o pump. 01 :25 - 02:00 0.58 DRILL N DFAL PROD1 Start new mud downhole. Wiper trip back 5-600psi mw, 33-40k pu pulled tight at 7447' Really ratty hole. Fighting between 7400-7485'. Work pipe to bottom. New mud seems to be helping. 02:00 - 03:55 1.92 DRILL N DFAL PROD1 Circulate and try to clean this hole up. Questioning orienter now also. Re-sync MWD. Orient might be working. Having problems with MWD re-sync. Okay re-sync'd. Orienting and lost sync. Swap to pump #2. Still not seeing continuous pulses/ pulse is strong but then dies. Tool may be plugging off. Try higher rate without help. Shut down and recycle MWD. (last chance) Pulsing....RIH to bottom . 03:55 - 04:05 0.17 DRILL N DFAL PROD1 Drill ahead f/7483' to 7490' putting some motorwork pressure on system. Still having problems wtih inconsistant pulses. Surface transducer does not seem to be the problem. There are two independent transducers with the same intermittent flat pulse observed. 04:05 - 05: 1 0 1.08 DRILL N DFAL PROD1 TOH overpulls 40-50k f/ 7370'-7180'. Pulled to 4100' to fix levelwind. Noticed that MWD has not skipped any pulses since leaving the window. It's going to be hard to tell whats wrong with a working tool. 05:10 - 06:30 1.33 DRILL N DFAL PROD1 RIH to try again. Tie into EOP flag. RIH. Tight hole at 7190'. Attempt to orient. Lose MWD pulses in higher dogleg sections. 06:30 - 08:00 1.50 DRILL N DFAL PROD1 POOH to trouble shoot tools and weekly test BOPS. 08:00 - 08:30 0.50 DRILL N DFAL PROD1 Get off well. LD BHA/mwd. Discuss leaving out resistivity tool with town team. 08:30 - 15:00 6.50 BOPSURP PROD1 Weekly test of BOP equipment. Paged AOGC 3 times in last 18 hours. No response. Test against master valve. Good test. E-mail results to AOGCC. 15:00 - 15:30 0.50 DRILL N DFAL PROD1 MU BHA assembly. Stab coil. Get on well. Printed: 7/22/2003 8:50:30 AM ( ( Page 7 of 21 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M PC-26 M PC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT Phase 6/24/2003 15:30 - 17:00 1.50 DRILL N 17:00 - 17:30 0.50 DRILL N 17:30 -18:30 1.00 DRILL N 18:30 - 19:45 1.25 DRILL N 19:45 - 20:30 0.75 DRILL N 20:30 - 22:30 2.00 DRILL N 22:30 - 22:50 0.33 DRILL N 22:50 - 00:00 1.17 DRILL N 6/25/2003 00:00 - 01 :50 1.83 DRILL N 01 :50 - 02:00 0.17 DRILL N 02:00 - 03:40 1.67 DRILL N 03:40 - 05:00 1.33 DRILL N 05:00 - 07:30 2.50 DRILL N 07:30 - 09:00 09:00 - 10:30 1.50 DRILL N 1.50 DRILL N Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12/29/1995 End: 7/19/2003 Description of Operations RIH. Shallow test mwd. Good. Continue in hole. Log GR tie in at 6730'. Subtract 1'. Orient to go through window. Orienter not clicking, then jumping several clicks. POOH for orienter. At surface. Unstab and get off well. LD new style W-ford. PU older style with bleed sub. RIH shallow hole test MWD and Orienter. RIH tie in to EOP flag -16' correction. Tag up 7,000'. Orient to high side. No Go. Orient 15R. RIH with pumps at 7034 set down. Set down at 7200 old side track. Orient 105 R NO GO Tried fast ,slow withand without pumps. Orient 120 R. Orient 120 R. Set down 7225, 72787300 worked to bottom. Incorrect tool face. Orient to 20R NO GO at 7204' Over pull 35K. RIH 60R 2.6 bpm at 2800 psi worked down 7234 120R. Tag 7469. 2.6/2.6 bpm 3100. Incorrect tool face 165L. Pull heavy. Cannot orient below 7200'. RIH stack out 7308 PU and attempt to orient. Orient to high side. Continue to try and orient near btm. No clicks. Over pull our way up hole to 7200'. Hole smooth above this point. Able to get click for click. Unable to get back down to btm and hold correct tool face. DPRB PROD1 POOH for orienter. Discuss options with town. DPRB PROD1 At surface. Unstab coil from BHA. Get off well. Decide to OH sidetrack. PU Sperry orienter (w/12/32" bleed sub orifice) and Hughes sidetrack bit. Keep 1.7 deg mtr. Stab coil. Get on well. RIH. Shallow test MWD & orienter. Both working well. Questions on directional plan forward. Wait on directional plan decisions to verify required motor angle. Hold discussions with rig team and Steve Horton and AI Pate. RIH with 1.7 mtr. Begin increasing mud wt from 9.3 to 9.8 ppg. Log GR tie in from 6730'. -19 ft at flag. +8 feet after tie in (?) Work through window. Several tries. Got through at 135R. Continue in hole. A few set downs, fairly smooth. Orient to 180 deg. Having trouble getting clicks. Micro motion packing off. Try at 7190 moving pipe up, down, and static. Nothing. POOH to 7000'. Get two clicks. RIH. TF flopped back to 10R, but still an improvement. RIH to 7150'. Getting 1 for 3 15 deg clicks. SLowly working around to 180 deg. Orienter (Sperry) appears to be too weak to handle 45 deg d-Iog geometry. Orient at 7070, 7006Not getting any clicks. PU into casing 6933 attempt to get clicks None. Orienter failure. DFAL PROD1 POH paint flag at 6100 EOP. POH to surface. Mud up to weight: 9.8 ppg. DFAL PROD1 Change out orienter WAIT PROD1 Accident Mike Price got left forearm pinched in little jerk pipe tongues while attempting to bleed off hydraulic pressure prior to riggijng up tubing cutter. Made notifications MPU security, DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 10:30 - 11 :30 1.00 STKOH N DPRB PROD1 11 :30 - 12:30 1.00 STKOH N DPRB PROD1 12:30 - 13:30 1.00 STKOH N DPRB PROD1 13:30 - 14:00 0.50 STKOH N DPRB PROD1 14:00 - 15:00 1.00 STKOH N DPRB PROD1 15:00 - 19:30 4.50 STKOH N DPRB PROD1 19:30 - 20:30 1.00 STKOH N 20:30 - 21 :30 21 :30 - 00:00 1.00 STKOH N 2.50 STKOH N Printed: 7/22/2003 8:50:30 AM t' ( BP Operations Summary Report Page 8 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-26 MPC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12/29/1995 End: 7/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/25/2003 21 :30 - 00:00 2.50 STKOH N WAIT PROD1 Paul Hyatt, Jeff Kilfoyl. Milne EMS transported Mike Price to Milne Point base for initial evaluation. Perform initail investigation with Rig Crew, Schulmberger Management team, Paul Hyatt, Mary Vendi, Jeff Kilfoly. 6/26/2003 00:00 - 01 :00 1.00 STKOH N WAIT PROD1 Continue accident investigation. 01:00 - 01:15 0.25 STKOH P PROD1 PJSM for cutting coil. 01 :15 - 02:30 1.25 STKOH P PROD1 Cut 450 ' of coil. 02:30 - 04:00 1.50 STKOH P PROD1 Install coil connector. Pull test to 40K. Pressure test to 4000 psi. OK. 04:00 - 05:30 1.50 STKOH N DFAL PROD1 RIH with R60st bit on 1.6 mtr. 05:30 - 06:00 0.50 STKOH N DPRB PROD1 Log GR tie in. -16' correction. 06:00 - 07:00 1.00 STKOH N DPRB PROD1 RIH. Work though window. Finally get through with 50-60R TF and pumping at 2.4 bpm. 07:00 - 08:00 1.00 STKOH N DPRB PROD1 RIH to 7160'. Short trip to clean up hole. 08:00 - 09:00 1.00 STKOH N DPRB PROD1 Orient to 160R. 09:00 - 10:30 1.50 STKOH N DPRB PROD1 Begin OH trough up at 160R from 7150' to 7135'. 10:30 - 11 :00 0.50 STKOH N DPRB PROD1 POOH to 6850'. Shut down for safety standown. 11 :00 - 12:30 1.50 STKOH N DPRB PROD1 Hold standown mtg in ops cab with Milne Point reps and Nordic 2 crew. 12:30 - 14:00 1.50 STKOH N DPRB PROD1 Attempt to move pipe. Stuck. Able to pump down coil, no returns 1.8 bpm @ 3300 psi. Work pipe to max push & pull (-10k & 80K#). Pressure down back side at 500,1000,1500 psi. Work pipe. Bleed backside quickly & work pipe. Repeat several times. No movement. 14:00 - 16:30 2.50 STKOH N DPRB PROD1 Drop circ sub ball. Get on seat. Shear sub. Circ pressure dropped slighly: 3100 psi@ 1.8 bpm. Continue to work pipe. Concerned about pipe life. (50%/7904K ft) Drop disconnect ball. Pull 70K. Disconnect sheared at 4500 psi. No pipe movement. 16:30 - 00:00 7.50 STKOH N DPRB PROD1 Continue safety standown. Review coil cutting procedures with chemical cutter. Review incident with Tom Gray, Devin Rock, Doug Stevens and Dave Hendricks. 6/27/2003 00:00 - 06:00 6.00 STKOH N DPRB PROD1 Continue safey standown. Nordic/Schumberger crew completed Walkthru reviewing the items on the "Nordic 2 CTD Training Matrix" 06:00 - 18:00 12.00 STKOH N DPRB PROD1 Begin review of training matrix with day crew. Walk through rig and discuss specifics of each piece of rig equipment, its operation, energy source, potential hazards, and use. Also discuss which hands should operate equipment and which should not. Generate detailed matrix document for each rig hand during walk through. Hold 2 hr mtg in ops cab with crews, Nordic & SLB management. Discuss matrix revisons. 18:00 - 00:00 6.00 STKOH N PROD1 Review revised training matrix with New Schulmberger night crew and Nortic night crew. 6/28/2003 00:00 - 17:00 17.00 STKOH N DPRB PROD1 Safety stand down. Review plan forward. Addressing details and specific equipment requirements. 17:00 - 19:00 2.00 STKOH N DPRB PROD1 Final review with MPU asset the completion of the requirements to proceed issued by the incident investigation committee. Asset agreed the requirements were fullfilled and concurred with returning the rig to operations. 19:00 - 22:20 3.33 STKOH N STUC PROD1 Attempt to work pipe. Pull80K SO -18 NO Go. Bullhead 13 bbls .@ .7 bpm and 2200 psi. while holding 80K. No Go. Stack Printed: 7/22/2003 8:50:30 AM ( (' BP Operations Summary Report Page 9 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-26 MPC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12/29/1995 End: 7119/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/28/2003 19:00 - 22:20 3.33 STKOH N STUC PROD1 25k while bullheading. NoGo. Bullhead 25 bbl dead crude and displace with mud .25 bpm and 2200 psi. Continuing to have 25K stacked. Increase rate of displacement to 1 bpm @ 3100 psi. This matches the pressure used to displace the ball for the disconnect. Bull head 10 bbl crude out of coil. 22:20 - 00:00 1.67 STKOH N STUC PROD1 Allow crude to soak. Periodically pump 5 bbls and shut down. Pull pipe in tension. Conducted table top Fire and well control drills. 6/29/2003 00:00 - 04:30 4.50 FISH N STUC PROD1 Pump 5 bbl crude and soak. Pull 53K 23 over hold. Pump 5bbl crude. Hold at neutral weight. Work pipe 90K to 6K. Pressure backside to 1500 and bleed off rapidly. No Go. Bullhead balance of crude and over displace by 20 bbl. 04:30 - 04:45 0.25 FISH N STUC PROD1 PJSM for cutting coil at surface and stripping up injector. 04:45 - 06:00 1.25 FISH N STUC PROD1 PU injector. Close upper combi rams with 1 OK# over pull (37K# total). Cut coil under injector. 06:00 - 06:30 0.50 FISH N STUC PROD1 Hold PJSM / Tech Limit mtg in ops cab to discuss general operations forward. Discuss mu of coil head assembly. 06:30 - 09:30 3.00 FISH N STUC PROD1 Dress coil. MU Macco type coil connector. Pull test same & re-tighten connector. Pull test to 30K#. OK. MU block valve, pump in sub. RU sling from bails to YT elevators to provide enough room for e-line packoff assembly. 09:30 - 12:00 2.50 FISH N STUC PROD1 RU SLB e-line equipment. Spot truck. Hang sheave from derrick. Thread and RU packoff. 12:00 - 14:00 2.00 FISH N STUC PROD1 RIH with free point indicator. Pipe getting "more free" with depth. Tool readings appear to be bad. POOH for second FP tool. 14:00 - 14:30 0.50 FISH N STUC PROD1 Get off well. Change out free point tool. Get on well. 14:30 - 18:30 4.00 FISH N STUC PROD1 RIH. Calibrate FP tool. Continue to measure "stations". Free Point indicates that the Coil is free to the coil connector. 18:30 - 19:30 1.00 FISH N STUC PROD1 Discuss the plan forward with Anchorage. 19:30 - 21 :00 1.50 FISH N STUC PROD1 Wait on GR. 21 :00 - 21 :45 0.75 FISH N STUC PROD1 PJSM for PU and rih with chemical cutter. 21 :45 - 22:45 1.00 FISH N STUC PROD1 MU & PU chemical cutter. 22:45 - 00:00 1.25 FISH N STUC PROD1 RIH with chemical cutter. RIH to 200'. Release combi's. Pull 5 k over with blocks. Continue to RIH to logging depth. Correct to setting depth +16' correction. Set cutter on depth 6,746'. 6/30/2003 00:00 - 00:50 0.83 FISH N STUC PROD1 Attempt to cut coil. NO GO. Down hole electrical short . 00:50 - 01 :50 1.00 FISH N DFAL PROD1 POH. 01 :50 - 02:00 0.17 FISH N DFAL PROD1 PJSM to LD unfired chemical cutter. 02:00 - 02:25 0.42 FISH N DFAL PROD1 Change out chemical cutter. Second tool not testing. GR is suspected source of problem. Spare GR just returned form another job. 02:25 - 04:00 1.58 FISH N DFAL PROD1 Wait on GR. 04:00 - 05:00 1.00 FISH N DFAL PROD1 Further investigation idenfified the fireing head as source of problem. PU Chemical cutter. 05:00 - 05:10 0.17 FISH N DFAL PROD1 PJSM to pu and running chemical cutter. 05:10 - 05:30 0.33 FISH N DFAL PROD1 MU chemical cutter. 05:30 - 07:00 1.50 FISH N STUC PROD1 RIH. Log tie in to whipstock setting gr log from 6-19-03. Place cutter at 6747'. Pull 50K (18k# over pipe up weight). Pipe jumped with cut. PU on blocks to verify free. 07:00 - 08:00 1.00 FISH N STUC PROD1 POOH with cutter. 08:00 - 10:00 2.00 FISH N STUC PROD1 At surface. Hold PJSM. LD e-line tools. RD SLB trucks etc. PU on coil 1 0' to verify free. Slack off. Coil dropped slowly in Printed: 7/22/2003 8:50:30 AM ( ~' BP Operations Summary Report Page 10 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-26 MPC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12/29/1995 End: 7/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 6/30/2003 08:00 - 10:00 2.00 FISH N STUC PROD1 hole, as though sinking into fill, back to original depth. 10:00 - 13:00 3.00 FISH N STUC PROD1 Hold PJSM. Prep to splice coil with spoolable connector. Round up all equipment & tools. Discuss well control contingencies. Inspect injector sling. MU to injector. 13:00 - 15:30 2.50 FISH N STUC PROD1 Prep coil ends for connector. Make splice. Strip down over coil with injector. Get on well. POOH. Connector failed after passing gooseneck. Held together with Smiley splice cable assembly. 15:30 - 16:00 0.50 FISH N STUC PROD1 Evaluate situation and make plan forward. 16:00 - 18:00 2.00 FISH N STUC PROD1 RU to Resplice. 18:00 - 18:30 0.50 FISH N STUC PROD1 PJSM with new crew on resplice procedure. 18:30 - 19:30 1.00 FISH N STUC PROD1 Resplice field connection. 19:30 - 20:00 0.50 FISH N STUC PROD1 Weld field connection. 20:00 - 21 :30 1.50 FISH N STUC PROD1 POH to surface with coil tubing fish. 21 :30 - 22:00 0.50 FISH N STUC PROD1 Strip off well. End of coil packed full of fill. Stab back onto well. Pump to clear obstruction. Circulate mud out of coil fish. 22:00 - 22:15 0.25 FISH N STUC PROD1 RU N2. 22: 15 - 22:30 0.25 FISH N STUC PROD1 PJSM for displacing coil to N2. 22:30 - 23:30 1.00 FISH N STUC PROD1 Cool down N2 unit. Displace coil with N2. 23:30 - 23:45 0.25 FISH N STUC PROD1 PJSM for stripped off well and pulling back the tubing to the reel. 23:45 - 00:00 0.25 FISH N STUC PROD1 Pull back coil tubing to reel. 7/1/2003 00:00 - 01 :30 1.50 FISH N STUC PROD1 Spool back coil tubing to reel. Secure reel for shipment. 01 :30 - 01:45 0.25 FISH N STUC PROD1 PJSM for lower reel to Peak trailer. 01 :45 - 03:00 1.25 FISH N STUC PROD1 Lower reel to Peak double drop trailer. Delicate operation due to position of rig and distance to edge of pad. Well done. 03:00 - 03:45 0.75 FISH N STUC PROD1 Wait arrival of Peak crane to reposition new reel on tail of trailer to accomodate tight quarters on the location. 03:45 - 05:00 1.25 FISH N STUC PROD1 Reposition reel on trailer and spot trailer under reelhouse. 05:00 - 06:00 1.00 FISH N STUC PROD1 PU reel into reel house and align drive pins. 06:00 - 09:00 3.00 FISH N STUC PROD1 Bushings not fitting into reel. Drop same. Replace bushings. PU reel. 09:00 - 11 :30 2.50 FISH X SFAL PROD1 RU hardline on inner reel valve. End of CT on inside of reel too long, pinning it against inside of spool. Modify spool in order to MU the hardline. 11 :30 - 12:30 1.00 FISH N STUC PROD1 Slip connector into reel and pull test. 12:30 - 15:00 2.50 FISH N STUC PROD1 Pull CT over pipe shed with winch and stab injector. Stop to remove clamps from top rollers on gooseneck 15:00 -15:10 0.17 FISH N STUC PROD1 PJSM 15:10 - 16:00 0.83 FISH N STUC PROD1 Pickup lubricator. MU CTC & Dart catcher. 16:00 - 17:15 1.25 FISH N STUC PROD1 PT Hardline to 4000psi. Good test. Pump foam pig. Foam pig is difficult to insert into CT, need to find a better way. CT volume= 60.5bbls 17:15 - 17:30 0.25 FISH N STUC PROD1 PJSM 17:30 - 18:45 1.25 FISH N STUC PROD1 PU Cleanout assembly BHA #16: Cleanout nozzle and one joint of 2-3/8" PH6. 18:45 - 19:45 1.00 FISH N STUC PROD1 RIH to 6627. 19:45 - 22:00 2.25 FISH N STUC PROD1 Wash to 6674. Wash back to 6627. Wash from 6627 to top of liner at 6727 @3.9 bpm at 3611 psi. Pump 10 bbllow vis followed by 20 bbl high vis sweep. Pull back at 10.2 ftlmin. to 6627. Wash from 6627 to 6764. CTU top of fish. Circulating @3.9 bpm at 3611 psi. Pump 10 bbllow vis followed by 20 bbl high vis sweeps. Wash back to 6627 @. 6ft/min. Wash down Printed: 7/22/2003 8:50:30 AM f ~ {' BP Operations Summary Report Page 11 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-26 MPC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12/29/1995 End: 7/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/1/2003 19:45 - 22:00 2.25 FISH N STUC PROD1 from 6627 to top of fish @ 3.9 bpm at 3500 psi. Pump 10 bbl low vis followed by 12 bbl high vis sweeps. Top of fish corrected to E line depth 6747'. Paint flag 6500 EOP Eline corrected. Sweeps bring back cow pie's but not blinding screens. Cutting have been continuous since pumping began. Didn't witness seeing any evidence of tagging top of fill but a 4 bpm unlikely unconsolidated top of fill would be seen. 22:00 - 00:00 2.00 FISH N PROD1 POH @ 63 fpm pumping at 3.9 BPM @3360 psi 7/2/2003 00:00 - 00:15 0.25 FISH N STUC PROD1 POH to surface. 00:15 - 01 :00 0.75 FISH N STUC PROD1 Set back injector and LD BHA #16. 01 :00 - 06:00 5.00 BOPSUR P PROD1 Weekly BOPE test. BOP test witness waived by AOGCC's Chuck Shieve. 06:00 - 06:30 0.50 FISH N STUC PROD1 PJSM, Crew change. 06:30 - 07:00 0.50 FISH N STUC PROD1 Load BOT tools into pipe shed. 07:00 - 07:20 0.33 FISH N STUC PROD1 PJSM: Discuss PU wash pipe and jars. Pinch points, overhead loads, good communication. Hot work permit needed for installing CTC. Focus. 07:20 - 09:00 1.67 FISH N STUC PROD1 PU BHA #17: Mule shoe, 3.75" Wash pipe extension, 3.5" Wash pipe, Circ Sub, Hyd Dis., Bowen up/dwn jars, 2x drill collars, accelerator, swivel, BPV, CTC. Cut coil and MU Baker CTC. Pull test, Press test CTC. Stab injector. 09:00 - 10:30 1.50 FISH N STUC PROD1 RIH. Correct depth to EOP flag at 6500'. -18' correction. 10:30-11:15 0.75 FISH N STUC PROD1 RIH and tag up on liner top at 6,720'. Pumping 2.5 bpm. Work through liner top. Successfully get through liner top wlo pump. Increase pump to 2.5 bpm, 2,135 psi. Wash down. Pressure increased to 2,800 psi at 6,735.1'. Continue washing down and pressure dropped off. Wash down to 6,738.5'. Weight check. PU=26K. Wash to 6,740'. PU=26K, SO=17K. Wash to 6,745.2'. PU. Continue washing down to 6,749'. 11 :15 - 12:00 0.75 FISH N STUC PROD1 Attempt to wash over fish at 6,749.4'. Unable to get over fish. 12:00 - 13:45 1.75 FISH N STUC PROD1 POH at 1:1 pumping 3bpm. 13:45 - 14:00 0.25 FISH N STUC PROD1 PJSM on LD tools. 14:00 - 17:00 3.00 FISH N STUC PROD1 LD BHA #17. Found mule shoe 2/3 packed with clay and gravel. Discuss forward plan with town team and rig team. Unload mud pulse MWD tools from pipe shed. Modify wash string guide from mule shoe to cut-lip style. Surface test Weatherford old style orientor. Getting 15deg clicks. 17:00 - 19:00 2.00 FISH N STUC PROD1 PU BHA #18. Tapered wash string with orientor and cut-lip guide. 19:00 - 20:30 1.50 FISH N STUC PROD1 RIH tag liner top 6722. Orient RIH to 6735 pressure up. Continue to wash. 2.5 bpm at 2300 psi. Anticipated top of fish 6749 Take weight 6751'. 20:30 - 00:00 3.50 FISH N STUC PROD1 Wash over 2.5 bpm @ 2350 psi. Washover to 6760 PU to neutral weight. Continue to wash 6765 PU to neutral weight 25K. Washing at 2.5 bpm @2500 psi to 6770 PU to 6765 Clean pick up. Wash back to 6770 2.9 bpm @ 2800 psi and to 6774. PU to 6765. Clean pickup. Wash 6777. 7/3/2003 00:00 - 06:30 6.50 FISH N STUC PROD1 Continue to wash 2.9 bpm @ 2950 psi. Averaging about 10'/hr sweeping hole every 100 bbl with high vis sweep. Wash back to 6782. PU to 6,775'. Clean pick-up. Wash 2.9 bpm 2850 psi. Wash to 6785. PU to 6775. Wash to 6787 2.9 bpm and 2900 psi. Continue to wash to 6793 with 2.9 bpm @ 3050 psi. PUts remain clean and sweeps aren't bringing back any abnormal Printed: 7/22/2003 8:50:30 AM BP Operations Summary Report Page 12 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-26 M PC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12/29/1995 End: 7/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/3/2003 00:00 - 06:30 6.50 FISH N STUC PROD1 amounts of cuttings. Wash to 6790. PU to 6769. Wash to 6794. PU to 6789. Wash to 6796. Starts taking weight at 6796'. This is close to the coil connector depth on fish (calculated at 6794'). PU. 06:30 - 07:30 1.00 FISH N STUC PROD1 Orient 45deg. Wash down, still taking wt below 6796'. 2850psi 2.86/2.86bpm in/out. Park at 6801.5, slowly gain weight back. Wash down to 6803.5, bring pump rate up to 3.4bpm at 3450-3500psi. (OA=583psi, PVT=204) Start losing fluid over shakers, back rate down to 3bpm at 2940psi. PU clean. Off bottom circ press= 2900psi at 3bpm. 07:30 - 09:30 2.00 FISH N STUC PROD1 Send 10bbl High Vis pill around. Continue washing over fish at 6,809.4'. Orient to place shoe in different position. 3.0 bpm / 2,900 psi. Set down and see pressure increase, weight coming back. Clean pick up. Wash to 6810.6'. Progress has slowed considerably, we should be safely below the upper disconnect at this point. Based on our initial tag at 6749' at top of fish we expect the top of the CTC at 6796' & the top of the lower disconnect at 6801'. We consistently start stacking weight at 6804' which places the 3.75" x 3.5" washpipe XO 8' back at 6796' (top of CTC). 09:30 - 11 :00 1.50 FISH N STUC PROD1 POH pumping 3bpm at 60fpm chasing high vis pill to surface. 11 :00 - 11: 15 0.25 FISH N STUC PROD1 PJSM 11:15 -13:00 1.75 FISH N STUC PROD1 LD BHA #18. PU Orientor and function test. Good test. PU BHA #19: Baker Hydraulic Overshot with cut-lip guide, Weatherford Orientor, Disconnect, circ-sub, UplDown Jars, 2x drill collars, Accelerator. 13:00 - 15:00 2.00 FISH N STUC PROD1 RIH with BHA #19 15:00 - 15:30 0.50 FISH N STUC PROD1 PU wt= 26000lb above 5" liner top. See top of liner at 6722'md, fall through. Continue RIH dry. Tag top of fish at 6740'. Set down 40001b. PU, overpull to 42,000. Lose wt as we pull out of 5" liner, continue poh. PU above liner top 28000lb. Looks like we latched onto fish. 15:30 - 16:40 1.17 FISH N STUC PROD1 POH, filling across the top. PJSM- discuss LD fish and BHA, overhead loads and Coil memory are paramount. Discuss job roles and keep floor clear. 16:40 - 18:00 1.33 FISH N STUC PROD1 LD BHA #19. No Fish overshot plugged with cuttings. MU BHA 20. 18:00 - 19:25 1.42 FISH N STUC PROD1 RIH at .4 bpm at 1070 psi. RIH 6700 CTM . Up wt = 26K . RIH correct to liner top -10' correction. Circulate 1.44 bpm at 2700 psi. 19:25 - 20:00 0.58 FISH N STUC PROD1 Begin washing at 6710 corrected depth. Tag liner to 6725 No Go . Orient 4 . No Go . Orient 4. No Go Orient 4 OK 20:00 - 20:15 0.25 FISH N STUC PROD1 Tag 6736 Washing 1.36 bpm @ 2500 psi. Wash to 6740'. PU 10'. Wash to 6745. PU 10'. Wash to 6749 1.5 pbm 3200 psi. PU 10'. Wash to 6751 PU 10'. Wash to 6752.2 Top fish. PU 10'. Wash to 6753 stacking. Short trip and wash 6754. Pressure increase 200 psi jars hit down got weight back. 20:15 - 20:30 0.25 FISH N STUC PROD1 Circulate 1.5 3200 psi to clear annulus of fill. 20:30 - 21 :15 0.75 FISH N STUC PROD1 Shut down pump. Pull 52 Kpull above liner top set down see liner top with cutlip guide. PU to 6650. RIH seen bobble at 6673 bottom of fish tagging liner top "Maybe" . Need to look and see. 21:15-23:00 1.75 FISH N STUC PROD1 POH filling across the top of the hole. Printed: 7/22/2003 8:50:30 AM t ,JII' ( BP Operations Summary Report Page 13 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-26 MPC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12/29/1995 End: 7/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/3/2003 23:00 - 23:30 0.50 FISH N STUC PROD1 LD BHA NO Fish. Cut lip guide partially plugged off. 23:30 - 23:45 0.25 FISH N STUC PROD1 Establish plan forward. (prep for rotary work and get custom 4.125 shoe made to washover with coil) 23:45 - 00:00 0.25 FISH N STUC PROD1 PJSM for removal of pipe from shed. 7/4/2003 00:00 - 04:30 4.50 FISH N STUC PROD1 RU standpipe. Continue removing liner/tubing from pipe shed. 04:30 - 05:00 0.50 FISH N STUC PROD1 Move Kelly and kelly sock into pipe shed. 05:00 - 06:00 1.00 FISH N STUC PROD1 Load 3-1/2" PH6 work string into pipe shed. 06:00 - 06:30 0.50 FISH N STUC PROD1 Technical limits meeting. Review plan forward. 06:30 - 13:00 6.50 FISH N STUC PROD1 Continue loading 3-1/2" PH6 work string into pipe shed. Drift and strap work string. Modify riser and bell nipple. 13:00 - 15:30 2.50 FISH N STUC PROD1 Hoist Kelly Swivel onto rig floor. 15:30 -16:00 0.50 FISH N STUC PROD1 PJSM. Review plan forward, roles and responsibilities. 16:00 - 19:00 3.00 FISH N STUC PROD1 Remove CTD Lubricator, install riser. 19:00 - 00:00 5.00 FISH N STUC PROD1 Continue to NU riser. Load rotary fishing tools in pipe shed. Continue to RU rotary swivel. PU kelly hose. RU DP tongs, Remove and modify riser. Stab kelly into kelly bushing. RU kelly shuck and rat hole. 7/5/2003 00:00 - 05:45 5.75 FISH N STUC PROD1 Re-install riser. Make up kelly cock to swivel and kelly. RU counter weights for pipe tongs, Install couplings on kelly hose. 05:45 - 06: 15 0.50 FISH N STUC PROD1 Tech limits meeting, review plan forward, action items, HSE and LL'd. 06:15 -15:00 8.75 FISH N STUC PROD1 Raise Kelly hose up to standpipe elbow. Unable to MU graloc fittings from kelly hose to Standpipe. A hydraulic ram used for raising windwalls and platform in derrick impedes the connection. Cuss and discuss. Loosen clamps on standpipe to enable it to rotate elbow at the top of the standpipe. Wrestle with kelly hose to get it into the correct position. MU Kelly hose to Kelly swivel. 15:00 - 16:30 1.50 FISH N STUC PROD1 MU 2" circulating hose. 16:30 - 20:00 3.50 FISH N STUC PROD1 RU to pressure test kelly hose, kelly cock valve, 2" circulating hose, standpipe manifold. Find 4" Standpipe valve in poor condition. Rebuild 4" standpipe valve. Inspect remainder of valves on standpipe. 20:00 - 20:20 0.33 FISH N STUC PROD1 PJSM pressure testing of the kelly hose. 20:20 - 23:00 2.67 FISH N STUC PROD1 Pressure test kelly hose. Swivel packing failed to test 1500 psi. Repair swivel packing. No Test. Rebuild swivel packing missin split ring to complete rebuild. Will retest swivel after picking up DP. PU bails. 23:00 - 00:00 1.00 FISH N STUC PROD1 PU handling tools for washpipe. 7/6/2003 00:00 - 00:30 0.50 FISH N STUC PROD1 Continue to RU floor. 00:30 - 00:45 0.25 FISH N STUC PROD1 PJSM for picking up BHA and PH-6 workstring. 00:45 - 02:30 1.75 FISH N STUC PROD1 PU BHA #21 (Washover assembly): 4-1/8" burning shoe, 2 jts 4" Washpipe, WO basket, Bumper sub, Jars, 6x Spiral drill collars, Accelerator. 02:30 - 06:00 3.50 FISH N STUC PROD1 PU 70 joints of 3.5" PH-6, 12.95#, P11 0 tubing. MU torque 7000 ft-Ibs. 06:00 - 06:20 0.33 FISH N STUC PROD1 Tech Limits. Discuss plan forward, roles and HSE. 06:20 - 11 :00 4.67 FISH N STUC PROD1 PU 130 joints 3.5" PH6 work string. 11 :00 - 11: 15 0.25 FISH N STUC PROD1 PJSM. 11: 15 - 14:45 3.50 FISH N RREP PROD1 Install new packing & split ring in kelly swivel. Pressure test. Failed test. PU=75Klbs Printed: 7/22/2003 8:50:30 AM ( ,( BP Operations Summary Report Page 14 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M PC-26 MPC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12/29/1995 End: 7/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/6/2003 11 :15 - 14:45 3.50 FISH N RREP PROD1 SO=65Klbs At 70Klbs, Rotating torque = 2000Ft-lbs (180Amps) 14:45 - 15:00 0.25 FISH N RREP PROD1 PJSM. Review revised plan forward. Keep rig floor clear of non-essential personnel. 15:00 - 16:00 1.00 FISH N RREP PROD1 PT upper kelly cock valve. Record on chart. Install line on kelly shuck to rack back kelly. 16:00 - 20:00 4.00 FISH N RREP PROD1 Replace wash pipe and packing in kelly swivel. 20:00 - 20:30 0.50 FISH N STUC PROD1 Attempt to stand back kelly. With new kelly and new roller in kelly bushing having trouble setting it in kelly shuck. Loosen roller. Still having troubles but they will get it figured out. 20:30 - 22:00 1.50 FISH N STUC PROD1 UP wt 70K, DN wt 60K, ROT wt 67K @ 180 amp = 2000 ft-Ibs. PU 6 joints PH-6 via mouse hole. Dry tag top of liner at 6725 DPM. Corrolation within 2' of CTM. Rotate off liner top. Tag top off fill at 6735'. 22:00 - 23:30 1.50 FISH N STUC PROD1 PU above liner top and circulate bottom up at 7 bpm 1870 psi. Wash kelly down ( 5' above fish) circulate bottoms up. 23:30 - 00:00 0.50 FISH N STUC PROD1 Make connection wash and rotate kelly down. Circulate bottoms up. 7/7/2003 00:00 - 02:30 2.50 FISH N STUC PROD1 Continue to wash 7 bpm 1850 -2200 psi circulating bottoms up prior to each connection. Wash and rotate over fish to 6810'. 02:30 - 03:30 1.00 FISH N STUC PROD1 Pump 15 bbllow vis and 25 bbl high vis sweeps at 7 bpm. Surface to surface. Cuttings came back continuously while circulating bottoms up. Significantly more cuttings than what was returned with CT at 3-3.5bpm a few days ago. Returns cleaned up nicely. 03:30 - 03:45 0.25 FISH N STUC PROD1 Pull three joints, and position fishing assembly above the 5" liner in the 7" casing. 03:45 - 04:45 1.00 FISH N STUC PROD1 Wait for solids to settle, moving pipe. 04:45 - 05:00 0.25 FISH N STUC PROD1 RIH dry tag fill at 6810. No indication of fall back. Still struggling with racking back kelly into kelly shuck. 05:00 - 12:00 7.00 FISH N STUC PROD1 POH standing back work string (doubles). 12:00 - 14:00 2.00 FISH N STUC PROD1 LD BHA #21. 6 drill collars and remainder of BHA. Gallon of debris (metal pieces + pebbly shale) found in boot basket. Burning shoe had wear on the leading edge of cutright, likely due to metal wear. PU BHA#22, overshot assembly. 14:00 - 20:00 6.00 FISH N STUC PROD1 PU 104 stands PH6. 20:00 - 20:50 0.83 FISH N STUC PROD1 Up wt 75K, DN wt 65K, ROT wt 70K, 2000 ft-Ibs. 590 psi at 1.7 bpm, Latch up 6749. Pull 105. NO GO. Jarred at 100K 4 licks and pulled fish free. Circulate 640 psi at .45 bpm. 20:50 - 21:15 0.42 FISH N STUC PROD1 Stand back kelly. Pull two stands. 21: 15 - 21:45 0.50 FISH N STUC PROD1 Monitor well. 21:45 - 00:00 2.25 FISH N STUC PROD1 POH standing back 67 stands of PH-6 tubing. 7/8/2003 00:00 - 02:30 2.50 FISH N STUC PROD1 Continue to POH to BHA standing back work string. LD BHA #22, accelerators, Stand back collars, LD jars. 02:30 - 03:30 1.00 FISH N STUC PROD1 Recovered fish to disconnect. Fish longer than anticipated. We had stopped washing about 18" above disconnect. Shoe had worn thru wall of coil tubing about 60 degrees of the circumference. End of coil full of 3/4" minus gravel. . RU hydraulic cutter and cut coil fish. Recovered a total of 7 gallons of gravel from coil fish. Going to have to washover top of second half of fish. 03:30 - 04:00 0.50 FISH N STUC PROD1 Clean up floor. Fish pulled wet. Printed: 7/22/2003 8:50:30 AM ( ~.. BP Operations Summary Report Page 15 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-26 MPC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12/29/1995 End: 7/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/8/2003 04:00 - 04:30 0.50 FISH N STUC PROD1 Wait on arrival of washover-shoe. 04:30 - 06:00 1.50 FISH N STUC PROD1 PU BHA #23, washover shoe w/ cutright and 2 joint of 4" washpipe. 06:00 - 08:00 2.00 FISH N STUC PROD1 PU 66stands of PH6 and RIH. 08:00 - 10:00 2.00 FISH N RREP PROD1 Repair tongs, pin sheared. 10:00 - 11 :30 1.50 FISH N STUC PROD1 PU 38stands of PH6. 208joints total. 11:30 -12:00 0.50 FISH N STUC PROD1 PU kelly break circulation. 12:00 - 14:00 2.00 FISH N STUC PROD1 Tagged fill at 6811' unable to circulate down, started rotation. Washed to 6834' at 7bpm 60-70 rpms no torque. (May have been able to not rotate this section after first couple of feet but not tried.) No cuttings seen at surface. PU and RIH tagged TOF at 6819'. Pumped hi-vis sweep - no increase in cuttings seen. Make connection and washed down w/o rotation @ 7 bpm to 6866', 8' from bit depth to possibly prevent fish from falling further downhole. Pumped low/high vis sweeps - no increase in cuttings to surface. 14:00 - 19:30 5.50 FISH N STUC PROD1 TOH wet to BHA. (Give AOGCC 24hr notice of pending BOPE test) 19:30 - 20:15 0.75 FISH N STUC PROD1 LID washover BHA. Recover 2gal 50/50 shale-metal cuttings from bootbasket. 20:15 - 20:30 0.25 FISH N STUC PROD1 Clean rig floor. 20:30 - 20:45 0.25 FISH N STUC PROD1 PJSM review next BHA and TIH procedures. 20:45 - 21 :40 0.92 FISH N STUC PROD1 PU BHA #24, overshot assembly. 21 :40 - 00:00 2.33 FISH N STUC PROD1 TIH w/ 210 jts 31/2" workstring to 6788'. 7/9/2003 00:00 - 01 :30 1.50 FISH N STUC PROD1 PU kelly break circulation. Wash down with grabble BHA to expected TOF at 6819'. Continue to wash kelly down to 6830'- no fish. PU singles continue to wash down to 6944' before bottoming out with the 4.75" OD x-over within this BHA, on top of 5" liner. 01 :30 - 02:30 1.00 FISH N STUC PROD1 Circulate at 6 bpm. No cuttings/shale to surface. Review options with town engineer. Presently believe fish is laying free below the window. DLS below window range from 32-50 deg. Decide to swap to coil with: GS spear, CircSub, Disconnect, up/dwn Jars, PH-6, Chk, CTC 02:30 - 03: 1 0 0.67 FISH N STUC PROD1 Blowdown and standback kelly. 03:10 - 03:45 0.58 FISH N STUC PROD1 PJSM. Review problems with standing back kelly. Identify problems with some equipment in use. Discuss plan forward and review I/d procedures for 3 1/2" PH-6. 03:45 - 04:45 1.00 FISH N STUC PROD1 LID 31 jts of PH-6 to make room for working with injector. 04:45 - 06:00 1.25 FISH N STUC PROD1 TOH stand back remaining 3 1/2" on off driller's side. 06:00 - 06:30 0.50 FISH N STUC PROD1 Crew change safety meeting. 06:30 - 10:30 4.00 FISH N STUC PROD1 Finish standing back 3-1/2" PH-6. 10:30 - 11 :30 1.00 FISH N STUC PROD1 LD overshot BHA. Clean/clear floor. 11 :30 - 14:30 3.00 FISH N STUC PROD1 SD operations for roundtable discussion with peer review team. 14:30 - 17:00 2.50 FISH N STUC PROD1 ND flow riser. NU lubricator. 17:00 - 18:00 1.00 FISH N RREP PROD1 Replace wear roller bar for winch line. Still need to replace wickered rope and make guard for drum. 18:00-18:15 0.25 FISH N STUC PROD1 Crew change / TL meetings 18:15 -18:50 0.58 FISH N STUC PROD1 MU BHA #25 GS spear on coil 49.95' 18:50 - 19:50 1.00 FISH N STUC PROD1 P/U injector. Circulate 1 coil volume. Stab injector. 19:50 - 21 :40 1.83 FISH N STUC PROD1 RIH 1.18bpm 2100 psi. Make -9' correction to flag 6400'. 1.8bpm 3350 psi. Tagged TOL @ 6923' no correction made 23k pu, pu @ 7050' 24k tagged fish @ 7081' pushed to 7093' Printed: 7/22/2003 8:50:30 AM { ~: BP Operations Summary Report Page 16 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-26 MPC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12/29/1995 End: 7/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/9/2003 19:50 - 21 :40 1.83 FISH N STUC PROD1 with diminishing weight. P/U wo pump 27k. 21 :40 - 23:00 1.33 FISH N STUC PROD1 TOH to above TOL to 6648'. RIH bumped at 6667' which would be TOL with fish (55') on GS. RIH to original tag of TOL 6723' didn't see much of weight drop as before. Looks good for having fish. Line up to fill on back side and TOH. Hold PJSM review plans for handling BHA and fish. 23:00 - 23:50 0.83 FISH N STUC PROD1 Setback injector. PU BHA and secure fish. Mousehole fishing BHA and LD same. LD fish. 23:50 - 00:00 0.17 BOPSURN STUC PROD1 Prep to test BOPE. Witnessing wavied by AOGCC rep. John Crisp 7/10/2003 00:00 - 00:10 0.17 BOPSUR N STUC PROD1 PJSM review BOP test procedures. 00:10 - 06:30 6.33 BOPSUR N STUC PROD1 Testing BOPE 250 psi low 3500 psi high. Unable to test against 7" master valve. Remove lubricator from stack and set 7" test plug. Resume test. Pull test plug; install lubricator. 06:30 - 09:30 3.00 STKOH N DPRB PROD1 RU N2 unit, safety meeting, blowdown reel with N2. 09:30 - 09:45 0.25 STKOH N DPRB PROD1 Safety meeting -- unstab coil. 09:45 - 11 :00 1.25 STKOH N DPRB PROD1 Unstab coil and secure to reel. 11 :00 - 14:30 3.50 STKOH N DPRB PROD1 Swap reels to E-coil. Slip and cut drill line. 14:30 - 17:00 2.50 STKOH N DPRB PROD1 Stab E-coil. Install CTC. Pull test. 17:00 - 18:15 1.25 STKOH N DPRB PROD1 Rehead E-line to upper quick connect. 18:15 - 19:50 1.58 STKOH N HMAN PROD1 MU lower blind (used to PT CTC) to quick connect. Gauled threads on lower blind and upper quick connect. MU 2nd set with same results. Identify problem with miss cut threads on lower blind. 19:50 - 20:40 0.83 STKOH N HMAN PROD1 Fill coil with mud and while waiting for XO from Baker needed for PT of CTC. 20:40-21:10 0.50 STKOH N DPRB PROD1 PT CTC to 3500 psi. OK 21:10 - 22:40 1.50 STKOH N DPRB PROD1 PU BHA #26 22:40 - 22:50 0.17 STKOH N DPRB PROD1 RIH to 700' tools appear to have shorted out. 22:50 - 23:00 0.17 STKOH N DPRB PROD1 TOH 23:00 - 23:30 0.50 STKOH N DPRB PROD1 Change out BHI flow sub. 23:30 - 00:00 0.50 STKOH N DPRB PROD1 RIH comms looks good. 7/11/2003 00:00 - 01 :00 1.00 STKOH N DPRB PROD1 Continue RIH to tie-in point 6740'. 01 :00 - 01:45 0.75 STKOH N DPRB PROD1 Log tie-in -15' correction. 01 :45 - 02:00 0.25 STKOH N DPRB PROD1 RIH to 7130' 02:00 - 03:30 1.50 STKOH N DPRB PROD1 Start OHST at 7130' free-spin @ 2.60 bpm 3200 psi. Trough at 30'/hrw/180 TF. Start mud swap. Trough to 7145' at this rate twice. Continue at 40'/hr to 7154'. Pressures with new mud: 2.58bpm 3710psi FS 03:30 - 04:25 0.92 STKOH N DFAL PROD1 MWD computer problems. Wiper trip back up. Looks like the Power/Comms section of BHA is not responding to surface computer. 04:25 - 05: 15 0.83 STKOH N DFAL PROD1 TOH paint EOP flag at 6200'. 05: 15 - 06:00 0.75 STKOH N DFAL PROD1 Change out Power/Comms sub. 06:00 - 06:30 0.50 STKOH N DFAL PROD1 Safety and tech limit meeting. 06:30 - 07:00 0.50 STKOH N DFAL PROD1 Finish C/O BHA. Bit ball'd with dark clay and lots of metal. 07:00 - 09: 15 2.25 STKOH N DFAL PROD1 RIH with BHA #27. Shallow hole test -- lost communication to tools. POOH. Must have been some surface computer glitch, tools OK. RIH. Correct depth at flag (-16'). RIH. 09:15-10:00 0.75 STKOH N DFAL PROD1 Log tie-in at 6735' GR spike. Correct a bunch more (-9') -- ?? RIH and tag TD 7146'. 10:00 - 10:30 0.50 STKOH N DPRB PROD1 Start drilling 7146' with 2.6/3450 FS and 3855 psi AP. Drill to 7175' at about 80 - 100 FPH, bringing TF up to 30L. Near bit Printed: 7/22/2003 8:50:30 AM ( BP Operations Summary Report Page 17 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-26 M PC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12/29/1995 End: 7/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations I 7/11/2003 10:00 - 10:30 0.50 STKOH N DPRB PROD1 inclinometer shows well is sidetracked at 7125' (based on today's "corrected" depths). Apparently the troughing we did two weeks ago was enough to sidetrack the well. Unfortunately, this means we sidetracked at a lower inclination and also drilled too far at the LS TF. So, we are not going to land in our ìVD window 6970' - 6980'. Even with a motor change to get to a DLS of 45 ish, landing depth will put us in the vicinity of 6985' - 6990'. 10:30 - 12:00 1.50 STKOH N DPRB PROD1 POOH to increase motor bend. 12:00 - 13:00 1.00 STKOH N DPRB PROD1 Increase motor bend to 3.6. Bit ball'd again, but obviously not affecting ROP. 13:00 - 14:30 1.50 STKOH N DPRB PROD1 RIH. Correct depth at 6500' EOP flag (-28') 14:30 -15:15 0.75 STKOH N DPRB PROD1 Log tie-in. Correct depth (+3'). RIH and log RA. Corrected RA depth at 6977' (withing one foot of expected). RIH. Tag and work past junction 7132' with 150R TF. RIH and tag TD 7177'. 15:15 -17:30 2.25 STKOH N DPRB PROD1 Drilling about 150 - 200 FPH. Adding DrilZone into mud to reduce bit balling tendency. Into A3 sand at about 7180'. Planned fault at 7320' kicked us to the right and gave us a 64 deg DL. Drill to 7400'. 17:30 - 20:10 2.67 STKOH N DPRB PROD1 Wiper to window. Open circ sub. POOH for planned motor bend change and to install resistivity. Circulate at 3.3 BPM; 4025 psi CTP to surface (requires 3 gensets). 20:10 - 21 :30 1.33 STKOH N DPRB PROD1 Change motor setting from 3.6 to 1.3 deg and change out lower quick disconnect. Unable to PU resistivity tool because of software incompatability with present Power/Comms unit's software. Not able to download updated software. We tryed this early this morning and knocked out the PIC unit that was downhole at the time. (we tripped to change out the PIC) 21 :30 - 21 :50 0.33 STKOH N DPRB PROD1 RIH with BHA #29. Short in tools. 21 :50 - 22:15 0.42 STKOH N DFAL PROD1 TOH 22:15 - 00:00 1.75 STKOH N DFAL PROD1 Diagnose short problem. Narrowed down the problem to the Power/Comms section of the BHA. Among other things the PIC unit converts input voltage of 400v to a 33v bus for other system operations. The problem with the PIC is in the high voltage section. It is not making the stepdown to the lower voltage. Tested all surface systems and other BHA componets without findings problems. Have been on the phone with Celie techs in Germany for the past couple hours. Discussion has centered around procedures for downloading softwear to accept the USR (new name for res. tool). We have successfully made the download so will PU the PIC that was laid down this morning. Chances are fair that repairs can be made to the stepdown transformer in the other PIC. 7/12/2003 00:00 - 01 :30 1.50 STKOH N DFAL PROD1 Swap out Power/Comms unit and PU USR tool. 01 :30 - 02:45 1.25 STKOH N DFAL PROD1 RIH 02:45 - 03:45 1.00 STKOH N DPRB PROD1 Log tie-in -13' correction. 03:45 - 03:50 0.08 STKOH N DPRB PROD1 RIH problems getting past 7136' orient around without success. Point it 180 deg drill through bridge continue RIH to bottom tagged at 7409'. 03:50 - 04:30 0.67 STKOH N DPRB PROD1 Directionally drill ahead fl 7409' 9.8 I 9.9 free-spin 3200 psi at 2.47 bpm, 9.5k wob, 160'/hr, 300-450psi MW. Increase rate to Printed: 7/22/2003 8:50:30 AM ( ( BP Operations Summary Report Page 18 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-26 M PC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12/29/1995 End: 7/19/2003 Date From - To 'Hours Task Code NPT Phase Description of Operations 7/12/2003 03:50 - 04:30 0.67 STKOH N DPRB PROD1 2.68bpm 3420 psi FS Drilled to 7524'. 04:30 - 04:50 0.33 DRILL P PROD1 Back on productive time. Drilled f/7500' to 7524'. 04:50 - 06:00 1.17 DRILL P PROD1 Wiper trip to top of 5" liner. SD pump and open circ sub at window. Increase pump rate to 3.8 bpm 4200 psi to TOL. RIH. 06:00 - 07:00 1.00 DRILL P PROD1 Make resistvity MAD pass 7150' -7400'. 07:00 - 08: 15 1.25 DRILL P PROD1 Drill to 7675' at 150 - 200 FPH. 08:15 - 09:15 1.00 DRILL P PROD1 Wiper to window, orienting to 130L to "widen" junction. RIH. Tag and stall 7137'. Skip through. RIH to TD. 09: 15 - 11 :30 2.25 DRILL P PROD1 Continue drilling at 91 - 92 deg. GR wrapping and resistivity getting depressed starting at about 7700'. Don't know if the sand we've drilled is A3 or A2 so don't know if we've punch up through the A3 or down through the A2. Will rely on the seismic interpretation which suggests that for now, the dip is going up and away from us greater than the 1 - 2 deg climb we've been on. So, based on this interpretation, need to nose it up further to get back up into the A2. Increase inclination to 98 deg. Drill to 7830'. 11 :30 - 12:30 1.00 DRILL P PROD1 Wiper to window 3.0/3850. 10k overpull wlo MW at 7200' (seen this before here). Orient to 70L backreaming thru junction. RIH. Tougher getting past junction at 7137'. Tag several times. Adjust TF from 120R-180. Finally dropped in. RIH to TD, some ratty stacking wlo MW in the silty stuff near bottom. 12:30 - 14:00 1.50 DRILL P PROD1 Continue drilling something other than A3/A2 to 7916'. Very good ROP but no signs of the A3 or A2 sands. Suspect now that these sands are below us. Discuss with asset. Will do another open hole sidetrack. 14:00 - 15:00 1.00 DRILL N DPRB PROD1 Wiper to window. Backream junction again slowly and a different TF. RIH. Clean through junction. Repeat. Clean. 15:00 - 18:25 3.42 STKOH N DPRB PROD1 Perform OH sidetrack at 180 TF. 2 hours: Trough down 7485' -7500' @ 15 FPH (2x) 1 hour: Time drill 7500' - 7503' @ 3 FPH (1/10' every 2 min) 1 hour: Time drill 7503' - 7506' @ 6 FPH (1/10' every 1 min). 18:25 - 20:10 1.75 DRILL N DPRB PROD1 Directionally drill ahead with OHST #4 from 7506' to 7632'. 20: 1 0 - 22:30 2.33 DRILL N DPRB PROD1 Wiper trip to window at 3.0bpm. Open circ-sub. Pump at 3.92bpm 4340psi pull up to 6500' while pumping 25bbl ex. hi-vis pill. RIH to 6970' then back up to 6500'. Good cuttings returns across shaker and centrifuges. Close ECD at the window reduce rate to 2.9 bpm RIH to bottom. No problems at 7137'. 22:30 - 00:00 1.50 DRILL N DPRB PROD1 Directionally drill ahead f/7632'. 2.9bpm 3500 free-spin 500psi motorwork. 120-140'/hr 4.5k wob 9.92in 19.97 out 10.71 ecd drilled to 7800'. 7/13/2003 00:00 - 01 :00 1.00 DRILL N DPRB PROD1 Wiper trip to window. Some trouble back in at 7137'. Oriented around to 180 and went through okay. 01 :00 - 02:45 1.75 DRILL N DPRB PROD1 Directionally drill ahead f/7800'. 3550 psi FS at 2.9bpm 400-500 mw. 9.92/10.0 5k wob 100'-120'/hr Drilled to 7938'. Starting to loose 3-4 bph mud. 02:45 - 04:30 1.75 DRILL P PROD1 Wiper trip to window. Pump a 25 bbl xtra hi-vis pill. Open EDC at window increase rate to 4bpm pull to top of 5" liner. Doing some good. Lots of clay and sand over shakers. 04:30 - 06:00 1.50 DRILL P PROD1 Directionally drill ahead f/7938'. 3640pdi fs at 2.9 bpm 400psi mw 9.9/10.0 holding 83deg TF 120'/hr. Drill to 8097'. Printed: 7/22/2003 8:50:30 AM ( ( BP Operations Summary Report Page 19 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-26 MPC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12129/1995 End: 7/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/13/2003 06:00 - 07:30 1.50 DRILL P PROD1 Wiper to window. Log tie-in. Correct depth (+11'). RIH. Tag with motor work 7137'. Repeat tag. Then fell through. RIH. Ratty hole conditions 7990'. RIH and tag TD 8104'. RIH wt at TD = 3k. 07:30 - 08:30 1.00 DRILL P PROD1 Drill 2.9/3750 to 8263' 08:30 - 10:00 1.50 DRILL P PROD1 Wiper to window. Sat down in 7137' junction several times before falling through at 180 TF. RIH. Sat down at 7745' and ratty at 8000' again. 10:00 - 11 :30 1.50 DRILL P PROD1 Drill to 8317' with negative weight but good slide and 130 FPH. Stack out at this depth, PUH, orient from high left to 90L, then can't get a bite and DWOB suggests no weight to bottom. Struggle with slide to 8358'. 11:30 -14:15 2.75 DRILL P PROD1 Wiper to window. Open circ sub. PUH to 6650'. Circulate 30 bbl of 150k - 200k LSRV pill and chase to surface at 4.0/4500. Not a lot of additional cuttings. RIH. Junctions good. 14:15 - 17:00 2.75 DRILL P PROD1 Drill. Slide is better. Drill 120 FPH and -5k to 8418'. Lost MW and WOB here. Fight it for about 20 minutes to get an inch, then ROP back to 130 FPH. Swap to new mud. Drill to 8538'. Looks like we're getting back into the B siltstone. 17:00 - 19:30 2.50 DRILL P PROD1 Wiper to window. Log tie-in. Correct depth (+5'). 19:30 - 19:40 0.17 DRILL P PROD1 Drill additional 2' to 8545' TD. 19:40 - 23:00 3.33 DRILL P PROD1 Wiper trip back to window. Open EDC and increase pump rate to 3.75 bpm 4150psi. Paint EOP flag at 5300'. TOH for liner. 23:00 - 00:00 1.00 DRILL P PROD1 LID BHA #30 7/14/2003 00:00 - 00: 15 0.25 CASE P COMP PJSM review procedures and hazards for PU of liner. 00:15 - 01 :00 0.75 CASE P COMP Rig up floor for running liner. 01 :00 - 02:10 1.17 CASE P COMP P/U 2 7/8" x 3 3/16" liner, 4" Deployment sleeve wI GS profile and BHI gr tools. 02:10 - 02:15 0.08 CASE P COMP Hold "kick while tripping" drill. 1 :45 min plu stab safety joint. 02: 15 - 03:30 1.25 CASE P COMP Continue running liner. 03:30 - 04:15 0.75 CASE P COMP MU Baker GS spear and BHi Gamma tools. P/U injector. Surface t4est BHi tools. 04: 15 - 06:30 2.25 CASE P COMP RIH with liner to flag. Correct -20'. P/U wt 30k RIH through window ok at 50'/min tagged at 7137'. PU 1 time went through. RIH tag at 7737',7747,8050,8339', pu 47k, 8349', 8410', 8426' plu 46k, 8442', etc. Slow going last 100'. Tag 8540'. Repeat twice -- same depth. 06:30 - 06:45 0.25 CASE P COMP Circulate and PUH. Off liner (27k up). PUH to tie-in point 06:45 - 07:00 0.25 CASE P COMP Log tie-in at 6735' GR marker. Correct depth (-2'). 07:00 - 10:00 3.00 CASE P COMP RIH with pumps and tag liner top. Bottom of liner at 8538' corrected depth, which puts liner top at 6979' corrected depth (corrected RA = 6977' which is worst case bottom of window; so liner top is 2' out). RIH wlo pumps to latch and confirm we've been tagging the TOL. Latch. PUH 48k. Have liner. RIH and attempt to work liner deeper -- not an inch. Unlatch. PUH and re-Iog tie-in. Correct depth (+1'). RIH and tag liner top at same depth. Wash whipstock face at 2.7; 3700 (several passes). POOH. 10:00 -10:30 0.50 CASE P COMP LD liner running equip. 10:30 - 12:00 1.50 EVAL P COMP Call for memory logging tools. 12:00 - 12:20 0.33 EVAL P COMP Safety meeting. 12:20 - 13:15 0.92 EVAL P COMP MU SLB GR/CCL in carrier, MU 5 jts CSH, MU E-line BHA. 13:15 - 16:15 3.00 EVAL P COMP RIH. Correct depth at flag (-17'). Log down 60 FPM from 6700' Printed: 7/22/2003 8:50:30 AM ~ ( BP Operations Summary Report Page 20 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M PC-26 MPC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12/29/1995 End: 7/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/14/2003 13:15 - 16:15 3.00 EVAL P COMP - 7135'. Very smooth; no set downs. Log up at 60 FPM. POOH. LD logging tools. 16:15-17:00 0.75 EVAL P COMP Safety meeting. LD logging tools. 17:00 - 17:30 0.50 CLEAN P COMP MU nozzle (with side jets) on E-BHA. 17:30 - 18:45 1.25 CLEAN P COMP RIH. 18:45 - 19:00 0.25 CLEAN P COMP Log tie-in at 6735'. -15' correction. 19:00 - 21 :20 2.33 CLEAN P COMP RIH to 6970' and wash to 6980' numerous times. Pull up to 5" liner top circulate and displace 9.9ppg Flo-pro mud with 9.3 brine at 3.6bpm. 21 :20 - 22:30 1.17 CLEAN P COMP TOH check rates at 800' getting 1:1 returns. 22:30 - 23:00 0.50 CLEAN P COMP LID BHA #33 23:00 - 23:30 0.50 CLEAN P COMP PJSM review next BHA make-up. Unload Weatherford whipstock fishing tools. 23:30 - 00:00 0.50 CLEAN P COMP Mu BHA #34 Scribe retrieval hook as highside to BHi orienter. 7/15/2003 00:00 - 01 :20 1.33 RUNCOI\IP COMP RIH wI whipstock retrieval tools to 6750'. 01 :20 - 01 :55 0.58 RUNCOI\IP COMP Log tie-in. -26' correction. 01 :55 - 05:35 3.67 RUNCOI\IP COMP RIH and orient hook to 53R parallel to WS face and wash WS slot. Check plu 27.3k Wash down and tag at 6968.5' orient around to 30R and work past to 6976'. Orient around to 127L that should put hook directly on WS face. Work area f/6965' - 6978' (top of slot should be at 6970', bottom at 6971.37') in 5 deg increments to 155 deg. Come back around to 120L and work 5 deg inc to 90L. Tried different TF in the 1 0-70R area without success. 05:35 - 06:30 0.92 RUNCOI\IP COMP TOH 06:30 - 07:30 1.00 RUNCOI\IP COMP LD BHA. Tools looked just like they went in. 07:30 - 08:30 1.00 RUNCOI\IP COMP Fill coil with fresh water. 08:30 - 09:00 0.50 RUNCOI\IP COMP Set 7" BPV. 09:00 - 09:30 0.50 RUNCOI\IP COMP Safety meeting. Unstab pipe and ND BOPE. 09:30 - 09:45 0.25 RUNCOI\IP COMP Pressure under BPV to 150 psi. No leak up through BPV. 09:45 - 13:00 3.25 BOPSUR P COMP Nipple down 7" BOP stack, 7" master valve. 13:00 - 21:30 8.50 BOPSUR P COMP NU 13 5/8" BOP stack. 21 :30 - 21:45 0.25 BOPSUR P COMP Remove BPV. 21 :45 - 00:00 2.25 BOPSUR P COMP Test 135/8" BOPE. Witnessing wavied by AOGCC rep. Jeff Jones. 7/16/2003 00:00 - 03:00 3.00 BOPSUR P COMP Continue testing BOPE 03:00 - 03:15 0.25 CLEAN P COMP PJSM review plan foward and next BHA P/U. 03: 15 - 03:45 0.50 CLEAN P COMP Clear floor. LID WE fishing tools from whipstock retrieval. 03:45 - 04:30 0.75 CLEAN P COMP Make-up BHA for drifting and cleanout of 7" casing. 04:30 - 04:45 0.25 CLEAN P COMP PJSM for RIH with 3 1/2" PH-6 string. 04:45 - 09:35 4.83 CLEAN P COMP RIH with BHA #34. Tag up on 5" liner top at 6725'. 09:35 - 10:30 0.92 CLEAN P COMP Circulate well. Some debris noted in returns, which cleaned up. 10:30 - 13:00 2.50 CLEAN P COMP MU and break down kelly to prep for rig move. 13:00 - 19:00 6.00 CLEAN P COMP POOH and lay down drill pipe. 19:00 - 19:20 0.33 RUNCOI\IP COMP PJSM to lId kelly. 19:20 - 22:00 2.67 RUNCOI\IP COMP Lay down kelly and components. Clear floor of tools. 22:00 - 22: 15 0.25 RUNCOI\IP COMP PJSM review plan for loading pipe shed. 22: 15 - 00:00 1.75 RUNCOI\IP COMP Load 3 1/2" completion string in pipe shed. Pull 11 " false bowl. 7/17/2003 00:00 - 08:00 8.00 RUNCOI\IP COMP Continue loading pipe shed with 3 1/2" completion string drift and strap. R/U tools to run tubing. 08:00 - 16:30 8.50 RUNCOI\IP COMP RIH with 3-1/2" IBT-M completion. Tag up top of liner tie back sleeve at 6727', rotate 1/4 turn and drop into tieback sleeve 7' Printed: 7/22/2003 8:50:30 AM ( ~ BP Operations Summary Report Page 21 of 21 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-26 MPC-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/15/2003 Rig Release: 7/19/2003 Rig Number: N2 Spud Date: 12/29/1995 End: 7/19/2003 Date From - To Hours Task Code NPT Phase Description of Operations 7/17/2003 08:00 - 16:30 8.50 RUNCOrvP COMP and tag. P/U and lid 1 full jt of tbg. 16:30 - 18:00 1.50 RUNCOrvP COMP Space out and mu tbg pups. 18:00 - 18:20 0.33 RUNCOrvP COMP Crew change TL and PJSM. Review plan forward. 18:20 - 19:00 0.67 RUNCOrvP COMP MU landing joint RIH and land tbg hanger. RIU to reverse corrosion inhibitor down annulus. 19:00 - 21 :30 2.50 RUNCOIVN RREP COMP Repair "frozen" 3" Demco valve in standpipe manifold needed to reverse.. Repair an adjacent leaking 3" Demco standpipe valve. 21 :30 - 00:00 2.50 RUNCOrvP COMP P/U and unsting from 5" liner. Reverse 1 annulus volume with 9.3ppg brine at 3bpm 355psi followed by 200 bbls corrosion inhibited 9.3ppg brine (25gal Corexit/100bbls). 7/18/2003 00:00 - 00:15 0.25 RUNCOrvP COMP PJSM review plan forward for setting and testing packer assembly. 00:15 - 00:45 0.50 RUNCOrvP COMP Drop 1-5/16" setting ball/rod. R/U to monitor test pressures. 00:45 - 03:45 3.00 RUNCOrvP COMP With ball on seat pressure up tubing set Baker S-3 packer and test tbg to 3500 psi for 30 min. Test good. Bleed down tbg to 1500 psi. Pressure up annulus to 3500 psi and hold for 30 min. Test good. Dump tbg pressure to shear RP valve. No good indication that it sheared. Re-pressure and try again but indications are that it did shear. Break circulation down tbg with returns from annulus with little to no back pressure. Again another good indication RP has sheared. 03:45 - 04:20 0.58 RUNCOrvP COMP LID landing joint and install TWC. Test under TWC to 1 OOOpsi 1 5 min. Good test. 04:20 - 06:00 1.67 WHSUR P COMP Drain stack. Nipple down 13 5/8" 5K bop stack by individual componets and remove from cellar. 06:00 - 06:30 0.50 WHSUR P COMP Hold TL & PJSM with day crew 06:30 - 10:00 3.50 WHSUR P COMP Continue to ND BOPs in to components. Place on BOP storage rack. 10:00 -10:15 0.25 WHSUR P COMP Hold PJSM with crew & FMC before NU THA and tree. 10:15-13:00 2.75 WHSUR P COMP NU THA and tree. Test THA to 5000 psi for 30 min. Test tree to 5000 psi. Good. 13:00 - 13:30 0.50 WHSUR P COMP Pull two way check valve. 13:30 - 15:00 1.50 WHSUR P COMP RU First energy. Hold PJSM with crews. Pump 90 bbls diesel down tbg annulus, take diesel rtns at surface. U-tube annulus to tbg. Well freeze protected to 2500'. Shut in annulus and secure tree. 15:00 - 17:00 2.00 WHSUR P COMP RU lubricator. Set BPV. Test same from below to 1000 psi. Bleed well to 100 psi. RD HB & R. 17:00 - 00:00 7.00 RIGD P POST Clean pits. Prep for rig move. 7/19/2003 00:00 - 03:00 3.00 RIGD P POST Continue RD operations. 03:00 - 0.00 RIGD P POST Rig Released at 0300hrs 7-19-2003 Move off MPC 26L 1. Lower 23/8" E-line reel to flatbed. Make final preparations for move to EOA DS 7-30 Printed: 7/22/2003 8:50:30 AM ) BP-GDB ) Baker Hughes INTEQ Survey Report Company: Field: Site: Well: Wellpath: BP Amoco Milne Point M PtC Pad MPG-26 MPC-26L1PB1 Date: 8/7/2003 Time: 16:20:44 Page: Co-ordinate(NE) Reference: Well: MPC-26, TrUe North Vertical (TVD) Reference: 47 : 26 617/1996 11 :4446.3 Section (VS) Reference: Well (0.00N;0.00E,2; 17Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Milne Point 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: Site: M pt C Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6027347.71 ft 558058.04 ft Latitude: 70 29 Longitude: 149 31 North Reference: Grid Convergence: lNi,[EQ Alaska, Zone 4 Well Centre bggm2003 7.200 N 31.821 W True 0.45 deg Well: MPC-26 Slot Name: 26 MPC-26 Well Position: . +N/-S 2019.80 ft Northing: 6029367.24 ft Latitude: 70 29 27.064 N +E/-W -1.26 ft Easting : 558041.02 ft Longitude: 149 31 31.858 W Position Uncertainty: 0.00 ft Wellpath: MPC-26L 1 PB1 500292263470 Current Datum: 47 : 26 6/7/1996 11 :44 Magnetic Data: 8/7/2003 Field Strength: 57541 nT Vertical Section: Depth From (TVD) ft 29.50 Height 46.30 ft Drilled From : Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 Survey Program for Definitive Wellpath Date: 8/7/2003 Validated: Yes Actual From To Survey ft ft 148.86 6926.59 6970.00 7640.00 Version: Toolcode 1 : MWD - Standard (148.86-7445.00) (0) MWD MWD (6970.00-7640.00) MWD Annotation MPC-26 6970.00 ft Mean Sea Level 25.25 deg 80.88 deg Direction deg 2.17 Tool Name MWD - Standard MWD - Standard 6970.00 6871.53 KOP 7640.00 6990.27 TD Survey: MWD Start Date: 6/22/2003 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path 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 6926.59 8.46 343.88 6828.59 6782.29 983.24 -420.34 6030347.08 557613.06 966.64 0.00 6970.00 8.56 345.27 6871.53 6825.23 989.44 -422.04 6030353.26 557611.31 972.77 0.53 7003.13 17.67 11.00 6903.78 6857.48 996.78 -421.71 6030360.60 557611.58 980.12 32.02 7037.08 31.38 18.00 6934.60 6888.30 1010.31 -417.98 6030374.16 557615.21 993.78 41.21 7069.62 42.80 25.13 6960.53 6914.23 1028.44 -410.64 6030392.35 557622.41 1012.18 37.45 7104.48 56.07 30.40 6983.16 6936.86 1051.75 -398.23 6030415.75 557634.63 1035.94 39.74 7136.55 70.66 34.62 6997.50 6951.20 1075.82 -382.81 6030439.93 557649.86 1060.57 46.98 7165.57 84.38 39.54 7003.76 6957.46 1098.34 -365.75 6030462.59 557666.74 1083.72 50.08 7196.10 93.25 49.74 7004.39 6958.09 1120.01 -344.35 6030484.42 557687.97 1106.18 44.24 7228.09 94.22 63.80 7002.30 6956.00 1137.46 -317.72 6030502.07 557714.47 1124.63 43.96 7259.80 91.93 77.16 7000.59 6954.29 1148.01 -287.94 6030512.86 557744.16 1136.30 42.68 7294.94 89.56 92.98 7000.13 6953.83 1151.02 -253.05 6030516.14 557779.02 1140.62 45.52 ) BP-GDB ) Baker Hughes INTEQ Survey Report Company: BP Amoco Field: Milne Point Site: M Pt C Pad Well: MPC-26 Wellpath: MPC-26L1 PB1 Date: 8/7/2003 Time: 16:20:44 Page: 2 Co-ordinate(NE) Reference: Well: MPC-26, True North Vertical (TVD) Reference: 47: 266/7/199611 :4446.3 Section (VS) Reference: Well (O.00N,O.00E,2.17 Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Survey 7339.09 93.60 98.25 6998.91 6952.61 1146.70 -209.15 6030512.17 557822.95 1137.97 15.03 7363.75 96.68 103.88 6996.70 6950.40 1141.99 -185.06 6030507.65 557847.07 1134.18 25.94 7395.61 100.28 112.31 6991.99 6945.69 1132.23 -155.13 6030498.11 557877.07 1125.55 28.50 7431.22 100.55 120.05 6985.55 6939.25 1116.79 -123.73 6030482.92 557908.59 1111.31 21.39 7454.16 98.09 122.86 6981.83 6935.53 1104.98 -104.42 6030471.26 557927.99 1100.24 16.16 7478.24 95.54 126.38 6978.97 6932.67 1091.40 -84.75 6030457.84 557947.76 1087.41 17.97 7515.69 91.05 130.95 6976.82 6930.52 1068.05 -55.58 6030434.72 557977.11 1065.18 17.09 7550.40 85.69 132.35 6977.81 6931.51 1045.00 -29.66 6030411.87 558003.21 1043.13 15.96 7585.13 81.12 130.59 6981.80 6935.50 1022.16 -3.82 6030389.24 558029.22 1021.28 14.09 7640.00 81.12 130.59 6990.27 6943.97 986.88 37.35 6030354.29 558070.66 987.59 0.00 BP Amoco Parent Wellpath: Tie on MD: WELLPATH DETAILS MPC·26L 1 500292263460 MPC-26L1PB3 7500.00 Rig: Ref. Datum: Nordic 2 47 : 26 6/7/1996 11:44 46.3Oft V.Section Origin Origin Angle +N/-S +E/-W 96.00° 0.00 0.00 Starting From TVD 29.50 REFERENCE INFORMATION Co-ordinate IN/E¡ Reference: Well Centre: MPC-26. True North Vertical (rVD Reference: System: Mean Sea Level Section (VS Reference: Slot - 26 (O.OON,O.OOE) Measured Depth Reference: 47: 266/7/199611:44 46.30 Calculation Method: Minimum Curvature ANNOTATIONS -El* SNo< TVO MO Annotatton "'P:-16A.P~1 0'" 9.a1~ -7Er973 """'" ~~~m\kF~..... 0'" 101162 ...1:2679 ~E·Œ~) 6825.23 6970.00 Window ..., '" 1Q..4306 -2188 1.I?::.2£A T62 69'5500 6.5973 14511 6988.55 7500.00 KOP U.;"':-26A. 164 11j10oo 67482 9((136 7018.32 8545.00 TO UP";·2E.A.T63 lœ5(( 62810 4189-1 6450 6500 6550 ?600 æ 6650 o II) ~700 .c .. Cß750 G.I Q 6800 ëã .~ 6850 1:: ~6900 26950 ... 7000 7050 7100 7150 bp B Jf&.. HE. LEGEND T ~~t~~.~p~;~ Vlan #6^ M MPC·26 (MPC-26L 1'61) ^ MPC-26 (MPC-26L 1 '62) i' MPC-26 (MPC-26L 1'63) ! MPC-26LI é 3:,'er H"gh~s :~~~:i~~;!;~~i~~t;q,'~m Wellpath: (MPC-26/MPC-26L 1) Azimuths to True North Magnetic North: 25.47" Magnetic Field Strength: 57516nT Dip Angle: 80.86° Date: 6/18/2003 Model: bggm2003 Created By: Brij Potnis Date: 817/2003 /Y\:>,. " ~t. ~<~;,<'~ Cf;n~act jr:fonTt3tior:~ INTEQ 1300---: . ...' ..... · . . .......... · · . . · .' · · , '.. .. ... ..... 1250~ J .. .............. . .................................. ...... ..... .. . . ...... ... ...... '. ./y . .. . · · · · . I¿UU · '/~ ./ · · .... ,........ h'----.", ..... ....... ... þ · · · 1150--- c.... ~ · --,-. ,.- . .. · . . ..................... I .,\77 :--- ~:: . . · . .... .. .. ......... . .. ... . ... .. .. ...... .. .... .. .. . '1 G/ [~\ ~.. · · '''m~ 00' .00<>' · ,,':-- ." 1 ........ · . · · · .......... 950~ , \ 'O~ .......m ... .~~ '\ · · , · · · · . ......... ~ '-... .. · · · , . · · · . · . . ... '..-,: ~ · 900~ \ ..m ····X ... .. -" . · · . · · · . . 850~ . .m . ..m.. . .. , .''', ~.. m .. ....m . ... ... . . . '.. 800-~ ...... '.. ..... \ ... ... .... ..... .. .'\ '~[~ ......... ... ...... · ... .. · .. . 7 50m~ ... .. 'm .. ..~ · ...... .... .. · ~v ... ......m.... ..... ....... . .. .. ........ . ... ..... .... .. · vv · \ · · ~ · . . · . . ... ... .... · · :......,-..... . · /< 650m~ ."m ........ . ..m ~-...-----~-- ?;c/ \ .m.... . ~------- .- . · · "---L.. . · · vvv \ · · ~ ·7'7 · .. ... m ........ .'.. .......... .'. · .... .' .......... ... .... ..... .... ClCIV \ · · MPC-26L 1 · · cæJ --- . · · · · · vVV · ' · · · · · · .. . · , . · · · · 'ClU · .. .... · V .. . .... ......... ...m.· .m. .. m... <. ... ....... ........ .......... .m. ..m ..' ....... ... .. .... .'. ........ .............. ... - , 50 '-4bo' -3 .. , . , · .. , . '¡ . . · . . , .' ... · I.!: ". : 7~;nmT -5 DO -4 50 -31 )0 -2 50 -2 )0 -1 50 -1' 00 -50 50 100 200 250 300 400 450 -~ ... :E' 1:: o ~ :E' .. ::I o (I) West(-)/East(+) [50ft/in] .'-'". 150 200 300 350 Vertical Section at 96.00' [50ft/in] 8/7/2003 J:19 PM BP-GDB ) Baker Hughes INTEQ Survey Report ø, '.¡ IS ""..." ,,,...,................,, IN'I',EQ Company: Field: Site: Well: Wellpath: BP·Amoco Milne Point M Pt C Pad MPC-26 MPC-26L 1 PB2 Date: 8/7/2003 Time: 16:22:42 Page: Co-ordinate(NE) Reference: Well: MPC~26, True North VertiCal (TVD) Reference: 47: 26 6/7/199611:4446.3 Section (VS) Reference: Well (0:QON,0;QOE,356.26Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Milne Point 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 bggm2003 Site: M pt C Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6027347.71 ft 558058.04 ft Latitude: 70 29 Longitude: 149 31 North Reference: Grid Convergence: 7.200 N 31.821 W True 0.45 deg Well: MPC-26 Slot Name: 26 MPC-26 Well Position: +N/-S 2019.80 ft Northing: 6029367.24 ft Latitude: 70 29 27.064 N +E/-W -1.26 ft Easting : 558041.02 ft Longitude: 149 31 31.858 W Position Uncertainty: 0.00 ft Wellpath: MPC-26L 1 PB2 500292263471 Current Datum: 47 : 26 6/7/1996 11:44 Magnetic Data: 8/7/2003 Field Strength: 57541 nT Vertical Section: Depth From (TVD) ft 29.50 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 MPC-26L 1 PB1 7205.00 ft Mean Sea Level 25.25 deg 80.88 deg Direction deg 356.26 Height 46.30 ft Survey Program for Definitive Wellpath Date: 8/7/2003 Validated: Yes Actual From To Survey ft ft 148.86 6926.59 6970.00 7196.10 7205.00 7490.00 Version: Toolcode Tool Name 1 : MWD - Standard (148.86-7445.00) (0) MWD MWD (6970.00-7640.00) (2) MWD MWD (7205.00-7490.00) MWD MWD - Standard MWD - Standard MWD - Standard Annotation MD ft 6970.00 7205.00 7490.00 TVD ft 6871.53 7003.86 7009.77 Window KOP TD Survey: MWD Start Date: 6/25/2003 Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard Engineer: Tied-to: From: Definitive Path BP-GDB ') r&,..' IS Baker Hughes INTEQ Survey Report lNTEQ Company: BP Amoco Date: 8/7/2003 Time: 16:22:42 Page: 2 Field: Milne Point Co-ordinate(NE) Reference: Well:MPC~26, True North Site: M PtC Pad VertiCal (TVD) Reference: 47 : 26 6/7/1996 11 :4446.3 Well: MPC-26 Settion(VS) Reference: Well (O.OON ,O;00E,356.26Azi) Wellpath: MPC-26L 1 PB2 Survey Calculation Method: Minimum Curvature Db: OraCle Survey MD loci Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 6970.00 8.56 345.27 6871.53 6825.23 989.44 -422.04 6030353.26 557611.31 1014.88 0.00 7196.10 93.25 49.74 7004.39 6958.09 1120.01 -344.35 6030484.42 557687.97 1140.10 39.60 7205.00 93.54 53.65 7003.86 6957.56 1125.51 -337.38 6030489.98 557694.90 1145.14 43.98 7224.59 93.69 50.44 7002.63 6956.33 1137.54 -321.96 6030502.12 557710.22 1156.13 16.37 7256.78 93.52 53.95 7000.60 6954.30 1157.22 -296.59 6030522.00 557735.44 1174.12 10.90 7287.78 92.46 57.82 6998.99 6952.69 1174.58 -270.96 6030539.56 557760.93 1189.77 12.93 7319.74 90.26 60.99 6998.23 6951.93 1190.84 -243.46 6030556.03 557788.29 1204.20 12.07 7350.67 90.53 65.56 6998.01 6951.71 1204.75 -215.84 6030570.15 557815.80 1216.27 14.80 7381.37 87.45 72.59 6998.56 6952.26 1215.70 -187.19 6030581.33 557844.36 1225.33 24.99 7413.08 84.02 81.73 7000.92 6954.62 1222.73 -156.40 6030588.59 557875.09 1230.33 30.71 7445.75 83.23 90.87 7004.55 6958.25 1224.82 -124.04 6030590.94 557907.44 1230.31 27.91 7490.00 83.23 90.87 7009.77 6963.47 1224.15 -80.10 6030590.61 557951.37 1226.77 0.00 BP Amoco WELLPATH DETAILS MPC·26L 1 500292263460 Parent Wellpath: Tie on MD: MPC·26L 1PB3 7500.00 Rig: Ref. Datum: Nordic 2 47 : 26 6m1996 11 :44 46.3Oft V.Sectlon Origin Origin Angle +N/·S +E/-W 96.00· 0.00 0.00 Starting From TVD 29.50 REFERENCE INFORMATION Co-ordinate (N/E¡ Reference: Well Centre: MPC-26, True North Vertical (rVD Reference: System: Mean Sea level Section (VS Reference: Slot - 26 (O.OON,O.OOE) Measured Depth Reference: 47: 26 6/7/199611:44 46.30 Calculation Method: Minimum Curvature ANNOTATIONS 'EJW SN.po TVO MD Anootatton UP:-·26A. Pd'nooJ I oeo 9.&10-. -78973 p~ ~:~~~.Jo:Frx1"". oeo 101162 ....1.2679 ~r~J 6825.23 6970.00 Window (,9,1:5(1) 10.&306 -2168 UV:-~T62 695-500 S5973 '''571 6988.55 7500.00 KOP "'P:-2'EoA 164 7010(0) 61481 ".0 36 7018.32 8545.00 TO I,IP"':-2'E.AT63 7Ct3-S 00 62810 4789-1 6450 6500 6550 ?600 æ6650 o It) ~700 J: .. a.tJ750 G) Q 6800 i .!:æ 6850 1:: ~ 6900 26950 to- 7000 7050 7100 7150 ·850 -800 -750 -700 -650 -600 op LEGEND T ~~g:~~'tffpc¿;~ 1, 'Ian #6f\ M MPG-26 (MPG-26L 1'81) .\ MPC-26 (MPG-26L 1 "82) r MPG-26 (MPG-26L 1 '83) f - MPC-26L1 é D;fect: {GO?; 267-6513 E-fHaH: b;ij.potf;~s~§?¡r.teq.œfn 8a~er Hugh~s ¡NTEQ- i9Ð7} 267 -6fDD Wellpath: (MPC-26IMPC-26L1) Azimuths to True North Magnetic North: 25.47" Magnetic Field Strength: 57516nT Dip Angle: 80.86· Date: 6J1SJ2003 Model: bggm2003 Created By: Brij Polois Date: 817/2003 .I/~' ~: ~ t ~; \ gi( . ~..;~~:~~'~ C~";î:~aGt ~fifof[n3Uùr;: ~"""""",,,",,V.·-'____V~ INTEQ .... .. ....m ....... ./ .... : ./ . . /J/~ =------ .. .. ...... .. ... ~-~..- .--- "~ . . . \ / //' --- "'~" .. . ...\ .. ,\'.x .. .......... ... ...... li~/· [~(\\ ~ ~ / . . . . ....mm .~ ...... ........ "'-" · ~ · .'. 950: ...\ ~~ .... .. .... "" ~0- ", .. .... . .... .. ..... . m.m.. . ... .< --- .. . .. . ........ . "'<~jMPG-26(MPC-26L1P83)1 . . . \ . . . ", '\:. .,., ,. ,.... ....... ... ..\.... ... >... . 800":'· . .... ···'Kr·· .. ...... 750:: . \ ... .... .. ... ... >,~ .... ...... ...... ... ......... ... \".... .. \ . .~__'....._ T ...m \ ... ....... ... . ... .. .... ~___..~-<._____ . . . ......... , . ------- ....m·m...m . 125~ .... ILUU 150-:: ..~~ 1 00--= 1050-:: 1000--: +' :c 1:: o ~ . :c .. ::::I o In 900-~ 850": ... 'VV 650~ VVV oJoJV -~~ .JVV : !tIn...... ""t:.' ,..nt" ...~I tDR?\ ..... .... . · . .... ..... · -- .... . · · . . . ...... ............................ ......... ....m... . .. . . .... .... . · · .. '/I . . . , D'.""" . .... . . . .... ... -_...-~ · ~..c..--.'l .y · ...... · · . .. . '/// --<' . · . \ \ . \ . . .\. .. ........ .... .... , , j -250 -200 -150 ·1)0 . . . . . ..... .... ..... >. ..... .. .. ..... ... " .. . , " ' :' .. " .' '.; . 300 400 550 650 7!iO ....... .... . ... . .. .... . , . . Ulli · · , , . . · · .. .. ........... :.......... 1 . , . 5) 100 150 200 . ., , toJV..< .... . -500 '-450 ': -3 )Q West(-)/East(+) [50ft/in] '-' 150 200 300 350 Vertical Section at 96.00° [50ft/in] 8/7/2003 -1 : 19 PM ) BP-GDB ) Baker Hughes INTEQ Survey Report Company: Field: Site: Well: Wellpath: BP Amoco Milne Point M Pt C Pad MPC-26 MPC~26L 1 PB3 Date: 8/7/2003 Time: 16:24:59 Page: Co-ordinate(NE) Reference: Well: MPC~26, True NOrth Vertical(TVD) Reference: 47: 26 6/7/199611:4446.3 Section (VS) Reference: Well (0.00N,0.00E,14.77Azi) Survey Cal¢ulation Method: Minimum Curvature Db: Oracle Field: Milne Point 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: Site: M pt C Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6027347.71 ft 558058.04 ft Latitude: 70 29 Longitude: 149 31 North Reference: Grid Convergence: ................,.."."......., . Alaska, Zone 4 Well Centre bggm2003 7.200 N 31.821 W True 0.45 deg Well: MPC-26 Slot Name: 26 MPC-26 Well Position: +N/-S 2019.80 ft Northing: 6029367.24 ft Latitude: 70 29 27.064 N +E/-W -1.26 ft Easting : 558041.02 ft Longitude: 149 31 31.858 W Position Uncertainty: 0.00 ft Wellpath: MPC-26L 1 PB3 500292263472 Current Datum: 47 : 26 6/7/1996 11 :44 Magnetic Data: 8/7/2003 Field Strength: 57541 nT Vertical Section: Depth From (TVD) ft 29.50 Height 46.30 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 Survey Program for Definitive Well path Date: 8/7/2003 Validated: Yes Actual From To Survey ft ft 148.86 6926.59 6970.00 7104.48 7125.00 7916.00 Version: Toolcode 1 : MWD - Standard (148.86-7445.00) (0) MWD MWD (6970.00-7640.00) (2) MWD MWD (7125.00-7916.00) MWD Annotation MPC-26L 1 PB1 7125.00 ft Mean Sea Level 25.25 deg 80.88 deg Direction deg 14.77 Tool Name MWD - Standard MWD - Standard MWD - Standard MD ft 6970.00 7125.00 7916.00 T"D ft 6871.53 6993.18 7009.95 Window KOP TD Survey: MWD Start Date: Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard Engineer: Tied-to: 7/12/2003 From: Definitive Path ) BP-GDB ) lB..! BA Ii:S Baker Hughes INTEQ Survey Report IN'I'EQ Company: BP Amoco Date: 8/7/2003 Time: 16:24:59 Page: 2 Field: Milne Point Co-ordinate(NE) Reference: Well: MPC-26, True North Site: M Pt C Pad Vertical (TVD) Reference: 47: 266/7/1996 11 :4446.3 Well: MPC~26 Section (VS) Reference: Well (O.OON,O.OOE, 14.77Azi) WeHpath: MPC-26L 1 PB3 Survey Calculation l\'I.ethod: Minimum Curvature Db: Oracle Survey MD lncl Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 6970.00 8.56 345.27 6871.53 6825.23 989.44 -422.04 6030353.26 557611.31 849.10 0.00 7104.48 56.07 30.40 6983.16 6936.86 1051.75 -398.23 6030415.75 557634.63 915.43 37.39 7125.00 65.39 33.22 6993.18 6946.88 1066.93 -388.79 6030431.00 557643.95 932.51 46.97 7160.35 55.26 35.08 7010.66 6964.36 1092.33 -371.59 6030456.53 557660.95 961 .46 29.02 7193.70 69.22 36.47 7026.15 6979.85 1116.20 -354.36 6030480.53 557677.99 988.93 42.02 7225.89 81.69 44.97 7034.24 6987.94 1139.70 -334.05 6030504.19 557698.12 1016.84 46.38 7250.90 90.83 52.73 7035.87 6989.57 1156.09 -315.29 6030520.72 557716.75 1037.46 47.88 7285.72 92.02 70.62 7035.00 6988.70 1172.54 -284.77 6030537.41 557747.13 1 061. 15 51.48 7320.37 89.23 92.92 7034.61 6988.31 1177.46 -250.70 6030542.60 557781.16 1074.60 64.85 7354.30 91.97 109.56 7034.26 6987.96 1170.88 -217.54 6030536.27 557814.37 1076.69 49.70 7382.46 89.08 121 .42 7034.00 6987.70 1158.78 -192.17 6030524.37 557839.83 1071.46 43.34 7411 .38 86.68 136.61 7035.07 6988.77 1140.64 -169.78 6030506.41 557862.36 1059.64 53.14 7440.47 87.02 141.56 7036.67 6990.37 1118.70 -150.76 6030484.62 557881.54 1043.27 17.03 7472.27 93.01 140.68 7036.66 6990.36 1093.96 -130.81 6030460.04 557901.69 1024.43 19.04 7499.02 94.42 148.25 7034.93 6988.63 1072.25 -115.31 6030438.46 557917.36 1007.40 28.73 7531.65 93.13 146.02 7032.78 6986.48 1044.91 -97.64 6030411.25 557935.24 985.46 7.88 7554.16 92.61 142.95 7031.65 6985.35 1026.61 -84.58 6030393.06 557948.44 971.10 13.82 7586.71 92.15 137.47 7030.30 6984.00 1001.63 -63.78 6030368.24 557969.43 952.25 16.88 7621.48 92.49 131.52 7028.89 6982.59 977.29 -39.01 6030344.10 557994.39 935.03 17.13 7653.70 93.07 126.02 7027.33 6981.03 957.15 -13.93 6030324.16 558019.63 921.95 17.14 7682.37 91.35 121 .27 7026.22 6979.92 941.28 9.92 6030308.48 558043.59 912.69 17.61 7717.27 91.38 115.39 7025.39 6979.09 924.73 40.61 6030292.17 558074.41 904.51 16.84 7750.76 91.53 109.03 7024.54 6978.24 912.08 71.59 6030279.77 558105.49 900.18 18.99 7782.01 91.41 105.57 7023.74 6977.44 902.79 101.42 6030270.71 558135.38 898.81 11.08 7810.87 94.89 108.02 7022.15 6975.85 894.4 7 129.00 6030262.60 558163.02 897.79 14.74 7845.45 97.01 113.66 7018.56 6972.26 882.24 161.13 6030250.63 558195.24 894.16 17.34 7916.00 97.01 113.66 7009.95 6963.65 854.14 225.26 6030223.03 558259.59 883.35 0.00 BP Amoco LEGEND T mmm ~þg:~~.¡tfpC¿;}¡ 1. 'Ian #6A M ~þg:~~ !~þg:~~t: ~~i¡ f MPC-26 (MPC-26L PB3) í - MPC-26L1 $- Ba<er H"g;1~S i~~~ ~~~~~~i~~~q"Nm Wellpalh: (MPC-26/MPC-26L 1) Azimuths to True North Magnetic North: 25.47" Magnetic Field Strength: 57516nT Dip Angle: 80.86° Date: 6/18/2003 Model: bggm2003 Created By: Brij Polnis Date: 8f7/2003 /./K:> rt.. ~-.j:;~-~ ,~ Parent Wellpath: Tie on MD: WELLPATH DETAILS MPC·26L 1 500292263460 MPC·26L 1PB3 7500.00 OJ) Crmtar..1 jr:forrn:~ilior: INTEQ Rig: Ref. Datum: Nordic 2 47 : 26 6f711996 11 :44 46.30f1 1300--: . ..mm' ...... , . ' , . , . · . · . , , .... .~~c . .. ..... .....,. · .. ,. . ...... DR?> 1250-:: · . ..'m '-'-'-C · ..... ...... · . .... .'. - .......'. ..,.. . ...... ... . ;........ .. . · ./ · · . , . , .~~ · · ,~vv · /' · , .. ,'. -;;;:? ~ .... ... ... · · 150-:: ,¿ ~--- "~ · . · · · \ 1>/ .---.\~" .. , , · ...'. 100--::: , , ..,. .' . ....... ....,.. .. '/~/ [52£/\ ~ , , , 1050--:: ' . , · · . . · . , 1 000-:: V; \", ""\;y/ , · , , , · · . · · , ~ 950~ ... ..... \"ìJ~ ,...... .mm.....'.. ~~~\., · , '.... ... ...... ,.. , ........ .'.. ... . ..... ..., +' ...... ..--<~j -~, <nD'" . :é 900'~ ...\ m ... .,.. 1:: , . , '. ... , 0 850-~ · . .... ,. ... ....'.' .'\", " ' ..'. . ~ , . ....·m....... ,.........,.. .... '. ... ... ..m .... ... .... .... mom... ~ .... 800-~ . .... mo ..... :é \ , .. 750-::: ... ...,. . , ;.M~_..L.D'__~< :I 0 · .'. .. Ä. In .. .. ...... ........ .. ....... ,.......... ... 'vv \ . , · ~'---.....- . , . .... .. ..'.. .. >~/</ 650-~ . m .... .... , ..m .. , .m ~ , \ , . ---.---- , . , . · , . · vvv \ ....,..... .. · ~ ---;;7 .... .- .... ... · ... .... ...... ..,.. ......... ... · ,-NV · \ · · . , 1M 'C-26L1 , · , ' r.:-æJ 500- · · . , , .. . , · -- · · , · ._~ -. , . . TUV ... .. .. \ ..... ...., .'. .. '. ......... . ..... .............. .... .. . ......... '.... ... ... ··.·0' .' · "i_3bo' . . , . , , . " .' '~k~ ' . . . .. .. 7~iO '. -5)0 -41)0 -3:50 -2 iO -200 -150 -100 -m 50 100 200 250 300 400 West(-)/East(+) [50ft/in] .~ V.Sectlon Origin Origin Angle +N/·S +E/·W 96.00· 0.00 0.00 Starting From TVD 29.50 REFERENCE INFORMATION Co-ordinate (N/E~ Reference: Well Centre: MPC-26. True North Vertical (rVD Reference: System: Mean Sea Level Section (VS Reference: Slot- 26 (O.OON.O.OOE) Measured Depth Reference: 47: 26 617/1996 11:44 46.30 Calculation Method: Minimum Curvature ANNOTATIONS .8'>'1 St..,. TVD MD Annotation "'P:-26A.~' 000 9..7 O~ -76"913 """"" ~~~frad;.n 000 101162 ~16H ir=~J 6825.23 6970.00 Window ..., 00 1~JC06 ·2158 t,lP'::.;?£A.T62 6~500 B.~13 14571 6988.55 7500.00 KOP J.fP";.2E.,.\ T6~ 701000 67.. 81 o/f.I :;6 7018.32 8545.00 TO 1,IP';-2'6A.T63 7"3500 62810 ~78 9-4. 6450 6500 6550 ?600 æ 6650 o It) -moo .c .. Cß750 G» Q 6800 ¡ .~ 6850 1:: ~ 6900 26950 ... 7000 7050 7100 7150 150 2ÒO 300 Vertical Section at 96.00· [50ft/in] 8/7/2003 -1:19 PM /,-~ J-OS07(2) 'b-'r BP-GDB ) Baker Hughes INTEQ Survey Report Company: Field: Site: Well: Wellpath: BP Amoco Milne Point M PtCPad MPC-26 MPC-26L 1 Date: 8/7/2003 Time: 16:25:23 Page: Co-ordinate(NE) Reference: Well: MPC-26, True North Vertical (TVD) Reference: 47 : 266/7/1996 11 :4446.3 Section (\'5) Reference: Well (0.00N,0.00E,96.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Milne Point 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: Site: M Pt C Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6027347.71 ft 558058.04 ft Latitude: 70 29 Longitude: 149 31 North Reference: Grid Convergence: BillI: BA H I: lNTEQ Alaska, Zone 4 Well Centre bggm2003 7.200 N 31.821 W True 0.45 deg Well: MPC-26 Slot Name: 26 MPC-26 W ell Position : +N/-S 2019.80 ft Northing: 6029367.24 ft Latitude: 70 29 27.064 N +E/-W -1.26 ft Easting : 558041.02 ft Longitude: 149 31 31.858 W Position Uncertainty: 0.00 ft Wellpath: MPC-26L 1 500292263460 Current Datum: 47 : 26 6/7/1996 11:44 Magnetic Data: 6/18/2003 Field Strength: 57516 nT Vertical Section: Depth From (TVD) ft 29.50 Height 46.30 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 Survey Program for Definitive Well path Date: 8/7/2003 Validated: Yes Version: 4 Actual From To Survey Toolcode ft ft 148.86 6926.59 1 : MWD - Standard (148.86-7445.00) (0) MWD 6970.00 7104.48 MWD (6970.00-7640.00) (2) MWD 7125.00 7472.27 MWD (7125.00-7916.00) (4) MWD 7500.00 8545.00 MWD (7500.00-8545.00) MWD Annotation MPC-26L 1 PB3 7500.00 ft Mean Sea Level 25.47 deg 80.86 deg Direction deg 96.00 Tool Name MWD - Standard MWD - Standard MWD - Standard MWD - Standard 6970.00 7500.00 8545.00 Window KOP TD 6871.53 7034.87 7064.64 Survey: MWD Start Date: Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard Engineer: Tied-to: 7/13/2003 From: Definitive Path ) BP-GDB ) Baker Hughes INTEQ Survey Report ....,',......,',,,,..,,............,,.,,....,..,...,,,.,.......n IN'IEQ Company: BP Amoco Date: 8/7/2003 Time: 16:25:23 Page: 2 Field: Milne Point Co-ordinate(NE) Reference: Well: MPC-26, True North Site: M Pt C Pad Vertical (TVD) Reference: 47 : 266/7/1996 11 :44 46.3 Well: MPC-26 Section (VS) Reference: Well (O.OON,0~00E,96.00Azi) Wellpath: MPC-26L 1 Survey 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 6970.00 8.56 345.27 6871.53 6825.23 989.44 -422.04 6030353.26 557611.31 -523.16 0.00 7472.27 93.01 140.68 7036.66 6990.36 1093.96 -130.81 6030460.04 557901.69 -244.45 20.07 7500.00 94.38 148.18 7034.87 6988.57 1071.47 -114.73 6030437.67 557917.95 -226.10 27.44 7529.45 88.92 146.72 7034.03 6987.73 1046.66 -98.89 6030413.00 557933.97 -207.76 19.19 7560.43 89.05 142.96 7034.58 6988.28 1021.34 -81.06 6030387.82 557952.00 -187.37 12.14 7595.84 91.14 134.94 7034.52 6988.22 994.66 -57.83 6030361.33 557975.44 -161.48 23.40 7635.92 90.37 124.33 7033.99 6987.69 969.13 -27.01 6030336.04 558006.45 -128.16 26.54 7676.52 90.52 116.52 7033.67 6987.37 948.59 7.98 6030315.77 558041.59 -91.22 19.24 7705.49 90.83 111 .89 7033.33 6987.03 936.72 34.39 6030304.11 558068.09 -63.71 16.02 7740.02 87.67 107.70 7033.78 6987.48 925.03 66.86 6030292.67 558100.66 -30.19 15.20 7770.17 85.48 110.58 7035.58 6989.28 915.16 95.29 6030283.03 558129.16 -0.89 11.99 7800.19 86.22 116.66 7037.76 6991.46 903.17 122.71 6030271.25 558156.67 27.63 20.35 7832.44 85.64 121.37 7040.05 6993.75 887.57 150.84 6030255.88 558184.91 57.23 14.68 7860.72 84.99 125.52 7042.36 6996.06 872.04 174.35 6030240.53 558208.54 82.24 14.81 7890.09 83.45 128.67 7045.32 6999.02 854.42 197.65 6030223.10 558231.98 107.26 11.89 7920.54 82.98 135.14 7048.92 7002.62 834.24 220.15 6030203.09 558254.63 131.74 21.16 7956.55 84.62 141.03 7052.81 7006.51 807.61 244.05 6030176.65 558278.73 158.29 16.89 7990.85 83.17 148.18 7056.46 7010.16 779.83 263.79 6030149.03 558298.69 180.83 21.15 8020.57 82.86 146.23 7060.08 7013.78 755.03 279.77 6030124.36 558314.86 199.31 6.60 8051.75 83.46 141.97 7063.79 7017.49 729.96 297.92 6030099.44 558333.20 219.98 13.70 8085.16 84.31 138.31 7067.35 7021.05 704.47 319.20 6030074.11 558354.68 243.82 11.19 8119.37 83.88 130.74 7070.88 7024.58 680.62 343.45 6030050.46 558379.11 270.42 22.05 8151.11 84.65 126.01 7074.05 7027.75 661.02 368.20 6030031.05 558404.01 297.08 15.02 8191.88 88.80 120.73 7076.38 7030.08 638.65 402.17 6030008.95 558438.16 333.21 16.45 8225.64 87.48 117.43 7077 .48 7031.18 622.25 431.66 6029992.78 558467.76 364.25 10.52 8257.27 88.04 11 3.44 7078.71 7032.41 608.68 460.19 6029979.44 558496.40 394.05 12.73 8287.39 89.14 109.61 7079.46 7033.16 597.64 488.20 6029968.61 558524.49 423.05 13.23 8330.30 90.00 102.03 7079.78 7033.48 585.95 529.45 6029957.25 558565.83 465.30 17.78 8358.46 90.43 98.93 7079.67 7033.37 580.83 557.14 6029952.34 558593.55 493.37 11.11 8389.30 93.38 95.05 7078.65 7032.35 577.08 587.72 6029948.83 558624.16 524.18 15.80 8425.19 94.64 89.10 7076.13 7029.83 575.78 623.48 6029947.81 558659.93 559.88 16.91 8453.62 95.93 86.04 7073.52 7027.22 576.98 651.76 6029949.23 558688.20 587.88 11.64 8483.73 95.50 79.42 7070.51 7024.21 580.77 681.47 6029953.25 558717.87 617.03 21.92 8545.00 95.50 79.42 7064.64 7018.34 591.97 741.42 6029964.92 558777.72 675.48 0.00 BP Amoco LEGEND T ~~g:~~'¡ffp~~~ I, 'Ian #61'. M ~~g:~g ¡~~g:~gt 1 ~~~¡ Þ MPG-26 (MPG-26L 1 ~B3) f MPG-26L 1 _~. -6 Baker H"g~es !ß~~ {)~1fA~;;i0.~~q':0m Wellpath: (MPC-26/MPC-26L1) Azimuths to True North Magnetic North: 25.4r Magnetic Field Strength: 57516nT Dip Angle: 80.86· Date: 6/113/2003 Model: bggm2003 Created By: Brij Potois Date: 817/2003 ,,/~ f\~ . ~. ;;;~.. ';- Parent Wellpath: Tie on MD: WELLPATH DETAILS MPC·26L 1 500292263460 MPC·26L 1 PB3 7500.00 Nordic 2 47 : 26 6m1996 11 :44 46.3Oft op Cr.:ntfir;t Jî:f0r~TÎa{i{)r:: INTI!~Q Rig: Ref. Datum: , · ... . .... . , ..... , . · . · , . . .... ."." ...m. · ....., m..·.. ".' .."..'..'.'... , . · , , , .... · I 30Q-~:m ' . . . . . . ....... . ....,.. '... .. Mi'G-26 , -'! ... .... mu ,. .. m ..... ..'.', /' V.Sectlon Origin Origin Angle +N/-S +E/·W 96.00· 0.00 0.00 Starting From TVD 125D-:: m 29.50 ,^ "vv . REFERENCE INFORMATION ~~ .'....... ~ "~ 100--:: \. / ;/ -----.'\~" ,.... / /.... .. ...,.... ,,".:'" '.'... ::: ...... . ~/ @/ \'\~ 950u: ...\"0 ~ 900u~ 850~ 800--: 750u~ ........ · · · I "D"'.O~ ~....?~';D'. "" , . ..// ... .,.. .,. /~/..... ->---' , . ,~7..· . Co-ordinate (N/E~ Reference: Well Centre: MPC-26, True North Vertical (tVD Reference: System: Mean Sea Level Section (VS Reference: Slot - 26 (O.OON,O.OOE) Measured Depth Reference: 47: 266/7/199611:44 46.30 Calculation Method: Minimum Curvature 15D-:: . . . : . · . ., ., ..... i . · ......... ..........'.......................... .~/ , . . ANNOTA nONS ·EJ-W Shoç,o TVD MD AnnotaHon UP";-26A.Pc:tyo?rlJ , OCO .,,'" -78913 """-' ~f.t..~f'Cfrxt...e 0'" 101162 ...c26 79 ~E'~I 6825.23 6970.00 Window 69-1Ho:. 10..&300 ·21 sa UP".;.2€.A,T62 .." '" 85913 14571 6988.55 7500.00 KOP UP':-26A T6.t 701QOO 61"82 .", 3ô 7018.32 8545.00 TO uv.:·2EJ,. 16 3 10J500 62810 HBg.c .........,. ,^ , ""'''' ." ,,'m^ ) . ,-- '":::~/ . . . . ... ~~ -un> .... .... ,,~~)m"" ._.., . ... ... ... . ""<"R, .......... . ... .... m ..... ""m\ ....... .... >~:~ . ..... ....~~: ..' ............... ... .~ . . ............... ~.~.''-". ~"----- .. ..~ , · ~ · . . .. . . +' - .c 1:: 0 Z - - . - .c .. ::s 0 6450 en 6500 6550 ~600 ~6650 &I) ~700 .c .. a.B750 GJ °6800 ¡ .!:æ 6850 1:: ~ 6900 26950 I- 7000 7050 7100 7150 . . · . · . . ...\.. ............. .. \ \ , · · ,. .. . . . . .... ... . . . ... .... .... .... ... . .. ........ . ... . . ... ... . .' . . · · . . .......... · . . . · · . 'vv 650u~ .... · VVV · · ........ · ..hN . · ... . \.. . \. · . \ \ .. . .... ... -?61 . · · · · . · , · · · .. . . .. .... .. . ...... .... · . ... :. ... . , . , . · · l . , <;0 100 150 200 250 300 400 450 . . , L!QJ · . . ~^^ vVV · \ . . '''JV . '. . . . ... \.. < . .... " ."." " '. ".' .'" 'j -5:)0 -450 -400 -350 -3)0 -2 jO -200 -1. jO 100 -:iO 0 · · . . ......... ......... .. .... l' 1 1 ' l .. 7~jO' l' West(-)/East(+) [50ft/in] --' 150 200 300 350 Vertical Section at 96.00° [50ft/in] 8/7/2003 '1 :19 PM I··i~\.' , ,- L~.:"ì ) rmr~ \.'_' lJ ) ffi\\ ~i (Æ., (~j~(( í\ L. 'I Ü \ì,\\/lJ .n.~ ::J IJ"\ æj U ü Lr1\ I / I FRANK H. MURKOWSKI, GOVERNOR AIfA~1iA. OIL AND GAS CONSERVATION COMMISSION 333 w. -¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark Johnson CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Milne Point Unit lVIPC-26Ll BP Exploration (Alaska), Inc. Permit No: 203-076 Surface Location: 1086' NSL, 2419' WEL, Sec. 10, TI3N, RI0E, UM Bottomhole Location: 1812' NSL, 1524' WEL, Sec., 10, TI3N, RI0E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to redrill the above development 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. The permit is for a new wellbore segment of existing well C-26, Permit No 195-206, API 50- 029-22634-00. Production should continue to be reported as a function of the original API number stated above. 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 pennit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this 1JS day of April, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ) STATE OF ALASKA ALASk.. OIL AND GAS CONSERVATION COh...JISSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test III Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 46.3' Milne Point Unit I Kuparuk 6. Property Designation River Sands ADL 047434 x = 558041, Y = 6029367 7. Unit or Property Name Milne Point Unit x = 557611, Y = 6030353 8. Well Number MPC-26L 1 x = 558929, Y = 6030100 9. Approximate spud date 05/07/03 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 8630' MD 17010' TVDss o 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 95 Maximum surface 2800 psig, At total depth (TVD) 7000' I 3500 psig Setting Depth Top Bottom Quantity of Cement enQth MD TVD MD TVD (include staQe data) 1650' 6980' 6835' 8630' 7010' Uncemented Slotted Liner 1 a. Type of work 0 Drill III Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1086' NSL, 2419' WEL, SEC. 10, T13N, R10E At top of productive interval 2075' NSL, 2840' WEL, SEC. 10, T13N, R10E At total depth 1812' NSL, 1524' WEL, SEC. 10, T13N, R10E 12. Distance to nearest property line 13. Distance to nearest well ADL 047433,1524' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 6970' MD Maximum Hole Angle 18. Casing ~rogram Specifications Size Hole CasinQ Weiaht Grade CouolinQ 3-3/4" x 4-1/8" 3-3/16"x2-7/8" 6.2#/6.16# L-80 ST-L 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Su rface Intermediate Production Liner 7445 feet 7342 feet 7400 feet 7297 feet Length Size 80' 4673' 20" 9-5/8" 6854' 717' 7" 5" t~( d,--\ 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 Plugs (measured) Junk (measured) Cemented MD TVD 250 sx Arcticset I (Approx.) 924 sx PF 'E', 250 sx 'G', 150 sx PF 'E' 112' 4704' 112' 4637' 170 sx Class 'G' 115 sx Class 'G' 6882' 6785' Rt:7tt=1V~rj' -7341' APR 2 2 2003 Perforation depth: measured 6966' - 6976', 7032' -7052', 7119' -7173' true vertical 6868' - 6877', 6933' - 6953', 7019' - 7072' Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments III Filing Fee 0 Property Plat III BOP Sketch 0 Diverter Sketch III Drilling Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report III 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Johnson, 564-5666 21. I hereby certify that t~;Joregoing is tr~ a d correct to the be~t of my kn~~ledge . Signed Mark Johnson ~'-- ô.. ~'2. -Title CT Dnlllng Engineer . GomþJ.~i~I1U"·Øn.I,~: ....; Permit Number ?^3 _ 0"7/ API N er d~J~ay.-e~e See cover letter ~ 'Cð 50- 029-22634-60 /( '-'O( c.J.-J for other reQuirements Conditions of Approval: Samples Required 0 Yes £'B'No Mud Log Required 0 Yes ŒNo Hydrog~n Sulfide Measures ~es "0' No Directional Survey Required ~es 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi ~ Other: Approved By R-~ Form 10-401 Rev. 12-01-85 ~ Prepared By NamelNumber: Terrie Hubb/e, 564-4628 Date 'f /2fð J by order of Commissioner the commission O~~,G.NA '. '1/2-8/03 Date Submit In Triplicate ) Milne Point MPC-26 L 1 Sidetrack - COiled\Ubing Drilling Summary of Operations: Nordic 2 will add a lateral leg to Milne Point MPC-26, drilling the sidetrack with kill weight drilling mud and/or the dynamically overbalanced coiled tubing drilling (DOCTD) technique (see description below). Flexibility between the two drilling techniques is planned to achieve resistivity L WD objectives (low salinity mud required) and for mud cost optimization. This horizontal sidetrack will target Milne Kuparuk A sand reserves. MPC- 26 L 1 will be a producing well. The Nordic 2 rig will pull ESP, sidetrack and drill LI, run pre-drilled liner, and recomplete with a new 3 ~"GLM tubing completion. Note that Nordic 2 will be rigging up a workover BOP stack and then a drilling BOP stack (pictures attached). MPC-26 Workover and Sidetrack with Nordic 2 rif 1. Pre-rig - pull 1.5" CT jet pump, test 7" casing packoff, confiffi1 injection through tubing perfs, set BPV. 2. MIRU Nordic 2. Pull BPV, kill well, set TWC. ND tree. NU 13 5/8" BOPs and test. Pull TWC. 3. Pull 2 7/8" ESP completion. 4. Set 11" x 7" false bowl in tubing head. Set BPV. 5. ND 13 5/8" bag and blinds. NU 7" CTD BOP stack on top of remaining 13 5/8" BOPs. Run test plug. Test 7" BOPs. Pull test plug. 6. With 2 3/8"CT - cleanout and drift liner & casing. Test 7" casing to 3500 psi. 7. With 2 3/8"CT - Set 5" whipstock and mill window. 8. Drill CT sidetrack with 3.75" x 4 118" bicenter bit to TD of8630' rod using kill weight drilling mud and/or the dynamically overbalanced coiled tubing drilling (DOCTD) technique. 9. Complete with pre-drilled 3 3/16" x 2 7/8" liner. Drop ofTOL ,...,10' outside window. 10. Pull whipstock tray. 11. Set BPV. ND 7" BOPs. NU 13 5/8" annular preventor and blinds on remaining 13 5/8" BOP stack. Set test plug. Test 13 5/8" BOPs. Pull test plug. Pull 11 " x 7" false bowl. 12. Run 3 ~"tubing GLM completion. Set packer. Test tubing and IA to 3500 psi. Set TWC. 13. ND 13 5/8" BOPs, NU THA and tree. Test. Pull TWC. 14. Freeze protect well. Set BPV. RDMO Nordic 2. Mud Program: . Steps 1-7: 8.5 ppg KCL/NaCI/NaBr biozan brine · Steps 8-14: 8.5 ppg Potassium Formate based Flo-Pro as KW mud and/or 8.5 ppg potassium formate based Flo-Pro with DOCTD technique (if reservoir pressure climbs away from parent wellbore). Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: Base case is 3 3/16" x 2 7/8" pre-drilled liner from 6980' to TD at 8630'. Option case is cemented liner completion if significant waterflood breakthrough is indicated in L WD resistivity logging. Mark o. Johnson 564-5666 office, 240-8034 cell 1/3 ) . Milne ,",oint MPC-26 L 1 Sidetrack - COih;~)TUbing Drilling Well Control: · Two BOP diagrams are attached. Diagrams are provided for the 13 5/8" workover BOP, and the 13 5/8" x 7" workoverlsidetrack/pressure deployment (wi sip d) BOP stacks. Whenever stack changes occur during the MPC-26 Ll operation, there will be two levels of protection frOln reservoir pressure and all new BOP equipment and flanges will be pressure tested to pressures listed below. All BOPs will be tested at periodic (7 day) testing intervals. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3~00 psi. · The annular preventer(s) will be tested to 400 psi and 2500 psi. Directional · See attached directional plans for MPC-26 L 1. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · LWD and LAD resistivity will be run in opelIDole. Hazards · Sidetrack may encounter minor losses through existing fracture stimulation in parent wellbore, and when crossing 3 faults expected along the directional plan. However, lost circulation risk is low based on historical infonnation. LCM materials will be on location as a contingency. · Reservoir pressure is 7.1 ppg EMW at the parent wellbore, but higher pressures up to 9.6 ppg EMW may be seen in penetrated fault blocks. · H2S at MP C pad is low. MPC-26 had an IDS level of 5 ppm on 5/01/00. Highest producing H2S level is from MPL-04 at 8 ppm. All H2S monitoring equipment will be operational. Reservoir Pressure · Res. pressure was measured in January 2003 at 2582 psi @ 7000'ss (7.1 ppg). Max. surface pressure with gas (0.1 psi/ft) to surface is 1882 psi. If a fault block contains 9.6 ppg original reservoir pressure (3500 psi at 7000'), max. surface pressure with gas (0.1 psi/ft) to surface is 2800 psi. Dvnamically Overbalance Drillinø As done in the past at KRU by CTD, dynamically overbalanced coiled tubing drilling (DOCTD) techniques will be employed to address high reservoir pressure. Plans are to use 8.5 ppg drilling fluid in combination with annular friction losses and applied surface pressure to always maintain overbalanced drilling conditions. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique with an underbalanced mud weight requires deployment of the BHA under trapped wellhead pressure. Deployment will be accomplished utilizing the BOP pipe VBRs and 3" slip rams (see attached wlslpd BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. At least 1.5 times hole volume of kill weight fluid will be on location as a contingency. Once drilling is complete, the production liner will be deployed into the wellbore after killing the well with kill weight fluid. Maximum reservoir pressure expected: 3500 psi at 7000' ss, 9.6 ppg EMW. Expected annular friction losses while circulating: 250 psi Planned mud density: 8.5 ppg equates to 3094 psi hydrostatic bottom hole pressure. Mark o. Johnson 564-5666 office, 240-8034 cell 213 Milne.)Oint MPC-26 L 1 Sidetrack - COiltJTubing Drilling While circulating 8.5 ppg fluid and holding 300 psi on the drilling choke, the bottom hole circulating pressure is estimated to be 3650 psi, -150 psi over-balanced to the reservoir. When circulation is stopped, a minimum of 550 psi surface pressure will be applied to over-balance the reservoir by -150 psi. Operating parameters will be adjusted based on real-time bottom hole pressure measurements while drilling. Flexibility between using the DOCTD method (8.5 ppg mud + surface pressure) and drilling with kill weight drilling mud (9.9 ppg EMW) is being utilized to obtain the best quality LWD resistivity data (best logged in a low CI- environment) and to optimize fluid costs. This flexibility in drilling technique is one of the main advantages of coiled tubing drilling. Mark O. Johnson 564-5666 office, 240-8034 cell 3/3 Plan: Plan #6 (MPC·26IPIØn#6 MPC-26A) Created By: Brij Potnis Contacllnrormalion: ~=: ~.~) 26?~~:ieq.com Baker Hu¡tIes INTEQ: (9(~ AZimuths to True North Magnetic North: 25.54· ~~~netic Field Stre:'X~;: 57513nT D~;gl1~=~ Model: BGGM2OO2 T 1\M ~ j" (f) < ~ LEGEND ..,'. MPC-26 (MPC-28) -- PI&nt6 MPC-26A - PIow1IU1 r.~¡Jj ,t···· ~¿t~2~~ ...~.. .. ... B:fItLs ....-.... .... ............-a.....· ....~...__...&._.......-_&-..._...&-.... ......... INTEQ bp 0·.·:·..· . . 500 1400 1300- 1200- 1100 ~l:: ~ ',),fr .·.·.·.}.·C~~PC.2~T6 j':' . :::: -- ~ _I: + ,.. \ 1+'·""7 M> ..... o£}.W _ ... 800, ..--:,., ,. '.-- '. ' . JE ~m! ~: ~IDM .. . j -'" lOIn won - - 700 . 7'D1ØClO 174..12 n!35 Port ". . : . . 7œ8DO 12110 4T1M PoI'II 1: . o 600, ~. :' . ~ 500, :--:..t.:.""::---:--,~,:,:,.. .I: .'..:.: : : ...,..:. 1: 400' ··..:,H,:·:·,..:--,~,--:·· 6400 . ..,. '::':':' '.,..'. ::: 30(1. :.: ,.,. ,.;.;.. 8450, :: 200' . :::: .:. ......&.... -0' .... 6500, .... -. 1 00, ~ .: ':U':' "";"" ",''':''','':--'''' ',"':-- --: -- ':.... ,-- ':" ',--:', ...:.,.,....!,.~.....L"....,...:,' ':..... I~:i u .... :1 ~J~~~~,~~. ,~' ~,:llir~,.~~!:,f.J;i,"l~,~:::,t~I¡;~¡~~~;,~ -~ 16750. .. . .. West(.)lEast(+) [100ft11n) ) 6800, .:::.:J:::t·I::::::r:Jt'·::·:::::.'f::' i .' , ". .. i~y::~~bl.m~ - . . .' . '.. .. · . .' . -. .. .:...:.. .:-..: .:.. .: . ..:- ~. .. ..: .;. .:. 7050' ..",,-- ,',,~,u:'+'+'Hm:m'~':- · . .' . '. -" ....-......-...........-----.-.-.--.- · . .' . '. -'. · . .' . .. - . . 7100· .....:+.~ :(:.):::?j' ..:·j:t: . - .. 7150· ;~;~ 00 ~ : BP Amoco MUl'ATM IIftMLI _-.u. - -,:.....:: = -. W,IIoo_ ."HIITI1_'bW"-3111 v,-=~= ~ ...... .... .... .... REFERENCE INFORMATION Co-«dfll18 (N/E RIIference: WeI Centre: MPC-26. True NDfIh v~ ==: ~~ON~~~ Mea&nd Depth RIIfMMœ: 47: 26 ~/1996 11:44 «<;.30 Cekiulnon MefIod: r.4rIITun Cuveturø UIr:T1DII .-rAt... _ _ ... .. "'" .... _..... w_ _ '..... , ....... AM.......... lna.ø ........ -ua.M .... 1oOI ...atU1 · ftT.... .........., ..-..u ...... ........... La ....n ..aa.,. J ....... ..'a ....,.. ......., ....... ......., .... ...... .......... .. " fLIIi..... ...... ...... ,..,.. ..J4&D ...... ..... ~ · ,..,.. "'"" .,... ..-..n "JII.a1 .øa.n ...... ..... -u:a.a · ,..,......, 111.11 ........ t~, ...... '11.00 101'" ..1'" , net.. IL'I'..... ...... .,... ,.... ,........ .... · ,.,..... ..... ,...... ....... ,..... ..... ,&.01...... 1..... e .,.1Ae 1104' ....." '....1. ........, ..,.., ,.... ~ ..." tI ......... I:LOI ,..,..., ''''11 n.a.n 1L01...... ......0 ...... ~~ ~U .............n3 AMlOT_. 'fWD MD_ 17U.ft _ TW' -.n n_ KDP IMoU7 _ ) -,,_. .a.I) 7tt1.t1 I _ ,...... I _.... 7711'" , ._ "".... I 7IX.'. 111'''''' . ,-." "_ TD 0····:::.'.:::::::·.·.· to' p~ ~'.'. ',' '. . ...., ,'.', ..' ',',' ~.'I: .: . ) BP) Baker Hughes INTEQ Planning Report .iíll 8=m.. .....,.....,...~......_"'.......,..........................-..... IN"rßQ. Company: BP Amoco Field: Milne Point Site.: M Pt C Pad Well: MPC-26 WeUpath: Plan#6 MPC-26A Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea level Date: 4/16/2003 Time: 15:40:39 Page: 1 Co-ordlDate(NE) Reference: Well: MPC-26, True North Vertical (TVD) Reference: System: Mean Sea level Section (VS) Reference: Well (O.OON,O.OOE,96.00Azi) Survey Calculation Method: Minimum Curvature Db: Ora de Map Zone: Coordinate System: Geomagnetic Model: Site: M Pt C Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft GroUDd Level: 0.00 ft 6027347.71 ft 558058.04 ft Latitude: Longitude: North Reference: Grid Convergence: Alaska, Zone 4 Well Centre BGGM2002 70 29 7.200 N 149 31 31.821 W True 0.45 deg Well: MPC-26 Slot Name: 26 MPC-26 Well Position: +N/-S 2019.80 ft Northing: 6029367.24 ft Latitude: 70 29 27.064 N +EI-W -1.26 ft Easting : 558041.02 ft Longitude: 149 31 31.858 W Position Uncertainty: 0.00 ft Wellpath: Plan#6 MPC-26A 500292263401 Current Datum: 47 : 26 617/1996 11:44 Magnetic Data: 4/16/2003 Field Streogth: 57513 nT Vertical Section: Depth From (TVD) ft 0.00 Height 46.30 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +EI-W ft 0.00 +N/-S ft 0.00 Targets MPC-26 6926.59 ft Mean Sea level 25.54 deg . 80.85 deg Direction . deg 96.00 : .. . : .·Map '., ...:Map':' <:;.:..- Lati~e.:->· ~ ·4.g1~de· -> . ·:Name·.· . oe.cription TVD ''+N/-S +EI~W' . . N~~løg ·..·E.s~ . Deg Min. Set' . '. Deg.~..'~"" .. Dip. Oir. . ·ft . ft :. (t.. ···:fL . ··ft. : .' .'. MPC-26A Polygon3.1 0.00 947.04 -789.73 6030308.00 557244.00 70 29 36.378 N 149 31 55.100 W -Polygon 1 0.00 947.04 -789.73 6030308.00 557244.00 70 29 36.378 N 149 31 55.100 W -Polygon 2 0.00 1440.78 -620.85 6030803.00 557409.00 70 2941.234 N 149 31 50.131 W -Polygon 3 0.00 1269.33 202.91 6030638.00 558234.00 70 29 39.548 N 149 31 25.886 W -Polygon 4 0.00 1018.09 614.00 6030390.00 558647.00 70 29 37.077 N 149 31 13.788 W -Polygon 5 0.00 930.94 1272.41 6030308.00 559306.00 70 29 36.219 N 149 3054.411 W -Polygon 6 0.00 274.12 855.23 6029648.00 558894.00 70 29 29.760 N 149 31 6.691 W MPC-26 Hydraulic Fracture 0.00 1011.62 -426.79 6030375.40 557606.39 70 29 37.013 N 149 31 44.419 W -Rectangle (2oox1) MPC-26A T6.1 6945.00 '/1043.06 -21.88 6030410.00 558011.00 70 29 37.323 N 149 31 32.502 W MPC-26A T6.2 6955.00 / 859.73 145.71 6030228.00 558180.00 70 29 35.520 N 149 31 27.570 W MPC-26A T6.4 7010.00 J 674.82 900.36 6030049.00 558936.00 70 29 33.701 N 149 31 5.361 W MPC-26A T6.3 7035.00 / 628.10 478.94 6029999.00 558515.00 70 29 33.241 N 149 31 17.764 W Annotation MD ft 6926.59 6970.00 6990.00 7176.69 7291.69 7491.69 7701.69 7914.69 TVD ft 6782.29 6825.23 6844.97 6958.00 6952.93 6944.84 6948.49 6990.82 I \~~O '{Ilð TIP KOP 3 4 5 6 7 8 , 'Sft 1r~ "...,'¿J/~ aI ßt,~ C S.tttd ('".. f f,fJ 3'~A þA 0"" 1 ~ù (1 ~ , \;3 sS ~ vf I \3 ~s O.:·:\:··.·b~. J .'...... ,~f:.;' Company: BP Amoco Field: MUne Point Site: M pt C Pad Well: MPC-26 WeUpath: Plan#6 MPC-26A Annotation MD ft 8161.49 8630.00 TVD . ft 7035.10 7009.67 9 TD ) BP) Baker Hughes INTEQ Planning Report Plan: Plan #6 New targets due to reservoir dip. Principal: Yes Plan Section Information .MD ft 6926.59 6970.00 6990.00 7176.69 7291.69 7491.69 7701.69 7914.69 8161.49 8630.00 Incl 'deg 8.46 8.56 9.76 90.00 94.71 89.87 88.18 68.96 90.47 95.25 Survey ·lIiel . deg 8.46 e·51 8.56 8.84 9.76 :·MD· ft . . 6926.59 ~~5n n~ c-6970.00~ 69/5.00 , 6990.00 I 7000.00 12.99 7025.00 I 22.99 ~g~~:gg, ¡¡: ~~ 7100.00 I, 55.83 7118.39~î} 64.01 7125.00 I 66.95 7148.87 77.59 7150.00 I 78.10 7175.00 I 89.25 7176.69 , ~ 7200.00 . 7225.00 J 92.22 7250.00 93.26 7275.00 I 94.18 7291.69} 94.71 1300.00 94.52 7325.00 93.94 7350.00 93.34 7375.00 92.74 7400.00 92.13 7425.00 91.52 7450.00 90.90 7475.00 90.28 7491.69 89.87 7500.00 89.80 7525.00 89.59 Azim <leg 343.88 345.27 353.74 46.00 97.60 121.13 146.28 128.99 108.17 52.06 ··:Adm deg 343.88 344.63 345.27 347.60 353.74 9.87 27.30 34.26 38.12 40.70 42.20 42.68 44.29 44.36 45.90 46.00 56.43 67.63 78.85 90.08 97.60 98.58 101.53 104.48 107.42 110.36 113.30 116.23 119.17 121.13 122.12 125.12 TVD ft 6782.29 6825.23 6844.97 6958.00 6952.93 6944.84 6948.49 6990.82 7035.10 7009.67 ·SSTVD ft 6782.29 68Q9.45 (6825.23) 6830.17 6844.97 6854.78 6878.54 6900.51 6919.84 6935.79 6945.00 6947.74 6955.00 6955.24 6957.99 ~ 6H5/./8 6957.05 6955.85 6954.23 6952.93 6952.26 6950.42 6948.83 6947.51 6946.44 6945.65 6945.12 6944.86 6944.84 tI ...., 11 6944.86 6945.00 +N/~S .ft 983.24 989.44 992.56 1091.55 1126.31 1060.47 916.58 762.95 649.47 726.13 NIS" ft: 983.24 986.57 989.44 990.17 992.56 994.51 1001.64 1011.75 1024.46 1039.27 1051.18 1055.62 1072.09 1072.87 1090.37 1091.55 1106.13 1117.83 1125.02 1127.42 1126.31 1125.15 1120.79 1115.18 1108.32 1100.24 1090.94 1080.48 1068.86 1060.47 1056.12 1042.28 _.- BAKU HUGIIH ..,"'..........."'.."'...."'........"'........................... IN'lßQ Date: 4/16/2003 Time: 15:40:39 Page: 2 Co-ordlnate(NE) Reference: Well: MPC-26, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (O.OON.O.OOE,96.ooAzi) Survey Calculation Method: Minimum Curvature Db: Oracle +EI.W ft -420.34 -422.04 -422.61 -342.23 -236.79 -49.66 100.92 239.58 451.07 893.70 EJW· It -420.34 -421.27 -422.04 -422.22 -422.61 -422.51 -419.78 -413.61 -404.23 -392.02 -381.48 -377.43 -361.79 -361.02 -343.44 -342.23 -324.08 -302.05 -278.18 -253.39 -236.79 -228.59 -204.05 -179.74 -155.74 -132.11 -108.92 -86.22 -64.09 -49.66 -42.59 -21.77 Date Composed: Venion: Tied-to: 4/16/2003 4 From: Definitive Path DLS Build Tura deg/1 DOft deg/100ft deg/100ft 0.00 0.00 0.00 0.53 0.23 3.20 9.00 5.98 42.37 45.02 42.98 27.99 45.00 4.09 44.87 12.00 -2.42 11.77 12.00 -0.80 11.98 12.00 -9.02 -8.12 12.00 8.72 -8.44 12.00 1.02 -11.98 .MapN ft 6030347.08 6030350.40 6030353.26 6030353.99 6030356.38 6030358.33 6030365.48 6030375.63 6030388.41 6030403.32 6030415.31 6030419.78 6030436.37 6030437.16 6030454.79 6030455.98 6030470.70 6030482.57 6030489.95 6030492.54 6030491.56 6030490.46 6030486.30 6030480.88 6030474.21 6030466.30 6030457.20 6030446.91 6030435.46 6030427.19 6030422.89 6030409.21 ". MapE' ft 557613.06 557612.10 557611.31 557611.12 557610.72 557610.80 557613.48 557619.57 557628.84 557640.94 557651.38 557655.40 557670.90 557671.67 557689.11 557690.32 557708.35 557730.29 557754.10 557778.87 557795.46 557803.67 557828.25 557852.60 557876.65 557900.34 557923.60 557946.37 557968.59 557983.09 557990.20 558011.12 TFO .' Target deg 0.00 64.76 52.65 52.66 84.00 101.00 94.00 220.00 -46.00 -84.00 "vs· ft -520.81 -522.09 -523.16 -523.41 -524.04 -524.15 -522.18 -517.10 -509.10 -498.50 -489.27 -485.70 -471.88 -471.19 -455.53 ····DLS: . . degi1"OOft 0.00 0.53 0.53 9.00 9.00 45.02 45.02 45.02 45.02 45.02 45.02 45.02 45.02 45.02 45.02 -454.45 45.02 -437.93 45.00 -417.24 45.00 -394.25 45.00 -369.85 45.00 -353.23 45.00 -344.95 12.00 -320.09 12.00 -295.32 12.00 -270.74 12.00 -246.39 12.00 -222.36 12.00 -198.69 12.00 -175.47 12.00 -160.24 12.00 -152.75 12.00 -130.60 12.00 'TFO" 'deg 0.00 64.76 64.02 52.65 50.35 Tool' TIP MWD KOP C MWD 3 52.66 MWD 36.84 MWD 20.18 MWD 14.03 MWD 11.03 MWD 9.37 MPC-26A 8.62 MWD 8.42 MPC-26A 7.93 MWD 7.91 MWD 7.74 4 84.00 MWD 84.10 MWD 84.42 MWD 84.96 MWD 85.69 5 101.00 MWD 101.08 MWD 101.30 MWD 101.48 MWD 101.64 MWD 101.76 MWD 101.86 MWD 101.92 MWD 101.95 6 94.00 MWD 94.00 MWD 0 BP ) II". 8AK.. .:,::'",':' t~r· MUGHlS :\.,;;);: ." :} Baker Hughes INTEQ Planning Report ..........,...................,...........,..................... J.N'l' ßQ Company: BP Amoco Date: 4/16/2003 Time: 15:40:39 Page: 3 Field: Milne Point Co-ordinate(NE) Reference: Well: MPC-26, True North Site: M Pt C Pad Vertical (TVD) Reference: System: Mean Sea Level Well: MPC-26 Section (VS) Reference: Well (O.OON,O.OOE.96.ooAzi) Wdlpath: Plan#6 MPC-26A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD loci Azim SSTVD N/S EIW l\fåpN >M.pE VS <>DLS TFO.' Tool· ft deg deg ft ft ft ft ft ft deg/100ft deg 7550.00 89.38 128.11 6945.22 1027.37 -1.71 6030394.46 558031.29 -109.09 12.00 93.98 MWD 7575.00 89.17 131.10 6945.54 1011.43 17.55 6030378.68 558050.67 -88.27 12.00 93.95 MWD 7600.00 88.97 134.10 6945.94 994.52 35.95 6030361.91 558069.20 -68.20 12.00 93.92 MWD 7625.00 88.77 137.09 6946.44 976.66 53.44 6030344.19 558086.83 -48.95 12.00 93.87 MWD 7650.00 88.57 140.08 6947.02 957.92 69.97 6030325.58 558103.50 -30.55 12.00 93.81 MWD 7675.00 88.38 143.08 6947.68 938.34 85.49 6030306.13 558119.18 -13.06 12.00 93.74 MWD 7700.00 88.19 146.07 6948.43 917.98 99.98 6030285.88 558133.82 3.47 12.00 93.66 MWD 7701.69 88.18 146.28 6948.49 . 916.58 100.92 6030284.49 558134.77 4.56 12.00 93.57 7 7725.00 86.03 144.48 6949.66 897.42 114.14 6030265.44 558148.14 19.71 12.00 220.00 MWD 7750.00 83.74 142.53 6951.89 ../ 877.41 128.95 6030245.54 558163.11 36.53 12.00 220.09 MWD 7775.00 81.46 140.57 6955.111" ~ 857.99 144.36 6030226.25 558178.67 53.89 12.00 220.26 MWD 7800.00 79.18 138.59 6959.32 839.23 160.34 6030207.62 558194.79 71.74 12.00 220.52 MWD 7825.00 76.92 136.57 6964.49 821.18 176.83 6030189.69 558211.42 90.03 12.00 220.85 MWD 7850.00 74.67 134.52 6970.63 803.88 193.80 6030172.53 558228.52 108.71 12.00 221.27 MWD 7875.00 72.45 132.43 6977.70 787.38 211.20 6030156.17 558246.05 127.74 12.00 221.77 MWD 7900.00 70.24 130.28 6985.70 771.73 228.97 6030140.66 558263.94 147.05 12.00 222.36 MWD 7914.69 68.96 128.99 6990.82 762.95 239.58 6030131.96 558274.61 158.52 12.00 223.05 8 7925.00 69.82 128.04 6994.45 756.94 247.13 6030126.01 558282.21 166.65 12.00 314.00 MWD 7950.00 71.93 125.79 7002.64 742.75 266.01 6030111.98 558301.20 186.92 12.00 314.33 MWD 7975.00 74.07 123.58 7009.95 729.15 285.67 6030098.53 558320.96 207.89 12.00 315.07 MWD 7975.17 74.08 123.57 7010.00 729.06 285.80 6030098.44 558321.10 208.03 12.00 315.72 MPC-26A 8000.00 76.22 121.43 7016.36 716.17 306.05 6030085.71 558341.44 229.51 12.00 315.72 MWD 8025.00 78.40 119.31 7021.85 703.84 327.09 6030073.55 558362.57 251.73 12.00 316.27 MWD 8050.00 80.59 117 .23 7026.41 692.21 348.74 6030062.08 558384.31 274.47 12.00 316.74 MWD 8075.00 82.80 115.17 7030.02 681.29 370.93 6030051.34 558406.59 297.69 12.00 317.12 MWD 8100.00 85.01 113.13 7032.68 671.12 393.61 6030041.35 558429.34 321.30 12.00 317.41 MWD 8125.00 87.23 111.11 7034.37 661.73 416.72 6030032.14 558452.52 345.26 12.00 317.63 MWD 8150.00 89.45 109.09 7035.10./ 653.14 440.18 6030023.73 558476.05 369.50 12.00 317.77 MWD 8161.49 90.47 108.17 7035.10 'ß 649.47 451.07 6030020.15 558486.96 380.71 12.00 317.82 9 8175.00 90.64 106.55 7034.97 645.44 463.96 6030016.22 558499.89 393.95 12.00 276.00 MWD 8200.00 90.95 103.57 7034.63 638.94 488.10 6030009.91 558524.07 418.64 12.00 275.98 MWD 8225.00 91.26 100.59 7034.14 633.72 512.54 6030004.88 558548.55 443.49 12.00 275.94 MWD 8250.00 91.57 97.60 7033.52 629.77 537.21 6030001.12 558573.25 468.44 12.00 275.89 MWD 8275.00 91.87 94.61 7032.77 627.11 562.06 6029998.66 558598.11 493.43 12.00 275.81 MWD 8300.00 92.17 91.63 7031.89 625.75 587.00 6029997.49 558623.06 518.38 12.00 275.72 MWD 8325.00 92.46 88.64 7030.88 625.69 611.98 6029997.63 558648.04 543.22 12.00 275.62 MWD 8350.00 92.74 85.65 7029.75 626.93 636.92 6029999.07 558672.97 567.90 12.00 275.50 MWD 8375.00 93.02 82.66 7028.50 629.48 661.75 6030001.80 558697.78 592.33 12.00 275.36 MWD 8400.00 93.29 79.67 7027.12 633.31 686.42 6030005.83 558722.41 616.46 12.00 275.21 MWD 8425.00 93.54 76.67 7025.63 638.43 710.84 6030011.14 558746.79 640.21 12.00 275.05 MWD 8450.00 93.79 73.68 7024.03 644.81 734.96 6030017.71 558770.85 663.53 12.00 274.87 MWD 8475.00 94.03 70.68 7022.32 652.45 758.70 6030025.52 558794.53 686.34 12.00 274.68 MWD 8500.00 94.26 67.68 7020.52 661.31 782.00 6030034.57 558817.76 708.59 12.00 274.47 MWD 8525.00 94.48 64.68 7018.61 671 .37 804.80 6030044.81 558840.48 730.22 12.00 274.25 MWD 8550.00 94.68 61.68 7016.61 682.62 827.04 6030056.23 558862.63 751.15 12.00 274.03 MWD 8575.00 94.87 58.67 7014.53 695.01 848.65 6030068.78 558884.14 771.35 12.00 273.79 MWD 8600.00 95.05 55.67 7012.37 708.51 869.57 6030082.45 558904.95 790.75 12.00 273.54 MWD 8625.00 95.22 52.66 7010.13 723.09 889.76 6030097.18 558925.02 809.30 12.00 273.27 MWD 8630.00 95.25 52.06 J 726.13 893.70 6030100.25 558928.94 812.90 12.00 273.01 TD 7009.67 t 1~ O::;;.·.·.·).:.··t1f:·:·,~ ... f"'" C;ompany: B P Amoco Field: Milne Point RefereDce Site: M pt C Pad Reference WeD: MPC-26 RefereD~e WeUpath: PJan#6 MPC-26A ) BP ) Anticollision Report Date: 4/16/2003 Time: 15:32:18 Rii8 811I.. ..... .,.......~................. .......,....................... IN'l'I1.Q Page: 1 Co-ordinate(NE) Reference: Well: MPC-26, True North Vertical (TVD) Reference: 47: 26 617/199611:4446.3 Db: Orade GLOBAL SCAN APPLIED: All well paths within 200'+ 100/1000 ofreference Interpolation Method: MD + Stations Interval: 10.00 ft Depth Range: 6970.00 to 8630.00 ft Maximum Radius: 1060.05 ft Reference: Error Model: Scan Method: Error Suñace: Plan: Plan #6 & NOT PLANNED PROGRA I ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Casing Points MD ft 115.00 4704.00 6970.00 8630.00 TVD ·ft 115.00 4637.18 6871.53 7055.97 Diameter in 20.000 9.625 5.000 2.875 Hole Size in 26.000 12.250 6.000 3.750 PlaD: Plan #6 New targets due to reservoir dip. Principal: Yes Summary 4i': ~të M PtC Pad M PtC Pad M PtC Pad M PtC Pad Site: M Pt C Pad Well: MPC-01 Wellpath: MPC-01 V1 :Reference' MJj '. TVD : ft . ft 8175.00 7081.27 8175.00 7081.27 8175.00 7081.27 8175.00 7081.27 8175.00 7081.27 . O«sefW..lpath . ·:·WeD·.·.· .' MPC-01 MPC-10 MPC-20 MPC-26 : .:. Offset MD TVD . . '. 11: ·ft 6330.00 6323.04 6340.00 6332.95 6350.00 6342.86 6360.00 6352.77 6370.00 6362.68 8175.00 7081.27 6380.00 6372.60 8175.00 7081.27 6390.00 6382.51 8175.00 7081.27 6400.00 6392.43 8175.00 7081.27 6410.00 6402.36 8175.00 7081.27 6420.00 6412.28 8175.00 7081.27 6430.00 6422.21 8175.00 7081.27 6440.00 6432.14 8175.00 7081.27 6450.00 6442.08 8175.00 7081.27 6460.00 6452.01 8175.00 7081.27 6470.00 6461.95 8175.00 7081.27 6480.00 6471.89 8175.00 7081.27 6490.00 6481.84 8175.00 7081.27 6500.00 6491.78 8175.00 7081.27 6510.00 6501.73 8175.00 7081.27 6520.00 6511.68 8175.00 7081.27 6530.00 6521.63 8175.00 7081.27 6540.00 6531.59 8175.00 7081.27 6550.00 6541.54 8175.00 7081.27 6560.00 6551.50 8175.00 7081.27 6570.00 6561.46 8175.00 7081.27 6580.00 6571.42 8175.00 7081.27 6590.00 6581.38 8175.00 7081.27 6600.00 6591.35 . ;>. 'WeUpatb MPC-01 V1 MPC-10 V1 MPC-20 V1 MPC-26 V5 .~~ ^ Ii) & IA(,~ IV dOS {.I 1(0 ~ Date Compos~l2oo3 Version: 4 Tied-to: From: Definitive Path Name 20" 9 5/8" 5" 27/8" . . . ". Reference . Offset MD "MD ft ft 8183.07 7020.00 . CtT~tr· 'No-Go . Distance Area ft· ft 814.94 102.78 6970.00 6970.00 0.00 0.00 'Seml';;Major Ads . . Ref : OUset 'TFO+AZI 'fFOøHS' Casing ft· ft deg· deg . in 12.35 8.66 152.80 46.25 12.35 8.69 153.24 46.68 12.35 8.71 153.68 47.12 12.35 8.74 154.12 47.57 12.35 8.76 154.57 48.02 Rule Assigned: Inter-Site Error: Qr-Ctr No..Go· Distøœ .l\iea· ft . ft' 1054.18 101.15 1048.17 101.36 1042.22 101.44 1036.34 101.52 1030.52 101.58 12.35 12.35 12.35 12.35 12.35 12.35 12.35 12.35 12.35 12.35 12.35 12.35 12.35 12.35 12.35 12.35 12.35 12.35 12.35 12.35 12.35 12.35 12.35 8.76 155.03 8.76 155.49 8.76 155.95 8.77 156.42 8.77 156.89 8.77 157.36 8.77 157.85 8.77 158.33 8.77 158.82 8.77 159.32 48.47 48.93 49.39 49.86 50.33 1024.75 101.59 1019.03 101.59 1013.36 101.60 1007.73 101.60 1002.15 101.61 996.62 101.62 991.14 101.62 985.71 101.63 980.34 101.63 975.02 101.64 969.75 101.62 964.55 101.60 959.40 101.57 954.33 101.55 949.31 101.53 944.36 101.51 939.48 101.49 934.66 101.47 929.92 101.45 925.24 101.43 920.63 101.41 916.10 101.39 911.65 101.37 50.81 51.29 51.78 52.27 52.76 8.77 159.82 8.76 160.32 8.75 160.83 8.74 161.35 8.73 161.87 53.26 53.77 54.28 54.79 55.31 8.73 162.39 8.72 162.92 8.71 163.46 8.70 164.00 8.70 164.54 8.69 165.09 8.68 165.65 8.68 166.21 55.84 56.37 56.90 57.44 57.99 58.54 59.10 59.66 ,I Major Risk 0.00 ft . Allowab~ ne"iatiOn Warning . .' ft . 974.87 Pass 968.52 Pass 962.23 Pass 956.00 Pass 949.84 Pass 943.78 937.77 931.80 925.88 920.01 914.18 908.41 902.68 897.01 891.39 885.85 880.38 874.96 869.56 864.20 858.91 853.68 848.51 843.42 838.40 833.44 828.57 823.77 Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Tree: 2 9/16" - 5M FMC Wellhead: 11" 5M FIV ) wI 27/8" FMC Tubing hunger, EUE lift threads, 2.5" CIW H BPV profile 20" 91.1 ppf, H-40 I 115' I . KOP @ 500' Max. hole angle = 9 to 11 deg. fl 1100' to 7100' Hole angle thru' perfs. = 9 deg. No DLS > 2.7 deg 1100' 9 5/8", 40 ppf, NT80LHE Btrc. I 4704' 27/8" 6.5 ppf, L-80, 8 rd EUE tbg.. ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, Btrc. production casing ( drift ID = 6.151", cap. = 0.0383 bpf) 5" 14.9 ppf , NT13Cr80 FL4S (drift = 4.283", cap. = 0.0188 bpf) Stimulation Summary 05/22/96 - 'A' Sand - 95.4 M# 16-20 Carbo lite behind pipe, went to flush. Tailed inproppant wI 0.15% "Propnet". Perforation Summary Ref log: 1/12196 AlIas GRlCCL (TVD) SIZE SPF INTERVAL 'C' Sand 3.375" 6 6966' - 6976' 'B' Sand 3.375" 6 7032' - 7052' 'A' Sand 3.375" 8 7119'- 7173' (6869' - 6879') . ,I ,I (6934' - 6954') ~ / / (7007' - 7061 ') ~ MPU C-26 . ~ ~ I ..... ~ ¡~¡¡Inr~ I~~ I ..=':::~ ~ '::~it ~~ I :: :::::: ~ ~:' ::.::~ ~ '~':'~~t I : :.':::- ~ ::!:d:~ ~ "~5~~ :~~ ~ .:I~I ~ .;~f.~ ~ . ~t~~~ I ':~:'",:,: I .::t, ~:~~ , J'~~ :,,:d 'tin ¡ >:A IL~ ; . :.~":~i ~ ·.:::íf:r: I ::.".:::::;: I . :::., :~~3 I~ ~ :'¡:¡i¡¡1i¡il Orig. DF Elev. = 45.4' (N 22E) Orig. ("'fv. = 16.7' DF To '--~l hng. = 28.5' (N 22E) ... Camco 2 7/8" x 1" side pocket KBMM GLM 141' ~ ·;:~$~X· ~........w& I \~~_tl ,. ;;....%:~ ~~·W 1-112" CTU Jet Pump Completion 1-1/2" CT Data: Wall = .109, 1.623#/ft. HS-70, 10 = 1.282" Capacity = 1.6 bls/1000' , GXIsttr.S WLS jet pump receptacle WLS Jet Pump TVD WLS Retreivable Double Grip Pkr. 6472 ' 6391' 6481' 1 t I Shot 4' interval (10 holes) at 6550'-6554'. Centrilift GC 1150 ESP, series 513, GPMTARC 1 :5, 135 Stg. Centrilift GRSTXBARH6 gas separator Centrilift GSTDBHL seal section Centrilift KMH 562 series, I 133 hp motor, 2205v./37 amps. 6576' 6592' 6598' 6611' Centrilift PHD lib :" 5"14.9 #/ft L-80 FL4S Liner : top : 7" float ~ shoe ¿.. 4J í Radioactive marker at 6472' wlm. 6625' 6727' 6882' ... I r A ,. / I , ·Landing collar ~ 5" Casing Shoe 7356' 7444' DATE REV. BY COMMENTS MILNE POINT UNIT 2/17/96 DLH Drilled and cased by Nabors 22E WELL C-26 06/15/96 JBF Initial Completion by Nabors 4 ES API NO: 50-029-22638 01/01/98 M. Linder RWO 5-ES 09/16/01 B.Hasebe Jet Pump completion and flow schematic BP EXPLORATION (AK) Tree: 29/16"-5M FMC '. MPU C-26 L 1 Wellhead: 11" 5M FMI -) wI 27/8" FMC Tubing hw. ....~r ,EUE · lift threads, 2.5" CIW H BPV profile Whipstock tray removed after CTD liner run ~ " . , I , 5" Whipstock packer ~: _ '~, J at 6980' md. Tray '1_:1\:7 removed, 2.5" ID 16 20" 91.1 ppf, H-40 I 115' I J KOP @ 500' Max. hole angle = 9 to 11 deg. fl 1100' to 7100' Hole angle thru' perfs. = 9 deg. No OLS > 2.7 deg 1100' 9 5/8", 40 ppf, NT80LHE Btrc. I A 4704' 7" 26 ppf, L-80, Btrc. production casing (drift ID = 6.151", cap. = 0.0383 bpf) ~ 5" 14.9 ppf , NT13Cr80 FL4S ~ Y. ( (drift = 4.283", cap. = 0.0188 bpI) ~ Orig. OF Elev. = 45.4' (N 22E) Orig. G""Y = 16.7' OF To (,.. ,"g. = 28.5' (N 22E) .þ" .;.:.:.w~ :¡::¡~¡¡¡¡~~¡ ~. .. froposed .þ': :::::::~::::~ }:~::::::..p ::::::::::::::~ , ~ ~E~~bing with mr:/ .:.:.:,.;.:-=~ :¡:¡jfj' :.:.:.:.:.:.:~.. ~ Jet pump receptacle ;0 ~813" X nipples above ~ / and below packer _/ /3112"X7"BakerS3paCker :8: :8: WLEG stabbed into liner tie back sleeve lZ 5" 14.9 #/ft L-80 FL4S Liner I 6727' ~ 7" float shoe I 6882' window at 6970' TOL at -6980' md [ 3 3/4" openhole 33/16" & 2 7/8" pre-drilled liner ] MPC-26 L 1 Perforation SUrTJ11ary Ref log: 1112196 AItas GRlCCL SIZE SPF INTERVAL (TW) ~ ~ 'e Sand 3.375" 6 69:ß - 6976 (fJ!ijg - 6879') '8' Saro 5" Casing Shoe 3.375" 6 7CßZ - 7rJ5Z (æ34' - 69)4') I 7444' I 'ft; San:f 3.375" 8 7119 - 7173' (1001' - 70011 0000 0000 0000 I ~ 8630'md 3 3/16" X 2 7/8" XO at 7200' md DATE REV. BY COMMENTS 2117/96 nlH Drilled and cased bv Nabors ??F MILNE POINT UNIT 06/15/96 JBF Initial Completion by Nabors 4 ES WELL C-26 RWO 5-ES API NO: 50-029-22638 01/01/98 M. Linder 09/16/01 B.Hasebe Jet Pump completion and flow schematic BP EXPLORATION (AK) 4-1-03 MOJ Proposed CTD sidetrack Ver. 2 ) r "- ~ Choke line I HCR valve ----r:::/) - ---r:::/)- - --1.6L - --1.6L - ~ ~ I, 1 2c=0~ I MOJ 4/9/03 ') Nordic 2 workover BOP stack "' 13 5/8" annular preventor .J ~ blind ram 0.13 ~~:B~P Kill line ~0=0Ch~~ o 135/8"BOP o 1 /1 2 7/8" x 5 1/2" VBR ~ pipe ram ~ 2 3/8" pipe ram 11" tubing head - ----,<:::;T - ----,<:::;T - -~-~- I r ---r:::/) - ~ --1.6L - ) "') 7" riser to rig floor I I r 7 1/16" annular preventor '- c:q c:::q l 071/16" QBOP I c::q c::q 071/16" () BOP ~xos \ / 71/16" x 13 5/8" \ \ HCR valve - ---r:::J\ - ---r:::J\ - -~-~- Choke line 13 5/8" ~ ~ o 135/8"BOP o I, I 2c==®~ I 11 .. tubing head MOJ 4/18/03 ""'\ Nordic 2 workoverlsidetrack BOP with CoilTrak pressure deployment capability J Þ= Blind/shear combi ram Þ= 23/8" pipe/slip combi ram Þ= 2 3/8" x 3 1/2" VBR pipe ram þ::::. 3" slip ram ~ ~=®==®Ch~~ Kill line 2 7/8" x 5 1/2" VBR ~ pipe ram ~ 2 3/8" pipe ram / I - ---r:::J\- ---r:::J\ - -~-~- - ---r:::J\ - 1- ~ - ROP TestinQ Options through 7" ROP a) Hanger wI TWC (possible ID constraints) b) RTTS or retrievable packer for casing <7" c) IBP > T when no hanger solution ) ) " c9ð3-ö70 l' ~~!Æ~E ~, f !Æ~!Æ~~~!Æ FRANK H. MURKOW5KI, GOVERNOR ~J A..,A.SIiA OIL AlWD GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 April 24, 2003 BP Exploration, (Alaska) Inc. Prudhoe Bay Unit P.O. BOX 196612 ANCHORAGE, AK 99519 Re: Permit to Drill Fee - MPC 26L 1 Enclosed is your check # P055051 for the permit fee for Well MPC 26L 1. Please refer to 20 MC 25.005 (e). This is a lateral permit that does not require the $100 permit fee. Sincerely, ~,o. ~ Linda S. Berg Administrative Manager Enclosures II- 0 5 50 5 ¡ II- I: 0'" ¡ 20 3 a q 51: 0 It 2 ? a q bill . DATE:(> AMoUNT -.- . . -. - - "-0 _ . n u ._ __ _.' .....-- .-.- - - - .;-'" Apttf4, ?Ø.P~<': ***t~t*$'1 00.00******* ALASKA OIL &iGÂ$ CONSËRVÃTIOt\J C(I§MMrSSION':·'.:;·;' . ..' . .,...... .'. 333'W··' 7t···ijAV.:·:'E·':N· ")E": ..... .... ., :':,o;::;:::u.. ········N9-r:VALln.:A~R.~?n~t-y§..:...' " . .. .:;. ., :"'1'. :!4I" "'" . l~':......................,~.........~...~:......... ..of''''"} .....~:···..Io..· "H' SUITE 1 OO·:i». '.. . ,"~::'- ¡..:..::. ..\'.::. ..:.:..:.:.:.~:.,~.,.. ··b·"~\\ .~::: ..:.:.:....~.: '.:'\ ......'.,-. -....,::'.,.,: .:> .. -. ....-...:;--- :....:.:~... -"-'.' .:.-. - .....;. .......,.......~:....~:....~....... ANCHORA~E~Äk 9~501-3539,/:";:?:\;:-:':', . ...... .--....:.\::.:..... ..... ~.~_..\.~' . ¿/i:~::: :~~:~·:·::;~.-~·,·-.:~.::~;þf~Z:~~;·h:~~~~~?~:~ .~?~~:: ;'::\ ~:.~ TO THE ORDER OF: .~ B l!J .. '. . ~:.. 0 ¡t.. ~4~1~_;!!~;::,~·:~;:~' . f:~;~~ -:.:;¡!,; BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE:, AK995J9-6612 PAY: CONSOUDATED COMMERCIAL ACCOUNT 56-389 4'1"2 NATIONAL CITY BANK Ashland, Ohio No. p 055051 TOTAL ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. All ska Oil & Gas Cons. Co mnission Anchorage RECEIVED APR 2 22003 ~ \Y'~C J;2<PCt H PERMIT TO DRILL FEE 4/4/2003 INV# CK040103A NET DISCOUNT GROSS DESCRIPTION. INVOICE I CREDIT MEMO DATE VENDOR .~ tÁ a- /4 ~J< ßv 2.bA-//C 2E>,.OOS.(e.) -f{~ ¡/OD tf-e.¿. i<;) ~v;¿¡¿. -P~ re-~ ck..cL /D tp. DATE CHECK NO. ~ 4/4/2003 055051 /~~ 1·23·03 p 055051 ) ) 72. Temporary shutdown of drilling or completion operations 75. Other wells in designated areas 80. Annular disposal of drilling waste ~o AAC 25.005 PERMIT TO DRILL. .".,--- (a) Before drilling or redrilling a well or re-entering an abandoned well, a person shall submit and obtain the commission's approval of an application for a Permit to Drill (Form 10-401). It: after drilling a well, a person wishes immediately to redrill below the structural or conductor casing to a new bottom-hole location not requiring a spacing exception under 20 AAC 25.055, the person may request oral approval from the commission to avoid interruption of operations. If oral approval is obtained, the name of the representative of the commission who provided oral· approval 'and the date of the· approval must be included on the application for a Permit to Drill, which must be submitted by the commission's next working day for final approval by the commission. (b) The commission will classify a well as (1) exploratory; (2) development, either oil or gas; (3) service; or (4) stratigraphic test. ( c) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (1) a fee of$100 payable to the State of Alaska/AOGCC; (2) a plat identifying the property and the property's owners and showing (A) the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines; (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the. top of each objective formation and at total depth; and (D) other information required by 20 AAC 25.050- (b); (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; ( 4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; (B) data on potential gas zones; and 2 I I I I I I I I I I I I I I I I I I I ) \ , (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030 (t); (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre-perforated liner, or screen to be installed; (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035 (h)(2); (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033 (t); (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061 (a); (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061 (b); (12) evidence showing that the requirements of20 AAC 25.025 have been met; (13) a copy of the proposed drilling program; (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the . operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well. (d) For a well that is to be intentionally deviated, the requirements of 20 AAC 25.050 (b) must be met. (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface, or production casing, the applicant shall designate one branch as the primary wellbore and include all information required under (c) of this section with the application for a Permit to Drill for that -branch. For each subsequent well branch, the application for a Permit to Drill need only include information under (c) of this section that is unique-to that branch and need not include the $100 fee. (t) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. (g) If drilling operations are not commenced with 24 months after the commission approves an application for a Permit to Drill, the Pennit to Drill expires. 3 p055051 ./f!~ úJ c¿ /4 k-ð. !1-v.2.b,4/lC 25>-,.OOS:(e.)/J-II<-<- f; jOD 7f.¿¿ t<J A.xYv~· -P~~ r£k~VIA- ck-cL 'þ ÞP. DATE CHECK NO. ~ ' 4/4/2003 055051 /~ ,/.¿3·05 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 4/4/2003 INV# CK0401 03A PERMIT TO DRILL FEE H fY\~C -2~Lt ,-=," RECEIVED APR 2 22003 AI, ska Oil & Gas Cons. Co 11rt1ission Anchorage THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 NATIONAL CITY BANK Ashland, Ohio 56-389 412 No. P 055051 CONSOLIDATED COMMERCIAL ACCOUNT . / AMOUNT ****'~**$1 00.00******* PAY: .." ." -.-. .- ". . - -- . . -. ." . . - - . ;:::.' .-.- :----..-.." .".-.- .-. .-'-." ;:;:::.:-" :. :-; -' ---- - ,_.._ __n. B fRu r:~ Z... .J9l'. . J"Ih¡ . ...., ""J t.UO . ..:'. . ':!JtQi;ì~I.4...,' l....{ ç,·s.· . :-'.-.: -. _ .' fl t- :_.-.:>_ I _ - _ .__ :_:~in"fI ....nn;._ ..lth .. TO THE ORDER OF: . .. .- - . : -.: - - " - -. " - - ~-- ',' '.:. -:-.-;:-. - - . "'. . .- .-- .- -- ...... ...... - - ---'. . --- - ---". ..' .............. . ........ .'. ....'--..--- .--...---.... ....... ..... , .-.-- --- -.- --'-:.-,:-, .... - -.-- - -- - -- ALASKA OIL &G.A.S C()NSE~\.fì\TIOtN C(Jfv,1MIŠ$ION( 333 W 7TH A V¡:NLJE SUITE 100. '. ..... ANCHORAGE;AK 99501-3539 N~VA0fK?~::;~~~~\ìzJt~~~~:;~ti;\:;t~ u.. ..... ~.::i~~4::.. .·.H. ..... ...... ...... ...... . Úé'(iS;'fr07~~!!~j~~;}¡:~;;;~;~iS~'~ 1110 5 50 5 ~ III I: 0 ~ ~ 2 0 ~ 8 ~ 51: 0 ~ 2 ? 8 ~ b 1111 ) ') TRANSMITAL LETTER CHECKLIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME IYlP{!- 20 L/ PTD# 20 _3 - D70 ADD-ONS /(OPTIONS) /l\ÍULTI ,,// LATERAL V (H API number last two (2) digits are between 60-69) CHECK WHAT APPLIES "CLUE" The permit is for a, new wellbore segment of existing well (!-- Z-~ . _. 4 -22t~ 3 d_öO Permit No, /I)f!- ZO/¡., API No. ~D 02 I . T . Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). Pfi.¡OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 ajody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST; Company J~P_I;X~.L.PB.A-lJ.oN (ALASKA) INÇ Well Name: MILNE PT_UNIT KR C-26L, 1 Program JII;V Well bore seg PTD#:2030760 Field & Pool MILNE POINT, KUPARUK RIVER OIL - 525100 Initial ClasslType DEV 11-0J~GeoArea 890 Unit 11328 On/Off Shore On Annular Disposal Administration 1 P~rrnitfee attache.d. . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . .. . _ . . . . . . . _ _ . . Y~s . . . _ _ . . I?er .20 MC .25.0Q5.(e). thi~ is. a. "~ub_sequ~otweH ÞratlGh~".and th~ .$j QO.fee i~ .notrequired; reJurlJ check.. . . . . . 2 .Leas~.m.HJlber .appropriate. . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . Y~s . . .. . . . . . . . . . . . . - . . . . . . . . . . . . . . . . . . . . . . . " . " . . . . . . . . . . . " . . .. . " . . . . . . . . . " . . . . " . 3 .unique welt n"am~ .atld lJumb"er . . . . . .. .. . . . . . . . . " " . . . . . . . " . . _ . . . . . . . " " _ Y~s . . . . . " . . . . . . . . . " . " - - - - . . . . .. . . . . . . . . . " " . . . . . " . . . . . . - . . . . . . . . . . . . . . . .. " . . . . . " . 4 .WeIlJQcat~d in.a.d.efine.d.pool. .. " . . . . " . . . . . . " " . . . . . . . " . " " . . . . . " . . . . . . Y~s . . . . . . . . . _ . . . . . . . . " . . " - . . . . " . . . .. . . . . . " . . . . . . . . " " . . . .. . . . " - . . . . . . " . . " . . 5 .Well JQcat~d prPPer .distance.from. qriJling unit. bpl,lndalY. . . . . . . . . . . . . . . . . . . . . .. . . Y ~s . . . . . . . . . . . . . . . . . . " . . . . " . . . . . . . . . . - . . . . . . . .. . . . . . .. . . . . . . . . . . . . . .. . . . . . . . . . . . . 6 .Well JQcat~d prpPer .distance. from. QtbeJ w~lIs. . . . . . . . . . " " . " . _ . . . . . " . . . . . . . . Y~s . . . . . . - - " . . .. ... - . - " - . . . " - - . . . . . . . . . " . .. .. . . " .. . . . . . . . .. . . . . . . . . - . - . . . . . - . . . . . 7 .S.utficient acreage.ayailable Î.n.drilJiIJ9 unH. _ . " . . .. . " . . . . . . . . . _ . . . . . . _ . . . . . . Y~s . . " . . . . . _ _ . . . . . . . . . . " _ . . . . . - " . . . . . . . " . . . . .. . " . " . - . . . . . - - - . . . . . . " . . . " . 8 .If.d~viated, is. weJI bQre plat.incJu.deq . _ . . . . . . . . .. . . . . . . . . . . . . _ . . . . . . . . . . . Y~s . . . . . . . .. . _ . .. . . . . . . . . . . . . . . . . .. .. . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . - . . . . - . - . . . . . . 9 .Operator ol1ly- affected pa.rty. . . . . . . . . .. . . " . . . . . . . . _ . . . . . . _ " _ _ . . . Y ~s _ " " _ _ _ . . _ " . - - . - . . . . . . . . . . . . . . . .. .. . . . . . . . . - . . . . . - . . . . . . . . . . . . . . . . .. . . . . . . . . . . . 10 .Operator bas.appropriate. Qond in JQrce .. . . _ _ . . _ . . . . . . . . . . . . . .. . _ . " . . _ . . . . Y ~s .. . . . . . . . . . . . .. . . . . . . .. . - . . . . . - . . . . . . . . . . . . " . - . . . . . . . . . . . . . . . . . . . . . . - - . . .. . - . " . 11 P~rmit c.atl be issued witbQut co.nservaJiOI1 Qrder. . . . . . . . . . . . . .. . . . . . " . . . . . . . . Y~$ . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . " " " " . . . . . . " " - " - " - " - Appr Date 12 P~rmit c.ao be issued witbQut ad.mini~trati'le.approvaJ . . . .. . . . . . . . . . . - " - - - . . . . . . Y~s - . . . . - - . - . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . " . . . . . . . . . . " . . " SFD 4/23/2003 13 .C.ao permit.be apPJQved before .15-day.. wa.it. . . . . . . . . . . . . . . . . . . . . - . . . . . . . . . Y~s . . . . . . . . . . . . . . " . . . . - . . . . . . . . . . . .. . " . . . . . . . . . " . . . . . . . . . . . . . . . . . . . . . . " " . . . .. . . . 14 .WellJQCÇltød wiJhil1 area artd"strataauthQrizeq by.lojectiolJ Ordør # (put.lO# in"cpmmøotsUFQr. NA . . . . . . . . . . . . . . " - .. . " . . . . . .. . . . . . . . . . . . " . . . . " . . . . . .. . . . . . . . . . . . - - - . . . . " - - - " - . - - 15 .AU welJs. within.1l4.llJite .are.a.of reyi~w idøotified (For ~ervjcø .w.elJ onlY-) _ _ _ _ " _ . . . _ . . . _ _ NA . . . . _ _ . . . . . . . . . . .. . . . . . . . . .. . . . . . .. . . . . .. . . . . . . . . . . . . . . . . . . . " " . . . . . . . . " . . . . . . . . 16 Pre-produ.ced ioj~ctor; .dl.lraljoRof pr~-.pro.duction løss. than" 3 mOl1ths. (FQr .seryice well Qn!y) . . NA . . . . . . . . . . . . . . . " . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17 ACM.P. F.inding .of CQn.si.steOGy..has bee"n j~sued. for. tbis prpiect " . . . . . . . _ . . . . . . . . . . NA . . . . . .. . . . . . . . . " " . " . . . . . . . . . " . . . .. .. . " . . . . . . . . . . . . . . . . . . . . . . . . - - - - . . - " " " . " - - " 18 "C.oodu.ctor ~trin.g.PJQvj.d~d . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . " . . . . . . . . . . NA _ _ . . . . _ latøra! Qf .e~i$ting w~IJ.. . . . . _ . . . . . " . . . . . . . . . " - . . . . . . . . . . . . . . . . . . . . . . - " . . . . . . . . 19 _S.urfacø.ca~ing.PJQteG.t~all.known.USQW~............"......... _''........ Yøs..".... .Aqujferse~empte.d.40.CF.R 147..102 (b)(3), ....... ."...."............... - - - -..... -.".".. 20 ..C.MT. vpt adequate.to circ.ulate.on.cond"uctor. & ~u.rf.csg . . . . . . . . _ _ _ . . . . . " _ . _ . . . _ NA . . . _ _ _ . latøra! of .e~isting w~IJ.. . . . . . . . . . . " . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . " - . . . . . . . . 21 "C.MT. vpl. ad~qu..ate.to tie-inJQng "striog to"S!,lrJ Ç&g.. " . . . . . . " " " " " " . . . . " " " " " " . . " . NA .. . " . . . .. latera! Qf .e~i$ting w~IJ." " . " . . . " . . . . . . .. " " " " .. . . . . . . . . " . .. . " " " " . . . . " " " . " . . . . . . .. " .. .. 22 .C.MT.will coyer.all KlJo.w.n.pro.dI.lGtiYe bQri~Qn.s. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . No. . . . . . . _ ~Iotted Iiller plalJn.ed.. . . . . . . . . . . . . . . " . . . . . . . - . . . . . . . . . . . . . . . . " . - - - . . . . " - . - 23 _Gasiog desi.gtl$ ad.eç¡ua.te for C,.T~ 8.&. p.erllJafrpst. . . . . . _ " _ _ _ _ . . . . _ _ " _ _ _ . . _ . . .Yes _ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . " . " - . . . . " - . . . . . - " - . . . . . . . . . . - .. . . . . . . . 24 Adequate.tan.kage.o.r re"serye pit. . . . . . _ .. . . _ . . . . . . . . . . . . _ . . . . . . _ _ " . _ _ . Y~s . . . . . _ . I;xi~tiOg rig with.ste.el. pits.. No re.serve pit planned.. .WasJe to .Cla.ss 11 well.. . . . " . . . . . . . " - . . - . . . . . . . 25 .If.a. re-drilt bas_a_ 10::-403 fQr aba.ndQnment. beøo apPJQv~d . . . " . . . . . . . . . . . . .. . . . . . NA . _ " . . . . latøra! of .e~i$ting w~I!.. Qriginal.ioteryal.wj.n.ot be. plugged.. . . . . . . . . . " " . . . . . . . - - " - - - - . - . - . . - - 26 .A.dequate.wellbore separation .proposed. . . . . . . . . " " . . _ _ _ _ _ " _ . _ . . _ . . _ . . . . . Yøs _ . _ . . _ . ~Q clos..e.approac.h js.ssue.identified.. . - " . . . " . . - " . . - . . . . . - " . " . . . . " - " . . . - . - . " . - . . . . . . 27 Jf.div~r:ter .req.uired, dQe~ it me~t reguJa.tiolls. " . . _ . _ . . . _ . _ . _ . . . . . . . . . . _ _ _ _ _ . NA . . _ _. ... - - . - . . . . . . . . . . . . . . . . - . - . . . . . . - - - - - . . . . . - . . . . . - " - - . . . . - . - . . . . 28 .D.ril.IiOg fluid. program sc.hematic.&. eq.uip Jist.adequatø. . . . . " . . . _ . . . . . . . . . . _ _ . _ . Yøs. . . _ . . . I;xpected. SHP up to .9.6.EMW.. PlalJ i.s.tQ us.e.KW (11!,1d or.dyoarnic O'lerb.alaoce.. . - - - - . . . - . - - - - . . 29 S'OPJ::s,.dp.theymeetreguJa.tioll..........." _. _. _ _ _ _ _. _ _ ...... _ _. _ .Yøs_ _ _ _.. .~Qrdiç2will.e!TI.Pl.oYÇlwor:ko'lerstaGk.topl!lI.anc;lru.nJl!bjn.g"andtheçoil.s.tac!<to.Qrill........ -.. 30 .S.oPJ::.pre.ss ra.tiog appropriate; .testtO.(pu.t psig in.comments)_ _ . . . _ . . . _ _ _ . . . . . . . . Y~s . . . . . . . MAS!? e~tim.ated at 2800 psi.. PlalJ i.s_tQ tøsUQ 3500 psi.. . . - . - . . . - . . . . " - - . . - . . - . . . . . . - . . 31 .C.hoke.manifQld ÇQrnpJies. w/API.RP-53. (May 84). . ~ . . . " _ _ . . . . . . . . . . _ _ . . . . . . . .Yøs _ " . . . . . . . . - . . . . . . . . " . - . . - . . - . - . - . . . . . . . - - . - . . . . . . . . . - - - - - - - . - . - - - - 32 WQrk will OGc.ur without "operation .sbutdQwn. _ . _ _ . . . _ _ _ _ . . _ . . _ _ _ _ . _ _ _ _ _ Y ~s _ _ . _ . . . . . . - . . . . . " - . . . . . . . . . - . . . . . . . - - . . . . - . . . . . . . . . . . . - - . . . . . - - . - . . . . . . . . . . 33 .Is pres.ence. Qf H2S gas. prob.able. . . . . . . . . _ . _ . . . . . . . . . " . . . NA. _ _. . _ Mud. should pr_eclude. H2S. o.n .the_ rig. .Rig has $enSor~ .aod alarms.. . . . . . . . - 134 __ .Mee~anical.coodjti.on o{ ~:~~~ within AOß verified. (For. service w~IJ QnJy:). . . . . . . . " _ _ . _ _ NA . . . . . . _ .. -......". - . . . . . - - . . . . " . . . . . . . . . - - - - . - . 135 Permitcao be issued wlQ hydrogens.ul.fide meas~res _ . . . . _ . . . . . _ . No. . H2S ha$.been. mea.sured inK.up production wells OIJ this.p_ad.Ç-26 measured 5 ppm H2S in. May, '00 (2_y~ars agQ Date 136 D.atapreselJted on. pote.ntial overpres.surø .zone~ _ _ . . . . . . . . _ . . . . . . . . . . . Yøs . . . MaximullJ re~ervQir.pressure e~p.ected is _9..6.ppg EMW.. . . . . " . . . . - - - . - - Appr 137 .Søi.smic.analys.is. Qf ~haJlow gas_zones. _ _ _ . _ _ . _ . _ _ . . NA . . . . . . . . . . . . . _ . . . - . . . - . - - - - . - SFD 4/23/2003 138 S~abed .conditioo survey .(if off-shore) . . _ . NA _ . . . . . . . \39 . CQntact na!TI.elphQne.forwe~kly progress reports [exploratory 9nlYl . . . . . . . . . . . . . . . . NA . . - . . . .. .... - . . . . . . . " . ) Engineering Appr Date TEM 4/24/2003 ,. ¡~f;At{~ Geology Geologic Commissioner: o D . ~ - - - - - - - - - - - - - - - - Date: Engineering Commissioner: Public Commissioner Date This lateral will be drilled to produce oil trapped in the shallow portion of a fault block that lies up-qip of the C-10 injection well. It will be drilled using a coiled tubing rig and dynamically overbalanced coiled tubing drilling techniques or kill weight drilling mud. Expected reservoir pressure ranges from 7.1 ppg EMW in the parent well bore up to 9.6 ppg EMW in the fault block containing the C-10 injector. Date ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennilling Process but is part of the history file. To improve the readability of the Well History file and to sim.plify 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. ) ') 2 () "3-0 "7 ç.., 12-5'72- **** REEL HEADER **** MWD 04/07/07 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 04/07/06 498151 01 3.125" GAM and 3.125 USR *** 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 7103.75: STOP.FT 7916.00: 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 #--------- ------------------------- SECT. 10 TOWN.N 13N RANG. 10E PDAT. MSL EPD . F 0 LMF . RKB FAPD.F 46.3 DMF KB E KB . F 4 6 . 3 EDF .F N/A EGL .F N/A CASE.F N/A OSl . DIRECTIONAL -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. 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. MPC -26L1 PB3 Milne Point Unit 70 deg 29' 27.064" N, 149 deg 31' 31.858" W North Slope Alaska Baker Hughes INTEQ 3.125" CoilTrak - GR/USMPR 10-Jul-03 500292263472 Description ------------------------------- 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 ) (2) All depths are Bit Depths unless otherwise noted. (3) All Resistivity and Gamma Ray data presented is realtime data. (4) Baker Hughes INTEQ Utilized CoilTrak / USMPR down hole tools and ADVANTAGE surface system. (5) The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control) curve. Per BPX instructions, the MWD Gamma Ray is the PDC for this wellbore. (6) The well was tied in to a Gamma Ray log from the MPC 26 wellbore at 6735 ft. MD (6593 ft. SSTVD) (7) The sidetrack was drilled from milled window in 5 inch casing. Top of window: 6968 ft. MD (6823 ft. SSTVD) Bottom of window: 6974 ft. MD (6829 ft. SSTVD) (8) An Open hole Sidetrack was performed after this well was drilled at 7500 ft. MD (6989 ft. SSTVD) for the final wellbore, MPC-26L1 (9) The interval from 7886 ft. MD to 7916 ft. MD (6968 ft. SSTVD to 6962 ft. SSTVD) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour RACLX -> Compensated Attenuation Resistivity, 400 kHz Compo & Borehole Corrected [MWD]. Ohmm RACHM -> Compensated Attenuation Resistivity, 2 MHz Compo & Borehole Corrected [MWD]. Ohmm RPCLM -> Compensated Phase Difference Resistivity, 400 kHz Compo & Borehole Corrected [MWD]. Ohmm RPCHM -> Compensated Phase Difference Resistivity, 2 MHz Compo & Borehole Corrected [MWD]. Ohmm CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT Tape Subfile: 1 67 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 COUN STAT MPC26L1PB3.xtf 150 BP Exploration (Alaska), Inc. MPL-26L1 PB3 Milne Point North Slope Alaska *** LIS COMMENT RECORD *** !! !!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control) curve. Per BPX instructions, the MWD Gamma Ray is the PDC for this wellbore. ) ') *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- RPCH RPCH RPCHX 0.0 RPCL RPCL RPCLX 0.0 RACH RACH RACHX 0.0 RACL RACL RACLX 0.0 ROP ROP ROPA 0.0 GRAX GRAX GRAX 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 RPCH MWD 68 1 OHMM 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RACH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 ROP MWD 68 1 F/HR 4 4 6 GRAX MWD 68 1 API 4 4 ------- 24 Total Data Records: 46 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7104.000000 7916.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 59 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 RPCH MWD 68 1 OHMM 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RACH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 ROP MWD 68 1 F/HR 4 4 6 GRAX MWD 68 1 API 4 4 ------- 24 Total Data Records: 91 Tape File Start Depth = 7103.750000 Tape File End Depth = 7916.000000 Tape File Level Spacing = 0.250000 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: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 RPCH RPCH RPCHX 0.0 RPCL RPCL RPCLX 0.0 RACH RACH RACHX 0.0 RACL RACL RACLX 0.0 ROP ROP ROPA 0.0 GRAX GRAX GRAX 0.0 * FORMAT RECORD (TYPE# 64) ---------------------------------------------------- ODEP *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM !! !!! !!!!!!!!!!!!!! Remark File Version 1.000 This file contains the unedited raw data. *** LIS COMMENT RECORD *** raw.xtf 150 BP Exploration (Alaska), MPL-26L1 PB3 Milne Point North ·Slope Alaska WDFN LCC CN WN FN COUN STAT -------------------------------- *** INFORMATION TABLE: CONS MNEM VALU ) ) **** FILE TRAILER **** Tape File Depth Units feet Tape Subfile: 3 104 records... Minimum record length: Maximum record length: **** TAPE TRAILER **** MWD 04/07/06 498151 01 **** REEL TRAILER **** MWD 04/07/07 BHI 01 Tape Sub file: 4 Minimum record length: Maximum record length: 54 bytes 4124 bytes 2 records... 132 bytes 132 bytes ) ') Tape Subfile 2 is type: LIS DEPTH RPCH RPCL RACH RACL ROP GRAX 7104.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7104.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7150.0000 3.5750 3.1100 2.8450 3.1150 -999.2500 164.8308 7200.0000 20.0500 18.5720 17.6280 14.7280 49.3900 79.7602 7250.0000 14.3457 14.0029 14.3129 13.1029 171.1200 110.3968 7300.0000 17.8375 18.4700 20.1425 16.1000 98.4400 87.8909 7350.0000 18.1167 17.2200 16.8067 14.0200 149.5500 73.2676 7400.0000 16.2800 15.5733 14.8133 13.4767 -999.2500 64.9744 7450.0000 28.2400 23.2100 19.5800 14.7500 20.9200 68.3639 7500.0000 19.6750 18.7850 18.8950 15.0400 161. 9300 67.2200 7550.0000 18.8100 19.0100 20.7700 16.0000 159.5870 67.2200 7600.0000 10.3100 10.9900 11.2780 12.0940 143.1470 135.5733 7650.0000 7.4300 7.3000 7.2700 7.2300 152.3360 141.8257 7700.0000 7.1200 6.1200 5.9700 5.1400 119.1520 146.3300 7750.0000 4.7450 4.0450 3.5550 3.6900 26.4810 166.3000 7800.0000 6.3300 6.1200 5.9600 6.3900 61.3500 149.7867 7850.0000 5.5400 4.1250 3.5100 3.7400 104.7050 162.4567 7900.0000 -999.2500 -999.2500 -999.2500 -999.2500 128.8860 -999.2500 7916.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth 7104.000000 Tape File End Depth 7916.000000 Tape File Level Spacing 0.500000 ) ) Tape Subfile 3 is type: LIS DEPTH RPCH RPCL RACH RACL ROP GRAX 7103.7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7104.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7150.0000 3.5750 3.1100 2.8450 3.1150 -999.2500 164.8308 7200.0000 20.0500 18.5720 17.6280 14.7280 49.3900 79.7602 7250.0000 14.3457 14.0029 14.3129 13.1029 171.1200 110.3968 7300.0000 17.8375 18.4700 20.1425 16.1000 98.4400 87.8909 7350.0000 18.1167 17.2200 16.8067 14.0200 149.5500 73.2676 7400.0000 16.2800 15.5733 14.8133 13.4767 -999.2500 64.9744 7450.0000 28.2400 23.2100 19.5800 14.7500 20.9200 68.3639 7500.0000 19.6750 18.7850 18.8950 15.0400 161. 9300 67.2200 7550.0000 18.8100 19.0100 20.7700 16.0000 159.5870 67.2200 7600.0000 10.3100 10.9900 11.2780 12.0940 143.1470 135.5733 7650.0000 7.4300 7.3000 7.2700 7.2300 152.3360 141.8257 7700.0000 7.1200 6.1200 5.9700 5.1400 119.1520 146.3300 7750.0000 4.7450 4.0450 3.5550 3.6900 26.4810 166.3000 7800.0000 6.3300 6.1200 5.9600 6.3900 61. 3500 149.7867 7850.0000 5.5400 4.1250 3.5100 3.7400 104.7050 162.4567 7900.0000 -999.2500 -999.2500 -999.2500 -999.2500 128.8860 -999.2500 7916.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth 7103.750000 Tape File End Depth 7916.000000 Tape File Level Spacing 0.250000 ) ) é)O,3-,·c¡7lp RECEIV:ED **** REEL HEADER **** RWD 03/12/01 BHI 01 DEC 11 2003 Ai.a Oil & Gas Cooª,. Commieeion Andtcrttge LIS Customer Format Tape **** TAPE HEADER **** RWD 03/12/01 , dv )~ 1 498151 01 3.125" GAM and 3.125 USR *** 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 6951.0000: STOP.FT 7640.0000: STEP.FT 0.2500: 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 NUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 10 TOWN.N 13N RANG. 10E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 46.3 DMF KB EKB .F 46.3 EDF .F N/A EGL .F N/A CASE.F 6974 OSl . DIRECTIONAL OS2 . RNT -Remarks LOG MNEMONICS: GRAM Gamma Ray APPARENT [RWD], (MWD-API units) ROP = Rate of Penetration, (ft/hour) RPCHM = Phase Resistivity, 2 MHz Compensated & Borehole Corrected [RWD], ( Ohm-m) RPCLM Phase Resistivity, 400 kHz Compensated & Borehole Corrected [RWD], ( Ohm-m) RACHM 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. MPC-26L1PB1 Milne Point 70 deg 29' 27.064" N 149 deg 31' 31.858" W North Slope Alaska Baker Hughes INTEQ 3 1/8" GAM and 3 1/8" USR 22-Jun-03 500292263470 Description ------------------------------- 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 Other Services Line 2 Attenuation Resistivity, 2 MHz Compo & Borehole Corrected [RWD], --........---.... ,,~ - ~ :::;".~ "'\."'\.-~-, , " '\ .,) \ ') \ \ \''--.=::::::-. ( Ohm-m) RACLM ( Ohm-m) REMARKS: (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Resistivity and Gamma Ray data are Realtime data. (4) Baker Hughes INTEQ Run 1-2 utilized NaviGamma service from 6984' MD (6838' SSTVD) to 7300' MD (6954' SSTVD). (5) Baker Hughes INTEQ Run 3 utilized Ultra Slim Multiple Propagation Resistivity (USMPR) from 7300' MD (6954' SSTVD) to 7640' MD (6944'SSTVD) (6) The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). As per BPX instructions, the RWD Gamma Ray is the PDC for this borehole. (7) The well was tied into the Gamma Ray log from the MPC-26 wellbore at 6735' MD (6593' SSTVD). (8) The sidetrack was drilled from milled window in 5 inch casing. Top of window: 6968' MD (6823" SSTVD) Bottom of window: 6974' MD (6829" SSTVD) (9) An open hole sidetrack was done at 7207' MD (6957' SSTVD) due to geological reasons after the well was drilled. (10) The interval from 7623' MD (6941' SSTVD) to 7640' MD (6944' SSTVD) was not logged due to sensor to bit offset. ) Attenuation Reistivity, 400 kHz Compo & Borehole Corrected [RWD], ) Tape Subfile: 1 69 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** RWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration (Alaska), Inc. MPC-26L1PB1 Milne Point North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final. It has not been depth shifted to a PDC (Primary Depth Control) as the Baker Hughes INTEQ RWD GR is the PDC for this wellbore (per BPXA Petro Technical Data Center) . *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0 2 0.0 RPCH RPCH RPCHM 0.0 RPCL RPCL RPCLM 0.0 RACH RACH RACHM 0.0 RACL RACL RACLM 0.0 ROP ROP ROPS 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: 0.250000 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 GR RWD 68 1 API 4 4 2 RPCH RWD 68 1 OHMM 4 4 3 RPCL RWD 68 1 OHMM 4 4 4 RACH RWD 68 1 OHMM 4 4 5 RACL RWD 68 1 OHMM 4 4 6 ROP RWD 68 1 F/HR 4 4 ------- 24 Total Data Records: 77 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 6951.000000 7640.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 2 90 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** RWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration (Alaska), MPC-26L1PB1 Milne Point North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!! !!! !!!!!! Remark File Version 1.000 This file contains the unedited raw data. *** INFORMATION TAB~ MNEM CHAN DIMT ) , CIFO CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCH RPCH RPCHM 0.0 RPCL RPCL RPCLM 0.0 RACH RACH RACHM 0.0 RACL RACL RACLM 0.0 ROPS ROPS ROPS 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: 0.250000 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 GRAM RWD 68 1 API 4 4 2 RPCH RWD 68 1 OHMM 4 4 3 RPCL RWD 68 1 OHMM 4 4 4 RACH RWD 68 1 OHMM 4 4 5 RACL RWD 68 1 OHMM 4 4 6 ROPS RWD 68 1 F/HR 4 4 ------- 24 Total Data Records: 77 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 6951. 000000 7640.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 90 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** RWD 03/12/01 498151 01 **** REEL TRAILER **** RWD 03/12/01 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: Tape Subfile 1 is type: LIS 2 records... 132 bytes 132 bytes ): Tape Subfile 2 is type: LIS DEPTH GR RPCH RPCL RACH RACL ROP 6951.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 6951. 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7000.0000 117.8889 -999.2500 -999.2500 -999.2500 -999.2500 18.9030 7100.0000 121.0205 -999.2500 -999.2500 -999.2500 -999.2500 39.1350 7200.0000 144.0823 -999.2500 -999.2500 -999.2500 -999.2500 31. 8650 7300.0000 137.2066 7.3020 6.9390 6.1000 5.9800 35.1460 7400.0000 103.4018 8.7110 8.3250 7.0840 7.4430 110.3600 7500.0000 127.0269 10.8530 9.0770 7.3460 7.3660 109.0590 7600.0000 135.4648 8.5130 7.5180 6.3360 6.8600 45.9360 7640.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 56.9540 Tape File Start Depth 6951.000000 Tape File End Depth 7640.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet ')' Tape Subfile 3 is type: LIS DEPTH GRAM RPCH RPCL RACH RACL ROPS 6951. 0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 6951. 2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7000.0000 117.6120 -999.2500 -999.2500 -999.2500 -999.2500 18.9030 7100.0000 118.3520 -999.2500 -999.2500 -999.2500 -999.2500 39.1350 7200.0000 142.8570 -999.2500 -999.2500 -999.2500 -999.2500 31.8650 7300.0000 135.0740 7.3020 6.9390 6.1000 5.9800 35.1460 7400.0000 101.2160 8.7110 8.3250 7.0840 7.4430 110.3600 7500.0000 126.3330 10.8530 9.0770 7.3460 7.3660 109.0590 7600.0000 145.5000 8.5130 7.5180 6.3360 6.8600 45.9360 7640.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 56.9540 Tape File Start Depth 6951.000000 Tape File End Depth 7640.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet ) ) Tape Subfile 4 is type: LIS ) ) )D3-()7~ # / ) ç-·o ~ **** REEL HEADER **** RWD 04/04/20 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** RWD 04/03/08 498151 01 3 1/8"/GAM *** 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 6951.0000: STOP.FT 7490.0000: 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 #--------- ------------------------- SECT. 10 TOWN.N 13N RANG. 10E PDAT. MSL EPD . F 0 LMF . RKB FAPD.F 46.3 DMF KB EKB .F 46.3 EDF .F N/A EGL .F NIA CASE.F 6974' OSl . DIRECTIONAL -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. 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. MPC-26L1PB2 Milne Point 70' NSL, 149' WEL North Slope Alaska Baker Hughes INTEQ 3 1/8" I GAM; 3 1/8" Ius R 25-Jun-03 500292263471 Description ------------------------------- 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 ) ) (2) All depths are Bit Depths unless otherwise noted. (3) All Resistivity and Gamma Ray data are Memory data. (4) Well MPC-26L1PB2 was drilled from an open hole sidetrack on MPC-26L1PB1 at 7207' MD (6957' SSTVD) on MWD Run3. (5) The well was tied into Gamma Ray log from the MPC-26 wellbore at 6735' MD (6593' SSTVD). (6) The sidetrack was drilled from milled window in 5 inch casing. Top of window: 6968' MD (6823' SSTVD). Bottom of window: 6974' MD (6829' SSTVD). (7) An open hole sidetrack was done at 7150' MD (6954' SSTVD) due to geological reasons after the well was drilled. (8) The interval from 7465' MD (6961' SSTVD) to 7490' MD (6963' SSTVD) was not logged due to sensor to bit offset. (9) Baker Hughes INTEQ runs 1-2 utilized NaviGamma service from 6984' MD (6838' SSTVD) to 7300' MD (6954' SSTVD). (10) Baker Hughes INTEQ runs 3-5 utilized Ultra Slim Multiple Propagation Resistivity (USMPR) service from 7300' MD (6954' SSTVD) to 7490' MD (6963' SSTVD). (11) Baker Hughes INTEQ runs 6-7 utilized NaviGamma service. There was no footage made on these runs due to hole conditions. (12) The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). As per BPX instructions, the MWD Gamma Ray is the PDC for this borehole. MNEMONICS: GRAM -> Gamma Ray RWD-API [RWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour RACLM -> Attenuation Resistivity, 400 kHz Compo & Borehole Corrected [MWD]. Ohmm RACHM -> Attenuation Resistivity, 2 MHz Compo & Borehole Corrected [MWD]. Ohmm RPCLM -> Phase Resistivity, 400 kHz Compo & Borehole Corrected [MWD]. Ohmm RPCHM -> Phase Resistivity, 2 MHz Compo & Borehole Corrected [MWD]. Ohmm EOZ END Tape Subfile: 1 74 records... Minimum record length: Maximum record length: 10 bytes 132 bytes **** FILE HEADER **** RWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration (Alaska) Inc. MPC-26L1PB2 Milne Point North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control) as the Baker Hughes INTEQ RWD GR is the PDC for ) ) wellbore (per BPXA Petro Technical Data Center) *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 ROP ROP ROPS 0.0 RACH RACH RACHM 0.0 RACL RACL RACLM 0.0 RPCH RPCH RPCHM 0.0 RPCL RPCL RPCLM 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 RWD 68 1 AAPI 4 4 2 ROP RWD 68 1 F/HR 4 4 3 RACH RWD 68 1 OHMM 4 4 4 RACL RWD 68 1 OHMM 4 4 5 RPCH RWD 68 1 OHMM 4 4 6 RPCL RWD 68 1 OHMM 4 4 ------- 24 Total Data Records: 30 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 6951.000000 7490.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 43 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** RWD .002 FRAME SPACE :::::: 0.250 * F ONE DEPTH PER FRAME Tape depth 10: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR RWD 68 1 AAPI 4 4 2 ROPS RWD 68 1 F/HR 4 4 3 RACH RWD 68 1 OHMM 4 4 4 RACL RWD 68 1 OHMM 4 4 5 RPCH RWD 68 1 OHMM 4 4 6 RPCL RWD 68 1 OHMM 4 4 ------- 24 Total Data Records: 60 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: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value:::::: 0) Datum Specification Block Sub-type is: 1 GR GR GRAM 0.0 ROPS ROPS ROPS 0.0 RACH RACH RACHM 0.0 RACL RACL RACLM 0.0 RPCH RPCH RPCHM 0.0 RPCL RPCL RPCLM 0.0 * FORMAT RECORD (TYPE# 64) ---------------------------------------------------- ODEP *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** LIS COMMENT RECORD *** raw.xtf 150 BP Exploration (Alaska) MPC-26L1PB2 Milne Point North Slope Alaska WDFN LCC CN WN FN COUN STAT -------------------------------- *** INFORMATION TABLE: CONS MNEM VALU 1024 ) ) Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 6951.000000 7490.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 73 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** RWD 04/03/08 498151 01 **** REEL TRAILER **** RWD 04/04/20 BHI 01 Tape Sub file: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes Tape Subfile 1 is type: LIS , , ) Tape Subfile 2 is type: LIS DEPTH GR ROP RACH RACL RPCH RPCL 6951. 0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 6951.5000 106.1000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7000.0000 118.6550 18.9030 -999.2500 -999.2500 -999.2500 -999.2500 7100.0000 117.3800 39.1350 -999.2500 -999.2500 -999.2500 -999.2500 7200.0000 142.6820 31.8650 4.2590 4.0140 5.7610 4.8300 7300.0000 135.8110 68.9270 5.7750 5.6180 8.7200 7.0000 7400.0000 135.0390 20.3590 5.8590 5.9050 9.1790 7.2680 7490.0000 -999.2500 67.3540 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth 6951.000000 Tape File End Depth 7490.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet ) Tape Subfile 3 is type: LIS DEPTH GR ROPS RACH RACL RPCH RPCL 6951.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 6951.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7000.0000 118.6550 18.9030 -999.2500 -999.2500 -999.2500 -999.2500 7100.0000 117.3800 39.1350 -999.2500 -999.2500 -999.2500 -999.2500 7200.0000 142.6820 31.8650 4.2590 4.0140 5.7610 4.8300 7300.0000 135.8110 68.9270 5.7750 5.6180 8.7200 7.0000 7400.0000 135.0390 20.3590 5.8590 5.9050 9.1790 7.2680 7490.0000 -999.2500 67.3540 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth 6951.000000 Tape File End Depth 7490.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet Tape Subfile 4 is type: LIS J é)C)3 ~'-{J --:r-Lf) J ;f., 6)~ **** REEL HEADER **** MWD 03/08/22 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 03/08/22 498151 01 3.00" 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 7105.0000: STOP.FT 8545.0000: STEP.FT 0.2500: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCAT I ON : CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NUMBER: NParameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 10 TOWN.N 13N RANG. 10E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 46.3 DMF KB EKB .F 46.3 EDF .F N/A EGL .F N/A CASE.F 6974 OSl . DIRECTIONAL OS2 . RNT -Remarks 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. MPC-26Ll Milne Point 70 deg 29' 27.064" N 149 deg 31' 31.858" W North Slope Alaska Baker Hughes INTEQ 3.00" CTK 14-Jul-03 500292263460 Description ------------------------------- 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 Other Services Line 2 ;': "",;, ~.."." .,r'''':,. ~""".; ~ 'f, !i ,.-.... """"",, :õ"'t:." ¡""~. ~ ,,="'^ ~ ';' .,. ~= ~ II ~ \\ H......,.; \~,~~~ ~r-.¡:"..-. z$ IQJ b-c; Llr AUf' 2" "I~'"'-' \.J _ D iUUO Ala,.!".... C)'·: ii. l.:··,:,.·.. "'/':';'~ /....,..., -:. ~ . ~\~ , I. .... ",'...' \.J.J¡;,~....\J¡t1:n:5~.)fi l\nc~hof a-J~; -,,-- .~, : ~r~~Ç~\~ ') ) LOG MNEMONICS: GRAX Gamma Ray APPARENT [MWD], (MWD-API units) ROP Rate of Penetration, (ft/hour) RPCHX Phase Resistivity, 2 MHz Compensated & Borehole Corrected [MWD], (Ohm-m) RPCLX Phase Resistivity, 400 kHz Compensated & Borehole Corrected [MWD], (Ohm-m) RACHX Attenuation Resistivity, 2 MHz Compo & Borehole Corrected [MWD], (Ohm-m) RACLX Attenuation Reistivity, 400 kHz Compo & Borehole Corrected [MWD], (Ohm-m) REMARKS: (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Resistivity and Gamma Ray data are Realtime data. (4) Baker Hughes INTEQ utilized Coil Trak/USMPR down hole tools and the ADVANTAGE surface system. (5) The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). As per BPX instructions, the MWD Gamma Ray is the PDC for this borehole. (6) The well was tied into the Gamma Ray log from the MPC-26 wellbore at 6735' MD (6593' SSTVD) (7) The sidetrack was drilled from milled window in 5 inch casing. Top of window: 6968' MD (6823" SSTVD) Bottom of window: 6974' MD (6829" SSTVD) (8) An open hole sidetrack was made from MPC-26L1PB3 at 7500' MD (6989' SSTVD) due to geological reasons after the well was drilled. (9) The interval from 8515' MD (7021' SSTVD) to 8545' MD (7018' SSTVD) was not logged due to sensor to bit offset. Tape Subfile: 1 67 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 COUN STAT mwd.xtf 150 BP Exploration (Alaska), Inc. MPC-26L1 Prudhoe Bay Unit North Slope Bourgh Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final. It has not been depth shifted to a PDC (Primary Depth Control) as the Baker Hughes INTEQ MWD GR is the PDC for this wellbore (per BPXA Petro Technical Data Center) . *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ) ) ---------------------------------------------------- GR GR GRAX 0.0 RPCH RPCH RPCHX 0.0 RPCL RPCL RPCLX 0.0 RACH RACH RACHX 0.0 RACL RACL RACLX 0.0 ROP ROP ROPA 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: 0.250000 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 GR MWD 68 1 API 4 4 2 RPCH MWD 68 1 OHMM 4 4 3 RPCL MWD 68 1 OHMM 4 4 4 RACH MWD 68 1 OHMM 4 4 5 RACL MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 F/HR 4 4 ------- 24 ¡., Total Data Records: 161 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 7105.000000 8545.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 2 174 records... Minimum record length: Maximum record length: 34 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 ) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration (Alaska), MPC-26Ll Prudhoe Bay Unit North Slope Bour Alaska *** LIS COMMENT RECORD *** !!!!! !!!!!! ! !!!! !!! Remark File Version 1.000 This file contains the unedited raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCH RPCH RPCHX 0.0 RPCL RPCL RPCLX 0.0 RACH RACH RACHX 0.0 RACL RACL RACLX 0.0 ROPA ROPA ROPA 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: 0.250000 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 API 4 4 2 RPCH MWD 68 1 OHMM 4 4 3 RPCL MWD 68 1 OHMM 4 4 4 RACH MWD 68 1 OHMM 4 4 5 RACL MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 F/HR 4 4 ------- 24 Total Data Records: 161 Tape File Start Depth 7105.000000 Tape File End Depth 8545.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet **** FILE TRAILER **** ) '~ Tape Subfile: 3 174 records... Minimum record length: Maximum record length: **** TAPE TRAILER **** MWD 03/08/22 498151 01 **** REEL TRAILER **** MWD 03/08/22 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: Tape Subfile 1 is type: LIS 34 bytes 4124 bytes 2 records... 132 bytes 132 bytes Tape Subfile 2 is type: LIS DEPTH GR RPCH RPCL RACH RACL ROP 7105.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7105.2500 140.4911 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7150.0000 164.8308 3.5750 3.1100 2.8450 3.1150 -999.2500 7200.0000 79.7602 20.0500 18.5720 17.6280 14.7280 49.3900 7250.0000 110.3968 14.3457 14.0029 14.3129 13.1029 171.1200 7300.0000 87.8909 17.8375 18.4700 20.1425 16.1000 98.4400 7350.0000 73.2676 18.1167 17.2200 16.8067 14.0200 149.5500 7400.0000 64.9744 16.2800 15.5733 14.8133 13.4767 -999.2500 7450.0000 68.3639 28.2400 23.2100 19.5800 14.7500 20.9200 7500.0000 75.1015 18.6100 18.1700 18.9600 15.2150 161.9300 7550.0000 60.1409 26.2000 25.1500 28.2300 18.6000 149.6800 7600.0000 66.9924 19.8000 18.0600 17.5100 14.1700 21.3900 7650.0000 84.7879 24.4379 19.2536 14.4964 13.2364 127.2000 7700.0000 138.8431 8.1100 8.0000 7.5300 8.3100 121.5700 7750.0000 138.5264 7.2700 6.0600 5.6750 5.0550 127.7900 7800.0000 69.5463 14.7900 16.3700 19.6900 17.7300 131. 4200 7850.0000 81.6089 33.7080 23.7260 17.2460 15.0520 93.5300 7900.0000 119.0526 24.6900 19.7900 17.7900 14.3200 99.8700 7950.0000 134.9172 13.0300 11.1300 9.6100 10.8900 107.9500 8000.0000 93.9455 13.3900 12.1800 10.7200 11.9600 128.7100 8050.0000 114.0191 39.3150 35.6600 31.8400 ) ) 25.0600 126.9400 8100.0000 85.8116 51.1411 44.3044 37.0478 30.5500 -999.2500 8150.0000 86.5196 46.0800 40.2871 32.5071 29.7200 125.8400 8200.0000 72.7237 50.7780 43.3920 31. 9180 29.3700 138.9800 8250.0000 99.2898 38.0271 36.9629 36.4271 31.1257 78.7600 8300.0000 77.3501 52.5700 43.5400 32.0500 28.1550 145.5000 8350.0000 76.4346 47.0700 42.7000 33.9250 33.3900 149.7600 8400.0000 76.0799 42.4500 38.2000 33.7300 29.4700 136.8500 8450.0000 80.1670 46.7500 33.7033 25.8833 19.6100 56.9800 8500.0000 -999.2500 10.6733 10.5600 9.1020 11.0280 113.0600 8545.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth 7105.000000 Tape File End Depth 8545.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet ) ) Tape Subfile 3 is type: LIS DEPTH GRAX RPCH RPCL RACH RACL ROPA 7105.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7105.2500 140.4911 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 7150.0000 164.8308 3.5750 3.1100 2.8450 3.1150 -999.2500 7200.0000 79.7602 20.0500 18.5720 17.6280 14.7280 49.3900 7250.0000 110.3968 14.3457 14.0029 14.3129 13.1029 171.1200 7300.0000 87.8909 17.8375 18.4700 20.1425 16.1000 98.4400 7350.0000 73.2676 18.1167 17.2200 16.8067 14.0200 149.5500 7400.0000 64.9744 16.2800 15.5733 14.8133 13.4767 -999.2500 7450.0000 68.3639 28.2400 23.2100 19.5800 14.7500 20.9200 7500.0000 75.1015 18.6100 18.1700 18.9600 15.2150 161.9300 7550.0000 60.1409 26.2000 25.1500 28.2300 18.6000 149.6800 7600.0000 66.9924 19.8000 18.0600 17.5100 14.1700 21.3900 7650.0000 84.7879 24.4379 19.2536 14.4964 13.2364 127.2000 7700.0000 138.8431 8.1100 8.0000 7.5300 8.3100 121.5700 7750.0000 138.5264 7.2700 6.0600 5.6750 5.0550 127.7900 7800.0000 69.5463 14.7900 16.3700 19.6900 17.7300 131. 4200 7850.0000 81. 6089 33.7080 23.7260 17.2460 15.0520 93.5300 7900.0000 119.0526 24.6900 19.7900 17.7900 14.3200 99.8700 7950.0000 134.9172 13.0300 11.1300 9.6100 10.8900 107.9500 8000.0000 93.9455 13.3900 12.1800 10.7200 11.9600 128.7100 8050.0000 114.0191 39.3150 35.6600 31. 8400 ) ') 25.0600 126.9400 8100.0000 85.8116 51.1411 44.3044 37.0478 30.5500 -999.2500 8150.0000 86.5196 46.0800 40.2871 32.5071 29.7200 125.8400 8200.0000 72.7237 50.7780 43.3920 31. 9180 29.3700 138.9800 8250.0000 99.2898 38.0271 36.9629 36.4271 31.1257 78.7600 8300.0000 77.3501 52.5700 43.5400 32.0500 28.1550 145.5000 8350.0000 76.4346 47.0700 42.7000 33.9250 33.3900 149.7600 8400.0000 76.0799 42.4500 38.2000 33.7300 29.4700 136.8500 8450.0000 80.1670 46.7500 33.7033 25.8833 19.6100 56.9800 8500.0000 -999.2500 10.6733 10.5600 9.1020 11.0280 113.0600 8545.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth 7105.000000 Tape File End Depth 8545.000000 Tape File Level Spacing 0.250000 Tape File Depth Units feet Tape Subfile 4 is type: LIS ) )