The URL can be used to link to this page

Home My WebLink About203-060 Image ~ .bject Well History File C"Jer Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~O~ - 0 bo Well History File Identifier Organizing (done) o Two-sided 111111111I111111111 ~can Needed OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner RESCAN ~Ior Items: o Greyscale Items: DIGITAL DATA ~kettes, No. ~ o Other, NolType: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Scanning Preparation A x 30 = o Other:: 1 '1 Date: 7 t~ tJ5' Isl fUP 1 - , . I JI') Date:7 ¡ ro os- Isl VVl1r t,o + $? = TPT~L PAGES b<6 (Count doe~ l1o}.Anr(lude cover sheet),1111 iJ Date: r- I ð OS- 151 r r V, 1 -I I BY: Helen~ Project Proofing BY: Helen (Maria ) ~ BY: Helen ç- Maria j.) BY: Production Scanning Stage 1 Page Count from Scanned File: b c¡ (Count does include c./" sheet) Page Count Matches Number in Scanning Preparation: V YES NO Helen ~aria . ) Date: 7'1 g I D~ Is! yVll 0 If NO in stage 1, page(s) discrepancies were found: YES" NO Stage 1 BY: Helen Maria Date: 151 II! 1111111111111111 1111111111111111111 1 Date: 151 Quality Checked 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: • ~~ .~~~ STATE OF ALASKA RECEIVED .'~' ALASK~IL AND GAS CONSERVATION CON~SION ~°'~ ` ~ ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG DEC 3 1 2008 Alaetra flil JL (,ac [`nnc f:nmmicei: 1a. Well Status: ^ Oil ^ Gas ^ Plugged ' ®Abandoned ^ Suspended 20AAC 25.105 2oMC z5.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completion ero 1b. Well Cla ' ®Develfi ~r~ Exploratory ^ Service ^ Strati raphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., o Aband. 12/6/2008 ~ 12. Permit to Drill Number 203-060. 308-398 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 05/10/2003 13. API Number. 50-029-20775-02-00 • 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 05/14/2003 14. Well Name and Number: PBU C-236 . 1315 FNL, 1030 FEL, SEC. 19, T11 N, R14E, UM Top of Productive Horizon: 4316' FNL, 1931' FEL, SEC. 19, T11 N, R14E, UM 8. KB (ft above MSL): 65.6' Ground (ft MSL): 37' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 3972' FNL, 2514' FEL, SEC. 19, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 10736' 9022' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 664349 ' y- 5959903 ~ Zone- ASP4 10. Total Depth (MD+TVD) 10821' 9025' " 16. Property Designation: ADL 028305 TPI: x- 663524 y_ 5956884 Zone- ASP4 Total Depth: x- 662932 y- 5957215 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No mi le r i nd rinted inf rmati n er 20 AA 2 0 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (lVD): 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, DIR, GR, RES, ABI, DEN, NEU 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT WT. PER FT. GRADE T P BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 0" x 3" In la n r rf 8' s Concret / 7 -/" 4# -8 rf 8 rf 7 12-1/4" 1 I s'G' 1 7" 26# -8 4 7575' 84 -1/2" 253 c CI 4-1/ " L- -1 4 I 23. Open to production or inject ion? ^ Yes ®No 24. TuewG RECORD If Yes, list each i (MD+TVD of Top i;< Bottom; Pe nterval open rforation Size and Number): SRE DEPTH SET MD PACKER SET MD 4-1/2", 12.6#, L-80 9167 9110' MD TVD MD ND 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~~~~~~,~, ~ ~k ~ - ~ JAS ` 209 DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 10675' Set Whipstock 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes -® No Sidewal l Core s A wired? ^ Yes •®No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. .~NLR.K~ None '~"^'gT u ~ . .F nn SATE i i=RI: I? Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE '~ ~ -., 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN KERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 9345' 8401' None Shublik 9381' 8435' Sadlerochit 9466' 8515' Zone 3 /Top CGL 9692' 8719' Zone 2C /Base CGL 9750' 8769' Zone 26u / 23S6 9825' 8829' Zone 261 / 22TS 9900' 8882' 21 P 10140' 9000' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. l ~ Si ned 31/~ 9 Terrie Hubble Title Drilling Technologist Date PBU C-23B 203-060 308-398 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Charles Reynolds, 564-5480 PrmiN./A rvaN. 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITeM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only . ~ • C-23B, Well History (Pre Rig Sidetrack) Date Summary 11/10/2008 T/I/O=SSV/0/0, Temp=Sl. PPPOT-T (PASS). Pre CTD PPPOT-T: External Alemite check installed. Stung into test port (50 psi), bled to 0 psi. Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 50 psi in second 15 min (PASS). Functioned LDS, all moved freely. Bled void to 0 psi. 11/21/2008 WELL S/I ON ARRIVAL. RAN 3.855" GAUGE RING TO 591' SLM. UNABLE TO WORK PAST. RAN 3.77" GUAGE RING TO TOP OF 4-1/2" XX-PLUG AT 2166' SLM (2185 MD). RAN 4-1/2" X-EQUALIZING PRONG AND EQUALIZED 4-1/2" XX-PLUG AT 2166' SLM (2185 MD). RAN 3.80" SWAGE TO 4-1/2" XX- PLUG AT 2166' SLM (2185 MD). PULL 4-1/2" XX-PLUG FROM SVLN AT 2166' SLM (2185 MD). LEFT WELL S/I. TURNED WELL OVER TO DSO. 11/27/2008 MIRU. MU and RIH with BOT motor and 3.80" Dry Tag "XN" nipple at 9144' ctmd. Mill through nipple. Dry tag PBTD at 10719' ctmd. POOH while freeze protecting coil. OOH. RD motor and mill. MU DMY Whipstock, tag up on slush or ice at - 23'. Pump 60/40 to clear plug freeze protect tubing. Freeze protect the flowline with 98 bbls 60/40. RIH with DMY. 11/28/2008 RIH with Dummy Whipstock drift. Dry tag at 10721 CTM. POOH, Lay down tools RDMO. Job Complete. 12/2/2008 T/I/O = 2300/0/0 MIT IA PASSED to 3000 psi ,MIT OA PASSED to 2000 psi, Infectivity test (CTD prep) Pressured up IA w/ 16.1 bbls crude. IA lost 80 psi 1st 15 mins and 40 psi 2nd 15 mins for a total loss of 120 psi in 30 mins. Bled to zero. RD from IA, RU to OA Pressured up OA w/ 2.7 bbls crude. OA lost 20 psi 1st 15 mins and 10 psi 2nd 15 mins for a total loss of 30 psi in 30 mins Bled to zero. Loaded tubing w/ 5 bbls meth and 230 bbls crude. Performed infectivity test with additional 54 bbls crude. Results as follows: 0.75bpm = 100psi 1.Obpm = 150psi 2.Obpm = 300psi 3.Obpm = 450psi 4.Obpm = 650psi 5.Obpm = 750psi FWHP's = 0/0/500 Swab =shut, Master =open, Wing =shut, SSV =shut, IA =open and tagged, OA =open and tagged. 12/4/2008 Pressure test tree valves for CTD. All valves Good. 12/4/2008 T/I/0=650/0/0 Set 6 3/8 CIW J BPV pre nordic. 1-2' ext used tagged 03108', no problems. Page 1 of 1 ~' ~~ BP EXPLORATION Page 1 of 8 Operations Summary Report Legal Well Name: C-23 Common Well Name: C-23 Spud Date: Event Name: REENTER+COMPLETE Start: 12/3/2008 End: 12/13/2008 Contractor Name: NORDIC CALISTA Rig Release: 12/13/2008 Rig Name: NORDIC 1 Rig Number: Date .From - To Hours Task 'Code NPT Phase Description of Operations 12/5/2008 04:00 - 06:00 2.00 MOB P PRE Move rig from C-30A to C-23C. MU 7-1/16" Valve to bottom of BOP stack. Spot Rig Over Well 06:00 - 10:00 4.00 RIGD P PRE ACCEPT RIG ~ 06:00 NU BOP 10:00 - 12:00 2.00 BOPSU P PRE Test BOP. AOGCC rep John Crisp waived witnessing BOP test. 12:00 - 13:00 1.00 BOPSU N PRE Repair test pump. 13:00 - 19:00 6.00 BOPSU P PRE Continue to BOP test. 19:00 - 21:15 2.25 RIGU P PRE RU lubricator, test to 2000 psi, Pull BPV Shut in P - 2350 psi 21:15 - 21:30 0.25 BOPSU P PRE Test inner reel valve and chart 21:30 - 23:15 1.75 RIGU P PRE PJSM, bleed off pressure to the TT, initial shut-in pressure 2425 psi. Bleed down to 1570 psi 23:15 - 00:00 0.75 RIGU P PRE Pump 260 bbl of KCI through kill line, pump at 3.75 bpm At 120 away Shut in - 0 psi, Continue pumping KCL 12/6/2008 00:00 - 01:45 1.75 RIGU P PRE Continue pumping 260 bbl KCI, pump 30 bbl pill, pump 160 bbl milling fluid pumping at 3.8 bpm Well Dead... 01:45 - 03:00 1.25 RIGU P PRE Pump slack and cut 375' coil 03:00 - 05:00 2.00 RIGU P PRE Install CTC, Rehead eline 05:00 - 06:00 1.00 WHIP P WEXIT Bring WS to rig floor, install pip tags, MU WS setting BHA 06:00 - 08:00 2.00 WHIP P WEXIT RIH to 9453 08:00 - 08:40 0.67 WHIP P WEXIT Log tie-in. Correction -17'. 08:40 - 09:00 0.33 WHIP P WEXIT RIH Orient WS 90 LHS. Place WS top At 10675'. Close EDC and pressure to 4350 to shear. 09:00 - 10:40 1.67 WHIP P WEXIT POH 10:40 - 12:15 1.58 WHIP P WEXIT LD WS BHA and PU milling BHA ~-` _ ~_ 1 :15 - 14:00 1.75 HIP P WEXIT RIH Tag XN. ~ 9167.5'. No GO. •3~'~ 14:00 - 14:15 0.25 STWHIP N WEXIT Check Baker job log. Check BP tubing tally to confirm tail pipe C•~i3G BakerLocked OK. 14:15 - 15:10 0.92 STWHIP P WEXIT Ream XN nipple. 2.61 bpm 2660 psi. Stall 9167.83' Ream MW 50 psi at 9167.76, MW to 9167.82 , 9168.03 MW 600 psi to 9168.07. 600 psi MW 9168.22 -9168.24. Ream w/o motor work to 9178. PU to 9130 RIH MW 9147.8 (X nipple) .Passed XN. Slight MW. 15:10 - 15:50 0.67 STWHIP P WEXIT RIH to window. MWD gamma failed after reaming waived tie-in. RIH Tag WS at 10674. Gas in returns. 15:50 - 18:30 2.67 STWHIP N DFAL WEXIT Time mill 2.57/2.54 bpm ~ 2615 psi. ECD 9.48 18:30 - 22:50 4.33 STWHIP N DFAL WEXIT Time mill 2.57/2.57 bpm ~ 2590 psi, 1.63k DHWOB, 9.49 ppg ECD ~ 10676.8 CTD MD 2.55/2.54 bpm ~ 2552 psi, 1.61k DHWOB, 9.48 ppg ECD ~ 10677.7 CT MD 2.55/2.55 bpm ~ 2527 psi, 1.64k DHWOB, 9.48 ppg ECD ~ 10678.5 CT MD, PVT = 298 2.55/2.55 bpm C~ 2523 psi, 1.65k DHWOB, 9.47 ppg ECD ~ 10679.2 CT MD, PVT =298 2.55/2.53 bpm ~ 2520 psi, 1.63k DHWOB, 9.47 ppg ECD ~ 10679.4 CT MD, PVT = 297 2.54/2.52 bpm ~ 2490 psi, 1.63k DHWOB, 9.47 ppg ECD ~ 10680.5 CT ME, PVT = 296 Printed: 12/22/2008 1:21:56 PM - TREE ~- • 6" McEV OY WELLHEAD = ACTUATOR= O KB. ELEV = 71.5' BF. ELEV = 39.4' KOP = 8575' Max Angle = 96 79 Datum MD = 9876' Datum TV D = 8800' SS Minimum ID = 3.725" @ 9154' 4-112" HES XN NIPPLE 9-5/8" DV PKR 13-3/8" CSG, 72#, L-80, ID = 12.347" TOP OF WHIPSTOCK I $-1 575' a EZSV 8608' 9-5/8" CSG, 47#, I 9442' L-80, ID = 8.681 " 90$9' ~~4-1/2" HES X NIP (9CR), ID = 3.813" 9110' ~ 7" X 4-1 /2" BKR S-3 PKR, ID = 3.875" 9133' 4-1/2" HES X NIP (9CR), ID = 3.813" PJC DRAFT C-23C SAP NOTES: "" 4-1 /2" CHROME NIPPLES"** 21$5' I-14-1 /2" HES X NIP (9CR), ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3020 3020 1 MMG-M DMY RK 0 05/30/03 5 3992 3989 11 MMG-M DMY RK 0 04/11 /08 4 5788 5515 41 MMG-M DMY RK 0 04/11 /08 3 7123 6517 39 MMG-M DMY RK 0 05/17/03 2 8054 7267 34 MMG-M DMY RK 0 05/17/03 1 9021 8093 19 KBG-2 DMY BK 0 05/17/03 8426' -~ 9-5/8" X 7" BKR LNR TIEBACK, ID = 7.500" $434' 9-5/8" X 7" BKR ZXP LTP w /LNR HGR, ID = 6.280" MILLOUT WINDOW (C-236) 8580 ' - 8596' 9154' ~~4-1/2" HES XN NIP(9CR), MILLEDT03.80" (11/27/08) 4-1/2" LNR, 12.6#, L-80 TCII, 9167' .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80 BTC, 9344' .0383 bpf, ID = 6.276" PERFORATION SUMMARY REF LOG: MCNL ON 12/11/08 A NGLE AT TOP PERF: 92° @ 11750' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11750 - 12250 O 12/12/08 9156' -17" X 5" BKR LTP w /TIEBACK, ID = 4.380" 9167' 4-1/2" WLEG, ID= 3.958" 9170' 7" X 5" BKR LNR HGR, ID = 4.450" 9177' 5" X 4-1/2" XO, ID = 3.958" 97$5' KB LNR TOP PKR, ID = 2.560" 9791' 3.7' DEPLOY SLV, ID = 3.00" MILLOUT WINDOW (C-23C) 10677' - 10685' 9$42' 3-1/2" X 3-3/16" XO, ID = 2.992" 10994' 3-3/16" X 2-7/8" XO, ID = 2.786" 4-1/2" MONO-BORE WHIPSTOCK (12/07/08) 10675' RA TAG 10684' PBTD 12257' 4-1/2" LNR, 12.6", L-80 BTGM, 10820' .0152 bpf, ID = 3.958" 3-1/2" LNR, 8.81 #, L-80 STL, .0087 bpf, ID= 2.995" 9842' 3-3/16" LNR, 6.2 #, L-80 TCII, .0076 bpf, ID = 2.80" 10994' 2-7/8" LNR, 6.16 #, L-80 STL, .0058 bpf, ID = 2.441" 12295' DATE REV BY COMMENTS DATE REV BY COMMENTS 09/04/82 ORIGINAL COMPLETION 10/17/96 D16 SIDETRACK(C-23A) 05/18/03 N2ES SIDETRACK (C-236) 12/13/08 NORDIC 1 CTDSIDETRACK(C-23C) 12/19/08 ?/ PJC DRLG DRAFT CORRECTIONS PRUDHOE BAY UNff WELL: G23C PERMIT No: 2181700 API No: 50-029-20775-03 SEC 19, T11 N, R14E, 1316' FNL & 1030' FEL BP Exploration (Alaska) • g ...2 ~ ,..~ ~ A & , s ~a~ . __,.i ~.u F .~ ~ ~ 1 ~{~ _.. t t ~. .~ ~,.. F .... ~ tf ° ~, e S { S" 4 ~ ~ 1 j ! S S~ Y t t `1 ~ ~ t.~ ~ d .6 VV } ~ e ~,.~ fir', d,« '~. i,,f d kM,,~ St l ~f~ L.~ } ~..~ k_ E t ~~.~ 1._r Li ~~, s . d ~L z l.~ ~ 6 ALASSA OIL A1~TD GA5 COI~TSERQATIOI~T CObIl-IISSIOI~T John McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-23B d Sundry Number: 308-398 b 3 ~ Q Dear Mr. McMullen: 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, Daniel T. Seamount, Jr. Chair DATED this s day of November, 2008 Encl. - '~ , . (~ j ( (~ I ~ STATE OF ALASKA ~ ~~ '0~ `~' ,D~ ,'"; ACA OIL AND GAS CONSERVATION COMMISSION ~~ ~~~ ~'~ ~ APPLICATION FOR SUNDRY APPROVAL, ~~ 1 20 AAC 25.280 1. Type of Request: ®Abandon ~ ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension- ^Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development - ^ Exploratory 203-060 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20775-02-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU C-23B Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): _ (~y~ ADL 028305 - 65.6' Prudhoe Bay Field / Prudhoe Bay Pool t2. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10821' ~ 9025' ~ 10736' _ 9022' None 10723' a in L h i M Burs Ila S ru r I rf 294' -/" 2 4 7 I rm i 5 7 7 47 r n in r 91 7" 7 7 ' - 84 7240 1 i 16 41/ " 1 '-1 1'- 2 ' 7 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10119' - 10730' 8993' - 9022' 4-1/2", 12.6# L-80 9167' Packers and SSSV Type: 7" x 41/2" Baker'S-3' packer Packers and SSSV MD (ft): 9110' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: November 15, 2008 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Charles Reynolds, 564-5480 Printed Name John c t9t Title En ineerin Team Leader Prepared By Name/Number. Signature Phone 564-4711 Dat~~.~~ ~ Terrie Hubble, 564-4628 ' Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~„~OP Test ^ Mechanical Integrity Test ^ location Clearance Other: 3~~(~ ~S~ t"~\v~`~'a1.s ~ `~®~ ~=L,`\' Subsequent Form Required: ~~ ~' ~ / '' - ~ APPROVED BY ~ 0 r J A roved B : COMMISSIONER THE COMMISSION Date ~~~~. ~ _~ Form 10-403 Revised (36/2006 ~' Submit In Duplicate ~t _ ~ ~ • To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Charles Reynolds CTD Engineer Date: October 30, 2008 Re: C-23C Sundry Approval CC: Well File Sondra Stewman/Terrie Hubble by Sundry approval is requested to abandon perforations on well C-23. C-236 is a Zone 2A rig sidetrack drilled in May 2003. Initial production yielded a high initial gas rate, prompting a MCNL loggin run in 9/1/03. Temperature warm-backs were performed after the MCNL and no channel was seen. The MCNL indicated a gas under-run (an anomalously low GOC), causing the well to have little to no standoff to gas. An 18' Zone 2A lens was also identified. After a year of limited production time, 6' of the Z2A lens was shot but minimal production impact was observed. Two months later, a CIBP was set over the horizontal in order to produce only the Z2A lens. Both oil and gas rates dropped and the GOR remained high due to a low oil rate. C-236 remained shut-in for nearly three years before 5' adperfs and 3' reperfs in the Z2A lens were shot in May 2007 giving the well a month of on-time before it climbed above the marginal GOR. The well was cycled over the next few months with no healing observed. The CIBP was milled and pushed to bottom in February 2008 in order to access the horizontal 2A perforation interval because the 2A lens was no longer able to support the well on its own. Disappointingly, this well work also proved to be short-lived with C-236 reaching marginal GOR less than two weeks later. During the pre-CTD screening in April 2008, the well passed an MITIA to 3000 psi and passed an MITOA to 2000 psi. A caliper was run and indicated the tubing was in good condition. The well was then secured with a TTP set at 2185' MD and on 4/21/08 it had a passing PPPOT-T. REASON FOR SIDETRACK: C-236 currently exhibits no healing after cycling and is expected to have 0% on-time. Sidetracking from this well will enable production of Zone 2A reserves from within another portion of the reservoir that would otherwise remain at risk. It will also allow for a future sidetrack from the newly drilled lateral to recover other remaining reserves. Pre-Rig Work: (Scheduled to bon November 15, 2008) 1. MIT-IA, -OA 2. Pull TTP from 4-1/2" X Nipple @ 2,185' 3. Mill XN at 9,154' to 3.80" with left handed motor, mill. 4. Tag CIBP Debris, Verify Depth and attempt to push to bottom. 5. Drift to PBTD with dummy whipstock 6. PT MV, SV, WV 7. Bleed gas lift and production flowlines down to zero and blind flange. ~"'~ -~` 8. Remove well house, level pad ~ ~ ~ ~ ~~~~. Rig P&A and Sidetrack Operations: (Scheduled to begin on December 20, 2008 using Nordic rig 1) ~~ 1. MIRU Nordic Rig 1 2. NU 7-1/16" CT Drilling BOPE and test. 3. Set Baker throu h tubin whi k t 1 7 r d PBTD 4. Mill 3.8"" window through 4-1/2". 5. Drill turn and lateral section to 12,300'. 6. Run and cement a 3-3/16" x 2-7/8" L-80 liner string to 9900'. This will P&A the existing perforations. 7. Make a cleanout run with mill, motor and SWS GR-CNL logging tool. 8. Perforate well. 9. FP well to 2000' with diesel. 10. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 11. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run gas lift design. 4. POP Well TREE= s° WELLHEAD= McEVOY ACTUATOR = OTiS KB. ELEV = 61.4' BF. ELEV = 39.4' KOP = 8575' Max Angle = )0 ~ 10300' Datum MD = 9876' Datum TVD = 8800' SS ~-23B S NOTES: N~ ID = 3.81 IG (04!13/08) I 2822' I L-80, ID =12.347" H 2894' Minimum ID = 3.725" +~ 9154' 4-1/2" HES XN NIPPLE PERFORATION SUMMARY REF LOG: MM) GR ON 05/07/03 A NGLE A T TOP PERF: 71 ° ~ 10119' Note: Refer to Production 06 for hLstorical pert data SQE SPF INTERVAL OIxUSgz DATE 2-7/8" 6 10119 - 10127 C 05/10/07 2-7/8" 8 10124 -10130 C 02/27/04 2-1 /2" 4 10330 - 10730 C 05/17/03 GAS LIFT MA MORELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3020 3020 1 MMG•M OMY RK 0 05/30/03 5 3992 3989 11 MMG-M DMY RK 0 04/11/08 4 5788 5514 41 MMGM OMY RK 0 04/11 /OS 3 7123 6518 39 MMG•M DMY RK 0 05/17/03 2 8054 7267 34 MMGM DMY RK 0 05/17/03 1 9021 8094 19 KBG-2 DMY RK 0 05/17/03 8428' I~ 9-5/8"X7" BKR ZXP LNR TOP PKR Mt.LOUT WINDOW 8580' -8596' TOP OF WHIPSTOCK ~ 8b7b' a ¢sv -~ s I 9-5/8" CSC, a7#, L-8o, to = s.66r' I ~2-7l8" LNR, 8.4#, L-80, ID = 2.441" H 1' 7" LNR, 26p, L-80, .0383 bpf, O = 8.276" 9089' H 4-1/2" HES X N~, ID m 3.813" 9110' 7"X4-1/2" BKR S-3 PKR, ID = 3.875" 8133' 4-1/2" HES X NIP, ID = 3.813" 9154' 4-1/2" HES XN N~ O m 3.725" 9158' --{ 7" X 5" ZXP LNR TOP PKR \ ~ 816T - 4-1/2" WLEG, O = 3.958" 103b8' 4.1/2" LNR, 12.6#, L-~, .0152 bpf, ~ = 3.958" 9187' T' LNR, 28p, L-80, .0383 bpf, ~ = 6.276" 9; 4-1/2" LNR, 12.6", L-~, .0152 bpf, ID=3.958" 10723' CTI DATE REV BY COMMENTS DATE REV BY COMMENTS 09104/82 ORIGINAL COMPLETION 04/11/08 KSBRLH GLV GO 10/06/98 Rlti SIDETRACK (C-23A) 04/18/08 K.IB/TLH XX PLUG SET (04/13108) 05/18/03 JDM/KK RIt3 SIDETRACK (C-23B) 04/03/04 MJA/KAK SETCIBP 05/10/07 TEUPAG ADPERFS 42/13/08 SRB/TLH CIBP MILLED & PUSHED TO B 10820' CIBP MLLED 8 PUSHED TO TD (02/13!08) PRUDHOE BAY UNIT W£LL: G23B PERMT No: 2030600 API No: 50-029-20775-02 SEC 19, T11 N, R14E, 1315' SNL 8 1030' WEL BP t3cploratiort (Alaska) TREE _. WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = ^ratum TVD = -23C P imposed C TD S iiet2ack ~ s-s/e" w PKR H 2822' ~. 13-3/8" CSG, 72p, L-80, ID ~ 12.347" 2894' Minimum ID ~ 3.TZ5" ~ 9154' 4-1/Z" HES XN NIPPLE PERFORATION S1,11Vn1AA RY REF LOG: MWD GR ON 05/07/03 A NGLE A T TOP PERF: 71 ° ~ 10119' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpNSgz DATE 2-7/8" 8 10119 - 10127 ~ 05!10/07 2-7/8" 8 10124 - 10130 C 02/27/04 2-1/2" 4 10330- 10730 C 05/17/03 TOP OF WHIPSTOCK 8bT6' a pprox '8" CSG 47lt L-80 H] a H_fi81" ~dd~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3020 3020 1 MMG-M DMY RK 0 OS/30!03 5 3992 398.9 11 MMG•M DMY RK 0 04/11!08 4 5788 5514 41 MMG•M OMY RK 0 04/11!08 3 7123 6518 39 MN1AfrM OMY RK 0 05!17/03 2 8054 7267 34 MMGM DMY RK 0 05/17/03 1 9021 8094 19 KBG2 DMY RK 0 05/17/03 I 9-5/8"X7" BKR 2XP LNR TOP PKR I III ! . 'I l I ';-6; ;i O~ A~ 4-1/2" NES X NIP 10= NIP, ID mlled to = 3.80" LNR TOP PKR TBG, 12.88, L-80, .0152 bpf, O = 3.958" 7" LNR, 26~t, L-80, .0383 bpt, O = 6.278' Mill Window off Mechanical Depth T3 °~ Verified , L-80..0152 bpf, ID' 3.93! I 9187' l 9900' Top of Proposed 3-3/16" Liner TOL Top of Cement 11200' 3-3/16" X 2-718" XO 3-3116" x 2-7/8" L-80 Liner, Cen DATE REV BY COMMENTS OWTE REV BY COMMENTS 08/04182 ORIGINAL COMPLETION 04/11/08 KSB/TLH GLV GO 10/08196 RIG SIDETRACK (C-23A- 04!18/08 KJBlTLH XX PLUG SET (04/13/08) Oti/19/03 JDM/KK RIt3 SIDETRACK (C-238) 10/14/08 MSE CTD PROPOSED SIDETRACK 04/03/Q4 MJA/KAK SETCIBP 05/10/07 TELIPAG ADPERFS 02!13/08 SRB/TLH GBP MB.LED 8 PUSHED TO B SA NOTES: I 4-112" HFS X NIP, ID ~ 3.813" I PRUDHOE BAY UNIT WELL: G23C PERMIT No: API No: 50-029-20775-03 EC 19, T11 N, R14E, 1315' SNL 8 103C BP Expbration (Alaska) • Page 1 of 1 Maunder, Thomas E (DOA) From: Preble, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Monday, February 25, 2008 1:54 PM To: Maunder, Thomas E {DOA) Subject: RE: 404 questions O ~,, ~ ~ V Tom, ~ - -~@" C-23B was a mill only. The pert was marked incorrectly. No perfs were shot. I need to check out Y-24 to see what the status is on that patch. Gary Preb/e Petro%um Dato Management Engineer SAZ"C 907-564-4944 preblegbG~bp. com ~~lr~l FED 2(~G~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent; Monday, February 25, 2008 12:46 PM To: Preble, Gary B (SAiC) Subject: 404 questions Gary, I am reviewing some recently submifted 404s and have some questions PBU Y-24 186-113 This relates to the patch operation of mid February. On 2112, the lower packer was set. Are there continuing operations to set the actual patch pipe and the upper packer? .._~ PBU C-23B 203-060 The 'information provided relates to milling out the CIBP. Perforating is also checked, but there are not details. Were perfs shot? Thanks in advance. Email is fine for any additional operational summaries. Tom Maunder, PE AOGCC 2J25/2008 ^d STATE OF ALASKA ~~~~~~~ `~'"~ ALA~A OIL AND GAS CONSERVATION COMMISSION 1~G~C1 ~ G~ FHB ~ ~ ~~Q~ REPORT OF SUNDRY WELL OPERATION~~aska ~'~'~ ~~~ Cons, Comm~~x~An 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other ~ LLED OUT Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ ~:ferdr~lJ {\, Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: ~~22M01- 5. Permit to Drill Number: Name: Development Exploratory 203-0600' 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: ,. Anchorage, AK 99519-6612 50-029-20775-02-00 7. KB Elevation (ft): 9. Well Name and Number: 65.6 KB PBU C-23B ~ 8. Property Designation: 10. Field/Pool(s): f ADLO-028305' PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10821' ~ feet Plugs (measured) NONE true vertical 9025' ~ feet Junk (measured) 10723 Effective Depth measured 10140' feet true vertical 9000' feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 26 - 106 26 - 106 1490 470 Production 8556 9-5/8" 47# L-80 24 - 8580 24 - 7699 6870 4760 Surface 2663 13-3/8" 72# L-80 25 - 2688 25 - 2688 4930 2670 Liner 21 9-5/8" 47# L-80 8426 - 8447 7575 - 7592 6870 4760 Liner 897 7" 26# L-80 8447 - 9344 7592 - 8400 7240 5410 Liner 21 7" 26# L-80 9156 - 9177 8221 - 8241 7240 5410 Liner 1643 4-1 /2" 12.6# L-80 9177 - 10820 8241 - 9025 8430 7500 Perforation depth: Measured depth: 101 19 - 10730 _ _ True Vertical depth: 8993 - 9022 _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 28' - 9167' Packers and SSSV (type and measured depth) 9-5/8" DV Packer 2616 9-5/8" Baker ZXP Packer 8434 4-1/2" Baker S-3 Perm Packer 9110 4-1/2" Baker ZXP Packer 9164 12. Stimulation or cement squeeze summary: Intervals treated (measured): f i-~=~3 ~ ;_ l~~~S Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 183 18561 1 0 328 Subsequent to operation: SHUT IN 0 0 0 0 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory Development ~" Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~' ; GINJ ~' WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary P bl Title Data Management Engineer Signature Phone 564-4944 Date 2/18/2008 Form 10-404 Revi d 04/2006 _ / Submit Original Only 5 s • C-23B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 2/12/2008 2/13/2008 CTU #6, Mill CIBP; MIRU CTU #6 w/ 1.75" OD CT. Load well with 150 bbls KGL to 'reduce WHP. RIH with Baker 2 7/8" Xtreme PDM w/ 3.70" - 5 Blade concave junk mill. Tagged CIBP at 10129' ctmd. Begin milling on CIBP. Cont' on WSR 2/13/08 CTU #6, Mill CIBP; Cont' from WSR 2/12/08 ... Milling on CIBP at 10127 ctmd._ Lost all circulation when plug broke free. Milled and pushed plug to bottom at 10723' ctmd. POOH. FP well to 2500' with 60/40 methanol. Well left shut in. Notified Pad Operator. RD CTU #6. *** Job Complete *** NOTE: Caution should be taken when entering liner because of possible CIBP debris. FLUIDS PUMPED BBLS 389 1 % KCL 82 60/40 METH 471 TOTAL • • -.o. r~~ F . - "-': ~.. MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_Inserts~Microfilm Marker.doc ~.;.;:.¡, '1 K'" L... V I- I V ......., STATE OF ALASKA ALA~ OIL AND GAS CONSERVATION COM~~ION k- MAY 2 1 2007 REPORT OF SUNDRY WELL OPERATIONS 1\...1.')1,.1~?(. &G C C .. n í}t~aJiL as ons_ ommlss on 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 'Oilier U Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Anchorage Change Approved Program D Operat. Shutdown D Perforate 0 Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development P Exploratory 203-0600 or 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-20775-02-00 '" 7. KB Elevation (ft): 9. Well Name and Number: 65.6 KB 8. Property Designation: ADLO-028305 ~ 11. Present Well Condition Summary: Total Depth measured true vertical 1 0821' / 9025' ~ Effective Depth measured true vertical 10140' 9000' Casing Conductor Production Surface Liner Liner Liner Liner Perforation depth: Length Size 80 20" 91.5# H-40 8556 9-5/8" 47# L-80 2663 13-3/8" 72# L-80 21 9-5/8" 47# L-80 897 7" 26# L-80 21 7" 26# L-80 1643 4-1/2" 12.6# L-80 Measured depth: 10119 - 10730 True Vertical depth: 8993 - 9022 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl SHUT IN SHUT IN x Contact Gary Preble PBU C-23B ... 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool feet feet Plugs (measured) Junk (measured) Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 000 000 15. Well Class after oroposed work: Exploratory Development lVI' 16. Well Status after proposed work: Oil P' Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. feet feet MD 26 - 106 24 - 8580 25 - 2688 8426 - 8447 8447 - 9344 9156 - 9177 9177 - 10820 TVD 26 - 1 06 24 - 7699 25 - 2688 7575 - 7592 7592 - 8400 8221 - 8241 8241 - 9025 - - 4-1/2" 12.6# L-80 9-5/8" DV Packer 9-5/8" Baker ZXP Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer SCANNED MAY 2'2 2007 10140 None Burst 1490 6870 4930 6870 7240 7240 8430 Collapse 470 4760 2670 4760 5410 5410 7500 28' - 9167' 2616 8434 9110 9164 Tubing pressure o o Service GINJ W DS PL Sundry Number or N/A if C.O. Exempt: WINJ Printed Name Gary pre;: /7 ~. / / Signature "Kky ø/ I" !: _ - Form 10-404 R~d 04/2006 n D , ~ 11\' ^ Title Data Management Engineer Phone 564-4944 Date 5/16/2007 RBDMS BFL MAY 2 2 1007 Submit Original Only "~ C-23B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 5/912007 WELL SHUT IN ON ARRIVAL. INITIAL TI 110 = 100/60010. PERFORATED FROM 10119' - 10127' USING A 2.8811 HSD 2906 PJ OMEGA GUN. ALL SHOTS DETONATED. TD TAGGED AT 10140'. JOB COMPLETE. FINAL TI 110 = 0/60010. WELL LEFT SHUT IN. TURNED OVER TO DSO. *** Job complete*** FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL · WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13, 2006 RE: MWD Formation Evaluation Logs: C-23B, C-41A_PBI, D-27A, G-30B, 1-27A, K-04B. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 C-23B: £>03 -ó<oo t± I t.../L/i../ / Digital Log Images: 50-029-20775-02 1 CD Rom C-41A PBl: 6JOt.I-/~'6 11 1~t.ILI3 Digital Log Images: 50-029-22385-01, 70 D-27A: tìOS--¡'ì3 -tt iL.ILILID~EDFEB C 1 2007 Digital Log Images: 50-029-21543-00 G-30B: döS--8ö'ð n 14L13'ì Digital Log Images: 50-029-21613-02 1-27 A:;)b d -dOO tt: /.../L/3'D Digital Log Images: 50-029-21733-01 K-04B: dö8 -QS3 -:P ¡4¿/L!d. Digital Log Images: 50-029-21023-02 1 CD Rom I CD Rom I CD Rom 1 CD Rom 1 CD Rom -::¡- e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard OkJand 333 West 7th Avenue, Suite 100 Anchorage, Alaska 9950 I February 25, 2004 /OLr.z:A RE: MWD Formation Evaluation Logs: C-23B, AK-MW-2431379 C-23B: Digital Log Images: 50-029-20775-02 ;rD0~OlfJO I CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ? Date~IjIOifl Signe'¿¡Jfl~p I r ~, ) J '8 J v~ DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 ~ lL.J (G "1~) ~J API No. 50-029-20775-02-00 Permit to Drill 2030600 Well Name/No. PRUDHOE BAY UNIT C-23B Operator BP EXPLORATION (ALASKA) INC MD 10821 r- TVD9006 ~ Completion Date 5/18/200~ Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION ------ --- Mud Log No Samples No Directional Survey Yes ------ -- - DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES, ABI, DEN, NEU Well Log Information: Log/ Electr Data Digital Dataset ,IYPJr,TYP "Med/Frmt Number Name ~ D 11808 IdS VQrific,tinn, ---- --- (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No b~ t \..~ v1-."l cwt7 St.. ß ~tJ yð 3 Interval OH/ Start Stop CH Received Comments ---- 8342 10757 Open 7/24/2003 8342 10757 Open 7/24/2003 8494 10821 Open 6/2/2003 MWD j Rpt i i~ Asc ~/D LIS Verification Directional Survey 3 Final Asc Directional Survey Production Final 8494 1 0821 Open 6/2/2003 ¡f1:.og / ! 2 Blu 7970 10720 Case 10/8/2003 Memory Production Profile & Injection Profile - Memory GRlCCLfT emp/Pres/Spin 7970 10720 Case 10/8/2003 Memory Production Profile & Injection Profile - Memory GRlCCLfTemp/Pres/Spin 7970 10720 Case 10/8/2003 Memory Production Profile & Injection Profile - Memory GRlCCLfTemp/Pres/Spin 7970 10720 Case 10/8/2003 Memory Production Profile & Injection Profile - Memory GRlCCLfT emp/Pres/Spin 7970 10720 Case 10/8/2003 Memory Production Profile & Injection Profile - Memory GRlCCLfTemp/Pres/Spin ¡ ! Log Injection Profile 2 Blu i e-/i Log Casing collar locator 2 Blu Log Temperature 2 Blu Log Pressure 2 Blu ----------- -- - ~7 DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Permit to Drill 2030600 Well Name/No. PRUDHOE BAY UNIT C-23B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20775-02-00 L/ 10821 TVD 9006 Completion Date 5/18/2003 Completion Status 1-01L Current Status 1-01L UIC N ~, Log --_._-~-- - Spinner 2 Blu 7970 1 0720 Case 10/8/2003 Memory Production Profile & Injection Profile - V Memory GRlCCL/T emp/Pres/Spin Pressure 9000 10170 Case 5/3/2004 STATIC BOTTOM HOLE PRESS- TEMP-GR-CCL ¡(go C Pds 12830 Neutron 7970 1 0720 Case 11/6/2004 COMP NEUTRON/MEM ~- ~" GRlCCUCNL 12830 Neutron Blu 7970 1 0720 Case 11/6/2004 COMP NEUTRON/MEM GRlCCUCNL ------- -- Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ..y /t~ Daily History Received? r"\, ~N ð/N Formation Tops Analysis Received? 'Y IN ~. --------~ ----"-- -- ---- - Comments: ~ ) I J w~ ~-)c== Compliance Reviewed By: Date: Schlumberger . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth rr,-/3J I' "' ~p/t)1L5-15 ì -(~5 S-06 ~- I">(¡, W-30 03.-áliC-23B ,'I..(}tß-39A F-11A .. -'D~t 15-25A , .oj(, 15-09A fj-ß' NGI-11 '7 -fRO J&:~* t Well Job# 10831305 10913848 10621828 10866597 10558571 10715430 10893034 10715429 10889178 10912989 Log Description LEAK DETECTION LOG SBHP SURVEY INJECTION PROFILE PPROFILE WIDEFTlGHOST MCNL SCMT SCMT SCMT SCMT USIT Date 07/05/04 09/26/04 10/01/04 09/26/04 09/01/03 09/13/04 09/16/04 09/12/04 10/17/04 10/26/04 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Irf;~~¥ Blueline 1 1 1 1 1 ~ (-) ~(. 3 "- 010'0 11/05/04 NO. 3252 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ~c Color Prints CD 1 ~-- ~ STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Suspend 0 RepairWellD Pull Tubing D Operation Shutdown D Plug Perforations[&] Perforate New PoolD 4. Current Well Class: Perforate 0 WaiverD Stimulate D Time ExtensionD Re-enter Suspended Well 0 5. Permit to Drill Number: 203-0600 OtherD Name: BP Exploration (Alaska), Inc. 3. Address: P.o. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Development [&] ExploratoryD 65.60 8. Property Designation: ADL-0028305 11. Present Well Condition Summary: Stratigraphic 0 ServiceD 9. Well Name and Number: C-23B 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 6. API Number 50-029-20775-02-00 Total Depth measured 10821 feet true vertical 9025.5 feet Plugs (measured) 10140 Effective Depth measured 10140 feet Junk (measured) None true vertical 8999.6 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 26 106 26.0 - 106.0 1490 470 Liner 21 9-5/8" 47# L-80 8426 - 8447 7574.6 - 7591.6 6870 4760 Liner 897 7" 26# L-80 8447 - 9344 7591.6 - 8400.1 7240 5410 Liner 21 7" 26# L-80 9156 - 9177 8221.4 - 8241.3 7240 5410 Liner 1643 4-1/2" 12.6# L-80 9177 - 10820 8241.3 - 9025.4 8430 7500 Production 8556 9-5/8" 47# L-80 24 - 8580 24.0 - 7698.5 6870 4760 Surface 2663 13-3/8" 72# L-80 25 - 2688 25.0 - 2687.9 4930 2670 Perforation depth: Measured depth: 10124 -10130 Packers & SSSV (type & measured depth): 7" 26# L-80 @ 24 28 4-1/2" 12.6# L-80 @ 28 9167 4-1/2" Baker S-3 Perm Packer @ 9110 4-1/2" Baker ZXP Packer @ 9164 9-5/8" Baker ZXP Packer @ 8434 9-5/8" DV Packer @ 2616 RECEIVED APR 2 8 2004 Alaska Oil & Gas Cons. Commission Anchorage True vertical depth: 8994.63 - 8974.64 Tubing ( size, grade, and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Prior to well operation: 780 35.7 9 1000 Subsequent to operation: 391 13.5 11 1000 Tubing Pressure 1781 756 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development ŒJ Service D Copies of Logs and Surveys run_ 16. Well Status after proposed work: Operational Shutdown D OilŒ] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations, ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron ~9I~ ~ Title Production Technical Assistant Date 4/21/04 APR 2 '7 19,9~ Signature Form 10-404 Revised 12/2003 O~IG!~JOÃC~8ft ~, ( C-238 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/03/04 Drift to 10171' with 3.611 Centralizer. Set Baker K-1 CIBP @ 10140' FLUIDS PUMPED BBlS No Fluids Pumped o TOTAl Page 1 , (' STATE OF ALASKA ¡ ALASKA OIL AND GAS CONSERVATION co~....dSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D 2. Operator Suspend 0 RepairWellD Pull Tubing D Operation Shutdown 0 Plug PerforationsD Perforate New PoolD 4. Current Well Class: Perforate ŒJ WaiverD Stimulate D Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 203-0600 OtherD Name: BP Exploration (Alaska), Inc. Development 00 ExploratoryD Stratigraphic 0 ServiceD 9. Well Name and Number: C-23B 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 6. API Number 50-029-20775-02-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 65.60 8. Property Designation: ADL-0028305 11. Present Well Condition Summary: Total Depth measured 10821 feet true vertical 9025.5 feet Effective Depth measured 10736 feet true vertical 9022.0 feet Casing Conductor Liner Liner Liner Liner Production Surface Perforation depth: Measured depth: 10124 -10130,10330 -10730 Length 80 21 897 21 1643 8556 2663 Size 20" 91.5# H-40 9-5/8" 47# L-80 7" 26# L-80 7" 26# L-80 4-1/2" 12.6# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 Plugs (measured) None Junk (measured) None MD TVD Burst Collapse 26 106 26.0 106.0 1490 470 8426 - 8447 7574.6 7591.6 6870 4760 8447 - 9344 7591.6 8400.1 7240 5410 9156 - 9177 8221.4 8241.3 7240 5410 9177 - 10820 8241.3 9025.4 8430 7500 24 - 8580 24.0 - 7698.5 6870 4760 25 - 2688 25.0 - 2687.9 4930 2670 True vertical depth: 8994.63 - 8996.53,9020.16 - 9021.75 Tubing ( size, grade, and measured depth): 7" 26# L-80 @ 4-1/2" 12.6# L-80 @ Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 9-5/8" Baker ZXP Packer 9-5/8" DV Packer 24 28 28 9167 Gþ 1. ~~) @ 9110 @ 9164 @ 8434 @ 2616 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS 8FL APR 0 13 Representative Daily Average Production or Injection Data Qil-Bbl Gas-Mef Water-Bbl Casing Pressure Prior to well operation: 835 37.1 9 2150 Daily Report of Well Operations. ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature .lJ~ cætr~ Form 10-404 Revisg 12/2003 Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run_ lOO%" 701 Tubing Pressure 1635 1786 9 1020 35.5 15. Well Class after proposed work: Exploratory D DevelopmentŒ] Service D 16. Well Status after proposed work: Operational Shutdown D Oil 00 GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Title Production Technical Assistant Phone 564-4657 ORiGiNAL Date 3/30/04 l' { ( C-238 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 02/27/04 Perforate 101241-1013016 SPF w/2-7/8" HSD @ 6 SPF. Charges == 2906 Powerjets. Tied into SWS Memory CNL dated 1-Sept-2003. Did not tag. 02/28/04 TIIIO = SSV/107010, TEMP = SI. IA FL AND BLEED FOR PAD OPERATOR. OPERATOR REPORTED THAT lAP WAS 1400 PSI WHEN WELL WAS POPPED. lAP INCREASED TO 2750 PSI WHILE HE WAS IN THE MANIFOLD BUILDING (5 MINUTES). HE SHUT THE WELL IN AT THE SSV AND THE lAP HAD INCREASED TO 3150 PSI. HE BLED THE IA FROM 3150 PSI TO 2600 PSI IN 30 MINUTES. REPLACED BAD GAUGE -lAP 1070 PSI. IA FL @ 57351. INFORMED OPERATOR AND CONTINUED BLEEDING. OPERATOR RETURNED TO PUT WELL ON PRODUCTION. BLED IA FROM 1070 PSI TO 950 PSI IN 30 MINUTES. MONITORED WHPS 30 MINUTES AFTER WELL WAS PUT ON PRODUCTION. FINAL WHPS = 2400/102010, TEMP = 42 deg F FLUIDS PUMPED BBLS No Fluids Pumped o ITOTAL Page 1 ( ~' TREE = WELLHEAD = AClUATOR= KB. ELEV = BF. B...EV = KÒP= .. fv1ax Angle = Datum rvo = Datum lVD= 6" Mc EV OY 011S 61.4' 39.4' 8575' 90 @ 10300' 9876' 8800' SS C-23B SAÆTY NOTES: I I 2185' H 4-1/2" HES X NIP, ID = 3.813" I I 9-518" DV PKR H 2622' ~= Minimum ID = 3.725" @ 9154' 4-1/2" HES XN NIPPLE GAS LIFT MANDRELS ~ ST MD TVD DEV TYPE VLV LATa; FORT DATE 6 3020 3020 0 MtvX3-M DMY RK 05/30/03 L 5 3992 3989 11 MtvX3-M DOME RK 16 05/30/03 4 5788 5513 41 MtvX3-M SO RK 20 05/30/03 - 3 7123 6517 39 MtvX3-M DMY RK 05/17/03 2 8054 7266 34 MtvX3-M DMY RK 05/17/03 1 9021 8042 38 KBG-2 DMY RK 05/17/03 113-318" CSG, 72#, L-80, ID = 12.347" H 2694' µ PffiFORA TION SUMv1ARY RS= LOG: MJVD GR ON 05/07103 ANGLEATTOPPffiF: 71 @ 10124' I'bte: Refer to Production OB for historical perf data SIZE SPF INTERV AL OpnlSqz DA 1£ 2-7/8" 6 10124 - 10130 0 02127/04 2-1/2" 4 10330 - 10730 0 05/17/03 z &----f 8426' l-r 9-5/8" X 7" BKR ZXP LNR TOP PKR I MLLOUT WINOOW 8580' - 8596' 1 TOPOFWHIPSTOO< 1-18575' approx~ 9-5/8" CSG, 47#, L-80, 10 = 8.681" H 9442' t----' ~ H 4-1/2" HES X NIP, 10 = 3,813" 9110' 1-1 7" X 4-1/2" BKR S-3 A<R, 10 = 3.875" I 9133' 1-1 ~1/2" HESX NIP, D =3.813" I 1-1 4-1/2" HES XN NP, 10 = 3.725" 1 9156' 1-1 7" X 5" ZXP LNR TOP PKR 1 9167' 1-14-112" WLEG, 10 = 3.958" 1 1 EZSV I" 8608' I I 12-7/8ILNR,6.4#,L-80,.0058bPf,10=2.441" 1-1 11662' 1 .~_ 4-1/2" LNR, 12.6#, L-80, -I 9167' ~.0152bPf.ID=3.95g, 7" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" 1-1 10358' I 1 7" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" 1-1 4-1/2" LNR, 12.6", L-80, .0152 bpf, 10 = 3.958" I H 10820' OATE 09/04/82 10/06/96 05/19/03 05/30/03 07/03/03 09/15/03 REV BY COMMENTS DA 1£ REV BY COMrvENTS ORIGINAL COMPLETION 02127/04 MJA/1LP ADD ÆRF RIG SIŒTRACK (C-23A) JDM/KK RIG SIŒTRACK (C-23B) CA O/KK GL V C/O CMO/TLP KB B...EVA 110N CORRECll0N CMO/TLP DA lUM MD'TVO, REF LOG/PERF FRLDHOE BA Y UNIT WELL: C-23B PERMIT No: 2030600 AA No: 50-029-20775-02 SEC19,T11N, R14E, 1315'SNL& 1030'WEL BP Exploration (Alaska) Schlumbergep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well P2-11 I ~-I~ ~/ GNI-01 -é)~ D.S. 13-271 Jio '"lbt \.:- D.S.6-21A ' ~() D.S.14-32 B <~.., ~~ C-23B ~ ~'~ -()(o() f-13A 1 lõ'-L~~ f-11A ~m--(')lo~ ~ ,.:~~:~~. go3-'~T ~ MPS-20 ~ðL\ \ Job# Log Description Date SBH TEMP & PRESSURE SURVEY TEMP & PRESS SURVEY LDL LDL LDL MEM PPROf & IPROf LOG MEM PPROf & IPROf LOG MEM PPROf & IPROf LOG INJECTION PROfiLE 10559234 CH EDIT SCMT (PDC) 10559234 SCMT 10/03/07 10/04/03 10/01/07 10/01/03 10/03/03 09/01/03 09/08/03 09/09/03 10/04/03 03/03/03 03/03/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: R~~'<Y\~ :;;=''''F"''C' ~I'\ J-J=~' ~~=: J:F~V L:U ~ ~,~- ~!.I ÎI ,,-,.. (\ n ?nn~, \..I\" t ...., u '_~'v- ÞJaska O~-i & Gas Cons. C:ommissfar1 hîchor~-ge Blueline NO. 2984 10/07/03 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 Color Prints 1 1 1 1 1 1 1 1 1 2 ~- CD ~\ ") ()~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage. AK 99503-5711 ATTN: Beth Received~~~C~~ ( { ~3-~ (( ßb'ß WELL LOG TRANSMfITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska June 04, 2003 RE: MWD Fonnation Evaluation Logs C-23B, AK-MW-2431379 1 LDWG fonnatted Disc with verification listing. llPI#: 50-029-20775-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish :ii~Qj) JUL 24 2003 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~_ort & Gas Cons. Commis8ion . Anchorage Signed: ~Q STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ( Q' t 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1315' SNL, 1030' WEL, SEC. 19, T11N, R14E, UM At top of productive interval 4813'SNL, 1817'WEL, SEC. 19, T11N, R14E, UM X=663651, Y=5956389 10. Well Number At total depth 206' SNL, 1875' WEL, SEC. 30, T11 N, R14E, UM X = 663610, Y = 5955716 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Prudhoe Bay Pool KBE = 61.4' ADL 028305 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 5/10/2003 5/14/2003 5/18/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 10821, 90G6' FT 10736 9003 FT 181 Yes 0 No 22. Type EI~ric o?£ther Logs Run MWD, DIR, GR, RES, ABI, DEN, NEU 23. CASING SIZE 20" X 30" 13-3/8" 9-5/8" Classification of Service Well 7. Permit Number 203-060 8. API Number 50- 029-20775-02 9. Unit or Lease Name X = 664349, Y = 5959903 Prudhoe Bay Unit C-23B 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2185' MD 1900' (Approx.) WT. PER FT. Insulated 72# 47# 26# 12.6# GRADE Conductor L-80 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 801 36" Surface 2694' 17-1/2" Surface 8580' 12-1/4" 8426' 93441 8-1/2" 91561 10820' 6-1/8" CEMENTING RECORD 8 cu yds Concrete 3720 cu ft Arctic Set II 1282 cu ft Class 'G', 130 cu ft AS I 253 cu ft Class 'G' 247 cu ft Class 'G' AMOUNT PULLED 7" 4-1/2" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 4 spf MD TVD 10330' - 10730' 8981' - 9002' 25. SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 9167' PACKER SET (MD) 9110' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze protect with 155 Bbls Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 13, 2003 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE 6/13/2003 4 TEST PERIOD 2,724 33,823 32 960 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OIL GRAVITy-API (CORR) Press. 660 24-HoUR RATE 26.7 28. CORE DATA i::t'rm\fEf' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SuR(Q(kI¡ri~ ~ J n. ,^,,) GAS-OIL RATIO 12,419 No core samples were taken. JUN 1 8 2003 ,......,....,-.-._.,-..."...._.,.,,..,.'"~........,. 1_¿J}ýo3_ t t V5ß.xIED ~. t,~:~·:::.:J A\ask~ Oi~ &~ Anchorage Gm~s" Cor¡"¡ir¡i~;~;i(¡m BIli$ Afl JUN 1 9 20a3 Form 10-407 Rev.~ ~-01-80 " ORIGINAL Submit In Duplicate ( 29. Geologic Markers Marker Name Measured Depth Sag River 9345' Shublik 9381' Sadlerochit 9466' Zone 31 Top CGL 9692' Zone 2C I Base CGL 9750' Zone 2Bu / 23SB 9825' Zone 2BII 22TS 9900' 21P 10140' 31. List of Attachments: ( 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 8305' 8335' 8407' 8601' 8652' 8718' 8785' 8955' OJ>E"""'C"" E' l~\fE.'''·~·[', ." ~ " ~",""" ;, "",,/I' '. .'"",, M \," "'''''''''''''''''''~ JUN 1. 8 2003 A11:113!Œ Summary of Daily Drilling Reports, Surveys 32. I ~erebY certify that the for,oin~ is true and correct to the best of my knowledge Signed TerrieHubble ~QMlR- ~~ Title Technical Assistant Date 00"'/7·D 3 C-23B 203-060 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Rob Tirpack, 564-4166 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 µîOducing 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 (OF, 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 ()RIGINAL Legal Name: C-23 Common Name: C-23 Test Date 5/9/2003 5/13/2003 Test Depth (TMP) 8,580.0 (ft) 9,344.0 (ft) TestType FIT FIT BPEXPLORATION Leak~OffTestSummary Test Depth. (TVD) 7,700.0 (ft) 8,401.0 (ft) AMW 10.70 (ppg) 8.50 (ppg) SuñacePressure 520 (psi) 500 (psi) Leak Off Pressure (BHP) 4,800 (psi) 4,210 (psi) Page 1 of 1 EMW 12.00 (ppg) 9.65 (ppg) Printed: 5/19/2003 10:39:08 AM (" ( BP EXPLORATION Operations Summary Report Page 1 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-23 C-23 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 5/6/2003 Rig Release: 5/18/2003 Rig Number: 2ES Spud Date: End: Date From - To Hours Task Code NPT Phase Description of Operations 5/512003 19:00 - 00:00 5.00 MOB P PRE Move shop, camp and pit module to C-Pad. Layover derrick for rig move. Change out Iron roughneck. 5/6/2003 00:00 - 01 :00 1.00 MOB P PRE cia iron roughneck with Peak crane. 01 :00 - 07:30 6.50 MOB P PRE Move substructure from DS 13 to C-pad. 07:30 - 09:00 1.50 RIGU P PRE Lay Herculite, spot sub base, raise derrick. 09:00 - 11 :00 2,00 RIGU P PRE Spot shop, pits, and camp. 11 :00 - 13:00 2.00 RIGU P PRE RlU floor, bridle down, 13:00 - 14:00 1.00 RIGU P PRE Take on sea water. Tubing pressure 40 psi, OA 0 psi, IA 0 psi. Rig accepted at 13:00 hours, 05/06/2003. 14:00 - 14:30 0.50 RIGU P DECaMP Pre Spud safety meeting with all personnel. 14:30 - 16:00 1.50 RIGU P DECaMP R/U DSM to pull BPV with lubricator. 40 psi on tubing. Attempted to shut master valve and bleed gas. Would not shut . Grease valve. Shut master valve. Bleed gas. RID DSM lubricator. 16:00 - 17:30 1.50 RIGU P DECaMP R/U circulating lines and test to 3,500 psi. Swab valve on tree would not open. Stem was pressure locked. PJSM with Cameron hand. Bleed trapped pressure from valve stem. open swab valve. 17:30 - 20:30 3.00 WHSUR P DECaMP Displace diesel from tubing, with sea water. Pump 50 bbl Condet sweep. Displace diesel from annulus. Circulate sweep to surface. Tubing pressure 0 psi, annulus pressure 0 psi. 20:30 - 21 :00 0.50 WHSUR P DECaMP Install TWC and check from below to 1,000 psi. 21 :00 - 21 :30 0.50 WHSUR P DECaMP Blow down surface equipment and RID circulating lines. 21 :30 - 23:00 1.50 WHSUR P DECaMP NID tree and adapter flange. 23:00 - 00:00 1.00 BOPSURP DECaMP N/U BOPE. 5/7/2003 00:00 - 01 :30 1.50 BOPSUR P DECaMP N/U BOPE. 01 :30 - 02:00 0.50 BOPSURP DECaMP R/U test equipment 02:00 - 06:00 4.00 BOPSURP DECaMP Test BOPE and all related valves to 250 psi low and 3,500 psi high. Witness of test waived by John Crisp of the AOGCC. 06:00 - 07:00 1.00 WHSUR P DECaMP RlU DSM and pull TWC. 07:00 - 08:00 1.00 WHSUR P DECaMP M/U landing joint, BOLDS, pull hanger to floor. Pulled free with 310K. Up weight 210 K. 08:00 - 09:00 1,00 PULL P DECaMP LID landing joint and hanger. R/U 5 1/2" casing equipment and spooling unit. 09:00 - 12:00 3.00 PULL P DECaMP LID 51/2",17#, L-80 tubing to 7,250'. The first 7 joints pulled required 21 OK - 180K up weight. On eighth joint, up weight spiked to 235K, then fell back to 170K. No further overpull. Recovered SSSV, 2 SS bands, 24 clamps with pins. 12:00 - 18:00 6.00 PULL P DECaMP LID 5 1/2" tubing from 7,250'. PJSM at cut joint( #197). Joint was cut 3/4" of the way through. LID joints #197 to #202. 18:00 - 21 :00 3.00 PULL P DECaMP Had trouble breaking joint #203. High torque after initial break. The threads were jumping, but without seperation, This connection was at the top of the upper pup joint on the sliding sleeve assembly. Determined the 5 1/2" X 3 1/2" liner top packer I hanger was set just above this connection. 21 :00 - 21 :30 0.50 PULL P DECaMP Remake the connection. P/U past the sliding sleeve. Break out the connection at the base of the lower pup joint on the SS assembly. P/U and confirm 2 7/8" liner suspended in 5 1/2". 21 :30 - 23:30 2.00 PULL P DECaMP Call for and R/U 2 7/8" handling equipment and false rotary table. PJSM regarding handling 2 7/8" with false rotary. 23:30 - 00:00 0.50 PULL P DECaMP Break the 2 7/8", 6.4#, L-80, STL liner at first available connection. No 1 3/4" coil tubing found inside. Cut 2 7/8" stub Printed: 5/19/2003 10:39:17 AM ( ~' BP EXPLORATION Operations Summary Report Page 2 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-23 C-23 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 5/6/2003 Rig Release: 5/18/2003 Rig Number: 2ES Spud Date: End: Date From - To Hours Task Code NPT Phase Description of Operations 5/7/2003 23:30 - 00:00 0.50 PULL P DECOMP remaining below sliding sleeve and LID same. Cut the 5 1/201 tubing just above the 5 1/201 X 3 1/201 hanger I packer. 'GS' fishing tool found at the top of the 27/801 liner hanger. LID sliding sleeve assembly and 5 1/201 tubing stub. 5/8/2003 00:00 - 01 :00 1.00 PULL P DECOMP Pull and LID 9 joints of 27/801,6.4#, L-80, STL liner. Beginning with third joint, about half of each joint was covered with thin sheaths of cement. The eighth and ninth joint were fairly corroded on the outside. The box of the tenth joint was all that came with the pin end of the last joint pulled. Approximately 310' of 2 7/801 liner recovered. 01 :00 - 01 :30 0.50 PULL P DECOMP Pulled and LID the final joint of 5 1/201 tubing and the PBR seal assembly. 01 :30 - 02:00 0,50 PULL P DECOMP RID casing equipment and clear rig floor. 02:00 - 03:30 1.50 BOPSUR P DECOMP R/U test equipment and test lower pipe rams and Hydril to 250 psi low and 3,500 psi high. Install wear bushing, RID landing joint. 03:30 - 04:30 1.00 EVAL P DECOMP PJSM. R/U Schlumberger for E-line run. 04:30 - 08:30 4.00 EVAL P DECOMP RIH with E-line GR/JB/CCLto 8,666' (GR 8.5001), POH. 08:30 - 09:30 1.00 EVAL N WAIT DECOMP Wait on Schlumberger. Bad 308 ignitors. Hot shot new ignitors to location. 09:30 - 10:00 0.50 EVAL P DECOMP M/U SWS firing head and EZSV. 10:00 - 14:00 4.00 EVAL P DECOMP RIH with EZSV on e-line. Log into position 4' above collar, set EZSV at 8,608' (ELM). Attempt to release from EZSV, Pull from cable head. POOH with e-line. RID SWS. 14:00 -17:00 3.00 FISH N DFAL DECOMP P/U and M/U fishing assembly to 861'. 17:00 - 22:00 5.00 FISH N DFAL DECOMP RIH P/U drill pipe from 861' to 8,555'. P/U weight 200K, S/O weight 155K. 22:00 - 22:30 0.50 FISH N DFAL DECOMP Wash down at 60 spm and 180 psi. Tag at 8,585'. Pressure increase to -400 psi. Slack off 8', take 20K weight.P/U to 225K (25K overpull), bleed jars. P/U to 235K, pull free. Pumps on to 20 spm and 380 psi. Confirm catch. 22:30 - 23:00 0.50 FISH N DFAL DECOMP Drop dart to open circ sub. Pump to shear open. Blow down surface equipment. 23:00 - 00:00 1.00 FISH N DFAL DECOMP POOH with drill pipe to 5,995'. 5/9/2003 00:00 - 02:00 2.00 FISH N DFAL DECOMP POOH from 5,995' to 861' with drill pipe. 02:00 - 03:00 1.00 FISH N DFAL DECOMP C/O handling equipment, stand back collars, Handle BHA. Recovered all of fish. 03:00 - 04:00 1.00 FISH N DFAL DECOMP Break out and LID fish and overshot. Clear rig floor. 04:00 - 05:00 1.00 EVAL P DECOMP R/U and test 95/801 casing to 3,500 psi for 30 minutes and record. Good test. 05:00 - 06:30 1.50 STWHIP P WEXIT P/U whipstock BHA to 80'. Orient MWD, M/U whip stock, M/U HOC, Upload MWD 06:30 - 07:30 1.00 STWHIP P WEXIT M/U BHA to 954', C/O elevators. 07:30 - 08:00 0.50 STWHIP P WEXIT Shallow test MWD tools @ 954' at 520 gpm and 950 psi. Blow down surface equipment. 08:00 - 11 :00 3.00 STWHIP P WEXIT RIH with drill pipe from 954' to 8,517'. Fill pipe and test MWD at 4,223' and 7,021'. Install blower hose. 11 :00 - 12:00 1.00 STWHIP P WEXIT Orient tool face 75 degrees LHS at 8,548'. Tag EZSV at 8,605'. P/U weight 205K, S/O weight 160K. Set trip anchor 25K down weight. P/U 15K over. Shear brass bolt with 35K down weight. P/U weight 205K. Printed: 5/19/2003 10: 39: 17 AM { {' Page 3 of 8 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-23 C-23 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To Hours Task Code NPT Phase 5/9/2003 12:00 - 14:00 2.00 STWHIP P WEXIT 14:00 - 19:30 5.50 STWHIP P WEXIT 19:30 - 20:00 0.50 STWHIP P WEXIT 20:00 - 21 :00 1.00 STWHIP P WEXIT 21 :00 - 21 :30 0.50 STWHIP P WEXIT 21 :30 - 22:00 0.50 STWHIP P WEXIT 22:00 - 23:30 1.50 STWHIP P WEXIT 23:30 - 00:00 0.50 STWHIP P WEXIT 5/10/2003 00:00 - 03:00 3.00 STWHIP P WEXIT 03:00 - 04:00 1.00 STWHIP P WEXIT 04:00 - 04:30 0.50 STWHIP P WEXIT 04:30 - 05:30 1.00 DRILL P INT1 05:30 - 09:00 3.50 DRILL P INT1 09:00 - 11 :30 2.50 DRILL P INT1 11 :30 - 14:00 2.50 DRILL P INT1 14:00 - 15:00 1.00 DRILL P INT1 15:00 - 00:00 9.00 DRILL P INT1 Start: 5/6/2003 Rig Release: 5/18/2003 Rig Number: 2ES Spud Date: End: Description of Operations Displace well from sea water to 10.7 ppg milling fluid at 8,580' @ 520 gpm and 3,050 psi. Mill window in the 95/8",47#, L-80 casing. TOW at 8,580'; BOW at 8,596'. Mill the first 8 feet with 3-6K WOB, 70 - 90 rpm at 510 gpm. Mill from 9 - 16 feet with 8 - 12K WOB, 95 rpm, 510 gpm. Open the remaining 14 feet with 15 - 25K WOB, 95 rpm, and 510 gpm. Estimate recovery of 135# metal. Pump Hi Vis sweep. Ream and work mills through window at 100 rpm and 510 gpm. P/U weight 200K, S/O weight 150K, Rot weight 165K. CBU 1.5X at 510 gpm and 2,800 psi. Perform FIT with 10.7 ppg mud to 12.0 ppg EMW (520psi) at 8,580' MD, 7,700' TVD. Monitor well, pump dry job, POOH to 8,517', blow down top drive. Remove blower hose. Cut and slip 99' drilling line. Service top drive. POH with drill pipe from 8,517' to 6,904'. POOH from 6,904' to 954'. Rack HWDP from 954'. Read MWD. LID MWD and Baker mills. Upper mill full gauge at 8.51". Clear rig floor, flush stack. M/U 8 1/2" drilling BHA to 1,096'. Surface check. OK RIH, P/U 4" dp singles from 1,096' to 4,177'. RIH with drill pipe from 4,177' to 8,472'. Fill pipe at 1,096', 4,177', and 7,164'. MAD pass from 8,472'. Orient TF 80 deg. LHS at 8,515', Slide through TOW at 8,580'. Ream undergauge hole from 8,604' to 8,610'. Directional drill from 8,610' to 9,160'. ART = 2,57 hrs, AST = 2.83 hrs, ADT = 5.40 hrs P/U weight 215K, S/O weight 155K, Rot weight 180K. Slide I Rotate 254' (8,610' - 8,864') Slide at TF -160 to initiate drop I RH turn Flow rate 550 gpm, on btm 3,850 psi, off btm 3,550 psi. WOB 12 K, Rap 80-120 fph Rotate at 60 RPM Flow rate 550 gpm, on btm 3,800 psi, off btm 3,550 psi. Torque on btm 12,000; Torque off btm 10,000 WOB 12K, Rap 80 -120 fph Slide I Rotate 296' (8,864' - 9,160') Slide at TF 80 to continue RH turn Printed: 5/19/2003 10:39:17 AM (' ~ BP EXPLORATION Operations Summary Report Page 4 of8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-23 C-23 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 5/6/2003 Rig Release: 5/18/2003 Rig Number: 2ES Spud Date: End: Date From - To Hours Task Code NPT Phase Description of Operations 5/1 0/2003 15:00 - 00:00 9.00 DRILL P INT1 Flow rate 550 gpm, on btm 3,650 psi, off btm 3,500 psi. WOB 12 K, Rap 50 fph Rotate at 80 RPM Flow rate 550 gpm, on btm 3,800 psi, off btm 3,600 psi. Torque on btm 12,000; Torque off btm 10,000 WOB 12K, Rap 120 fph 5/11/2003 00:00 - 01 :30 1.50 DRILL P INT1 Directional drill from 9,160' to 9,345'. ART = 0.60 hrs, AST = 0.20 hrs, ADT = 0.80 hrs P/U weight 225K, S/O weight 150K, Rot weight 185K. Slide / Rotate 185' (9,160' - 9,345') Slide at TF -40 to continue drop / RH turn Flow rate 550 gpm, on btm 3,800 psi, off btm 3,600 psi. WOB 15 K, Rap 75 fph Rotate at 80 RPM Flow rate 550 gpm, on btm 3,800 psi, off btm 3,600 psi. Torque on btm 12,000; Torque off btm 10,000 WOB 12K, Rap 130 fph Reach 8 1/2" section TD. 01 :30 - 02:30 1,00 DRILL P INT1 CBU, pump sweep, CBU at 550 gpm, 3,800 psi and 80 rpm, Geologist confirmed casing point with samples indicating Sag River sand. 02:30 - 04:00 1.50 DRILL P INT1 POH to window at 8,580'. P/U 235 - 245K, 10 - 20K overpull. Tight spot at the TOW, pulling to 250K. Work up and down. Circulate below window, Orient TF to 80 LHS. Pulled through, into casing. 