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Home My WebLink About201-180• WALL L®G (~ T"14'~4/1/~M/T7"~4L ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTI~ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaskaj, Inc. Petrotechnical Data Canter Attn: Andy Farmer 1.R2-1 900 E. Benson Blvd. Anchorage, Alaska 99506 ~~~~ N©V ~ 3 2flD~ and for-I~d0 '~ r56~`i ProActive Diagnostic Services, tnc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax (907j 245.8951 1) Leak Detectection - WLD 09-Nov-07 DS 05-128 2) Signed : ( / Print Name: ~_~ C i 5,~" ~ v1 ~ ~ 44~ t,I,~P.~ 1 EDE 50-029-2024402 9~i~~1~' Date : ~~ ~~~~~),~ 1'~ ;(;~ i`' ~ _~,1~ ~~,_,.,, PROACTNE Du-GNOSTiC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RP SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8961 FAX: (907)245-88952 E-MAIL: ndsancharage(p7roaQmar~aaa.carsa WEBSITE:mrnnM.rrse-aaon~loa.carn D:\Masoer Copy_00_PDSANC-ZOsoc\Z_WordlDislnbution\T~arrsmittal_Sheels\7tnnsmit_Origin~ New.dac .. . e e ~u~uŒ (ID~ FRANK H. MURKOWSKI, GOVERNOR AI'IASKA. OILAlWD GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jennifer Julian Wells Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, 05-12Bs,Ct,1~!~~...~i;\ii Sundry Number: 306-099 '., . ') ()"; Dear Ms. Julian: \%0 ~ J.P Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisZ",> day of March, 2006 an Enc!. /'H"jJ;J ~v~ rÆ 311¡-# ç, !Ie j/~a;; . I fvr sf ATE OF ÄLASKA . . A~ OIL AND GAS CONSERVATION COMM.ION vvr JY/2~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: 1. Type of Request: RæêtVéð' z.o oG. MAR 2 2 2006 Abandon Alter casing D Change approved program D Suspend Repair well 0 Pull Tubing D 2. Operator Name: Development ~ Stratigraphic 0 / Exploratory 0 Service 0 5. Permit to Drill Number: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage. AK 99519-6612 7. KB Elevation (ft): 201-1800 ./ 6. API Number: 50-029-20244-02-00 / 8. Property Designation: ADL-028326 11. Total Depth MD (ft): 10482 Casing Conductor Surface Production Liner Liner Liner Perforation Depth MD (ft): 9325 - 9735 / 9795 - 9845 Closed 9920 - 10100 Closed 10175 - 10330 Closed 10395 - 10460 Packers and SSSV Type: 9. Well Name and Number: 69 KB 05-12B ./ Total Depth TVD (ft): 8920.1 10. Field/Pools(s): PRUDHOE BAY Field / PRUDHOE OIL Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 10461 8917.94 9876 Junk (measured): None Collapse 520 2670 4760 10530 Length Size TVD Burst 80 20" 94# H-40 32 112 32 112 1530 2689 13-3/8" 72# N-80 31 2720 31 2720 4930 8876 9-5/8" 47# N-80 30 8906 30 8619 6870 190 3-1/2" 9.3# L-80 8200 83907951.5 8130 10160 516 3-3/16" 6.2# L-80 8390 8906 8129.97 8619 2389 2-3/8" 4.7# L-80 8093 10482 7851.46 8920 11200 11780 Perforation Depth TVD (ft): 8930.93 - 8924.93 8923.96 - 8921.67 Closed 8913.33 - 8904.59 Closed 8907.11 - 8909.95 Closed 8911.9 - 8917.84 5-1/2" Baker SAB Packer Tubing Size: 5-1/2" 17# /' 4-1/2" 12.6# Tubing Grade: N-80 N-80 Tubing MD (ft): 30 - 8447 8447 - 8564 Packers and SSSV MD (ft): 8436 / 13. Well Class after proposed work: Exploratory 0 Development ~ 15. Well Status after proposed irk: Oil ~ Gas 0 Plugged 0 Abandoned 0 WDSPL 0 12. Attachments: Descriptive Sum m ary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: Service 0 06 Date: WAG 0 GINJ 0 WINJ 0 Contact Prepared by Sharmaine Vestal 564-4424 Jennifer Julian 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed N Title Wells Engineer Phone 564-5663 Date COMMISSION USE ONLY 3/21/2006 Sundry Number: 30 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D Other: Subsequent Form Required: Approved by: Form 10-403 Revised 7/2005 BOP Test D Location Clearance D Mechanical Integrity Test D bp ... ,\~t.,~. _...~ ~~..- ~.._ --:...-.r .,~ ¡t.... .~'~~!!ì\" ". To: From: e e Memorandum D. Cismoski/J. Bixby GPB Well Ops Team Leaders Jennifer Julian & James Dean DS2 & 5 Production Engineer Date: March 6, 2006 AFE: PBD05WL 12-N Subject: 5-128 OA Down Saueeze / Est. Cost: lOR: $30,000 150 1. 2. 3. 4. 5. 6. o o o o SP OP '" Current Status: Last Test: Max Deviation: Min.ID: Last TD tag: Last Downhole Ops: Latest H2S level: L TSI - tubing leak Jan 19,2005: 57 BOPD, 179 BWPD, 3551 MCFPD 99 degrees @ 9822' md 1.92" @ 8104' md, 2-3/8" x 2-7/8" cross-over Sept 5,2004: CT RIH with 1-75" OD CIBP to 9976' (not TO) March 4, 2005: Set DSSSV at 2161' 5 ppm at separator on Jan 4, 1996 Job Obiective: An OA downsqueeze will be pumped to regain a passing MIT-OA and attempt to waiver the well for a small ./ tubing leak. Well History: We1l5-12B was drilled as a slimhole CTD sidetrack in December 2001. The well targeted Z1A but climbed into lower Z1 B near the toe. The well produced with nearly 100% ontime until March 2003 when the well was SI with a GOR of 37000 scf/bbl. After a 5 month SI, the production indicated minimal healing. A memory STP in January 2003 indicated 100% of the spinner and temperature response from the Z1 B toe section of the well below 9920' ctmd. A fault also intersects this portion of the wellbore. A CIBP was set at 9876' in September 2004 to shut-off the gas production from the toe of the well. The CIBP resulted in shutting off most of the oil and gas production. Two options are being evaluated to regain the oil production -shooting Z1 B ad perfs in the heel and milling the CIBP. In February 2005, the well failed a TIFL with an initial fluid level at 288' and a 1010 psi pressure increase overnight. A dummy safety valve was installed and the well failed the subsequent TIFL based on BUR. The well also passed a MIT-IA to 3000 psi. A caliper log run in Feb 2005 indicated minimal wall loss. The well was secured with a PGSL set in March 2005. The tubing and intermediate casing packoffs passed pressure tests in April 2005. A MIT-OA to 3000 psi failed with a LLR of 5 bpm at 1100 psi. An OA downsqueeze will be pumped to regain a passing MIT-OA and attempt to waiver the well for a small tubing leak. If the tubing leak waiver is successful, two wellwork options will be considered to improve well e e performance - shooting adperfs or milling the CIBP. Milling the CIBP will likely be attempted prior to shooting /' the adperfs. For questions or comments please call Jennifer Julian at 564-5663 (work) or 240-8037 (cell) or James Dean at 564-4668 (work) or 770-1023 (home). cc: w/a: James Dean Well File e OA Downsqueeze Procedure e This program is designed to depress FL to determine leak depth. Following the fluid depress, pump a column of cement from the shoe to approximately 500' above the shoe. JOB PLANNING DETAILS: 05/19/2005: MIT-OA failed with a LLR of 5.0 bpm at 1100 psi. Well has TxlA communication. / OA= 13-3/8" 72# N-80 IA= 9-5/8" 47# N-80 Shoe at 2720' OAxlA Annular Capacity=.0581 bbls/ft Volume to shoe = 158 bbls 500' of cement = 29 bbls Displacement= 158 -5 (H?O spacer) - 29 (cement) - 5 (H?O flush) = 119 bbls Approximate Fluid Requirements (Downsqueeze Only): Fresh Water: 400 bbls of =80 degree F (includes water for cement mixing and clean up.) 60/40 Methanol: 20 bbls Crude Displacement: 119 bbls at 30-60 degree F Crude: (volume needed to load OA) DS CW1 01: 1.Q bbls Arctic Set 1 Cement (15.7 ppg): 29 bbls pumpable (design the pumping time for 3+ hrs.) Note: Adjustments may be made as necessary by supervisor on-site. PREP WORK (pre downsQueeze): DHD/FB: 1. Depress OA FL w/ poor boy AL. 2. Shoot FLs and record WHPs. 3. The day prior to the downsqueeze, bleed the OAP to +/- 200 psi. 4. Fluid Pack the OA with crude. CEMENTING OPERATIONS: FB Pumping 1. Rig up cementers to the OA via a flanged 1502 integral union and in-line T valve. 2. If well has IA x OA communication (well has not shown this communication to date), the IA pressure / must be maintained at a pressure greater than the OA treating pressure to ensure no cement enters the IA. Tie into the IA with a LRS or pump. 3. Flood lines with warm fresh water and pressure test lines to 3000 psi. 4. Ensure the OA is fluid packed, and pump the following into the OA at maximum rate up to the / maximum pressure of 2000 psi. Note injectivity at pertinent times during the displacement. Start pumping into the OA as follows: e a. 10 bbls of 60/40 Methanol to establish injectivity b. 10 bbls of DS CW101 surfactant (optional) c. -180 barrels of 800 freshwater to flush OA (approx. 1.5 x annular volume) e d. 5 bbls of fresh water spacer e. 29 barrels of 15.7 ppg Arctic Set 1 cement / f. 5 bbls of fresh water flush g. 119 bbls of 30-60 degree F crude flush. Deliver cement down the OA at maximum rate of 5 BPM until 109 bbls of displacement has been pumped. Then, cut the rate to 1 BPM for another 5 bbls, then drop the rate to 0.5 BPM for the last 5 bbls. The leading edge of the cement should be 5 bbls short of the shoe when the pumps stop. 5. Shut down pumps and leave the well SI. Please DO NOT try to achieve a saueeze or to build saueeze pressure. The intent of this job is to place cement near the OA shoe, not to achieve a /' squeeze past the shoe. Record final pressures. Rig down and release cementers and pump trucks. Note: Make sure that the valve to the OA gauge has been left open so that OA pressures can be monitored. Do not allow more than 500 psi to build up on the OA. 6. Notify the Pad Operator prior to leaving location that the OA may be subject to rapid thermal pressure increases when the well is BOL. Frequent OA monitoring will be necessary for several days following the OA downsqueeze. Post Saueeze: FB: 7. M IT -OA to 3000 psi. /~ 8. Have a pre-job safety meeting on location prior to pumping the job to discuss options to safe out the wellhouse. fLLHEr.-D,= FMC AXELSON 69' N/A 5050' ¡X 9822' ¡tum MD = 9179' _.~---",.._,-'""-"------ ¡tum TVD 8800' SS I 13-3/8" CSG, 72#, N-80, 10 = 12.347" I I 4-1/2" BKR DEPLOY SLV, 10 = 3.00" 1 I TOP OF LINER, ELM, ON 12/16/01 1--1 I 2-7/8" X 2-3/8" LNR XO, 10 = 1.92" I 15-1/2" X 3-1/2" BKR TIEBACK SLV, 10 = 4.00" I e 05-128 / . 2159' AFETY NOTES: WELL ANGLE> 70° 9275' > 90° @ 9325'. PRE·5-12ASIDETRACK WELLBORE NOT SHOWN ON DIAGRAM. -i 5-1/2" CAMCO BAL-O SSSVN, 10 = 4.625" -i 4 1/2" PGSL (56' LONG) (03/04/05) -i 3-1/2" X 2-7/8" XO, 10 2.44" I 8200' -i 5-1/2" MOD. BKR RCP PKR, 10 = 2.690" / Minimum ID = 1.92" @ 8104' 2-7/8" X 2-3/8" LNR XO 8294' 8356' 3-1/2" LNR. 9.3#, L-80, .0087 bpf. 10 = 2.992" I I TOP OF 3-3/16" LNR I 5-1/2" TBG. 17#, N-80, .0232 bpf, 10 = 4.892" I I TOP OF 4-1/2" TBG I 8447' 8507' PERFORA TION SUMMARY REF LOG: SWS MEM GRlCNL ON 12/16/01 A T TOP PERF: 88 9325' Note: Refer to Production DB for historical SIZE SPF INTERV AL Opn/Sqz 1-11/16" 4 9325-9735 0 1-11/16" 4 9795-9845 1-11/16" 4 9920 - 10100 C 1-11/16" 4 10175 - 10330 C 1/16" 4 10395 - 10460 C 8564' J' BAKER CIBP SET ON 11/20/01 I 9-5/8" CSG, 47#, N-80, 10 = 8.681" 1 10020' '- 2-7/8" LNR, 6.5#, L-80. 10 = 2.441" 10588' 2-3/8" LNR, 47#, L-80, 10482' 1/ DATE 1998 03/04/99 12/16/01 04/19/01 10/10/0 11/20/01 REV BY COMMENTS TLH/tlh ELM DEPTHS ADDED CMO/TLP DATUM MD / PERF ANGLE KEY /TLP SET WFRO CIBP KSB/TLH CIBP CORRECTION KSB/TLH PGSL SET TO REV BY COMMENTS ORIGINAL COM PlETION CTD SIDETRACK (5-12A) CTD SIDETRACK (5-12B) CORRECTIONS XO CORRECTION SET CIBP DATE 03/20/02 8/03 5/04 03/02/05 03/05/05 5-1/2" CAM- OB-1 SLIDING SLV, ID = 4.500" 5-1/2" CAMCO DB - NIP, 10 = 4.313" 5-1/2"BAKERSBRASSY I 3-1/2" X 3-3/16" XO, FLUTED SUB NO GO AND XO 5-1/2" X 4-1/2" XO, (BEHIND LNR) I 4-1/2" CAMCO OB-6 NIP, 10 = 3.843" (BEHIND LNR) -l 4-1/2" TUBING TAIL(BEHIND LNR) H ELMO TT NOT LOGGED I 3-3/16" X 9-5/8" MILLOUT WINDOW 8906' - 8914' (OFF WHIPSTOCK) * RA TAG @ 8910' 9876' PRUDHOE BA Y UNIT WELL: 05-12B PERMIT No: 2011800 API No 50-029-20244-02 SEC 32, T11 N, R15E, 2897' NSL & 5143' WEL BP Exploration (Alas e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFiche\CvrPgs _ Inscrts\Microfilm _ Marker.doc Problem Well Notification: 05-12B (PTD #2011800) ) Subject: Problem Well Notification: 05-12B (PTD #2011800) Frpm: "Olsen, Clark A" <OlsenCA@BP.com> Date: Mon, 07 Feb 2005 18:09:47 -0900 To;: "GPB, FSIDSOps Lead" <GPBFS1DSOpsLead@BP.com>, "GPB, ~Sl DS5. Operator" .' . <Ç1PBFSIDS50perator@BP.com>, "GPB, .FSl/SIP/STP AfeaMgf"<:GPBFSl'fL@BP~com>, "G:pI:3, Wèlls.opt Bng" <GPBWellsOptEng@BP~com>, "Rossberg;.'RSteven" <RossbeRS@BP.com>," .'. . "N~U, ADW. Well Operations Supervisor". <NSUADWW ellOperationsSupervìsor@BP.cóm>~'''NSU, AL>yv.wt & "Completion Supervìsorn ~<N~ÚADwwL&CoÍllpletionSupervisor@BP .com>; "Dean, . Japes 'A" <deanja@BP.com>, "GPB, Ops Mgr": <GPBOpsMgr@BP..colll>'.~"AOGCC- Wiriton Aubert (E~rnail) (E-mail)" <winton - aubert@a4mín:state.ak.us>, "Jim:~egg(E-mail} (E~mail)n <jijJn_regg@admih~state.ak.us>' ..'."'...... ".. '. ..,.'.' .' .....'..'.... . C<p: "NSU, ADW.W ell Integrity E~gine~r"'<NSUADWW ellIntegrity~ngineer@BP .com>~' "Olsen~:. Cl~k AU '<OlsenCA@BP:com>, "Corcorati, Kevin D. (VECO)" <Corcorän~Kevin@BP.coni> . .'.'. ) a,ØfP t;<ßO All, Well 05-12B (PTD #2011800) has sustained casing pressure on the IA and the well has been classified as a Problem well. The TIOls on 02/06/05 were 2150/1600/vac. The plan forward for this well is as follows: 1. DHD: TIFL - Failed 2. FB: MITIA, LLR 3. SL:DMY SSSV Nipple / Caliper Attached isa wellbore schematic. Please call if you have any questions. «05-12B.pdf» Clark Olsen BP Exploration Alaska Greater Prudhoe Bay Wells Group Prudhoe: (907) 659-5580 Pager: (907) 659-5100 x (1873) Content-Description: 05-12B.pdf Content-Type: application/octet-stream Content-Encoding: base64 SCANNED FEB 2 22DDS I of 1 2/14/20059:20 AM lREE = 5-1/8" FMC GEN1 WELL H E'Þ. D = FI\,IK; ÄCiûÄTÖR~""'AXËlSÖN KB. ElEV "=" . 69; "BF~"EÜ~V- = "-"""'''''''''--''''-ÑÏÄ'' KOP= ....^..'~ m~~.. 5050' ïï.ïíãx Angie = 99 @ 9822' 't~tUmriiD";;"" ""''''''''''''''''''''9179'; ~-- ,__nmn [Æ¡tum lV D = 8800' SS I 13-3/8" CSG, 72#, N-80, ID= 12.347" l-i r 4-112" BKRDEPLOY SLV, ID= 3.00" I., I TOPOFlINER, ELM ON 12/16/01 l-t 1 2-7/8" X 2-318" LNRXO, ID = 1.92" I., 15-1/2" X 3-1/2" BKRTIEBACK SLV, ID= 4.00" I., Minimum ID = 1.92" @ 8104' 2-718" X 2-3/8" LNR XO ) 2720' 8097' 8093' 8104' 8223' 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" H 8390' I TOP OF 3-3/16" LNR H 8390' I 5-1/2" TBG, 17#, N-80, .0232 bpf, ID= 4.892" H 8447' 1 TOP OF 4-112" TBG H 8447' ÆRFORA TON SUM\t1ARY RB= LOG: SWS MEMGRlCNL ON 12/16/01 ANGLEAT TOP PERF: 88 @ 9325' Note: Refer to Production DB for historical perf data SIZE SPF INlERVAL Opn/Sqz DATE 1-11/16" 4 9325 - 9735 0 12/16/01 1-11116" 4 9795 - 9845 0 12/16/01 1-11116" 4 9920 - 10100 0 12/16/01 1-11116" 4 10175-10330 0 12/16/01 1-11116" 4 10395 - 10460 0 12/16/01 I BAKER aBP SET ON 11/20101 H 8950' 05-128 8 ~/ ~ ~ ~ 1 ') SAFETY NOTES: W8..LANGLE > 70° @ 9275' & > 90° @ 9325'. PRE-5-12A SIDETRACK WELLBORE NOT SHOWN ON DIAGRAM. 2159' H 5-1/2"CAMCOBAL-OSSSVN,ID=4.625" 1 ~ I I 8103' H 3-1/2" X 2-718" XO,ID=2.44" 1 8200' H 5-1/2" MOD. BKR RCP A<R, ID = 2.690" 1 II II 1 8294' I 8356' ~ ~~ 8386' ! 8390' 8: :&-I 8436' \ / 8447' 8507 / I 9-5/8" CSG,47#, N-80, ID= 8.681" H 9358' ~ 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID =2.80" H 9733' ~ 1 TOPOF2-7/8"LNR H 9734' ¡---- I WFRD CIBP SET 09/05/04 H 9876' 1 I BAKERCIBP SET 09/30100 H 10020' 1 I 2-7/8" LNR, 6.5#, L-80, ID = 2.441" H 10588' 1 DATE REV BY COIVMENTS 1998 ORIGINAL COM PLETION 03/04/99 CTD SIDETRACK (5-12A) 12/16/01 CTD SIDETRACK (5-12B) 04/19/01 RWTP CORREcrlONS 10/10/01 DTRlKK XO CORRECTION 11/20/01 DDW/KAK SET CIBP 01/07/02 CH'TP CORREcrlONS -- ;- ~ H 5-1/2" CAM- DB-1 SLIDING SLV, ID = 4.500" 1 H 5-1/2" CAMCO DB - NIP, ID= 4.313" 1 H ~ 1-4 9-5/8" X 5-1/2" BAKER SA B PKR, ID = 4.000" 1 H 1- 5-1/2" BAKER SBRASSY I 3-1/2" X 3-3/16" XO, FLUlED SUB NO GO AND XO 5-1/2"X 4-112" XO, (BEHINDLNR)'I 4-1/2" CAI\,IK;O DB-6NIP, ID = 3.843" (BB-IIND LNR) \ 8564' H 4-1/2" TUBING TAIL(B.EHIND;tN~r 1 H ELMDTTNOT LOGGED 3-3/16" X 9-518" MILLOvr WINDOW 8906' - 8914' (OFF WHIPSTOCK) * RA TAG @ 8910' 1 PBTD l-i 10458' 1 PBTDELM H 10461' 1 I 2-3/8" LNR, 4.7#, L-80, .0039 bpf, ID = 1.92" l-i 10482' 1 I)A. lE REV BY COMMENTS 03l20,.Q2 1LH/1Ih ELM ŒPTHS A DŒD 08l18,.Q3 CMOnLP DATUMM:> 1 ÆRF ANGLE 09/05,.Q4 KEY nLP SET WFRD CBP ffiUDHOE BA Y UNIT WELL: 05-12B PERVIrr No: 2011800 A A No: 50-029-20244-02 SEC 32, T11 N, R15E, 2897' NSL & 5143' WEL BP Exploration (Alas ka) / 8 J~ ~~ ~ '-{ DATA SUBMITTAL COMPLIANCE REPORT 1/6/2004 Permit to Drill 2011800 MD 10482 ..,. .- --- -. -._- -~----- Well Name/No. PRUDHOE BAY UNIT 05-12B ...---- Operator BP EXPLORATION (ALASKA) INC ~p~ 10 ~ ÁMl API No. 50-029-20244-02-00 TVD 8920 Completion Date 12/18/2001 --- Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey___~ :I.IJl\- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Electr Dataset Number Name ._-~ 105~~ Log/ Data Digital Type/ Med/Frmt ¡~ C I ~ ! ~D ~ D Well Cores/Samples Information: Name Log Log Run Scale Media No 1 5 8M 1 1 1 - . . .. c.rr503t3rAdu~¡ë>n c.-fó723~I$Ver¡fiçatioH .. -- -- - --- (data taken from Logs Portion of Master Well Data Maint) :._" Interval OH / Start Stop CH Received 8033 1 0459 Case 1/25/2002 Comments ------- 7800 7800 1 0454 Case 1/21/2003 1 0454 Case 1/21/2003 10482 Open 4/4/2002 8602 - ----- Interval Start Stop Sent Received ADDITIONAL INFORMATION Well Cored? y/(ij) Daily History Received? Chips Received? -y-.¡ N- - Analysis Received? Formation Tops X/N .--- Sample Set Number Comments 0N ~N ~. Comments: --- - - - - .. ----. - - . Com plia""e Reviewed By: ~ Date: ~ J ~ ~ - '1~'c. c.-. c - ( WELL LOG TRANSMITTAL ( ~o/~/tð ProActive Diagnostic Services, Inc. ~') '.- ( r' ~ î ( \' i\\ ~, ~-I~ -'~) t\.. ~, <. . c' ,¡ ... '. ;.. To: State of Alaska AOGCC 333 W. 7lhStreet Suite # 700 Anchorage. Alaska 99501 J/\l~ Z ï 2.00j \\\dsKa Oll & C~lG CÍJns. (¡ühIiHhi::hm ¡ /\(lcl1oraoo RE: Distribution - Final Print( s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CU-HUM FILM COLOR Open Hole 1 1 1 OS 05-12b 01/11/03 Res. Eva/. CH 1 1 1 Mech. CH 1 Caliper Survey Signed: ~1J.~ Date: Print Name: PRoAcTivE DiAGNOSTic SERvicES, INC" ~ 10 K STREET SUiTE 200, ANChoRAGE, AK 99~01 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage@memorylog.com Website: www.memorylog.com { ( Transmittal Form f===-'-ï'" ".'" "'" . "--'-",_...__...._,.."..",..".,...., 'r~~:~:'-:'.., ....-,.,~.,. ~.,_. ..., -.- .." .. ..., -,' .~'-".. ::'~"'~-'."':;;'~' .-;.' .~'~ ." ... BAKER HUGHES ~--. ~-' ..,.....--. , """'" ..,.._,.. ',;--:--::-:-. ::' :::-:-:-:-..-;-:~, AR~~~;VED ~,'~ . ~~~ ~j; ~~~ l r;.:) 0 .:: 2002 . . ~ ~ \ . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNIN(ij.M~.~~" -_: 'n,_~__','-=~~, OR FAXIN G YO DR C 0 PY AnchnrAIIA ":C", "".,-, """.". "'I~"" fi!it,ô't~iM ¡ '"~i, FAX: (403) 537-3767 ~~l"l::, Baker Atlas ~--~~_.J,"¡i"':: #1300, 401-9th Ave. S.W. !(""; Calgary, Albert a, Canada ! . 'I"""':"::'~::~~~;~:~j T2P 3C5 I ..~:~~t'~:'l Direct: (403) 537-3752 t'" I FAX: (403) 537-3767 ' Baker Atlas Canada GEOSciences Centre' To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference: BP Exploration, Inc, 18-32A Prudhoe Bay UnitcQO }-/o1 BP Exploration, Inc. H-07A Prudhoe Bay Unit é).o D-/,à 15 BP Exploration, Inc.15""41BPBIPrudhoeBayUnitaOJ-1 4.~ BP Exploration, Inc.A..41A.PB2Pl11dhoe BayUnitdOO--' O¡S BP Exploration, Inc.O$-12B PrudhoeBayUnitc90)~r~O BP Exploration, Inc~ 05-281\ PrudhQeElayUnitaDJ~}g5 1 - LAS Format disk "'~""'F'l ,. ,. . . .... .. .,'~:iJ ms.,:..,.:.,. "..' ".." '.'.' '.ià::~~~~~=:: Sent By: Josef Berg Received By: è~ ~: Date: Date: . ". 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' . - FW: 05-128,201-180,50-029-20244-02 ( Subject: FW: 05~1~. 1-180, ~ - 29-20244-02 Date: Wed, 13 ~~ -0600 From: "Hubble, Terrie L" <HubbleTL@BP,com> To: "McMains, Steve (AOGCC) (E-mail)" <Steve_McMains@admin.state.ak.us> ( Hi Steve, We found another small error (3') on a semi-recent Completion Report. Please change: PBTD: Top of 2-3/8" Liner: 10461' 8093' (TVD is correct) Thanks! ci1J 's . hYI~ ,q YYì~OL â~~ Terrie Hubble > -----Original Message----- > From: Hubble, Terrie L > Sent: Wednesday, March 13,2002 11:52 AM > To: NSU, ADW Wells Tech Aide > Cc: Catron, Garry R (515) > Subject: 05-12B > > Hi Ladies, > > > > > > > > Thanks! > > Garry, will you please make these two changes on the PDC copy of the > 10-407. Thanks so much for spotting this error! > > > > > I need two corrections to the Completion Diagram for this well. On 12/16/01 a CNL was ran and the PBTD was confirmed at 10461' with the Top of the Liner at 8093'. Probably the bottom of the Liner (from the Liner Summary) is incorrect but the correlation between these two depths doesn't work, so we'll just leave it at 10482'. Terrie Hubble GPB Drilling & Wells 564-4628, MB8-1, Cube 830 1 of 1 3/13/02 4:46 PM -1\ (' STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMI~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of SelVice Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 SelVice 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-180 3. Address 8. API Number P.O, Box 196612, Anchorage, Alaska 99519-6612 50- 029-20244-02 4. Location of well at surface .". ,. r1~1 9. Unit or Lease Name 2897' NSL, 5143' WEL, SEC. 32, T11N, R15E, UM; C;~'-:. . Prudhoe Bay Unit At top of productive intelVal ~.. ,.,.-;. "\' "§ 3786' NSL, 872' WEL, SEC. 31, T11N, R15E, UM !1..1.L:.LLf..L' .$-a .' 10. Well Number .. \. "r . ,-"'.. At total depth ; ~"I~,:,;;';::'. ..'" 05-12B 2770' NSL, 189' WEL, SEC. 31, T11N, R15E, UMt:-:::-'.::~~~.:~:::: .' <c. -." ~ .:.......I't"""';""""~ ~~",:;.,' 11. Field and Pool 5, Elevation in feet (indicate KB, DF, etc.) 6, Lease Designation and Serial No, Prudhoe Bay Field 1 Prudhoe Bay Pool RKB = 69' ADL 028326 12. Date Spudded 13, Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 12/10/2001 12/14/2001 12/18/2001 NIA MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional SulVey 20. Depth where SSSV set 21. Thickness of Permafrost i r\ 10482 8920 FT /0 ti~ 8918 FT 181 Yes 0 No (Nipple) 2159' MD 1900' (Approx.) 22. Type Electric or Other Logs ~Un r MWD, GR, CNL, CCL 23. CASING. LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PUllED 20" 94# N-80 Surface 112' 32" 260 sx Arctic Set (ADDrox.) 13-3/8" 72# H-40 Surface 2720' 17-1/211 61 00 sx Permafrost II 9-518' 47# N-80/S00-95 Surface 8906' 12-1/411 966 sx Class 'G', 275 sx PF II 3-3/16" x 2-7/8" 6.2# 1 6.5# L-80 8223' 8906' 4-1/811 31 bbls 15,8 DDQ LARC Ç. 2-3/811 4.7# L-80 809':t 1 0482' 3# 74 sx Class 'G' " I' 24. Perforations open to Production (MD+ TVD of Top and 25. TUBING RECORD Bottom and intelVal, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 1-11/16" Gun Diameter, 4 spf 5-112", 17#, N-80 8447' 8436' MD TVD MD TVD 4-1/2", 12.6#, N-80 8564' 8564' 9325' - 9735' 8931' - 8925' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9795' - 9845' 8924' - 8922' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9920' - 10100' 8913' - 8905' 2200' Freeze Protected Well with Methonal 10175' -10330' 8907' - 8910' 10395' -10460' 8912' - 8918' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) December 26, 2001 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl CHOKE SIZE GAS-Oil RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-Bel GAs-McF WATER-BBl Oil GRAVITy-API (CORR) Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. RECEIVED JAN 3 0 2002 .., - .. nn\ c:\ \t, 1\ t j~laska Oil & Gas Cons. Commission . . . U'\iUI ~ r\ 1.- - - - - Form 10407 Rev. 0701 80 FEB Y 2~~bmlt In Duplicate RBDMS 8Ft (,r- ( f 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. Top of Zone 2C 8949' 8660' Top of Zone 2B 9011' 8721' 22TS 9060' 8768' Top of Zone 2A 9112' 8816' Top of Zone 1 B 9165' 8859' Top of Zone 1A 9217' 8893' RECEIVED JAN 3 0 2002 '~Iaska Oil & Gas Cons. Commission Anchorage 31 . List of Attachments: Summary of Daily Drilling Reports, Surveys, Pre and Post Rig Summary, 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant Date 0/ -3 O. 05-12B Well Number 201-180 Permit No. / A roval No. Prepared By Name/Number: Sondra Stewman, 564-4750 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 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. ITEM 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 pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, 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. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev, 07-01-80 ORIGINAL BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: 05-12 Common Well Name: 05-128 Spud Date: 12/8/2001 Event Name: REENTER+COMPLETE Start: 12/6/2001 End: 12/19/2001 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/612001 00:00 - 01 :30 1.50 MOB P PRE Secure CT. Remove gooseneck. Set injector in box. Prep rig to move 01 :30 - 06:00 4.50 MOB P PRE Move rig off well and onto DS 14 Pad (-32 deg F ambient). LD windwalls. Scope down derrick. Open pipeshed roof. LD derrick. Close roof 06:00 - 12:00 6.00 MOB N WAIT PRE Crew change safety mtg prior to move. Security is moving D-16 camp-no escorts available. Place rig on Standby @ 0600. Move rig to entrance of DS-14 12:00 - 17:00 5.00 MOB P PRE Put rig on Moving rate. Move rig from DS 14 to DS 5 17:00 - 22:00 5.00 MOB P PRE Begin RU in front of 5-12b (balmy, -18 deg F) 22:00 - 00:00 2.00 MOB P PRE Pull injector out of box. Install gooseneck. Replace packoff. Stab CT 12/7/2001 00:00 - 01 :00 1.00 MOB P PRE Chk moving system, jack up rig 01:00 - 01:20 0.33 MOB P PRE Safety mtg re: move over tree 01 :20 - 02:30 1.17 MOB P PRE Spot rig over tree and set down. Berm cellar windwalls 02:30 - 04:30 2.00 BOPSUf; P DECOMP Accept rig for operations at 0230 hrs 12/7/01 ND tree cap. NU BOPE. DSM lay green tank tarp 04:30 - 06:30 2.00 BOPSUf; P DECOMP Test BOPE. Witness waived by AOGCC 06:30 - 11 :00 4.50 BOPSUf; P DECOMP Slide green tank in place. Lower rams not holding. Check test pump. Test pump ok, lower rams still leaking. Continue with BOP test while getting parts to repair rams from DS shop. 11 :00 - 13:00 2.00 BOPSUf; N RREP DECOMP Replace lower 2" rams. Rubbers torn on 1 ram. 13:00 - 18:00 5.00 BOPSUf; P DECOMP Continue pressure test. 18:00 -19:30 1.50 BOPSUf; P DECOMP BOP test finished. PU injector, weld on CTC. Pull test CTC 25k. Fill CT wi 2% KC!. PT CTC and inner reel valve @ 4000 19:30 - 20:30 1.00 STWHIP P WEXIT MU milling BHA 20:30 - 22:00 1.50 STWHIP P WEXIT RIH. Take 175 bbls (?) MeOH returns to slop tank 22:00 - 00:00 2.00 STWHIP N SFAL WEXIT Set down 10k at 8225' CTD 25.3k, 15k. PUH to 8100' and circ out MeOH 1.0/500 while BHI MWD tries to boot up new computers 1218/2001 00:00 - 00:50 0.83 STWHIP N SFAL WEXIT BHI work to sync new computer system. Continue to circ out MeOH 00:50-01:10 0.33 STWHIP N SFAL WEXIT Log up from 8080' CTD 1.5/1500, BHI give up on new PC's, not tracking depth among other things 01:10 - 02:30 1.33 STWHIP N SFAL WEXIT Circ at min rate while BHI MWD changes back to old PC's. Fire drill, discuss 02:30 - 03:30 1.00 STWHIP P WEXIT Log up from 8080' CTD 1.5/1500/11 OR 03:30 - 04:00 0.50 STWHIP P WEXIT Corr -6'. At 8020' E=7998' M. RIH, clean thru last set down area. RIH wi sli wt loss into 3-3/16". Tag at 8907' at min rate. PUH 25.3k, start pump 04:00 - 04:50 0.83 STWHIP P WEXIT Check TF at 60R. Orient to 160L. RIH and chk 1.6/1640 at 148L. RIH and tag at rate at 8906.6'. Flag CT here and reset to 8906.0'. PUH l' 04:50 - 05:10 0.33 STWHIP P WEXIT Begin time milling 1.7/1800/138L at 8905' by schedule 8905' E=8887.5' M. Had initial 500 psi diff, then back to FS. After 10 min TF started moving CW wi no ditto Ended up at 92L 05:10- 05:45 0.58 STWHIP N DPRB WEXIT Orient around parked at 8905'. Got 12, 7, 3 clicks and TF returned to exactly the same 92L 05:45 - 06:10 0.42 STWHIP N WEXIT PUH orienting and will start all over 06:10 - 06:45 0.58 STWHIP P WEXIT Back at 8905' 1.7/2080/164L Resume time milling at 0615 hrs 06:45 - 08:00 1.25 STWHIP P WEXIT Update at 06:45, 8905.1', 1.8/1.8/2100 psi. TF 220 deg. 17170 Ibs string wt. Spill drill ( (' Printed: 12/26/2001 8:57:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: (' (' Page-2 of 10 BP EXPLORATION Operations Summary Report 05-12 05-128 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Phase 12/8/2001 08:00 - 09:00 From - To Hours Activity Code NPT WEXIT Date 09:00 - 09:15 09:15 - 09:20 09:20 - 10:00 10:00 - 10:45 10:45 - 11 :05 11 :05 - 11 :26 11 :26 - 13:00 13:00 - 13:20 13:20 -13:50 13:50 -15:30 15:30 -17:00 17:00-17:10 17:10 - 17:25 17:25 -17:35 17:35 -18:30 18:30-21:15 21:15-22:45 22:45 - 23:15 23:15 - 23:50 1.00 STWHIP P 0.25 STWHIP P 0.08 STWHIP P 0.67 STWHIP P 0.75 STWHIP P 0.33 STWHIP P 0.35 STWHIP P 1.57 STWHIP P 0.33 STWHIP P 0.50 STWHIP P 1.67 STWHIP P 1.50 STWHIP P 0.17 STWHIP P 0.25 STWHIP P 0.17 STWHIP P 0.92 STWHIP P 2.75 STWHIP P 1.50 STWHIP P 0.50 STWHIP P 0.58 STWHIP P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Start: 12/6/2001 Rig Release: Rig Number: Spud Date: 12/8/2001 End: 12/19/2001 Description of Operations Update at 08:00.8905,5', 1,8/1.8/2255 psi, TF214 deg, 14300 Ibs string wt, 1600 wob, Seeing some reactive torque when we give each 0.1' now. Update at 09:00, 8509.9', 1.7/1.7/2310 psi, TF 183 deg, 14050 Ibs string wt, 1875 wob. Seeing more reactive now. Getting significant reactive torque. Not yet engaged on whipstock face. Milling depth is exactly at top of tray. Need to keep tool face aligned with whipstock. Pick up 6', get 1 click on orienter. Rate back up to 1.7/1.7/2270 psi free spin. RI H to 8906.0'. Back on milling depth of 8906.0'. 1.7/1.7/2240 psi, TF 220. Update at 10:00, 8906.3', 1.7/1.7/2400. TF 220. 8906.7', Getting significant reactive torque again, just as before. Tool face back around to 175 deg. Also getting 2700 Ibs wob, 300 Ibs motor work. Stop here and let drill off. Reluctant to get another click as it didn't seem to help last time, but have no other choice, as no loss of reactive during drilloff. Pick up and get 1 click. Got TF of 231 deg, RIH and try it again. Resume milling from 8906.7',1.7/1.7/2320 psi. TF 232 deg. WOB=2600. Stop here for 20 minutes prior to resuming time miling. 8906.8',1.7/1.7/2450, Tf=207. WOB=2140 Ibs. Resume time milling. Slow rate down to 0.1' every 15 minutes. Seem to get too much reactive when milling at the higher ROP. TF holding at 199 deg. 8907.4', 1.7/1.7/2670, TF=199, WOB=3450 Ibs. Continueing to time mill, at 15 min/0.1', TF holding steady. Getting some metal returns on ditch magnets, pump 10 bbl bio sweep to clean hole. Motor work fell off from 2670 to 2500 psi. TF holding constant at 200 deg. Increase ROP to 8 minutes/0.1'. 8909.0', 15:30 update. TF slowly walking around, now at 183 deg. CTP=2770 psi, lots of motor work, no Stalls. WOB up to 5670 Ibs. Slowly coming up ever since we increased Rap to 8 min/0.1'. No drilling breaks observed as yet. 8910.1',17:00 update. TF holding steady at 180 deg. CTP=2650, getting 350 psi good motor work. WOB up to 7200 Ibs. No losses. Continuing to mill at 8 min per 0.1'. CTP=2600 psi, WOB=7800 Ibs. Slow down ROP to keep from exceeding 8000 Ibs WOB. Pick up to check weight and free spin. FS pres=2250 at 1.6 bpm. RIH, tag at 8908.2, stack same WOB as before. 8910.2', Milling at very low ROP. Watching WOB, and maintaining less than 8000 Ibs. Circ press hanging in at 2770 psi (about 400 Ibs motor work). 8910.3' Keep WOB less than 8k wi 350 psi diff. Should be close to drillout. Pump sweep 8910.6' P rate has slowed and have a bunch of hours on motor. Flag CT at 8800' EOP. POOH to change motor Safety mtg re: Change out injector lifting slings for shorter slings-do it Change out motor. Mill had center wear and all areas had less Printed: 12/26/2001 8:57:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12/8/2001 12/9/2001 Date ( ( Page 3 of 1 0 BP EXPLORATION Operations Summary Report 05-12 05-128 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 23:15 - 23:50 From - To Hours Activity Code NPT WEXIT 23:50 - 00:00 00:00 - 01 :25 01 :25 - 02:00 02:00 - 03:30 03:30 - 05:00 05:00 - 05:30 05:30 - 07:00 07:00 - 07:45 07:45 - 09:05 09:05 - 09:30 09:30 - 10:00 10:00 - 11 :30 11:30-12:15 12:15 - 14:10 14:10 - 15:10 15:10 -15:40 15:40 -17:15 17:15 - 18:00 18:00 -19:00 19:00 - 20:10 20:10 - 20:25 20:25 - 20:40 0,58 STWHIP P 0.17 STWHIP P 1.42 STWHIP P 0.58 STWHIP P 1.50 STWHIP P 1.50 STWHIP P 0.50 STWHIP P 1.50 STWHIP P 0.75 STWHIP P 1.33 STWHIP P 0.42 STWHIP P 0.50 STWHIP P 1.50 STWHIP P 0.75 STWHIP P 1.92 STWHIP P 1.00 STWHIP P 0.50 STWHIP P 1.58 STWHIP P 0.75 STWHIP P 1.00 STWHIP P 1.17 STWHIP P 0.25 STWHIP P 0.25 STWHIP P Phase WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Start: 12/6/2001 Rig Release: Rig Number: Spud Date: 12/8/2001 End: 12/19/2001 Description of Operations than 10% wear Kick drill while MU BHA RIH wi BHA #2 (1.75 deg motorlsame mill) Continue RIH wi BHA #2 Corr -10.4' at flag. Boot up MWD PC. Chk TF 233 deg. RIH 1.6/2500/222 See other flag on depth. First minor motor work at 8906.7'. Brake ream to btm at 0.1'/2-10 min 8908.5' 250 diff 4.8k WOB Acting the same as previous run-like drilling on hard rubber. .. Shaker shows red paint/rubber like flakes (assume WF motor paint) and lots of fine steel-wool like particles 8910.0' 330 diff 7.8k WOB Pump a sweep 8910.6' 600 diff 8.6k WOB Lock brake and let it drill off. Have 10-15 deg reactive at 182 deg 8910.8', Update at 07:00. Milling at 1.7/1.713100 psi. Free spin 2550 psi. WOB=81 00 Ibs. Cleaned ditch magnets, checked 15 minutes later, getting good metal on magnets. Captured sample from shaker. Getting fine wiskers of metal back. Looks like typical window milling. Checked with Wells Group PE's, the bond log fax I got shows a 9-5/8" casing collar at 8910', which is where we are. Consult with town. POOH for BHA. POOH Lay down 1.75 deg motor, motor OK. Inspect mill. Still in very good condition. All diamonds still present, swirl wear pattern. Press test casing to see if we have an exit hole yet. Email photos of mills to town. Consult with town as to plan forward. Town CBL shows corrected collars, none at 8910'. MU BHA #3, Hughes 2.74" WS, re-ran 1.75 deg adjustable motor. RIH with BHA #3. Log tie in pass down from 8640' bit depth. Log at 60 fph. Make -7' correction. Stop and paint flag at 8906'. Tag up at 8911.0', Free spin=2150 psi at 1.55 bpm in rate. TF 220. Stack until we get motor work and WOB. 2600 psi (500 psi motor work), 3200 psi weight on bit. Significantly more work for this WOB. Feeding in at a rate that keeps motor work at 500 psi. Getting good drill offs on both motor work and WOB. TF around to 177. Pump 30 bbl sweep of 5% lubtexlKCL Mill at 6 minutes per 0.1'. Mill from 8911.0' to 8913.2'. WOB up to 4900 Ibs, CTP up to 2740 psi. Stop 6/0.1' until it drills off. Mill with tool stationary at 8913.2' until we get some drill off. 8913.2', Update at 18:00. WOB=4050 Ibs, CTP 2650 psi. 1.6/1.6 bpm. TF=180. 8914.0' 500 diff, 5.2k WOB Lock brake here and let it drill off for 40 min. Lost 3k wt, but only 100 diff Get 0.1' and stalled. PUH to 8900' and chk FS 1.6/2300. Ream back in hole wi little diff until 8913.5'. Ream 0.1'/3 min avg to TD Back to 8914.1' with full string wt, and 200 ditto Assume we have a window. Pump bio sweep. Drill open hole 15'/h r wi 250 Printed: 12/26/2001 8:57:12 AM BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: 05-12 Common Well Name: 05-128 Spud Date: 12/8/2001 Event Name: REENTER+COMPLETE Start: 12/6/2001 End: 12/19/2001 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/912001 20:25 - 20:40 0.25 S1WHIP P WEXIT diff and 2000 WOB at 200 deg TF. Will call btm of window at 8914', with top of window at 8906' 20:40 - 21 :10 0.50 S1WHIP P WEXIT 8917.6' 300 diff, 5k WOB and slow drill off. Resume drilling OH at 350 psi diff 4k WOB. Drill to 8920.0' and drill off, 171 R 21:10-21:30 0.33 S1WHIP P WEXIT Backream 2'/min, clean. Check flag at 8906' and on depth. POOH for dressing mill 21 :30 - 22:40 1.17 S1WHIP P WEXIT At 8000', PT wellbore to 384 psi and pump away at 0.3 bpm. Resume POOH 22:40 - 23:25 0.75 S1WHIP P WEXIT Change out mill. Mill had center wear and all areas had less than 30% wear. Gauged 2.74" minus. Change out reel swivel and PT @ 4000 23:25 - 00:00 0.58 S1WHIP P WEXIT RIH wi BHA #4 (2.72" tapered mill, cutrite only, no MM buttons) 12/10/2001 00:00 - 01 :00 1.00 S1WHIP P WEXIT Continue RIH wi BHA #4 01 :00 - 01: 15 0.25 S1WHIP P WEXIT Stop at 8900' and get TF 205 deg, RIH 1.6/2280/200 deg and corr -11' at flag and promptly stall at 8906.45' 01:15 - 03:00 1.75 S1WHIP P WEXIT Lose ground back to 8904.7' with two stalls. Begin dressing from here at 186 deg 03:00 - 04:10 1.17 S1WHIP P WEXIT 8910.3' stall. Brake ream (1.6/2280/200 deg TF avg) to TD at 8917.2' CTD (may be a little off depth). Losing 3 bph. Backream 1-2'/min at same TF to 8900', clean. RBIH 3'1 min to TD while pumping a 26 bbl sweep, clean 04:10 - 05:00 0.83 S1WHIP P WEXIT Get a click, backream to 8900'. RBIH. Repeat again. Final TF at 243 deg. RIH/POOH dry thru window twice, clean. Backream thru again at 254 deg, clean 05:00 - 06:20 1.33 S1WHIP P WEXIT POOH for drilling assy while chasing sweep to surface 06:20 - 07:30 1.17 S1WHIP P WEXIT LD milling BHA. Crayola mill guages 2.65". 07:30 - 08:00 0.50 DRILL P PROD1 MU drilling BHA. 2.1 deg motor, Hughes Bi centered bit. 08:00 - 09:35 1.58 DRILL P PROD1 RIH with BHA #5, First Build section BHA. Shallow hole test at 500', ok. Continue RIH. 09:35 - 10:10 0.58 DRILL P PROD1 Log tie in pass down from 8640' CTM. Make -9' correction. 10:10 -13:10 3.00 DRILL P PROD1 RIH thru window with no drag or bobbles on weight. TF was 160 R. Tag TD at 8918'. Start swap to mud. Test drill, able to make 50 fph with out pushing hard. 13:10 -14:40 1.50 DRILL N DFAL PROD1 Orient to 150L to begin drilling build section. Took 6 clicks, got none. Took 5 more, and didn't get any. Pull up below window. Got 3, but not all we needed, then BHA flopped while RI H. Pull up above window. Got clicks, tool flopped running back to bottom. Try again, this time don't get any clicks. Suspect orienter shot. Try again. Can't get any clicks now at all. 14:40 -15:50 1.17 DRILL N DFAL PROD1 8938', POOH for orienter. (Unrelated note - Geo reports 80% pebbly chert in cutting samples. Ouch) 15:50 - 16:30 0.67 DRILL N DFAL PROD1 Tag up at surface. Changed MHA (Leak at disconnect), changed orienter, Checked bit; in good shape. Reran same bit and motor. Motor housing had grooves on bottom 5' possibly from chert in hole. 16:30 - 18:15 1.75 DRILL N DFAL PROD1 RIH with BHA #6. 2.1 deg motor, Hughes bi centered bit. 2.70x3.0". Shalliow hole test at 5200' ok. Continue RIH. 18:15 - 18:20 0.08 DRILL N DFAL PROD1 Stop at flag from last pass at 8700'. Make a -11' correction. 18:20 - 21:15 2.92 DRILL P PROD1 RIH thru the window slick. Orient to 150L. Tag TD and orientor flops. Pull back thru window, clean and TF moves to desired setting. RIH thru window. Repeat several times while making 3' of hole to 8941' ( ( Printed: 12/26/2001 8:57:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/10/2001 12/11/2001 12/12/2001 (' ( BP EXPLORATION Operations Summary Report 05-12 05-128 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 21:15 - 22:30 From - To Hours Activity Code NPT 22:30 - 00:00 00:00 - 00:40 00:40 - 02:50 02:50 - 03:30 03:30 - 05:15 05:15 - 05:40 05:40 - 06:10 06:10 - 06:30 06:30 - 09:00 09:00 - 09:20 09:20 - 11 :00 11 :00 - 12:00 12:00 -12:15 12:15 - 12:25 12:25 - 13:35 13:35 -15:15 15:15 - 16:45 16:45 - 18:00 18:00 -19:00 19:00 - 21 :00 21 :00 - 22:45 22:45 - 00:00 00:00 - 00:30 00:30 - 01 :45 01 :45 - 03:30 03:30 - 04:00 04:00 - 04:30 1.25 DRILL 1.50 DRILL 0.67 DRILL 2.17 DRILL 0.67 DRILL 1.75 DRILL 0.42 DRILL 0.50 DRILL 0.33 DRILL 2.50 DRILL 0.33 DRILL 1.67 DRILL 1.00 DRILL 0.25 DRILL 0.17 DRILL 1.17 DRILL 1.67 DRILL 1.50 DRILL 1.25 DRILL 1.00 DRILL 2.00 DRILL 1.75 DRILL 1.25 DRILL 0.50 DRILL 1.25 DRILL 1.75 DRILL 0.50 DRILL 0.50 DRILL P P P P P P P P P P P P P P P P P P P P P P P P P P P P Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Page 5 of 10 Start: 12/6/2001 Rig Release: Rig Number: Spud Date: 12/8/2001 End: 12/19/2001 Description of Operations Begin making steady progress from 8941' albeit slow due to hard Zone 3 formation at about 5'/hr 1.6/3300/11 OL. Did not see RA marker at 8910.5' 8953' Penetration rate increasing, up to 17'/hr with few stalls. Drill to 8976' 1.6/2850/130R 8976' Orient around Drilling 1.6/2850/70L at about 25'/hr wi frequent stalls in 25 API Z2 rock 9022' Orient around Drilling 1.6/2870/90L at 30'/hr. No azimuth yet. Penetration rate pick up at 9030' to 50'/hr 9073' Attempt survey wo success. Get two clicks Drilling 1.6/2900/25L 60-1 OO'lhr 9101' Get a survey and getting a tite turn. Orient to right 9108', Drilling 1.6/1.6 2950 psi, TF=45R, trying to straighten out curve a little. Got real tight just out side the window. (Who says HC bicenter bits don't build angle? We were getting 28's!). No fluid losses, ROP=25-30 fph. Geo's expect shale at this depth, so ROP is appropriate. 9200', Wiper trip to shoe. Return to drilling. 9236', Hard drilling in shale. 1.6/1.613400 psi. TF10R. Getting good motor work, slow ROP. 9243', Noon update. Still drilling hard shale. 1.6/1.6/3250 psi. TF 20R. Getting good motor work, Pluggin' away at 15 fph. ROP down to 4 fph. Wiper trip prior to resuming drilling, Back to drilling 15 fph. 9260' Not getting the build angles in this shale we need to land well above Kavik. POOH for bigger bend motor. No bobbles at all through window. Flag pipe at 8800' EOP. BHA change out. Change motor from 2.13 to 2.6 deg. RIH. Minus 6' correction at flag. Continue in hole. Window smooth at 8906'. Ream shale at 9215'. Drilled at 15R. Orient to original TF. Ream ahead. Tough drilling. Work our way back to TO of 9260'. 3100 psi @ 1.5 bpm. Drilling build section. Drilled out of shale at 9264 ft CTD. ROP = 40-80 FPH, TF = 30R, 1.6 11.6 BPM, 3000 psi. Drilled to 9300 ft. Drilling build section. Landed well in Zone 1 sand at 9330 ft CTD, 8862 ft TVDSS. ROP = 80 FPH, TF = 90R, 1.6 11.6 BPM, 3000 psi. Drilled to 9377 ft CTD. POOH for lateral MWD BHA. POOH with build BHA. CIO MWD batteries, adjust motor to 1.15 deg. bend. M/U Bit #8 RIH with lateral MWD BHA #8. Shallow test BHI tools. RIH to flag. Correct -17 ft CTD at flag. Log Tie-in with GR at RA tag at 8910.5 ft. [ + 6 ft CTD]. Good RA tag. RIH to TD of 9381 ft. No problem running in open hole across Printed: 12/26/2001 8:57:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/12/2001 12/13/2001 ( ( , BP EXPLORATION Operations Summary Report 05-12 05-128 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Activity Code NPT 04:00 - 04:30 04:30 - 07:15 07:15 - 08:30 08:30 - 10:00 10:00 -10:15 10:15 - 10:30 10:30 - 11 :30 11 :30 - 12:20 12:20 - 12:30 12:30 - 14:30 14:30 -15:45 15:45 - 17:00 17:00 -19:10 19:10 - 20:30 20:30 - 21 :00 21 :00 - 21 :30 21 :30 - 22:00 22:00 - 00:00 00:00 - 02:00 02:00 - 04:00 04:00 - 05:00 05:00 - 05:45 05:45 - 06:30 06:30 - 08:00 08:00 - 08:15 08:15 - 10:00 10:00 -10:15 10:15 -10:30 10:30 - 12:15 12:15 -12:30 12:30 - 15:00 15:00 -16:00 16:00 -16:15 16:15 -19:00 0,50 DRILL 2.75 DRILL 1.25 DRILL 1.50 DRILL 0.25 DRILL 0.25 DRILL 1.00 DRILL 0.83 DRILL 0.17 DRILL 2.00 DRILL 1.25 DRILL 1.25 DRILL 2,17 DRILL 1.33 DRILL 0.50 DRILL 0.50 DRILL 0.50 DRILL 2.00 DRILL 2.00 DRILL 2.00 DRILL 1.00 DRILL 0.75 DRILL 0.75 DRILL 1.50 DRILL 0.25 DRILL 1.75 DRILL 0.25 . DRILL 0.25 DRILL 1.75 DRILL 0.25 DRILL 2.50 DRILL 1.00 DRILL 0.25 DRILL 2.75 DRILL P P P P P P P P P P P P P P P P P P P p P P P P P P P P P P P P P P Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Page 6of 10 Start: 12/6/2001 Rig Release: Rig Number: Spud Date: 12/8/2001 End: 12/19/2001 Description of Operations shales. Drilling, 1.6/1.6 bpm, 3000 psi, TF = 90L. Drill to 9550'. Short trip to window. Ream and back ream shale from 9200' to 9250'. Drilling, 1.6 11.6 bpm, 3050 psi fs, TF:65L Drill to 9680'. Orient to 40L. Drill to 9700'. Wiper trip to window. Ream shale at 9200-9250' again. Drill ahead to 9747'. Orient to 90R Drilling, 1.6/1.6 3200 psi fs. TF:90R Drill to 9843' Ratty drilling, erratic ROP. Short trip to window. A lot of motor work while pulling through 9240-9200'. Ran through same section with reduced pump rate. Fairly smooth, but several bobbles. Drilling, 1.6/1.5 bpm 3200 psi fs, TF:90R. Drill to 9908'. Start new mud down hole. Continue drilling. TF = 170R, 1.5 I 1.5 bpm, 2600 psi. Drilled to 9950 ft. Drilling, 1.6 11.6 bpm, 2800 psi, TF = 175R, Drilled to 9988 ft. Wiper trip to window. Hole in good condition. Log tie-in with GR at RA tag at 8910.5 ft. Added 9 ft to CTD. RIH to TD. Hole clean. Drilling, TF = 170R. 1.6 11.6 bpm, 2800 psi, Incl = 90 deg, Drilled to 10,042 ft. Drilling, stacking wt. 1.7/1.7 bpm, 2800 psi, TF = 95R, Drilled to 10,066 ft. Adding Lubetex to mud to bring up to 4%. Drilling, 1.7/1.7 bpm, 2800 psi, TF = 95R, Incl = 92 deg, Drilled to 10,140 ft. Wiper trip to window. Hole Clean. RIH. Found ledge at 9800 ft. Bounced thru on fourth try. RIH to TD. Orient TF to Drilling, TF = 120L, 1.7/1.7 bpm, 3000 psi, 91 deg incl. Drilled to 10150'. Drilling, in shale. Drop angle to 89 deg. Orient to 30L to stop drop. Drilling, 1.7/1.7 bpm, 3000 psi fs, TF:30L. Drill to 10260'. Orient to HS. Drilling, 1.6/1.6 3000 psi fs, TF:HS. Inc: 84 deg. Drill to 10272' . Short trip to window. Ream and back ream from 9200' to 9230'. Cannot run through easily pumping at 1.6, but able to go with minor bobbles pumping at 0.5 to 0.8 bpm. Did not see ledge at 9800'. Orient to 85L. Drilling, 1.6/1/6 3050 psi fs, TF:80L. Drilling in sand, but having trouble keeping pipe moving with motor work. Drill to 1 0343'. Drilling, very slow. Possible problem with BHA. Drill to 10347'. Orient to 11 OL. Drilling, 1.6/1.6 3100 psi fs, TF:11 OL. Drilling very slow in Printed: 12126/2001 8:57:12 AM ( ( Page 7 of 10 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 05-12 05-128 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date 12/13/2001 12/14/2001 12/15/2001 From - To Hours Activity Code NPT 16:15 -19:00 19:00 - 20:00 20:00 - 22:00 22:00 - 22:40 22:40 - 00:00 00:00 - 00:30 00:30 - 01 :00 01:00-02:10 02:10 - 02:30 02:30 - 04:45 04:45 - 06:00 06:00 - 07:00 07:00 - 07:15 07:15 - 08:00 08:00 - 08:15 08:15 - 08:30 08:30 - 10:30 10:30 -13:00 13:00 - 14:15 14:15 - 15:30 15:30 -16:30 16:30 - 17:30 17:30 - 19:30 19:30 - 20:00 20:00 - 20:15 20:15 - 20:45 20:45 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 01 :30 01 :30 - 02:30 2.75 DRILL 1.00 DRILL 2.00 DRILL 0.67 DRILL 1.33 DRILL 0.50 DRILL 0.50 DRILL 1.17 DRILL 0.33 DRILL 2.25 DRILL 1.25 DRILL 1.00 DRILL 0.25 DRILL 0.75 DRILL 0.25 DRILL 0.25 DRILL 2.00 DRILL 2.50 DRILL 1.25 DRILL 1.25 DRILL 1.00 DRILL 1.00 DRILL 2.00 DRILL 0.50 DRILL 0.25 CASE 0.50 CASE 2.25 CASE 0.50 CASE 0.50 CASE 1.50 CASE 1.00 CASE P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P P Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 COMP CaMP COMP CaMP COMP COMP COMP Start: 12/6/2001 Rig Release: Rig Number: Spud Date: 12/8/2001 End: 12/19/2001 Description of Operations shale at 10366'. POOH to check BHA. Pull up 500 ft and found scrape marks on CT on reel. Mark on coil is 500 ft into well with bit at TD, so mark is from junk in injector head, possible broken pin or bolt scraped on CT. File marked section, Ultrasonic tester measured only 0.02" of wall loss at worst point. Marked pipe will only be flexed a few more times while drilling to TD. It will stay on the reel after running liner. Decide to finish well with reel. POOH to check BHA. At surface, press test MHA - OK. Change out motor. Install new bleed sub. Bit had 2 plugged jets. Only one slightly worn PDC. RIH with MWD BHA #9. 1.00 deg. bent motor and Bit #9 RR1, HC bi-center. RIH with BHA#9. Log Tie-in with GR at RA tag. -11 ft. CTD. RIH to TD. Ream shale at 10145 ft. RIH to TD of 10366 ft. Orient TF to 100L. Drilling, 1.5/1.5 bpm, 2850 psi, TF = 120L, Very slow drilling in high GR shale. GR is above 210 API. Drilled to 10,396 ft. Drilling, 1.6/1.6 bpm, 3000 psi, TF = 80L, Very slow drilling in high GR shale. Drilled to 10,400 ft. Drilling, 1.6/1.6 bpm, 3000 psi, TF = 80L, Drill to 10430' Orient to 80L to begin leveling out. Drilling, 1.6/1.6 bpm, 3000 psi fs, TF:80L. Drill to 10460'. Orient to 30L. DriUing. Having trouble getting started after orienting Short trip to window. Tight spots @ (10,194- 10154- 9210)-orient to pass 9210' Drill to 10479'.. Hit shale again at +1- 10458'. Call TO. Condition hole for liner. Log final gr tie in from 8590'. Add 11' correction. RIH. Hole pretty smooth. Reamed 9200 to 9230' once, then RIH to TD, corrected to 10482'. Pump 30 bbl hi vis pill wi 5% lubtex. Lay in 1:1. POOH Layout MWD BHA. Bit still in great shape [1-1-1, 1 worn PDC] SAFETY MEETING. Review procedure and hazards for running 2 3/8" liner. Prep rig floor to run 2 3/8" liner. Run 2 3/8", 4.6#, L-80, STL Liner. Drift each STL connection with BKR 1.90" drift, using 1" CSH JT and Pup Fill liner at half way point. Run 2 3/8", 4.6#, L-80, STL Liner. Drift each STL connection with BKR 1.90" drift, using 1" CSH JT and Pup. 2 STL turbos did not drift after make up. Replaced them and re-drifted OK. Finish running 2-3/8", 4.6#, L-80, STL liner. Drift each made up STL conn. with 1.90" drift. MIU BKR CTLRT and CT connector. Pull test and press test. BHA = 2394.2 ft. ,... Printed: 12/26/2001 8:57:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/15/2001 12/16/2001 ( , ( Page 8 of 10 BP EXPLORATION Operations Summary Report 05-12 05-128 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 02:30 - 04:00 From - To Hours Activity Code NPT COMP 04:00 - 04:40 04:40 - 05:20 05:20 - 07:00 07:00 - 07:45 07:45 - 08:00 08:00 - 09:30 09:30 - 10:00 10:00 - 10:15 10:15 - 12:00 12:00 - 13:00 13:00 -19:00 19:00 -19:30 19:30 - 19:45 19:45 - 20:15 20:15 - 22:30 22:30 - 00:00 00:00 - 01 :30 01 :30 - 02:00 1.50 CASE P 0.67 CASE P 0.67 CASE P 1.67 CASE P 0.75 CASE P 0.25 CASE P 1.50 CASE P 0.50 CASE P 0.25 CASE P 1.75 CASE P 1.00 CASE P 6.00 BOPSUF P 0.50 EVAL 0.25 EVAL P P 0.50 EVAL P 2.25 EVAL 1.50 EVAL 1.50 EVAL P P P 0.50 EVAL P Phase COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP Start: 12/6/2001 Rig Release: Rig Number: Spud Date: 12/8/2001 End: 12/19/2001 Description of Operations RIH with 2 318" liner on CT. Stop above window at 8800 ft. Up wt = 25.5K, Dwn wt = 15K. Run thru window with no wt. loss. RIH at 60 fpm, 0.1 bpm, 1600 psi. RIH slick to 10,162 ft. Set down wt. in shale at 10150 ft. Work thru, Set down at 10217 ft, work thru. Set down at 10,350 ft. Work thru. Set down at 10430 ft. RIH to TD of 10495 ft, Set down 5 times at same depth. Up wt = 27K. Correct CTD to 10,482 ft BKB. Pump 5/8" steel ball to release from liner. Stack 10K on liner. Ball on seat at 31 bbls. Shear released at 3700 psi. Designed to shear at 2400 psi. Pick up free at 18K, Pick up free twice. Set back down on liner. Circ well to 2% KCL water with friction reducer. Recover FloPro and ship back to MI for reconditioning. pump 1.7 bpm, full returns, 2900 psi. MIRU OS cementers. Batch mix 16 bbls Class G, 15.8#, latex cement. Continue to circulate at 1.0 in I 0.8 out. Cement up to weight. Hold pre job safety I tool box mtg. Discuss pumping, safe area, clean up procedures. Pump 5 bbls fresh water. PT to 4000 psi. Pump 16 bbls cement. Drop & verify dart away. Displace cement w/1 bbl kcll 20 bbls bio I 28 bbls kcl. Initial disp at 2.0 at 3700 psi. Dart landed at 40.6 bbls. Lost rtns. Had to slow to 1.0 bpm at 4000 psi. Erratic rtns that slowly cleaned up to 1: 1. Plug bumped at 49.6 bbls. Bleed coil. Floats holding. Pressure up to 1000 psi. Unsting from liner at 19K# up wt. Estimate lost 2-3 of 16 bbls to formation. Continue to circulate bio out of coil to wash lap. Liner also full ofbio. Circulate OOH. 1:1 rtns. Estimate 2-3 bbls good green cement in returns. MU swirl nozzle. Jet out BOP stack to remove cement. Perform weekly BOP test. Witness waived by J. Crisp (AOGCC) Prep floor to run SWS memory CNL I GR I CCL. SAFETY MEETING: Review procedure and hazards for running CNUGR and 1" CSH workstring. MIU CNUGR logging tools, circ sub, Hyd Discon and XC. DS lab CMT sample at 1800 psi at 1930 hrs. Pick up 80 Jts, 1" CSH workstring. RIH with CNL I workstring on CT. 0.7 bpm, 670 psi. Tagged top of liner at 8906 ft CTD. Pick up and fell thru OK. RIH. Log down from 8000 ft at 30 fpm with SWS Memory CNUGR/CCL logging tools. Circ. at 1.0 bpm, 1400 psi, Full returns. Tag PBTD of 10,458 ft at 10,418 ft CTD, about 40 ft shallow. Apparently have some cement in liner above landing collar. Pump 15 bbls, new high viscosity FloPro to circ sub. Printed: 12/26/2001 8:57:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/16/2001 12/17/2001 ( (' BP EXPLORATION Operations Summary Report 05-12 05-128 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 02:00 - 03:45 From - To Hours Activity Code NPT 03:45 - 05:00 05:00 - 06:00 06:00 - 06:15 06:15-07:15 07:15 - 07:45 07:45 - 08:00 08:00 - 12:00 12:00 - 13:45 13:45 - 15:00 15:00 -19:00 19:00 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 02:15 02:15 - 02:30 02:30 - 04:30 04:30 - 04:45 04:45 - 09:00 09:00 - 09:30 1.75 EVAL 1.25 EVAL 1.00 EVAL 0.25 EVAL 1.00 EVAL 0.50 EVAL 0.25 PERF 4.00 PERF 1.75 PERF 1.25 PERF 4.00 PERF 3.00 PERF 1.00 PERF 1.00 PERF 2.25 PERF 0.25 PERF 2.00 PERF 0.25 PERF 4.25 PERF 0.50 PERF P P p P P P P P P P N N Phase COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP STUC COMP STUC COMP N STUC COMP P P P P P P P COMP COMP COMP COMP COMP COMP COMP Page 9 of 10 Start: 12/6/2001 Rig Release: Rig Number: Spud Date: 12/8/2001 End: 12/19/2001 Description of Operations Log up from PBTD at 30 fpm while laying in new FloPro in liner. 0.3 bpm, 500 psi. Log up to 8000 ft, Flag CT at 5500 ft EOP. BHA = 2468 ft. POOH with CT. Stand back 40 stds of CSH workstring. SAFETY MEETING. Review procedure and hazards for laying out CNUGR. LD logging tools. Process data. Found PBTD at corrected depth of 10461' indicating no cement above landing collar. Corrected TOL is 8093'. EOP flag corrected to 5545'. Test liner lap to 2000 psi for 30 minutes. Held solid. Hold pre job safety mtg to discuss running perf guns. MU 80 jts 1" CSH and 1,155' (54) 1.56" HSD PJ 1606 4SPF guns. BHA: 3601.5' RIH with perf guns. Tie in to EOP flag at 5545'. Subtract l' correction. Continue in hole, Tag PBTD at 10458'. PU to put btm shot at 1 0457'. Pump 10 bbls new 150K flo vis. Circulate 0.5" ball to firing head at 1.8 bpm at 2900 psi. Up wt 22K3. Ball on seat at 38.6 bbls. Guns fired at 3200 psi. Attempt to POOH. Guns stuck. Pull up to 62K#. Unable to move. ,.. Work pipe to 62K#. 80% tensile on 1" CSH is 41 K#. With coil up wt of 22K#, we are close to 80% on CSH. Attempt to inject. Pressure well to 1750 psi. Very slow inj rate (est 0.1-0.2 bpm). Bleed off. Continue to work pipe every 30 minutes while waiting on crude. Pump 20 bbl dead crude. Lay in 15 bbls. Shut in well and bullhead 4 bbls past perf guns. Pump into perfs, 0.5 bpm at 1800 psi. Work pipe to 61 K up and -8K down. No movement. Pump 30 bbl FloPro I friction reducer pill with 3% Lubetex and 3% Flolube. Circ. out 15 bbls. Shut in well and inject 10 bbls to perfs, 0.5 bpm at 1650 psi. Work pipe, 61K up and -8K down. No movement. Stop pump, work pipe, no movement. Inject pill at 1.0 bpm at 1900 psi, pumped 2 bbls, saw 400 psi pump press spike and pulled free at 60K up wt. Pick up with 24.3K up wt. Full up wt. Appear to have perf guns. POOH. Saw wt drop 21 K to 19K while POOH at 8000 ft [top of liner], indicating we have all the perf guns. POOH. POOH with CT. Full up wt. Circ. out 15 bbl dead crude to tank. SAFETY MEETING. Review procedure and hazards for pulling CSH workstring. Layout 30 singles, Stand back 25 doubles of CSH. Stop at top perf gun. SAFETY MEETING. Review procedure and hazards for handling fired perf guns. Recover SWS fired 1-11/16" perf guns. Recovered all guns. Nothing unusal found. Mic'd several gun bodies and "shot swells". 1.55" gun bodies, swelled areas 1.65" to 1.70". All shots fired. Rig down floor from perf job. Printed: 12/26/2001 8:57:12 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/17/2001 12/18/2001 f ( BP EXPLORATION Operations Summary Report 05-12 05-128 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Phase 09:30 - 09:45 From - To Hours Activity Code NPT COMP 09:45 - 10:30 10:30 - 13:30 13:30 - 15:00 15:00 - 17:00 17:00 - 20:00 20:00 - 23:00 23:00 - 00:00 00:00 - 02:00 02:00 - 03:00 0.25 PERF P 0.75 PERF P 3.00 PERF P 1.50 RUNCO~P 2.00 DHEQP P 3.00 RIGD N 3.00 RIGD P 1.00 RIGD 2.00 RIGD 1.00 RIGD p P P COMP COMP COMP COMP SFAL COMP COMP COMP COMP COMP Start: 12/6/2001 Rig Release: Rig Number: Page 10 of 10 Spud Date: 12/8/2001 End: 12/19/2001 Description of Operations Pump 2 bbls KCL into well to check injection rate. 1.0 bpm at 1800 psi. RIH with CSH. POOH laying down CSH. RIH to 2200'. POOH and FP well with 50/50 meoh. FP top 100' with 100% meoh. Test new Schlumgerger 2.125" disconnect, circ sub, and checks at surface. 50K# pull test good. PT to 4950 psi good. Circ sub with 2 screws sheared at 1200 psi (should have been 3200 psi). Hyd dis with 4 screws did not shear release. Reduced Hyd Disc to 3 screws and shear released at 4000 psi. SWS will continue to test and modify MHA as needed. Prep to blow down reel with nitrogen. Trouble getting N2 pumper cooled down and primed. Charge pump was worn out. Press test line. Pump N2. 15 min. at 1000 scfpm. Bleed down CT. Clean rig pits. NID hardline to tank. NID BOPE. NID BOPE. Move injector head and gooseneck. NIU tree cap and Pressure test with 4000 psi. RELEASED RIG AT 0300 HRS, 12/18/2001. TOTAL TIME ON WELL WAS 11 DAYS, 0.5 HOURS. Printed: 12/26/2001 8:57:12 AM ( (' Well: Field: API: Permit: 05-12B Prudhoe Bay Field / Prudhoe Bay Pool 50-029-20244-02 201-180 Rig Accept: Rig Spud: Rig Release: D ri iii n 9..£!!9 : 12/07/01 12/10/01 12/18/01 Nordic 1 " , ,:,'; )" >:"" ,,' ,,"',""; PRE- RIG WORK 10/11/01 DRIFT TO TOP OF RCP @ 8163' SLM WI 3-3/8 D-GUN, RAN PDS CALLIPER FROM 8153' SLM TO SURFACE. DRIFTED TO 9317' SLM WI 2,625" X 2' DRIFT. STOPPED DUE TO DEVIATION. RDMO. 10/18/01 & 10/19/01 DRIFTED TUBING INTO LINER TO 8930' SLM WITH WEATHERFORD DUMMY WHIPSTOCK - 26' LONG, 2.5" MAX OD -(NOTE: SEVERE DOG LEG IN THIS AREA - DMY DRIFT STICKING & HAD TO JAR FREE) RDMO. DRIFTED TUBING INTO LINER TO 8928' SLM WITH WEATHERFORD DUMMY WHIPSTOCK - 12' LONG, 2.5" MAX OD - BAD DOGLEG AT THIS POINT IN LINER, VERY STICKY, HAD TO JAR FREE. NO CLEAR MARKS ON DMY WHIPSTOCK TO INDICATE IT WAS HANGING UP ON LOW SIDE, HIGH SIDE OR IN MIDDLE. RDMO. 11/20/01 SET BAKER CIBP @ 8950 FT (TOP OF PLUG). TAGGED TOP TO CONFIRM SET AND LOG OFF. 11/23/01 SET WHIPSTOCK AT 8906 FT (TOP OF WHIPSTOCK) WS SET @ 146 DEG L. STOP CCL AT 8880 FT (CCL TO TOP OF WHIPSTOCK: 26 FT). RA PIP TAG ON WHIPSTOCK AT 8910.5 FT (RIH WITH HEAD/SWIVEUKOS/SAFE HEAD/BAKER 5-05fT1W WEIGHTSfTlW WHIPSTOCK. TL: 42.4 FT. TW: 250 LBS.MOD: 2.5", FLUID LEVEL 7500 FT. TAG PLUG AT 8950 FT 12/02/01 TIO = 470/550/0, BLED TBG,IA, AND OA TO 0 PSI. TUBING FL @ 7450',IA FL NEAR SURFACE. 12/04101 LOAD TUBING WITH180 BBLS 60/40 MEOH POST - RIG WORK 12/26/01 MIRU DS CTU #3. WELL SI ON ARRIVAL, PUT WELL IN TEST. RIH W/1.75" JS NOZZLE & SLIM ASSEMBLY. MAKE STOPS AT 2500',3500',4000', & 6000' WHILE PUMPING A TOTAL OF 2600 GAL OF N2 AT 750 SCFIMIN, WELL SLOWLY COMING ON - COME OFFLINE W/N2 TO SEE IF WELL IS STABLE. MONITOR WELL FOR 2 HRS, WELL SLOWLY WARMING UP, FLOWING AT 545 PSIG WHP (61 DEG F). POOH FROM 6000' WHILE PUMPING N2. RD DS CTU #3, 0"-", : bp (' BP Amoco Baker Hughes INTEQ Survey Report ( M... BAKD HUGIll S -----~._---_.._-- INTEQ Compaay: BP Amoco FIeld: Prudhoe Bay Site: PB os 05 WeD: 05-12 Wellpatll: 05-12B Date: 11312002 TIme: 11:15:27 Page: 1 Co-ordlaate(NE) Refereace: Well: 05-12, True North Vertical (lVD) Refere.ce: 25: 125/1211977 00:00 69.0 Secöoa (VS) Refereace: Well (0.OON,O.OOE,145.00Azi) Sarvey Cak.laöoa Metltod: Minimum Curvature Db: Oracle Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 PB DS 05 TR-11-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5947204.70 ft 697428.91 ft Latitude: 70 15 35.696 N Longitude: 148 24 14.424 W North Reference: True Grid Convergence: 1.50 deg 5949063.85 ft 697203.63 ft Latitude: Longitude: 12 70 15 54.034 N 148 24 19.560 W Well: 05-12 05-12 Well Position: +N/-S 1864.52 ft Northing: +EI-W -176.47 ft Eastlng: Position Uncertainty: 0.00 ft Slot Name: Survey: MWD Drilled From: 05-12 Tle-on Depth: 8906.00 ft Height 69.00 ft Above System Datum: Mean Sea Level Declination: 26.63 deg Mag DIp Angle: 80.81 deg +N/-S +EI-W DIrection ft ft deg 0.00 0.00 145.00 Start Date: 12/14/2001 Engineer: Tied-to: From: Definitive Path Wellpath: 05-12B 500292024402 Current Datum: 25: 125/12/1977 00:00 Magnetic Data: 11/27/2001 Field Strength: 57512 nT Vertical Section: Depth From (TVD) ft 0.00 Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard Annotation MD ft 8906.00 10482.00 TVD ft 8618.80 8920.10 ." KOP TD Survey MD Inel Azlm TVD SSTVD N/S EIW MapN MapE DLS VS ft deg deg ft ft ft ft ft ft deg/100ft ft 8906.00 18.39 324.17 8618.80 8549.80 957.45 -1071.22 5949992.86 696107.76 0.00 -1398.73 8942.02 14.15 308.00 8653.39 8584.39 964.77 -1078.03 5950000.00 696100.77 17.12 -1408.63 8973.42 8.96 244.60 8684.25 8615.25 966.09 -1083.28 5950001.18 696095.48 40.99 -1412.72 9005.37 13.80 186.59 8715.65 8646.65 961.22 -1085.98 5949996.25 696092.91 36.85 -1410.28 9034.92 18.28 152.49 8744.11 8675.11 953.59 -1084.23 5949988.66 696094.85 34.64 -1403,03 9077.42 20.39 118.74 8784.33 8715.33 944.09 -1074.63 5949979.42 696104.70 26.39 -1389.74 9104.52 26.81 119.44 8809.15 8740.15 938.81 -1065.16 5949974.39 696114.31 23.71 -1379.98 9145.62 37.62 127.18 8843.89 8774.89 926.63 -1047.03 5949962.69 696132.75 28.11 -1359.61 9177.07 45.70 134.21 8867.38 8798.38 912.95 -1031.29 5949949.43 696148.85 29.65 -1339.37 9199.13 49.39 141.24 8882.28 8813.28 900.91 -1020.37 5949937.67 696160.07 28.84 -1323.24 9234.53 57.48 146.86 8903.36 8834.36 877 .88 -1003.77 5949915.09 696177.28 26.16 -1294.86 9264.58 66.53 148.27 8917.45 8848.45 855.50 -989.56 5949893.10 696192.06 30.40 -1268.38 9305.88 80.86 155.30 8929.03 8860.03 820.65 -970.96 5949858.74 696211.57 38.33 -1229.16 9337.83 92.29 158.11 8930.93 8861.93 791.41 -958.38 5949829.84 696224,91 36.83 -1197.98 9375.18 97.65 172.18 8927.68 8858.68 755.55 -948.85 5949794.25 696235.38 40.17 -1163.15 9414.53 94.48 168.66 8923.52 8854.52 716.98 -942.33 5949755.86 696242.90 12.00 -1127.81 9457.40 93.08 162.28 8920.70 8851.70 675.59 -931.60 5949714.77 696254.71 15.20 -1087.76 9499.95 89.91 158.11 8919.58 8850.58 635.59 -917.20 5949675.16 696270.16 12.31 -1046.72 ..,,-~ . .... ¡"In, . .... l.. t..; ........r- ~t DP Amoco Baker Hughes INTEQ Survey Report R.8 IIAJCD( HUGIll S "--.. -------..-.,--. INTEQ Compaay: BP Amoco FIeld: Prudhoe Bay Site: PB OS 05 WeD: 05-12 Wellpatit: 05-128 Date: 11312002 TIme: 11 : 15:27 Page: 1 Co-ordia.te(NE) Refereace: Well: 05-12, True North Vertkal (1VD) Refereace: 25: 12 5I12119n 00:00 69.0 Sectloa (VS) Refereace: Well (O.OON,O.ooE. 145,ooAzi) Sarvey Calcalaüoa Metlaod: Minimum Curvature Db: Oracle Survey MD lad AzIm TV» SS TV» NIS E/W MapN MapE DLS VS ft deg deg ft ft ft ft ft ft degl1 00ft ft 9537.98 88.77 152.84 8920.02 8851.02 601.00 -901.42 5949641.00 696286.84 14.18 -1009.34 9571.38 89.30 147.92 8920.59 8851.59 571.98 -884.92 5949612.43 696304.09 14.81 -976.11 9609.51 89.38 143.35 8921.03 8852.03 540.52 -863.40 5949581.54 696326.42 11.99 -937.99 9640.81 87.80 139.83 8921.80 8852.80 516.00 -843.96 5949557.54 696346.49 12.32 -906.76 9702.48 87.98 129.64 8924.07 8855.07 472.68 -800.24 5949515.39 696391.33 16.51 -846.20 9753.08 89.56 124.36 8925.16 8856.16 442.25 -759.86 5949486.02 696432.50 10.89 -798.11 9762.96 92.61 122.61 8924.54 8855.54 425.76 -734.93 5949470.19 696457.65 12.34 -770.30 9614.13 92.55 125.42 6923.06 8854.08 408.36 -709.14 5949453.47 696484.08 9.05 -741.25 9845.51 92.72 129.29 8921.64 8852.64 369.34 -684.23 5949435.11 696509.48 12.33 -711.39 9879.26 96.06 134.91 6919.05 8650.05 366.76 -659.26 5949413.22 696535.03 19.32 -676.58 9918.34 99.93 140.54 6913.62 8844.62 336.18 -633.24 5949365.31 696561.78 17.37 -640.24 9959.64 95.36 142.65 8906.13 6639.13 306.12 -607.83 5949353.92 696588.03 12.17 -599.39 9997.29 91.65 144.40 6905.76 8836.76 275.91 -565.50 5949324.31 696611.15 10.41 -561 .84 10027.67 69.21 146.51 6905.46 8836.46 250.89 -568.27 5949299.75 696629.02 11.12 -531.46 10057.27 90.35 149.66 8905.59 6836.59 225.76 -552.63 5949275.05 696645.31 11.36 -501.91 10100.79 92.37 160.22 6904.55 6635.55 186.41 -534.23 5949236.19 696664.73 24.65 -459.12 10130.32 90.00 158.11 6903.94 8634.94 156.62 -523.73 5949206.89 696675.95 10.74 -430.50 10161.94 63.67 154.25 6905.69 8636.69 129.95 -511.00 5949160.37 696689.44 23.43 -399.55 10195.17 84.02 146.62 6909.26 6840.26 100.95 -495.20 5949151.79 696705.98 16.88 -366.73 10232.24 69.56 147.92 6911.33 8642.33 69.48 -475.75 5949120.64 696726.26 15.06 -329.79 10271.10 91.65 153.19 6910.65 8641.85 35.66 -456.65 5949087.53 696746.23 14.76 -291.13 10295.22 90.70 150.73 6910.32 8641.32 14.36 -445.32 5949066.56 696758.12 11.26 -267.20 10322.15 90.62 146.27 8910.00 6841.00 -6.62 -431.65 5949043.72 696772.39 9.14 -240.36 10353.14 88.66 142.65 6910.15 6841.15 -34.34 -414.09 5949018.66 696790.61 19.00 -209.36 10391.17 66.57 140.16 6911.66 6642.66 -64.04 -390.39 5948969.61 696815.07 6.85 -171.46 10435.02 64.02 134.56 6915.26 8646.26 -96.18 -360.81 5946958.26 696645.48 14.03 -128.17 10454.52 64.11 129.99 6917.28 6646.28 -109.22 -346.47 5948945.60 696860.17 23.31 -109.25 10482.00 64.11 129.99 8920.10 8651.10 -126.79 -325.52 5948928.58 696681.56 0.00 -82.85 WELLPATH DETAILS Ref. 145.00" 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Centre: 05,12, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Slot, 12 (O.OON,O.OOE) Measured Depth Reference: 25: 12511211977 00:00 69.00 Calculation Method: Minimum Curvature ANNOTATIONS TVD MD Aooot"'= B549BO 690600 KOP BB51 10 1048200 TO lEGEND Wellpath: (05'12105-128) Date 11312002 1200: :' I " : , , . .. ,, ' , , , .. 1100 : . " , ..: ,.. , , -\ ' " 1000 : ' .. ,: ~ ' , I ' 900 , ' , , I : . : i ' : : ' " , , N , , [ , " I ! ,[ , " , I " I' , \ ,,\1 I . I.'" 'II ,, ' , 600 .." '\' :" " ,: '. : ., ~ ' ..... , . . ~ N ~ ,",': I. ;... , " .. = 400 , " : " " "'- :' : ,I .: " , ' 300 \ " : ,,' , ,:' I : : ' : \ '\ V I 100 1.- .... , I,. " 1\ "ì" .: .. j ~ " ,.. '.. ~ ' :" " 0 ,..~ ' 1 Iv , ; :" '<. -200 -.. -- ,,' , I " ,I : I I ,: i i .~ : I -~ wv , ,.' , I ' , , , , , ' I,: 0, on 0, ,M <nnn <aM M M «M UM <OM <OM ,n ;~M '900-80~' ,/ 00 -800 -¡ 00 -400 ,3)0 ,¡ 00 ,100 '6 100 200 300 4 10 500 01/24/02 Scblumbepger NO. 1742 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Sherrie Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Wee pie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay -~~ Well Job # Log Description Date Blueline Sepia Color Prints CD D,S, 1-31 , 'l'1,,- I -::z... ~ PRODUCTION PROFILE 01/07/02 1 1 NK-22A ~ t~-)- .:\3"""çJ STATIC PRESSUREITEMP 01/09/02 1 1 W-o2A qD 1-,,:)/4 22005 MCNL 12/19/01 1 1 1 D.S.4-31 I ~S-OÎLI 22016 RST-SIGMA 12/11/01 1 1 1 D,S. 5-12B.-JOJ -/7L) 22017 MCNL 12/16/01 1 1 1 D.S.11-16 ,~ ~- 079 22020 RST-SIGMA 12/23/01 1 1 1 D.S.11-18 / ?rio - II d 22022 RST-SIGMA 12/26/01 1 1 1 .~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnlcal Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage. AK 99503-5711 ATTN: Sherrie Recelved~ ~pf) Date Delivered: JAN 2 5 2002 ÞBãOiJIGiSCons. ConInission Anchorage ( ~ilÄ11fŒ (ID~ 1Ä1~~~[K\~ ~ ~. I ALAS IiA. 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 November 16,2001 Alister Sherwood Drilling Engineer BP Exploration (Alaska) Inc, P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Unit DS 05-12B BP Exploration (Alaska) Inc. Permit No: 201-180 Sur Loc: 2897' NSL, 5143' WEL, SEC. 32, TIIN, RISE, UM Btmhole Loc. 2917' NSL, 999' WEL, SEC 31, TI1N, RISE, UM Dear Mr. Sherwood: Enclosed is the approved revised application for permit to re-drill the above referenced well. The revision is for a change in bottom hole location. The provisions of the original approved permit dated September 21, 200 I are in effect for this reVISIOn, Sincerely, ~ ' ~L.,~ Cammy echsli Taylor Chair BY ORDER OF THE COMMISSION Dated this 16th of November, 2001 jjc/Enclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. STATE OF ALASKA ,NO GAS CONSERVATION COMMIS( PERMIT TO DRILL 20 AAC 25.005 ALASKA O{ 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface . 2897' NSL, 5143' WEL, SEC. 32, T11N, R15E, UM V At top of productive interval 4023' NSL, 992' WEL, SEC. 31, T11 N, R15E, UM ./ At total depth 2917' NSL, 209' WEL, SEC. 31, T11 N, R15E, UM 1 b. Type of well - - 12. Distance to nearest property line 13. Distance to nearest well ADL 028329,2917' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 8925' MD Maximum Hole Angle 18. Casin9 Program Specifications Size Casina Weiaht Grade CouDlina Lenath 2-3/8" 4.7# L-80 STL 2250' Hole 3" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 1 0725 feet 8813 feet 10200 feet 8847 feet Length Size 112' 2720' 8950' 20" 13-3/8" 9-5/8" ,N fill{i-5 ~ \\ I 0\ \ \ pb REVISED: 11/01/01 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool RKB = 69' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028326 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 05-12B 9. Approximate spud date 11/26/01 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10500' MD / 8862' TVDss 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 0 93 Maximum surface 2236 psig, At total depth (TVD) 8800' / 3300 psig Setting Depth TOD Bottom MD TVD MD TVD 8250' 7929' 1 0500' 8862' 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 Ouantitv of Cement (include staae data) 49 sx Class 'G' Plugs (measured) clap at 10020' (09/00) Junk (measured) Cemented MD TVD 224 sx Arcticset 6100 sx Permafrost II 966 sx Class 'G', 275 sx PF II 112' 2720' 8950' 112' 2720' 8660' 2365' 3-1/2" x 3-3116" x 2-7/8" 31 Bbls 15.8 ppg LARC 8223' - 10588' 7973' - 8822' RECEIVED Perforation depth: measured 9398' - 9900', 10098' - 10156' true vertical 8910' - 8871', 8858' - 8851' NOV 0 1 2001 Alaska Oil & Gas Cons. Commission .. II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Alistair Sherwood. 564-4378 Prepared By Name/Number: Terrie Hubble. 564-4628 21. I hereby certify that the fore ~9i,1 ing ~:,' tr~i¡(n~. correctlo the best of my kn~~ledge . I' I' I ~d Signed Alistair Sherwood ,J I(;)jf l . .,/'l/Jt/ ¿;-JlYJ {/ ( Title CT Drilling Engineer Date r /, I u , , '" ",' "':,'~:;.:' ":r,>::':/':::>:';.';,::<::':::Cørn~,iS$:iQ;n,Us~;:Ø:nïi::::.;',,::,::,:::,:::::, ;,' :;,:'",,:,::', : :'1","" " ' , Permit Number API Number Apprc;>vpl D~te See cover letter 201-180 50- 029-20244-02 I//It/Ill / for other reauirements Conditions of Approval: Samples Required 0 Ves BI No Mud Log Réquired 0 Ves ~No Hydrogen Sulfide Measures rg(Ves 0 No Directional Survey Required rgrVes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K '~3.5K psi for CTU 20. Attachments Other:o .. I S. d B ngma Igne y Approved By - n' ,. Form 10-401 Rev. 12-01-85 a RIG I N A L Commissioner by order of the commission Date (/ ;//~/ tJ / Submit }f¡ Triplicate f (' 5-12B Permit to Drill Revision Request The AOGCC approved Permit #201-180 for the drilling of sidetrack 5-12B on the 21 Sept 2001, Re-approval is being requested because a revised directional drilling plan moves the TD >500' away, Revision was necessary because of our inability to set a bridge plug and whipstock in the 3-3/16" liner at 9200' and 9160' respectively. Tortuosity in the 3-3/16" liner at 8960', the KOP of the 1 st sidetrack is the problem, New setting depths of 8950' and 8925' have been identified, The 8925' exit forces a riskier 2 string, (3-3/16" & 9-5/8") window milling procedure. It does however bring a more attractive reservoir target into range. Technical documentation including the directional plan have since been amended for the new target. Alistair Sherwood 10/3101 ( BPX 5-12B Sidetrack ( Summary of Operations: A CTD sidetrack of well 5-12B will be drilled, Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. Phase 1: Isolate & integrity test inner annulus, (IA). Drift tubing and liner. Set a mechanical plug below the whipstock setting depth, followed by a mechanical whipstock. Mill the window with service coil, if available. Planned for November 5, 2001 . Drift well and tag as deep as possible with slickline. . Liquid pack and integrity test the IA. . Set a mechanical plug in the 3-3/16" liner at 8950' MD (8592' TVDss). . Set a mechanical whipstock in the 3-3/16" liner at 8925' MD (8568' TVDss), Phase 2: Drill and Complete CTD sidetrack: Planned for November 26, 2001 2" coil will be used to drill a -1,575 ft, 3" open hole sidetrack, (as per attached plan) from a window cut through 3-3/16" and 9-5/8" casing. The sidetrack will be completed with 2250 ft of solid, cemented & perforated 2-3/8" liner. Mud Program: . Phase 1: Seawater . Phase 2: Seawater and Flo-Pro (8.5 ppg) Disposal: . No annular injection on this well. . 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: . 2-3/8", l-80, solid liner will be run from 8,250'md (Tal, 7,929' TVDss) to TD at approximately 10,500' md. Liner will be cemented with approximately 10 bbls (annular volume plus 25% excess in OH) of 15.8 ppg class G cement. Well Control: . BOP diagram is attached. . Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3,500 psi. . The annular preventer will be tested to 400 psi and 2,200 psi. Directional . See attached directional plan, . 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 the open hole section. . A memory GR/CNUCCl will be run inside the liner. Hazards . A recent H2S concentration for 5-12A is not available. However, there are currently no wells on Pad 5 that are producing with H2S concentrations in excess of 100 ppm. . The well path will cross one mapped fault. This fault, with an estimated 10 feet of throw, will be located near the heel of the well and is not expected to cause severe fluid losses. Reservoir Pressure Reservoir pressure is estimated to be 3,300 psi at 8,800ss. Maximum surface pressure with gas (0.12 psi/ft) to surface is 2,236 psi. TREE = , FMC GEN1 W8..LHEA D= FMC ACTUATOR= AX8..S0N KB. 8..EV = 69' BF. 8..EV = KOP= 5050' Max Angle = 99 @ 9822' Datum MD = 9513' Datum 1VD= 8800' { 05-128 PKOPOSED CTD SIDETRACK 8 2159' 8436' 13-3/8" CSG, 72#, N-80, ID = 12.347" 1 2720' 8250' 8200' 8223' I TOPOF 3-1/2" LNR l-i 8223' 8294' Minimum 10 = 2.375" @ 9732' BAKER X-OYER 8356' 8386' 8390' 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" 8390' 5-1/2" TBG, 17#, N-80, .0232 bpf, ID = 4.892" 1-1 8447' 8447' 8507' ÆRFORATION SUMMARY REF LOG: MEM CNL 03/02/99 ANGLEATTOPÆRF: 89 @ 9393 Note: Refer to Production DB for historical perf data 8564' SIZE SPF INTERV A L Opn/Sqz DATE 2-1/8' 4 9398-9900 0 01/19/99 2-1/8' 4 10098-10156 C 01/19/99 1 9-5/8" CSG, 47#, N-80, ID = 8.681" 1 I TD 1 9358' 9368' 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.8" 1 9733' I 3-3/16" x 2-7/8" XO, ID=2.375" 1 9733' 8950' ( ---i 5-1/2" CAMCO BALO SSSV NIPPLE. ID = 4.625" l-i Top of Proposed 2-3/8" Liner 1 4-1/2" BAKER TIE BACK SLV. ID = 4.00" 1 5-1/2" CAMCO DB-1 SLIDING SLV ID = 4.500" (BEHIND TBG) --i 5-1/2" CAMCO DB - NIPPLE, 10 = 4.313" I -1 5-1/2" BAKERSBRASSY I 3-1/2" X 3-3/16" XO, FLUTED SUB NO GO AND XO -1 9-5/8" X 5-1/2" BAKER SAB PKR, ID = 4.000" 1 -i 5-1/2" X 4-1/2" XO, (BEHIND LNR) 1 4-1/2" CAMCO DB-6 NIP, ID = 3.843" (BEHIND LNR) -i 4-1/2" TUBING TAIL(BEHIND LNR) I ELM TTAIL - NOT LOGGED I 1-1 9-5/8" WINDOW 8950'-8957' 2-3/8" L-80 liner entad & perfed -10500 """"""""'."" 1'1'11""""""""""""""""'11 rllil Mill Window off Mech Whipstock 110163'1-1 FISH 1 10725' --L!E] 2-7/8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.441" I DATE REV BY COMMENTS DATE REV BY COMMENTS 1998' ORIGINAL COMPLETION 07/05/01 pcr 05-12B Proposed ST 03/04/99 SIDETRACK COMPLETION 11/06/00 SIS-SL T CONVERTED TO CANVAS 01/05/01 SIS-LG REVISION 04/19/01 RN/TP CORRECTIONS 10588' PRUDHOE BA Y UNIT W8..L: 05-12B Proposed ÆRMIT No: API No: 50-029-20244-02 SEC 31 ,TIIN,R15E 1613.31 FEL 5 FNL BP Exploration (Alaska) . ' . TREE = , FMC GEN1 W8.LHEAD= FMC ACTUð. TOR= AXELSON KB. a.ev = 69' BE a.ev = KOP= 5050' Max Ange = 99 @ 982Z Datum MD = 9513' DatumlVD= 8800' 05-12A 13-3/8" CSG. 72#. No80. ID = 12.347" 2no' TOP OF 3-1/2" LNR 8223' Minimum 10 = 2.375" @ 97321 BAKERX-OVER 3-1/2" LNR, 9.3#, L-80. .0087 bpf, D = 2.992" TOP OF 3-3/16" LNR 8390' 8390' 5-1IZ' TBG, 17#. N-80, .0232 bpf, ID = 4.892" lOP OF 4-1/2" TBG 8447' 8447' FERFORA TON SUMv1ARY Ra: LOO: M8'v1 Q\JL 03,{)2199 ANGLE AT TOP PERF: 89 @ 9393 Note: FËfer to Production DB for historical perf data SIZE SPF INTffiV AL Opn/Sqz DA. lE 2-1/8' 4 9398-9900 0 01/19199 2-1/8' 4 1 0098-1 0156 C 01/19199 9358' 9368' 3-3/16" LNR, 6.2#. L-80. .0076 bpf, 10 = 2.8" TOP OF 2- 7/8" LI\R - .. 2159' f , j 1 SAFETY NOTES: I 9733' 8200' 8223' 8294' 8356' 8386' 8390' 843õ 8447' 8507 8564 ' 8950' 5-112" CAtvCO BALO SSSV NPA...E,ID = 4.625" 5-112" M)[)FIEÐ RCP,ID = 2.690" 4-112" BAKERTIEBAO< SLV, 10 = 4.00" 5-1/Z' CAMoo 00-1 SLlDIN3 SLV ID = 4.500" (BEHND TBG) 5-112" CA tvCo DB - I\IPPLE, D = 4.313" 5-112" BAKERSBRASSY 3-112" X 3-311 f;' XO, FL urED SLE f\O GOANDXO 9-5/8" X 5-112" BAKERSAB PKR,ID =4.000" 5-112" X 4-1/2" XO, (BEHND LNR) 4-lIZ' CAMoo 00-6 NIP, ID = 3.843" (BEHND LNR) 4-112" TIJBNGTAl(BEHIt'Ð LNR) ELMTTAIL- f\OTLOOGED TOPOFWIt'ÐON 9-5/8" MILLOUT WIN DOW 8950' - 8957' 9733' 3-3/16" X 3-lIZ' XO, ID = 2.375" 10020' OBP SET 9/30/00 10163' 10725' 2- 7/8" LNR, 6.5#. L-80. .0058 bpf, ID = 2.441" DAlE REV BY COMrÆNTS DATE REV BY 00 Mv1 ENT S 1998' ORIGINAL ootvPlETlON 03104199 SlDErRACK COMPlETION 11106100 SIS-SL T oof\WERTEDTO CANVAS 01/0&01 SIS-lG REV Eì ION 04119/01 RNITP ooRRECTIONS PRUDI-OE BAY LNrr WELL: 05-12A PffiMT N:>: 98-260 AA No: 50-029-20244-01 SEC31,TIIN,R15E1613.31 Fa. 5Ff\L BP exploration (Alaska) BP Amoco WELLPATH DETAILS PIa- 05-12B 500212024402 Par..t W.II......, TIe .. 1010, RlS' Ref. Dato"" 05-12 "25.00 25 :12 5/12/1877 00.00 ".ODft v.s.ctIo. ""S,. 145.00' ~1t; Dñøl. +Ef..W 0.00 ::::"fu 0.00 0,00 i . ¡ i Co-ordmate (NÆ) Reference: Well Centre: 05-12, True North ! I Vertical (TVD) Reference: System: Mean Sea level ¡ , Section (VS) Reference: Slot - 12 (O,ODN,O,()()E) I I Measured Depth Reference: 25: 12 5I12119n ()():OO 69,00 I : Calculation Method: Minimum Curvature i SE<:T1ON DETAILS ! i 500 liD ... A%I TVD .""" +EI-W OLeI TF... V... T..." I I' '8900.00 '8.30 324.17 8"""" ..5... .'070,12 0,00 0,00 -'396.83 , 2 1925.00 18.30 324.17 8567,83 ,,2.3, ,1074.73 0,00 0,00 .'404.72 I I 3 1035.00 I.,.' 320." 8577,30 ..4.70 ,ID7...7 20,00 210,00 ,'407.73 I 4 8..0.00 .... 288...7 8"',15 070.7. .1.....' 24.00 210,00 .1417,88 ! : =:::: :".:: '~m :w.:~ ~;:g -~;;:~~ ~~~ r~::::: '~: ¡ i ~ :=:::: :::~ :~~ :~~: i~~ :m~ :::: ~ ::;s. I ! . '0""00 02.74 '28'" 1162.33 ,8." -345.18 '4.00 275,00 ,..4... I . j I j REFERENCE INFORMATION ANNOTATIONS TARGETIJETMS N~. lVD _.s 'E!-W S- ::;t:~WF'" ..J.g:¡ '¡g¡~ -~i~ ~~ 05-128""'-2 S8T0.00 «1... = Pon 05-128""'-3 887000... -358.63 P",," TVD liD ""....tIo. 1544.11 1100.00 TIP 8517.83 ..25.00 KOP 8577.3& ..35.00 1 1131.15 "80.00 2 1117.34 '315.00 3 1171.51 '740.00 4 1170.71 10040.00 5 1111.11 10215.00 1 1..2.33 10500.00 TO 83oo 8350- 84oo _8450 C . æ 85oo 0 II) 8550 . - . I I I I ! I i I , I i i I I I I I I I I I I I I I I .c .. 86oo a. G» ... Q 8650; - . fa :: U 87oo . .- .. t:: ..... G» 8750m~; > .: G» 88oo 2 I- 8850 ., ..- 89oo 8950... 9000- 9050, . -1650-1600-1550-1500-1450-1400-1350-1300-1250-1200-1150-1100-1050-1000 -950 -900 -850 -800 -750 -700 -650 -6oo -550 -500 -450 -400 -350 -300 -250 -200 -150 -100 Vertical Section at 145.00. [50ft/in] ---10/25/2001 -10~1 AM O:l';(,\. (\107) 267-(;(,13 E.maiL t.rij.potniseq)!nlcQ rom B:ikcrHughes IrHEO. i90ïì 2(37-(,-)0 ----~ -- T l\M !' I Plan: Plan 118 (05-12/PlanIl8 05.12B) lEGEND - 05-12 (05-12) 05-12 (05-12A) 05-17 (05-17) - 05-17A (O5-17A) - 05-17B (O5-17B) P18n#8 05-12B Plan #8 Azimuths to True North Magnetic North: 26,67' Magnetic Field Strength: 57511nT Dip Angle: 80.81. Date: 1012412001 Model: BGGM2001 Created By: Bnj Polnis Dale: 10/25/2001 --- --- .. Of) Contact InfGrmalion. 1 ooO -. 1300nC' 1200,. 1100 900 ~: - C æ 800- 0 0 700 ... - - 600 + - .c 500- t:: 0 Z 400n - - . - 300- .c . .. -- :I - 0 200-' en . 'ì '\ i I~ / ~", ;' . \ . I 05-17A (O5-17Aj( \\ \. i \ \ i i ¡ \ \\ ~J.~:1lEIJJ \. -"--.', 100 o-n' -100-' -200- -300] ¡ :' ¡ 05-17 (05-17)1 < . -1800-1700-1600-1500-14oo-1300-1200-1100-1000 -900 -800 -700 -600 -500 -400 -300 -200 -100 West(-)/East(+) [100ft/in] 800 900 4oo 500 600 700 0 100 200 300 -'-- \ \ i\ !\. i\ i' ¡\ , ' i " \ ' i \ I " \ . .'.'\""'--- 0_5-17B(g5-.17B);' I i \ \ " i \ \. 1 i I 05-17A (O5-17Aj.--..J íOS:-17T0S-17il:~ -50 100 250 150 200 0 50 ObP ( BP Amoco f Baker Hughes INTEQ Planning Report .~. BAK'Ut HUGIll S .---,.,----..-------- INT EQ -- ._----- -------------------.----.---,.-- -..-----.--.-------------. -.. -----,-----,.--..-----..------,-.------....-------- --------- : Company: BP Amoco Date: 10/25/2001 Time: 10:52:37 I Field Prudhoe Bay Co-ordinate(NE) Reference: Well: 05-12, True North I S~te:: PB DS 05 Vertical (fVD) Reference: System: Mean Sea Level L ::~!~~!h: ~f~~~ 05-12B ------------~~:; J~~;;:~:1~~_~_.____;;1~~~~;~r~~_~~~~~~;b:...__~-~-~Ie .._---_J -.-- . ------------......-----.----.--.---------- ---------.--.--,--.----------------.- -----"-1 : Field: Prudhoe Bay I I North Slope i UNITED STATES : Map System:US State Plane Coordinate System 1927 Map Zone: 'I Geo Datum: NAD27 (Clarke 1866) Coordinate Sy. stem: Sys Datum: Mean Sea Level Geomagnetic Model: L______- - ---- -. - --------- -_. ---.. .... - -- --- .... -- ------ Page: 1 Alaska, Zone 4 Well Centre I BGGM2001 ----.---------- --------.-.-.- -- '-_. -,-.-J .-,--------.--.--.---..,. -..------,---- _.,-----,--- -.--------.-----..--- -.---.---------------,---- -'-"-- _._'.'-.. Site: PB DS 05 TR-11-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5947204.70 ft 697428.91 ft Latitude: 70 15 35.696 N Longitude: 148 24 14.424 W North Reference: True Grid Convergence: 1.50 deg --------- ----,.....------- -----------.--,--.. ---,- - -.----.--.--- --. - --.----.-- ----.-. -- ------ ----- .---...---_u.-. ---_.-- -.-..-, --- ---------~-- -----.,---.-- -----.---------.----------. --------'-----.- Well: 05-12 05-12 Well Position: +N/-S 1864.52 ft Northing: +E/-W -176.47 ft Easting: Position Uncertainty: 0.00 ft Slot Name: 12 5949063.85 ft 697203.63 ft Latitude: Longitude: 70 15 54.034 N 148 24 19.560 W -.-------------.---------,------.--.--,--,,- -- ----,.- .-..-.-..-... '_u.-"-' -.---. '----'----------'._-'.'--'... .'--- - -.----,.----..- -.-----------.-.-- ----_. -- -- ---.-------------.-- -- --.---- -. -- .---..- --- ---------- -.,.-.. --- ---- - - - - ,-. .-- -..-----.,- --- -- ----.- . -------- - - - -- - -._- ---- +N/-S ft 0.00 Drilled From: Tie-on Depth: 69.00 ft Above System Datum: Declination: Mag Dip Angle: +E/-W ft -_._-.------ 0.00 05-12 8925.00 ft Mean Sea Level 26.67 deg 80.81 deg Direction deg -------------,-,...- ._m'_._.- ._._._----- --....--., --.- 145.00 Wellpath: Plan#8 05-12B 500292024402 Current Datum: 25: 125/12/1977 00:00 Magnetic Data: 10/24/2001 Field Strength: 57511 nT Vertical Section: Depth From (TVD) ft 0.00 Height ,-----..-------.--------------,-..-..-------- - --....-.--- .,_.... ".-._U_--._u_..'----"--"----'- -..--------....-.---,--.-.--,-.-,-.--.--,-,------.-.....-...-.- --_.__._----,----,- -------..---.-----, -.-- -----._--- I ::~~~iP:J;~~~: ~~~=-~~===~;~::~PO~: ==r:;~::~~t~===- Targets '~- N :~-: O::riPtiO~:- Ti----::~;~~~:---J1~.c~~~~~ir~E::J~t~~g¡~~:;-] 05-128 Polygon8.1 0.00 -107.58 -431.63 5948945.01 696775.00 70 15 52.975 N 148 24 32.121 W -Polygon 1 0.00 -107.58 -431.63 5948945.01 696775.00 70 15 52.975 N 148 24 32.121 W -Polygon 2 0.00 -10.49 -319.04 5949045.01 696885.00 70 15 53.930 N 148 24 28.845 W -Polygon 3 0.00 270.48 -351.69 5949325.01 696845.00 70 15 56.694 N 148 24 29.795 W -Polygon 4 0.00 580.89 -553.63 5949630.01 696635.01 70 15 59.746 N 148 24 35.673 W -Polygon 5 0.00 802.48 -1183.07 5949835.02 696000.02 70 16 1.925 N 148 24 53.995 W -Polygon 6 0.00 447.58 -1192.38 5949480.02 696000.01 70 15 58.435 N 148 24 54.264 W -Polygon 7 0.00 355.02 -714.62 5949400.01 696480.00 70 15 57.525 N 148 24 40,358 W 8870.00 806.20 -1132.93 441.86 -592.28 5.56 -358.63 5949840.06 696050.04 70 16 1.962 N 148 24 52.535 W 05-12B T8.1 8870.00 05-12B T8.2 5949490.02 696600.02 70 15 58.379 N 70 15 54.088 N 148 24 36.798 W 05-128 T8.3 8870.00 5949060.02 696845,00 148 24 29.997 W ---.----------...- -- _n_-__"- ___n._____.-.-'.'.----------'-'-- . .-'_.0------.--- ,---,----,----_._- ._u.--'---'-----.--..----.---- -.,-..---.-----.-,---- Annotation - ---- _'n_...__....------ ------------.------ .. .. .. ..... . L.:_~~... ._~, .'L-L.~L~~__. n- _..__LL--_-,--,-~---_.. ""_~~__~':'L.~_~n___. .,. -,.. L:...L.__.... .._..:.. --.,.---...--.-. L_~._. --. ._._-_.,:__.. ..-. _..:._~----~ ,c_.- .__._--_.C_.c_-,.. c... -,----~,.:._... n~.:~_' .--..-... 8900.00 8544.11 TIP 8925.00 8567.83 KOP 8935.00 8577.36 1 8990.00 8631.15 2 9365.00 8867.34 3 9740.00 8871.51 4 10040.00 8870.79 5 10265.00 8868.18 6 .. .. . . . . . ... . . . . ... .. ........ ....... ... , -.--.,..-.-.-.-.-.----.-..,-"...-.'--""---"".'. -.....--.--,.-.,..-.--..-. --.-.-.- --,-.-----,------.-----.---.---,-.----.,-.,.--- ----'--. - -..,.------.--.--.,-.--..-.-----.-------,---.----u_--..---.----.----.---.-- ---'--.-.-.--'--'.--'----'- -.--'.'--'-'---'-----.-'---- ObP f BP Amoco { Baker Hughes INTEQ Planning Report Bíi8 BAKD. HUGHES ..,--.....--...... LNTEQ ,-- --.,----... -...-.....-..---- -.. - _..-... ""-'-- .... -"...,-'-.. --oo-----..- --- .... ....----oo-oo- - - - ---...- . -- - ----.... -- -....- - ---- ---- _... .--- -----"l I Company: BP Amoco Date: 10/25/2001 Time: 10:52:37 Page: 2 : Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 05-12, True North i I. Site: PB DS 05 Vertical (TVD) Reference: System: Mean Sea Level i Well: 05-12 Section (VS) Reference: Well (0.00N,O.00E,145.00Azi) . L_~ellpath: .._-~~-~~ O~ 12~..- ---"'----... Survey..oo~~!~~~ti.c?.n~~!..~~~~.~~ni~.~~..g~.~~~-~~~_._........__......~.~,:_......9..~~~~--_...._oo..' Annotation -- MD --'-- TVD ----.oo.-.-.---..-.----------..--,--.---------- I ,-. - - .._~_.._- ---~ ..-- -oo..--. ...--- .-......-- -...-.... -.-.. .-....- - -. - .. - ---oo ..--- -.. ......-.-. - .-- .. - -oo .-.oo-oo. - - .-- . .-.. .. ...... ...... ...- --- -.....oo oo... ....... - -........- ---.oo-..-......... - .. ... ..-. - - --.....---.. ---- -. ....--oo..-j : 1 0500.00 ~62.33_.___~D ,----.---.---------.-..-.-----,..,----------,.,-------.1 Plan Section Information . ---..- ----'-'-- _.- ..."- - - -.. --. ---..-----....- '--'--------.--"- MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/10OO deg --.-.. ... ..... -- -. -.. .......-. .- -.oo -..... - ""'" '..-.- .-.-. ..-- .......-.-- -...-..--...... . ,_. -"'...."-""- ... -.... . -........ -.' ...,....... .. ..-.. --... ...... """" """- ,....., -..... - ..... -, -.. . - -... ._-.... .... ..-.. ....... ........ .. "'-"". ... - -... ...... -- -........... ..... -. .. """'" ..... .... .......... -,..... """"" - .. .. -... - 8900.00 18.39 324.17 8544.11 955.91 -1070.12 0.00 0.00 0.00 0.00 8925.00 18.39 324.17 8567.83 962.31 -1074.73 0.00 0.00 0.00 0.00 8935.00 16.69 320.69 8577.36 964.70 -1076.57 20.00 -17.03 -34.84 210.00 8990.00 8.36 268.97 8631.15 970.76 -1085.61 24.00 -15.13 -94.03 210.00 9365.00 90.00 178.97 8867.34 731.45 -1116.05 24.00 21.77 -24.00 270.00 9740.00 89.00 88.97 8871.51 497.03 -873.11 24.00 -0.27 -24.00 269.00 10040.00 91.26 130.91 8870.79 396.99 -597.37 14.00 0.75 13.98 87.00 10265.00 90.03 162.39 8868.18 211.40 -475.25 14.00 -0.55 13.99 92.00 10500.00 92.74 129.59 8862.33 19.30 -345.68 14.00 1.15 -13.96 275.00 Survey ..---- --.----, -- ...---...---.--- - -.-- -..-. ..--..--..-- -,- ...'- r"""=---"--""""""-""-""--"-'-"'-""""C-"""----""""'-"""'-"-"'-------"-'-'-'--:--.---.-..,...-,-...,oo-...--..--....-...,...----"'------""'C-"-"----"""",.,...............oo.......-..oo.--,.......-.-oo......-.....--..,....,........--.............-.......""""-"-"""""""-, MD loel Azhn SSTVD N/S E/W MapN MapE' DLS VS TFO Tool' ft - - -deg. deg ft .' ft ftftft deg/100ft ftdeg .--..-..-...--....'-.-,..,....... """""""""'...oo"-""""""'" .-........-oo..-.'.-.'......,'..... .......-.............-.,........,-, .....---....--.........,.............-.......................-.........-.......-......,-----..,-......-....'-.....-.-oo......... ............" ..........-............. .c............._.... ........-............-...................................-..-..oo..'-....... 8900.00 18.39 324.17 8544.11 955.91 -1070.12 5949991.36 696108.91 0.00 -1396.83 0.00 TIP 8925.00 18.39 324.17 8567.83 962.31 -1074.73 5949997,63 696104.12 0.00 -1404.72 180.00 KOP 8935.00 16.69 320.69 8577.36 964.70 -1076.57 5949999.97 696102.23 19.97 -1407.73 210.02 1 8950.00 13.68 313.06 8591.84 967.58 -1079.23 5950002.78 696099.49 24.02 -1411.61 209.99 MWD 8975.00 9.62 290.75 8616.33 970.34 -1083.35 5950005.43 696095.31 24.00 -1416.24 217.36 MWD 8990.00 9000.00 9025.00 9050.00 9075.00 9100.00 9125.00 9150.00 9175.00 9200.00 9225.00 9250.00 9275.00 9300.00 9325.00 9350.00 9365.00 9375.00 9400.00 9425.00 9450.00 9475.00 9500.00 9525.00 9550.00 9575.00 9600.00 9625.00 9650.00 9675.00 9700.00 8.36 8.70 11.83 16.61 21.98 27.60 33.35 39.16 45.02 50.90 56.80 62.72 68.64 74.57 80.50 86.44 90.00 89.96 89.85 89.75 89.65 89.56 89.46 89.38 89.30 89.23 89.17 89.11 89.07 89.04 89.01 268.97 252.90 223.54 208.50 200.33 195.30 191.88 189.37 187.42 185.83 184.49 183.32 182.27 181.30 180.38 179.50 178.97 176.57 170.57 164.57 158.57 152.58 146.58 140.58 134.58 128.58 122.58 116.58 110.58 104.57 98.57 8631.15 8641.04 8665.66 8689.89 8713.48 8736.17 8757.71 8777.86 8796.41 8813.14 8827.88 8840.47 8850.76 8858.64 8864.04 8866.88 8867.34 8867.35 8867.39 8867.48 8867.61 8867.78 8867.99 8868.25 8868.53 8868.86 8869.21 8869.58 8869.98 8870.39 8870.82 970.76 970.53 968.11 963.11 955.58 945.59 933.27 918.75 902.17 883.74 863.64 842.10 819.36 795.66 771.26 746.44 731.45 721.45 696.62 672.22 648.51 625.76 604.21 584.11 565.66 549.08 534.55 522.21 512.22 504.68 499.66 -1085.61 -1087.06 -1090.63 -1094.11 -1097.44 -1100.60 -1103.55 -1106.25 -1108.68 -1110.81 -1112.62 -1114.08 -1115.18 -1115.92 -1116.27 -1116.25 -1116.05 -1115.66 -1112.86 -1107.48 -1099.58 -1089.25 -1076.60 -1061.76 -1044.91 -1026.21 -1005.89 -984.16 -961.26 -937.44 -912.97 5950005.79 5950005.52 5950003.01 5949997.92 5949990.30 5949980.24 5949967.85 5949953.25 5949936.63 5949918.14 5949898.01 5949876.44 5949853.67 5949829.96 5949805.57 5949780.75 5949765.78 5949755.80 5949731.05 5949706.80 5949683.30 5949660.83 5949639.63 5949619.92 5949601.92 5949585.84 5949571.84 5949560.08 5949550.69 5949543.77 5949539.40 696093.03 696091.59 696088.08 696084.74 696081.60 696078.71 696076.08 696073.76 696071.77 696070.12 696068.84 696067.94 696067.43 696067.32 696067.60 696068.28 696068.87 696069.53 696072.97 696078.99 696087.50 696098.43 696111.64 696127.00 696144.33 696163.45 696184.14 696206.19 696229.34 696253.35 696277.94 24.01 24.00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 23.98 24.00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 24.00 -1417.88 -1418.52 -1418.59 -1416.49 -1412.23 -1405.86 -1397.46 -1387.11 -1374.93 -1361.05 -1345.62 -1328.82 -1310.82 -1291.83 -1272.05 -1251.70 -1239.31 -1230.90 -1208.95 -1185.88 -1161.93 -1137.36 -1112.46 -1087.48 -1062.70 -1038.39 -1014.83 -992.26 -970.94 -951.10 -932.96 239.18 2 270.10 MWD 285.90 MWD 314.82 MWD 329.41 MWD 337.13 MWD 341.70 MWD 344.66 MWD 346.68 MWD 348.13 MWD 349.20 MWD 349.99 MWD 350.58 MWD 351.01 MWD 351.32 MWD 351.52 MWD 351.59 3 269.00 MWD 269.00 MWD 269.01 MWD 269.03 MWD 269.06 MWD 269.10 MWD 269.16 MWD 269,22 MWD 269.29 MWD 269.36 MWD 269.45 MWD 269.54 MWD 269.63 MWD 269.73 MWD ------ ----...-----,--------,..-.... .-.------....... ..--....,--....---.--.-...,--.... .......-.-------... ,--oo..----...--...-.--- -------'-'-.--"'---.'-""-"--- -"----'------ ....-.--.-.-- .-...------,--..--,-....------ _.-.-_.._-....,- . ObP ( BP Amoco ( Rií8 BAKD. HUGHES Baker Hughes INTEQ Planning Report ------------------- INTEQ !Com;~~y:- BP A~oco --- ----- m - ---- - -... - - ------....-.. - - - ------. ... -...- . Date: 10/25/2001 Time: 10:52:37 Page: 3 I Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 05-12, True North I Site: PB DS 05 Vertical (TVD) Reference: System: Mean Sea Level , Well: 05-12 Section (VS) Reference: Well (0.00N,0.00E,145.00Azi) L.~~~~ath~_~_~n#8 °5:!~-~-_._-_._.. Survey Calculation Method: Minimum Curvature Db: Oracle -.-- __00__.- - . - - -.....'-' ----.- ----.- -----_._- ---.-.- - -.--- ----.- ---- --- - - - -- -,-- -- --- .-. -.- ------ --....._--- - - -,.-- -- ----...--. -..- .--- -.- ---- -,-. -- -- -- - --- -..-- - - -- - 00.- -- --,- -- ,-- -... -. - -..---. - - ---" Survey r.-MD-m---.-I~cI----.---~¡-;;---SSTVn --N/S------~t\V"'----- MapN - MapE DLS VS TFO Tool l I_. ._-,_.. - ..._~-- ------ - ~~--- --.-- d e ~_._-_. -- ---- _.m_- _!! - . - -----. -- - ----..--. - --~ -. - ---'..., -,- -... _00_- ~--...- - -... ----. - -- - -- --,. -'-'- -~-_.- ._--... -- -- .---- - -- --_.~ -- -.--- - -- - -- -.- -~:_~~~~~ - -.- - ,m~- - ----- - -- ------~:~.- -- -- - --- --. -- -- -- - - j 9725.00 89.00 92.57 8871.25 497.24 -888.10 5949537.63 696302.87 24.00 -916.71 269.83 MWD 9740.00 89.00 88.97 8871.51 497.03 -873.11 5949537.81 696317.85 24.01 -907.94 269.94 4 9750.00 89.07 90.37 8871.68 497.09 -863.11 5949538.14 696327.85 14.02 -902.25 87,00 MWD 9775.00 89.26 93.87 8872.04 496.17 -838.13 5949537.87 696352.84 14.00 -887.17 86.98 MWD 9800.00 89.45 97.36 8872.33 493.72 -813.26 5949536.08 696377.77 14.00 -870.90 86.93 MWD 9825.00 89,64 100.86 8872.52 489.77 -788.58 5949532.77 696402.54 14.00 -853.50 86.89 MWD 9850.00 89.83 104.35 8872.64 484.31 -764.18 5949527.96 696427.07 14.00 -835.04 86.86 MWD 9875.00 90.03 107.85 8872.67 477.38 -740.17 5949521.66 696451.26 14.00 -815.59 86.84 MWD 9900,00 90.22 111.34 8872.62 469.00 -716.62 5949513.89 696475.02 14.00 - 795.22 86.84 MWD 9925.00 90.41 114.83 8872.48 459.20 -693.62 5949504.70 696498.26 14.00 -774.00 86.85 MWD 9950,00 90.60 118.33 8872.26 448.01 -671.27 5949494.10 696520.90 14.00 -752.02 86.86 MWD 9975.00 90.79 121.82 8871.96 435.49 -649.64 5949482.15 696542.84 14.00 - 729.35 86.90 MWD 10000.00 90.97 125.32 8871.57 421.67 -628.82 5949468.88 696564.02 14.00 -706.08 86.94 MWD 10025.00 91.16 128.82 8871.11 406.60 -608.88 5949454.34 696584.35 14.00 -682.31 86.99 MWD 10040.00 91.26 130.91 8870.79 396.99 -597.37 5949445.04 696596.10 13.97 -667.83 87.14 5 10050.00 91.21 132.31 8870.57 390.35 -589.89 5949438.60 696603.75 14.04 -658.10 91.87 MWD 10075.00 91.09 135.81 8870.07 372,97 -571,93 5949421 .69 696622.16 14.00 -633.57 92.03 MWD 10100.00 90.96 139.31 8869.63 354.53 -555.07 5949403.70 696639.50 14.00 -608.79 92.10 MWD 10125.00 90.82 142.81 8869.24 335.09 -539.36 5949384.68 696655.71 14.00 -583.85 92.16 MWD 10150.00 90.69 146.31 8868.91 314.73 -524.87 5949364.70 696670.73 14.00 -558.86 92.22 MWD 10175.00 90.55 149.80 8868.64 293.52 -511.64 5949343.85 696684.51 14.00 -533.90 92.26 MWD 10200.00 90.41 153.30 8868.43 271.54 -499.73 5949322.19 696696.99 14.00 -509.07 92.30 MWD 10225.00 90.26 156.80 8868.28 248.88 -489.19 5949299.82 696708.12 14.00 -484.46 92.33 MWD 10250.00 90.12 160.29 8868.20 225.61 -480.05 5949276.80 696717.87 14.00 -460.15 92.35 MWD 10265.00 90.03 162.39 8868.18 211.40 -475,25 5949262.72 696723.04 13.98 -445.76 92.43 6 10275.00 90.15 161.00 8868.16 201.91 -472.11 5949253.31 696726.43 13.98 -436.18 275.11 MWD 10300.00 90.46 157.51 8868.03 178.53 -463.25 5949230.18 696735.89 14.00 -411.96 275.00 MWD 10325.00 90.76 154.02 8867.76 155.74 -453.00 5949207.66 696746,74 14.00 -387.40 274.98 MWD 10350.00 91.06 150.54 8867.37 133.62 -441.37 5949185.85 696758.94 14.00 -362.61 274.94 MWD 10375.00 91.36 147.05 8866.84 112.24 -428.42 5949164.83 696772.44 14.00 -337.68 274.89 MWD 10400.00 91.65 143.56 8866.18 91.70 -414.20 5949144.66 696787.20 14.00 -312.69 274.81 MWD 10425.00 91.93 140.07 8865.40 72.06 -398.75 5949125.44 696803.15 14.00 -287.74 274.72 MWD 10450.00 92.21 136.58 8864.50 53.40 -382.14 5949107.22 696820.24 14.00 -262.93 274.61 MWD 10475.00 92.48 133.09 8863.47 35.79 -364.43 5949090.09 696838.41 14.00 -238.35 274.49 MWD 10500.00 92.74 129.59 8862.33 19.30 -345.68 5949074.09 696857.59 14.00 -214.08 274.33 TO ----- --- -.-- - -- ----- - .-- - ---- -_..--- .--- --- ---------,- -- -----.- -- ---- - -----.------- -------------------.--------- -----------.--. ------- ___00- ---- t \ 2 nCT 10,000 psi Pack-Off Lubricator Blind/Shear 7 1/16" Pipe/Slips Pipe/Slips 71/16" Pipe/~/ip!l 7 1/16" x 5,000 psi .( 'C I { ... 'd..." ... ~ ~cZ 1/ ... ~" SWAB OR MASTER VALVE !!I.I- \ ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME !1s!l. 0::;' / 2- ß ( CHECK 1 STANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) D EVELO PMENT RED RILL J PILOT HOLE (PH) EXPLORATION I ANNULAR fÞlSPOSAL (1 I ) NO V INJECTION WELL ANNULAR DISPOSAL l-> YES INJECTION WELL RED RILL ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new well bore segment of existing well . Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. ., I Annular Disposal of drilling wastes will not be approved. . . , DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS l-> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved ,subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. l it ~1f!A\1fŒ [ll~ !A\~!A\~~!A\ ALAS K& 0 IL AND GAS COlVSERVATI ON COMMISSION / TONY KNOWLES, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT, Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit 05-12B BP Exploration (Alaska) Inc, Permit No: 201-180 Sur Loc: 2897' NSL, 5143, WEL, Sec. 32, TIIN, RISE, UM Btmhole Loc. 3606' NSL, 1631' WEL, Sec. 31, TIIN, RISE, UM Dear Mr. Endacott: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made, Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit 05-12B. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole, Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~(À¿M.:~ Cammy cYechsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 21st day of September, 2001 jj c/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 " 1 a. Type of work 0 Drill 181 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2897' NSL, 5143' WEL, SEC, 32, T11N, R15E, UM At top of productive interval 4023' NSL, 992' WEL, SEC. 31, T11 N, R15E, UM At total depth 3606' NSL, 1631' WEL, SEC. 31, T11N, R15E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028308, 3368' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 9160' MD ' Maximum Hole Angle 18. Casin~ Program Specifications Size Casino Weicht Grade Couolino 2-3/8" 4.7# L-80 STL 1 b, Type of well Hole 3" Lenoth -2Qð[f ~~~O 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 1 0725 feet 8813 feet 10200 feet 8847 feet Length Size 112' 2720' 8950' 20" 13-3/8" 9-5/8" d (11(1' '-1!J() fo! k /JD 0 Exploratory 0 Stratigraphic Test 181 Development Oil 0 Service 0 Development Gas S SinglEj.,.fone 0 Multiple Zone 5. Datum Elevation (OF or KB) 1lC Field and Pool RKB = 69' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028326 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 05-12B 9. Approximate spud date 11/15/01 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10100' MD / 8874' TVDss 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 0 88 Maximum surface 2236 psig, At total depth (TVD) 8800' / 3300 psig Setting Depth Too Bottom Ouantitv of Cement MD TVD MD TVD (include staae data) 8100' 7789' I~I .BWr4' 64 sx Class 'G' , () ~Sf' ~ \..5- Â~ , 11. Type Bond (See 20 MC 25.025) Number 2S100302630-277 Plugs (measured) CIBP at 10020' (09/00) Junk (measured) Cemented MD TVD 224 sx Arcticset 6100 sx Permafrost II 966 sx Class 'G', 275 sx PF II 112' 2720' 8950' 112' 2720' 8660' 2365' 3-1/2" x 3-3/16" x 2-7/8" 31 Bbls 15.8 ppg LARC Alaska Oil & Gas cons. CommissÏ(m 'MchQrag.e III Filing Fee 0 Property Plat III BOP Sketch 0 Diverter Sketch III Drilling Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mary Endacott. 564-4388 Prepared By Name/Number: Terrie Hubb/e. 564-4628 21. I hereb~~i~ ~~t~. tor. e,go{in~i~ t~~: ~d,9orrect to the best of my knowledge ,'J; /','.' j, . Signed ~~(~aè6tt,-./ p t¿.1 it CÆ>}!i Title CT Drilling Engineer Date 7/'if () I " ",:,,"',:: .::",;)'"..::':::,:,::,!:::": ,:";:"':,i::'::;:' ,';i ;:),:,::!:';>;;:i::::/':':i::';:,,:::::::,,'ç¡miÐ~~siqn.:,USt::Qr.:ly,¡,::,',>,:/,:i;:;::,\:i:::'":O,i':,::,:/,,.,.,:"'",":;">,::":"::'::"".':,".'::,..,,...,"...;'.,'..,' Permit Number API Number App!Q.val Date See cover letter ?-D l-¡g ['\ 50- 029-20244-02 ~ 27, () ( for other reQuirements Conditions of Approval: Samples Required DYes Ø-.NO Mud Log Required DYes gNo Hydrogen Sulfide Measures .ø.res 0 No Directional Survey Required ß.Yes D No Required Working Pressure for BOPE 0 2K D 3K D 4K 0 5K 0 10K D 15K ~.5K psi for CTU Or?~~~r Signed avO R \ G \ N A L ,.. ftL .1: Commissioner Perforation depth: measured 9398' - 9900', 10098' - 10156' true vertical 8910' - 8871', 8858' - 8851' 20. Attachments Approved By Form 10-401 Rev. 12-01-85 . 8223' - 10588' \7?f~' [~B822' RECEI ft~) ~tP 07 2.001 by order of the commission Date 9.;2 / . 0 / Submit In Triplicate ( , { 8PX 5-128 Sidetrack Summary of Operations: A CTD sidetrack of well 5-12B will be drilled. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below, Phase 1: Isolate & integrity test inner annulus, (IA). Drift tubing and liner. Set a mechanical plug below the whipstock setting depth, followed by a mechanical whipstock. Mill the window with service coil, if available. Planned for November 10, 2001 . Drift well and tag as deep as possible with slickline. . Liquid pack and integrity test the IA. . Set a mechanical plug in the 3-3/16" liner at 9200' MD (8782' TVDss). . Set a mechanical whipstock in the 3-3/16" liner at 9160' MD (8759' TVDss). . Mill window with seNice coil if available. Phase 2: Drill and Complete CTD sidetrack: Planned for November 15, 2001 2" coil will be used to drill a -1,670 foot, 3" open hole sidetrack, (as per attached plan) and run a solid, cemented & perforated 2-3/8" liner completion. Mud Program: . Phase 1: Seawater . Phase 2: Seawater and Flo-Pro (8.5 ppg) Disposal: . No annular injection on this well. . 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: . 2-3/8", L-80, solid liner will be run from 8,100'md (Tal, 7,789' TVDss) to TD at approximately 10,830'md. Liner will be cemented with approximately 13 bbls (annular volume plus 25% excess in OH) of 15.8 ppg class G cement. Well Control: . BOP diagram is attached. . Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3,500 psi. . The annular preventer will be tested to 400 psi and 2,200 psi. Directional . See attached directional plan. . Magnetic and inclination suNeys will be taken every 30 ft. No gyro will be run. Logging . An MWD Gamma Ray log will be run over the open hole section. . A memory CNL will be run inside the liner. Hazards . A recent H2S concentration for 5-12A is not available. However, there are currently no wells on Pad 5 that are producing with H2S concentrations in excess of 100 ppm. . The well path will cross one mapped fault. This fault, with an estimated 10 feet of throw, will be located near the heel of the well and is not expected to cause severe fluid losses. Reservoir Pressure ReseNoir pressure is estimated to be 3,300 psi at 8,800ss. Maximum surface pressure with gas (0.12 psi/ft) to surface is 2,236 psi. ( TREE = FMC GEN1 WB..LHEAD= FMC ACn..LA.TOR= AXELSON KB. ELEV = 69' BF. ELEV = KOP= 5050' Max Ange = 99 @ 9822' Datum MD = 9513' Datum TVD= 8800' 05-12A (I) 13-3/8" CSG, 72#, N-80, ID = 12.347" 2720' TOP OF 3-1/2" LNR 8223' II Minimum 10 = 2.375" @ 9732' BAKER X-OVER I 3-1/2" LNR, 9.3#, L-80, .0087 bpf, D = 2.992" TOP OF 3-3/16" LNR 8390' 8390' 5-1/Z' TBG, 17#, N-80, .0232 bpf, ID = 4.89Z' TOP OF 4-1/2" TBG 8447' 8447' ÆRFORA TON SUrvMARY REF LOG: M8v1 Q\JL 03102/99 ANGLE AT TOP PERF: 89@ 9393 Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz D6.1E 2-118' 4 9398-9900 0 01/19/99 2-118' 4 10098-10156 C 01/19/99 I 9-518" CSG, 47#, N-80, ID = 8.681" I I TD I 9358' 9368' 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.8" 9733' TOPOF 2-7/8" LNR 9733' I R3TD I 2159' (' I SAFErY NOTES: 5-112" CArvcO BALO SSSV t\lPRE, ID =4.625" 5-112" WOCAFIID RCP, ID =2.690" 4-112" BAKER TIE BAO< SLV, 10= 4.00" 5-1/Z' CAMCO 00-1 SLIDING SLV 10 = 4.500" (BEI-fND TBG) 5-112" CArvcODB- NIPPLE, D =4.313" 8200' 8223' 8294' 8356' 8386' 8390' 8436' 8447' 8507 8564' 8950' 5-112" BAKERSBRASSY 3-112" X 3-3116" XO, FLUTEDSLB 1\0 GOANDXO 9-5/8" X 5-112" BAKER SAB PKR, ID = 4.000" 5-112" X4-1/2"XO, (BEHNDLNR) 4-1/Z' CAMCO 00-6 NIP, ID = 3.843" (BEHND LNR) 4-112" lUBNG TAL(BEHIND LNR) EL M TIA IL - I\OT LOGGED TOP OF WINDOW 9-5/8" MILLOUTWINDOW 8950'- 8957' 9733' 3-3/16"X 3-1/Z' XO, ID= 2.375" 10020' asp SET 9/30100 10163' 10725' 2- 7/8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.441" DA1E REV BY COMrvENTS DATE REV BY COrvMENTS 1998' ORIGINAL CO~LEfION 03104199 SIDEfRACK COMPLETION 11/06100 SIS-SL T CONV ERfED TO CANVAS 01/05101 SIS-LG REV IS ION 04/1 9/01 RNrrp CORRECTIONS PRUOI-k)E BAY LNIT WELL: 05-12A PERMT tIb: 98-260 AA No: 50-029-20244-01 SEC31,TIIN,R15E1613.31 FB.. 5 FN... BP Exploration (Alaska) TREË = WELLHEAD= - -- . ACTUA TOR= KB. ELEV = ----- ______0. - 00 - -- ---- BF. ELEV = KOP = 5050' Max Angle = 99 @ 9822' -. - - - - .. Datum MD = 9513' Datum ND= 8800' 13-3/8" CSG, 72#, N-80, 10 = 12.347" I FMC GEN1 FMC AXELSON 69' 05-12 B PROPOSED CTD SIDETRACK <if) 2720' 1 TOP OF 3-1/2" LNR 1--1 8223' Minimum 10 = 2.375" @ 9732' BAKER X-OYER 3-1/2" LNR, 9.3#, L-80, .0087 bpf, 10 = 2.992" 1 I TOP OF 3-3/16" LNR I 8390' 8390' 5-1/2" TBG, 17#, N-80, .0232 bpf, 10 = 4.892" I TOP OF 4-1/2" TBG I 8447' 8447' PERFORA TION SUMMARY REF LOG: MEM CNL 03/02/99 ANGLE AT TOP PERF: 89 @ 9393 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8' 4 9398-9900 0 01/19/99 2-1/8' 4 10098-10156 C 01/19/99 2159' ( -i 5-1/2" CAMCO BALO SSSV NIPPLE, 10 = 4.625" 1-1 Top of Proposed 2-3/8" Liner 4-1/2" BAKER TIE BACK SLV, 10 = 4.00" 1 5-1/2" CAMCO DB-1 SLIDING SLV 10 = 4.500" (BB-iIND TBG) 8100' 8200' 8223' 8294' 8356' 8386' 8390' 8436' 8447' 8507' 8564' 8950' --1 5-1/2" CAMCO DB - NIPPLE, 10 = 4.313" I --1 5-1/2" BAKER SBR ASSY I 3-1/2" X 3-3/16" XO, FLUTED SUB NO GO AND XO -1 9-5/8" X 5-1/2" BAKER SAB PKR, 10 = 4.000" 1 --1 5-1/2" X 4-1/2" XO, (BB-iIND LNR) I 4-1/2" CAMCO DB-6 NIP, 10 = 3.843" (BB-iIND LNR) --1 4-1/2" TUBING TAIL(BB-iIND LNR) I 1 ELM TIAIL - NOT LOGGED I --1 TOP OF 9-5/8" WINDOW 1 I 2-3/8" L-80 LINER, Cemented & Perforated I 1 9-5/8" CSG, 47#, N-80, 10 = 8.681" I I TO 1 9358' 9368' 3-3/16" LNR, 6.2#, L-80, .0076 bpf, 10 = 2.8" I 9733' 1 TOP OF 2-7/8" LNR I 9733' 1 PBTD 1 10830' 110163'1-1 FISH I 1 0725' ~ 2-7/8" LNR, 6.5#, L-80, .0058 bpf, 10 = 2.441" 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 1998' ORIGINAL COMPLETION 04/25/01 pcr 05-12B proposed ST 03/04/99 SIDETRACK COMPLETION 11/06/00 SIS-SL T CONVERTED TO CANVAS 01/05/01 SIS-LG REVISION 04/19/01 RNlTP CORRECTIONS 10588' PRUDHOE BA Y UNIT WELL: 05-12B Proposed PERMIT No: API No: 50-029-20244-02 SEC 31,TIIN,R15E 1613.31 FEL 5 FNL BP Exploration (Alas ka) BP Amoco WELLPATH DETAILS Pia." 05-12. 500212~ h..., w..,.... TIe 011 M D: 05-12A 1180.00 IUs. Ref. Do...... V.s.ctlo. ""Ia 145.00' 25 ,12 511211177 00:00 n.oott ~~:; 0.00 :=~ e.oo ~111!: 0.00 REFERENCE INFORMATION Co-ordinate (NIE) Reference: Well Centre: 05-12, True North Vertical (NO) Reference: System: Mean Sea Level Seclion (VS) Reference: SIoI- 12 (O.ooN.O,OOE) Measured Depth Reference: 25: 125/1211977 00:00 69,00 Ca!culation Method: Minimum Curvature SECTIOH DETAILS See liD ... AzI Tn ....... +£1-11 DLoI W... vSec T_", 1 8145.78 51,2<""88 8750." '_,30 -1125.37 0.00 0.00 -"21A1 2 8180.00 52.85....88 87"'" 1080.25 -1127.78 20.24 58.20 -1531.78 3 13&8,'2 88.00 "".72 _78 '17'." -12<10.00 38.00 270.00 .'_30 < 1883.'2 88... 238." saßOt '_.07 -1582." '0.00 270.00 .1780.38 5 'Ot25.37 88.05 '17.88 8875.00 88"" -1778.85 "'00 288.00 .'575.85 8 'D578.37 88... ,..... 880'7,58 257,71 -1882.88 "'00 287.00 .,,84.58 7 'D830,oo ..... '17,'" "'5.24 31.7' -155&38 "'00 93.00 -It..., ANNOTATl0N5 TVD MD "'-- 8750.11 IfU.78 TIP 1758'" 1180.00 KOP "".78 1388.12 1 ...I.of 18Þ.12 2 8875.00 fOf28.37 3 "17.54 10578..7 " 8115.... 10UO.00 TO TARGET ŒTAiLS H.... TV[) ....s ,EPH ...... O>-'29T5.1 807500 602.73 -m... """ 05-'28T5.2ftTIJ _.00 .20<.10 .151959 """ 05-'29_' 000 "'09 .2103." """"" 83OO--.:::------~- . -- --- - - -- 840<>--=---~-- ------ 8450---.:::--- --_.~-- - C .- - = ~855O ;- ~_n--.-- - .c 8600~ ~ .. D. G) a -- __n_- -- c¡ 8700-=---:------- CJ . - :e 875O--=: G) = > 8800-=---- G) -10;::,2 (05-12A)t :I - .. 8850 ... - 8900 -- nn___'- m:- ., m 8950 [Q§,12 (O~ bp LEGEND - 05-12 (05-12) - 05-12 (05-12A) - PIan#605-12B - Planlffl T l ---- -- - -- .-0- ---.- -.- " D. B""--.. 'j .- ; . . ìTEQ , ~ ¡ , . --~ ~ ..~ -no, ~ ;;:~~~ ~~:: ; 05-12B T5.2i --- - .-- .-- ------+-; 05-12B T5.2,- -- ---- 9000-.- 1300 - 905O-..:~ - -------------- -----_.--.-. ---. .-.-- ---------~ Azimuths to True North Magnetic North: 26,72' Magnetic Field Strength: 575O8nT Dip Angle: 80,80' Date: 812912001 Model: BGGM2001 Plan: Plan #6 (05-121PIan#6 05-12B) Created By: Brij Polnis Date: 812912001 , 05-n~~.1' 1000 -- ë 800 - .- - = 0 0 ... - - + - .c 1:: 40 0 ~ 300 . - . - .c .. :I 0 U) -100 --- -300 ___n___----.- Contact Information' Direct (907) 267-6613 E.mail: brij.potnisiWinteqcom Baker Hughes INTEO: (907) 267.66öo --- ------- -2700-2600-2500-2400-2300-2200-2100-2000-1900-1800-1700-1600-1500-1400-1300-1200-1100-1000 -900 -800 -700 -600 -500 -400 -300 -200 -100 West(-)/East(+) [100ft/in] -2000-1950-1900-1850-1800-1750-1700-1650-1600-1550-1500-1450-1400-1350-1300-1250-1200-1150-1100-1050-1000 -950 -900 -850 -800 -750 -700 -650 -600 -550 -500 -450 -400 -350 -300 -250 -200 -150 -100 Vertical Section at 145.000 (50ft/in] ¡ PIan#605-12B: .8/29/2001 10:18 AM -1 I , ~- ~.-,.~, ( ( ... SA'" ...... INTEQ ObP BP Amoco Baker Hughes INTEQ Planning Report ,.---.------- -----------.----------- -'--------------' : Company: BP Amoco Date: 8/29/2001 Time: 10:19:48 Page: 1 :1 Field: Prudhoe Bay C()o()rdinate(NE) Reference: Well: 05-12, True North I Site: PB DS 05 Vertical (I'VD) Reference: System: Mean Sea Level ¡Well: 05-12 Section (VS) Reference: Well (0.OON,O.00E.145.00Azi) i Wellpath: Plan#6 05-12B Survey Calculation Method: Minimum Curvature Db: Oracle; ,-- ------- --- --- -------------------------- -----------------~-- - ------ ------------------- --..--..-.- ------ --- --- --_u_------ ------- -.--_! - --_.----- .-----.--------------- ----...------------. ------.--.--..-..----------..------- --~------~-----'--l ! Field: Prudhoe Bay North Slope UNITED STATES : Map System:US State Plane Coordinate System 1927 : Geo Datum: NAD27 (Clarke 1866) [Sys Datum: Mean Sea Level ---..-------- -----------------.--....----.--" Map Zone: Coordinate System: Geomagnetic Model: Alaska. Zone 4 Well Centre BGGM2001 I I I I I I -.. ... ..---..-------...------..1 .. -.--- -----.---------.--'--------- ..--..----..-..-.------- .-- -_.---- -----.- "'------.------------- - --- .-----------------"u----'------.'" --....--'.------"--" ..----------.----.--.--.-------------------.------..-----.---------.----,,-.--- --------- Site: PB DS 05 TR-11-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5947204.70 ft 697428.91 ft Latitude: 70 15 35.696 N Longitude: 148 24 14.424 W North Reference: True Grid Convergence: 1.50 deg - ......-------.-.-.----u_-.--------------_u_--------"--""-"- ---..-'.._'-- .._u -.---------------------_.--------.---..._---- """-",---.-------,,,.--,"----"--."- m....._u"-----" ..-----.--.----...-.-- ------..-- .-..-..--..---...-------.------ ---.---. -...--..------....---------------. ------------..-..---.----------- ..------.....-..---- -- .'-'-----"------- --- 5949063.85 ft 697203.63 ft Latitude: Longitude: 12 70 15 54.034 N 148 24 19.560 W Well: 05-12 05-12 Well Position: +N/.S 1864.52 ft Northing: +E/.W -176.47 ft Easting : Position Uncertainty: 0.00 ft Slot Name: ---......-_..__.._n__.._"_"----,,.--"'-----------------.------'-.'-"---------"---""---'- .m- ..------..... -----..-""------.- .----------------.,------------,.-,,-,,--,,-,-.-,.-----'--"-"-' .. ".........-..------....-..-------..-....".-" -" '--"" - -.._-_.__.._-----------.._---_.__..__.~-----_._----------_...--------.-........------.--------.-.-----.-.----- ----"- .--. .--..-------------.-- --.-----..---..-----"--.--' -..--..-.... ..... Wellpath: Plan#6 05-128 500292024402 Current Datum: 25: 125/12/1977 00:00 Magnetic Data: 8/29/2001 Field Strength: 57508 nT Vertical Section: Depth From (TVD) ft . -..-..."" --.--..--..""-""" ------.-..---,,-..----.--------- ._-- ---.....---.-------..-..----..... 0.00 Drilled From: 05-12A Tie-on Depth: 9160.00 ft Height 69.00 ft Above System Datum: Mean Sea Level Declination: 26.72 deg Mag Dip Angle: 80.80 deg +N/-S +E/-W Direction ft ft deg ... ..--. .-..----.....-----------..---.. _.--- -...--- .-.-".. -----..----..-..-.------------------.-------..-- -----.-------.---------.---.-- 0.00 0.00 145.00 ---.-----------..-------.-..----------.. ... ..-..-..- -- ...--.--------..----.--.....-..-....------.-.."-" ""-"--""-----""----"'--------"------"""---'--------"---.----------.---..--"'--'---"----.'----'---""'- .------...-..--..---.- -. --. ..---------.----. n_....__-"'-..'---.--. .- ..,,-..----..--. ""--'---'-'--"----'-"------- --..-.- -"----""'------------_._'---------""--~----_._-----"'----'------.....--....--------..-..-----...-..,----.....--..---........... ..-...-..-..-...-----.---..-----...--...-.' ---"._--- Principal: Plan #6 Based on Lamar's Plan #5 Yes Date Composed: Version: Tied-to: 8/29/2001 1 From: Definitive Path Plan: -- "--""-.-..-..--.-.'" ---_..- ..-...--.."--- ,,--- - ...---.....---------------.....-------.............---.--""-'-"""----"_.._m....__--_--...----.---'------"-.----""'-----.----'-------,--",-------".---,----------,,---,------,-----,--'---__...._n_-----.....- Targets :;" c _.~, -.."- .c-::------ - - ----.-- --'---"-- '--' --..-'C.ë;'="":'F~=,:"::;.."":"",,,,-~:-",,;-;,~';rrc";:,,¡¡;r",'"è:1:;7"; :~.."..;;-, :-::",~~r"'~:-;T."":":c':"'"c:-:..,..~"1"cr:ë"'1;;"';:::C":ë;r;;;rc;~;;"7:r: c'!"n" "7:-c~;-~'-:-:ë:":T;"'~"?:':'r:-":~':;¡:T'~'*;;-"'::!"T':;:7" .' .' Map Map <--.- Latitude' --~:":~H'I.;C)n~itud;~¡+-?!, Name Description TVD +N/-S +E/-W.' Northing Easting Deg Mln Sec;::III::,»~gIIM~~~!'!,~èc;,:',!;¡:~¡,' '-.-,....-..-------.-..-----'-------"--"-"--" -."-------." ---------"-------'--"---~!"------:__:--_-----_h..._~nn__--- --_..._._~....~- -----------_:..--~-------.._,-----_._-_t..!_-_:._-_......_: _.._--._-----------_.._-_.._---_.:L~~"_~..._L,:"~_..'L~::..i",-1,::_~L{:...";._J~:: 05-12B Polygon5.1 0.00 991.69 -2103.48 5950000.05 695075.02 70 16 3.784 N 148 25 20.786 W -Polygon 1 0.00 991.69 ~2103.48 5950000.05 695075.02 70 16 3.784 N 148 25 20.786 W -Polygon 2 0.00 973.73 -1418.68 5950000.03 695760.02 70 16 3.609 N 148 25 0.853 W -Polygon 3 0.00 -188.56 -1349.12 5948840.03 695859.99 70 15 52.178 N 148 24 58.822 W -Polygon 4 0.00 -243.58 -1730.71 5948775.03 695480.00 70 15 51.636 N 148 25 9.927 W 5948820.03 695689.99 70 15 52.025 N 148 25 10.974 W 148 25 3.784 W 05-128 T5.2 8875.00 8930.00 682.73 -1766.44 -204.10 -1519.59 5949700.04 695420.01 70 16 0.746 N 05-12B T5.1 ,,-. - - ,,- ....""'---- ...- -.....-...""-""'---.----"-"--"'---.-- --..-------...------.--------....'--.--------..---"'---------".--..-..-----------------.... .---------------------..-----.---.---------...-----"'-'------------.--------------.------------------- Annotation 9145.78 9160.00 9388.12 9663.12 10128.37 10578.37 10830.00 8750.19 8758.94 8849.78 8859.01 8875.00 8897.54 8915.24 TIP KOP 1 2 3 4 TD ObP ( ( BP Amoco Baker Hughes INTEQ Planning Report ..8 .... (NT EQ .-- --. _cc- , , Company: BP Amoco Date: 8/29/2001 Time: 10:19:48 Page: i Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 05-12. True North : Site: PB DS 05 Vertical (TVD) Reference: System: Mean Sea Level ! Well: 05-12 Section (VS) Reference: Well (0.00N,0.00E,145.00Azi) . ~__~e!_lpa~~~~_~_05-12~____h_--"-- --------- ----_._---_._-------__.~u~ey Calculation Method: -~_~~~':".um- Cu.~tu~!_------~~-=-_~CIE!.h____-; Plan Section Information ;-----_c '---------_c_c_---------------,- ------_c -C_----------------_C_C-'l MD loci ADm TVD +N/-S +EI-W DLS Build Tum TFO Target I , - ------.f!_.-----.- d~_____---~~-----------_!!_--------~------~-----_._~-~gl1 O..~ _~eg~1 00ft d.:~/1 O~------ de~_____--_._----------------_._---j 9145.78 51.24 346.08 8750.19 1069.30 -1125.37 0.00 0.00 0.00 0.00 I 9160.00 52.88 349.08 8758.94 1080.25 -1127.78 20.24 11.53 21.10 56.20 9388.12 88.00 261.72 8849.78 1171.19 -1290.00 38.00 15.40 -38.29 270.00 9663.12 88.23 234.21 8859,01 1069,07 -1542.33 10.00 0.08 -10.01 270.00 10128.37 88.05 187.66 8875.00 681.12 -1774.85 10.00 -0.04 -10.01 269.00 10578.37 86.50 142.63 8897.54 257.78 -1662.68 10.00 -0.34 -10.01 267.00 10830.00 85.56 167.84 8915.24 31.71 -1558.36 10.00 -0.37 10.02 93.00 --- ..m_c . _c_c_- ---- - - . c c --_..------- c_----- c C.h__cc__- -~--------_..__c_-- c_-.._c_-.--.-----_c_---cc_ccc_.c"--------.--.-_c_--_uc----c----..-._c---.. -----c- 2 Survey r c --_c_~-- -.cc_-.--.- ----_c_----------- - .-.-------,--------- - --- c ---------.-------.--- ---.-------,-..---------.----..---- _c_-----" ------------.._---..---,--_.c- MD loel Azim SSTVD N/S E/W MapN MapE DLSVS TFO, Tool ft deg deg ft,ft ft ft c, ft deg/100ft ft deg cc ... - .--. - --",._- ----,---------~----_._----------_.._--- -..------_c-....._- ..-,---_.._- - ,---------.------- -.-- ----..-...--- ---_c_c_----c_--- -_..~~------_....-.__.._----------~_..,--,--,----_. '-"'--'----------------------'----- 9145.78 51.24 346.08 8750.19 1069.30 -1125.37 5950103.25 696050.71 0.00 -1521.41 0.00 TIP 9150.00 51.72 346.98 8752.82 1072.51 -1126.14 5950106.44 696049.85 20.24 -1524.48 56.20 MWD 9160.00 52.88 349.08 8758.94 1080.25 -1127.78 5950114.13 696048.01 20.24 -1531.76 55.64 KOP 9175.00 53.09 341.94 8767.98 1091.83 -1130.77 5950125.63 696044.71 38.00 -1542.96 270.00 MWD 9200.00 54.38 330.26 8782.80 1110.20 -1138.93 5950143.78 696036.08 38.00 -1562.69 274.30 MWD 9225.00 9250.00 9275.00 9300.00 9325.00 9350.00 9375.00 9388.12 9400.00 9425.00 9450.00 9475.00 9500.00 9525.00 9550.00 9575.00 9600.00 9625.00 9650.00 9663.12 9675.00 9700.00 9725.00 9750.00 9775.00 9800.00 9825.00 9850.00 9875.00 9900.00 9925.00 9950.00 9975.00 10000.00 10025.00 10050.00 10075.00 10100.00 56.75 60.06 64.13 68.81 73.93 79.37 85.00 88.00 88.00 88.00 88.01 88.02 88.04 88.06 88.08 88.11 88.14 88.17 88.21 88.23 88.21 88.17 88.13 88.10 88.07 88.04 88.02 88.00 87.99 87.98 87.97 87.97 87.97 87.97 87.98 87.99 88.01 88.03 319.10 308.64 298.92 289.90 281.45 273.44 265.72 261.72 260.53 258.03 255.53 253.03 250.53 248.02 245.52 243.02 240.52 238.02 235.52 234.21 233.02 230.52 228.02 225.52 223.02 220.52 218.01 215.51 213.01 210.51 208.01 205.51 203.01 200.50 198.00 195.50 193.00 190.50 8796.96 8810.09 8821.81 8831.80 8839.80 8845.58 8848.98 8849.78 8850.19 8851.07 8851.94 8852.80 8853.66 8854.51 8855.35 8856.19 8857.01 8857.81 8858.60 8859.01 8859.38 8860.17 8860.98 8861.80 8862.63 8863.48 8864.34 8865.21 8866.08 8866.96 8867.85 8868.73 8869.62 8870.50 8871.39 8872.27 8873.14 8874.00 1126.97 1141.66 1153.90 1163.32 1169.69 1172.82 1172.62 1171.19 1169.36 1164.71 1159.00 1152.23 1144.41 1135.57 1125.72 1114.88 1103.06 1090.29 1076.60 1069.07 1062.03 1046.57 1030.26 1013.15 995.26 976.62 957.28 937.27 916.62 895.38 873.58 851.28 828.50 805.30 781.71 757.79 733.58 709.12 -1150.84 -1166.18 -1184.53 -1205.38 -1228.16 -1252.26 -1276.99 -1290.00 -1301.73 -1326.28 -1350.60 -1374.65 -1398.38 -1421.74 -1444.70 -1467.21 -1489.22 -1510.70 -1531.60 -1542.33 -1551.89 -1571.52 -1590.45 -1608.65 -1626.09 -1642.73 -1658.55 -1673.50 -1687.56 -1700.71 -1712.93 -1724.17 -1734.44 -1743.70 -1751.93 -1759.13 -1765.28 -1770.37 5950160.22 5950174.52 5950186.26 5950195.14 5950200.90 5950203.40 5950202.56 5950200.79 5950198.65 5950193.36 5950187.01 5950179.61 5950171.18 5950161.73 5950151.28 5950139.85 5950127.46 5950114.14 5950099.90 5950092.10 5950084.81 5950068.84 5950052.05 5950034.46 5950016.12 5949997.06 5949977.31 5949956.91 5949935.90 5949914.33 5949892.22 5949869.63 5949846.59 5949823.16 5949799.36 5949775.26 5949750.90 5949726.31 696023.73 696008.01 695989.35 695968.26 695945.32 695921.16 695896.44 695883.47 695871.79 695847.38 695823.22 695799.36 695775.84 695752.71 695730.02 695707.81 695686.11 695664.98 695644.45 695633.92 695624.55 695605.33 695586.83 695569.09 695552.12 695535.97 695520.68 695506.25 695492.73 695480.15 695468.51 695457.85 695448.19 695439.54 695431.93 695425,35 695419.84 695415.40 38.00 38.00 38.00 38.00 38.00 38.00 38.00 38.02 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 9.97 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 -1583.25 -1604.09 -1624.63 -1644.32 -1662.60 -1678.98 -1693.01 -1699.30 -1704.52 -1714.80 -1724.07 -1732.31 -1739.53 -1745.69 -1750.78 -1754.81 -1757,75 -1759.61 -1760.39 -1760.38 -1760.09 -1758.68 -1756.19 -1752.61 -1747.96 -1742.24 -1735.46 -1727.64 -1718.80 -1708.94 -1698.09 -1686.27 -1673.50 -1659.80 -1645.21 -1629.74 -1613.43 -1596.32 281.22 MWD 287.55 MWD 293.05 MWD 297.60 MWD 301.22 MWD 303.92 MWD 305.78 MWD 306.80 1 270.00 MWD 270.04 MWD 270.13 MWD 270.22 MWD 270.30 MWD 270.39 MWD 270.47 MWD 270.56 MWD 270,64 MWD 270.72 MWD 270.80 MWD 271.06 2 269.00 MWD 269.04 MWD 269.12 MWD 269.20 MWD 269.28 MWD 269.36 MWD 269.45 MWD 269.53 MWD 269.62 MWD 269.71 MWD 269.80 MWD 269.88 MWD 269.97 MWD 270.06 MWD 270.15 MWD 270.24 MWD 270.33 MWD 270.41 MWD L_c-_c c ---. -.------,-'-"'------......cc__'..m..cc.__"c_..c- -,,_c,----------_c"C_C_--cc'---"C- c_--"""-,,--~'c,,-----_c_c_',,---,--,, ,..--..--_c_-....--c_-,c_---_c__cc_-.c"--'---.'---"---------c,---'ccc_._,._c_--------,---_c,----'----_.u_-----"C"C_'---,cc_c-..,_c,c_- ccc..c_- -c- ..cc ( ( 2"CT 10,000 psi Pack-Off Lubricator Blind/Shear 7 1/1611 Pipe/Slips ... Pipe/Slips 71/16" Pipe/~/;ps ... ... 7 1/16" x 5,000 psi SWAB OR MASTER VALVE :;;tIt ~ 3/.g II :)." ~, ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED INTRANSNUTTAL LETTER WELL NAME fl? it 0.;;;-/2-6 CHECK 1 STANDARD LETTER DEVELOPMENT ,. DEVELO ~M7 RED RILL j EXPLORATION INJECTION WELL INJECTION WELL RED RILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT. HOLE (PH) / ANNULAR DI~OSAL . ( r Á NO 'V' ANNULAR DISPOSAL <-> YES ANNULAR DISPOSAL THIS WELL "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. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name. on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has n~t been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS <-> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved' 'subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. H 194712 DATE INVOICE I CREDIT MEMO 072701 CKO72701C PYMT OMMENTS: HANDL NG I N5T : ( DESCRIPTION Per it To Drill ee 5tH - Terrie Hub Ie iE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. PAY To The ORDER O-f BP EXPLORATION, (ALASKA) INC. p.o. BOX 196612 ANCHORAGE, ALASKA 99519-6612 TOTAL ... ~I CHECK NO. 00194712 DATE 07/31/01 GROSS VENDOR DISCOUNT 00 100.00 ALASKAOILA NET 100.00 X4628 100.00 100.00 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No.H 194712 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 ~ 00194712 OO/100~**~************~~*~**~************** US D~LLAR , , ,. , ALAakA OIL AND GAS , CQNSERV,t,T I QNÇ:OMMI 5S! (IN' aa3wEsfr 7TH AVENUE ,', ""', SUITE 1<)0 ' "" ANCHORAGE ,>DATE ,"':' O,7/3i/Ol, , " , '.AMOUNT " !~1 OO,':~H;I AK 995ål I'",;",l ": NQ;rVALlOi:\fTER120 DAYS' " ,",' ' , ~"'i'. ii,~.. .' ,., -7t~..-".~,)~ ' "~~~ ''.:'/ " ~':n IJ.~A . .,',,'. " (~~,&;iJl:r'~',i'" , , ,,' , :;~.,;~_.w"';;',¡~!., " ' " III ~ g ... ? ~ 2 III I: 0 ... ~ 2 0 3 8 g 5 I: 0 0 8 ...... ~ ~ III <II. WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRA TION . / 'I \ V COMPANY WELL NAME tJS"--!2- " D INIT CLASS '~I / 1 DI L-- 1.Permitfeeattached.........,.....",..... 2. Lease number appropriate. . . , . . . , . . . . . , , . . . . 3, Unique well name and number. .. . . . , . . , . . . , . . . . 4. Well located in a defined pool.. . . . . . . . . , . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6, Well located proper distance from other wells., . , . . . . . . 7. Sufficient acreage available'in drilling unit.. . , . . , . . . . . 8. If deviated. is wellbóre plat included.. . . . . . . . . , . . . . 9. Operator only affected party.. . . . . . . . . . . , , . . . . . 10. Operator has appropriate bond in force. , . . , . . . . . . . . 11. Permit can be issued without conservation order. . . . . . , . 12. Permit can,be issued without administrative approval.. . , . . 13. Can permit be approved before 15-day wait.. , . . . . , . , . ~~: ~~~~:~:~;~i:t~~~e:1I kn~~' US'DWs.". '. " '. '. '. '. '. '.' . ~ ~~. ~<L~"<- ~~~l~ '->->CL'-' 16. CMT vol adequate to CIrculate on condudor & suñ csg, , . . . Y N - ---d 17, CMT vol adequate to ,tie-in long string to surf csg. . . , . , . . Y N 18. CMT will cover all known productive horizons. . . . . '. . , . . N 19. Casing designs adequate for C, T, B & permafrost. . , . . . . ' N ~c.. ~ A ~~: ~~e~~I~~~~~ ~~se;,ea~:~d¿n~~t ¡'~e~ ~PP~o~~d: : : ~ ~~ ~ - ~ ~ ~"- ~ ~ ~ 4l.~ '? ~ 22. Adequate well bore separation proposed.. . . . . . . . , . . . N . 23. If diverter required. does it meet regulations. . . . . . , . . . \-..:) ~ 24. Drilling .fluid program schematic & equip list adequate. . . , . N 25. BOPEs. do they meet regulation. . . . . . . . . . ~. . . ,N f\ RÞ,TJoSE 26. BOPE press rating appropriate; test to ~~\.....J psig, N~~~'Q C<.~~ ~ ;;';)'S~ ~~' I_, . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . ,N . . ~g: ~~~::~~~rH~h;~ ~~~:~f: ~~u~d~~n: : : : : : : : : : : y Œ5\-\;)~~"S ~~~~ c~ ~~( \t~~ ~':.f¿~~'t~ "'I ~~s~~\~~~ 30. Permit can be issued wlo hydrogen sulfide measures. . . . .. Y N J()..Jl../~ .:;;; f . L- -5 ¿-t',,' ) :.2 31. Da~a ~resented. on potential overpressure zones. . . . . . . . Y ¿Jl.>å--1A.: Þd-- ~ J rd ~ ¿ J-'U) t'êð uJtL 12--0 / íP((~Yl (W.flj( os-- /9' c:.~ 3-/1- 7t:. ".86 32. Seismic analysIs of shallow gas zones. . . . . . . . . . . .~ 0 DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . , , . . y 11./'>- D I 34. Contact name/phone for weekly progress reports (explorato only] Y NNULAR DISPOSAL35. With proper cementing records. this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate frèshwater; or cause drilling waste. .. to surface; ." .' (C) will not impair mechanical integrity pf the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 AAC 25.412, Y N GEOLO Y: ENGINEERING:' UIC/Annular COMMISSION: RP WM~, -8~s SA JMR PROGRAM: exp - dev ~ redrU / serv GEOL AREA fVO UNIT# w~lIbore seg _ann. disposal para req - ON/OFF SHORE (?),I-J :&;R DATE! ' 11-/(.0 ENGINEERING GEOLOGY AP APPR Y N Y N DATE Com me ntsllnstructions: . , c:\msoffice\wordian\diana\checklist (rev. 11101/100) c 0 Z 0 -i :E :0 - -i m - Z -4 ,::£: - en :Þ :0 m > WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRA TION PROGRAM: exp - dev - redrll GEOL AREA 1,Permitfeeattached.....,....,.,......,... N 2. Lease number appropriate. . . . . . , . . . . . . . . . . . . . N 3. Unique well name and number. ., . . . , . . . . . . . . . . , N 4, Well located in a defined pool.. . . . . . , . , . . . . . . . . N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. , . . . . . . . N 7. Sufficient acreage available in drilling unit.. . . . . . . . , . . N 8. If deviated. is well bore plat included., , . . . . , . . . . . . . N 9. Operator only affected party.. . . . , . . . . . . . . . . . . . ' N 10. Operator has appropriate bond in force, . . . . , . . . . . . . N 11, Permit can be issued without conservation order. . . . . . . . N 12. Permit can be issued without administrative approval.. . . . , . N 13. Can permit be approved before 15-day wait.. . . . . . . . . . ' N ¡¡: ~~*:;i~f~~;:~I:t~~f~~~:~~i~u"rt~g': : : ": : ~ ~~ >~~L'cC~~~'~\-\"", ~ \ \ 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ~ N 18. CMT will cover all known productive horizons. . . . . . . , , , N 19, Casing designs adequate for C. T, B & permafrost. . . . . . . N . " . ~~: ~~e:~~~,~~:~a2~ ~,¡;,;~;;v,~b:~d~n;";'~t b~e~ ~pp;o~~d: : : y ~ 'l.:" ""'co> t"'t ~~~ ~ '1;~{~.. 22. Adequate wellbore separation proposed.. . . . . . . . . . . . ~ N \,,--~(L Q t -- ~ ~U\:~t~ 23. If diverter required. does it meet regulations. . . . . . . . . . . ~þ...,. . 24. Drilling fluid program schematic & equip list adequate. , . . , N 25. BOPEs. do they meet regulation. . . . . . . . ~~ . , . . N \. 1 ~ '";") G. n J ~ r 1', 26, BOPE press rating appropriate; test to ~-::>~) psig. N j-' ~\' ~.. ~ ~~\r) ~~ \ 27. Choke manifold complies w/API RP-53 (May 84). . . . . , . . N \ . ~~: ~~~~::~~~~~rH~~h;~~ ~~:~:~f; ~~u~d~~n: : .' : .' .' .' .' : : : y ~rR~"s.~~\~ ~,5tt.~C(-~~o.. \~\"\'-\.> ~ "'^-JD>~~\>\1t.~~ ~~n . ~ 30. Permit can be issued w/o hydrogen sulfide measures. . . . . Y N v.¿, '.,.'. _.5 ¿..' 'f...R. or¿¿..6. 31. Oa~a ~resented, on potential overpressure zones. . . . . ". Y tJ... 1¿~d) ræ.-h;}~", /:l~ . ~l~t; ~ /1/ ¿p.. .' ';-n (6!;:- Þ¡- tnt $'/I.5'~) 32. selsmlcanal~s..lsofshaIlO~gaSZones, . . . . . . . . . ~.. It N ~CCéÞ-7Cf~ r? '~'. ~ 4!&-4'/4-./:/~ ci::~ tS.D A:~ OA TE 33. Seabed condition survey (If off-shore). . . . . . , . . . . . . Y N J /" C¡,lb,ð/ 34. Contact name/phone for weekly progress reports [explo~ ry only] Y N . ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate. freshwater; or cause drilling waste. .. to surface; . (C) will not impair mechanical integrity of the well used for disposal; Y N (0) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25,252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Aonular COMMISSION: RÞ8 ~crW . WM ~ S ~. TE~4s.:~"""G.[D1Ù APPR J;>AJ"E - :J.:.JM/ J ENGINEERING ~%~ GEOLOGY APPR DATE wellbore seg _ann. disposal para req - C-"; II C,,- ~7) ON/OFF SHORE .Qa- serv c 0 Z 0 -I ~ ::0 ( - -I m . .-..-".. - Z -I ::I: - Y N Y N en » ::0 m » (" Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) "" \ Ii Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. , To improve the readability of the Wen History file and to simplify finding information, infonnation 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. ! ! ! ! !! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! -Version Information VERS, WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 8602.0000: STOP.FT 10482,0000: STEP.FT 0,5000: NULL. -999.2500: COMP.. COMPANY: WELL. WELL: FLD. FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL, TOOL NAME & TYPE: DATE. LOG DATE: API. API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 32 TOWN. N UN RANG. 15E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 69 DMF KB EKB ,F 69 EDF .F N/A EGL .F N/A CASE.F N/A OSl . DIRECTIONAL -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Tie in log with Schlumberger BHCS/GR dated 27 May 1977. (5) Well 05-12B was kicked off @ 8906' MD (8550' SSTVD) from the original wellbore of Well 05-12, Well 05-12B was drilled to 10482' MD (8851' SSTVD). RA marker at 8910' MD (8553,6' SSTVD) , The interval from 10472' MD (8850' SSTVD) to 10482' MD (8851' SSTVD) was not logged due to sensor to bit offset. ,j' \ **** REEL HEADER **** MWD 02/03/29 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 02/03/29 234764 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** (' cJOJ-1BU IC'~ì;)\ ,- Remark File Version 1.000 Extract File: Idwg,las 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration, Inc. 05-12B Prudhoe Bay Unit 2897' NSL, 5143' WEL North Slope Alaska Baker Hughes INTEQ 1,75" NaviGamma - Gamma Ray 14-Dec-Ol 500292024402 (6) (7) (8 ) Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 ~t.:1 i{ (' (9) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) supplied by BPX (SWS, 16-Dec-01). (10) A Magnetic Declination correction of 26.63 degrees has been applied to the Directional Surveys. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD) (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 1 19.10 ft. 23.56 ft. 2 19.10 ft. 23.56 ft. 3 19.10 ft. 23.56 ft. 4 19,72 ft. 24.18 ft. 5 19,06 ft. 23,52 ft. 6 19.06 ft. 23.52 ft. 7 19,06 ft. 23.52 ft. 8 19.06 ft. 23.52 ft. 9 18.69 ft. 23.15 ft. CURVE SHIFT DATA BASELINE, 8626,52, 8887,73, 8906.83, 8959.55, 9006.22, 9009.55, 9029.86, 9045.92, 9056.83, 9099.55, 9109.55, 9196.22, 9214.70, 9284.10, 9307.43, 9377.43, 9408.64, 9414.40, 9440.76, 9451. 07, 9462.58, 9595.31, 9668.95, 9718.95, 9726.83, 9735,92, 9750.76, 9761.07, 9793.79, 9798.04, 9831.98, 9860.16, 9868.04, 9889.55, 9900,16, 9916.52, 9940.76, 9955.31, 9977.73, 10102.0, 10121.1, 10153.2, 10208.9, 10321.4, MEASURED, 8628.04, 8887,13, 8908.64, 8964.40, 9010.46, 9013.79, 9033.49, 9049.86, 9060.76, 9104.10, 9113.79, 9200.46, 9216.22, 9292.58, 9315.61, 9381,67, 9412.28, 9419.25, 9446.22, 9453.79, 9464,40, 9603.79, 9675.31, 9726,83, 9733.49, 9740.16, 9759.55, 9769.25, 9801. 98, 9805.61, 9841.37, 9867.43, 9881.07, 9893.19, 9906.22, 9925.61, 9950.46, 9962.89, 9980,76, 10109.2, 10126.5, 10160.5, 10217.4, 10329.9, DISPLACEMENT 1.51562 -0,605469 1. 81836 4.84863 4.24219 4.24219 3.63574 3.93848 3.93945 4.5459 4.24219 4.24219 1. 51562 8,48438 8.18164 4,24219 3.63672 4.84863 5.45508 2.72656 1. 81836 8.48438 6.36328 7.87793 6.66699 4.24219 8.78809 8.18164 8.18262 7.5752 9.39355 7.27246 13.0303 3.63672 6.06055 9.09082 9.69727 7.57617 3.03027 7.27344 5.4541 7.27246 8.48438 8.48535 ( { 10330.8, 10340.8, 10 10392.0, 10392.6, 0,605469 10408.0, 10410.2, 2.12109 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subtile: 1 127 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------- WDFN LCC CN WN FN COUN STAT mwd,xtf 150 BP Exploration, Inc. 05-12B Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data, 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 16-Dec-01. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR ROP ---------------------------------------------------- GR ROP GRAX12 ROPS12 0,0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 84 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Length Size 1 2 68 68 1 1 GR ROP 4 4 4 4 MWD MWD API F/HR ------- ( ( 8 Total Data Records: 45 Tape File Start Depth 8602.000000 Tape File End Depth 10482,000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subtile: 2 54 records". Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD ,002 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------- WDFN LCe CN WN FN COUN STAT mwd.xtf 150 BP Exploration, Inc. 05-12B Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPS GRAX ROPS GRAX ROPS 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 84 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 2 GRAX ROPS (' MWD MWD 68 68 Total Data Records: 1 1 API F/HR 45 Tape File Start Depth 8602,000000 Tape File End Depth 10482,000000 Tape File Level Spacing = 0,500000 Tape File Depth Units = teet Tape Subtile: 3 **** FILE TRAILER **** Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 02/03/29 234764 01 **** REEL TRAILER **** MWD 02/03/29 BHI 01 Tape Subtile: 4 Minimum record length: Maximum record length: Tape Subtile 1 is type: LIS Tape Subtile 2 is type: LIS DEPTH 8602.0000 8602.5000 8700.0000 8800.0000 8900.0000 9000.0000 9100.0000 9200.0000 9300.0000 9400,0000 9500.0000 9600.0000 9700.0000 9800.0000 9900.0000 10000.0000 10100.0000 10200.0000 10300.0000 10400.0000 10482.0000 GR -999.2500 -999.2500 -999.2500 -999.2500 18.6760 23.6352 17.6204 133.5102 63.3413 57.3757 45.9525 50.8326 51.5971 117,9803 128.0546 40.6913 41.5827 38.4035 38.8850 63.0854 -999.2500 54 records.., 2 records... 132 bytes 132 bytes ROP -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 21.1324 94,1167 60.7851 25.0131 90.0732 183.5002 76.9489 99.3538 52.2491 79.5300 18.1005 107.8209 22.5005 105.8820 16.3351 -999.2500 4 4 ------- { ( 4 4 8 ( (' Tape File Start Depth 8602.000000 Tape File End Depth 10482.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH 8602.0000 8602.5000 8700.0000 8800.0000 8900.0000 9000.0000 9100.0000 9200.0000 9300.0000 9400.0000 9500.0000 9600.0000 9700.0000 9800.0000 9900.0000 10000.0000 10100,0000 10200,0000 10300.0000 10400,0000 10482.0000 GRAX -999.2500 63.1950 -999.2500 -999.2500 19.1190 16,4960 73.0600 106.0120 75.1590 50.3920 47.0340 54.8590 38.0090 47.8790 58.7180 33.6940 66.3440 39.8980 34.4410 65.7140 -999.2500 ROPS -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 24.3080 21. 0120 33.5530 34,7870 88,3280 25.4250 7.0870 156.5360 71.9250 262,0800 141. 2170 241,0830 151.3810 137,3680 11,0960 107,8800 Tape File Start Depth 8602.000000 Tape File End Depth 10482.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS