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Home My WebLink About203-002 C. l N ' I I C l0 T U v O V CU pp u Jo LL r W LOW 0 a) r>o a 0"0 x c6 a r o N LL ( NZ p N spm aLL C I- Y0 1 O `° O s! H co > ,_ cO Es a o o 0 J v a O v E ''_^ CO L V Y J < F. - a) O Y �, to a _ ,- v) _C C C (O c W in )f) N N N N 0 , -6 Q > G Z l7 r r r C C a >' a) Z 17 3' C C C C C C C C C O- ' O CO CO CO CO CO CO CO CO Oa '"O O >. WlL 7 7 7 7 7 7 M ") a > a -0 i'a M CD 0 00 LO CO NI Cr el M N N N N N N U N co O 0 M a V 6 . 00 C c6 0 O y a C N t Q 16 , .- = ' 0 0 0 0 0 0 0 0 0 a) C v p u 0 J J J J J J J J J a) -c w U –4 W W W W W W W W W cc — v LL LL LL LL LL LL LL LL LL y Y a) s O ..72 > u C 0 Z Z Z Z Z Z Z Z Z E a) a O O LL I.L. LL LL LL LL LL LL LL C O Q C V - @ a a -a C rO 0 Q a t u > CO C) RS • �r CV N ' 0 Z r II :? 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OE Z N 1•6 vl .� L7 I .--1 Ul' .._) to .- G)C/o d� g 0_ a ) } Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J.oa - OD~ Well History File Identifier Organizing (done) o Two-sided 11I1111111I11111111 ~scan Needed RESCAN ~olor Items: o Greyscale Items: DI~TAL DATA 0" Diskettes, No. d-. o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: BY: Helen ~ o Other:: "" Date: 4/;)7, DS" /s/ vnP Project Proofing Scanning Preparation BY: Helen ~ _ ~ x 30 ::: to 0 mr + CJ ::: TOTAL PAGES (,,0 (Count dO.. .,,; not ¡n,'ude cover sheet, WI () Date: Lf ~ 7 r-J!:>- /5/ ,/- , . I Date: If J-] OS- /5/ BY: Helen r Maria) . BY: Production Scanning Stage 1 Page Count from Scanned File: 7 0 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~E,S NO Helen ~ Date: Lf 'í}. 7 êJS /s/ vn r YES Stage 1 If NO in stage 1, page(s) discrepancies were found: NO BY: Helen Maria Date: /5/ II1I I Scanning is complete at this point unless rescanning is required. ReScanned III I BY: Helen Maria Date: /5/ Comments about this file: Quality Checked 11I111111111 "1111I i BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of S-Pad Dear Mr. Maunder, ~ ~J b ,~ ` , ~ JUL a 1 2009 ~~~~~a Ai! ~ Gas ~onse Camrni~si~n Ancha~ag~ ~a 3 -o e a-- J~ ~~~ Enclosed please find a spreadsheet with a list of we(Is from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, C~ ~ *; Y~~ [F '~ R< e~ / "~~ . +,`~~;?[~V~~,~~ ~~i~;r '~ °~ L~~\.,'~:.,; Torin Roschinger BPXA, Well Integrity Coordinator ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operetions (10-M104) &pad nnre ('i/?5/2009 Well Name PTD k Initial top of cement Vol. of cement um ed Final top ot cement Cement top off date Corrosion inhibitor Corcosion inhibitod sealant date ft bbls it na al S-01B 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 1.7 5/25/2009 S-03 1811900 1325 NA 1325 NA 92.65 5/20/2009 5-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-05A 1951890 0 NA 0 NA 0.9 5/26/2009 5-06 1821650 0 NA 0 NA 0.9 5/26I2009 S-07A 1920980 0 NA 0 NA 0.9 5/26I2009 S-088 2010520 0 NA 0 NA 0.85 5/27/2009 S-09 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-10A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 5-11 B 1990530 025 NA 025 NA 1.7 S127/2009 S-12A 1851930 025 NA 025 NA 1.7 6/1/2009 S-13 1821350 8 NA 8 NA 55.3 6/1/2009 5-15 1840170 025 NA 0.25 NA 3 6/2/2009 S-17C 2020070 0.25 NA 025 NA 2.6 6/1/2009 S-18A 2021630 0~.5 NA 0.5 NA 3 6/2/2009 S-19 1861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2070450 025 NA 0.25 NA 1.3 5/19/2009 S-21 7900470 0.5 NA 0.5 NA 3.4 5/25/2009 S-228 1970510 0.75 NA 0.75 NA 3 5l19/2009 S-23 1901270 0.25 NA 025 NA 1.7 5/25/2009 5-248 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26l2009 S-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 5-288 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29A1t 1960720 0 NA 0 NA 0.85 5/27/2009 S30 1900660 0.5 NA 0.5 NA 5.1 5/31/2009 S31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 S-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 S33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 5-34 7921360 0.5 NA 0.5 NA 3.4 5/31/2009 S-35 1921480 0 NA 0 NA .BSin 5/31/2009 5-36 1927760 0.75 NA 0.75 NA 4.25 5/27/2009 S-s7 1920990 125 NA 125 NA 71.9 5/27/2009 5-38 1921270 025 NA 025 NA 102 5/27/2009 S-at 1960240 1.5 NA 1.5 NA i 1.1 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5l30/2009 5-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 S-a4 1970070 025 NA 025 NA 1.7 5/28/2009 5-700 2000780 2 NA 2 NA 21.3 5/29/2009 S-107 2007150 125 NA 725 NA 77.9 5/29/2009 5-102L7 2031560 125 NA 125 NA 11.1 5/31/2009 S-103 2001680 1.5 NA 1.5 NA 71.9 5/18/2009 5-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 S-to5 2001520 4 NA 4 NA 32.7 5/20/2009 5-706 2010120 1625 NA 1625 NA 174.3 6/2/2009 S-707 2011130 225 NA 225 NA 28.9 5/18/2009 S-~oa 2011000 3.5 NA 3.5 NA ao 5/30/2009 S-109 2022450 2 NA 2 NA 21.3 5/30/2009 5-110 2011290 i t 75 NA 11.75 NA 99.6 5/30/2009 S-i 1 ~ 2050510 2 NA 2 NA 19.6 5/30/2009 5-172 2021350 0 NA 0 NA 0.5 5/30/2009 S-7t3 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 5-114A 2021980 t25 NA 1.25 NA ~02 5/30I2009 S-~ 15 2022300 2.5 NA 2.5 NA 272 5/29/2009 S-116 2031810 7.5 NA 1.5 NA 13.6 5/28/2009 5-117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 S-718 2032000 5 NA 5 NA 76.5 5/28/2009 S-119 2041620 1 NA 1 NA 5.2 5/30l2009 S-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 5-121 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 5-722 2050810 3 NA 3 NA 21.3 5/29/2009 S-723 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 S-124 2061360 1.75 NA 1.75 NA ~1.9 5/26/2009 S-125 2070830 225 NA 2.25 NA 20.4 5/28/2009 5-126 20710970 125 NA 125 NA 15.3 6/1/2009 5-200 1972390 125 NA 125 NA 14.5 5/28/2009 S-201 2001840 0 NA 0 NA 0.85 6/19/2009 5-213A 2042130 2 NA 2 NA 13.6 5/29/2009 5-215 2021540 2 NA 2 NA 18.7 6/i/2009 S-216 2001970 4.75 NA 4.75 NA 51 5/29/2009 5-217 2070950 025 NA 025 NA 1.7 6/1/2009 S-400 2070740 2 NA 2 NA 9.4 5/2&2009 S-407 2060780 16 NA i6' NA 99.5 6/2/2009 5-504 0 NA 0 NA 0.85 5/28/2009 ~ • --~ ~- -.~ ~1~1~-~iI~I~~ 03/01/2008 DO NOT PLACE ,=, =a_ .,~,,. ~° ANY NEW MATERIAL UNDER THIS PAGE F: \LaserFiche\CvrPgs_Inserts\Microfilm_Marker. doc 12/06/06 Schlumberger NO. 4065 Schlumberger-DCS 2525 Gambell 5t, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Orion Prudhoe Bay Well Job# Log Description Date BL Color CD 5-121 11368505 MEMORY PROD PROFILE 11/06/06 1 S-28B P81 40008506 OH EDIT OF MWD/LWD 02101/03 2 1 1-100 11216289 OH EDIT OF MWD/LWD 04113/06 2 1 L-212 40011670 OH EDIT OF MWD/LWD 04/13/05 2 1 L-212 PB1 40011670 OH EDIT OF MWD/LWD 03/25/05 2 1 L-212 PB2 40011670 OH EDIT OF MWD/LWD 04/06/05 2 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: Received by· BP !"xploration (Alaska) Inc Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508·4254 . Date Delivered: SCAi\!rlfû DEe 0 B dC53 -00 d if ¡'-/Q1S;J ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS MAY 1 0 7005 1. Operations Performed: Abandon 0 Alter Casing D Change Approved Program D Repair WellD PluQ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate ŒJ 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 63.66 8. Property Designation: ADL-028258 11. Present Well Condition Summary: Total Depth measured 11715 feet true vertical 8921.1 feet Effective Depth measured 11624 feet true vertical 8916.9 feet Casing Length Size Conductor 80 20" 91.5# H-40 Liner 1340 7" 26# L-80 Liner 25 5" 15# L-80 Liner 2183 4-112" 12.6# L-80 Production 8531 9-5/8" 47# L-80 Surface 2559 13-3/8" 72# L-80 Perforation depth: 4. Current Well Class: Development Œ] Stimulate 0 Alaska Oil & e~r~S. Commis~i WaiverD Time Ext~ge Re-enter Suspended WellD 5. Permit to Drill Number: 203-0020 6. API Numbe 50-029-22095-02-00 ExploratoryD Stratig raphic D- .....:____...9.§rvice D 9. Well Name and Number: S-28B 10. Field/Pool(s): Prudhoe Bay Field I Prudhoe Oil Pool SCANNED MAY Ii :l 2.005 Plugs (measured) None Junk (measured) None MD TVD Burst Collapse 30 110 30.0 110.0 1490 470 8385 - 9725 7665.0 - 8756.1 7240 5410 9502 - 9527 8622.1 - 8639.3 8290 7250 9527 - 11710 8639.3 - 8920.9 8430 7500 29 - 8560 29.0 - 7820.7 6870 4760 30 - 2589 30.0 - 2589.0 4930 2670 Measured depth: 10065 - 10078, 10100 - 10113, 10476 - 10484, 11125 - 11300, 11320 - 11340, 11370 - 11580 True vertical depth: 8874.52 - 8878.41,8885.24 - 8889.25, 8913.57 - 8913.45,8925.47 - 8922.51,8922.25 - 8921.86,8920.84 - 8914.79 Tubing ( size, grade, and measured depth): 3-1/2" 9.2# 13Cr80 Packers & SSSV (type & measured depth): @ 25 9519 7-5/8" Baker ZXP Top Packer 4-1/2" Baker ZXP Packer 3-112" Baker S-3 Packer @ 8385 @ 9502 @ 9454 RBDMS Ofl MA V } 1 2005 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron J:1~ C~ 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: Oil-Bbl 450 450 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations_ ! Signature Form 10-404 Revised 4/2004 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 0.3 867 1262 0.3 867 1340 Tubing Pressure 253 253 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil Œ] Gas D Development ŒI Service D 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 Date 5/9/05 ,I " , l) C'\ ¡ lJ i r~ 1\ L ) ) 5-288 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/26/05 Perforate 100651-100781 4.2 SPF FLUIDS PUMPED BBLS 30 60/40 Methonal/Water 30 TOTAL Page 1 TREE = 4-1/16" crvv WELLHEA D = FMC Ä C-rUÄ TÒR ,;"'. OTIS ~KB:-ELE\Í--;;·-~·"--·-"--63. 6Ef BÞ.ELEi/';' . 36.26' -Kõp ;;------". 262'5'7 _~~_~!-n~e;~,~9~~~~ii~~~~ Datum MD = 9823' "'" "".""""""'"'''''''''''''''''''' Datum 1VD = 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2590' Minimum ID = 2.750" @ 9506' 3-1/2" HES XN NIPPLE PERFORA TION SUMMARY REF LOG: ANGLE AT TOP PERF: 73 @ 10065' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/2" 4.2* 10065 - 10078 0 03/25/05 2-1/2" 4.2* 10100 - 10113 0 03/25/05 2-1/2" 4.2* 10476 - 10484 0 03/25/05 2-1/2" 6 11125-11300 0 03/09/03 2-1/2" 6 11320 - 11340 0 03/09/03 2-1/2" 6 11370 - 11580 0 03/09/03 * = PURE PERFS 8582' 1-1 WHIPSTOCK 1 8587' I~ 19-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 9672' 17" CSG, 26#, L-80 1-1 10100' 2-7/8" SLTD LNR, 6.16#, L-80, -I 10624' 1 .0058 bpf, ID = 2.37" I TD 1-1 11050' I DA TE REV BY COMMENTS 01/02/91 ORIGINAL COM PLETION 05/02/96 SIDETRACK (S-28AO 02/18/03 DDW/KK RIG SIDETRACK (S-28B) 02/24/03 JB/KAK GL V C/O 03/09/03 SRB/TP A DD PERFS 03/27/05 WTS/TLH ADD PERFS ) SAFETY r'y:s: 3" FLOWLINE IN SKID PORTIONS OF THIS WEL......J FLOWLINE ARE 3" AND SUBJECT TO EROSION. THE GC SHOULD BE NOTIFIED OF ANY WELL OPERATION WHICH COULD INCREASE THE FLOW OR EROSION RATE. ***3-1/2" CHROME TBG.*** 5-288 I I I 2241' ---I 2589' ~. 1-13-1/2" HES X NIP, ID = 2.813" I I~ GAS LIFT MANDRELS DEV TYPE VLV LATCH 11 CA MMG DMY RK 30 CA MMG DOME RK 33 CA MMG DOME RK 27 CA MMG DOME RK 28 CA MMG SO RK PORT DATE o 02/24/03 16 02/24/03 16 02/24/03 16 02/24/03 20 02/24/03 ~ ST MD 1VD 5 3041 3038 4 3876 3810 3 6171 5723 2 7569 6929 1 8656 7905 L 8: 8385' 1-19-5/8" X 7" ZXP LNR TOP PKR, ID = 6.280" 1 ~ MILLOUT WINDOW 8560' - 8576' 9432' 1-l3-1/2" HES X NIP, ID = 2.813" 1 9454' 1-1 BKR S-3 HYDRO-SET PROD PKR, ID = 3.875" 9483' 1-13-1/2" HES X NIP, ID = 2.813" I I 9502' 1-14-1/2" ZXP LNR TOP PKR I 9506' 1-1 3-1/2" HES XN NIP, ID = 2.750" I 9519' 1-13-1/2" WLEG, ID = 2.992" 1 I 11624' I-1PBTD I 3-1/2" TBG, 9.2#, 13-CR-80, -I .0087 bpf, ID = 2.992" 17" CSG. 26#, L-80. .0383 bpf, ID = 6.276" 1-1 14-1/2" LNR, 12.6#, L-80. .0152 bpf, ID = 3.958" 1-1 11710' 1 DA TE REV BY COMMENTS PRUDHOE BAY UNrr WELL: S-28B ÆRMrr No: "'2030020 API No: 50-029-22095-02 SEC 35, T12N, T12E, 1636' SNL & 1269' EWL BP Exploration (Alaska) 8t ~ ;LaCJr DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2030020 Well Name/No. PRUDHOE BAY UNIT S-28B Operator BP EXPLORATION (ALASKA) INC MD 11715 TVD 8921 Completion Date 3/9/2003 Completion Status 1-01L Current Status 1-01L - ------- ----- REQUIRED INFORMATION J~ ~lfl1Jtttt'JJ;~ <1 API No. 50-029-22095-02-00 UIC N Mud Log No Samples No Directional sunt~~ ----"------ --------------- DATA INFORMATION Types Electric or Other logs Run: MWD, DIR, GR, RES Well log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint) Received Comments A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 1/14/2003. An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 1/14/2003. PB1 log log Run Scale Media No Interval OH / Start Stop CH ----------- ~~ ie- ;ED L___ Directional Survey Directional Survey Directional Survey Directional Survey 12104 LI~tion (,~" 8553 10522 Open 2/18/2003 8553 11715 Open 2/18/2003 8553 11715 Open 2/18/2003 8553 1 0522 Open 2/18/2003 Col 10926 11614 Case 8/8/2003 Sample Set Sent Received Number Comments Las __~ -0-_- ___ Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? Y / ~ Daily History Received? 0N D/N Chips Received? ~ Formation Tops Analysis Received? ---- Y/N --- ----.- ------ -----------~----- --- ---------- .~ PB1 CCUGR :~ DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2030020 Well Name/No. PRUDHOE BAY UNIT S-28B Operator BP EXPLORATION (ALASKA) INC MD 11715 Completion Date 3/9/2003 Completion Status 1-01L Current Status 1-01L TVD 8921 Comments: ------- h Date: Compliance Reviewed By: API No. 50-029-22095-02-00 UIC N / 2- ~Il )J;'è ç- -- c~ Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job # ) c¡ :3 -(-;~ ~ J 'i~ ~ / -:¡.~. g - ð l..l c-') { ~ ;,--(: \0 \ ~ ((-C~~ \ ~~'- \ C;~ \ D.0 -C-~, ct 1 S l (ì .- \ 1:'",. ~ r ~ J ~ C:.~J,~ '-\ , \J~-C;\~ D.S.4-11A \ 9 ~- \ i=J7< 3-25/M-27 j cl r "- \ ~ '-'.~ -*S-28B ~~-~ 23414 *(PRINTS SEtlt OUT 5/ðãiõ3)" D.S. 9-04A NK-38 E-10A C-16 D.S.11-16 R-34 D.S.7-21 D-14A P2-03 A-06 Log Description PROD PROFILE/DEFT STATIC PRESSURE SURVEY LDL GRAVEL PACK W/RST-C PROD PROFILE/DEFT/GHOST INJECTION PROFILE LDL LDL CHFR PROD PROFILE/DEFT LDL SCMT (REPRINT-DEPTH SHIFTED) CH MEM GR (PDC) 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: ~c~ ~'-Y"\.~ \...C 6:-~ è'~~ Date 07/31/03 08/01/03 07/07/03 04/30/03 06/05/03 05/17/03 07/30/03 07/28/03 05/03/03 06/27/03 07/21/03 01/04/03 03/09/03 Blueline NO. 2933 08/05/03 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott Color Prints 1 1 1 1 1 1 1 1 1 1 1 1 CD ~. \'''\\b~ 1 \7'- ... ~ ..:'::- Schlumberger GeoQuest 3940 Arctic Blvd,Suite 300 Anchorage, AK 99503-5711 AITN: Beth Received by:·· :1 7/~/~3 J .~ ~1 ) " ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) In,q. , 3. Address I P.O. Box 196612, Anchorage, Alaska 4. Location of well at surface 1636' SNL, 4011' WEL, Sec. 35, T12N, R12E, UM At top of productive interval 3574' SNL, 1717' WEL, Sec. 34, T12N, R12E, UM At total depth 3566' SNL, 3385' WEL, Sec. 34, T12N, R12E, UM X = 614811, Y = 5977853 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 63.66' ADL 028258 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 1/24/2003 . 2/4/2003/" 3/9/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 11715 8921 FT 11624 8917 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, DIR, GR, RES 23. CASING SIZE 20" 13-3/8" 9-5/8" ~"~'\¡~"~T'I"~!\..:loI'l"'S'W~~~~'t:.~.~'c,;r~ j'.:, M)(;A:rU)~,i;Î\:~.i\ .~ Y~i~~ '.;~{ '.L . ':f.~. ~:'; t:~~.~ 9. X = 619432, Y = 5979855 :.., ¡' .;: t ..3 :·q.:ï93: "'''''''''''-~- ._,_...,"-,--,...,..~,... ; \1¡;¡';~i 99519-6612 ,...._...:,,;~~ ..... ¡ Classification of Service Well 7. Permit Number 203-002 8. API Number 50- 029-22095-02 Unit or Lease Name Prudhoe Bay Unit X = 616479, Y = 5977871 10. Well Number 5-288 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2241' MD 1900' (Approx.) -( I y~ ~.5:bD' ß'lb / · 7~ 2/ "7Yì;:, 7" WT. PER FT. Conductor 68# 47# 26# 12.6# CASING, liNER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 110' 33' 2531' 29' 8560' 8385' 9725' 9502' 11710' GRADE CEMENTING RECORD AMOUNT PULLED 4-1/2" L-80 NT80S L-80 L-80 17-1/2" 2022 cu ft AS III, 1066 cu ft AS II 12-1/4" 2068 cu ft Class 'G' 8-1/2" 310 cu ft Class 'G' 6-1/8" 1235 cu ft Class 'G' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and ,numbeJ) I 2-1/2" Gun Diameter, 6 spf MD TVD 11125' - 11300' 8925' - 8922' 11320' - 11340' 8922' - 8922' 11370' - 11580' 8921' - 8915' 25. SIZE 3-1/2",9.2#, 13Cr80 "MD' TVD TUBING RECORD DEPTH SET (MD) 9519' PACKER SET (MD) 9454' ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect with 160 Bbls of Diesel 26. 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 19, 2003 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl 4/3/2003 4 TEST PERIOD 2,455 2,521 -0- Flow Tubing Casing Pressure CALCULATED Oll-BBl GAs-McF WATER-BBL Press. 287 24-HoUR RATE CHOKE SIZE 95.3° Oil GRAVITY-API (CORR) 26.5 GAS-Oil RATIO 1,027 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit corRE eEl VE 0 No core samples were taken. fØ)MS Bt- L- ~PR 3 0 20~J Form 10-407 Rev. 07-01-80 ORIGINAL APR 1 6 2003 A'aska Oil & Gas Cons. Commission Anchorage ~p Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sag River 9720' 8753' Shublik 9794' 8788' Sadlerochit 1 0027' 8863' RECEIVED APR 1 6 2003 Alaska Oil & Gas Cons. Commission Anchorage \. I,...,., WI" """'''1 31. List of Attachments: Summary of DailY Drilling Reports, Surveys 32. I ~erebY certify that the. f()YO,i.~9 is true and correct to the best of my knowledge Signed Terrie Hubble "1~. ~ Title Technical Assistant Date 04- lS·Ó3 S-28B 203-002 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No.1 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 producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (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'. O(~IGINAL Form 10-407 Rev. 07-01-80 ¡ , ~ '11;\" ' .~.",. '....'\I,~IoT" 1\ Legal Name: 8-28 Common Name: 8-28 Test Date 1/24/2003 1/30/2003 FIT FIT Test Type Test Depth (TMD) 8,560.0 (ft) 9,725.0 (ft) BPEXPUQRATION Lea.k..()ff···..,.est·..···S.·I.I..rn·mar¡ Test Depth tWD) 7,820.0 (ft) 8,759.0 (ft) AMW 11.30 (ppg) 8.50 (ppg) Sur'facëPtessure LeakOffPrèssur~{BfiP) 5,075 (psi) 4,368 (psi) EMW 12.49 (ppg) 9.60 (ppg) 485 (psi) 500 (psi) -~ --.,....' Printed: 2/17/2003 2:28:42 PM ) ) BP EXPLORATION Page tort6 Operations.·Summ:ary. Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-28 S-28 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 1/17/2003 Rig Release: 2/15/2003 Rig Number: Spud Date: 1/18/2003 End: 2/15/2003 Date From -:- To Hours TaSk· Code .NPT Phase Description of Operations 1/17/2003 12:00 - 14:30 2.50 MOB P PRE R/D Floor, Disconnect Inter Connect, Bridle - Up. 14:30 - 17:00 2.50 MOB P PRE Move Shop & Pit Complex to S-28 Location. 17:00 - 18:00 1.00 MOB P PRE Drop Beaver Slide, Un - Pin Derrick & Lay Derrick Down. 18:00 - 22:00 4.00 MOB P PRE Move Rig Off S-1 09. Move Rig to S-28B. 22:00 - 00:00 2.00 MOB P PRE Lay Rig Mats & Herculite. Spot Rig, Pits, Shop & Camp. 1/18/2003 00:00 - 02:00 2.00 RIGU P PRE MU Mud, Steam & Water lines 02:00 - 03:00 1.00 RIGU P PRE PJSM Raise Derrick 03:00 - 05:30 2.50 RIGU P PRE RU Pipe Shed Chute, Bridle DN 05:30 - 06:30 1.00 WHSUR P DECaMP RU Lubricator, Pull BPV, RD Lubricator TBG Press = 250 psi, 4 1/2 X 9 5/8 Press = 320 psi, 133/8 X 9 5/8 = 410 psi 06:30 - 08:30 2.00 CLEAN P DECaMP RU To Reverse Circ. Freeze Protect From TBG & Annulus 08:30 - 10:00 1.50 CLEAN P DECaMP Test Lines to 3500 psi, Reverse Circ. Freeze Protect from TBG @ 2.5 BPM, 500 psi 10:00 - 15:00 5.00 CLEAN P DECaMP Displace Freeze Protect from IA with IcP 0.75 BPM @ 1900 psi, FCP 0.75 BPM @ 3000 psi 15:00 - 16:30 1.50 WHSUR P DECaMP Install TWC Valve Test From Below to 1000 psi 16:30 - 17:30 1.00 WHSUR P DECaMP ND Tree & Adapter Flange 17:30 - 18:30 1.00 WHSUR P DECaMP Clean, Inspect Hanger, Pull Control Lines. 18:30 - 21 :30 3.00 BOPSURP DECaMP NU BOP Stack & Related Equip 21 :30 - 00:00 2.50 BOPSUR P DECaMP RU Test Equip and Press Test BOP's 250 psi for 5 min Low and 3500 psi for 5 Min High. Witness of BOP Test Waived by John Crisp AOGCC 1/19/2003 00:00 - 02:30 2.50 BOPSURP DECaMP Test BOP's 250 psi Low 3500 psi High. Witness of BOP Test Waived by John Crisp AOGCC. Blow Down Choke & Kill Lines, Blow Down Choke Manifold 02:30 - 03:00 0.50 WHSUR P DECaMP PU MU Lubricator, Pull TWC, LD Same 03:00 - 06:00 3.00 PULL P DECaMP MU Jt DP with XO to TBG Hanger, Unseat Hanger Attempt to Pull TBG, Work TBG String, Max Wt. Pulled 265K, No Go, LD Jt DP with XO 06:00 - 10:00 4.00 PULL N DPRB DECaMP WO SWS for Chemical TBG Cut 10:00 - 11 :00 1.00 PULL N DPRB DECaMP PJSM with SWS, RU SWS for String Shot 11 :00 - 14:00 3.00 PULL N DPRB DECaMP RIH with String Shot to 9150', Fire String Shot @ 9150', POOH & RD String Shot 14:00 - 15:00 1.00 PULL N DPRB DECaMP PJSM, RU & Arm Chem Cutter 15:00 - 18:00 3.00 PULL N DPRB DECaMP RIH with Chem Cutter/Jars on E-Line, Chemically Cut 4 1/2" TBG @ 9150'" POOH with Same 18:00 - 19:00 1.00 PULL N DPRB DECaMP RD Chemical Cutter 19:00 - 20:00 1.00 PULL N DPRB DECaMP MU Jt DP with XO to TBG Hanger, Unseat Hanger Attempt to Pull TBG, Max Wt. Pulled 265K, No Go, Circ, 0.75 BPM @ 3000 psi 20:00 - 23:00 3.00 PULL N DPRB DECaMP RU String Shot #2, RIH and Fire String Shot #2 @ 9000', POOH & RD String Shot 23:00 - 00:00 1.00 PULL N DPRB DECaMP RU TBG Equip. MU 4 1/2" Pup Jts Screw Into hanger 1/20/2003 00:00 - 00:30 0.50 PULL N DPRB DECaMP Pull 20klbs overpull in pipe & set slips. Install collar clamp above slips. MU safety valve & secure well. 00:30 - 01 :30 1.00 PULL N DPRB DECaMP Wait on delivery of 4 1/2" IF pump in sub and packoff from SWS - phase 2 weather conditions. 01 :30 - 02:00 0.50 PULL N DPRB DECaMP PJSM SWS, NAD, BP on handling chemical cutter @ surface & appropriate actions if problems. 02:00 - 04:30 2.50 PULL N DPRB DECaMP RIH with chemical cutter and log on depth at 9000' ELMD. Fire cutter to sever tubing. 04:30 - 05:30 1.00 PULL N DPRB DECaMP POH with cutter & RD wireline. Indication that cutter may not ! have made full circumferential cut. ¡ I Printed: 2/17/2003 228:50 PM ) ) BP <EXPLORATIQN Page 2 of 16 Ope rati onsSul11maryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-28 S-28 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 1/17/2003 Rig Release: 2/15/2003 Rig Number: Spud Date: 1/18/2003 End: 2/15/2003 Date From.., To Hours Task Code NPT Phase Descri ptionQfOperations 1/20/2003 05:30 - 09:00 3.50 PULL N DPRB DECOMP Work pipe up to 80% tensile rating but won't come free. Attempt to establish circulation but no improvement from previous cut attempts. Suspect tubing is cemented in 9 5/8" casing to above 9000'. 09:00 - 10:00 1.00 PULL N DPRB DECOMP RU to fire string shot at -8625'. 10:00 - 11 :00 1.00 PULL N DPRB DECOMP RIH with string shot. Cannot pass GLM at 3093' with string shot. POH & inspect shot - end bent over. Straighten same - OK. 11 :00 - 14:00 3.00 PULL N DPRB DECOMP Re-run string shot and log on depth at -8625' ELMO. Fire string shot. POH with string shot 14:00 - 15:00 1.00 PULL N DPRB DECOMP Pull 25klbs overpull in pipe & set slips. Install collar clamp above slips. PJSM SWS, NAD, BP on handling chemical cutter. RU chemical cutter 15:00 - 17:00 2.00 PULL N DPRB DECOMP RIH with chemical cutter and log on depth at 8625' ELMO. Cutter misfired twice. Waited 2 minutes, Cutter misfied again 17:00 - 18:30 1.50 PULL N DPRB DECOMP POH with chemical cutter to 200' ELMO from surface 18:30 - 19:30 1.00 PULL N DPRB DECOMP PJSM SWS, NAD, BP on pulling misfired chemical cutter to rig floor. Pull chemical cutter to rig floor. Trouble shot tool, determined leaky O-ring caused misfire 19:30 - 21 :30 2.00 PULL N DPRB DECOMP Redress chemical cutter. Re-run chemical cutter and log on depth at 8610' ELMO. Fire cutter to sever tubing, good indication of successful cut on rig floor. 21 :30 - 22:30 1.00 PULL N DPRB DECOMP POH with chemical cutter & RD wireline 22:30 - 00:00 1.50 PULL P DECOMP Pull hanger to floor, string weight 125klbs. Break SSSV control lines off hanger and tie off 1/21/2003 00:00 - 01 :00 1.00 PULL P DECOMP Circ sweep around at 500+ GPM 700 psi. RU SchlCamco ctrl line spooling unit. 01 :00 - 01 :30 0.50 PULL P DECOMP Flowcheck well - OK. Pump dry job. 01 :30 - 04:00 2.50 PULL P DECOMP LD tubing hanger and landing jt. Pull 4.5" tubing & LD same to SVLN. 04:00 - 04:30 0.50 PULL P DECOMP LD SVLN. RD Cameo. Recovered 25 control line clamps + 3 SS bands + all control line - OK. 04:30 - 09:00 4.50 PULL P DECOMP Cant pulling tubing & LD same - 214 jts, 1 cut off, 3 GLM's, 1 SVLN. 09:00 - 09:30 0.50 PULL P DECOMP RD tubing equ'pt. Clear rig floor. 09:30 - 14:30 5.00 WHSUR P DECOMP Bleed 400 psi pressure off OA to bleed tank prior to pulling 9-5/8" packoff. 14:30 - 17:00 2.50 WHSUR P DECOMP Latch into packoff with pulling tool. Back out lockdown screws. Unseat packoff with 45 klbs overpull and retrieve same. Install new packoff, torque lockdown screws and gland nuts. Test to 5000 psi for 10 min. 17:00 - 18:00 1.00 BOPSURP DECOMP Install test plug, test lower pipe rams - 250 psi low, 3500 psi high. LD test plug. Install wear bushing. 18:00 - 20:00 2.00 CLEAN P DECOMP MU Baker whipstock mill assembly with DC's, jars and HWDP 20:00 - 00:00 4.00 CLEAN P DECOMP RIH with mill assembly picking up single joints of 4" HT-40 DP. Break circulation at 2800' 1/22/2003 00:00 - 02:00 2.00 CLEAN P DECOMP Cont. RIH with mill assembly picking up single joints 4" H-40 DP. Break circulation at 5800'. Tag tubing stub at 8605'. PU weight 195 klbs, SO weight 170 klbs, torque 3000 ftlb @ 75 RPM. 02:00 - 03:00 1.00 CLEAN P DECOMP Circulate 25 bbl Hi-Vis sweep followed by seawater surface to surface, 13 BPM @ 1990 psi. Reciprocate pipe while circulating. I Printed: 2/17/2003 2:28:50 PM ) ( ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-28 S-28 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 1/17/2003 Rig Release: 2/15/2003 Rig Number: Spud Date: 1/18/2003 End: 2/15/2003 Date From-To Hours Task Code NPT Phase Description of Operations 1/22/2003 03:00 - 04:30 1.50 CLEAN P DECaMP PJSM Little Red Services, NAD, BP on pumping hot diesel, pressure testing lines and spill prevention measures. RU Little Red. Pump 20 bbl Hi-Vis spacer. Switch over to Little Red test lines to 3000 psi - OK. Pump 80 bb1150-170 degree diesel at 2 BPM. 04:30 - 05:30 1.00 CLEAN P DECaMP Chase diesel with 20 bbl Hi-Vis spacer followed by seawater to surface pumping 6 BPM @ 430 psi. 05:30 - 07:30 2.00 CLEAN P DECaMP Circulate diesel to cuttings tank, 2 BPM @ 100 psi. Continue until clean seawater to cuttings tank. 07:30 - 08:30 1.00 CLEAN P DECaMP Circulate 25 bbl Hi-Vis sweep followed by seawater surface to surface, 13 BPM @ 1990 psi. Reciprocate pipe while circulating. 08:30 - 11 :30 3.00 CLEAN P DECaMP Monitor well, pump dry job. POH with whipstock mill assembly. PU weight 210 klbs, SO weight 160 klbs 11 :30 - 12:30 1.00 CLEAN P DECaMP Cut and slip drilling line 79'. 12:30 - 13:00 0.50 CLEAN P DECaMP Service rig. 13:00 - 14:30 1.50 CLEAN P DECaMP Cont. POH. Stand back HWDP and collars. Lay down jars, bit sub, casing scraper and orienting sub 14:30 - 18:30 4.00 STWHIP P WEXIT PJSM SWS, Halliburton, NAD, BP on rigging up, handling CIBP and explosives safety. RU E-line equipment. Log on depth to set top of CIBP at 8587' ELMD. SWS setting tool misfire. POH with E-line. 18:30 - 23:00 4.50 STWHIP N DFAL WEXIT Safe out explosives. Trouble shoot Schlumberger tools, electrical malfunction in the wireline head, changout toolstring, changeout explosives. 23:00 - 00:00 1.00 STWHIP N DFAL WEXIT 2nd RIH with CIBP on E-line. 1 /23/2003 00:00 - 00:30 0.50 STWHIP N DFAL WEXIT Cant. RIH with E-line to set bridge plug at 8587' ELMD 00:30 - 01 :30 1.00 STWHIP N DFAL WEXIT Log on depth and set CIPB at 8587' ELMD. POH with setting tool. RD SWS. 01 :30 - 02:00 0.50 STWHIP P WEXIT Test 9 5/8" 47# casing to 3500 psi, hold for 30 minutes. Outer annulus pressure increase from 0 psi to 10 psi during pressure test. 02:00 - 03:00 1.00 STWHIP P WEXIT PU and MU whipstock, orient same to MWD. 03:00 - 04:30 1.50 STWHIP P WEXIT MU BHA. Function test MWD at 945' - OK 04:30 - 08:30 4.00 STWHIP P WEXIT RIH with whipstock to 8587' at 90 seconds per stand. Fill pipe every 2000' 08:30 - 09:00 0.50 STWHIP P WEXIT Orient whipstock to 69 degrees left of high side (final position). Set anchor with 20 klbs down weight. Shear mills with 45 klbs down weight. Tagged up at 8582' 09:00 - 12:00 3.00 STWHIP P WEXIT Circulate new 11.3 PPG mud surface to surface at 220 GPM @ 600 psi. Get slow pump rates: SPR#1 2 BPM = 310 psi, 3 BPM = 415 psi, SPR#2 2 BPM = 315 psi, 3 BPM = 415 psi. MD = 8560', TVD = 7820' 12:00 - 20:00 8.00 STWHIP P WEXIT Mill window with whipstock assembly from 8560' to 8576' plus 14' of openhole to 8590'. PU wt. 195 klbs, SO wt. 165 klbs, ROT wt. 170 klbs. INITIAL CUT 160 SPM, 400 GPM, 1900 PSI, 3K - 5K WOB, 7K - 9K TO. FINAL CUT 184 SPM, 450 GPM, 2170 PSI, 120 RPM, 20K - 22K WOB, 7K TO. 80% recovery of metal. Work pipe through window rotating and sliding, no 1 ,00 STWHIPI p problems 20:00 - 21 :00 WEXIT Circulate 50 bbl Hi-Vis sweep surface to surface 450 GPM @ 2180 PSI to clean hole 21 :00 - 00:00 3.00 STWHIP!P WEXIT Monitor well - no flow. Pump dry job. POH, PU wt. 200 klbs, SO I Printed: 2/17/2003 22850 PM ) ) . BP EXPLORATION. OperâtionsSummary Report Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: S-28 S-28 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From -To Houts Task Code NPT Phase 1/23/2003 3.00 STWHIP P WEXIT 21 :00 - 00:00 1/24/2003 00:00 - 00:30 0.50 STWHIP P 00:30 - 02:00 1.50 STWHIP P 02:00 - 03:00 1.00 STWHIP P 03:00 - 05:00 2.00 DRILL P 05:00 - 08:00 3.00 DRILL P 08:00 - 09:30 1.50 DRILL P 09:30 - 10:00 0.50 DRILL P 10:00 - 10:30 0.50 DRILL P 10:30 - 12:00 1.50 DRILL P 12:00 - 00:00 12.00 DRILL P 1/25/2003 00:00 - 05:30 5.50 DRILL P 05:30 - 08:00 2.50 DRILL P WEXIT WEXIT WEXIT LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 08:00 - 00:00 16.00 DRILL P LNR1 1/26/2003 00:00 - 08:00 8.00 DRILL P LNR1 08:00 - 09:30 1.50 DRILL P LNR1 09:30 - 12:30 3.00 DRILL P LNR1 12:30 - 14:00 1.50 DRILL P LNR1 14:00 - 14:30 0.50 DRILL P LNR1 14:30 - 17:30 3.00 BOPSURP LNR1 17:30 - 19:00 1.50 DRILL P LNR1 19:00 - 21 :00 21 :00 - 22:00 2.00 DRILL P 1.00 DRILL I P I LNR1 LNR1 Start: 1/17/2003 Rig Release: 2/15/2003 Rig Number: Spud Date: 1/18/2003 End: 2/15/2003 Description of Operations wt. 160 klbs. No drag, hole appears to be clean. SPR#1 2 BPM = 330 PSI 3 BPM = 400 PSI, SPR#2 2 BPM = 335 PSI, 3 BPM = 410 PSI. MD - 8590', TVD -7847' Stand Back HWDP LD BHA #2, 9 steel DC, MWD and mill assembly Flush BOP stack, clear and clean floor PU BHA #3 PU MU singles from pipe shed, 129 joints TI H to 8300' FIT EMW = 12.5 ppg. Baseline ECD = 11.74 Orient tool face to 60 degrees left. Continue TIH to 8590' Drill from 8590' to 8622'.205 SPM, 505 GPM @ 2640 PSI. PU weight 210 klbs, SO weight 160 klbs. AST = 1.13 hrs., ART = 0 hrs. Continue drilling from 8622' to 8788', slide most of each stand to drop angle. PU.weight 190 klbs, SO weight 155 klbs. AST = 7.21 hrs., ART = 0.25 hrs. Drill from 8788' to 9011' 215 SPM, 525 GPM @ 3260 PSI. PU weight 194 klbs, SO weight 156 klbs, ROT weight 178 klbs. Baseline ECD = 11.74 ppg, calc ECD = 11.70 Circulate and backream 1 stand to clean hole. ECD increase from 11.7 ppg to 12.4 ppg. Observed a small amount of splintered shale across shakers. Weight up mud 0.1 to 11.4 ppg. Circulate hole clean. Calculated ECD = 11.85, actual ECD = 11.91 Drill from 9011' to 9235' MD. Backream full stands @ 80 RPM, reduce pumps on down stroke. Calculated ECD = 11.75, actual ECD = 11.82. PU weight 198 klbs, SO weight 169 klbs, ROT weight 179 klbs. AST = 11.96 hrs., ART = 0.8 hrs, TVD = 8415' Drill from 9235' to 9330'. PU weight 201 klbs, SO weight 168 klbs, ROT weight 180 klbs. 208 SPM, 510 GPM @ 3000 PSI. ART 0.0 hrs, AST 4.68 hrs. Rap low. Circulate sweep surface to surface. Max pump rate 520 GPM @ 3095 PSI, 212 SPM. Reduce pump rate on downstroke to prevent surging of formation. ECD = 11.84 ppg, calculated ECD = 11.78 ppg. Monitor well- NO FLOW. Pump dry job. POH for bit chg. PU weight 206 klbs, SO weight 165 klbs. Intermittent increase in drag from 5-10 klbs in open hole section. No noticeable increase in drag across window LD 2 joints of HWDP. Standback remaining HWDP, Jars, Collars. LD MWD. Bit in gauge and no cutter damage. Clean and clear rig floor Pull wear ring. RU to test BOP. Test BOP - rams to 3500 psi / 250 psi, annular to 3500 psi / 250 psi. witness of BOP test waived by John Spaulding, AOGCC. RD test equipment, blow down lines. Install wear ring PU new motor, MU bit (DS70). Adjust motor to 1.5 degrees. PU MWD, ARC/PWD. Orient same. RIH with collars, jars and 5" HWDP. Shallow function test MWD at 500 GPM @ 1060 psi - OK. RIH to 5000', fill DP at 2500' i Cut and slip 65' of drill line. Test and function Crown-Q-Matic. i Printed: 2/17/2003 22850 PM ) ') Legal Well Name: S-28 Common Well Name: S-28 Spud Date: 1/18/2003 Event Name: REENTER+COMPLETE Start: 1/17/2003 End: 2/15/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/15/2003 Rig Name: NABORS 9ES Rig Number: Date From- To Hours Task Code NPT Phase Description of Operations 1/26/2003 21 :00 - 22:00 1.00 DRILL P LNR1 Service top drive and blocks. 22:00 - 22:30 0.50 DRILL P LNR1 Circulate 1 DP volume of mud at 400 GPM @ 1470 psi to break gels. Reciprocate DP. PU weight 132 klbs, SO weight 117 klbs. 22:30 - 00:00 1.50 DRILL P LNR1 Continue RIH at 1 minute per stand. Monitor DP displacement 1/27/2003 00:00 - 00:30 0.50 DRILL P LNR1 Continue RIH to 8480'. Orient 60L and pass thru window at 8560' - OK. Took 10-15K at 8620' & went on thru. 00:30 - 01 :30 1.00 DRILL P LNR1 Break circ & stage pumps up to 500 gpm. Circ down & work past obstruction at 9302'. Wash down to 9330'. 01 :30 - 12:00 10.50 DRILL P LNR1 Drill ahead to 9480' MD. 100% sliding. 500 gpm. 3020 psi. 200 klbs up. 170 klbs dn. ROP appears to improve below -9430' to 20-35 fph range. Still having difficulty holding tool face but stalls less frequent. 12:00 - 21 :00 9.00 DRILL P LNR1 Drill ahead to 9700' MD. 100% sliding. 510 gpm, 3240 psi. 202 klbs up, 163 klbs down. ROP 30-40 fph. ROP decrease below -9690' MD. 21 :00 - 22:30 1.50 DRILL P LNR1 Circulate bottoms up at 9700'. pump sweep to surface » surface. Reciprocate DP at 80 rpm, 3200 psi. Geologist to pick TD. 22:30 - 00:00 1.50 DRILL P LNR1 Drill ahead to 9725' MD. 100% sliding. 510 gpm, 3240 psi. 202 klbs up, 163 klbs down. TD for 7" liner picked by geologist 10-15' MD into the Sag R Fm. 1/28/2003 00:00 - 01 :00 1.00 DRILL P LNR1 Circulate samples, pump sweep at TD. 80 rpm, 510 gpm, 208 spm, 3300 psi 01 :00 - 02:00 1.00 DRILL P LNR1 Monitor well. Short trip to 8605' MD. Pulled 10 klbs over at 9365' MD. 210 klbs up, 155 klbs down. 02:00 - 02:30 0.50 DRILL P LNR1 Monitor well. TIH at 1 min/stand. Circ down and work past obstruction at 9398'. Wash down to TD 9725". 02:30 - 05:00 2.50 DRILL P LNR1 Stage pumps up to 510 gpm, 3300 psi, 80 rpm. Pump sweep surface»surface. Spot 1 00 bblliner running pill. Pump dry job. Drop rabbit. 05:00 - 08:30 3.50 DRILL P LNR1 Monitor well. POH to 8525'. Monitor well before tripping out of window. Continue POH to run 7" liner. 08:30 - 10:30 2.00 DRILL P LNR1 LD Jars, MWD, ARC/PWD, motor, bit. Bit in gauge and no cutter damage. 10:30 - 11 :00 0.50 DRILL P LNR1 Clean and clear floor 11 :00 - 12:00 1.00 BOPSURP LNR1 PU joint of DP, flush BOP stack. Pull wear ring. Install test plug. 12:00 - 13:30 1.50 BOPSUR P LNR1 Change out BOP rams from 3 1/2 X 6 variables to 7". Test door seals 3500/250 psi 13:30 - 14:30 1.00 CASE P LNR1 RU casing tongs & fill up line. Install 7" elevators 14:30 - 15:00 0.50 CASE P LNR1 PJSM NAD, Nabors Csg, Baker, BP on running liner, picking up float equipment and cementing head. 15:00 - 16:30 1.50 CASE P LNR1 PU 7" 26# BTC-Mod float equipment. Torque to mark. Fill and check float equip. RIH with 7" liner. Fill all joints. MU HMC liner hanger and ZXP liner top packer. 68 klbs up, 60 klbs down. 16:30 - 20:30 4.00 CASE P LNR1 RIH with 4 stands 5" HWDP. Circulate liner vol. Stage pumps to 5 BPM, 179 psi. RIH with DP at 1 stand per min. Fill every 10 stands to 5000' 20:30 - 21 :00 0.50 CASE P LNR1 Circ. DP and Liner volume at 5 BPM, 415 psi 21 :00 - 23:00 2.00 CASE P LNR1 RIH 1 stand per minute to top of window, 8560' MD. 187 klbs Ip up, 161 klbs dn. i 23:00 - 00:00 1.00 CASE I LNR1 Circulate BU at top of window. Stage pumps to 6 BPM, 680 psi I Printed 2/17/2003 2:2850 PM '1\ } ) BPEXPLORATION Page 60f 16 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-28 S-28 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From - To Hours Task Code NPT Phase 1/29/2003 00:00 - 01 :00 1.00 CASE P LNR1 01 :00 - 02:30 1.50 CASE P LNR1 02:30 - 05:00 2.50 CASE P LNR1 05:00 - 06:00 1.00 CEMT P LNR1 06:00 - 06:30 0.50 CASE P LNR1 06:30 - 07:30 1.00 CASE P LNR1 07:30 - 08:30 1.00 CASE P LNR1 08:30 - 12:00 3.50 CASE P LNR1 12:00 - 12:30 0.50 CASE P LNR1 12:30 - 13:00 0.50 DRILL P PROD1 13:00 - 14:00 1.00 BOPSUR P PROD1 14:00 - 17:30 3.50 BOPSUR P PROD1 17:30 - 18:30 1.00 DRILL P PROD1 18:30 - 21 :00 2.50 DRILL P PROD1 21 :00 - 22:30 1.50 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P PROD1 1/30/2003 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 01 :00 0.50 DRILL P PROD1 01 :00 - 02:30 1.50 DRILL P PROD1 02:30 - 05:00 2.50 DRILL P PROD1 05:00 - 05:30 0.50 DRILL P PROD1 05:30 - 06:00 0.50 DRILL P PROD1 06:00 - 08:00 2.00 DRILL P PROD1 08:00 - 08:30 0.50 DRILL P PROD1 108:30 - 09:00 0.50 DRILL P PROD1 109:00 - 10:30 1.50 DRILL Ip PROD1 I I I I Start: 1/17/2003 Rig Release: 2/15/2003 Rig Number: Spud Date: 1/18/2003 End: 2/15/2003 Descri ptionC>f0përatidrns Continue Circulate BU at 8497'. 250 gpm, 800 psi. 180 klbs up, 150 klbs down. RIH with 7" liner to tag TD at 9725".200 klbs up, 150 klbs down Break circulation at 34 SPM. stage up pumps to 300 gpm, 1460 psi. Circulate 1-1/2 bottoms up. Pump 5 bbl KCL water. Test lines to 4000 psi - OK. Pump 5 bbl KCL water. Follow with 30 bbl Alpha Spacer at 12.3 ppg. Pump 55 BBL, 275 SX, class G cement with Super CBL at 15.8 ppg. Drop plug and kick out with 10 bbl water. Drop plug and kick out with 10 bbl water. Pump 121 bbls at 6 bpm with rig pumps. bump plug at calculated displacement. Cement in place 0600 hrs Set HMC liner hanger as per Baker. Pressure up to 3500 psi. Set down 25 klbs to confirm hanger set. Bleed down press to check floats - OK. ROT 20 turns right to release. Pressure up to 1000 psi. PU to clear seals and open dogs. Circ 10 bbl to clear cement from tieback. Set down 50 klbs several times confirm shear. Set down 25 klbs and rotate to set packer. Circulate cement from liner. 10 bpm, 2190 psi. Spacer seen at surface but no cement seen. Break out and LD cement head POH with liner running tool LD HWDP. Break out and LD liner running tool Clean and Clear floor Pull wear bushing, Install test plug. Change out 7" rams, install 3-1/2" to 6" variable. RU and Test BOP 3500/250 psi. BOP test witness waived by Jeff Jones, AOGCC. Pull test plug. Install wear bushing. Blow down lines MU bit, motor, NM Stab. PU MWD, LWD. Orient same. RIH, shallow test 250 gpm, 1000 psi - OK. RIH with DP to top of I;iner at 8384'. 170 klbs up, 135 klbs down. Service Rig. Cut and slip 65' of drilling line. Service top drive, blocks, crown. Continue RIH with DP to 9495. Break circulation and wash down watching for cement top. Continue wash down from 9401'. Tag cement at 9576' MD. Test 7" 26# Csg to 3500 psi, hold for 30 min. Drill Cement and Float equip. from 9576' to 9725'. Drill 3' of new hole to place bit outside of csg during mud swap. Circulate new Qwik Drill 8.5 ppg mud surface»surface. 245 gpm, 1750 psi Drill 17' to 9745' to perform FIT FIT EMW = 9.6 ppg. surface pressure = 500 psi-- Test mud wt. 8.5-- TVD 8759. Directional drill from 9745' to 9795', sliding. Hole began losing fluid at 100-150 BPH. P/U and monitor losses. Monitor well for losses. Losing 100 bph Directional drill from 9795' to 9820', while mixing 55 BBL. Baracarb pill @ 100 ppb. Pump 55 bbl Baracarb pill. Spot pill outside pipe. Reciprocate Printed 2/17/2003 2:28:50 PM J ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Operations Summary Report S-28 S-28 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 1/17/2003 Rig Release: 2/15/2003 Rig Number: Spud Date: 1/18/2003 End: 2/15/2003 Date From - To Hours Task Go de NPT Phase Description of Operations 1/30/2003 09:00 - 10:30 1.50 DRILL P PROD1 and monitor losses @ 80 bph. After app. 40 bbls. lost the hole become static. Mix 55 BBLS. 100 PPB LCM pill with following ingredients: 20 ppb Baroseal (F) 20 ppb Baroseal (M) 30 ppb Barofibre 20 ppb OM seal 10 ppb Walnut (F) 10:30 - 12:00 1.50 DRILL P PROD1 Directional drill from 9820' to 9835', sliding. 189 klbs up, 156 klbs down, 185 klbs rot. 105 spm, 258 gpm, 1450 psi. Intermittent losses from 10-50 bph while drilling ahead stringing in Barofibre at 10 SX per hour 12:00 - 16:00 4.00 DRILL P PROD1 Directional drill from 9835' to 9894', sliding. 8% decrease in flow at 9894'. Monitor well losses = 180 bph. 16:00 - 16:30 0.50 DRILL P PROD1 Transer 18 bbl Barafibre pill over to active system. Pumped downhole. Regain circulation. Losses = 80 bbl 16:30 - 23:30 7.00 DRILL P PROD1 Directional drill from 9894' to 9988', sliding, rotate last stand. Lost returns at 9988'.193 klbs up, 160 klbs down, 178 klbs rotate. 262 gpm, 1730 psi on bot, 1625 psi off. Back ream stands at 60 rpm, reduce pump rate on downstroke. 23:30 - 00:00 0.50 DRILL P PROD1 Transfer 10 bbl Barofibre pill over to active system. Circulate. Reciprocate pipe while monitoring well. Regain circulation. Lost 120 bbls. Total losses for 24 hrs = 540 bbl 1/31/2003 00:00 - 00:30 0.50 DRILL P PROD1 Pump Barofibre pill around. Reciprocate DP. Regain circulate. String in 20 SX barofibre per hour. Dynamic losses = 120 bph. 00:30 - 03:30 3.00 DRILL P PROD1 Directional drill from 9988' to 10118'. Intermittent dynamic losses gradually reduced from 120 bph to 40 bph. Continue stringing in 20 SX barofibre per hour. Having detection problems with MWD as LCM concentrations are increased. 03:30 - 04:00 0.50 DRILL P PROD1 Monitor well, static losses 12 bph. Reduce Barofibre from 20 SX/hr to 10 SX/hr 04:00 - 06:30 2.50 DRILL P PROD1 Directional Drill from 10118 to 10176' monitoring losses and string in Baroseal. Detection problems increasing causing questionable toolface data. Losses app. 80 BPH. 06:30 - 07:30 1.00 DRILL N DPRB PROD1 Circulate and monitor well. Dynamic losses app. 64 BPH. Mix LCM pill. Drop ball rod to open circ sub. Pump 40 BBL of 100 ppb LCM pill. Chase with 104 BBL mud to spot pill outside of DP, 107 SPM, 262 GPM, 650 PSI. The 100 ppb LCM pill had the following ingredients: 20 ppb Baroseal (F) 20 ppb Baroseal (M) 30 ppb Barofibre 20 ppb OM seal 10 ppb Walnut (F) 07:30 - 08:00 0.50 DRILL N DPRB PROD1 POH to 9213 to put BHA above LCM pill. 198 klbs up, 155 klbs down. 08:00 - 09:30 1.50 DRILL N DPRB PROD1 Circulate across the top of the LCM pill. Monitor well to check losses with circulation rate. 115 GPM = 12 BPH loss, 150 = 4 BPH loss, 300 GPM = 4 BPH loss, 400 GPM = 8 BPH loss, 300 GPM = 12 BPH loss. Shut down pumps monitor well - static, no losses. I I Printed 2/17/2003 22850 PM ') '> Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-28 S-28 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 1/17/2003 Rig Release: 2/15/2003 Rig Number: Spud Date: 1/18/2003 End: 2/15/2003 Date From - To Hours Task Code NPT Phase Description of Operations 1/31/2003 09:30 - 12:00 2.50 DRILL N DPRB PROD1 Pump dry job. Monitor well - static. POH to change out circ sub, MWD, motor, bit. 12:00 - 14:00 2.00 DRILL N DPRB PROD1 On TIH at +/- 5325' Flosho indicated the hole was taking fluid. Monitor well, estimated losses 60 BPH. TIH monitoring losses. Stop at shoe to fill DP, 40 BBL lost on TIH. Monitor well, static losses app. 12 BPH 14:00 - 15:00 1.00 DRILL N DPRB PROD1 Pump 50 BBL, 100 ppb LCM pill at 160 GPM, 300 psi. Chase with DP vol. of mud to spot pill outside of DP. Monitor well, lost 38 BBL while pumping LCM. Fill hole and continue monitoring well, static at this point, no losses. The LCM pill had the following ingredients: 35 ppb Baroseal (F) 35 ppb Baroseal (M) 20 ppb OM seal 10 ppb walnut (F) 15:00 - 15:30 0.50 DRILL N DPRB PROD1 POH to 8360'. Hole Fill = DP Distplacement. 15:30 - 17:00 1.50 DRILL N DPRB PROD1 Stage pump to drilling rate 250 GPM, 384 psi. Losses decrease to 0 BPH after pumping away 5 BBL. Increase pump rate to 270 GPM, 475 psi - NO losses. 400 GPM, 700 psi - NO losses. Monitor well - static, no losses. Pump dry job. 17:00 - 20:30 3.50 DRILL N DPRB PROD1 Continue POH from 8360' to BHA. Hole fill is 4 BBL over DP disp. Monitor well, static no losses. 20:30 - 22:00 1.50 DRILL N DPRB PROD1 Attemp to flush the BHA with water, packed off with LCM. Stand back collars, jars. LD MWD. Clean LCM out of stabilizer and lead collar 22:00 - 22:30 0.50 DRILL N DPRB PROD1 Clean and clear floor 22:30 - 23:30 1.00 DRILL N DPRB PROD1 MU new bit, new motor, new MWD. Orient MWD. TIH with collars and jars to shallow test MWD. Check circ sub. 23:30 - 00:00 0.50 DRILL N DPRB PROD1 RIH - monitoring DP displacement Losses for last 24 hrs = 890 bbl 2/1/2003 00:00 - 04:00 4.00 DRILL N DPRB PROD1 RIH with DP, watching DP fill volumes. Fill DP every 25 stands. No losses on TIH 04:00 - 04:30 0.50 DRILL N DPRB PROD1 Rig Service. Service top drive, draw works 04:30 - 05:30 1.00 DRILL N DPRB PROD1 Break circulation at the csg shoe. Stage pumps up to 105 SPM, 255 GPM, 1140 psi. Reciprocate DP, keeping bit below csg. shoe. No losses while circulating 05:30 - 07:00 1.50 DRILL N DPRB PROD1 Wash and ream down to 9866' slowly with 105 SPM, 255 GPM, 1140 psi. Attempting to move 100 ppb LCM pill up hole. At 9866' the hole started taking fluid. Monitor well while keeping the backside full, app 50 BPH static losses. Circlulate, regain returns. Dynamic losses app. 60-100 BPH Continue wash down to 10176', 07:00 - 21 :30 14.50 DRILL P PROD1 Directional drill from 10176' to 10521'. Dynamic losses while drilling 40-80 BPH. Back ream stands at 60 RPM, reduce pump rate on downstroke. 190 klbs up, 155 klbs down, 174 klbs rot. Unable to get turn rate needed to avoid departure from polygon on Northern boundry. 21 :30 - 22:30 1.00 DRILL P PROD1 Circulate sweep at 260 GPM, 1100 psi. Reciprocat DP at 60 RPM. Dynamic losses while circulating app. 40 BPH. Suspected problem with IFR corrections MWD data. Decision made to re-survey from 10,118' to csg. shoe. 22:30 - 00:00 1.50 DRILL N DPRB PROD1 Monitor well - Static losses app. 80 BPH. POH to 10,118. POH from 10,118 to casing shoe taking check shots every 30 ft. to Printed 2/17/2003 228:50 PM ) \ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-28 S-28 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 1/17/2003 Rig Release: 2/15/2003 Rig Number: Spud Date: 1/18/2003 End: 2/15/2003 Date From- To Hours Task Code NPT Phase Description of Operations 2/1/2003 22:30 - 00:00 1.50 DRILL N DPRB PROD1 confirm and re-calculate MWD data and IFR corrections. Dynamic losses during MAD pass 40 BPH 2/2/2003 00:00 - 01 :00 1.00 DRILL N DPRB PROD1 Continue POH making MWD check shot from 10,118 to the csg. shoe. Dynamic losses during MAD pass 40 BPH 01 :00 - 02:30 1.50 DRILL N DPRB PROD1 Circulate sweep out of hole at csg shoe while calculating and correcting MWD surveys. Anchorage and rig team decision was made to open hole sidetrack at 10065" MD. Too much risk was associated with drilling outside the Polygon with the fault / lost circulation potential. 02:30 - 03:00 0.50 STKOH N DPRB PROD1 RIH to 10050'. Fill DP. Break circulation, stage pump to 106 SPM, 260 GPM, 1045 psi. 03:00 - 04:00 1.00 STKOH N DPRB PROD1 Orient MWD to low side of hole. Trench from 10030' to 10065' to start sidetrack. 04:00 - 10:30 6.50 STKOH N DPRB PROD1 Time drill open hole sidetrack from 10065' to 10095' at 5' ftlhr. Hold inclination at the bit to greater than 72 degrees to drop away from previous wellbore. Dynamic losses 30-50 BPH 10:30 - 12:00 1.50 STKOH N DPRB PROD1 Directional drill from 10095' to 10126'. 100% sliding. Increasing WOB and ROP. Maintain inclination at bit and turn to the left (South) to avoid previous wellbore and regain polygon. 250 GPM @ 11 psi. 190 klbs up, 150 klbs down, 174 klbs Rot. 12:00 - 00:00 12.00 STKOH N DPRB PROD1 Directional drill from 10126' to 10363'.100% sliding. Back ream stands at 60 RPM, reduce pump rate on downstroke. Dynamic losses while drilling ahead 50 BPH. 192 klbs up, 155 klbs down, 178 klbs Rot. Directional drilling as per sidetrack plan, sidetrack dropped below previous wellbore then turned to the south to put the sidetrack within the original polygon. 2/3/2003 00:00 - 06:00 6.00 STKOH N DPRB PROD1 Directional drill from 10363' to 10522'.100% sliding. Back ream every stand at 60 RPM, reduce pump rate on downstroke. Dynamic losses while driling ahead 50-60 BPH. 190 klbs up, 155 klbs down, 174 klbs Rot. 106 SPM, 260 GPM, 1250 psi. Drop angle from -94 to -91 degrees, slide to the south, just north of plan. 06:00 - 12:00 6.00 STKOH P PROD1 Directional drill from 10522' to 10670'. Sliding. Dynamic losses while driling ahead 35-55 BPH to 10620' then increased to 75-100 BPH. 197 klbs up, 152 klbs down, 174 klbs Rot. 104 SPM, 250 GPM, 1350 psi. Hold angle at -90 degrees, slide to the south, on plan. 12:00 - 23:00 11.00 STKOH P PROD1 Directional drill from 10670' to 10881'. Back ream every stand at 60 RPM, reduce pump rate on downstroke. Dynamic losses while driling ahead 60-80 BPH. 196 klbs up, 152 klbs down, 177 klbs Rot. 104 SPM, 250 GPM, 1350 psi. Drop angle from -90 to -86 degrees, well walking north, on plan. 23:00 - 00:00 1.00 STKOH P PROD1 Lost returns at 10881' Monitor well, static losses app. 136 BPH, dynamic losses app. 180 BPH. Set up mud pump #2 on secondary kill line to keep the backside full of fluid. Mix 30 PPB Barofibre LCM pill. Current wellbore is 42' above and 124' North of S-28A wellbore, which experienced lost circulation through this same interval. 2/4/2003 00:00 - 00:30 0.50 DRILL P PROD1 Spot 33 bbls of 30 PPB LCM pil. Fill hole across the back side I with #2 mud pump through the secondary kill line. Reciprocate DP above pill and allow LCM to soak in. Monitor well, static losses 105 BPH. 00:30 - 18:00 17.50 DRILL Ip , PROD1 Directional drill from 10895' to 11,715'. lost returns at app. I i i I Printed: 2/17/2003 22850 PM ) ), Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-28 S-28 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 1/17/2003 Rig Release: 2/15/2003 Rig Number: Spud Date: 1/18/2003 End: 2/15/2003 Date From - To Hours Task Code NPT Phase Description of Operations 18:00 - 19:30 1.50 DRILL N PROD1 10995'. Started pumping 1 bbl/min across the backside with pump #2 to keep the hole full. Pump #1 104 SPM, 250 GPM, 1215 psi. Losses increasing from 140 to 400 BPH. At 03:00 switched over to seawater. 200 klbs up, 153 klbs down, 178 klbs Rot. While drilling ahead at 11,715 losses of 600-700 were developed. AST= 2.7 ART=7.7 ADT=10A DPRB PROD1 POOH while backreaming intermittent tight spots. Saw 20K drag while working out of hole at 10,090 to 10,060. ( Trough area and kick-off point.) DPRB PROD1 Drop circ. sub dart and pump to seat. Shear and pump down inside and outside keeping hole full while building 110 PPB LCM pill with following products: 10 ppb Baroseal fine; 10 ppb. Baroseal Med.; 20 ppb. Barofiber; 20 ppb OM seal; 10 ppb. wallnut med.; 30 ppb steelseal; 10 ppb Baracarb 600. 2/4/2003 00:30 - 18:00 17.50 DRILL P 19:30 - 00:00 4.50 DRILL N 2/5/2003 00:00 - 00:30 0.50 DRILL N DPRB PROD1 Spot 100 bbls. LCM pill # 1 at 110 PPB outside DP. Pump rate at 90 SPM @ 450. Slow to 65 SPM @ 200 as LCM started out circ. sub.. Once LCM started out circ. sub., rate was returned to 90 SPM. Losses were reduced to 245 BPH once pill was in place. 00:30 - 03:00 2.50 DRILL N DPRB PROD1 Mix and build 100 bbl. LCM pill #2 while monitoring well for losses. Initial after spot 245 30 minutes 385 1 hour 465 1.5 500 2 hours 550 2.5 hours 650 03:00 - 06:00 3.00 DRILL N DPRB PROD1 Spot 100 BBL. LCM pill # 2 at 120 PPB with following products. 10 ppb Baroseal fine--20 ppb Baroseal Med.--20 ppb Barofiber--20 ppb OM seal--1 0 ppb wallnut--30 ppb Steel seal--10 ppb Baracarb 600. Monitor well while mixing LCM pill. Initial after spot 45 BPH 1 hour 350 2 hour 500 3 hour 540 06:00 - 10:00 4.00 DRILL N DPRB PROD1 Spot 100 BBLS. LCM pill #3 at 120 PPB as per above ingredients. Monitor losses and build LCM pill Initial after spot 45 BPH 1 hour 181 12 hour 213 i I Printed: 2/17/2003 2:28:50 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date S-28 S-28 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 1/17/2003 Rig Release: 2/15/2003 Rig Number: Spud Date: 1/18/2003 End: 2/15/2003 2/5/2003 From - To Hours Task Code NPT Phase 06:00 - 10:00 4.00 DRILL N DPRB PROD1 10:00 - 14:00 4.00 DRILL N DPRB PROD1 Description of Operations 2.5 hour 500 Spot 100 BBLS. LcM pill #4 at 120 PPB Monitor losses and build LCM pill 14:00 - 18:00 4.00 DRILL N Initial after spot 100 BPH 1 hour 140 2 hour 356 3 hour 377 4 hour 380 DPRB PROD1 Spot 100 BBLS. LcM pill # 5 at 120 PPB Monitor losses and build LCM pill Initial after spot 168 1 hour 90 2 hour 244 3 hour 275 18:00 - 23:00 5.00 DRILL N DPRB PROD1 Spot 100 BBLS. LCM pill # 6 at 120 PPB Monitor well and build 130 PPB LCM pill. Waiting for MI to deliver Form-A-Plug Initial after spot 1 hour 2 hour 3 hour 4 hour 4.5 hour 101 125 165 180 200 started losses of 600 BPH 23:00 - 00:00 1.00 DRILL N DPRB PROD1 Spot 40 BBLS. LCM pill # 7 to slow losses while Preparing to mix Form-A-Plug. Losses reduced to 450 DPRB PROD1 Mix and spot 64 bbls. FORM-A-PLUG as follows: Test lines to 3,500. Spot 100 BBLS. LCM pill at 130 ppb., 10 bbls. 10.9 spacer, 64 bbls. FORM-A-PLUG, 10 bbls. 10.9 spacer and 90 bbls. seawater. Bit at 9679 and circ. sub at 9514. Shoe @ 9,725. 2/6/2003 00:00 - 02:00 2.00 REMCM-N Pressures as FORM-A-PLUG exited circ. sub and was spotted at 7" shoe: As the Plug exited circ. sub 290 strokes @ 156 PSI 575 strokes @ 313 PSI 600 strokes @ 322 PSI 800 strokes @ 415 PSI 1000 strokes @ 451 PSI 1200 strokes @ 490 PSI 1400 strokes @ 528 PSI 1600 strokes @ 577 PSI Slowed pumps and spotted with 1680 strokes. Plug in place at 01 :45 HRS. Confirm no pressure and open bag. Pull 2 stands drillpipe to ! 9,494. I Printed: 2/17/2003 228:50 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ') ,I B.IÞ··.··æl~IL@~~TI(.8)tsJ O:'erratiiQf1s····SLimmary· ·:Repørt S-28 S-28 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 1/17/2003 Rig Release: 2/15/2003 Rig Number: Spud Date: 1/18/2003 End: 2/15/2003 Date From- To Hours Task Code NPT Phase Descriptionöf Operations 2/6/2003 02:00 - 02:30 0.50 REMCM-N DPRB PROD1 Close bag and IBOP on topdrive. Wait 30 minutes. (No fluids added to wellbore during wait.) 02:30 - 09:30 7.00 REMCM-N DPRB PROD1 Pull 2 stands to 9,306. Close bag around pipe and shut IBOP on drill string. Added no fluids to wellbore during waiting period. 09:30 - 12:30 3.00 REMCM-N DPRB PROD1 Check inside/outside well pressures to confirm zero pressures and open up well. Fill pipe inside and outside with 52 BBLS. Fluid level had dropped 770 ftoo Circulate bottoms up with full returns and no gas show. 12:30 - 13:00 0.50 REMCM-N DPRB PROD1 Monitor well---static. 13:00 - 14:00 1.00 REMCM-N DPRB PROD1 Spot 60 bbls. LCM at 110 PPB. Observe well---static. 14:00 - 18:00 4.00 REMCM- PROD1 POH. Lay down BHA. Break and grade bit. 18:00 - 21 :00 3.00 REMCM-N DPRB PROD1 Test BOP as per policy--250/3,500. Witness of test waived by AOGCC. AOGCC had granted an extension of the weekly test, due to hole problems. 21 :00 - 00:00 3.00 REMCM-N WAIT PROD1 Wait on Weather. Due to blowing and drifting snow with zero visibility, Phase 3 driving conditons were announced. 2/7/2003 00:00 - 05:00 5.00 DRILL N DPRB PROD1 Pick up used 61/8 Hughes STX-09D, NB stabalizer, F/S, XO, 7 jts. HWDP, Jars, and 1 jt. HWDP. TIH with "Dumb Iron" BHA. Break circulation at 5,000 and 8,400. No losses on TIH 05:00 - 06:30 1.50 DRILL N DPRB PROD1 Circulate and wash LCM from 8,400 to 9707 with 300 GPM @ 625 PSI, 170 Up, 150 DW, 160 RT, 80 RPM with 2,700 TO. Full returns at 20% on flowshow---no losses. 06:30 - 09:30 3.00 DRILL N DPRB PROD1 Bring bottoms up to remove LCM prior to going into open hole. Began showing reduction in flow-show. Reduced rate and continued to bring bottoms up. Staged back to 300 GPM with full returns before bottoms up was reached. 09:30 - 00:00 14.50 DRILL N DPRB PROD1 Reaming from 9,707 to 10,456 as follows: Ream down 2 stands at 150 FPH and pump a Hi-vis sweep S-S, then continue reaming 2 stands at 150 FPH followed by sweep. Follow this process until reaching bottom. Losses ranging from 80-110 initially; improving to 40-60 BPH 300 GPM @ 660 PSI 80 RPM @ 6-7,500K torque **No problems getting into open hole sidetrack at 10,065.** 2/8/2003 00:00 - 01 :00 1.00 DRILL N DPRB PROD1 Ream from 10,456 to 10,549, with following parameters: ROP==150 GPM==300 PSI===660 RPM==80 @ 6-7,500 TO. Losses=40-60BPH 01 :00 - 02:30 1.50 DRILL N DPRB PROD1 Pump 10 bbls. Hi-Vis sweep S-S. No significant increase in cuttings seen at shakers. Small amounts of Form-a-plug seen in washed samples. 02:30 - 04:00 1.50 DRILL N DPRB PROD1 Ream from 10,549 to 10,736. 04:00 - 05:30 1.50 DRILL N DPRB PROD1 Pump 10 bbls. Hi-Vis sweep 5-S. No significant increase in cuttings seen at shakers. 05:30 - 14:00 8.50 DRILL N DPRB PROD1 Ream from 10,736 to 10,823 when total loss of returns was observed. Est. Loss rate @ 450 BPH. Continue reaming to bottom with 450 BPH losses. Pump down backside to keep hole full. Hole began packing off with high torque from 10,976 Printed: 2/17/2003 228 50 PM ) ) BP EXPLORATION Page 13 of 16 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-28 S-28 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 1/17/2003 Rig Release: 2/15/2003 Rig Number: Spud Date: 1/18/2003 End: 2/15/2003 Date From - To Hours Task CodeNPT Phase· Description of Operations 2/8/2003 05:30 - 14:00 8.50 DRILL N DPRB PROD1 to 11,175. Work different parameters while trying to make progress in hole. Hole condition deteriorating. Pumping 6 BPM down drill string and 4 BPM down backside to keep hole full. 14:00 - 15:30 1.50 DRILL N DPRB PROD1 Backream out of the hole to 10, 736--hole tight and packing off. 15:30 - 19:00 3.50 DRILL N DPRB PROD1 Ream from 10,736 to 11,110 with 1 BPM 9.6 mud down drillpipe and 10 BPM down backside keeping hole full. Pump 40 bbls. Hi-vis pill down backside at 10,736 and 10,923. 19:00 - 00:00 5.00 DRILL N DPRB PROD1 Ream from 11,110 to 11,420 with 4 to 5 BPM down drillpipe keeping backside full from kill line. Pumping 10 bbls. Hi-Vis sweeps every 45 ft. Total fluid loss this 24 hours= 9294 Total fluid loss to well=======36,194 2/9/2003 00:00 - 03:00 3.00 DRILL N DPRB PROD1 Ream to bottom from 11 ,420 to 11,715 with following parameters: 80 RPM 10-11,500 TO. 245 GPM @ 660 PSI down drillpipe--pump down annulus as required to keep hole full. Pumping 10 bbl. Hi-Vis sweeps every 45' reamed Losses at 385, with no increases when final footage was reamed to TO Pump 20 bbl. Hi-Vis sweep outside bit + 50 bbls. prior to POH. 03:00 - 05:00 2.00 DRILL P PROD1 Short trip back to 7" casing shoe at 9725. Back ream and clean hole as follows: 85 RPM 9-10,000 TO. 245 GPM @ 660 PSI down drillpipe--pump down annulus as required to keep hole full. 385 bbl. losses while POH 05:00 - 05:30 0.50 DRILL P PROD1 Perform service work to Topdrive at 9704. 05:30 - 06:30 1.00 DRILL P PROD1 RIH to 11,715. Intermittent down drag from 10,900 to 11,688. 06:30 - 07:00 0.50 DRILL P PROD1 Pump 20 bbl. Hi-Vis sweep outside drillpipe plus open hole volume. Losses at 365 BPH 07:00 - 08:30 1.50 DRILL P PROD1 POH backreaming to above fault at 10,770. 08:30 - 13:30 5.00 DRILL P PROD1 POH. Lay down "Dumb Iron" BHA. Bit in gauge. Clear floor of all vendors excess equipment. Average loss while POH==385BPH Pumping 6.5 BPH down secondary kill line to keep hole full 13:30 - 18:00 4.50 CASE P COMP PJSM. R/U casing equipment and run 53 jts. of 4.5 12.6# L-80 liner with "HMCV" cementing equipment. 18:00 - 00:00 6.00 CASE P COMP RIH with 4 1/2 liner on 4" HT 40 drillpipe filling pipe every 10 stands. Tag up on ledge at 11,165. Make up topdrive and work ledge. Keep backside full with 7 BPM. Losses from 350 to 425 bbls. per hour. Phase 2 driving conditons hindering delivery of seawater. 2/10/2003 00:00 - 01 :00 1.00 CASE N DPRB ,COMP Attempt to work 4 1/2 liner to bottom at 11,165. Wash and ! pound on ledge with 60k down and various pump rates. Once i I I Printed: 2/17/2003 22850 PM ) ). BPEXPLORATION Operations Summary Report Page 14 of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-28 S-28 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 1/17/2003 Rig Release: 2/15/2003 Rig Number: Spud Date: 1/18/2003 End: 2/15/2003 Date From - To Hours Task Code NPT Phase Description of Operations 2/10/2003 00:00 - 01 :00 1.00 CASE N DPRB COMP stode up by ledge, no further downhole progress was made. Unable to keep up with seawater trucking due to "Phase 2" driving conditons. Zero visibility, drifting snow -27 below WC. Discuss options with Anchorage Drilling Manager, and rig team. 01 :00 - 02:00 1.00 CASE N DPRB COMP Trip back to casing shoe at 9725. Circulate down pipe to insure string is clear. Establish loss rate of 425 BPH. Blow down topdrive and allow fluid level to drop 5 minutes. Shut annular preventer, annulus valve and IBOP on drillpipe. 02:00 - 03:30 1.50 CASE N DPRB COMP Perform service work to topdrive/cut drilling line. 03:30 - 06:00 2.50 CASE N DPRB COMP Top off pits with seawater and truck seawater to location. Phase 2 driving conditions making trucking a slow process. 06:00 - 06:30 0.50 CASE N DPRB COMP Check inside outside pressures on wellbore and open choke to open position. Open annular preventer and IBOP. Fill hole with 235 bbls. Calculated fluid level after 4 hours shut in was 3475 ft. Calculate losses at 550 bbls. per hour once hole was filled. 06:30 - 07:30 1.00 CASE N DPRB COMP Top off well with seawater and allow to drop for 1 hour. 07:30 - 08:00 0.50 CASE N DPRB COMP Fill hole with 280 bbls.. Calculated fluid level at 4114. Static losses at 550 BPH. 08:00 - 09:30 1.50 CASE N DPRB COMP Shut well in and evaluate options with Anchorage Team. Decision to make another clean out run with hole opener. 09:30 - 13:00 3.50 CASE N DPRB COMP POH filling 2 X DP displacement every 5 stands. 13:00 - 18:00 5.00 CASE N DPRB COMP R/U casing equipment. Lay down 4 1/2 liner to float equip. Heat and break float equipment out. Nose section gone from float shoe. Put 100 bbls. fuid in wellbore. Clear floor of casing equipment and all excess tools. 18:00 - 19:00 1.00 CASE N DPRB COMP P/U clean out assembly with following components: 6 1/8 "Porcupine" hole opener, F/S, 3 ea. 4 3/4 DC, 6 1/8 stab, XO, 7 ea. 4" HWDP, jars, 1 HWDP. 19:00 - 00:00 5.00 CASE N DPRB COMP RIH filling pipe and adding 100 bbls. fluid to well at 6,000 ft. Continue RIH to 9714 and fill hole with 250 bbls. Establish loss rate of 595 BPH static. