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Home My WebLink About202-214Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/06/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231206 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 13-8 50133203040000 177029 11/15/2023 HALLIBURTON EPX NCIU A-17 50883201880000 223031 11/28/2023 HALLIBURTON RBT PBU 04-46A 50029224340100 223082 11/1/2023 HALLIBURTON RBT PBU 05-26A 50029219840100 201221 11/24/2023 HALLIBURTON PPROF PBU 06-20B 50029207990200 223075 10/18/2023 BAKER MRPM PBU D-01A 50029200540100 197078 10/31/2023 HALLIBURTON RBT PBU N-07A 50029201370100 204105 10/7/2023 BAKER SPN PBU P1-08A 50029223840100 202199 9/22/2023 BAKER SPN PBU P2-56 50029226100000 195162 11/14/2023 BAKER SPN PBU P2-57A 50029221830100 202214 11/1/2023 BAKER SPN Please include current contact information if different from above. T38205 T38206 T38207 T38208 T38209 T38210 T38211 T38212 T38213 T38214 12/6/2023 PBU P2-57A 50029221830100 202214 11/1/2023 BAKER SPN Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.06 14:25:58 -09'00' • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 Mr. Jim Regg sAYANED AUG 0 ZOlL Alaska Oil and Gas Conservation Commission 333 West 7 Avenue �� I Anchorage, Alaska 99501 �1 ®� Y. Subject: Corrosion Inhibitor Treatments of GPMA PM -2 pc9-- 51 R Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA PM -2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) GPMA PM -2 Date: 04/30/2012 Corrosion Vol. of cement Final top of Cement top Corrosion inhibitor/ sealant Well Name PTD # API # Initial top of cement pumped cement off date inhibitor date ft bbls ft na gal P2 -01 1970730 50029227610000 0.3 NA 0.3 NA 1.70 6/22/2009 P2 -03 1970440 50029227490000 2.0 NA 2.0 NA 10.20 6/22/2009 P2-04 1981560 50029229070000 1.0 NA 1.0 NA 5.10 6/22/2009 P2-06 1931030 50029223880000 4.0 NA 4.0 NA 30.60 6/22/2009 P2 -07 1940580 50029224690000 2.0 NA 2.0 NA 13.60 6/22/2009 P2 -08A 2061690 50029228960100 0.8 NA 0.8 NA 4.30 6/21/2009 P2 -09 1980660 50029228760000 0.3 NA 0.3 NA 0.85 6/21/2009 P2 -10 1980970 50029228860000 0.3 NA 0.3 NA 1.70 6/21/2009 P2 -11A 2060260 50029229230100 3.5 NA 3.5 NA 69.70 6/21/2009 P2 -12 1931150 50029223950000 Sealed conductor NA NA NA NA NA P2 -13 1970600 50029227570000 0.5 NA 0.5 NA 2.60 6/21/2009 P2 -14 1981050 50029228880000 1.5 NA 1.5 NA 10.20 6/21/2009 P2 -15A 2070320 50029224090100 Sealed conductor NA NA NA NA NA P2 -16 1931230 50029223970000 3.0 NA 3.0 NA 28.10 6/20/2009 P2 -17 1981370 50029229020000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -18 1940600 50029224710000 0.8 NA 0.8 NA 2.60 6/20/2009 P2 -19A 2070120 50029227650100 0.3 NA 0.3 NA 0.90 6/20/2009 P2 -20 1960590 50029226640000 0.5 NA 0.5 NA 2.60 6/20/2009 P2 -21 1940530 50029224670000 0.8 NA 0.8 NA 3.40 6/20/2009 P2 -22 1972490 50029228500000 1.0 NA 1.0 NA 7.70 6/20/2009 P2 -23 1940320 50029224530000 1.3 NA 1.3 NA 11.10 6/20/2009 P2 -24 1980080 50029228540000 1.5 NA 1.5 NA 1020 6/15/2009 P2 -25 1971110 50029227760000 1.8 NA 1.8 NA 17.90 6/10/2009 P2 -27 1971250 50029227850000 1.3 NA 1.3 NA 8.50 6/10/2009 P2 -28 1950440 50029225510000 3.3 NA 3.3 NA 37.40 4/18/2012 P2 -29 1931470 50029224070000 10.3 NA 10.3 NA 71.40 6/15/2009 P2 -30 1920950 50029222890000 2.8 NA 2.8 NA 17.90 6/10/2009 P2 -31 1940360 50029224560000 2.2 NA 2.2 NA 2120 6/20/2009 P2 -32 1951350 50029225930000 Surface casing leak NA NA NA NA NA P2 -33B 1972310 50029228120200 2.0 NA 2.0 NA 16.60 6/9/2009 P2 -34 1950660 50029225580000 1.5 NA 1.5 NA 11.50 6/9/2009 P2-35 1951790 50029226200000 1.0 NA 1.0 NA 13.60 6/9/2009 P2 -36A 2060220 50029228010100 1.1 NA 1.1 NA 6.00 6/9/2009 P2 -37A 2050570 50029225760100 2.0 NA 2.0 NA 23.00 6/9/2009 P2 -39 2111230 50029234540000 0.8 NA 0.8 NA 10.20 4/30/2012 P2-40 1972260 50029228370000 0.5 NA 0.5 NA 5.10 6/9/2009 P2-41 1952050 50029226330000 1.5 NA 1.5 NA 17.00 6/9/2009 P2-42 1931430 50029224050000 19.3 NA 19.3 NA 121.60 6/20/2009 P2-43 2050240 50029232500000 0.8 NA 0.8 NA 6.00 6/8/2009 P2-44 1960630 50029226660000 2.3 NA 2.3 NA 23.80 6/8/2009 P2-45B 2080210 50029227690200 0.8 NA 0.8 NA 5.10 6/8/2009 P2-46 1931320 50029224010000 2.3 NA 2.3 NA 25.50 6/8/2009 P2 -47 1951900 50029226280000 0.0 NA 0.0 NA NA NA P2-48 1921260 50029223090000 0.2 NA 0.2 NA 1.70 4/18/2012 P2-49 1920240 50029222520000 2.5 NA 2.5 NA 18.70 6/7/2009 P2 -50B 1950960 50029222610200 2.0 NA 2.0 NA 23.00 6/8/2009 P2 -51 1920380 50029222620000 0.3 NA 0.3 NA 0.85 6/7/2009 P2 -52 1972010 50029228260000 3.8 NA 3.8 NA 47.60 6/7/2009 P2 -53 1960410 50029226560000 2.0 NA 2.0 NA 21.30 6/7/2009 P2 -54A 2030300 50029224700100 0.8 NA 0.8 NA 3.40 6/7/2009 P2 -55 1920820 50029222830000 4.0 NA 4.0 NA 79.90 6/22/2009 P2 -56 1951620 50029226100000 2.8 NA 2.8 NA 17.90 6/7/2009 7 P2 -57A 2022140 50029221830100 15.5 NA 15.5 NA 77.40 6/22/2009 P2 -58 1900080 50029220000000 Sealed conductor NA NA NA NA NA P2 -59A 1982010 50029220960100 Sealed conductor NA NA NA NA NA P2-60 1910910 50029221920000 8.3 NA 8.3 NA 56.10 3/13/2012 Schlumberger NO. 4260 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons iComm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 .é)O.) - ê) 1'--1 "14.. {S ( 8<1 Field: Prudhoe Bay J b# BL CD CI D t Well 0 Lo!! Description ae o or 03-36 10831325 CH EDIT PDC GR 08/11/04 1 MPL-40 98160 OH EDIT MWD/LWD (REVISED) 03/05/98 4 1 L2-18A 11421036 RST 10/14/06 1 1 A-04 11221855 RST 03/22/06 1 1 06-04A 11320998 RST 08/02/06 1 1 C-24A 11209609 MCNL 06/19/06 1 1 P2-57 A 10831796 RST 04/29/06 1 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. 51i"'/'·MNED MAY 1 7 2007 Petrotechnical Data Center LR2-1VI"ü. . 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: t'lAY J. ~1 ZOOl Received by: '-q- 05/15/07 . . . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13, 2006 RE: MWD Formation Evaluation Logs: S-106_PB1, S-112, S-205, C-OlA, 2T-218, P2-57A. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 S-106_PBl: :dO I-Old. tt /L./37"S Digital Log Images: 50-029-22999-00, 70 1 CD Rom S-112: U::t:~ Qo;)-{3S- :þ IL/~/ Digital Log Images: 50-029-23099-00 5 .9/~· 4b~(edWr(),^,~- S 2G5! Ù.::r:.c..~Od- I-S-~ d: /'--/39-;) Digital Log Images: 50-029-23107 -00 1 CD Rom 1 CD Rom 5CANNED JAN 3 0 2007 C-OIA: 963 -bl 0 -tr [Lint> Digital Log Images: 50-029-20121-01 1 CD Rom 2T-218: Q63 -Off I':t-/L/3-:::J-1 Digital Log Images: 50-029-20449-00 1 CD Rom P2-57A: ~Od -éjlL.{ 'it ¡L.f3(p1 Digital Log Images: 50-029-22183-01 1 CD Rom e e TO Beth @ Schlumberger We also receive these Well Logs and no transmittal to accompany them API 50-029-23294-00 KuparuklWest Sak Permit # 205-209 MDT-GR FMI-DSI-GR P&S and Dipole CST-U, CST-V, GR Best DT, Final Result and 2 CD's to accompany them with the logs on them Date 6-Mar-2006 GO;;) API 50-029-22183-01 Point Mclntrye P2-57 A Permit #-2-&4-214 RST Sigma, PBMS-A, RST-C Date 29-Apr-2004 ¡,,--,- '1'1'1,1 'f ~ SCAN:ìit:::U ",l; ~ .:.. ~ c~~~Q Çl~' . ~ 1<;)\)~ \\)~ \ '~sc¡,\otl V \.PJ~~ C\tls. Q\\ 'b. G~ ~~e ~~ þ.tlð'-Q ., \)~ ~ ,0\ ~ · . WELL LOG TRANSMITTAL / -3548 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 23,2004 RE: MWD Formation Evaluation Logs: P2-57A, AK-MW -2326440 P2-57A: Digital Log Images: 50-029-22183-01 QD? ,. d It- I CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 995] 8 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 .-:, Date ~ I ~ IJ lov /L~/) Signedt¿)O~QQ) r) . . ..·····r·······.·········'····"·,·-·· ,'~ . ..~:,,'. '. .i\ ;;.~ MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc {G ~~(JO\ DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2022140 Well Name/No. PRUDHOE BAY UN PTM P2-57A Operator BP EXPLORATION (ALASKA) INC 5f! d I t. r1tv\..ÀÖ (;J 3- API No. 50-029-22183-01-00 MD .-" Completion Date 3/16/2003 111 02 TVD 8847 ' Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, ROP, Memory GR, CCL,RES, CNL Well Log Information: Electr Digital Dataset Med/Frmt Number D Log/ Data Type 1Æb I Rpt ¡ Rpt ! I I ¡ i i I ¥-D Log Log Scale Media Run No 1 3 Name Directional Survey LIS Verification Directional Survey ct.m5 L-IS V.(jrific:ltiorT (;V~. fU.í'y(..'( f<G r' I 3 B5 C Asc cm16 LIS Verification ~D C Pds /016 Neutron ~' i C Casing collar locator µ:D Pds .....-r2016 i l-t.og C016 Neutron vr 016 Casing collar locator fLog i I Well Cores/Samples Information: 2 2 2 2 Blu 2 Blu Name Interval Start Stop Received Sent Current Status 1-01L UIC N ~ Directional Survey~ (data taken from Logs Portion of Master Well Data Maint) Interval OH/ Start Stop CH Received Comments 9643 11102 Open 4/17/2003 9558 11 056 Open 6/25/2003 9643 11102 Open 4/17/2003 An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 11/21/2002. 9558 11 056 Open 6/25/2003 A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 11/21/2002. 8960 11075 Case 6/10/2003 Compensated Neutron Log, Memory GRlCCUCNL 8960 11075 Case 6/10/2003 Compensated Neutron Log, Memory GRlCCUCNL 8960 11075 Case 6/10/2003 Compensated Neutron Log, Memory GRlCCUCNL 8960 11075 Case 6/10/2003 Compensated Neutron Log, Memory GRlCCUCNL 8960 11075 Case 6/10/2003 Compensated Neutron Log, Memory GRlCCUCNL Sample Set Number Comments '_/ "~ DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2022140 Well Name/No. PRUDHOE BAY UN PTM P2-57A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22183-01-00 MD 11102 TVD 8847 Completion Date 3/16/2003 Completion Status 1-01L Current Status 1-01L UIC N ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? ~ Q}N Chips Received? "'¥"f1"r Formation Tops Analysis ~ Received? .~ Comments: Compliance Reviewed By: L Date: / J~ ßrt ~ s --- .') ) ~o~-~,+ ./ f 17> 3S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Howard Okland 333 West 7tb Avenue, Suite 100 Anchorage, Alaska June 19, 2003 RE: MWD Formation Evaluation Logs P2-57 A, AK-MW-2326440 1 LDWG fonnatted Disc with verification listing. API#: 50-029-22183-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun DriUing Services Attn: Rob Kalish 6900 Arctic Blvd. An.()h~F~~'iA\~lç~.Q9~, 18 ¡i~\ I·,' c.... I ~.. ...., r: II ,Ii I ri ,~, ¡, \:. I':....,. ·.,i/ '..,,:1 \:~/ ¡.:,."., ;:,..,,1') BP Exploration (Alaska) Inc. Petro- Technical.Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 (;1 r:: '"'003 lJ 1/..) L.! Signed: J? ~ c; G t\. I!," ,...Ðafè¡ Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well v"'Wjt9AL1 ~Cb2-d. ~E) vP2-57 A floóJ -e \ ~ 0.5. 12-20 \ ?fõl-\1fi D.S.15-21A t <-t9. -0" . B-04 1 T<:2 -0 -.., ., YF-10A ()-(!;(J.... d (Q . t "Ð"-~OA~œ -d J-t e) )t[f-¡2B - \~ L:) vK"-01 . -' \ & \ Job# Log Description PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 23099 TIE-IN MGRlCCL 23272 MCNL LDL PRODUCTION PROFILE PRODUCTION PROFILE/GHOST LDL MEM PRODUCTION PROFILE MEM PRODUCTION PROFILE LDL o / /.0 -- (~~ J' t'} u¡\ .. ". ;-.: "':-:.:-!~ r,-,';::' ;-t~ "J" ,~. 06/05/03 NO. 2800 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Date Blueline Prints CD 03/06/03 1 1- 1él:C) 15 03/15/03 1 1 /~O / If) 06/03/03 1 05/15/03 1 05/17/03 1 05/18/03 1 OS/20/03 1 OS/22/03 1 05/16/03 1 - ~ ;~CC. f-c~ E ~ \/ i:::.W Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ~ . - ! - /í. ' . r· ..'0l V ! '"'. . . ReceIved by: ~J';' f' JJL -()(ø~ ~ ~--, 4 \-r' . . -p. " ~ _....~. - - -;¡ .....~ ~ .~._-,,_... Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well aoé\· À~ W-19AL 1 ""'-....ø ~~~~ P2-57A . ~ ì ¡a .. , q \ 0.5. 12-20 "'-.j j q<\. 02~ D.S.15-21k-J '1 D . Ó 32 B-04 .--.J .9.ùt. 0 (,.1 F-10A --.....; ).0 ~. ;í\~O D-30A '-....J ~\)~.)ó5 D-22B -J J t'!J . 12. t K-01·-...¡ Job# Log Description 23099 TIE-IN MGRlCCL 23272 MCNL LDL PRODUCTION PROFILE PRODUCTION PROFILE/GHOST LDL MEM PRODUCTION PROFILE MEM PRODUCTION PROFILE LDL PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~ /"" 10 ~():3 06/05/03 NO. 2800 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Date Blueline Prints CD 03/06/03 1 1 03/15/03 1 1 06/03/03 1 05/15/03 1 05/17/03 1 05/18/03 1 OS/20/03 1 OS/22/03 1 05/16/03 1 -. --- Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Be~th /!Iæ rr 7 - ¡ /\ It 'l ,r" 1 Received ~..QJ..~ ~j J(i,,'t-.:J \. ' ) .) STATE OF ALASKA ¡ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 594' SNL, 12201 EWL, SEC. 14, T12N, R14E, UM At top of productive interval 4577' SNL, 7761 EWL, SEC. 14, T12N, R14E, UM X = 681129, Y = 5993995 10. Well Number At total depth 4032' SNL, 1891 EWL, SEC. 14, T12N, R14E, UM X = 680528, Y = 5994525 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Point Mcintyre KBE = 41', I ADL 034624 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 3/10/2003 3/13/2003 3/16/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 11102 8847 FT 11102 8847 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, ROP, RES, Memory GR, CCL, CNL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE 20" 91.5# H-40 Surface 104' 30" 13-3/8" 68# L-80 Surface 4364' 16" 9-5/8" 47# L-80 Surface 9560' 12-1/4" 650 sx Class 'G' 7" 29# L-80 9233' 9660' 8-1/2" 300 sx Class 'G' 8.81#/6.2#/6.16# L-80 9254' 11102' 3-3/4" 74sxClass'GI ; ,! ¡ \,1: I : ~I I 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, si~e ªnønur;nÞ~rL, 2-7/8" Slotted Section MD TVD' I MD ' TVD 10341' - 111 00' 8877' - 88471 27. Date First Production March 19,2003 Date of Test Hours Tested 4/21/2003 5.2 Classification of Service Well 7. Permit Number 202-214 8. API Number 50- 029-22183-01 9. Unit or Lease Name X = 681471, Y = 5997988 Point Mcintyre P2-57 A 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 22231 MD 1900' (Approx.) CEMENTING RECORD 440 sx Coldset II 1670 sx AS III, 350 sx 'G', Top Job 175 sx AS I AMOUNT PUllED * 3-1/2" x 3-3/16" x 2-7/8" 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2", 17#, L-80 9202' 4-1/2",12.6#, L-80 9202' - 92961 9181' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10267' - 10270' Pre-Drilled holes in 2-7/8" Liner, Cemented over with Bonzai Cement Job 2200' Freeze Protected with 60/40 MeOH PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR'I Oll-BBl TEST PERIOD 4,739 Oll-BBl CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presen.ce ,Of Oi~., gas or water. Submit core cRE C E , VE 0 ìì6&11 No core samples were taken. ;", . 'r; V_~, {i APR 2 4 2 ,. ~ .' f.(:14. ' /-, 003 ,~ .~lib/oJ h>~~rl'f~~" PR 0 ··¡Oi)]· î v r'b: ~~.~ RIDMS BFL A 3, L ,.u~~:'· ·;i...~':~~~~:.i~~:'· Form 1 0-407 Rev. 07-0 1 ~~ ':,"'" ....'..' '. ,I,;:;: ~".~;;;::::;;;,;;.J 0 RIG I !' I , ! ~ Flow Tubing Casing Pressure CALCULATED Press. 628 24-HoUR RATE 28. GAs-McF 3,624 GAs-McF WATER-BBl 62.35 WATER-BBl CHOKE SIZE GAs-all RATIO 13° 765 all GRAVITY-API (CORR) Alaska Oil & Gas Cons. Commission Anchorage ( It:-- ~ Submit In Duplicate ") ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Kuparuk 9622' 8586' UB4 9654' 8615' UB3 9675' 8634' UB1-2 9698' 8656' LC4 9726' 8682' LC3 9742' 8697' LC2 8741' LB2-4 ;9817' 9845' 8766' LB1 8789' R~C~I\I~D APR 2 4 2003 Alaska Oil & G as Cons. Co . Anchorage tnmlssion 31. Lìst of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerríeHubble 4R~ ~ TItle Technical Assistant Date (j{~~·()3 P2-57 A 202-214 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer; Mark Johnson, 564-5666 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Jog on all types of lands and leases in Alaska. IrEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. IrEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data çsrtinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, K8, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. I;oEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 OI~!GINAL ) ) ARGO Page.1 of 7 Operations· $ummaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-57(10) P2-57(10) REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/9/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/12/1991 End: Date From - To Hours Task Code NPT Phase Descri ption of Operations 3/8/2003 00:00 - 06:30 6.50 MOB P PRE Move Nordic Rig #1 from W-19AL 1 in the WOA to P2-57 at Point Mcintyre. Move onto PM2 pad and spot rig in front of P2-57. 06:30 - 07:15 0.75 MOB P PRE Safety meeting prior to moving over well. 07:15 - 08:00 0.75 MOB P PRE Position rig over well P2-57. Nipple down tree cap. 08:00 - 0.00 MOB P PRE Start nippling up stack. Accept rig at 08:00 hrs. 3/9/2003 00:00 - 06:00 6.00 MOB N WAIT PRE P2-57 has a 5 1/8" tree. Locate 51/8" x 41/16" or 5 1/8" x 7 1/16" flange for BOP. 06:00 - 07:00 1.00 RIGU P PRE Install neccessary xIo's on bottom of stack, and nipple down tree cap. 07:00 - 07:45 0.75 RIGU P PRE PJSM prior to moving over well. Also discuss working at heights and fall protection requirements, and reviewed responce to fire/spill on W-19AL 1. 07:45 - 12:00 4.25 RIGU P PRE Spot rig over well. Nipple up stack. Accept rig at 08:00 hours. Continue rigging up. Get pad operator to pump open SSV. Install remote shutdown for well P2-56 on rig floor. 12:00 - 18:00 6.00 BOPSUB P PRE Pressure test rig BOP stack. Witness waived by AOGCC, Jeff Jones. Note - Nordic welder and mechanic are removing SPM pump #2 to send to town for repair. They have rig piping disconnected in the motor room. A Vac truck of mud is standing by. It is not possible to safely fill pits while lines are unflanged and unblinded. No blinds available on location. 18:00 - 19:00 1.00 BOPSUB N RREP PRE Wait on rig hands to re assemble suction lines in motor room. Load mud pump on flat bed. 19:00 - 20:00 1.00 RIGU P PRE Take on mud. Check for leaks. 20:00 - 20:30 0.50 RIGU P PRE Hold pre spud meeting with all personnel. 20:30 - 21 :30 1.00 STWHIP P WEXIT Redimple CTC. Pull test and pressure test CTC. MU milling BHA. Fill coil with mud. Change packoff. 21 :30 - 22:00 0.50 STWHIP P WEXIT Change coil packoff in injector. 22:00 - 00:00 2.00 STWHIP P WEXIT Stab injector. RIH to 9,500'. PU=42.5K, SO=21 K. Tag whipstock at 9,674'. Correct depth to 9,660' and flag pipe. 3/10/2003 00:00 - 01 :20 1.33 STWHIP P WEXIT Displace well to 9.5 ppg flo pro at 2.6 bpm prior to milling window due to formation pressure. 01 :20 - 06:00 4.67 STWHIP P WEXIT Mill window from 9,660' to 9,664'. 06:00 - 08:00 2.00 STWHIP P WEXIT 9664', Continue window milling. Pit vol=305 bbls. IAP=240 psi, OAP=30 psi. 2.6/2.6/2450 psi. 08:00 - 08:45 0.75 STWHIP P WEXIT 9667', Broke thru bottom of window. Window depths are 9960'-9967', CTM. Drill 10' of openhole to 9677'. 08:45 - 10:00 1.25 STWHIP P WEXIT Ream window. Dry drift window, no overpulls seen, got to bottom easily. 10:00 - 12:00 2.00 STWHIP P WEXIT POOH with window milling BHA. 12:00 -12:15 0.25 STWHIP P WEXIT Stop at 173' for no flow test. 12:15 -13:00 0.75 STWHIP P WEXIT Confirmed no flow. Tag up at surface. Rig down window milling BHA. Confirmed swirl pattern on face of 00261 DSM. Confirmed mill and reamer still gauge 3.80". Good window. Layout rest of Baker eq. 13:00 - 13:15 0.25 DRILL P PROD1 Pre spud safety meeting with all rig hands and support personnel. 13:15-15:10 1.92 DRILL P PROD1 Cut off Baker CTC. Re head with SWS CTC. Pull test to 40 klbs, pres test to 35klbs. Pick up BHA #2 to drill build and turn section. Printed: 3/17/2003 9:41:30 AM ) '\ i) ARGO Qperations Summary.·Report Page 2 of 7 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-57(10) P2-57(10) REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/9/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/12/1991 End: Date From - To Hours Task Code NPT Phase Description of Operations 3/10/2003 15:10 -16:50 1.67 DRILL P PROD1 RIH with BHA #2, first build section BHA. Shallow hole test of MWD and orienter at 1200' was good. Continue RIH. Hung up at window. 16:50 - 17:00 0.17 DRILL P PROD1 PU, orient from 45R to 142R. 17:00 - 18:00 1.00 DRILL P PROD1 9677', Tag bottom correct -15'. Begin drilling. Free spin 2990 psi at 2.7 bpm. 2.7/2.7/3200 psi. IAP=229 psi, OAP=10 psi. Pit vol=320 psi. 18:00 - 19:45 1.75 DRILL P PROD1 9707', Drilling ahead. Free spin dropped to 2850 psi. 2.6/2.6/3000. IAP=359 psi. OAP=23 psi, Pit vol=319 bbls. Drill to 9,748'. 19:45 - 21 :00 1.25 DRILL P PROD1 Pull to above window for tie in. Log GR markers. Add 6'. RIH. Log RA tag in whipstock, no correction. 21 :00 - 00:00 3.00 DRILL P PROD1 Tag bottom at 9,755'. Drill to 9,776'. Drill at 2.6 bpm, 3,200 psi, TF=90L. Off bottom 2,800 psi. Having trouble holding TF while drilling. Pull into casing. Orienter functioning ok. Having a lot of problems staying oriented to 90L when going to bottom. Orienting uphole, then losing TF when going to bottom. 3/11/2003 00:00 - 00:30 0.50 DRILL P PROD1 Still having trouble holding TF. 00:30 - 02:50 2.33 DRILL P PROD1 Finally get TF to hold. Drill from 9,776' to 9,853. Bleed IA to from 500 psi to 150 psi and OA from 200 psi to 20 psi. 02:50 - 03:05 0.25 DRILL P PROD1 PU off bottom to orient one click. Unable to get one click. Will come to window and try. Get one click at window. RIH. TF rolled going in hole. 03:05 - 03:20 0.25 DRILL P PROD1 Try to orient just off bottom. Unable to get one click. PU to window and orient one click. 03:20 - 05: 1 0 1.83 DRILL P PROD1 Drill to 9,952'. 2.6 bpm, 3,140 psi, TF=4L. Off bottom 2,900 psi. ROP= 100 fph. 05:10 - 06:00 0.83 DRILL P PROD1 Attempt to orient 90L. Unable to orient near bottom with 2.83 degree bent housing motor. Pull up to window and orient. 06:00 - 07:05 1.08 DRILL P PROD1 9952', Resume drilling. IAP=235, OAP=73, Pit Vol=312 bbls. Free spin 2950 psi at 2.6 bpm. 2.6/2.6/3050 psi. 07:05 - 07:50 0.75 DRILL P PROD1 9978', Pick up to orient to 90L. Having to come to the window to get clicks. Orienter working fine at window. It is just in too much of a bind when in the build section of the hole. 07:50 - 08:45 0.92 DRILL P PROD1 Resume drilling. Pit vol=31 0 bbls. Drilling at 2.6/2.6/3050 psi. ROP=45 fph. 08:45 - 09:00 0.25 DRILL P PROD1 Try to take a click. 09:00 - 10:00 1.00 DRILL P PROD1 Drill ahead. 10:00 - 10:15 0.25 DRILL P PROD1 10182', Wiper trip. 10:15 -10:25 0.17 DRILL P PROD1 Resume drilling. 10:25 - 10:50 0.42 DRILL P PROD1 10210', We may be landed. We still have turn to make, but can get it with a smaller bend motor. Wiper to window to let DD cypher. Decision is to continue drilling to 10270'. 10:50-11:10 0.33 DRILL P PROD1 Resume drilling. 11:10 -13:05 1.92 DRILL P PROD1 Well build and turn complete. POH for lateral section BHA 13:05 - 13:50 0.75 DRILL P PROD1 Tag up at surface with BHA #2. Stand back injector. Lay down BHA. Bit graded 1,1. 13:50 - 15:00 1.17 DRILL P PROD1 Make up BHA #3 to drill lateral section. DPI Bicentered bit, 1.04 deg motor, RES tool. 15:00 - 17:20 2.33 DRILL P PROD1 RIH with BHA #3, to drill lateral section. Run thru window & tag TD @ 10265'. Correct CTD to 10250'. Printed: 3/17/2003 9:41:30 AM ) '\ ) ARCO . Operations Summary Rèport PROD1 MAD pass resistivity from TD to window. Make +2' correction. PROD1 Shallow resistivity reading higher than deep resistivity. Town geologists wants to stop drilling and confirm readings. Relog from 9,860' to 9,750' to confirm tool readings. Repeat pass shows same readings. 10,252'. Drill at 2.7 bpm, 3130 psi, 170 fph, TF=12R. Orient. Not getting clicks. Pull up hole to orient. Still not getting clicks. Pull into casing. Getting clicks one for one. RIH. Orient one click to 80L. Drill from 10,252' to 10,340'. Drill to 10,369'. TF=40L. Orient to 80L. Drill to 10,392'. Geology wants to drop 2 deg. of inclination. Orient to 110 left. Drill from 10,392' to 10,422'. Not getting necessary left hand turn rate. Best left hand turn rate in the last 120' is 6 degree/100' dog leg. Need 12 degree dog legs to stay inside the north polygon boundary. Decide to trip for 1.69 deg motor. POH to change to 1.69 degree motor. Down load MWD. Change motor bend to 1.69. Change out MWD tools (pulser, DIRlGRlRESrrM). Initialize tools & M/U coil. RIH with BHA #3. SHT tools @ 600' - OK. Continue RIH. Tag up @ 9688' (window). PUH & check TF - 40R. Orient TF to LS & run thru window. Continue RIH. Tag TD @ 10439'. Correct CTD to 10422'. MAD pass resistivity from TD to 10150' @ 160fph. Deep resistivity now reading higher than the shallow resistivity (as expected) - could be that last RES tool was faulty. Geo wants to continue logging to window. Continue MAD pass resistivity from to window @ 800fph. Tie-into RA pip tag & added 1.6' to CTD. RBIH to btm. Drill to 10478' with 70-90L TF, 2.6/2.6bpm, 2800/3150psi, 140fph ave ROP. TF walking to the right. Orient TF to 120L. Drill to 10497' with 110-90L TF, 2.6/2.6bpm, 2800/3150psi, 70fph ave ROP. Seeing average of 13degs/100ft turns. Orient TF to 95L. Drill to 10600' with 95L TF, 2.6/2.6bpm, 2800/3150psi, 80fph ave ROP. Wiper clean to window. RBIH. Orient & drill to 10627' with 95-100L TF, 2.6/2.6bpm, 2800/3200psi, 60fph ave ROP. Orient & drill to 10643' with 80L TF, 2.6/2.6bpm, 2800/3200psi, 45fph ave ROP. TF walking right. Orient TF around to 105L. Drill to 10724' with 85L TF, 2.6/2.6bpm, 2800/3150psi, 160fph ave ROP. Orient TF around to 105L. Drill to 10,750'. Wiper trip to 9,700'. RIH. No over pulls. Drill at 2.7 bpm, 3,440 psi, TF=70L - 90L. ROP slowed down to 40 fph. Drill to 10,803'. Orient to 74R. Drill at 2.7 bpm, 3,440 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-57(10) P2-57(10) REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From- To Hours Task Code NPT Phase 3/11/2003 17:20 - 19:25 19:25 - 21 :30 2.08 DRILL P 2.08 DRILL N 21 :30 - 22:00 0.50 DRILL P PROD1 22:00 - 23:20 1.33 DRILL P PROD1 23:20 - 00:00 0.67 DRILL P PROD1 3/12/2003 00:00 - 00:35 0.58 DRILL P PROD1 00:35-01:10 0.58 DRILL P PROD1 01 :10 - 01 :30 0.33 DRILL P PROD1 01 :30 - 02:00 0.50 DRILL P PROD1 02:00 - 04:10 2.17 DRILL N DPRB PROD1 04:10 - 07:20 3.17 DRILL N DPRB PROD1 07:20 - 09:00 1.67 DRILL N DPRB PROD1 09:00 - 09:20 0.33 DRILL N DPRB PROD1 09:20 - 09:55 0.58 DRILL N DPRB PROD1 09:55 - 12:50 2.92 DRILL N DFAL PROD1 12:50 - 13:10 0.33 DRILL N DFAL PROD1 13:10 -13:40 0.50 DRILL P PROD1 13:40 - 14:00 0.33 DRILL P PROD1 14:00 - 14:20 0.33 DRILL P PROD1 14:20 - 14:30 0.17 DRILL P PROD1 14:30 - 15:40 1.17 DRILL P PROD1 15:40 - 16:25 0.75 DRILL P PROD1 16:25 - 16:50 0.42 DRILL P PROD1 16:50 - 17:15 0.42 DRILL P PROD1 17:15 - 17:35 0.33 DRILL P PROD1 17:35-18:15 0.67 DRILL P PROD1 18:15 -18:50 0.58 DRILL P PROD1 18:50 - 19:50 1.00 DRILL P PROD1 19:50 - 22:45 2.92 DRILL P PROD1 Page 30f 7 Start: 3/9/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/12/1991 End: Description of Operations Printed: 3/17/2003 9:41:30AM ) ) ARGO Page·4 of? OperationsSu m maryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3/12/2003 3/13/2003 P2-57(10) P2-57(10) REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/9/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/12/1991 End: From - To Hours Task Code NPT Phase Description of Operations 19:50 - 22:45 2.92 DRILL P PROD1 psi, 70 - 90 fph. Rap picked up to 120 fph at 10,885' - 10,905'. TF falling to 95R. 22:45 - 23:05 0.33 DRILL P PROD1 Orient to 70R. 23:05 - 23:20 0.25 DRILL P PROD1 Drill to 10,925'. 23:20 - 00:00 0.67 DRILL P PROD1 Wiper trip to window. 00:00 - 00:35 0.58 DRILL P PROD1 RIH to 10,925'. 00:35 - 01 :00 0.42 DRILL P PROD1 Drill at 2.8 bpm, 3,500 psi, 3,200 psi off bottom, TF=74R, ROP=100 fph. Drill to 10,950'. 01 :00 - 01 :15 0.25 DRILL P PROD1 Orient to 90L. 01 :15 - 03:35 2.33 DRILL P PROD1 Drill at 2.8 bpm, 3,610 psi, 3,340 psi off bottom. TF=1 01 L, ROP=70 - 80 fph. Built angle from 92 to 94 deg. Increase WOB to get more reactive torque and break build trend. TF=135L, ROP=80 - 120 fph. Orient to 90L - 105L. Drill to TD at 11, 1 00' . 03:35 - 04:20 0.75 DRILL P PROD1 Wiper trip to window. 04:20 - 04:40 0.33 DRILL P PROD1 Tie in to RA tag. Add 3'. 04:40 - 05: 15 0.58 DRILL P PROD1 RIH and tag at 11,102', corrected TD. 05:15 - 05:25 0.17 DRILL P PROD1 Circulate 1.25 times OH annulus volume. 05:25 - 07:50 2.42 DRILL P PROD1 POH to run liner. Spot 29 bbls of new 9.8 ppg, 148,000 LSRV, 3% lubtex flo pro pill in OH. Paint EOP flags @ 9200' & 7800'. 07:50 - 09:30 1.67 DRILL P PROD1 Down load MWD & LID drilling BHA. Bit grades 1,1,1 09:30 - 10:00 0.50 CASE P CaMP Cut 8' of CT. M/U Baker CTC. Pull test to 35k & P/test to 3500 psi - OK. 10:00 - 11 :00 1.00 CASE P CaMP Load wiper dart, launch & check. Chase dart with mud & pig CT. Dart bumped on catcher @ 59.2bbls. 11 :00 - 11 :30 0.50 CASE P CaMP R/U to run liner. 11 :30 - 11 :45 0.25 CASE P CaMP PJSM & HA/HM for running liner. Review procedures & discussed well control scenarios. 11 :45 - 14:00 2.25 CASE P CaMP M/U 24 jts 2-7/8" perforated, 5 jts solid 6.16# L-80 STL x/a to 28 jts 3-3/16" 6.2# L-80 TC11 liners with float equipment, pup jts, diverter collar, perforated pup & a-ring sub. 14:00 - 14:30 0.50 CASE P CaMP R/U Baker handling tools (false table, bowl & slips) for 1-1/4" CSH. Meanwhile carryout environmental compliance audit & pass with flying colors. 14:30 - 15:00 0.50 CASE N WAIT CaMP W.o. Baker slip elevators as Nordic's own went in for repairs. 15:00 - 16:15 1.25 CASE P CaMP M/U 31 jts of 1-1/4" CHS tbg inner string. 16:15 - 17:00 0.75 CASE P CaMP Fill up 1-1/4" CSH & 3-3/16" TCII annulus. M/U landing CSH jt, land Baker stinger no-go twice on ORS & space out for 2.5'/4.5' stinger above/below ORS. LID landing jt. 17:00 - 17:30 0.50 CASE P CaMP M/U circ head on 1-1/4" CSH. Pump/test & confirm ORS/stinger pressure integrity. 17:30 - 18:45 1.25 CASE P CaMP M/U X/O, Howco 'x' nipple & Baker CTLRT w/ 1 1/4" CS Hydril inner string. 18:45 - 20:05 1.33 CASE P CaMP RIH w/ liner to EOP flag at 7800'. Correct depth, -13.1' correction. PU=44.8K, SO=22K. 20:05 - 20:45 0.67 CASE P CaMP Run liner into open hole. Tag bottom at 11,104'. PU=43K. 20:45 - 21 :50 1.08 CASE P CaMP Drop 5/8" phenolic ball and pump 44 bbls at 2.2 bpm. Slow rate to 0.3 bpm. Ball seated at 54 bbls. Pressure up to 2,800 psi to release from liner. PU 8' and verify liner is released. Slick stick came out of a-ring sub before weight broke over. Run back into top of liner and SO 10K. Bring up pump. Ball already sheared out of seat. 21 :50 - 00:00 2.17 CASE P CaMP Displace well to 9.7 ppg 3% KCI / NaCI brine from 10,270' to Printed: 3/17/2003 9:41 :30 AM ) ) ARGO Page50f 7 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-57(10) P2-57(10) REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/9/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/12/1991 End: Date From - To Hours Task Code NPT Phase Descri ption· of Operations 3/13/2003 21 :50 - 00:00 2.17 CASE P COMP surface. 3/14/2003 00:00 - 00:30 0.50 CASE P COMP Displace well to 9.7 ppg, 3% KCI brine. 00:30 - 01 :00 0.50 CEMT P COMP PJSM for cement job. 01 :00 - 01 :25 0.42 CEMT P COMP Batch mix cement and prime pumps. Mix 30 bbl biozan/brine pill. 01 :25 - 02:30 1.08 CEMT P COMP Pump 5 bbls of water. Pressure test lines to 4,000 psi. Pump 15 bbls of 15.8 ppg class G expansive cement with 3% Mag. Oxide BWOC at 2.0 bpm, 1,760 psi. Drop CT wiper dart Shut in reel. Wash lines. Pump 0.2 bbls of 9.7 ppg biozan brine pill to launch dart. Shut down and confirm dart lanched. Displace cement with 28 bbls of 9.7 ppg, 3% KCI, biozan pill followed with 9.7 ppg, 3% KCI brine at 2.2 bpm, 1,400 psi - 2,300 psi when cement reached CS hydril. Slow pump to 1.1 bpm, 740 psi at 55 bbls pumped. Bump plug to 930 psi at 60.3 bbls. Bleed CT to 500 psi. CIP at 02:30. Full returns during job. 02:30 - 02:40 0.17 CEMT P COMP PU to pull out of liner. Weight broke over at 46K then came up to 60K. Weight fell off and lost pressure on CT, (plug sheared?). Pick up with excess drag, ratty, and weight came back to 60K. Weight fell off. PU and weight came back to 60K. Stopped and pumped -0.9 bbls at -300 psi down coil to see if plug actually sheared or if dart was in 1 1/4" CS Hydril stinger. Weight fell off, got returns and shut down pump (may have been vacume locked). Pumped 0.9 bbls total. Note: (Had 10K set down on liner and depth read 11,110'. Picked up 28' on depth counter prior to pumping the 0.9 bbls). 02:40 - 04:20 1.67 CEMT P COMP POH to 9,200', above liner top, filling hole down the back side. Shut in returns and POH filling hole with biozan pill followed by brine thru CT. Did not take returns while POH. 04:20 - 07:00 2.67 CEMT P COMP Stand back 1 1/4" CS Hydril. LD Baker CTLRT. Recovered CT/CSH dart. 07:00 - 07:15 0.25 CLEAN P COMP PJSM for liner cleanout run. 07:15 - 10:00 2.75 CLEAN P COMP M/U liner cleanout BHA with new 2.3" 0331 mill, 2-1/8" motor, up jar, 62jts of 1-1/4" CSH & lower/upper MHAs. Circ new CSH to ensure no scale plug off. M/U Coil. 10:00 - 11 :25 1.42 CLEAN P COMP RIH with liner cleanout BHA to 9100'. Up wt check - 33k. Park Mill @ 9000' to wait for cement to reach 2000psi compressive strength. 11 :25 - 13:45 2.33 CLEAN P COMP W. O. Cement Meanwhile W. O. reconditioned mud (truck shortage). 13:45 - 14:45 1.00 CLEAN P COMP Line up to test liner lap. OS lab confirms compressive strength of cmt - >2000psi. WH/IAlOA @ 0/-3/6psi @ onset of test Staged up WH/IAlOA to 2000/-3/6psi. After 5mins we have WH/IAlOA @ 1150/175/7psi. After 15mins we have WH/IAlOA @ 660/190/7psi. Repeat test & lost 11 OOpsi in 18 mins. Ask Baker to prep a L TP. Will test BS before setting L TP. 14:45 - 15:25 0.67 CLEAN P COMP RIH cleanout BHA & seeing slight motor work from 10135'. 15:25 - 16:00 0.58 CLEAN P COMP PUH to 9900' & circulate down reconditioned 9.7ppg, 38k LSRV flopro mud to mill @ 1.5bpm & 2200psi. 16:00 - 16:30 0.50 CLEAN P COMP Wash & precautionary ream down @ 1.5bpm, 2200/psi & 625fph. Tag O-ring sub @ 10251'. 16:30 -18:00 1.50 CLEAN P COMP Mill thru O-Rig sub with 1.5/1.5bpm, 2500psi & 4 stalls. Mill to 10253'. Having clean PIUs @ 34k. Printed: 3/17/2003 9:41 :30 AM ) ) ARGO Page 6 of 7 OperatiönsSurnmary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-57(10) P2-57(10) REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/9/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/12/1991 End: Date From-To Hours Task Code NPT Phase Descri ptionof Operations 3/14/2003 18:00 -18:10 0.17 CLEAN P COMP Wash down thru 10' pup to float collar tagged @ 10264'. Observe no hard cement. 18:10 - 00:00 5.83 CLEAN P COMP Mill the float collar with 1.5/1.5bpm, 2500/2650psi. Mill 15' of hard cement below float collar to baffle plate. Mill baffle plate. Cement returns in mud verified by pH and phenolphthaline. 3/15/2003 00:00 - 00:30 0.50 CLEAN P COMP Mill through baffle plate and RIH below to 10,400'. Clear below baffle plate. 00:30 - 01 :00 0.50 CLEAN P COMP Pull up hole to above liner top and chase cuttings out of liner. 01 :00 - 02:20 1.33 CLEAN P COMP RIH. Wipe through area from 10,240' to 10,288' and make sure milled area is clean. PU to 10,235' and drift down to 10,290' w/o pump, clear accesses. RIH and tag guide shoe at 11 ,1 09'. 02:20 - 06:00 3.67 CLEAN P COMP Displace liner and well bore to 9.7 ppg, 3% KCI brine. POH to above liner top. Drop ball to open circ. sub. POH. 06:00 - 07:30 1.50 CLEAN P COMP OOH. PJSM. SIB 1-1/4" CSH & LID jar, motor & mill. Recover 1/2" ball from circ sub. 07:30 - 07:45 0.25 EVAL P COMP R/U for CNL job. C/O circ sub. 07:45 - 10:45 3.00 EVAL N SFAL COMP Wait for logging crew to rectify/replace faulty computers in Schlumberger logging unit. Had to reboot computers with a system floppy and pull/re-install motherboard to get it to work. Calibrate & check out loggings tools OK. Load logging tools into pipe shed. 10:45 -11:00 0.25 EVAL P COMP Held PJSM for RIH & logging MCNLlCCLlGR. 11 :00 - 12:30 1.50 EVAL P COMP P/U logging/cleanout BHA #7 (1966.24') with 2.3" mill on 2-1/8" motor, CNLlCCLlGR logging tool carrier & 62 jts of 1-1/4" CSH tbg. M/U injector. 12:30 - 13:50 1.33 EVAL P COMP RIH BHA#7 on CT to 9000'. 13:50-15:10 1.33 EVAL P COMP Log down @ 30fpm from 9000' to guide shoe tagged @ 11116'. 15:10 - 15:45 0.58 EVAL P COMP Log up @ 60fpm from shoe to 9000'. 15:45 - 17:30 1.75 EVAL P COMP POOH from 9000'. 17:30 - 17:45 0.25 EVAL P COMP Pop off & drop 1/2" ball to open circ. sub. 17:45-18:15 0.50 EVAL P COMP Crew change & PJSM on RIB CSH 18:15-19:30 1.25 EVAL P COMP Stand back CSH. PJSM on RA source. LD logging tools. 19:30 - 21:15 1.75 EVAL P COMP Down load logging tools. Process log to determine spaceout of liner top packer. No pups needed. 21 :15 - 23:30 2.25 CASE P COMP MU liner top packer. RIH. 23:30 - 00:00 0.50 CASE P COMP Sting into deployment sleeve with seal assembly while pumping at minimum rate. Confirm seals are stung in with pressure increase. Bleed off CT pressure. Prior to test TII/O = 0/ 134 / 10 psi. Test liner lap. Pressure up to 2,000 psi. IA came up to 400 psi. Pressure fell to 1,171 psi in 9 minutes and IA came up to 555 psi. Bleed off pressure back side pressure. Bad test. Will need to set liner top packer. 3/16/2003 00:00 - 00:45 0.75 CASE COMP Drop ball to set liner top packer. Pump until ball seats. 00:45 - 01:45 1.00 CASE COMP Sting seals into deployment sleeve. Test backside to confirm seals are stung into deployment sleeve. Pressure up to 2,000 psi, IA=640 psi. Lost 75 psi in 10 minutes. Looks like it's holding this time. Bleed IA to 220 psi to diagnose. Tubing pressure decreased as expected and leveled off at 1,808 psi after IA was shut in. IA held at 220 psi. Bleed pressure off tubing and IA. Printed: 3/17/2003 9:41 :30 AM ) ) ARCO Page7of7 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-57(10) P2-57(10) REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/9/2003 Rig Release: 3/16/2003 Rig Number: Spud Date: 6/12/1991 End: Date From ~ To Hours Task Code NPT Phase Description of Operations 3/16/2003 01 :45 - 02:30 0.75 CASE CaMP Repeat liner lap test. Prior to test T/I/O 0/0/10. Pressure up to 2,000 psi. IA=141 psi. Hold for 20 minutes. Final pressure on backside, 1,910 psi. Fina11A=141 psi. Good test. Discuss options with Anchorage. Decide to pull liner top packer to preserve the use of the 'X' nipple in the liner and the larger 10. 02:30 - 04:30 2.00 CASE CaMP POH with liner top packer. Unable to pump down coil due to ball on seat to set packer. Pump down the backside taking no returns to fill the hole. 04:30 - 05:30 1.00 CASE CaMP Stand back injector. LD liner top packer. MU nozzle. Stab injector. 05:30 - 07:40 2.17 CASE CaMP RIH nozzle to 9250'. 07:40 - 07:45 0.08 CASE CaMP Circulate 20bbls of 3% KCL out of nozzle @ 2.6bpm & 2050psi. 07:45 - 09:00 1.25 CASE CaMP POOH displacing well to 3% KCL @ 2.5bpm/1750psi & holding back 55psi/1 OOOft + 50psi WHP. 09:00 - 10:00 1.00 CASE POST POOH from 2200' freeze protecting with 60/40 MeOH. SI master (32 turns) & swab (27 turns) with 495psi final WHP. 10:00 - 10:30 0.50 RIGD POST OOH. UD nozzle & stinger. SIB injector & circ fresh water thru CT to eliminate any corrosion from residual salts after blowing down. 10:30 - 11 :30 1.00 RIGD POST Well has a 7-1/16" flange from BOP X/O to 4-1/16" spool x/a to 5-1/8" tree. Thus cannot set the planned 5-1/8" BPV. Review situation with town & agree to move off well with a closed master, SSV & swab valves. DSO close SSV. 11 :30 - 11 :45 0.25 RIGD POST MIRU OS N2 unit. 11:45 - 12:00 0.25 RIGD POST PJSM for blowing down CT with N2. 12:00-13:15 1.25 RIGD POST Flush CT with 50 bbls of fresh water. Pump 5bbls of MeOH spacer. PT N2. Blow down CT with N2 & bleed off 13:15 - 14:00 0.75 RIGD POST PJSM. Unstab CT, pull back to reel & secure. Wind gusting @ 18.7mph max & 14mph ave - plan to swap out CT reels & BOP ram sizes before moving onto P2-54. 14:00 -14:15 0.25 RIGD POST PJSM on swapping out reels with Peak crane crew. Also discuss overhead power line crossing. 14:15 -17:00 2.75 RIGD POST Swap reels from 2-3/8" to 2" CT with Peak crane. Change out both reel bushings. Meanwhile cleanout pits. 17:00 - 18:00 1.00 RIGD POST Changeout packoff, remove injector legs & set injector on floor in preparation for gripper blocks chageout. 18:00 - 21:00 3.00 RIGD POST Changeout BOP combi ram configuration to (btms up): 2" pipe/slip, 2-3/8" pipe/slip & 2" pipe/slip. NO BOP. 21 :00 - 23:00 2.00 RIGD POST Change out 51/8" x 4 1/16" XO flange on tree. Install tree cap and test tree. Secure well. Release rig at 23:00. Hold PJSM for moving off P2-57 and moving on P2-54. 23:00 - 00:00 1.00 RIGD POST Move rig to P2-54 Printed: 3/17/2003 9:41 :30 AM ) 02-Apr-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well P2-57 A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 9,643.29' MD Window / Kickoff Survey: 9,660.00' MD (if applicable) Projected Survey: 11,102.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED APR 1 7 2003 Alaska Of; & Ga" I"~_ ~ IoNfJ$. Carom' . AnåJOIðge ~ ;;; () él- ¡;( It¡ Sperry-Sun Drilling Services North Slope Alaska BPXA P2-57 A -......;.."/' Job No. AKMW2326440, Surveyed: 13 March, 2003 Survey Report 26 March, 2003 Your Ref: API 500292218301 Surface Coordinates: 5997987.30 N, 681470.61 E (70023' 58.9722" N, 148031'22.7735" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing: 41.00ft above Mean Sea Level _/ spe..........y-sul! DRILLING SERVIc:es A Halliburton Company Survey Ref: svy3997 Sperry-Sun Drilling Services Survey Report for P2·57 A Your Ref: AP/500292218301 Job No. AKMW2326440, Surveyed: 13 March, 2003 BP EXPLORA TION (ALASKA) INC. BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 9643.29 23.870 193.850 8563.95 8604.95 3945.07 S 486.30 W 5994031.58 N 681080.25 E -486.30 Tie On Point MWD Magnetic 9660.00 23.880 193.720 8579.23 8620.23 3951.64 S 487.91 W 5994024.98 N 681078.80 E 0.320 -487.91 Window Point 9690.53 18.940 174.680 8607.68 8648.68 3962.60 S 488.92 W 5994014.00 N 681078.06 E 27.738 -488.92 9735.16 18.950 140.070 8650.03 8691.03 3975.41 S 483.58 W 5994001.32 N 681083.71 E 24.835 -483.58 9776.33 25.550 115.240 8688.19 8729.19 3984.35 S 471.22 W 5993992.68 N 681096.28 E 27.581 -471.22 9806.33 25.990 89.510 8715.30 8756.30 3987.06 S 458.76 W 5993990.28 N 681108.81 E 37.061 -458.76 --, 9836.88 33.830 74.360 8741.79 8782.79 3984.70 S 443.83 W 5993993.00 N 681123.67 E 35.465 -443.83 9867.83 44.230 69.770 8765.81 8806.81 3978.63 S 425.35 W 5993999.52 N 681142.00 E 34.857 -425.35 9904.68 58.590 69.600 8788.73 8829.73 3968.65 S 398.41 W 5994010.14 N 681168.69 E 38.970 -398.41 9934.13 70.400 67.310 8801.39 8842.39 3958.88 S 373.74 W 5994020.51 N 681193.11 E 40.708 -373.74 9962.48 80.970 68.010 8808.39 8849.39 3948.46 S 348.37 W 5994031.54 N 681218.22 E 37.360 -348.37 10005.71 85.110 49.510 8813.68 8854.68 3926.28 S 311.87 W 5994054.60 N 681254.18 E 43.533 -311.87 10038.03 85.550 37.350 8816.32 8857.32 3902.93 S 289.77 W 5994078.48 N 681275.70 E 37.523 -289.77 10065.93 84.850 27.660 8818.66 8859.66 3879.52 S 274.84 W 5994102.25 N 681290.05 E 34.700 -274.84 10107.66 83.260 12.860 8823.00 8864.00 3840.69 S 260.50 W 5994141.41 N 681303.45 E 35.478 -260.50 10136.61 85.900 4.580 8825.74 8866.74 3812.23 S 256.14 W 5994169.97 N 681307.11 E 29.895 -256.14 10172.88 87.050 354.180 8827.98 8868.98 3776.08 S 256.54 W 5994206.10 N 681305.84 E 28.794 -256.54 10203.98 86.340 340.260 8829.78 8870.78 3745.88 S 263.39 W 5994236.13 N 681298.26 E 44.742 -263.39 10261.46 85.730 325.280 8833.78 8874.78 3695.04 S 289.55 W 5994286.32 N 681270.88 E 26.020 -289.55 10292.89 88.990 326.340 8835.22 8876.22 3669.07 S 307.19 W 5994311.85 N 681252.61 E 10.906 -307.19 10324.19 88.460 324.400 8835.92 8876.92 3643.32 S 324.97 W 5994337.16 N 681234.21 E 6.424 -324.97 10357.89 91.810 322.640 8835.84 8876.84 3616.23 S 345.00 W 5994363.76 N 681213.52 E 11.229 -345.00 10395.31 92.160 322.640 8834.54 8875.54 3586.51 S 367.69 W 5994392.92 N 681190.12 E 0.935 -367.69 ~ 10426.29 90.660 317.000 8833.78 8874.78 3562.86 S 387.67 W 5994416.08 N 681169.57 E 18.832 -387.67 10454.34 93.390 313.300 8832.79 8873.79 3542.99 S 407.43 W 5994435.46 N 681149.33 E 16.385 -407.43 10484.59 93.920 309.070 8830.86 8871.86 3523.11 S 430.15 W 5994454.78 N' 681126.14 E 14.065 -430.15 10515.81 92.860 303.610 8829.01 8870.01 3504.65 S 455.24 W 5994472.63 N 681100.61 E 17.785 -455.24 10544.96 92.070 297.970 8827.76 8868.76 3489.75 S 480.25 W 5994486.92 N 681075.24 E 19.519 -480.25 10574.56 91.720 293.210 8826.78 8867.78 3476.98 S 506.92 W 5994499.04 N 681048.27 E 16.116 -506.92 10604.06 89.780 286.870 8826.39 8867.39 3466.87 S 534.62 W 5994508.47 N 681020.33 E 22.472 -534.62 26 March. 2003 - 12:29 Page 2 of4 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for P2-57A Your Ref: AP/5oo292218301 Job No. AKMW232644o, Surveyed: 13 March, 2003 BP EXPLORA T/ON (ALASKA) INC. BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10632.59 93.480 282.460 8825.58 8866.58 3459.66 S 562.20 W 5994515.01 N 680992.59 E 20.170 -562.20 10668.37 94.450 277.180 8823.11 8864.11 3453.57 S 597.36 W 5994520.24 N 680957.29 E 14.969 -597.36 10702.19 94.890 272.240 8820.35 8861.35 3450.80 S 630.94 W 5994522.19 N 680923.65 E 14.616 -630.94 10784.87 93.920 266.950 8817.84 8858.84 3451.03 S 663.51 W 5994521.17 N 680891.10 E 16.410 -663.51 10766.87 90.480 260.610 8816.61 8857.61 3454.50 S 695.28 W 5994516.94 N 680859.43 E 22.526 -695.28 10796.99 91 .720 256.730 8816.03 8857.03 3460.41 S 724.80 W 5994510.31 N 680830.06 E 13.521 -724.80 92.690 261 .490 8814.73 8855.73 3466.81 S 758.03 W 5994503.11 N 680796.99 E 14.328 -758.03 -~ 10830.87 10860.12 93.040 268.360 8813.26 8854.26 3469.39 S 787.11 W 5994499.82 N 680767.98 E 23.488 -787.11 10890.64 91.810 275.060 8811.97 8852.97 3468.48 S 817.57 W 5994499.99 N 680737.50 E 22.300 -817.57 10923.19 94.270 280.880 8810.24 8851 .24 3463.98 S 849.75 W 5994503.71 N 680705.23 E 19.387 -849.75 10957.29 93.390 285.460 8807.96 8848.96 3456.23 S 882.87 W 5994510.65 N 680671.93 E 13.647 -882.87 10993.59 93.660 279.110 8805.73 8846.73 3448.52 S 918.25 W 5994517.50 N 680636.37 E 17.476 -918.25 11025.59 92.160 277.180 8804.10 8845.10 3443.99 S 949.89 W 5994521.26 N 680604.64 E 7.632 -949.89 11058.92 87.670 273.650 8804.15 8845.15 3440.85 S 983.05 W 5994523.59 N 680571.40 E 17.134 -983.05 11102.00 87.670 273.650 8805.91 8846.91 3438.11 S 1026.01 W 5994525.29 N 680528.39 E 0.000 -1026.01 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastin9s are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 90.000° (True). Magnetic Declination at Surface is 26.074°(06-Mar-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 111 02.00ft., The Bottom Hole Displacement is 3587.94ft., in the Direction of 196.616° (True). ~ 26 March, 2003 - 12:29 Page 3 0'4 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for P2-57A Your Ref: AP/500292218301 Job No. AKMW2326440, Surveyed: 13 March, 2003 BP EXPLORA T/ON (ALASKA) INC. North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastlngs (ft) (ft) (ft) Comment 9643.29 9660.00 11102.00 8604.95 8620.23 8846.91 3945.07 S 3951.64 S 3438.11 S 486.30 W 487.91 W 1026.01 W Tie On Point Window Point Projected Survey -/ Survey tool proaram for P2-57A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9643.29 0.00 9643.29 8604.95 11102.00 8604.95 BP High Accuracy Gyro(P2-57) 8846.91 MWD Magnetic(P2-57A) ~ 26 March. 2003 - 12:29 Page 4 of4 DrillQuest 3.03.02.002 ) ~~fA\lE ~~ fA\~fA\~íßfA\ AI/A.~1iA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7fH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276·7542 Mark O. Johnson CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Point McIntrye P2-57 A BP Exploration (Alaska), Inc. Permit No: 202-214 Surface Location: 594' SNL, 1220', EWL, Sec. 14, TI2N, RI4E, UM Bottomhole Location: 3706' SNL, 143' EWL, Sec. 14,TI2N, RI4E, 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. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~ð~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this ;1.oM.day of November, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. I') STATE OF ALASKA ). ALASKA (.,1&_ AND GAS CONSERVATION COMMlbv¡ON PER~IT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 11'I Development Oil [J Service [J Development Gas [J Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 41' Point Mcintyre 6. Property Designation ADL 034624 7. Unit or Property Name Point Mcintyre 8. Well Number / P2-57 A 9. Approximate spud date 12/01/02 ¿ Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 11500' MD / 8830' TVDss o 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)} 91 Maximum surface 3371 psig, At total depth (TVD) 8787' / 4250 psig Setting Depth TaD Bottom Quantitv of Cement Lenath MD TVD MD TVD (include staae data) 2250' 9250' 8205' 11500' 8830' 64 sx Class 'G' / 1 a. Type of work [J Drill 11'I Redrill [J Re-Entry [J 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 594' SNL, 1220' EWL, SEC. 14, T12N, R14E, UM At top of productive interval 4531' SNL, 731' EWL, SEC. 14, T12N, R14E, UM At total depth 3706' SNL, 143' EWL, SEC. 14, T12N, R14E, UM VJ Ä It- ii' I AI" t- 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 12. Distance to nearest property line 13. Distance to nearest well /' ADL 028297,143' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 9630' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casina Weiaht Grade CouDlina 3-3/4" 3-3I16"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 1 0113 feet 9034 feet 10020 feet 8949 feet Length Size Structural Conductor Surface Intermediate Production Liner 104' 20" 4364' 13-3/8" 9560' 9-5/8" 879' 7" Perforation depth: measured 9824' - 9904' true vertical 8770' - 8843' Plugs (measured) Junk (measured) Cemented MD TVD 440 sx Coldset II 104' 104' 1670 sx AS III, 350 sx 'G', 4364' 4019' Top Job: 175 sx AS I 650 sx Class 'G' 9560' 8529' 300 sx Class 'G' 9233' - 10112' 8230' - 9033' R!€BIVED OCT 2 1 2002 AlasKa 0"'& Gas eons. commtsslon [J Diverter Sketch 11'I Drillin&K-ùJ~~ [J Seabed Report [J 20 AAC 25.050 Requirements Prepared By Name/Number: Terrie Hubble, 564-4628 11'I Filing Fee [J Property Plat 11'I BOP Sketch 11'I Drilling Fluid Program [J Time vs Depth Plot [J Refraction Analysis Contact Engineer Name/Number: Mark Johnson, 564-5666 20. Attachments correct to the best of my knowledge Title CT Drilling Engineer ·,·;~·:(:I,~mr-mjs$ión·..Use:OnIY· Date /o/ufo L- API N er 50- 0 -22183-01 Samples Required 0 Yes B No Hydrogen Sulfide Measures 181 Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other:«s t- ßo PL= Iv 3S"00 r'~{. QRIGINAL SIGNED BY M L. BII 21. I hereby certify that the foregoing is tru Signed MarkJohnson ~ Ú. Permit Number 2r) 2. - ...2. J ¿¡ Conditions of Approval: Approved By Form 10-401 Rev. 12-01-85 APpr1\i~pP.~~ n See cover letter \ ':}\( J L) ~ for other reauirements Mud Log ReqJired ,DYes WNo Directional Survey Required .a Yes 0 No o 4K D5K D10K D15K 0 3.5K psi for CTU by order of L1!. ' 1~.·.s1i~., r~ r\ ~ /\.hr.commission . ~., , ~ '1 III! \!1 :".~ ',-.. ~\ ~ \.,j Ü a d R \ Date '~i¡;;fQ,~e ) ") BP P2-57 A Sidetrack Summarv of Operations: / A CTD through tubing sidetrack is. planned for well P2-57. The coil sidetrack, P2-57A, will exit the 7" liner and target Zone LB 1./ A whipstock will be set at 9660' (nd the perfs below will be P&A'd with cement (form 10-403 submitted). CTD will sidetrack out of the 7" liner and drill to a TD of'""' 11500'. The production liner will be a cemented 3 3/16" solid" x 2 7/8" slotted liner bonzai completion. Phase 1: Prep work. Planned for November 7,2002. 1. Slickline - Drift for whipstock and caliper tubing/casing. Tag bottom. Dummy GL V s as necessary. PT inner annulus to 2500 psi. PT outer annulus to 2400 psi. 2. E-line - Set 4 1h" x 7" whipstock at 9660' md. 3. Service coil-Pump 15.8 ppg class G ceIDent down past the whipstock to P&A the wellbore perforations. Pump a total of'28J3bl of 15.8 ppg class G cement during the job. Cement will be cleaned out down to t~",hipstock tray. 4. wac. Pressure test wellbore to 1000 psi. P&A complete. If the cement were to fail the pressure test, a second squeeze is not planned since this portion of the wellbore will be isolated by cement during the primary cement job of the new sidetrack liner. Phase 2: Mill window, Drill and Complete sidetrack: Planned for December 1, 2002. ~ 1. :rvnR.U CTD rig 2. Mill out XN nipple and mill 3.8" sidetrack window from whipstock at 9660'. /. 3. Drill 3.75" openhole to '""'11500' TD with MWD/GR. / 4. Run and cement 3 3/16" x 2 7/8" bonzai cemented/slotted liner completion. The 3 3/16" liner portion will be solid from 9250' (TaL) to 10620' and cemented trom 9400-10600'....- The 2 7/8" liner section will be slotted from 10620' to 11500' TD. /" 5. RDMO. Mud Program: · Phase 1: Seawater · Phase 2: Mill with seawater/biozan, drill with Flo-Pro (9.4-9.6 ppg) ./ 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: · 3 3/16" x 2 7/8" bonzai cemented/slotted liner completion. The 3 3/16" liner portion will be solid from 9250' (TOL) to 10620' and cemented from 9400-10600', The 2 7/8" liner section wi~otted from 10620' to 11500' TD. Liner cement (15.8 ppg class G) volume is planned to b~bls. Well Control: · BOP diagram is attached. / · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. ) ') Directional · See attached directional plan. Max. planned hole angle is 92 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray log will be run over all of the open hole section. Hazards /' . The highest H2S iTom P2-57 was 20 ppm on 9/23/02. PM2 is not an H2S pad. . Drilling near faults, but with low risk of lost circulation. Reservoir Pressure Res. press. is estimated to be 4250 psi at 8787'ss (9.3 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 3371psi. / MOJ 10/17/02 TREE = , _? WELLHEAD = CALICO-CIW/IVICEVOY ·Ä·ëfüÃTÕR'·,;;··_···················_····AXËlSÕf.j· ·KB.··Ëi.:Ë.V·;;·······..····································¡1'; ·s·F.··Ëlë\ï;;···· ··················..················..····6;· ·KÕp·;;·······..······· ················..········..·····1469; ·;.¡;äx·Ãngïë··;·· ......m..m·····..····34·(~·"31·ÖÖ;· . Däiüiiïi\ñ·ö·,;;...· ........... ......... ···············9S·Ö1·; ................................................................................................................................... Datum TVD = 8800' SS ) 13-3/8" CSG, 68#, L-80, ID = 12.415" 1-1 4364" ~ Minimum ID = 3.80" @ 9283' OTIS XN NIPPLE 5-1/2" TOO-lPG, 17#, L-80, .0232 bpf, ID= 4.892" 1-1 9202' 1 . TOP OF 7" LNR 1-1 9232' 14-1/2" TBG-IPC, 12.6#, L-80, .0152 bpf, ID= 3.958" l-i 9-5/8" CSG, 47#, L-80, ID= 8.681" l-i 9296' 9560' ÆRFORA TION SUMMARY REF LOG: DLUMSFLlGRlSPON 07/05/91 ANGLEAT TOP PERF: 24@9824' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9824-9904 isolated proposed I PBTD 1-1 10020' 7" LNR, 29#, L-80, 0.0371 bpf, ID= 6.184" l-i 10113' P2-57 A ~ ~ l ')FETY NOTES Proposed CrD Sidetrack I 2223' 1-1 5-1/2" OTIS HRQ SVLN, ID = 4.89" I . ~ ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2669 2584 29 MMG RK 2 5821 5262 31 MMG RK 3 7811 6979 30 MMG RK 4 8943 7967 26 MOO RK 5 9067 8079 25 MMG RKP L :8: :& 9181' 1-1 9-5/8" x 5-1/2" BA KER SB-3A PKR I 9202' 9250' 9260' 9283' 9296' DATE 07/04191 11/28/00 02/21/01 09/04/01 10/17/02 SIS-lsl SIS-LG RNITP MOJ COMMENTS II DA TE I REV BY ORK3INAL COMPLETION (FORMERLY PM-10) CONVERTED TO CANVAS REV IS ION CORRECTIONS A'oposed sidetrack REV BY 10600' 1-1 Bottom of Bonzai Cement I I 10620' 1-13-3/16 x 2-7/8 X-over ~ 000000 ~ I 1 I r l : ~~ " I ~ ~ ~: ... "... 1:::::::::/:: ..... ....... .......... .. ... .. .- .. 9400' 1-1 \5-1/2" X 4-1/2" BAKER XO I I-ITop of 3-3/16" Liner I 1-13.5" XN Nipple I 1-1 4-1/2" OTIS XN NIP, ID = 3.725" 1 1-1 4-1/2" TUBING TAIL, SHEAR SUBIWLEG 1-1 ELMO TT NOT LOGGED I -ITop of Cement 2-7/8" pre-drilled liner 9660' 1--1 Mechanical Whipstock 1-1 11500' I I COMMENTS POINT MCINTY RE UNIT WELL: P2-57 PERMIT No: 91-079 API No: 50-029-22183-00 SEC 14, T12N, R14E 4594.12 FEL 4724.66 FNL BP Exploration (Alaska) TREE= · _7 WELLHEAD = CALICO-CIVV/fv'K;EVOY ·Ä·ëfüÃroif;··..···········........····AxËlsÕN· l<:ã··ËlË.\Ï·;;_···· ······································-·41·; ·ší=..·ËlË\,,;;;·············································"if ·j(op·;;;············· ··...·····························-14·69; ·Mä;¡-Ãiig·të··.;;···························34·@··31·ÖÖõ· . õäiüiiïÑIÖ·;···· ........ ... ························99"Ö1·; ·~t~·m·iVD·;···...·········..··········...ä"iiöö;·sš· ) P2-57 l SAFETY NOTES ") - 2223' 1-1 5-1/2" OTIS HRQ SVLN, ID= 4.89"1 13-3/8" CSG, 68#, L-80, ID= 12.415" 1-1 4364' ~ ~ GAS LIFT MANDRELS ST MD lVD DEV TYPE VLV LATCH PORT DATE 1 2669 2584 29 MMG RK 2 5821 5262 31 MMG RK 3 7811 6979 30 MMG RK 4 8943 7967 26 MOO RK 5 9067 8079 25 MMG RKP L Minimum ID = 3.725" @ 9283' OTIS XN NIPPLE :8: & 9181' 1-1 9-5/8" x 5-1/2" BAKER SB-3A PKR I 5-1/2" Too-IPC. 17#, L-80, .0232 bpf, ID= 4.892" 1-1 9202' " ,/ I 9202' 1-1 5-1/2" x 4-112" BAKER XO 1 I TOP OF 7" LNR 1-1 9232' ill ..... ~ r 1 9283' 1-1 4-1/2" OTIS XN NIP, ID = 3.725" I 14-1/2" TBG-IPC, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 9296' I 9296' 1-1 4-1/2" TUBING TAIL, SHEAR SUB/WLEG ~ ~ 1-1 ELMD TT NOT LOGGED I 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 9560' PERFORA TION SUMMA RY REF LOG: DLLlMSFLlGRlSPON 07/05/91 ANGLE AT TOP PERF: 24 @ 9824' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9824-9904 0 11/14/93 I PBTD l-i 10020' ~ 7" LNR, 29#, L-80, 0.0371 bpf, ID= 6.184" 1-1 10113' DATE 07104191 11128/00 02/21/01 09/04/01 SlS-lsl SIS-LG RNITP COMMENTS II DATE I REV BY ORIGINAL COMA-ErION (FORMERLY PM-10) CONVERTED TO CANVAS REV ISION CORRECTIONS COMMENTS POINT MCINTYRE UNIT WELL: Pl-57 PERMIT No: 91-079 API No: 50-029-22183-00 SEC 14, T12N. R14E 4594.12 FEL 4724.66 FNL BP Exploration (Alaska) REV BY Plan: Plan .11 (P2-S7/Plant11 P2-S7A) Created By: Brij PoInis Date: 101712002 Direct: (907) 267 -6613 E-mail: brij_potnis.@inteQ_com Baker Hughes INTEQ: (907) 267--6600 ~. --' 1017/2002 3:29 PM o _ - i , j ¡ ¡ ¡ I _I L- I ¡ ~--L !. --'- ~ 37C1O--=-- I Ii! I I I . ii' I I--------¡---- :::: -¡ . Ii! I I í I I! i: ~ 38Q(} =! ! ¡ -.-:-l---:! ¡ _I - _I II 1- i --L-l ¡ L-L_--'--------------" -- _L___---'- .c - , - ¡ i ! !! i. P2-57,a. 111211 ¡ j ¡ , c.... ..... . '=C.'.C' !:tr~i·~·--I-=!1c-tt~,~'! I i ~A~,:-l-i-:ll--j=:t--!=t~ 82~---.i---~--------¡~------r--------~·_---- j I I I ! I ! I I .~ ! I I ! ! : ! ¡ i : '.. \ - ! :1. . ,. I. . _ II _ 1_ . - ' - -: - - - -4200 . I ·1 - I' ¡ I ! 1- I - I . - I 1- - Iii ¡ i I I i _II! :- 8~1-----¡-.:- - ~- -! -I - - - j--¡----¡ I I. I ! i i~t----! - - I r- ¡-ji--t--------t~----L-t--+ :' , I '! 'I ". i'· I, Ii! I ¡,,:: : ¡, i!" " . III ¡ ¡!, I: "I! I ¡ ¡. i II! \1' ¡ II I I Ii ¡, I III ¡ ¡, I' ¡ ':!:!!"!": ¡! I ¡,: I! :!'::' Ii;, I ¡, ,¡ \ ., I··,,! :, i' .~~J=t...~=·.:=I~ --1- .. ·1700·1800·1500·1400·13O<}·1200·1100·1000.900 -8OOW:t{-e:;'IE;";)~o:ñ~ 0 100 200 30<} 400 500 800 700 800 900 _8400-:-¡-- i I I ¡- ! I i I I 1 I I ! 1 1 II! 1 1- 1 I I I ! i ¡ ¡ I ¡ I c =\ I I \- - I - \ - - - - - -\ . 1- -- -\- - - I - ! 1- \ I \- --1\ 1 - _1- _1- : " - 1- 1- - .---" - - u_ I... - I . . , - 1 - . I \ . . . - ¡ ! - : - 5- 8450 -- - - . - . . . - . . -.. . - . I - - - - - I· - + - . r . - -l . - I - - - ! - - -. -. -. ,-.- -- -. -- - I I - ! ! . ! ¡ - 1 . ! ¡-~ _ I 1 r f I I I! I I I I I I : I !! I I I I I I! I ¡ I I I ! : = rJ'·· I ..--. j- - 1- ----1-00 -- --i-- L- -----I-c--- _1-·-- d_ -·------Fd!--I-~. J.. -¡-:d-==¡-i. !!!.~- . --==-~ .. 1_ - ,______ I~- i.~ ¡ 1---· ·1 Tf I ! --1"=--/-1-_ ¡ .c 8550 ---+- ----------~-- I I I - I . K ! I ¡ ¡ I 1-¡------r-----~. .. -- I I I I I . .. . . . I,· ! r ¡ ; c:a. -, I I 'I , I I I I I I ! I I , I , I ~ I I I I ' , i I ii' I , CÞ :1_ I I 1-1----1- -1-1---1- I -1--1---1 ---¡--- I 1- --I--I'~-- _H - -- -'--¡:~-I--'- - -I ¡- -t--c-I-I· I ! ! i j ¡:~ .. . .:lu_.· ........ ... I .. I .11~~}à'< .. ..... u[·lt Ti·li¡ i 1:: ----------- - Ii! I ¡ I I ' I ! cþ 8700 _ . . I " I ! Ii! i ! I i _, , , I I , , ! " I I I , I I I I 1 I , I , I , i I I I ¡I; : ! ! ~8750~1:-1--1!-- I :./..1"- I -=11l:S7,a.1!1~ 1:-_'___1_.J_--'--------¡ J _.1 - IJ.~_JA;1J; -'I--C!-¡ _ f -1_ -J_ !- : [ :1. 2 -11- I - I· ! _1- ~ l-- - \ - - - -~- --- - -. --J -- - - -- ,- -- r P - -~4 P2-S7,a. T11.2 -I - -1- - - -1- I I ! - t~- 1-8800 - . I I 1 8" I rT " ,~\ I ! I I ! I ,¡ ::1 . . 1 . -\ I - 1 ~ - - - -1- -- --- -- - _u_ - - -F- -, - -- - - - -- --I· - -- - r I ! "! I ¡ ~" .....:l . "1- "I -\ --- Î -- - . II - -- --- - - - - - - - ì -1- -: ! . i 88 __ I -S7A 11.41 - 5' ! I i - ¡ :1 I I , I!,! I I. I P2-57A T1131 I I ! ; ! ! , ~~-t-~t- ¡II -¡ -I I·! l I-I 1-:-1 ! I-I t 1-:( I -1- 1:- 1- I ¡ I \ i I 1- ! ii ¡ -: I I I I I I : I I I I I I I r f I I ! I I I I I Î I ¡ i ! r : 8950~~----t____=+_-+_ I ----J~:t ------1 --I -r- --1- I -\ ~ 1 t .d_ --~-! -'-----~----I- '1- 1 il:-+---~ --t +--\ =1 Þi I I ¡. I - - - ! - I I I ¡ t I I I -- ¡ 1- ¡- - i-I ¡I! i ¡ ~~I' I,., ;-;--;-:--f"..I, ,- II" .,.- 11.,1:'-1-:1-11 ¡",- 111./1111 - ""111' "-1:'-' .,-I··-r 1P2-S7(P2-5rv.-l1 ,-"liT" "1'1. ,. '-¡'1 '-'1 ,·I;'-I;";,,,I: ;.:,-,1:,:._1:,_,.1.. ,¡:.,:!-. ¡"'-: . I I I 'I . I I I I I, I . I I !. .. ~ . J ; . r . I I . I I I I . I. I . ! : r I I " . I t I I I I I I I r ,. I" . r I .... I , , I . - , I . , I ~ . . ! : ! I. . I ! I - I I ,I . I J I . . . -1600-1550-1500-1450-1400-1350-1300-1250-1200-1150-1100-1050-1000 -950 -000 -850 -sOo -750 -700 -650 -600 -550 -500 -450 -400 -350 -300 -250 -200 -150 -100 -50 Ò 50 100 150 2Òo 250 300 350 Vertical Section at 90.00· [50ft/In] BP Amoco walrATH DlTAlU _. PU1A _tn.. -~'t ='... _. ~ n .I7I111Z1'1_.," .I.IIIIft v.e.;:: 0::: = :~ ..... .... .... .... REFERENCE INFORMATION c~onil'lal.~¡ Reference: W" Cenlr&: P2-S7. True Nor\h v:=n (VS ~:=:: ~~7=ge~~ Measured Depth Referenc8: 77: 57 6/12/199100:00 41.00 Cak:uIation Me!hod: MIniITUtI CuMIIln ..... ....1oIU _ _ Me .... 1VII .... - _.... --.,..... t ....... a.. tMM -.ea..,. ~ ...... .... &01 ........ a ...... aa..ae tn.N ....... 4ULM ......... ... SC1'At .......... : == ftJ: 1:::: :::tn :=::: :D sf:: == ::m · .....,....... ."... .,..., .....,. 41.... Ii........ .J1LU · ,......,...... It... ....'11 .att.tl ..",11 It....... 4OS.81 ., ,....,.. ...,.. 'Mil' ..n.u ~.. ...a.u 1~..... ·ta.n · .....n &1. "'.t. ........ -Mi.'" ....... 11." .IM ......,. · .......... ....ø Ift..t. .....a ....... .....1.. .t.eo 1T1." -In.,.. t.,'....,.. 11... IOI..aO ..11.2:I 41....' ....L.. tI... _00 ..1.... 'It It...... ........... ..... 4t1U1 ....n..ø fL.. ø.... ·ten.A7 Azimuths 10 True North Magnetic North: 26.20· Magnetic Reid Strength: 51546nT D~a~1il7sg~; Model: BGGM2002 T ^M 4 LEGEND - ~1\~ß,a. PIøn.11 ÆJ·" ;.¡r1! ~:. ..........1 :-_-.~. f ~---. .-;-:! ~-- ~ ',.. ... BtIII.. lNTEQ ObP - .... .... .... .... TAIIOET OETM.S "'" -- - 11't000....0I 41' 14 ::: ~m~ .;:= MUoo .SUUS <201103 - Pl'¡'AT1I, P241. TII.2 ~::;:~U; ANIIOTA_ TVD .._ .N1.17 __ 111' ....... _... ICeif' 1f7II.I. _... . IIII.L1I ._ I -... _.n _ -._ ......n . ...7.1' _n . ....... ._n . -.,_ ._.n , .....11 un..n . _All u_... TD Company: Field: Site: Well: Wellpath: Field: Obp BP Amoco Point Mac Pt Mac 2 P2-57 Plan#11 P2-57 A ') BP ~) Baker Hughes INTEQ Planning Report Bii. .... INTEQ Date: 10n/2oo2 Time: 15:29:39 Page: Co-ordlnate(NE) Reference: Well: P2-57, True North Vertical (fVO) Reference: System: Mean Sea Level Seetion (VS) Reference: Well (0.OON,O.00E,90.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Point Mac North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: Pt Mac 2 TR-12-14 UNITED STATES: North Slope Site Position: Northing: From: Map Eastlng: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Well: P2-57 P2-57 Well Position: +N/-S 2691.72 ft Northing: +E/-W 6662.23 ft Easting: Position Uncertainty: 0.00 ft Wellpath: Plan#11 P2-57 A 500292218301 Current Datum: 77: 576/12/1991 00:00 Magnetic Data: 1017/2002 Field Strength: 57546 nT Vertical Section: Depth From (TVD) ft 0.00 Targets Name Description TVD Dip. Dlr. ft P2-57A T11.1 8790.00 P2-57 A T11.2 8814.00 P2-57A T11.4 8830.00 P2-57A T11.3 8845.00 Annotation MD ft 9619.90 9630.00 9650.00 9700.00 9960.79 10105.79 10430.79 10605.79 10980.79 11230.79 11500.00 TVD ft 8542.57 8551.80 8570.21 8618.13 8788.81 8804.33 8837.14 8845.04 8840.33 8835.22 8830.48 TIP KOP 1 2 3 4 5 6 7 8 TD Plan: Plan #11 Identical to Lamar's Plan #11 Principal: Yes Map Zone: Coordinate System: Geomagnetic Model: 5995140.76 ft 674873.98 ft Latitude: Longitude: North Reference: Grid Convergence: Slot Name: 5997987.39 ft 681471.00 ft Latitude: Longitude: Height 41.00 ft Drilled From: Tle-on Depth: Above System Datum: Declination: Mag Dip Angle: +EI-W ft 0.00 +N/-S ft 0.00 +N/-S ft -3954.09 -3787.75 Map Map Northing Easting ft ft 5994026.99 681248.99 5994196.99 681397.99 +E/-W ft -318.14 -165.04 -3112.22 -1082.97 5994849.99 680463.99 -3415.65 -246.03 5994566.99 681307.99 Date Composed: Version: Tied-to: Alaska, Zone 4 Well Centre BGGM2002 70 23 32.530 N 148 34 37.934 W True 1.34 deg 57 70 23 58.973 N 148 31 22.762 W , P2-57 9630.00 ft Mean Sea Level 26.20 deg 80.89 deg Direction deg 90.00 <- Latitude --> <- Longitude --> Deg MlnSee Deg Mln See 70 23 20.085 N 148 31 32.077 W 70 23 21.721 N 148 31 27.594 W 70 23 28.364 N 148 31 54.475 W 70 23 25.381 N 148 31 29.966 W 10n /2002 1 From: Definitive Path ObP ) BP ) .a: Baker Hughes INTEQ Planning Report INTRQ Company: BP Amoco Date: 10fll2002 Time: 15:29:39 Page: 2 Field: Point Mac Co-ordlnate(NE) Reference: Well: P2-57, True North Site: Pt Mac 2 Vertical (fVD) Reference: System: Mean Sea Level Well: P2-57 Section (VS) Reference: Well (0.00N,O.OOE,90.00Azi) Wellpath: Plan#11 P2-57 A Survey Calculation Method: Minimum Curvature Db: Oracle Plan Section Information MD Incl Azim TVD +N/-S +EI-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/10Oft deg/100ft deg/10Oft deg 9619.90 23.90 194.00 8542.57 -3935.89 484.05 0.00 0.00 0.00 0.00 9630.00 23.89 193.94 8551.80 -3939.86 485.04 0.26 -0.10 -0.59 247.61 9650.00 22.21 192.31 8570.21 -3947.49 486.82 9.00 -8.42 -8.14 200.00 Jt'1'lllC'1 9700.00 11.59 150.60 8618.13 -3961.18 486.37 31.00 -21.24 -83.41 210.00 9960.79 84.00 77.09 8788.81 -3953.75 -318.24 31.00 27.77 -28.19 285.00 1õf ~~Ù~ 10105.79 84.35 31.90 8804.33 -3872.16 -203.91 31.00 0.24 -31.17 268.00 %f)I./3' sS 1 fL 10430.79 84.78 342.91 8837.14 -3561.20 -163.55 15.00 0.13 -15.07 268.00 10605.79 90.14 317.18 8845.04 -3411.09 -250.14 15.00 3.06 -14.70 281.00 , þt2 0 <t?~~ 10980.79 91.23 272.19 8840.33 -3258.46 -582.14 12.00 0.29 -12.00 271.60 ¡CO f <:t 11230.79 91.06 302.20 8835.22 -3185.41 -818.20 12.00 -0.07 12.00 90.00 f$~(,.. 11500.00 90.90 269.89 8830.48 -3112.01 -1073.47 12.00 -0.06 -12.00 270.00 Survey MD Incl ADm SSTVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft deg/100ft 9619.90 23.90 194.00 8542.57 -3935.89 -484.05 5994041.15 681082.69 484.05 0.00 TIP .. 9625.00 23.89 193.97 854 7 .23 -3937.90 484.55 5994039.14 681082.24 484.55 0.26 MWD , 9630.00 23.89 193.94 ( 8551.80 J -3939.86 485.04 5994037.16 681081.80 -485.04 0.26 KOP 9650.00 22.21 192.31 öSfO.21 -3947.49 -486.82 5994029.50 681080.20 486.82 9.00 1 l6W~ 9675.00 15.95 178.11 8593.83 -3955.55 -487.72 5994021.42 681079.50 -487.72 31.00 MWD Co 486.37 ~1.00 - 9700.00 11.59 150.60 8618.13 -3961.18 486.37 5994015.82 681080.99 223.45 2 - --- 9725.00 15.49 121.42 8642.46 -3965.11 482.28 5994011.99 681085.17 482.28 31.00 285.00 MWD 9750.00 21.55 105.95 8666.17 -3968.12 -475.01 5994009.16 681092.52 -475.01 31.00 313.43 MWD 9775.00 28.41 97.34 8688.83 -3970.14 -464.68 5994007.39 681102.89 -464.68 31.00 328.12 MWD 9800.00 35.62 91.93 8710.01 -3971.15 451.48 5994006.70 681116.10 451.48 31.00 335.94 MWD f ~1(. 9825.00 42.99 88.15 8729.35 -3971.12 -435.66 5994007.12 681131.92 435.66 31.00 340.54 MWD 9850.00 50.46 85.30 8746.48 -3970.05 417.51 5994008.63 681150.04 417.51 31.00 343.47 MWD 9875.00 57.98 83.00 8761.08 -3967.96 -397.35 5994011.20 681170.14 -397.35 31.00 345.43 MWD . \6 9900.00 65.54 81.06 8772.90 -3964.90 -375.56 5994014.79 681191.85 -375.56 31.00 346.77 MWD ~,,\ 9925.00 73.12 79.34 8781.72 -3960.91 -352.53 5994019.34 681214.77 -352.53 31.00 347.70 MWD 9950.00 80.72 77.75 8787.37 -3956.08 -328.68 5994024.75 681238.50 -328.68 31.00 348.30 MWD 9960.79 84.00 77.09 8788.81 -3953.75 -318.24 5994027.33 681248.87 -318.24 31.00 348.66 3 9975.00 83.86 72.67 8790.31 -3950.06 -304.61 5994031.35 681262.41 -304.61 31.00 268.00 MWD 10000.00 83.71 64.87 8793.02 -3941.07 -281.46 5994040.90 681285.34 -281.46 31.00 268.47 MWD 10025.00 83.68 57.07 8795.77 -3929.02 -259.75 5994053.47 681306.75 -259.75 31.00 269.31 MWD 10050.00 83.76 49.28 8798.51 -3914.14 -239.87 5994068.83 681326.25 -239.87 31.00 270.17 MWD 10075.00 83.96 41.49 8801.19 -3896.70 -222.19 5994086.70 681343.50 -222.19 31.00 271.02 MWD 10100.00 84.26 33.70 8803.76 -3877.01 -207.04 5994106.75 681358.18 -207.04 31.00 271.86 MWD ).10105.79 84.35 31.90 8804.33 -3872.16 -203.91 5994111.67 681361.18 -203.91 31.00 272.66 4 10125.00 84.25 29.00 8806.24 -3855.69 -194.23 5994128.37 681370.46 -194.23 15.00 268.00 MWD 10150.00 84.15 25.24 8808.77 -3833.55 -182.89 5994150.77 681381.26 -182.89 15.00 268.29 MWD 10175.00 84.08 21.47 8811.33 -3810.73 -173.04 5994173.83 681390.55 -173.04 15.00 268.67 MWD 10200.00 84.03 17.70 8813.92 -3787.30 -164.71 5994197.45 681398.31 -164.71 15.00 269.05 MWD 10225.00 84.01 13.93 8816.53 -3763.38 -157.93 5994221.52 681404.50 -157.93 15.00 269.45 MWD 10250.00 84.01 10.16 8819.14 -3739.07 -152.75 5994245.95 681409.10 -152.75 15.00 269.84 MWD 10275.00 84.04 6.39 8821.74 -3714.47 -149.17 5994270.63 681412.08 -149.17 15.00 270.23 MWD 10300.00 84.09 2.62 8824.33 -3689.69 -147.22 5994295.45 681413.42 -147.22 15.00 270.62 MWD 10325.00 84.17 358.85 8826.88 -3664.82 -146.90 5994320.31 681413.14 -146.90 15.00 271.01 MWD 10350.00 84.27 355.08 8829.40 -3639.99 -148.22 5994345.11 681411.22 -148.22 15.00 271.40 MWD 10375.00 84.40 351.31 8831.87 -3615.29 -151.17 5994369.72 681407.67 -151.17 15.00 271.78 MWD 10400.00 84.56 347.55 8834.27 -3590.84 -155.73 5994394.06 681402.51 -155.73 15.00 272.15 MWD 10425.00 84.73 343.79 8836.61 -3566.72 -161.89 5994418.01 681395.77 -161.89 15.00 272.51 MWD 10430.79 84.78 342.91 8837.14 -3561.20 -163.55 5994423.50 681393.98 -163.55 15.00 272.86 5 10450.00 85.33 340.08 8838.80 -3543.05 -169.62 5994441.49 681387.47 -169.62 15.00 281.00 MWD 10475.00 86.07 336.39 8840.67 -3519.90 -178.86 5994464.40 681377.67 -178.86 15.00 281.24 MWD ObP ) BP ) B.. .... Baker Hughes INTEQ Planning Report INTEQ Company: BPAmoco Date: 1017/2002 Time: 15:29:39 Page: 3 Field: Point Mac Co-ordinate(NE) Reference: Well: P2-57, True North Site: Pt Mac 2 Vertical (fVD) Reference: System: Mean Sea Level Well: P2-57 Section (VS) Reference: Well (0.OON,O.ooE,90.ooAzi) Wellpath: Plan#11 P2-57 A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD loel Azim SSTVD NIS E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/10OO deg 10500.00 86.83 332.71 8842.22 -3497.38 -189.58 5994486.66 681366.41 -189.58 15.00 281.52 MWD 10525.00 87.60 329.04 8843.43 -3475.57 -201.73 5994508.17 681353.73 -201.73 15.00 281.75 MWD 10550.00 88.38 325.37 8844.31 -3454.57 -215.27 5994528.83 681339.69 -215.27 15.00 281.93 MWD 10575.00 89.16 321.70 8844.85 -3434.48 -230.12 5994548.56 681324.36 -230.12 15.00 282.06 MWD 10600.00 89.95 318.03 8845.04 -3415.37 -246.23 5994567.27 681307.79 -246.23 15.00 282.14 MWD 10605.79 90.14 317.18 8845.04 -3411.09 -250.14 5994571.45 681303.78 -250.14 15.00 282.16 6 10625.00 90.20 314.88 8844.98 -3397.27 -263.47 5994584.94 681290.11 -263.47 12.00 271.60 MWD 10650.00 90.28 311.88 8844.87 -3380.10 -281.64 5994601.67 681271.53 -281.64 12.00 271.59 MWD 10675.00 90.37 308.88 8844.73 -3363.90 -300.68 5994617.39 681252.11 -300.68 12.00 271.58 MWD 10700.00 90.45 305.88 8844.56 -3348.73 -320.54 5994632.08 681231.88 -320.54 12.00 271.56 MWD 10725.00 90.53 302.88 8844.34 -3334.61 -341.17 5994645.69 681210.92 -341.17 12.00 271.54 MWD 10750.00 90.61 299.88 8844.10 -3321.60 -362.51 5994658.18 681189.27 -362.51 12.00 271.52 MWD 10775.00 90.68 296.88 8843.81 -3309.71 -384.50 5994669.53 681167.00 -384.50 12.00 271.49 MWD 10800.00 90.76 293.88 8843.50 -3299.00 -407.09 5994679.69 681144.16 -407.09 12.00 271.45 MWD 10825.00 90.83 290.89 8843.15 -3289.48 -430.20 5994688.64 681120.83 -430.20 12.00 271.42 MWD 10850.00 90.90 287.89 8842.78 -3281.18 -453.77 5994696.37 681097.06 -453.77 12.00 271.37 MWD 10875.00 90.97 284.89 8842.37 -3274.13 -477.75 5994702.83 681072.92 -477.75 12.00 271.33 MWD 10900.00 91.04 281.89 8841.93 -3268.35 -502.07 5994708.03 681048.47 -502.07 12.00 271.28 MWD 10925.00 91.10 278.89 8841.46 -3263.84 -526.65 5994711.93 681023.79 -526.65 12.00 271.23 MWD 10950.00 91.16 275.89 8840.97 -3260.63 -551.43 5994714.54 680998.93 -551.43 12.00 271.17 MWD 10975.00 91.21 272.89 8840.45 -3258.72 -576.35 5994715.85 680973.98 -576.35 12.00 271.11 MWD 10980.79 91.23 272.19 8840.33 -3258.46 -582.14 5994715.96 680968.19 -582.14 12.00 271.05 7 11000.00 91.23 274.50 8839.92 -3257.34 -601.31 5994716.62 680949.00 -601.31 12.00 90.00 MWD 11025.00 91.22 277.50 8839.38 -3254.73 -626.16 5994718.63 680924.09 -626.16 12.00 90.05 MWD 11050.00 91.21 280.50 8838.85 -3250.82 -650.85 5994721.93 680899.32 -650.85 12.00 90.11 MWD 11075.00 91.20 283.50 8838.32 -3245.62 -675.29 5994726.53 680874.76 -675.29 12.00 90.18 MWD 11100.00 91.19 286.50 8837.80 -3239.16 -699.43 5994732.41 680850.47 -699.43 12.00 90.24 MWD 11125.00 91.17 289.50 8837.29 -3231.43 -723.20 5994739.55 680826.52 -723.20 12.00 90.30 MWD 11150.00 91.15 292.50 8836.78 -3222.48 -746.53 5994747.94 680802.98 -746.53 12.00 90.37 MWD 11175.00 91.13 295.50 8836.28 -3212.31 -769.36 5994757.55 680779.91 -769.36 12.00 90.43 MWD 11200.00 91.10 298.50 8835.80 -3200.97 -791.63 5994768.35 680757.37 -791.63 12.00 90.49 MWD 11225.00 91.07 301.50 8835.32 -3188.47 -813.28 5994780.32 680735.43 -813.28 12.00 90.54 MWD 11230.79 91.06 302.20 8835.22 -3185.41 -818.20 5994783.25 680730.44 -818.20 12.00 90.60 8 11250.00 91.06 299.89 8834.86 -3175.51 -834.65 5994792.75 680713.76 -834.65 12.00 270.00 MWD 11275.00 91.06 296.89 8834.40 -3163.63 -856.64 5994804.10 680691.49 -856.64 12.00 269.96 MWD 11300.00 91.05 293.89 8833.94 -3152.91 -879.21 5994814.26 680668.66 -879.21 12.00 269.90 MWD 11325.00 91.04 290.89 8833.48 -3143.39 -902.32 5994823.22 680645.33 -902.32 12.00 269.85 MWD 11350.00 91.03 287.89 8833.03 -3135.09 -925.90 5994830.94 680621.56 -925.90 12.00 269.79 MWD 11375.00 91.01 284.89 8832.58 -3128.04 -949.88 5994837.41 680597.42 -949.88 12.00 269.74 MWD 11400.00 91.00 281.89 8832.14 -3122.25 -974.19 5994842.60 680572.97 -974.19 12.00 269.68 MWD 11425.00 90.98 278.89 8831.71 -3117.74 -998.77 5994846.51 680548.29 -998.77 12.00 269.63 MWD 11450.00 90.95 275.89 8831.29 -3114.53 -1023.56 5994849.12 680523.43 -1023.56 12.00 269.58 MWD 11475.00 90.93 272.89 8830.88 -3112.62 -1048.48 5994850.43 680498.47 -1048.48 12.00 269.53 MWD 11500.00 90.90 269.89 8830.48 -3112.01 -1073.47 5994850.43 680473.48 -1073.47 12.00 269.48 TO ') Nordic CTD BOP Detail /'. /UI I 7-1/16" ID, 5000 psi working pressure ~ Ram Type Dual Gate BOPE I TOT I"'~ Manual over Hydraulic c:: I I XO Spool as necessary \ / ~ I I ® I I 'I THA I L ~_ __ ~ Tubing @ r Spool ì I I -@r~ ~ Methanol Injection ~ 8tiS 7" WLA Quick II onnect - I 7-1/16" ID, 5000 psi working pressure ;...- Ram Type Dual Gate BOPE Manual over Hydraulic '-- I r t=ê rc= HCR I [@Itffi TOT Flanged Fire Resistant Kelly Hose to Dual Choke Manifold Full production christmas tree MOJ 9/15/02 ) o~ ~ -.. CT Injector Head I 1 -- Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ 7" Riser 1'1 I " Annular BOP (Hydril),7-1/16" ID /' 5000 psi working pressure ~ I I I CJ=t I Blind/Shear I 12 3/8 II Combi PiPe/Sli~ I ~ Kill line check valve Jl-~-III -WO-'-I l Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold / I I 2" Side outlets F ~ I =1 23/8" Combi Pipe/Slip 2 3/8" x 3 1/2" VBRs 2 flanged gate valves Inner Annulus Outer Annulus · ' SUBJECT BASED ON ENGINEER i"l ) ~" ~' ""-, \ ~" \ ~, \ , .' ~i. , // /·///1.. ,/,i ,,' I //1/// , , AK 2337-1 (3/94) ) ) ENGINEERING DATA SHEET NO._ OF_ DEPT. APP'VL BUDGET/AFE NO. FILE NO. DATE f2-S7/1 L / ~ c V-&s41~",t W /f/~e- (),OC5~ ßbf l f"ij, $ ~ ('3,7S-~3,1'2.) 0f€VI ", fI , C)I 3'/,t =- !O ~OD - .'1'" 0..:::. C¡i./D· ';( 10 "Z...9 )< /. ~ =: s: 0 711 ~'" X 3~~':: 7bfoo - 'j'fex:/ ::=- Zb¿(·;·I;:~?"9~ ~ - 71 I _ /02.-' J TOC- / ?)L(oo 12, J ~t; I 3 I3bl i j I, nc ¡r 50 /f '-- , L 1/ 1¡~II(.f" ~ '1(1~ rr Y> I J h1f5 OI!1 I -f. Ì/ 1/ '76lft. ,IJ'I . 7'1~ Z'li fl.' #. WI of c< "" ,. t 'f0 / ~.l~b:~'> _ L----+------_~cP ----=--.- ~.__=,:::.. -..J( , -. -- - \ :::.,'" " '" C) r .__--~ ....-...'-_..........~......~pII""~J~,.....-.~~~.---- Mo5 /0//7 !Dl-- i 207124 DATE INVOICE / CREDIT MEMO (20/02 INV# CK091602J : ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) 'INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY ) DESCRIPTION PERMIT TO DRILL FEE GROSS P;Z-SiR TOTAL ~ B. TO THE ALASKA OIL GAS CONSERVATION ~~ER ~6H6~~~~ ~~~9~6~roo FIRST NATIONAL BÁNK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56-389 4'12 ~"'þ . 'I"'·'· ,.." .1", ........ ÜI," '," SEPT. 20, 2002 III 2 0 ? ~ 2 L, III I: 0 L. ~ 2 0 3 a ~ 5 I: 0 0 a L, L. ~ g III DATE ) 9/20/02 CHECK NO. H207124 VENDOR DISCOUNT NET RE€&IVED OCT 2 1 2002 AI._' G~ Gons. com_on AnC:1orage No.H 207124 CONSOLIDATED COMMERCIAL ACCOUNT ****$lQO.OÖ**** ~.\~~;~.~::~::~~D(£:~. ..:::.~~~'i:~}:~.~:/~.:<:;;~.~ .........~... ..·C·..··,ot.... ...... ...... ...... :.\;:.;.: '. ':":; .~... :.~~., :~~::""~'~ ....'. .if / ~:~:;·:':,:~::.:\:i~.·. .:~:~:;~ë:;} /'~:~}~i;::~:~~ ~?~~~~'~;:~: ~~'i 1t ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API num ber last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. 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) froW: records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\j ody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuànce 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. ~,~1 11 ~./.vi¡T~ WELL PERMIT CHECKLIST COMPANY AP.x WELL NAME!.2.. - S? A PROGRAM: Exp _ Dev ~ Redrll ~ Re-Enter _ Serv _ Wellbore seg _ FIELD & POOL ~bC/þl) INITCLASS /}¡O..;¿'/ /-0/) GEOLAREA '?7n UNIT# //h...\~ ON/OFFSHOREdL0 ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . f0 N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. Y N 6. Well located proper distance from other wells.. ...... Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . Y N IJf}/ I. l _ / 8. If deviated, is wellbore plat included. . . . . . . . . . . . . . Y N f¥.l-L- /~:L 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . 'V N , (Service Well Only) 13. Well located w/in area & strata authorized by injection order #_ Y V ¡t). A. (Service Well Only) 14. All wells wlin X mile area of review identified. ){"N ENGINEERING $.E. APPR DATE APPR DATE ,~W§A-. '.nll ¡IOL (Service Well Only) GEOLOGY APPR DATE /Ie. I~¿z- (Exploratory Only) Rev: 10/15/02 15. Conductor string provided. . . . . . . . . . . . . . . . . . . 16. Surface casing protects all known USDWs. . . . . . . 17. CMT vol adequate to circulate on conductor & surf csg. 18. CMT vol adequate to tie-in long string to surf csg. . . 19. CMT will cover all known productive horizons. . . . . . 20. Casing designs adequate for C, T, B & permafrost. . . 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved. . . 23. Adequate wellbore separation proposed.. . . . . . . . . . . . 24. If diverter required, does it meet regulations. . . . . . . . . . 25. Drilling fluid program schematic & equip list adequate. . . . . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 27. BOPE press rating appropriate; test to 35"00 psig. 28. Choke manifold complies w/API RP-53 (May 84) . 29. Work will occur without operation shutdown. . . . . . . . . . . 30. Is presence of H2S gas probable.. . . . . . . . . 31. Mechanical condition of wells within AOR verified. . . . . . . . 32. 33. 34. 35. 36. Permit can be issued wlo hydrogen sulfide measures. . . . . Data presented on potential overpressure zones. . . . . . . . Seismic analysis of shallow gas zones. . . . . . . . , . . . . Seabed condition survey (if off-shore). . . . . .. ...... Contact name/phone for weekly progress reports. ...... ftC/it-- -Y N ~ crDe.<. &. N 10/1-7-10'2- ~N ¥ N /\flit- N fI1 (l,A/ Mid tj. í, f ¡J c¡ N N mC;i=' ~~11 jJ{,/ N N N 'l-V ffl-... 'ì (¿~ I () L . ¥-N- Ai/A:- Y@ ~ÞfA, GEOLOGY: RPL PETROLEUM ENGINEERING: TEM RESERVOIR ENGINEERING JDH UIC ENGINEER JBR SFD_ WGA ./ MJW G:\geology\perm its\checklist.doc ( ( COMMISSIONER: COT Il(!o~ DTS 1//'>' g MLB '~ (~?,.. Comments/Instructions: ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dx )ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 19 10:21:46 2003 ') ôo~-~~i' ll~36 Reel Header Service name............ .LISTPE Date.................... .03/06/19 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.. . . . . . . . . . . . . . . . . . . .03/06/19 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA P2-57A 500292218301 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 19-JUN-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0000232644 S. LATZ SARBER/KOLST MWD RUN 2 MW0000232644 B. JAHN SARBER/KOLST MWD RUN 3 MW0000232644 B. JAHN EGBEJIMBA/KO # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 14 12N 14E 594 1220 41.00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.125 7.000 9660.0 # 1. ) ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE J.~JTED. THESE DEPTHS ARE MEASURED DEPTH (MD). REMARKS: 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK IN THE P2-57 WELLBORE. THE TOP OF THE WHIPSTOCK WAS SET AT ABOUT 9660' MD / 8579' TVDSS. 4. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. UPHOLE TIE-IN DATA (SGRC) ARE INCLUDED WITH RUN 1 DATA. 5. MWD RUNS 2 - 3 COMPRISED DIRECTIONAL WITH DGR¡ AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). AFTER THE COMPLETION OF RUN 2 IT WAS DETERMINED THAT THE EWR TOOL WAS READING INCORRECTLY. THEREFORE RESISTIVITY DATA OVER THE INTERVAL 9652'MD TO 10389'MD WERE ACQUIRED DURING A MEASUREMENT AFTER DRILLING (MAD) PASS PRIOR TO MWD RUN 3. NO SEPARATE MAD PASS DATA ARE PRESENTED. RESITIVITY DATA GATHERED ON THE MAD PASS ARE INCLUDED WITH RUN 2 DATA. 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN P2-57A ON 15 MARCH 2003. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY DEWAYNE SCHNORR ON 17 JUNE 2003. 7. MWD RUNS 1 - 3 REPRESENT WELL P2-57A WITH API#: 50-029-22183-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11102'MD / 8806'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY ( SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name............ .STSLIB.OOl Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/06/19 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ ') ') 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9558.5 9650.5 9650.5 9650.5 9650.5 9650.5 9685.0 STOP DEPTH 11056.0 11069.0 11069.0 11069.0 11069.0 11069.0 11101.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE DEPTH 9558.5 9574.0 9575.5 9578.0 9581.5 9587.0 9589.5 9656.5 9663.0 9668.5 9672.0 9675.5 9682.0 9684.5 9700.0 9704.0 9710.5 9712.0 9728.5 9746.0 9759.0 9775.5 9783.0 9786.5 9792.5 9796.0 9807.0 9814.5 9820.5 9828.5 9840.0 9853.0 9863.0 9886.0 9893.5 9895.5 9904.0 9908.0 9919.0 9933.0 9937.0 9940.5 9948.5 9965.0 9977.0 GR 9556.5 9572.0 9573.0 9576.5 9580.0 9585.5 9588.5 9659.0 9664.0 9667.5 9671.0 9674.5 9681.5 9683.5 9698.0 9702.0 9709.0 9710.0 9727.0 9746.0 9756.0 9773.5 9779.5 9783.5 9791.5 9795.0 9805.0 9812.0 9818.5 9827.0 9839.0 9852.5 9863.5 9888.0 9894.5 9896.5 9904.0 9908.0 9917.5 9928.5 9932.5 9936.0 9946.5 9966.0 9976.5 9987.5 9998.5 10013.0 10024.5 10050.0 10056.5 10081.0 10093.5 10100.5 10177.0 10245.5 10270.5 10298.0 10302.5 10322.5 10334.5 10346.5 10356.5 10363.5 10380.0 10402.5 10416.0 10433.5 10443.0 10454.5 10461.5 10551.5 10622.0 10689.5 10743.0 10820.0 10855.5 10872.5 10887.5 10917.0 10925.5 10940.0 10968.0 10980.5 11012.5 11033.5 11040.0 11048.5 11053.0 11101.0 $ 9986. ) 9994.5 10011.5 10021.0 10049.0 10055.0 10077.0 10087.5 10095.0 10179.0 10248.0 10273.0 10299.5 10302.5 10321.5 10335.0 10346.0 10354.0 10360.0 10376.5 10400.0 10411.0 10429.5 10439.0 10448.5 10455.5 10546.0 10620.0 10685.5 10738.0 10821.5 10858.0 10875.0 10890.0 10916.0 10925.0 10938.5 10969.0 10982.5 11014.0 11035.0 11040.5 11049.0 11054.5 11102.5 ) # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 9556.5 10251.5 10421.5 MERGE BASE 10251.5 10421.5 11102.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing... ................. .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units....................... Datum Specification Block sub-type...O ') ) Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9558.5 11101 10329.8 3086 9558.5 11101 ROP MWD FT/H 0.71 1795.62 105.901 2833 9685 11101 GR MWD API 23.08 396.38 43.7382 2875 9558.5 11056 RPX MWD OHMM 0.09 2000 190.737 2838 9650.5 11069 RPS MWD OHMM 0.1 2000 227.046 2838 9650.5 11069 RPM MWD OHMM 0.1 2000 267.784 2838 9650.5 11069 RPD MWD OHMM 0.03 2000 558.078 2838 9650.5 11069 FET MWD HOUR 0.17 43.3 15.0917 2838 9650.5 11069 First Reading For Entire File........ ..9558.5 Last Reading For Entire File......... ..11101 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/19 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/19 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 9556.5 9684.0 STOP DEPTH 10222.5 10251.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE 11-MAR-03 SURFACE SOFTWARE VERE ): DOWNHOLE SOFTWARE VERSiON: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Insite 4.3 Memory 10250.0 9683.0 10250.0 18.9 87.1 TOOL NUMBER 78012 4.125 9296.0 Flo Pro 9.70 65.0 9.0 135000 .0 .000 .000 .000 .000 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 ) .0 138.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9556.5 10251.5 9904 1391 9556.5 10251.5 ROP MWD010 FT/H 0.71 254.05 114.168 1136 9684 10251.5 GR MWD010 API 23.08 396.38 51.4976 1205 9556.5 10222.5 ) ) First Reading For Entire File......... .9556.5 Last Reading For Entire File.......... .10251.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/19 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/19 Maximum Physical Record. .65535 F i 1 e Typ e. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPX RPS GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 9652.5 9652.5 9652.5 9652.5 9652.5 10223.0 10252.0 STOP DEPTH 10389.5 10389.5 10389.5 10389.5 10389.5 10377.0 10421.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 12-MAR-03 Insite 4.3 Memory 10422.0 10250.0 10422.0 85.7 92.2 # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RES IS. 4 TOOL NUMBER 82758 126589 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (1) DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 4.125 9296.0 ) Flo Pro 9.80 65.0 9.0 135000 .0 .100 .050 .160 .100 65.0 141.0 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9652.5 10421.5 10037 1539 9652.5 10421.5 ROP MWD020 FT/H 9.54 1795.62 131.594 340 10252 10421.5 GR MWD020 API 24.34 46.89 33.4062 309 10223 10377 RPX MWD020 OHMM 0.09 2000 29.442 1475 9652.5 10389.5 RPS MWD020 OHMM 0.1 2000 146.763 1475 9652.5 10389.5 RPM MWD020 OHMM 0.1 2000 301.711 1475 9652.5 10389.5 RPD MWD020 OHMM 0.03 2000 697.181 1475 9652.5 10389.5 FET MWD020 HOUR 8.79 43.3 27.7301 1475 9652.5 10389.5 First Reading For Entire File......... .9652.5 Last Reading For Entire File.......... .10421.5 File Trailer service name............ -)SLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/19 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/19 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 4 ) header data for each bit run in separate files. 3 .5000 START DEPTH 10377.5 10390.0 10390.0 10390.0 10390.0 10390.0 10422.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 11057.5 11070.5 11070.5 11070.5 11070.5 11070.5 11102.5 TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 13-MAR-03 Insite 4.3 Memory 11102.0 10422.0 11102.0 87.9 94.9 TOOL NUMBER 78012 126589 4.125 9296.0 Flo Pro 9.80 65.0 MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: ) 9.0 135000 .0 ) .100 .050 .160 .100 65.0 144.0 65.0 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 10377.5 11102.5 10740 1451 10377.5 11102.5 ROP MWD030 FT/H 2.49 895.37 93.6073 1362 10422 11102.5 GR MWD030 API 26.65 58.77 39.3678 1361 10377.5 11057.5 RPX MWD030 OHMM 30.15 2000 366.347 1362 10390 11070.5 RPS MWD030 OHMM 55.4 2000 320.297 1362 10390 11070.5 RPM MWD030 OHMM 66.18 2000 242.348 1362 10390 11070.5 RPD MWD030 OHMM 113.94 2000 410.384 1362 10390 11070.5 FET MWD030 HOUR 0.17 11.96 1.22859 1362 10390 11070.5 First Reading For Entire File......... .10377.5 Last Reading For Entire File.......... .11102.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/19 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.005 \ . ) ) Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/19 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/19 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File