04:00 - 04:30 0.50 DRILL P INT1 RIH to 9,345'. No problems. 04:30 - 06:30 2.00 DRILL P INT1 CBU. Pump Hi Vis Nut plug sweep, rotate at 90 rpm, 530 gpm and 3,800 psi. Spot liner running pill in open hole. Monitor well. 06:30 - 10:30 4.00 DRILL P INT1 POOH from 9,345' to 1,096'. Pulled tight at TOW again. Worked through. Pump dry job at 8,471'. 10:30 - 12:00 1.50 DRILL P INT1 LID BHA from 1,096' to 169'. 12:00 - 14:30 2.50 DRILL P INT1 LID BHA from 169' to 107'. Pump water through MWD and motor. Break bit. Download MWD. LID BHA from 107'. Clear floor. 14:30 - 16:30 2.00 BOPSURP LNR1 C/O top set of rams to 7". Pull wear bushing and install test plug. Test 7" rams and Hydril to 250 psi low and 3,500 psi high. 16:30 - 17:30 1.00 CASE P LNR1 PJSM. R/U 7" casing equipment. 17:30 - 18:00 0.50 CASE P LNR1 M/U shoe track to 125'. Check floats. 18:00 - 19:00 1.00 CASE P LNR1 M/U 7", 26#, L-80, BTC liner to 897'. Run a total of 22 joints 7", 26#, L-80, BTC casing. Average M/U Torque 8,300 ft-Ibs. 19:00 - 19:30 0.50 CASE P LNR1 M/U Baker liner hanger/packer and 1 stand dp. 19:30 - 20:00 0.50 CASE P LNR1 Circulate 1 liner volume at 35 spm and 30 psi. R/D casing equipment. 20:00 - 21 :30 1.50 CASE P LNR1 Run in -20' of stand #2. Set down solid. Hanger/ packer 145' below rig floor. POOH to inspect hanger. Pins of shifting sleeve were sheared. LID hanger/ packer assembly. Printed: 5/19/2003 10:39: 17 AM ~ ( BP EXPLORATION Operations Summary Report Page 5 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-23 C-23 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 5/6/2003 Rig Release: 5/18/2003 Rig Number: 2ES Spud Date: End: Date From - To Hours Task Code NPT Phase Description of Operations 5/11/2003 21 :30 - 00:00 2.50 CASE N WAIT LNR1 Ship assembly to Baker shop for hanger replacement. Replacement arrives at midnight. 5/12/2003 00:00 - 01 :00 1.00 CASE N WAIT LNR1 P/U and M/U replacement liner hanger/packer assembly. R/D casing equipment. 01 :00 - 01 :30 0.50 CASE P LNR1 RIH with 10 stands drill pipe to 1,870'. Circulate drill pipe volume at 240 gpm and 140 psi. 01 :30 - 05:00 3.50 CASE P LNR1 RIH with liner on drill pipe to TOW at 8,577'. P/U weight 175K, S/O weight 135K. 05:00 - 05:30 0.50 CASE P LNR1 Circulate one drill pipe volume at 7 bpm and 1,020 psi. 05:30 - 06:00 0.50 CASE P LNR1 Run into open hole with 7" liner, from 8,577 to 9,345'. No problems. 06:00 - 07:00 1.00 CASE P LNR1 Stage pumps up slowly to 6 bpm and 1,190 psi. 07:00 - 08:00 1,00 CEMT P LNR1 Pump 5 bbl water and test lines to 4,500 psi. Pump 35 bbl MudPUSH @ 11.7 ppg. Pump 43 bb115.8 ppg, 'G' cement. Drop dart and displace with rig pumps at 8 bpm. Bump plug to 3,500 psi to set hanger. Check floats. P/U weight 195K, S/O weight 145K. CIP at 07:55, 05/12/2003, 08:00 - 10:00 2,00 CASE P LNR1 Release from hanger with 15 RH rotations. CBU at 11 bpm and 3,100 psi. Set 70K down weight to set packer. Rotate to verify set. 10:00 - 11 :30 1.50 CASE P LNR1 C&S 82' drilling line. Service top drive and crown. 11 :30 - 12:00 0,50 CASE P LNR1 POOH from 8,398' to 6,498'. 12:00 -15:30 3.50 CASE P LNR1 POOH from 6,498'. Service break the running tool and LID. Clear rig floor. 15:30 - 17:30 2.00 BOPSUR P PROD1 C/O top set rams from 7" to 3 1/2" X 6" VBR. Pull wear bushing. Install test plug. Pressure test to 250 psi low and 3,500 psi high. Pull test plug and install wear bushing. 17:30 - 18:00 0.50 DRILL P PROD1 C/O handling equipment. Prepare for P/U 6 1/8" BHA, 18:00 - 19:00 1.00 CASE P PROD1 Pressure test the 9 5/8" X 7" to 3,500 psi for 30 minutes and record. Good test. UCA results - 2,000 psi compressive strength at 8.0 hours. 19:00 - 20:30 1.50 DRILL P PROD1 PJSM regarding M/U BHA. P/U and M/U 6 1/8" BHA to 45'.Orient, M/U bit, C/O motor stabilizer blade. M/U BHA to 137'. 20:30 - 22:00 1.50 DRILL P PROD1 Up load and function test MWD at 5 bpm and 930 psi. LOAD RAS. M/U BHA from 137' to 236'. 22:00 - 00:00 2.00 DRILL P PROD1 C/O handling equipment. RIH from 236' to 4,718'. Fill pipe at 3,490' and check MWD at 5 bpm and 1,290 psi. 5/13/2003 00:00 - 02:00 2,00 DRILL P PROD1 RIH with drill pipe from 4,718' to 9,260', Tag 7" landing collar at 9,260'. 02:00 - 05:00 3.00 DRILL P PROD1 Drill landing collar, cement, and float equipment to 9,340'. 05:00 - 06:30 1.50 DRILL P PROD1 Displace well from 10.7 LSND mud to 8.6 ppg QuickDrilN fluid. 06:30 - 07:00 0.50 DRILL P PROD1 Drill 7" float shoe and 20' of new hole to 9365' 07:00 - 07:30 0.50 DRILL P PROD1 Perform FIT. EMW 9.6 ppg with 8.8 ppg mud at 500 psi. 07:30 - 00:00 16.50 DRILL P PROD1 Directional drill 6 1/8" hole from 9365' to 9851'. ART = 2.04 hrs, AST = 10.27 hrs, ADT = 12.31 hrs P/U weight 190K, S/O weight 150K, Rot weight 165K. Flow rate 250 gpm, on btm 1580 psi, off btm 1450 psi. WOB 20 K 5/14/2003 00:00 - 19:00 19.00 DRILL P PROD1 Directional drill from 9851' to 10821'. Printed: 5/19/2003 10:39:17 AM { It BP EXPLORATION Operations Summary Report Page 6 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-23 C-23 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 5/6/2003 Rig Release: 5/18/2003 Rig Number: 2ES Spud Date: End: Date From - To Hours Task Code NPT Phase Description of Operations 5/14/2003 00:00 - 19:00 19.00 DRILL P PROD1 ART = 4.97 hrs, AST = 8.91 hrs, ADT = 13.88 hrs P/U weight 188K, S/O weight 145K, Rot weight 170K. Slide I Rotate 604' (9851' - 10455') Slide at TF 35 deg to 15 deg right of high side. Flow rate 265 gpm, on btm 1640 psi, off btm 1540 psi. WOB 22 K, ROP 48 fph Rotate at 60 RPM Flow rate 265 gpm, on btm 1640 psi, off btm 1540 psi. Torque on btm 9300; WOB 25K, ROP 100 fph Slide I Rotate 366' (10455' - 10821') Slide at TF 160 deg right of high side. Flow rate 265 gpm, on btm 1700 psi, off btm 1560 psi. WOB 22 K, ROP 46 fph Rotate at 90 RPM Flow rate 265 gpm, on btm 1700 psi, off btm 1560 psi. Torque on btm 10,000; WOB 22K, ROP 118 fph Reach 61/8" TD. 19:00 - 21 :00 2.00 DRILL P PROD1 Circulate and condition mud. Pump around high vis sweep. 21 :00 - 23:30 2.50 DRILL P PROD1 POH. MAD pass from 10821' to 10250' at 300'/hr. 23:30 - 00:00 0.50 DRILL P PROD1 POH from 10250' to 9290'. Wiper trip prior to run 4 1/2" liner. 5/15/2003 00:00 - 00:30 0.50 DRILL P PROD1 Service Top Drive and crown. 00:30 - 01 :00 0.50 DRILL P PROD1 RIH to 10821 '. No hole problems. 01 :00 - 03:30 2.50 DRILL P PROD1 Circulate. Spot 60 bbl new mud liner running pill in open hole. 03:30 - 05:00 1.50 DRILL P PROD1 POH to run 4 1/2" liner. Lay down 45 joints excess drill pipe. 05:00 - 06:00 1,00 DRILL P PROD1 Drop pump out sub dart, open pump out sub. Pump dry job. 06:00 - 08:30 2,50 DRILL N RREP PROD1 Repair rig. Change out brake linkage block. 08:30 - 11 :30 3.00 DRILL P PROD1 POH to BHA. 11 :30 - 14:30 3.00 DRILL P PROD1 Lay down BHA. Pull Nukes. Down load MWD. Clear floor. 14:30 - 15:00 0.50 DRILL P PROD1 Wash BOP with jetting tool. 15:00 - 15:30 0,50 CASE P COMP Rig up to run 4 1/2" liner. 15:30 - 16:00 0.50 CASE P COMP PJSM on running liner. Make up 4 1/2" float equipment and check same. 16:00 - 18:00 2.00 CASE P COMP Run 40 joints 4 1/2" 12.6# L-80 BTC-M liner. 18:00 - 18:30 0.50 CASE P COMP Make up liner hanger and ZXP liner top packer. 18:30 - 19:00 0.50 CASE P COMP Circulate liner volume at 300 BPM with 100 psi. 19:00 - 23:00 4.00 CASE P COMP RIH with 4 1/2" liner on 4" dril pipe to 7" shoe. Fill pipe every 10 stands. 23:00 - 23:30 0.50 CASE P COMP Circulate drill pipe and liner volume at 7 BPM with 670 psi. Up weight 165K, down weight 140K. 23:30 - 00:00 0.50 CASE P COMP RIH with 41/2" liner on 4" dril pipe to 10180'. 5/16/2003 00:00 - 00:30 0.50 CASE P COMP RIH with 41/2" liner on 4" dril pipe to 10821'. Wash last joint to bottom as precaution. 00:30 - 03:00 2.50 CASE P COMP Make up cementing head and lines. Circulate bottoms up at 6 bpm with 1 020 psi. Printed: 5/19/2003 10:39:17 AM f { BP EXPLORATION Operations Summary Report Page 7 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-23 C-23 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 5/6/2003 Rig Release: 5/18/2003 Rig Number: 2ES Spud Date: End: Date From - To Hours Task Code NPT Phase Description of Operations 5/16/2003 03:00 - 04:00 1.00 CEMT P CaMP Cement 4 1/2" liner with 44 bbl (205 sx) Class "G" Latex cement at 15.8 ppg. Displace with 44 bbl perf pill followed by 71 bbl mud using Schlumberger pump truck. Bumped plug, floats held. Set liner hanger with 3500 psi. Shoe at 10,820' landing collar at 10,735', top of liner tie-back at 9156', Cement in place at 03:50. Rotate and release from liner hanger, confirm with pick up weight. 04:00 - 05:00 1.00 CEMT P CaMP Unsting from liner, circulate at 11 bpm with 2050 psi. Reverse out 3 bbl contaminated cement. Set down 50K to set ZXP liner top packer. 05:00 - 06:00 1.00 CEMT P CaMP Rig down cementing head and lines. Presure test liner top packer with 1000 psi for 10 minutes. 06:00 - 07:30 1.50 CEMT P CaMP Displace well from liner top with clean sea water 8.6 ppg. 07:30 - 11 :30 4.00 CEMT P CaMP POH. lay down liner running tool. Clear rig floor, 11:30-12:00 0.50 BOPSUR P CaMP Pull wear bushing. Install test plug. 12:00 - 15:30 3.50 BOPSURP CaMP Test BOP and related equipment to 250 psi low and 3500 psi high. Witnessing of test waived by Jeff Jones of AOGCC. 15:30 - 16:00 0.50 BOPSUR P CaMP Pull test plug and install wear bushing. 16:00 - 16:30 0.50 CASE P CaMP Test casing and liner to 3500 psi for 30 minutes. 16:30 - 17:00 0.50 PERF P CaMP Pick up 400' of 2 1/2" Millenium perforating guns with TDF firing head and associated tools. 17:00 - 17:30 0.50 PERF P CaMP Rig up to run 2 7/8" drill pipe. 17:30 - 19:30 2.00 PERF P CaMP RIH with perforating guns to 1645'. Pick up 40 joints 2 7/8" PAC drill pipe. 19:30 - 20:00 0.50 PERF P CaMP Rig down 2 7/8" handling equipment. 20:00 - 22:30 2.50 PERF P CaMP RIH with DPC perf guns to 10,736'. Tag up on landing collar. 22:30 - 23:00 0.50 PERF P CaMP PJSM with crew and Halliburton. Space out and position guns. Pressure up drill pipe and annulus to 3300 psi and perforate well from 10,730' to 10,330' (400') 4 SPF 60 deg phasing. 23:00 - 23:30 0.50 PERF P CaMP POH to 10,236'. 23:30 - 00:00 0.50 PERF P CaMP Monitor well. Fluid to formation at 4 bbl per hour. 5/17/2003 00:00 - 01 :30 1.50 PERF P CaMP POH. Stand back 48 stands 4" drill pipe, 01 :30 - 02:30 1.00 PERF P CaMP Slip and cut 95' drilling line. 02:30 - 05:30 3.00 PERF P CaMP POH. Lay down excess 4" drill pipe. 05:30 - 07:00 1.50 PERF P CaMP Change out handling equipment to 2 7/8". Lay down 2 7/8" PAC drill pipe. 07:00 - 08:30 1.50 PERF P CaMP Change out handling equipment to 2 1/2". PJSM. Lay down 2 1/2" Perforating guns. All shots fired. 08:30 - 09:30 1.00 RUNCONP CaMP Clear rig floor of 2 1/2" tools and perforating gun handling equipment. 09:30 - 10:00 0.50 RUNCONP CaMP Pull wear bushing. 10:00 - 10:30 0.50 RUNCONP CaMP Rig up 4 1/2" tubing running equipment. 10:30 - 18:30 8.00 RUNCONP CaMP PJSM with crew and Baker Rep. Pick up Wireline entry guide and completion assembly. RIH with 216 joints 41/2" 12.6# L-80 IBT-M tubing completion. Tag up at 9163'. String weight up 130K, down 115K. 18:30 - 19:30 1.00 RUNCONP CaMP Space out completion. Make up tubing hanger and land string. 19:30 - 20:00 0.50 RUNCONP CaMP Run in lock-down screws. 20:00 - 22:30 2.50 RUNCONP CaMP Reverse circulate clean sea water and spot corrosion inhibitor Printed: 5/19/2003 10:39:17 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: I~: Page 8 of 8 BP EXPLORATION Operations Summary Report C-23 C-23 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To Hours Task Code NPT Phase 5/17/2003 20:00 - 22:30 2.50 RUNCOIVP COMP 22:30 - 00:00 1.50 RUNCOIVP COMP 5/18/2003 00:00 - 02:00 2.00 RUNCOIVP COMP 02:00 - 03:00 1.00 BOPSUR P COMP 03:00 - 04:30 1.50 BOPSUR P COMP 04:30 - 06:30 2.00 WHSUR P COMP 06:30 - 08:00 1.50 WHSUR P COMP 08:00 - 09:30 1.50 WHSUR P COMP 09:30 - 10:30 1.00 WHSUR P COMP 10:30 - 11 :00 0.50 WHSUR P COMP 11 :00 - 12:00 1.00 WHSUR P COMP Start: 5/6/2003 Rig Release: 5/18/2003 Rig Number: 2ES Spud Date: End: Description of Operations in annulus. Drop 1 7/8" ball and rod. Lay down landing joint. Pressure up tubing to 3500 psi. Set production packer. Hold pressure for 30 minutes. Bleed pressure to 1500 psi. Pressure up annulus to 3500 psi and hold for 30 minutes. Bleed down tubing pressure to shear DCR valve in upper GLM with 2300 psi. Install two way check and test from below with 1000 psi. Nipple down BOP, riser and flow line. Nipple up CIW adapter flange and tree. Test tree to 5000 psi. Rig up lubricator. Pull two way check. Rig up hot oil unit, test lines to 3500 psi. Freeze protect tubing and IA with 155 bbl diesel to 2200'. Freeze protect diesel"U" tube to tubing. Install back pressure valve and test with 1 000 psi from below. Rig down hot oil unit. Secure well. Rig released at 12:00 hrs 5/18/2003 Printed: 5/19/2003 10:39:17 AM ( ( 29-May-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well C-23B Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 8,494.101 MD Window / Kickoff Survey: 8,581.00' MD (if applicable) Projected Survey: 10,821.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager ¿D3~Dfo 0 RECEIVED Attachment(s) JUN 0 2 2003 AJaIka OH & Gas Coni. Commiseion Anchcnge ~0.~ Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_WOA C Pad C-23B Job No. AKZZ0002431379, Surveyed: 14 May, 2003 Survey Report 28 May, 2003 Your Ref: API 500292077502 Surface Coordinates: 5959903.00 N, 664349.00 E (70017'48.3779" N, 148040' 08.6771" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959903.00 N, 164349.00 E (Grid) Surface Coordinates relative to Structure Reference: 2644.30 N, 1857.24 E (True) Kelly Bushing: 65.60ft above Mean Sea Level Elevation relative to Project V Reference: 65.60ft Elevation relative to Structure Reference: 65.60ft !5þa::r"r"Y-SUf1 DFtILLING seRVices A Halliburton Company DEF NITuVE ~ .- Survey Ref: 5vy4032 DrillQuest 3.03.02.005 Page 20f4 28 May, 2003 - 10:40 Sperry-Sun Drilling Services Survey Report for PBU _WOA C Pad - C-23B Your Ref: API 500292077502 Job No. AKZZ0002431379, Surveyed: 14 May, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) r/100ft) 8494.10 36.270 187.800 7564.09 7629.69 2606.97 S 451.72 W 5957286.78 N 663954.39 E 525.70 Tie On Point AK-6 BP IFR-AK 8581.00 37.360 188.310 7633.66 7699.26 2658.53 S 459.02 W 5957235.07 N 663948.22 E 1.303 534.46 Window Point 8594.54 37.970 187.820 7644.38 7709.98 2666.72 S 460.18 W 5957226.86 N 663947.24 E 5.019 535.85 8627.37 36.460 186.530 7670.53 7736.13 2686.42 S 462.67 W 5957207.11 N 663945.19 E 5.177 538.89 -- 8658.64 33.440 185.170 7696.15 7761.75 2704.23 S 464.50 W 5957189.26 N 663943.75 E 9.973 541.23 8687.29 30.460 183.770 7720.46 7786.06 2719.34 S 465.69 W 5957174.12 N 663942.89 E 10.717 542.85 8721.37 27.670 181.900 7750.25 7815.85 2735.88 S 466.52 W 5957157.58 N 663942.42 E 8.609 544.15 8752.37 26.200 179.950 7777.88 7843.48 2749.91 S 466.75 W 5957143.54 N 663942.49 E 5.532 544.78 8780.84 23.230 179.640 7803.74 7869.34 2761.82 S 466.71 W 5957131.64 N 663942.79 E 10.442 545.08 8814.08 21 .960 180.150 7834.43 7900.03 2774.59 S 466.69 W 5957118.87 N 663943.10 E 3.866 545.42 8835.69 21.720 180.550 7854.49 7920.09 2782.63 S 466.74 W 5957110.83 N 663943.23 E 1.307 545.70 8873.86 21.020 182.260 7890.04 7955.64 2796.53 S 467.07 W 5957096.93 N 663943.19 E 2.455 546.43 8907.97 20.760 184.560 7921.90 7987.50 2808.67 S 467.79 W 5957084.77 N 663942.74 E 2.522 54 7.50 8967.11 20.310 186.640 7977.29 8042.89 2829.31 S 469.82 W 5957064.09 N 663941 .17 E 1.449 550.10 9060.20 18.640 189.780 8065.05 8130.65 2860.02 S 474.21 W 5957033.29 N 663937.44 E 2.117 555.37 9153.93 18.850 186.070 8153.81 8219.41 2889.84 S 478.36 W 5957003.39 N 663933.95 E 1.291 560.36 9245.92 18.380 185.760 8240.99 8306.59 2919.05 S 481.38 W . 5956974.12 N 663931.56 E 0.522 564.22 9277.01 17.810 185.620 8270.54 8336.14 2928.66 S 482.34 W 5956964.49 N 663930.82 E 1.839 565.45 9341.31 16.910 184.390 8331.91 8397.51 2947.77 S 484.02 W 5956945.35 N 663929.56 E 1.512 567.67 9372.84 18.570 183.850 8361.94 8427.54 2957.35 S 484.71 W 5956935.76 N 663929.08 E 5.291 568.63 9405.67 20.620 183.320 8392.87 8458.47 2968.34 S 485.39 W 5956924.76 N 663928.63 E 6.268 569.63 -', 9434.22 20.930 196.690 8419.58 8485.18 2978.25 S 487.15 W 5956914.81 N 663927.09 E 16.613 571.67 9468.27 21.180 211.760 8451.38 8516.98 2989.31 S 492.14 W 5956903.64 N 663922.35 E 15.877 576.97 9499.56 23.680 219.350 8480.30 8545.90 2998.98 S 499.10 W 5956893.82 N 663915.60 E 12.212 584.20 9528.03 24.210 222.350 8506.32 8571.92 3007.72 S 506.66 W 5956884.92 N 663908.23 E 4.664 592.01 9561.74 24.560 227.810 8537.03 8602.63 3017.53 S 516.51 W 5956874.90 N 663898.60 E 6.765 602.13 9592.49 25.260 234.060 8564.93 8630.53 3025.67 S 526.56 W 5956866.53 N 663888.74 E 8.854 612.41 9620.90 26.320 239.130 8590.51 8656.11 3032.4 7 S 536.87 W 5956859.52 N 663878.57 E 8.611 622.91 9655.26 28.230 245.620 8621.05 8686.65 3039.73 S 550.81 W 5956851.95 N 663864.79 E 10.280 637.06 9686.79 28.610 247.980 8648.78 8714.38 3045.64 S 564.61 W 5956845.74 N 663851.13 E 3.760 651.01 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad - C-23B Your Ref: API 500292077502 Job No. AKZZ0002431379, Surveyed: 14 May, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9715.22 29.620 253.090 8673.63 8739.23 3050.24 S 577.64 W 5956840.86 N 663838.20 E 9.436 664.17 9749.25 33.040 257.320 8702.69 8768.29 3054.72 S 594.74 W 5956836.01 N 663821.20 E 11.944 681.40 9779.82 36.600 262.080 8727.79 8793.39 3057.81 S 611.91 W 5956832.54 N 663804.10 E 14.644 698.64 9808.19 38.630 264.910 8750.26 8815.86 3059.76 S 629.11 W 5956830.22 N 663786.95 E 9.394 715.89 9842.16 42.500 269.800 8776.07 8841.67 3060.74 S 651.16 W 5956828.75 N 663764.93 E 14.738 737.96 /"=~ 9872.03 45.460 272.770 8797.57 8863.17 3060.26 S 671.89 W 5956828.78 N 663744.19 E 12.076 758.67 9900.78 47.510 275.400 8817.36 8882.96 3058.77 S 692.68 W 5956829.82 N 663723.37 E 9.738 779.41 9934.77 51.520 279.180 8839.43 8905.03 3055.46 S 718.31 W 5956832.56 N 663697.68 E 14.513 804.93 9964.17 55.310 282.130 8856.95 8922.55 3051.08 S 741.50 W 5956836.43 N 663674.40 E 15.200 827.98 9993.52 57.560 284.680 8873.18 8938.78 3045.41 S 765.28 W 5956841.58 N 663650.50 E 10.543 851.60 10027.78 60.900 287.060 8890.71 8956.31 3037.35 S 793.58 W 5956849.02 N 663622.02 E 11 .430 879,66 10057.29 64.760 289.120 8904.18 8969.78 3029.19 S 818.53 W 5956856.63 N 663596.91 E 14.479 904.37 10087.70 68.050 291.410 8916.35 8981.95 3019.54 S 844.67 W 5956865.71 N 663570.57 E 12.831 930.22 10120.24 70.750 292.420 8927.80 8993.40 3008.17 S 872.92 W 5956876.46 N 663542.07 E 8.791 958.13 10151.78 74.120 294.210 8937.32 9002.92 2996.26 S 900.53 W 5956887.76 N 663514.21 E 11.976 985.39 10180.96 76.920 295.110 8944.61 9010.21 2984.48 S 926.20 W 5956898.98 N 663488.28 E 10.049 1010.72 10213.56 81.830 297.030 8950.62 9016.22 2970.40 S 954.97 W 5956912.43 N 663459.21 E 16.135 1039.08 10245.23 86.480 297.530 8953.85 9019.45 2955.96 S 982.96 W ' 5956926.25 N 663430.91 E 14.766 1066.65 10273.91 90.060 299.610 8954.71 9020.31 2942.25 S 1008.13 W 5956939.40 N 663405.45 E 14.434 1091.42 10366.81 90.370 299.500 8954.36 9019.96 2896.43 S 1088.94 W 5956983.45 N 663323.65 E 0.354 1170.89 10459.88 90.310 301.330 8953.81 9019.41 2849.32 S 1169.20 W 5957028.80 N 663242.39 E 1.967 1249.78 10554.04 89.010 300.910 8954.37 9019.97 2800.65 S 1249.81 W 5957075.69 N 663160.74 E 1.451 1328.97 --, 10647.94 90.430 302.500 8954.83 9020.43 2751.31 S 1329.69 W 5957123.27 N 663079.79 E 2.270 1407.41 10741.25 87.350 303.440 8956.64 9022.24 2700.54 S 1407.95 W 5957172.31 N 663000.44 E 3.451 1484.19 10775.38 87.780 303.560 8958.09 9023.69 2681.72 S 1436.38 W 5957190.51 N 662971.60 E 1.308 1512.08 10821.00 87.780 303.560 8959.85 9025.45 2656.52 S 1474.37 W 5957214.87 N 662933.08 E 0.000 1549.34 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 268.370° (True). Magnetic Declination at Surface is 25.874°(07-May-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 10821.00ft., ------ 28 May, 2003 - 10:40 Page 3 of4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad - C-23B Your Ref: API 500292077502 Job No. AKZZ0002431379, Surveyed: 14 May, 2003 BPXA North Slope Alaska The Bottom Hole Displacement is 3038.24ft., in the Direction of 209.0300 (True). Comments '--- Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment -, 8494.10 8581.00 10821.00 7629.69 7699.26 9025.45 2606.97 S 2658.53 S 2656.52 S 451.72 W 459.02 W 1474.37 W Tie On Point Window Point Projected Survey Survey tool prOf/ram for C-23B From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8494.10 0.00 8494.10 7629.69 10821.00 7629.69 BP High Accuracy Gyro (C-23) 9025.45 AK-6 BP _IFR-AK (C-23B) -, 28 May, 2003 - 10:40 Page 4 0(4 DrillQlIest 3.03.02.005 ( 1(' 29-May-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well C-238 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 8,494.101 MD Window / Kickoff Survey: 8,581.00 I MD (if applicable) Projected Survey: 10,821.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, ~l? 3 -b fc;D RECEIVED William T. Allen Survey Manager JUN 0 2 2003 Alalka Oil & Gas Coni. CornmiIeion AndKnge ~ v).~ Attachment(s) Sperry-Sun Drilling Services North Slope Alaska BPXA PBU WOA C Pad C-238 MWD ""---:3!;:-... Job No. AKMW0002431379, Surveyed: 14 May, 2003 Survey Report 28 May, 2003 Your Ref: API 500292077502 Surface Coordinates: 5959903.00 N, 664349.00 E (70° 17' 48.3779" N, 148040' 08.6771" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ,-- Surface Coordinates relative to Project H Reference: 959903.00 N, 164349.00 E (Grid) Surface Coordinates relative to Structure Reference: 2644.30 N, 1857.24 E (True) Kelly Bushing: 65.60ft above Mean Sea Level Elevation relative to Project V Reference: 65.60ft Elevation relative to Structure Reference: 65.60ft spe'-'''''y-5U1! DRILLING SERVIc:es A Halliburton Company Survey Ref: 5vy4033 DrillQuest 3.03.02.005 Page 20f4 28 May, 2003 - 11:18 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad - C-238 MWD Your Ref: API 500292077502 Job No. AKMW0002431379, Surveyed: 14 May, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8494.10 36.270 187.800 7564.09 7629.69 2606.97 S 451.72 W 5957286.78 N 663954.39 E 525.70 Tie On Point MWD Magnetic 8581.00 37.360 188.310 7633.66 7699.26 2658.53 S 459.02 W 5957235.07 N 663948.22 E 1.303 534.46 Window Point 8594.54 37.970 187.820 7644.38 7709.98 2666.72 S 460.18 W 5957226.86 N 663947.24 E 5.019 535,85 8627.37 36.460 186.530 7670.53 7736.13 2686.42 S 462.67 W 5957207.11 N 663945.19 E 5.177 538.89 -- 8658.64 33.440 185.170 7696.15 7761.75 2704.23 S 464.50 W 5957189.26 N 663943.75 E 9.973 541.23 8687.29 30.460 183.770 7720.46 7786.06 2719.34 S 465.69 W 5957174.12 N 663942.89 E 10.717 542.85 8721.37 27.670 183.250 7750.25 7815.85 2735.87 S 466.71 W 5957157.58 N 663942.23 E 8.220 544.34 8752.37 26.200 180.090 7777.88 7843.48 2749.90 S 467.12 W 5957143.54 N 663942.12 E 6.617 545.16 8780.84 23.230 179.820 7803.74 7869.34 2761.80 S 467.12 W 5957131.65 N 663942.39 E 10.440 545.49 8814.08 21.960 180.540 7834.43 7900.03 2774.57 S 467.15 W 5957118.88 N 663942.63 E 3.910 545.89 8835.69 21.720 180.920 7854.49 7920.09 2782.61 S 467.26 W 5957110.84 N 663942.70 E 1.289 546.22 8873.86 21.020 182.620 7890.04 7955.64 2796.51 S 467.68 W 5957096.93 N 663942.58 E 2.449 54 7,04 8907.97 20.760 185.030 7921.90 7987.50 2808.64 S 468.49 W 5957084.78 N 663942.04 E 2.632 548.20 8967.11 20.310 187.110 7977.29 8042.89 2829.27 S 470.68 W 5957064.11 N 663940.30 E 1.449 550.97 9060.20 18.640 190.470 8065.05 8130.65 2859.93 S 475.39 W 5957033.35 N 663936.27 E 2.160 556.54 9153.93 18.850 187.640 8153.81 8219.41 2889.67 S 480.12 W 5957003.52 N 663932.18 E 0.996 562.12 9245.92 18.380 187.330 8240.99 8306.59 2918.78 S 483.95 W - 5956974.33 N 663929.00 E 0.522 566.78 9277.01 17.810 186.170 8270.54 8336.14 2928.37 S 485.08 W 5956964.72 N 663928.07 E 2.169 568.18 9341.31 16.910 184.390 8331.91 8397.51 2947.47 S 486.86 W 5956945.58 N 663926.71 E 1.625 570.50 9372.84 18.570 180.520 8361.94 8427.54 2957.07 S 487.25 W 5956935.98 N 663926.53 E 6.455 571.17 9405.67 20.620 183.350 8392.87 8458.47 2968.07 S 487.64 W 5956924.98 N 663926.38 E 6.879 571.87 /¿.----~~-- 9434.22 20.930 196.890 8419.58 8485.18 2977.97 S 489.41 W 5956915.04 N 663924.82 E 16.822 573.93 9468.27 21.180 212.040 8451.38 8516.98 2989.01 S 494.45 W 5956903.89 N 663920.03 E 15.961 579.27 9499.56 23.680 219.800 8480.31 8545.91 2998.64 S 501.47 W 5956894.12 N 663913.22 E 12.369 586.57 9528.03 24.210 222.850 8506.33 8571.93 3007.31 S 509.10 W 5956885.28 N 663905.78 E 4.729 594.44 9561.74 24.560 228.300 8537.03 8602.63 3017.04 S 519.03 W 5956875.33 N 663896.06 E 6.753 604.64 9592.49 25.260 234.170 8564.93 8630.53 3025.13 S 529.13 W 5956867.02 N 663886.15 E 8.353 614.96 9620.90 26.320 239.630 8590.51 8656.11 3031.86 S 539.48 W 5956860.06 N 663875.95 E 9.152 625.50 9655.26 28.230 246.400 8621.06 8686.66 3038.97 S 553.50 W 5956852.65 N 663862.09 E 10.595 639.72 9686.79 28.610 248.970 8648.79 8714.39 3044.67 S 567.38 W 5956846.65 N 663848.33 E 4.062 653.76 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad - C-23B MWD Your Ref: API 500292077502 Job No. AKMW0002431379, Surveyed: 14 May, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9715.22 29.620 253.960 8673.63 8739.23 3049.05 S 580.49 W 5956841.98 N 663835.33 E 9.247 666.98 9749.25 33.040 258.900 8702.70 8768.30 3053.16 S 597.68 W 5956837.50 N 663818.23 E 12.562 684.29 9779.82 36.600 263.590 8727.79 8793.39 3055.79 S 614.93 W 5956834.50 N 663801.04 E 14.565 701,60 9808.19 38.630 266.560 8750.27 8815.87 3057.26 S 632.17 W 5956832.65 N 663783.83 E 9.591 718.88 9842.16 42.500 270.000 8776.07 8841.67 3057.90 S 654.24 W 5956831.53 N 663761.78 E 13.1 55 740,96 - 9872.03 45.460 273.350 8797.57 8863.17 3057.28 S 674.97 W 5956831.70 N 663741.05 E 12.601 761.66 9900.78 47.510 276.150 8817.36 8882.96 3055.54 S 695.74 W 5956832.98 N 663720.24 E 10.035 782.37 9934,77 51.520 278.980 8839.43 8905.03 3052.12 S 721.35 W 5956835.84 N 663694.56 E 13.388 807.88 9964.17 55.310 281.610 8856.95 8922.55 3047.89 S 744.57 W 5956839.56 N 663671.26 E 14.756 830.97 9993.52 57.560 283.980 8873.18 8938.78 3042.47 S 768.41 W 5956844.46 N 66364 7.30 E 10.199 854,65 10027.78 60.900 286.160 8890.70 8956.30 3034.81 S 796.83 W 5956851.49 N 663618.72 E 11.177 882.83 10057.29 64.760 288.740 8904.18 8969.78 3026.93 S 821.86 W 5956858.83 N 663593.52 E 15.217 907.63 10087.70 68.050 288.140 8916.35 8981.95 3018.11 S 848.30 W 5956867.06 N 663566.90 E 10.969 933.81 10120.24 70.750 286.150 8927.80 8993.40 3009.14 S 877.40 W 5956875.39 N 663537.61 E 10.080 962.64 10151.78 74.120 287.370 8937.32 9002.92 3000.47 S 906.19 W 5956883.43 N 663508.64 E 11.303 991.17 10180.96 76.920 295.580 8944.62 9010.22 2990.12 S 932.45 W 5956893.20 N 663482.16 E 28.878 1017.12 10213.56 81.830 299.370 8950.63 9016.23 2975.34 S 960.86 W 5956907.36 N 663453.44 E 18.903 1045.10 10245.23 86.480 303.410 8953.86 9019.46 2958.94 S 987.73 W 5956923.17 N 663426.21 E 19.404 1071.50 10273.91 90.060 305.410 8954.73 9020.33 2942.74 S 1011.38 W 5956938.85 N 663402.21 E 14.296 1094.68 10366.81 90.370 298.780 8954.38 9019.98 2893.41 S 1090.04 W 5956986.45 N 663322.50 E 7.144 1171.90 10459.88 90.310 301.640 8953.82 9019.42 2846.58 S 1170.46 W 5957031.50 N 663241.07 E 3.074 1250.95 10554.04 89.010 302.270 8954.38 9019.98 2796.75 S 1250.35 W 5957079.58 N 663160.11 E 1.534 1329.39 -~. 10647.94 90.430 298.340 8954.84 9020.44 2749.38 S 1331.39 W 5957125.16 N 663078.05 E 4.450 1409.06 10741.25 87.350 300.820 8956.65 9022.25 2703.34 S 1412.51 W 5957169.42 N 662995.94 E 4.237 1488.84 10775.38 87.780 302.060 8958.10 9023.70 2685.55 S 1441.61 W 5957186.57 N 662966.4 7 E 3.842 1517.41 10821.00 87.780 302.060 8959.87 9025.4 7 2661.35 S 1480.24 W 5957209.91 N 662927.31 E 0.000 1555.34 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 268.370° (True). Magnetic Declination at Surface is 25.874°(07-May-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 10821.00ft., ------ 28 May, 2003 - 11:18 Page 3 of4 DríllQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad - C-23B MWD Your Ref: API 500292077502 Job No. AKMW0002431379, Surveyed: 14 May, 2003 BPXA North Slope Alaska The Bottom Hole Displacement is 3045.31ft., in the Direction of 209.083° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment ~i'-,_ 8494.10 8581.00 10821.00 7629.69 7699.26 9025.4 7 2606.97 S 2658.53 S 2661.35 S 451.72 W 459.02 W 1480.24 W Tie On Point Window Point Projected Survey Survey tool prOf/ram for C-23B MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8494.10 0.00 8494.10 7629.69 10821.00 7629.69 BP High Accuracy Gyro (C-23) 9025.47 MWD Magnetic (C-238 MWD) - --- 28 May, 2003 - 11:18 Page 4 0'4 DrillQuest 3.03.02.005 ~~!Æ~E ~ ( 1 !Æ~!Æ~~~!Æ FRANK H. MURKOWSKI, GOVERNOR ~ AI1ASIiA OIL AND GAS CONSERVATION COltDlISSION 333 w. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhor Bay Unit C-23B BP Exploration (Alaska), Inc. Pennit No: 203-060 Surface Location: 1315' SNL, 1030' WEL, Sec. 19, T11N, R14E, UM Bottomhole Location: 3998' SNL, 2497' WEL, Sec.,19, T11N, R14E, UM Dear Mr. Isaacson: Enclosed is the approved application for pennit to redrill the above development well. This pennit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this permit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, t0~~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this~ day of April, 2003 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section V~6/\- Y /i{l..cC'$ 1 a. Type of work 0 Drill II Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 664349, Y = 5959903 1315' SNL, 10301 WEL, SEC. 19, T11 N, R14E, UM At top of productive interval x = 663370, Y = 5956910 4286' SNL, 2085' WEL, SEC. 19, T11N, R14E, UM At total depth x = 662950, Y = 5957190 3998' SNL, 2497' WEL, SEC. 19, T11N, R14E, UM , STATE OF ALASKA ,: ALASKÅ ...JIL AND GAS CONSERVATION COMt.3SION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test III Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 67.9' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028305 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number C-23B ./ 9. Approximate spud date 05/19/03 Amount $200,000.00 14. Number of acres in property 15. PrQposed depth (MD and TVD) 2560 ~ 10823' MD / 9023' TVDss o 17. Anticipated press}ue {see 20 AAC 25.035 (e) (2)} 90 Maximum surface 2411 psig, At total depth (TVD) 8955' I 3306 psig Setting Depth Top Bottom LenQth MD TVD MD TVD 918' 8425' 75751 9343' 8392' 1630' 91931 8251' 10823' 9023' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 12. Distance to nearest property line 13. Distance to nearest well ADL 028310,1282' MD No Close Approach / 16. To be completed for deviated wells Kick Off Depth 8575' MD Maximum Hole Angle 18. casing~~~gram Specifications Hole Casina WeiQht Grade CouDlina 8-1/2" 7" 26# L-80 BTC-M 6-1/8" 4-1/2" 12.6#' L-80 IBT-M Quantity of Cement (include staae data) 239 cu ft Class 'G' 239 cu ft Class 'G' / 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 Liner 11662 feet 9015 feet 11567 feet 9019 feet Length Plugs (measured) Junk (measured) 1536' of 1-3/4" coil tubing BHA with perf guns at about 8742' (10/97) Cemented MD TVD Size I , I 80' 2694' 9442' 20" X 30" 13-3/8" 9-518" 8 cu yds concrete 3720 cu ft Arctic Set II 1282 cu ft Class 'G', 130 cu ft AS I 80' 2694' 9442' 80' 2694' 8386' 773' 26471 7" 2-7/8" 364 cu ft Class 'G' 129 cu ft Class 'G' 9176' - 9949' 8166' - 88291 ReOf!1VEe' - 9016' true vertical Sqzd: 11060'-11140', 11200' -11420' 9023' - 90301, 9033' - 9024' APR 0 7 Z003 Perforation depth: measured 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis Contact Engineer Name/Number: Rob Tirpack, 564-4166 is true and correct to the best of my knowledge . ~I\"'~' . Title Senior Drilling Engineer Alaska ŒI & Gai Cons. Commi3sion A~ o Diverter Sketch II Drilling Program o Seabed Report II 20 AAC 25.050 Requirements Prepared By Name/Number: Terrie Hubble, 564-4628 Date Permit Number API Number A' ~pp~o~a. 01 D)411_ te See cover letter .2.0~:s - Obc::5 50- 029-20775-02 '1'~ ~ for other reQuirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Required 0 Yes .ŒI No Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required .IS Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: -n~t \~,ofL; f-c ~SOO Î?~ / 4___ ZJ ,_ _.J - , by order of Approved By ~ /~LA-- ~ cO~)I¡1ii· . I ~ NhAC(·mmission Form 10-401 Rev. 12-01-85 - / .... 0,. t\ _ ... ' Date OJLI/09/D3 Submit In friPlicate { ( I Well Name: I C-23B Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: Estimated Target Location: Ivishak Zone 2A Bottom Hole Location: x = 664,349 Y = 5,959,903 1315' FNL 3925' FWL Sec. 19, T11 N, R14E Umiat X = 663,370 Y = 5,956,910 TVDss 8960' 4286' FNL 2883' FWL Sec. 19, T11N, R14E Umiat X = 662,950 Y = 5,957,190 TVDss 8955' 3998' FNL 2469' FWL Sec. 19, T11 N, R14E Umiat I AFE Number: I PBD4P2060 I I Estimated Start Date: 1 05/19/03 _.-/ I RiQ: 1 Nabors 2ES / I OperatinQ days to complete: 118.4 I MD: 110,823' I I TVD: 19023' I I GL: 139.4' 1 1 KB: 128.5' I 1 KBE: 167.9' I Well DesiQn (conventional, slim hole, etc.): 12 String Horizontal Sidetrack I Objective: I Ivishak Zone 2A Formation Markers Formation Tops (wp04c) MD TVD TVDss Kingak JF - Top of Kingak N/A N/A 7,582' Kick-off Point 8,575' 7,695' 7,627' Kingak JO 8,948' 8,019' 7,951' Kingak JC 9,055' 8,120' 8,052' Kingak JA 9,253' 8,307' 8,239' Sag River 9,333' 8,383' 8,315' Shublik 9,390' 8,437' 8,369' TSAD - Zone 4 9,449' 8,493' 8,425' SAD - Zone 3 9,651' 8,682' 8,614' SAD - Zone 2C 9,762' 8,778' 8,710' SAD - Zone 2Bu 9,841' 8,840' 8,772' SAD - Zone 2BI 9,908' 8,887' 8,819' SAD - Zone 2A 10,011' 8,948' 8,880' PGOC 10,039' 8,962' 8,894' TO 10,823' 9,023' 8,955' TD Criteria: Based on 300' of perfable sand in horizontal. C-23B Permit to Drill Comments 8.5 ppg EMW 8.5 ppg EMW 8.5 ppg EMW 8.5 ppg EMW 8.5 ppg EMW Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing IÐ :1 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW ~.(P 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW Page 1 ~' \ ~. Directional - Sperry wp03 KOP: 18,575' MD Maximum Hole Angle: -370 in 8-1/2" hole - at KOP -900 in 6-1/8" horizontal section There are no close approach issues. MWD with IFR/Casandra Close Approach Well: Survey Program: CasinQ/Tubing Program Hole Size CsglTbg O.D. WtlFt Grade Con~ Length Top Btm / MDITVD MDITVD 8-1/2" 7" 26# L-80 BTC-M 918' 8,425'/7 ,575' 9,343'/8,392' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 1,630' 9,193'/8,251 ' 10,823'/9,023' Tubing 4-1/2" 12.6# L-80 IBT-M 9,165' GL 9193'/8,251 ' Mud Program Section Milling Mud Properties: LSND I Whip Stock Window 95/8" I Density (ppg) Viscosity PV YP 10 sec gel MBT PH API FI 10.7 40 - 60 14-18 40+ 15-20 6-8 9.0- 9.5 8 Intermediate Mud Properties: LSND I 8-1/2" hole section I Density (p~ 10-Sec Gel PV YP 10 sec gel MBT PH API FI 10.7 40 - 60 12-14 15-21 15-20 6-8 9.0- 9.5 <6 Production Mud Properties: Quickdril I 6-1/8" hole section I Density (ppg) TauO PV YP LSYP MBT pH API FI 8.3 - 8.6 3-7 7 -11 30 - 35 8-14 <6 9.0 - 9.5 4-6 Logging Program 8-1/2" Intermediate: Sample Catchers - None Drilling: Dir/GR/Res- Real time Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - over entire interval, samples described Drilling: MWD Dir/GR/Res/ABI - Real time; Den/Neu - recorded mode Open Hole: None Cased Hole: None C-23B Permit to Drill Page 2 ~I, Cement PrOQram Casing Size I 7" 26#, L-80 Intermediate Liner Basis: lead: None Tail: Based on 8p~hoe track, 768' of 7" X 8-1/2" open hole with 40% excess, 150' 7" X 9-5/8" Liner lap, and 20Q>~ ~5/8" X 4" OP excess. Tail TOC:~29/MD (TOl) I Total Cement Vol~ lead None Tail 43 bbls, 239 ft3, 206 sacks Class G @ 15.8 ppg, 1.16 ft3/sack ~,/ Casing Size I 4.5" 12.6#, L-80 Production Liner Basis: lead: None Tail: Based on 80' shoe track, 1471' of 4-1/2" X 6-1/8" open hole with 40% excess, 150' 4-1/2" X 7" Liner la~, 00' of 7" X 4" OP excess. Tail TO .91 MO (TOl) I Total Cement Vo: lead None . Tail 43 bbls, 239 ft3, 206 sacks Class G @ 15.8 ppg, 1.16 ft3/sack / Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Oiverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test Integrity Test - 8-1/2" hole Production Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casingn" Liner Test Integrity Test - 6-1/8" hole Planned completion fluids 3073 psi (7.1 ppg @ 8324' TVOss) 2241 psi (.10 psi/ft gas gradient to surface) Infinite with aæ2 g FIT Rams test to, psi/250 psi. Annular test t,500 psi/250 psi 3500 psi surface pressure 12.0 ppg FIT after drilling 20' outside window /3306 psi (7.1 ppg @ 8955' TVOss) / 2411 psi (.10 psi/ft gas gradient to surface) Infinite with 9.6~IT Rams test toß,5"O.eJ psi/250 psi. Annular test(to'""2.,SOO psi/250 psi 3500 psi sulÌãêe pressure 9.6 ppg EMW FIT 8.4 ppg Seawater / 6.8 ppg Diesel Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at 08-04. Any metal cuttings will be sent to the North 810pe Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to 08-04 for injection. Haul all Class I wastes to Pad 3 for disposal. C-23B Permit to Drill Page 3 it ( Sidetrack and Complete Procedure Summary Pre-RiQ Work: 1. Rig up slick line, drift 5-1/2" tubing to top of fish at - 8,742' MD. 2. Fluid-pack the 5 Y2" tubing and 9-5/8" x 5 Y2" annulus to surface. 3. R/U E-line. RIH with Chemical cutter and cut the 5 Y2" tubing at -8,692' MD. 4. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect top 2200' MD with diesel. 5. Test the 9-5/8" pack-off and tubing hanger seals to 5000psi for 30 minutes. Function all Lock Down Screws, repair or replace as needed. 6. Bleed casing and annulus pressures to zero. 7. Set a BPV in the tubing hanger. Secure well. 8. If necessary, level the pad. Please provide total well preparation cost on the handover form. RiQ Operations: /' 1. MIRU Nabors 2ES. 2. Pull BPV. Circulate out freeze protection an~isplace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull 5-1/2" tubing from above pre-rig cut. 5. PU and single in DP with watermelon mill to top of 5-1/2" tubing stub. 6. Circulate well with clean seawater. ,/'/ 7. MU bridge plug on e-line with CCL. RIH and set at -8600' MD, set as needed to avoid cutting a casing collar. 8. Pressure test casing to 3500 psi for 30 minutes. /' Mf<:f 9. RIH with 9-5/8" Baker bottom trip whipstock assembly. Orient whipstock and set on bridge plug. 10. Displace well over to 10.7 ppg milling fluid. /' _ 11. Mill window in 9-5/8" casing at -8575' MD, plus 20' past middle of window. Perform FIT. POOH 12. MU 8-1/2" drilling assembly with Dir/GR/Res and RIH. Kick off and drill the 8-1/2" intermediate ,- interval, dropping and turning at 5°/100' to a 19° hold angle. 13. Drill ahead to casing point at Top Sag River to an estimated depth of 9,344' MD. 14. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing to 8,425' /' MD. Displace cement with mud. POOH. 15. MU 6-1/8" BHA with Dir/GR/Res/ABI/Den/Neu and RIH to the landing collar. /' 16. Pressure test wellbore to 3500 psi for 30 minutes. 17. Drill shoe track. Swap over to 8.6 ppg mud and drill 20' of new formation. Perform FIT. 18. Drill the 6-1/8" production interval building at 11 °/1 00' to horizontal, targeting Z2A Ivishak. Drill ahead' /" to an estimated TD of 10,822' MD 19. Run and cement a 4-1/2" solid liner throughout the 6-1/8" wellbore and back into the 7" dri!ÿng liner to 9194' MD. Displace cement with perf pill and clean seawater. Release from TOL. /' 20. Displace well to clean seawater. 21. RIH with DPC perf guns. Perf intervals to be determined from LWD logs. /' 22. POOH. LD DP and perf guns. / 23. Run 4-1/2",12.6#, L-80 completion tying into the 4-1/2" liner top. 24. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. /" 25. Set and test TWC. 26. ND BOPE. NU and test the tree to 5000 psi. 27. Freeze protect the well to -2200' and secure the well. 28. RDMO. Post-RiQ Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. C-23B Permit to Drill Page 4 (' ( C-23B Drilling Program Job 1: MIRU Hazards and Contingencies ~ No wells will require well house removal or shut-in for the rig move onto C-23B. The closest neighboring well is spaced as follows: C-24 at -110'. Care shou Id be taken while moving onto the well. Spotters will be used at all times. ~ C-Pad is not designated as an H2S ~ite. However, Standard,ºperating P~ocedures for H2S /'" precautions should be followed at all times. Recent H2S data'frorp the pad IS as follows: ,/ I The maximum level recorded of H2S on the pad wa)s10 pp,~ on C-26A and C-27A in 10/22100.1,,-:__/.-/" )0> Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP ~~'¡;¡.-,-,:,:.:.a)¡l,:"".~,':,',',':;;,':,',',':,',".'¡;.::;,:;:;,·.:..:;.:,:,:.;,:,:;;,:;m,,~.~,I,~~~~¡",lm/o.l!om,¡,I',I.I,~OO,~-,:;":;,:'-:',I.\'~.-:;;:,·;:;;;#:.:,:;;":;'.;,:,;,;,.,.;..,.',.,.m,·,:,.;'"'".mm..m......"'_·,w,,·^"',~,,...,1,L,I,I'!,~.I,I,lmm.~:.::,:.·,:þ.I,,I,I!,I):I:!,I!;,;;:,',.;,w.·,:;;.,...,·,·.:..,,:,·..;,·'.wm,·'~,:,IKlm.I,~.,I,I.I,I,I.Q',:mm,I',~',:,:,I!,I),,I¡.m,:¡.,~¡.¡.;,~AI,-,,-;:!,-,-~..~ Job 2: De-complete Well Hazards and Contingencies » C-23A is currently Shut-in with a coil tubing fish and unfired perf guns. Pre-Rig operation will NOT include cement work. The existing perforations were cement squeezed in 10/97 during a planned Gas Shut-off Procedure. ~ Note and record required PU weight to pull tubing at cut point. ~ NORM test all retrieved well head and completion equipment. » Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP -'".W"......~····~,,~""~~·A"'...·...WAW".·'.~...·N.MM'oM~ _I ~., ·..··X·······..V...W".,·.....·..WU"...·"""N..W...'''j.,..''''.'.."."....~~-t« ·······..··..··....:;::;;¡_ioI.o,..··-"~~ . .... Job 4: Window Mill Hazards and Contingencies » Position bridge plug to avoid cutting a casing collar while milling the window. » Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP 1;\,'::.'ii;~I:I$:I'~¡.,,~W"~:-:..~,~~~',""w.w.'!\"X~~W,;;l;"<':O:>:<N:<\I:W\~I:I.I;I,W;;~M¡.~I;\,~::v:~I),~~~~~.').~~ ;:~~~..:';;*"~,~~"...~..,'---_.-~,-"'~.""""'~-- C-23B Permit to Drill Page 5 ( I~; ~, Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies » The intermediate section will kick off in the Kingak IF' inteNal and TD at the top of Sag River. Since C-23B will be at -370 inclination at a 1880 azimuth, maintain mud weight at minimum 10.7 ppg to inteNal TD. Follow all shale drilling practices to minimize potential problems. » There are no fault crossings in the intermediate section. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. » There are no close approach issues while drilling the intermediate hole section. » KICK TOLERANCE:9ge worst-case scenario of 8.8 ppg pore pressure at the Sag River depth, a fracture gradient~' 12. ppg at the 9-5/8" casing window, and 10.7 ppg mud in the hole, the kick tolerance is)nfinit . Reference RP C~ .:. "Shale Drilling, Kingak and HRl" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" :;n¡¡,I¡m;,IJ,I¡,IJJ~,I,;,l)i!m~m;IW.l,l,IÞ',I,I",a,I''¡¡,~',I,:,:!A~,,:;,-,.,\\,I;"'-!,-,~.a!,:,-.¡,'-"-.',',-,:,IJ.-!.wm,lmm¡,I,I.I.I,I,I,IHI).;,I',I,I,I,!J,I.I,IJ,I,I.I)!,I,I/I,I',I',:,I.I,I,I,I,I),I,D..m,:,:'A'D,:,Iffl,W,~,_,';',,_.:,:.ø.:,).-.-!¡A:;.a,\:,~,:!,I;',I",-.),I.I.:mm,I,-.-wn,:J',!,l;mml,:,lJ.Imm!i~I!,I,IAlmmm.lu.:,:,:¡'.I;AI,_,:,),I,:':;,:;!!,:.C,_.,_.~_...:,:,I;:',-;;;K.-¡,-,-.:¡;,-',,:.I,I.~-::,,:.I.'!,I,I.w.J~:m,I,:;.:,I.:;':~~~W.~'Þ,:;l!cJ.:J.Im,I,v.:m,u.uJ,1,I. Job 6: Install 7" Intermediate Liner Hazards and Contingencies » Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. » Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP ~.,,~::G,';,"~'~'~'~~~~':<;~::;~>:<:~~~~~'!':~~_,(_:>':~_':<;;:(>:~'~"~~ <~~«.~y:~'(~:.-.:~~~~~~~,.;«~ ~~.:.:<:~~~o:o:<:~~~w:;:~.w:~~<,,*,~,~~~.~ Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies » A pump out sub will be run in the BHA to aid in placing LCM material. » There are no fault crossings in the production section. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. » There are no close approach issues while drilling the production hole section. C-23B Permit to Drill Page 6 (' ( ~ KICK TOLERANCE: In the worst-case scenario of 8.8 ppg pore pressure in the Ivishak, a fracture gradient of 9.6 ppg at the 7" casing window, and 8.6 ppg mud in the hole, the kick tolerance is Infinite. Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP ".. T >'flfpj, ~LllmllL .\.IIL.' __ --.-.-...¡-- ..'" r--;.--· .....'10'111. _I. .'IU__I":!!:I..I.I._I..II__I I 'I(--'UIIII;-;-- "I'WIIL~··"''''I!III_III_.IL _I. .I L _I. _1_'1.1· Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies >- Differential sticking is a concern. The 8.6ppg mud will be -700psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. >- Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner. ~ Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. ~~;,.w,M~I..M~;"',,-;'+'I;:I:I:~~ .~ ~:':'iI,I,-;.MI,I;.;"-,'"I,.,0,;;';'-~;';'-';'-.;'','!'H''''<:1o:~~:';'M-~~;''''''',\'''I,V.,:A~,;':'.,,;'''''...·,,·~~AA!;.""-;.;;.;.;.:¡.p,I..I.M"AA~-M,-¡.;.¡.,;,;.-...-¡.,.¡..~,·~;m-;;...,-;.,-;..-;.,"'A...."'4,-;.,.;.,.A;~·....~~·"~....,:"",·"""m."""'_I<<;<;,...........~¡ifo¡"I,\IPil/"'!~w¡,;~i'Þio,;"''''''-¡¡';''~...,'';...I,I,L,.,,\,,,,;MI#I,I,1):~ Job 10: DPC Perforate Production Casina Hazards and Contingencies >- Observe Halliburton's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. Reference RPs .:. Follow Halliburton perforating practices and recommendations. .:. UDPC Perforating" RP _«~_.w-W"''(oI...........,..,..~.Nio.·'_'~'''''~''''w..I-.v'v...,~~_X_<»:«-»I«<+I(_«-»(~''U'~""'W'Ü'."'..'>.__,. _W«I«_««<<<,..."'...".·AW.....~~_:(~(..O':o'-.,'W...._._~....,.~~~~ Job 12: Run Completion Hazards and Contingencies >- Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP H>K¡;=¡;~¡.¡;.~._~~"W,·...,·'u·:I'> . ·:··,w....,...,...."',..._...>_,'--/._,_ ....~....l'...,·...·......''I1~....'>;.w.__~"...."''w,.,..·,_ »»:_....",.....,~y.:,.m.¡;¡:,»i«::..,,"".,~.,..:~ Job 13: ND/NU/Release Ria C-23B Permit to Drill Page 7 ( {' Hazards and Contingencies ~ No wells will require well house removal or shut-in for the rig move onto C-238. The closest neighboring well is spaced as follows: C-24 at -110'. Care should be taken while moving onto the well. Spotters will be used at all times. Reference RP .:. "Freeze Protecting an Inner Annulus" RP C-238 Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Intermediate Hole Section: · There are no close approach issues. · Differential sticking has been experienced in the past. Keep pipe moving at all times. · Lost circulation while drilling has not been problematic at C-Pad. In the event of lost circulation, consult the LCM Decision Tree. · The intermediate hole section will be drilled with a recommended mud weight of 10.7 ppg to ensure shale stability in the Kingak. · Kick tolerance is Infinite with a 12.0 ppg LOT. · There are no fault crossings expected in the intermediate hole section. Production Hole Section: · There are no fault crossings expected in the production hole section. Lost circulation risk is low. Use LCM Decision Tree in the event of losses. · Unexpected Faulting could cause drilling out of zone. Monitor drilling trends and cuttings. · Kick tolerance is Infinite. · Differential sticking had been experienced in other long horizontal sections. Keep pipe moving at all times. HYDROGEN SULFIDE - H2S /'- · This drill-site not designated as an H2S drill site. Recent tests indicate a very low concentration of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE C-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION C-238 Permit to Drill Page 8 C-23A TREE = W8...LHEAD = ACTUA TOR = ·tfB-:-KÉ~}·;-·-·-- BF. 8...EV = i<õp ;----....-.-'.... ~!~ngle = Datum MD = Datum ìVD = 6" McEVOY McEVOY ~-""~.--~~._--.,.,-,,,,- OTIS ·....·..·..-..·---64.9Î 39.4' ......._..h...¥".......~..._ 4000' 94 @ 11300' 1 0001 ' 8800' SS I 9-5/8" DV A<R 1-1 2622" ~= 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2694" µ Minimum ID = 2.372" @ 9015' TOP OF 2-7/8" LINER TOP OF DAMAGED 4-1/2" OTIS GS FN (CTM) 1-1 8742" 1 1 TIWTIEBACKSLV,ID=3.76" I--{ 8997" 1 5-1/2" X 3-1/2" TIW LNR A<R/ HGR, ID = 2.44" 1-1 9005" I I TOP OF 2-7/8" LNR, ID = 2.372" 1-1 9015" 1 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 1-1 9059" g I 7" BOT LNR HGR W/ TIEBACK 1-1 9176" I -¡ r 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 9242" I l 9-5/8" CSG, 47#, L-80, 0.0732 bpf, ID = 8.681" 1-1 9442" ~ ÆRFORA TION SUMMARY REF LOG: MWDlGR on 10/02/96 ANGLE AT TOP ÆRF: 84 @ 11060' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-9/16" 4 11060 -11140 S 10/25/97 1-9/16" 4 11200 -11420 S 10/25/97 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" l-i 10358" I DATE 09/04/82 -10/06/96 02/05/01 03/09/01 08/28/01 DATE REV BY REV BY COMMENTS ORIGINAL COMPLETION SIS-lsl RIG SIDETRACK SIS-1s1 CONVERTED TO CANVAS SIS-LG FINAL CH/KAK CORRECTIONS S1~9Y NOTES: FISH AT 8742' (CTM) IS 1536' OF 1-3/4" d{ 3G AND 25' OF LIVE 1-11/16" SWS TCP GUNS. TOP OF COIL HAS A DAMAGED 4-1/2" OTIS GS FN LOOKING UP. BTM OF FISH @ +/- 10317'. W8...L > 70 DEG @ 10120' AND> 90 DEG @ 11238'. (f) 2112" 1-1 5-1/2" OTIS SSSVN, ID = 4.562" 1 GAS LIFT MANDR8...S - ST MD ìVD DEV ìYÆ VLV LATCH PORT DATI - 13 3070 2999 1 OTlS-LBD DOME RA 16 1 0/27/~ 12 4519 4421 23 OTlS-LBD S/O RA 20 1 0/27/~ .. 11 5480 5210 40 OTIS- LBD DV RA 0 10/27/~ 10 6149 5714 42 OTlS-LBD DV RA 0 10/27/~ L 9 6306 5831 42 OTlS-LBD DV RA 0 1 0/27/~ 8 6799 6199 40 OTlS-LBD DV RA 0 1 0/27/~ 7 6955 6318 40 OTlS-LBD DV RA 0 1 0/27/£ 6 7450 6704 37 OTIS-LBD DV RA 0 1 0/27/9 5 7607 6831 36 OTIS-LBD DV RA 0 10/27/9 4 8191 7310 34 OTIS-LBD DV RA 0 10/27/9 3 8348 7441 35 OTlS-LBD DV RA 0 10/27/9 ~ 8673 7702 38 OTIS-LBD DV RA 0 10/27/9 '_I 1 8830 7824 39 OTIS-LBD DV RA 0 10/27/9 8742"ctm 1- FISH - 1536' OF 1-3/4 COILED TBG W/ BHA. ~ f BHA HAS 25' OF LIVE 1-11/16" TCP GUNS. 1 9023" 1-1 5-1/2" OTIS XA SLIDING SLV, ID = 4.562" I I ~ 9059" 1-1 TOP OF OTIS PBR 1 9079" 1-1 9-5/8" x 4-1/2" OTIS PACKER 1 9159" 1-1 4-1/2" OTIS X NIP. ID = 3.813" 1 9204" 1-1 4-1/2" OTIS XN NIP, ID = 3.800" 9243" l-i 4-1/2" WLEG I I I ~ 7" MILLOUT WINDOW 9949' - 9964' (CMf KO PLUG) CAUTION: BTM OF 1-3/4" CT FISH @ +/- 10317'. BHA HAS 25' OF LIVE 1-11/16" SWS TCP GUNS ON BTM. 1 PBTD 1-1 11567" 1 12-7/8" LNR, 6.4#, L-80, STL, .0058 bpf, ID = 2.441" l-i 11662' COMMENTS PRUDHOE BAY UNIT W8...L: C-23A ÆRMrTNo: 96-1190 API No: 50-029-20775-01 1315' SNL & 1030' W8..., Sec. 19, T11N, R14E BP Exploration (Alaska) SAFETY NOTES: FISH AT 87 42' (~,~\ IC) 1536' OF 1-3/4" COIL TBG AND 25' OF LIVE 1( 6" SWS TCPGUNS. TOP OF COIL HAS A DAMAGED 4-1/2" OTIS GS FN LOOKING UP. B1M OF FISH @ +/- 10317'. WELL> 70 DEG@ 10120' AND> 90 DEG @ 11238'. NOTE: CHARGES ARE NO LONGER TREE = 6" McEVOY WELLHEAD = McEVOY ACTUATOR = OTIS KB.-Ëi.EV = "-"'-'''--'--'--'''6'4:~F 'äF~"ELËV''';'''''''''''''' ",··"_·....·,,,··,,..,,""·.."39:4; 'ROp =..··----·..'·........'......·..···-'-·....'..-....-4006; . , .,. ^ , Max Angle = 94 @ 11300' Datlïm'MÓ; .. .,. -···-........·---:¡OOO'1ï Datum lVD = aâoõ"ò'šs' . C'-23A Pre-Rld I 9-5/8" DV A<R l-i 2622' 13 3/8" CSG, 72#, L-80, 10 = 12.347" 2694' 51/2" TBG, 17#, L-- 80, .0232'bpf, 10 = 4.892" 9059' (f) -I 2112' l-i 5-1/2" OTIS SSSVN, 10 = 4.562" I GAS LIFT MANDR8..S ST MD lVD DEV lYÆ VL V LA TCH 13 3070 2999 1 OTIS-LBO DOME RA 12 4519 4421 23 OTIS-LBO S/O RA 11 5480 5210 40 OTIS-LBO DV RA 10 6149 5714 42 OTIS-LBO DV RA 9 6306 5831 42 OTIS-LBO DV RA 8 6799 6199 40 OTIS-LBO DV RA 7 6955 6318 40 OTIS-LBO DV RA 6 7450 6704 37 OTIS-LBO DV RA 5 7607 6831 36 OTIS-LBO DV RA 4 8191 7310 34 OTIS-LBO DV RA 3 8348 7441 35 OTIS-LBO DV RA 2 8673 7702 38 OTIS-LBO DV RA 1 8830 7824 39 OTIS-LBO DV RA FQRT DA TE 16 10/27/97 20 10/27/97 o 10/27/97 o 10/27/97 o 10/27/97 o 10/27/97 o 10/27/97 o 10/27/97 o 10/27/97 o 10/27/97 o 10/27/97 o 10/27/97 o 10/27/97 1-= j - - ~ L ~C>-- - r-<::::; ~ Pre rig tubing cut at 8692', I I T1W TIEBACK SL V .I-i 8997' I~ -~ 5-1/2" X 3-1/2" TWV - -~ F 8742' FISH - Top of damaged 41/2" Otis GS FN. -.. LNR A<R / HGR, 10 9005' 1536' of 1 3/4 coiled tubing w / BHA. = 2.44" /1 1 9023' l-i 5-1/2" OTIS XA SLIDING SLV, 10 = 4.562" I TOP OF 2-7/8" LNR, 10 = 2.372" 9015' ~ ~I 9059' l-i TOP OF OTIS PBR 1 -I 9079' l-i 9-5/8" x 4-1/2" OTIS PACKER I 7" BOT LNR HGR 9176' W/ TIEBACK 4-1/2" TBG, 12.6#, - L-80, .0152 bpf, 10 9242' = 3.958" ~ 9-5/8" CSG, 47#, L-80, 0.0732 bpf, 9442' ID = 8.681" 7" MILLOUT WINDOW 9949' - 9964' (CMT KO PLUG) 7" LNR, 26#. L-80, - .0383 bpf, ID = 10358" 6.276" 9159' l-i 4-1/2" OTIS X NIP, ID = 3.813" I 9204' l-i 4-1/2" OTIS XN NIP, ID = 3.800" 9243' l-i 4-1/2" WLEG I Minimum ID = 2.372" @ 9015' TOP OF 2-7/8" LINER I I ~ ÆRFORA TION SUMMARY REF LOG: I'v1\ND/GR on 10/02/96 ANGLEATTOPÆRF: 84 @ 11060' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-9/16" 4 11060 -11140 S 10/25/97 1-9/16" 4 11200-11420 S 10/25/97 CAUTION: BTM OF 1-3/4" CT FISH @ +/- 10317'. BHA HAS 25' OF LIVE 1-11/16" SWS TCP GUNS ON B1M. NOTE: CHARGES ARE NO LONGER ACTIVE. 2-7/8" LNR, 6.4#, L- - 80, STl., .0058 bpf, ID 11662' = 2.441" DATE 09/04/82 1 0/06/96 02/05/01 03/09/01 08/28/01 REV BY COMMENTS ORIGINAL COMPLETION SIS-lsl RIG SIDETRACK SIS-Is I CONVERTED TO CANVAS SIS-LG FINAL CHlKAK CORRECTIONS PRUDHOE BA Y UNrr WELL: C-23A ÆRMIT No: 96-1190 API No: 50-029-20775-01 1315' SNL & 1030' WEL, Sec. 19, T11N, R14E BP Exploration (Alaska) DATE 01/02/03 03/20/03 REV BY dew RBT COMMENTS Proposed pre rig Proposed pre rig -l 2200' H 41/2" 'X'landing nipple.ID = 3.813" TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumlYD= 6" I\t1cEVOY I\t1c EV OY OTIS 67.9' 39.4' 8575' 90° @ 10300' 10300' 8955'SS C'·238 Propd...ied Completio~. I 9-5/8" DV PKR 1-1 2622' 1-: j ~ GAS LIFT MANDRB...S ST MD lYD DEV lYPE VLV LATCH SIZE 6 3000 1.0° DV RA 4 1/2 X 1 1/2" 5 4000 13.0° DCK RA 4 1/2 X 1 1/2" 4 5500 41.5° DV RA 4 1/2 X 1 1/2" 3 6500 39.0° DV RA 4 1/2 X 1 1/2" 2 7250 33.6° DV RA 4 1/2 X 1 1/2" 1 8000 37.5° DV RA 4 1/2 X 1" 8425' 11 9 5/8" X 7" 'ZXP liner top packer w / TBS, 'HMC liner hanger 13 3/8" CSG, 72#. L-80, ID = 12.347" 2694' ---1 ~ 8 / - 9135' 1-1 41/2" 'X' Nipple. ID = 3.813" 9150' 1-1 7" X 4 1/2" Baker S-3 Packer 1 9165' 1-1 41/2" 'X' Nipple, ID = 3.813" - I 9180' 1-1 41/2" 'XN' Nipple, ID = 3.725" \ ~'S1t; 95/8" Bridge Aug. 8600' - ~ b 9193' 1-1 7" X 5" 'ZXP liner top packer w / I TBS, 'HMC liner hanger 9343' 1-1 7",26.0#, L-80 liner. BTC-M 9-5/8" CSG, 47#, L-80. 0.0732 bpf, ID = 8.681" ~t- .. ~ 9442' . 7" MILLOUT WINDOW 9949' - 9964' (CMT KO A..UG) I ,j.o~ 1-1 4 1/2", 12.6#. L-80 liner. IBT-M 10 81..3 ¡ 7" LNR, 26#. L-80. - .0383 bpf. ID = 10358' 6.276" DATE 09/04/82 1 0/06/96 02/05/01 03/09/01 08/28/01 REV BY COMMENTS ORIGINAL COMA..ETION SIS-lsl RIG SIDETRACK SIS-Is I CONV ERTED TO CANVAS SIS-LG FINAL CHlKAK CORRECTIONS DATE 01/07/03 03/24/03 REV BY dew RBT COMMENTS Proposed completion Proposed completion PRUDHOE BAY UNIT WELL: C-23B ÆRMfT No: API No: 50-029-20775-02 1315' SNL & 1030' WEL, Sec. 19. T11N, R14E BP Exploration (Alaska) ( SOHIO ALASKA PETROLJ:~U~ COHPAHY WELLHEAD lOCATION DATA . 1) HE L L C - 23 2) Pad C EXT 3) \'!e 11 head Loca t ion 131SSNL l030h'EL x = 664,349 y = S,9S9~903 LAT. 70° 17' 48.38" LONG. 148° 40' 08.69" 4) Bearing of Gyro l'~arker N6° 26'W Light Pole (Tr'ue) 5) local Bench~ark Elevation MJN C-2 38.88 Ft. ANSL 6) Top Edge of Cellar * 37.10 Ft. At· ~ S l 7) Base Flange Elevation ~~ . L\ Ò Ft. A:·\SL 8) Kelly Bushing Elevation \\.~) Ft. At'~SL * Base Flange and Kelly Bushing NOT Installed This Date. NOTES: 1) Items 1 and 2 should be filled in by the Drilling Supervisor on the rig when a new well Spu9S in. 2) The surveyor should fill in Items 3, 4, 5 and 6. 3) The completed form should be returned to Drilling Dept. for distribution. 4) The bearing of the Gyro rl¡arker ;s required as a True, not a l'~agnetic bearing. 5) Base Fl ange and Kelly Bushi ng E1 eva t ions measured by the Dr; 11 i n9 Supet-v i sor. \ District Field Engineer - 2 District Drilling Engineer/Drilling Engineer - 1 Slope - to Rig for Posting - 2 Well Record Clerk, Geology - 1 :'~ell Fil s [nginccl ing Þ.ssociate, Drilling - OrigÍl:Jl PetrolcJm Enginc0ring, SFO -1 Ell e r. H. ;.~ ; 11 e r --.~,"'~\\ -.....~ of A( \, :-t:5. ~ ......... 4_n I, ~~r .... ~ -'. v+ f, ", G;) ..':- ':~ ". -ÿ., $*f' 9!!! ~ \-tt~ e· ... · ·········h-(41····· . · ~ ~ ..... .. "..{h... ..;- ..I! .,~' I' .~¡t 'i t¿; ":.. Gary L MtNcU ..:.~ iJ ,~ ~ . . ~ "'. ""~ .. lS-S121 .. ~ " .... ~ .... ,.- ~~ ,., .., <"'ð.o ..........~'\";,,~-:' ~ \. ~";ES~I'~:~,,\. \. __q,r '\.",,'~,~~ April 20, 1982 ----- - --------r-;t~e------ -- ---- C IRe U LA T I (.: ~ : , Start Dir 121100' : 8575' MD, 7694.%'TVD --1' Start Dir5/100': 8595' MD, 771O.85'TVD --r i '! i I I ! ¡~! TJþ- ~ i TtC/ ¡ ) i I ,I -T11· ¡ I: I : ! ¡ TJA¡" i i I I , I -dOR ~ ~ Start 101100' : 9359.5' MD, 8407.9'TVD -! 7' 71 End Die 9377.76'MD,8425.16'TVD ~~ I ! I Start Die 1100' : 9463.69' MD, 8506.38'TVD ~AJ ~i I '}500 ¡ I: : ,! i i ¡ ¡ ¡! fooù{rza I I! ! J ! I I I...;¡¡ ¡ i i ¡ I ¡ ..J.~ ~ I BCGf' If"'C , I 'I I . ! I : i 23fBtTZ2Bu ! i I 2TIW?QI ! !' I ¡ : I : I I ! I I il- I I I I , I , I I I o 9000 :5 8250 ~ ~ £!. ..c ø. ~ '" <.> 'f ~ $ 8500 8150 p-23 I Vertical ~-:!3) I 250 i~ 0,. N:Þ~: ~ 1'1 VI cJdOOir) ¡ fJ ~ I " I ¡ ¡ I ¡ I \ I, \ \ I 500 Section at 268.31° [250ft/in] &, op i i ¡ , End Dir : 10311.83' MD. 9027.9' TVD / Start, Dir,,8II,00', : 1,0386, .83' MD. ~27'9'TVD,' , ! End Dir : 10665.82 MD,9025.53 , '/ "I ';'" ¡, 'I f-23B wp03 : I I . _ Iii 1 I ¡ I 'f--o"-/ I ; , '~J€€: ' I ' I' I I t ¡---<\ i , I I '!' I , , I ' . , ¡! : i I i I I I ! r r 112" ~oIal ~~; 10822.56' MDJ~2.¡" TVD ¡ Iii ¡ i I I ! [I, I I I I I ¡ i I; I--¡- I " I '" I , I \ \ I 1 SO 1000 I 1250 TVD ,I I ,I ¡P I I 1fP ,I ,I ,I "I o ¡ /// 1 ;/ Y:/ 1 1// >", ,:// /' /,,( !//: !""):1/.: / :: ; , /' ,./ ' ,.. . ,/ : ,': ' ¡ ,.: ' ~"",'/"',,:..·V\ ",/ .:/., " ,/,' /V: 0://- d311!:// , ' ' '/ ' ' :: : /Í' ", ; i :,) , Hi ! ',~/,',',/ ://v" /J¡i //1/; . ;t' /: /; /j ::t: ,) ; : ': ~ ! :.1 '/.. 0q, ""..?O{;þ 1ft ,~ ..,~ /" ~ '..S) t) ~ ~o /q,o ~""- 8000 1150 All TVD depths are ssTVD plus 67.9'for RKBE. O···bP " OOMPANY DETAIlS BP Amoco CakuIaôoo M_ Minirmm Cur\'OIUre Enor Sysæm: ISCWSA Scan M_ T",v Cylioœr Nonh Enor Suñaœ: EßipcDI + Casing WamioR M_ Rules Bas:d REFERENCE INFORMATION Co-onIinaIe (N'E) Rd'erenœ: WeD Ceobe: C-23. True Nonh Vertical (TVD) ReIèn:1Jœ: 67.W 67.90 Sedioo (VS) Refereoœ: UserDefiœd(-2653.53N.-458.27E) Measured Depth Rd'erenœ: 67.W 67.90 Calculatioo M_ Minirmm 0IMdure CASING DETAILS No. TVD MD Name Size 1 8392.90 9343.62 1" 1.000 2 9022.90 10822.55 41/2" 4.500 FORMATION TOP DETAILS No. TVDPath MDPath Formation I 8018.90 8941.61 TJD 2 8119.90 9054.62 TJC 3 8306.90 9252.58 TJA 4 8382.90 9333.04 TSGR 5 8436.90 9390.19 TSHU 6 8492.90 9449.43 TSAD 1 8681.90 9651.49 TCGUfZ3 8 8111.90 9162.22 BCGLrrZ2C 9 8839.90 9841.18 23SBITZ2Bu 10 8886.90 9901.91 22TSlfZ2BI 11 8941.90 10010.98 21TSm2A 12 8961.90 10039.26 PGOC SECTION DETAILS See MD lne Azi TVD +N/-S +E/-W DLeg TFace VSee Target 1 8515.00 31.26 188.21 1694.96 -2653.53 -458.21 0.00 0.00 0.00 2 8595.00 31.53 184.34 1110.85 -2665.60 -459.60 12.00 -85.00 1.61 3 8963.01 19.15 186.28 8033.36 -2838.89 -414.82 5.00 111.98 21.8\ 4 9359.50 19.15 186.28 8407.90 -2968.20 -489.05 0.00 0.00 39.70 C-23B Shu 5 9311.16 19.05 191.85 8425.16 -2914.10 -489.99 10.00 96.04 40.81 6 9463.69 19.05 191.85 8506.38 -300 1.54 -495.15 0.00 0.00 41.35 1 10311.83 90.00 292.00 9021.90 -2911.06 -1044.29 11.00 99.60 594.19 C-23B TI 8 10386.83 90.00 292.00 9021.90 -2942.91 -1113.82 0.00 0.00 663.51 9 10665.82 90.96 314.30 9025.53 -2191.38 -1345.93 8.00 81.41 891.21 10 10822.56 90.96 314.30 9022.90 -2681.93 -1458.09 0.00 0.00 1000.22 C-23B T2 TARGET DETAILS Name TVD +NI-S +EJ-W Nonhing C-23B Sbu 840790 -296820 -489.05 5956925.00 C-23B 1'2 9OU90 -268193 ·1458.09 5957190.00 C-23B Poly 9022.90 ·294024 -1538.77 5956930.00 C-23B TI 9027.90 -2971.06 ·1044.29 5956910,00 -II Shape 663925.00 Point 662950.00 Point 662875.00 PoIy¡¡oo 663370.00 Point Depth Fro Depth To '5.00 10822.56 Name +NI-S C-23 264492 SURVEY PROGRAM Sun'C)'lPIao P\anDed: C-23B ..p03 V6 +EJ-W 1856.71 Tool MWD WELL DETAILS Nonhiog Eastiog S9S9902.98 664349.00 Checked: Plan: C-23B "-1'03 (C-23IPlan C-23 B) CreaIed By: Ken Allen latilUdo LooIPIUdo 70"IT48.378N 148"40U8.677W SIoI 23 Date: Date: -= :§ ~ ~ +' ~ o ~ ::ë' ':; o (/) 3000 -2750 I I I: ,\! I' I 'I I J ¡ 11L': !; ¡ I I: i I! ¡ I: I! , I I I I I I: I I C-2~ B WØJ3! Ii: I! ¡ i \ ' 1<J,taI Deptþ: 1082Z.~6' \tJ, 90J2.~ ~vþ : I I 4,1£ I ! Lii' !! , I I:, I I C-233' 1 i : I, I ! I tl I 106~5.82' _1, 902515,- ~I' ! I I I, Mp : R. ': ' i ! !! I : Ii,!! i ! I ! I I I !! i I; II I I I I ! , : I' i '. I I .' I: i I ¡ ¡ ¡ ¡ I I i ¡ ! :! 't:vt ~r 81 ',. I 8~ 83' ~ ,90:'7 ''TVI> I ~IY I ! : Ent:- ~r , 103' l.&3PP, 907f9' riD! ! ¡ ~ I C-23B~ ! ¡! I I ¡ I! r---- ¡ I I!· ì--~i ! III ~- I 1/1: ! ¡ I ! I I.: !~;, !~OW! i I I ! I I ¡ ! ! !. ! ! 'I I !; ¡! 'I' : !! C 23 (C "3) i' I \ ì I I I I I I I 1 I I ¡ I' !! i I I ! t23 ~C-f3f) \I I l ,\ \ ; ì I ¡I I, ; I ¡ \I ¡ 500 -1250 -1000 -750 West(-)lEast(+) [250ft/in] ! i i : i I L ~tán 'Jir 121100': 8575' MD, 7694.96'TVD l... f+ Jir 5/100' : 8595' MD, 771O.85'TVD 7Rhol ¡ i EhdiDir : 8963.0I'MD, 8033.36'TVD ../ : I , 8100 I : I , ¡ I I S,w1 Dir 10/100': 9359.5' MD, 8407.9'TVD , . / ~rl!J)¡" : 9377.76' MD, 8425.16' TVD l ~ Ii r 84J01 I /\ Ii 8-0(" st.årtbir 111100' : 9463.69' MD, 8506.38'TVD 1 I I , ¡ i I ; ! I ~ I I ¡ I I :: \ I ¡;, 500 I -250 I o -2500- All TVD depths are ssTVD plus 67.9'for RKBE. ø '"", ,~ ~~;Sf ~ ~ .,~ /4ò CASING DETAILS No. TVD MD Name Size 8392.90 9343.62 7" 7.000 9022.90 10822.55 4 112" 4.500 WElL DETAILS Name ~NI.s ~fJ·W North ing Easlin8 Lalitude Loogirudo SIo< C-2J 261492 1856.71 59S9902.98 664349.00 70"IT48J71!N 148"4O'OII,677W 2J TARGET DETAJl.S Name TVD ~NI.s +EJ-W Northing Eosting Shape C-2JB SIIu !!407.90 -2968.20 -<189.05 5956925.00 663925,00 Poinl C-2JB 12 9022.90 -2681.93 -14511.1)9 5957190.00 6629S0,OO Poinl C-2JB Poly 9022.90 -2940.24 -1538.77 59SØJ30.00 6628'75.00 Polygoa C-2JB TI 9027.90 -2971.06 -1044.29 5956910.00 663370.00 Poinl SECTION DETAILS See MD Inc Azi TVD +N/-S +FJ-W DLeg TFace VSee Target I 8575.00 37.26 188.27 7694.96 -2653.53 -458.27 0.00 0.00 0.00 2 8595.00 37.53 184.34 7710.85 -2665.60 -459.60 12.00 -85.00 1.67 3 8963.01 19.15 186.28 8033.36 -2838.89 -474.82 5.00 177.98 21.81 4 9359.50 19.15 186.28 8407.90 -2968.20 -489.05 0.00 0.00 39.70 C-23B Shu --. 5 9377.76 19.05 191.85 8425.16 -2974.10 -489.99 10.00 96.04 40.81 6 9463.69 19.05 191.85 8506.38 -3001.54 -495.75 0.00 0.00 47.35 7 10311.83 90.00 292.00 9027.90 -2971.06 -1044.29 11.00 99.60 594.79 C-23B Tl 8 10386.83 90.00 292.00 9027.90 -2942.97 -1113.82 0.00 0.00 663.51 9 10665.82 90.96 314.30 9025.53 -2791.38 -1345.93 8.00 87.47 891.21 10 10822.56 90.96 314.30 9022.90 -2681.93 -1458.09 0.00 0.00 1000.22 C-23B T2 FORMA nON TOP DETAILS No. TVDPath MDPath Formation I 8018.90 8947.67 TJD 2 8119.90 9054.62 TJC 3 8306.90 9252.58 TJA 4 8382.90 9333.04 TSGR 5 8436.90 9390.19 TSHU 6 8492.90 9449.43 TSAD 7 8681. 90 9651.49 TCGLlTZ3 8 8777.90 9762.22 BCGUrz2C 9 8839.90 9841.18 23SBITZ2Bu 10 8886.90 9907.91 22TSrrZ2BI II 8947.90 10010.98 2 ITSrrZ2A 12 8961.90 10039.26 PGOC ö COMPANY DETAILS BP Amoco CaJcuJa6œ Method: Minimum CurwIun: Enor SysIem: ISCWSA Scan Method: Trav Cylinder Nonh Enor Surf"",,: Elliptical + CasiÐg WamiD¡ Method: Rules I!as<d REFERENCE INFORMATION Co-mIinaIe (NIE) Reference: Well C<ntte: C-2J. True Nonh VerûcaJ (TVD) Ref""""",: 67.9(167.90 Sectioo (VS) Refereoc:e: User DefIned (-265353NA58.27E) Measured Depth Reference: 67.9(1 67.90 Calculatioo Medx>d: Minirœm CW'Wbue SURVEY PROORAM Depth Fm Depth To Sun'OylPlan 8575.00 10822.S6!'1amed: C·2JB "pOJ V6 Tool MWD Plan: C-23B wp03 (C-23/Plan C-23B) Crealed By: Ken Allen Dale: Checked: Date: Dale: ( BP KW A Planning Report MAP ( Company: BP Amoco Field: Prudhoe Bay Site: PB C Pad Well: C-23 Wellpath: Plan C-23B Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Date: 1/1512003 Time: 10:28:26 Page: 1 Co-ordinate(NE) Reference: Well: C-23, True North Vertical (TVD) Reference: 67.90' 67.9 Section (VS) Reference: User (-2653.53N.-458.27E,268.37Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: PB C Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5957218.72 ft 662550.03 ft Latitude: Longitude: North Reference: Grid Convergence: 70 17 22.367 N 148 41 2.797 W True 1.24 deg Well: C-23 Slot Name: 23 C-23 Well Position: +N/-S 2644.92 ft Northing: 5959902.98 ft Latitude: 70 17 48.378 N +E/-W 1856.71 ft Easting : 664349.00 ft Longitude: 148 40 8.677 W Position Uncertainty: 0.00 ft Wellpath: Plan C-23B Current Datum: Magnetic Data: Field Strength: Vertical Section: 67.90' 12/16/2002 57537 nT Depth From (TVD) ft 0.00 Height 67.90 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft -458.27 "__'__h__"__'___W C-23 8575.00 ft Mean Sea Level 26.01 deg 80.82 deg Direction deg 268.37 __.___.____0._____._________ +N/-S ft -2653.53 Plan: C-23B wp03 Principal: Yes Date Composed: Version: Tied-to: 1/15/2003 6 From: Definitive Path Casing Points MD TVD Diameter Hole Size Name ft ft in in 9343.62 8392.90 7.000 8.500 7" 10822.55 9022.90 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle DipOirection ft ft deg deg 0.00 TKNG 0.00 0.00 8947.67 8018.90 TJD 0.00 0.00 9054.62 8119.90 TJC 0.00 0.00 9252.58 8306.90 TJA 0.00 0.00 9333.04 8382.90 TSGR 0.00 0.00 9390.19 8436.90 TSHU 0.00 0.00 9449.43 8492.90 TSAD 0.00 0.00 9651.49 8681.90 TCGL/TZ3 0.00 0.00 9762.22 8777.90 BCGL/TZ2C 0.00 0.00 9841.18 8839.90 23SBITZ2Bu 0.00 0.00 9907.91 8886.90 22TSITZ2BI 0.00 0.00 10010.98 8947.90 21TSITZ2A 0.00 0.00 10039.26 8961.90 PGOC 0.00 0.00 Targets Map Map <- Latitude -> <-, Longitude,-> Name Description TVD +N/-S +E/-W Northing Easting Deg Min See Deg Min See Dip. Dir. ft ft ft ft ft C-23B Shu 8407.90 -2968.20 -489.05 5956925.00 663925.00 70 17 19.185 N 148 40 22.927 W C-23B T2 9022.90 -2681.93 -1458.09 5957190.00 662950.00 70 17 22.000 N 148 40 51.163 W ( ( BP KW A Planning Report MAP Company: BP Amoco Date: 1/15/2003 Time: 10:28:26 Page: 2 Field: Prudhoe Bay C.ordinate(NE) Reference: Well: C-23, True North Site: PB C Pad Vertical (TVD) Reference: 67.90' 67.9 Well: C-23 Section (VS) Reference: User (-2653.53N,-458.27E.268.37 Azi) WeUpath: Plan C-23B Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <- Latitude -> <- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min See Dip. Dir. ft ft ft ft ft C-23B Poly 9022.90 -2940.24 -1538.77 5956930.00 662875.00 70 17 19.459 N 148 40 53.512 W -Polygon 1 9022.90 -2940.24 -1538.77 5956930.00 662875.00 70 17 19.459 N 148 40 53.512 W -Polygon 2 9022.90 -2548.45 -1615.23 5957320.00 662790.00 70 17 23.312 N 148 40 55.742 W -Polygon 3 9022.90 -2329.61 -1330.35 5957545.00 663070.00 70 17 25.465 N 148 4047.443 W -Polygon 4 9022.90 -2909.35 -892.90 5956975.00 663519.99 70 17 19.764 N 148 40 34.694 W -Polygon 5 9022.90 -3080.83 -1056.70 5956799.99 663359.99 70 17 18.077 N 148 40 39.466 W C-23B T1 9027.90 -2971.06 -1044.29 5956910.00 663370.00 70 17 19.157 N 148 40 39.104 W Plan Section Information MD Incl Azim TVD +N/-S +EI-W DLS BuDd Turn TFO Target ft deg deg ft ft ft deg/10OO deg/10OO deg/10OO deg 8575.00 37.26 188.27 7694.96 -2653.53 -458.27 0.00 0.00 0.00 0.00 8595.00 37.53 184.34 7710.85 -2665.60 -459.60 12.00 1.37 -19.63 -85.00 8963.01 19.15 186.28 8033.36 -2838.89 -474.82 5.00 -4.99 0.53 177.98 9359.50 19.15 186.28 8407.90 -2968.20 -489.05 0.00 0.00 0.00 0.00 C-23B Shu 9377.76 19.05 191.85 8425.16 -2974.10 -489.99 10.00 -0.59 30.52 96.04 9463.69 19.05 191.85 8506.38 -3001.54 -495.75 0.00 0.00 0.00 0.00 10311.83 90.00 292.00 9027.90 -2971.06 -1044.29 11.00 8.37 11.81 99.60 C-23B T1 10386.83 90.00 292.00 9027.90 -2942.97 -1113.82 0.00 0.00 0.00 0.00 10665.82 90.96 314.30 9025.53 -2791.38 -1345.93 8.00 0.34 7.99 87.47 10822.56 90.96 314.30 9022.90 -2681.93 -1458.09 0.00 0.00 0.00 0.00 C-23B T2 Survey MD loci Azim TVD Sys TVD MapN MapE VS DLS TFO Tool/Comment ft deg deg ft ft ft ft ft deg/10OO deg 8575.00 37.26 188.27 7694.96 7627.06 5957240.24 663948.89 0.00 0.00 0.00 MWD 8595.00 37.53 184.34 7710.85 7642.95 5957228.15 663947.83 1.67 12.00 275.00 MWD 8600.00 37.28 184.35 7714.82 7646.92 5957225.12 663947.66 1.99 5.00 177 .98 MWD 8700.00 32.29 184.69 7796.92 7729.02 5957168.18 663944.42 8.08 5.00 177 .97 MWD 8800.00 27.29 185.12 7883.68 7815.78 5957118.62 663941.27 13.72 5.00 177.70 MWD 8900.00 22.30 185.74 7974.43 7906.53 5957076.80 663938.24 18.85 5.00 177.32 MWD 8947.67 19.92 186.13 8018.90 7951.00 5957059.70 663936.84 21.11 5.00 176.76 TJD 8963.01 19.15 186.28 8033.36 7965.46 5957054.58 663936.40 21.81 5.00 176.39 MWD 9000.00 19.15 186.28 8068.30 8000.40 5957042.50 663935.34 23.47 0.00 180.00 MWD 9054.62 19.15 186.28 8119.90 8052.00 5957024.64 663933.77 25.94 0.00 180.00 TJC 9100.00 19.15 186.28 8162.76 8094.86 5957009.81 663932.46 27.99 0.00 180.00 MWD 9200.00 19.15 186.28 8257.23 8189.33 5956977 .13 663929.59 32.50 0.00 180.00 MWD 9252.58 19.15 186.28 8306.90 8239.00 5956959.94 663928.07 34.88 0.00 180.00 TJA 9300.00 19.15 186.28 8351.69 8283.79 5956944.45 663926.71 37.02 0.00 180.00 MWD 9333.04 19.15 186.28 8382.90 8315.00 5956933.65 663925.76 38.51 0.00 180.00 TSGR 9359.50 19.15 186.28 8407.90 8340.00 5956925.00 663925.00 39.70 0.00 180.00 C-23B Shu 9377.76 19.05 191.85 8425.16 8357.26 5956919.08 663924.19 40.81 10.00 96.04 MWD 9390.19 19.05 191.85 8436.90 8369.00 5956915.10 663923.44 41.76 0.00 0.00 TSHU 9400.00 19.05 191.85 8446.18 8378.28 5956911.95 663922.85 42.50 0.00 0.00 MWD 9449.43 19.05 191.85 8492.90 8425.00 5956896.10 663919.89 46.26 0.00 0.00 TSAD 9463.69 19.05 191.85 8506.38 8438.48 5956891.53 663919.03 47.35 0.00 0.00 MWD 9500.00 18.78 204.17 8540.74 8472.84 5956880.31 663915.66 51.27 11.00 99.60 MWD 9550.00 19.73 220.65 8587.98 8520.08 5956866.37 663907.17 60.46 11.00 87.94 MWD 9600.00 22.00 234.76 8634.73 8566.83 5956854.27 663894.27 73.95 11.00 72.37 MWD 9650.00 25.25 245.89 8680.55 8612.65 5956844.12 663877.09 91.62 11.00 59.18 MWD 9651.49 25.35 246.18 8681.90 8614.00 5956843.85 663876.52 92.21 11.00 48.97 TCGLfTZ3 9700.00 29.13 254.43 8725.04 8657.14 5956836.03 663855.79 113.30 11.00 48.71 MWD 9750.00 33.44 261.03 8767.77 8699.87 5956830.06 663830.56 138.80 11.00 41.37 MWD 1\ ~^ BP KW A Planning Report MAP Company: BP Amoco Date: 1/15/2003 Time: 10:28:26 Page: 3 Field: Prudhoe Bay Co-ordiDate(NE) Reference: Well: C-23, True North Site: PB C Pad Vertical (fVD) Reference: 67.90' 67.9 Well: C-23 Section (VS) Reference: User (-2653.53N.-458.27E,268.37 Azi) WeUpath: Plan C-23B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Tool/Comment ft deg deg ft ft ft ft ft deg/10OO deg 9762.22 34.54 262.42 8777.90 8710.00 5956828.93 663823.83 145.58 11.00 35.72 BCGUTZ2C 9800.00 38.03 266.24 8808.35 8740.45 5956826.26 663801.64 167.87 11.00 34.57 MWD 9841.18 41.95 269.78 8839.90 8772.00 5956824.80 663775.24 194.32 11.00 31.49 23SBfTZ2Bu 9850.00 42.80 270.47 8846.42 8778.52 5956824.69 663769.30 200.26 11.00 28.77 MWD 9900.00 47.70 273.99 8881.62 8813.72 5956825.34 663733.82 235.66 11.00 28.27 MWD 9907.91 48.48 274.49 8886.90 8819.00 5956825.64 663727.94 241.52 11.00 25.79 22TSfTZ2BI 9950.00 52.69 276.99 8913.62 8845.72 5956828.21 663695.54 273.76 11.00 25.45 MWD 10000.00 57.75 279.62 8942.13 8874.23 5956833.28 663654.80 314.19 11.00 23.86 MWD 10010.98 58.87 280.16 8947.90 8880.00 5956834.68 663645.56 323.34 11.00 22.36 21 TSfTZ2A 10039.26 61.76 281.48 8961.90 8894.00 5956838.77 663621.35 347.32 11.00 22.08 PGOC 10050.00 62.86 281.97 8966.89 8898.99 5956840.50 663611.99 356.58 11.00 21.42 MWD 10100.00 68.00 284.11 8987.68 8919.78 5956849.80 663567.50 400.55 11.00 21.20 MWD 10150.00 73.17 286.10 9004.29 8936.39 5956861.10 663521.74 445.69 11.00 20.30 MWD 10200.00 78.36 287.99 9016.58 8948.68 5956874.29 663475.13 491.58 11.00 19.64 MWD 10250.00 83.56 289.80 9024.43 8956.53 5956889.25 663428.10 537.81 11.00 19.18 MWD 10300.00 88.77 291.58 9027.77 8959.87 5956905.85 663381.07 583.94 11.00 18.89 MWD 10311.83 90.00 292.00 9027.90 8960.00 5956910.00 663370.00 594.79 11.00 18.77 C-23B T1 10386.83 90.00 292.00 9027.90 8960.00 5956936.56 663299.87 663.51 0.00 0.00 MWD 10400.00 90.05 293.05 9027.89 8959.99 5956941.34 663287.59 675.53 8.00 87.47 MWD 10450.00 90.22 297.05 9027.78 8959.88 5956961.51 663241.86 720.19 8.00 87.47 MWD 10500.00 90.40 301.04 9027.51 8959.61 5956984.82 663197.64 763.19 8.00 87.48 MWD 10550.00 90.57 305.04 9027.08 8959.18 5957011.15 663155.15 804.30 8.00 87.50 MWD 10600.00 90.74 309.04 9026.51 8958.61 5957040.38 663114.61 843.33 8.00 87.53 MWD 10650.00 90.91 313.03 9025.79 8957.89 5957072.36 663076.20 880.09 8.00 87.58 MWD 10665.82 90.96 314.30 9025.53 8957.63 5957083.03 663064.52 891.21 8.00 87.64 MWD 10700.00 90.96 314.30 9024.96 8957.06 5957106.36 663039.55 914.99 0.00 0.00 MWD 10800.00 90.96 314.30 9023.28 8955.38 5957174.60 662966.48 984.53 0.00 0.00 MWD 10822.56 90.96 314.30 9022.90 8955.00 5957190.00 662950.00 1000.22 0.00 0.00 C-23B T2 ___. ____ ~_~_,.....o-__. ___ _ _ __..-----. - - -~-._-~~.,--~.~-----~,,......,...~-~_._-- - ----~.'.~.~~..---.- .--~""...,.,.."~~~_..,.~,-..=,,.,,~- -------,---".......=~~--""'..~~~-,,-~'- ->-~-. _.-----. ~-~ ~ - - -.,....,----'..-~--~--- ,- ,-~. .....--~ -'-"''I-~,,,-~ "'-~-.........,_............-.~~ II- 0 5 5 0 3 ? II- 1: 0... ~ 2 0 3 a q 51: 0 ~ 2 ? a q I; 1111 AtA$KA QU- ~~':'GAS QQNSf;.,RVAT!QN:·(iÇ>Mf'Af$$lØ~·'· ~~~~lt:~:5~1.~~á~'~ ..." ~.. TO THE ORDER OF: -, :"*~c~~,~~~$1 oo:~op.~*·*~*~~ - ~\, -. . . . ..... ~ .--.... . - DATE :' , Maiêh~1,2.i20Ô3, ,- , , .. .~_._ - _:- .. ..',...:.. - <=1 _ '~ .- . :,. .; ",i, -:.{rt""::-'~"';:{'~-:", - .,~)- . ','. " : .,- '.:' ,,~_.."?trï'~',~·lf$t: Qf~" ::';. ,'"..., ::: ;~'..:~:.JL ': :,?~;'~: "4"1~ ;,~::,;~~~::, PAY: TOTAL ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. '-/ ! VENDOR DISCOUNT GROSS PERMIT TO DRILL C·9-'3B 3/12/2003 INV# CK030603J / H NET DESCRIPTION INVOICE I CREDIT MEMO DATE CHECK NO. 055037 DATE 3/12/2003 p055037 Rev: 07/10/02 C\jody\templates TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARA GRAPH S TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "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. HOLE 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). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a' conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY 8Px WELLNAME,I'Aq C-;z.=?t PROGRAM: Exp_ Dev.)( RedrllL Re-Enter_ Serv_ Wellboreseg_ FIELD & POOL c: yó / < t)' /'? INIT CLASS Oe» J -t:>J ï GEOL AREA ~ 7 r'J UNIT# //t::: )' ñ ON/OFF SHORE c.tJ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . IV' N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated. is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . ~ N (Service Well Only) 13. Well located wlin area & strata authorized by injection order #_ Y N (Service Well Only) 14. All wells wlin % mile area of review identified. . . . . . . . .. Y N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ,~ 16. Surface casing protects all known USDWs. . . . . . . . . . . _~ !: t-ll A- 17. CMT vol adequate to circulate on conductor & surf csg. . . . . -,--,-... 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y N 19. CMT will cover all known productive horizons. . . . . . . . . . 20. Casing designs adequate for C, T, B & permafrost. . . . . . . 21. Adequate tankage or reserve pit.. . . . . . .. . . . . . . . . 1· ~ ¡V",b"K 2-tH. 22. If a re-drill, has a 10-403 for abandonment been approved. . . N "3/ ¿~ 10 .5 23. Adequate wellbore separation proposed.. . . . . . . . . . . . - N 24. If diverter required, does it meet regulations. . . . . . . . . . if /1'\ 25. Drilling fluid program schematic & equip list adequate. . . . . P f1 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 27. BOPE press rating appropriate; test to 3$"00 psig. , ~~:-: ~~~s:.O.l 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. . . . . . . . . . . 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y gj) , 31. Mechanical condition of wells within AOR verified. . . . . . . . - y' N ' Nflr- 32. Permit can be issued wlo hydrogen sulfide measures. . . .. ~y 00 33. Data presented on potential overpressure zones. . . . . . . . Y N/ 34. Séismic analysis of shallow gas zones. . . . . . . . . . . . . ~ ~ /t,~ A \ 35. Seabed condition survey (if off-shore). . . . . .. ...... I.. 36. Contact namelphone for weekly progress reports. ...... GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING RP~ APPR DATE IlL 9b,h~ APPR DATE \N6A- <ilil (:r~ (Service Well Only) GEOLOGY APPR DATE /þ¿ ~,43 ~ (Exploratory Only) Rev: 2/25/03 \weILpermit_checklist UIC ENGINEER COMMIS, _S_19~~ SP rpo~ RR DS 0 4 )o~ /0"":> TM JH JR SFD_ WA /' MW ( l Comments/Instructions: i Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. \r .. "¥ Sperry-Sun DJ~ _~ing Services LIS Scan Utility ~: ~3-o<øO II'St)ß $Revision: 3 $ LisLib $Revision: 4 $ Tue Jun 03 12:25:04 2003 Reel Header Service name.. . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/06/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Previous Reel Name.... . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name..... . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA C-23B 500292077502 BP Exploration (Alaska) I Inc. Sperry-Sun Drilling Services 03-JUN-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002431379 J. SACK R. BORDES / MWD RUN 2 MW0002431379 J. SACK R. BORDES / MWD RUN 3 MW0002431379 J. SACK R. BORDES / JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MAD RUN 3 MW0002431379 J. SACK R. BORDES / # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 11N 14E 1315 1030 65.60 37.10 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT i_ 8.500 6.125 ~ (IN) SIZE (IN) DEPTH (FT) 9.625 8580.0 7.000 9344.0 ( # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK. THE TOP OF THE WINDOW WAS 8580'MD/7698ITVD AND THE BOTTOM OF THE WINDOW WAS 8596'MD/7711ITVD. SROP DATA ARE INCLUDED FOR THIS RUN. SGRC DATA OVER THIS INTERVAL WERE ACQUIRED WHILE RIH FOR RUN 2. 4. MWD RUN 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS) AND ELECTROMAGNETIC WAVE RESISTIVITY -PHASE 4 (EWR4). 5. MWD RUN 3 COMPRISED DIRECTIONAL; DGR; EWR4; STABILIZED LITHO-DENSITY (SLD); AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). MAD PASS DATA WERE ACQUIRED OVER THE INTERVAL FROM 10820'MD - 10246'MD (BIT DEPTHS), WHILE POOH AFTER REACHING FINAL TD. 6. LOG AND DIGITAL DATA ONLY WERE BLOCK-SHIFTED 1.5 FEET UPWARD PER E-MAIL INSTRUCTIONS FROM DEWAYNE SCHNORR, DATED 27 MAY 2003. HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 7. MWD RUNS l,2,AND 3 REPRESENT WELL C-23B WITH API# 50-029-20775-02. THIS WELL REACHED A TOTAL DEPTH OF 10821'MD / 9025'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT SMOOTHED TOOL SPEED WHEN NOT DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . .-' SNP2 = SMOOTJ~ NEAR-DETECTOR-ONLY PHOTOELECTJ~~ ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE. CURVE MNEMONICS WITH 1M' SUFFIX DENOTE MAD PASS DATA PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.5 PPG MUD SALINITY: 11,000 PPM CHLORIDES FORMATION WATER SALINITY: 10,994 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/03 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD RPX RPS RPM FET ROP NCNT NPHI FCNT PEF DRHO RHOB $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 8432.5 8470.5 8470.5 8470.5 8470.5 8470.5 8579.0 9255.5 9256.0 9256.0 9346.5 9346.5 9346.5 STOP DEPTH 10757.0 10764.0 10764.0 10764.0 10764.0 10764.0 10818.5 10730.5 10730.5 10730.5 10744.0 10744.0 10744.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 MERGED MAIN PASS. $ MERGE TOP 8580.5 8608.0 9345.0 MERGE BASE 8608.0 9345.0 10821.0 File Header Service name............ .STSLIB.002 Physical EOF File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/03 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.002 First Reading For Entire File......... .8432.5 Last Reading For Entire File.......... .10818.5 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8432.5 10818.5 9625.5 4773 8432.5 10818.5 ROP MWD FT/H 0.58 366.21 91.2003 4480 8579 10818.5 GR MWD API 12.99 544.79 67.8205 4650 8432.5 10757 RPX MWD OHMM 0.67 1757.78 20.0902 4588 8470.5 10764 RPS MWD OHMM 0.76 2000 24.3013 4588 8470.5 10764 RPM MWD OHMM 0.35 2000 39.6085 4588 8470.5 10764 RPD MWD OHMM 0.03 2000 63.966 4588 8470.5 10764 FET MWD HOUR 0.24 56.26 3.77672 4588 8470.5 10764 NPHI MWD PU-S 5.03 62.93 23.8043 2950 9256 10730.5 FCNT MWD CNT/ 117.7 3298.4 708.787 2950 9256 10730.5 NCNT MWD CNT/ 14466.6 50716 28828.7 2951 9255.5 10730.5 RHOB MWD G/CM 2.038 3.073 2.27166 2796 9346.5 10744 DRHO MWD G/CM -0.148 0.427 0.0385093 2796 9346.5 10744 PEF MWD BARN 0.76 10.31 1.86317 2796 9346.5 10744 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNT/ 4 1 68 36 10 NCNT MWD CNT/ 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 (' # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing................... ..60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O (" ( Service Sub Level Name. ~ Version Number.......... .1.0.0 Date of Generation...... .03/06/03 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE NCNT FCNT NPHI PEF DRHO RHOB GR FET RPD RPM RPS RPX RAT $ 2 and clipped curves; all MAD runs merged using earliest passes. .5000 # MERGED DATA SOURCE PBU TOOL CODE MWD $ # REMARKS: START DEPTH 10164.5 10164.5 10164.5 10178.0 10178.0 10178.0 10191.0 10198.0 10198.0 10198.0 10198.0 10198.0 10248.5 STOP DEPTH 10730.5 10731.0 10730.5 10742.0 10742.0 10742.0 10757.0 10764.5 10764.5 10764.5 10764.5 10764.5 10819.5 MAD RUN NO. MAD PASS NO. MERGE TOP 3 1 10150.0 MERGED MAD PASS. $ MERGE BASE 10821.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 NPHI MAD PU-S 4 1 68 32 9 FCNT MAD CNTS 4 1 68 36 10 NCNT MAD CNTS 4 1 68 40 11 RHOB MAD G/CM 4 1 68 44 12 DRHO MAD G/CM 4 1 68 48 13 PEF MAD BARN 4 1 68 52 14 ( ( First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10164.5 10819.5 10492 1311 10164.5 10819.5 RAT MAD FT/H 0.44 935.52 266.942 1143 10248.5 10819.5 GR MAD API 14.61 97.29 29.9804 1133 10191 10757 RPX MAD OHMM 5.85 18.34 9.84499 1134 10198 10764.5 RPS MAD OHMM 6.31 22.91 11.1936 1134 10198 10764.5 RPM MAD OHMM 7.43 25.87 12.9334 1134 10198 10764.5 RPD MAD OHMM 8.6 23.72 13.2687 1134 10198 10764.5 FET MAD HOUR 3 14.1 8.09306 1134 10198 10764.5 NPHI MAD PU-S 20.73 31.36 25.9203 1133 10164.5 10730.5 FCNT MAD CNTS 381.6 822.4 584.83 1134 10164.5 10731 NCNT MAD CNTS 23630 34192.5 29437.2 1133 10164.5 10730.5 RHOB MAD G/CM 2.11 2.468 2.22977 1129 10178 10742 DRHO MAD G/CM -0.054 0.22 0.0685412 1129 10178 10742 PEF MAD BARN 0.94 3.78 1.73845 1129 10178 10742 First Reading For Entire File......... .10164.5 Last Reading For Entire File.......... .10819.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .03/06/03 Maximum Physical Record. .65535 File Type....... . . . . . . . . . LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 3 header data for each bit run in separate files. 1 .5000 START DEPTH 8580.5 STOP DEPTH 8608.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): 07-MAY-03 Insite 66.37 Memory 8610.0 8580.0 8610.0 HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: ( # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record. . . . . . . . . . . . .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 .0 .0 TOOL NUMBER 81497 8.500 8580.0 LSND 10.70 55.0 9.3 1400 4.5 .000 .000 .000 .000 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD010 FT/H Min 8580.5 0.58 Max 8608 184.47 First Reading For Entire File......... .8580.5 Last Reading For Entire File.......... .8608 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Mean 8594.25 14.1718 Nsam 56 56 ( .0 150.0 .0 .0 First Reading 8580.5 8580.5 Last Reading 8608 8608 .' (" version Number.......... .0.0 Date of Generation...... .03/06/03 Maximum Physical Record. .65535 F i 1 e Typ e. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/03 Maximum Physical Record. .65535 F i 1 e Typ e. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPD RPS RPX FET ROP $ 4 tÍ 'I{ header data for each bit run in separate files. 2 .5000 START DEPTH 8434.0 8465.0 8465.0 8465.0 8465.0 8465.0 8600.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 9307.0 9299.0 9299.0 9299.0 9299.0 9299.0 9345.0 Il-MAY-03 Insite 66.37 Memory 9345.0 8610.0 9345.0 17.8 38.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 132477 163840 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): 8.500 8580.0 LSND 10.70 44.0 9.0 1600 ~. FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: ( 4.0 l \ 1.980 25.380 1.950 2.400 80.0 141.0 80.0 80.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 8434 9345 8889.5 1823 8434 9345 ROP MWD020 FT/H 4.61 366.21 129.853 1475 8600 9345 GR MWD020 API 54.65 175.62 119.655 1747 8434 9307 RPX MWD020 OHMM 0.94 1843.23 5.83741 1669 8465 9299 RPS MWD020 OHMM 0.92 2000 6.66594 1669 8465 9299 RPM MWD020 OHMM 0.34 2000 38.7731 1669 8465 9299 RPD MWD020 OHMM 0.02 2000 40.5111 1669 8465 9299 FET MWD020 HOUR 0.24 27.64 5.19632 1669 8465 9299 First Reading For Entire File......... .8434 Last Reading For Entire File.......... .9345 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 It Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/03 Maximum Physical Record. .65535 File Type........ . . . . . . . . LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT NPHI FCNT FET RPD RPM RPS RPX GR ROP PEF DRHO RHOB $ 5 { header data for each bit run in separate files. 3 .5000 START DEPTH 9257.0 9257.5 9257.5 9290.5 9290.5 9290.5 9290.5 9290.5 9307.5 9345.5 9348.0 9348.0 9348.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ STOP DEPTH 10732.0 10732.0 10732.0 10765.5 10765.5 10765.5 10765.5 10765.5 10758.5 10820.0 10745.5 10745.5 10745.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: 14-MAY-03 Insite 66.37 Memory 10821.0 9345.0 10821.0 16.9 90.4 TOOL NUMBER 184054 150253 100983 159436 6.125 9344.0 QuikDril-N 8.50 45.0 9.1 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9257 10820 10038.5 3127 9257 10820 ROP MWD030 FT/H 2.98 252.98 73.3762 2950 9345.5 10820 GR MWD030 API 12.99 544.79 36.6272 2903 9307.5 10758.5 RPX MWD030 OHMM 0.67 1642.24 27.9742 2951 9290.5 10765.5 RPS MWD030 OHMM 0.76 1676.66 34.1217 2951 9290.5 10765.5 RPM MWD030 OHMM 0.35 1930.64 52.4946 2951 9290.5 10765.5 RPD MWD030 OHMM 0.91 2000 95.4666 2951 9290.5 10765.5 FET MWD030 HOUR 0.45 56.26 3.39531 2951 9290.5 10765.5 NPHI MWD030 PU-S 5.03 62.93 23.8043 2950 9257.5 10732 FCNT MWD030 CNTS 117.7 3298.4 708.787 2950 9257.5 10732 NCNT MWD030 CNTS 14466.6 50716 28828.7 2951 9257 10732 RHOB MWD030 G/CM 2.038 3.073 2.27166 2796 9348 10745.5 DRHO MWD030 G/CM -0.148 0.427 0.0385093 2796 9348 10745.5 PEF MWD030 BARN 0.76 10.31 1.86317 2796 9348 10745.5 First Reading For Entire File......... .9257 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O $ REMARKS: # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # 75.0 154.0 78.0 78.0 .750 .380 .800 1.250 (' 11000 6.5 MUD CHLORIDES (PPM): t FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: ., .. " '" Last Reading For Entire Fil . . . . . . . . . .10820 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/03 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/06/03 Maximum Physical Record. .65535 F i 1 e Type........... . . . . . LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT PEF RHOB DRHO GR RPX RPS RPM RPD FET RAT $ 6 r( I~ header data for each pass of each run in separate files. .5000 3 1 START DEPTH 10166.0 10166.0 10166.0 10179.5 10179.5 10179.5 10192.5 10199.5 10199.5 10199.5 10199.5 10199.5 10250.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY STOP DEPTH 10732.0 10732.5 10732.0 10743.5 10743.5 10743.5 10758.5 10766.0 10766.0 10766.0 10766.0 10766.0 10821.0 14-MAY-03 Insite 66.37 Memory 10821.0 10246.0 10821.0 16.9 90.4 TOOL NUMBER 184054 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10166 10821 10493.5 1311 10166 10821 RAT MAD031 FT/H 0.44 935.52 266.942 1143 10250 10821 GR MAD031 API 14.61 97.29 29.9804 1133 10192.5 10758.5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD031 FT/H 4 1 68 4 2 GR MAD031 API 4 1 68 8 3 RPX MAD031 OHMM 4 1 68 12 4 RPS MAD031 OHMM 4 1 68 16 5 RPM MAD031 OHMM 4 1 68 20 6 RPD MAD031 OHMM 4 1 68 24 7 FET MAD031 HOUR 4 1 68 28 8 NPHI MAD031 PU-S 4 1 68 32 9 FCNT MAD031 CNTS 4 1 68 36 10 NCNT MAD031 CNTS 4 1 68 40 11 RHOB MAD031 G/CM 4 1 68 44 12 DRHO MAD031 G/CM 4 1 68 48 13 PEF MAD031 BARN 4 1 68 52 14 75.0 154.0 78.0 78.0 .750 .380 .800 1.250 QuikDril-N 8.50 45.0 9.1 11000 6.5 6.125 9344.0 150253 100983 159436 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value.............. . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O $ REMARKS: # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # I STÅ ~IZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 SLD CTN EWR4 $ ,.., ~'J1f End Of LIS File Physical EOF Physical EOF Reel Trailer Service name.......... . . .LISTPE Date.................... .03/06/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Trailer Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/06/03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/03 Maximum Physical Record. .65535 F i 1 e Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.007 First Reading For Entire File......... .10166 Last Reading For Entire File.......... .10821 f'-' i" ( 5.~ " RPX MAD031 OHMM 18.34 9.84499 1134 10199.5 10766 RPS MAD031 OHMM 6.31 22.91 11.1936 1134 10199.5 10766 RPM MAD031 OHMM 7.43 25.87 12.9334 1134 10199.5 10766 RPD MAD031 OHMM 8.6 23.72 13.2687 1134 10199.5 10766 FET MAD031 HOUR 3 14.1 8.09306 1134 10199.5 10766 NPHI MAD031 PU-S 20.73 31.36 25.9203 1133 10166 10732 FCNT MAD031 CNTS 381.6 822.4 584.83 1134 10166 10732.5 NCNT MAD031 CNTS 23630 34192.5 29437.2 1133 10166 10732 RHOB MAD031 G/CM 2.11 2.468 2.22977 1129 10179.5 10743.5 DRHO MAD031 G/CM -0.054 0.22 0.0685412 1129 10179.5 10743.5 PEF MAD031 BARN 0.94 3.78 1.73845 1129 10179.5 10743.5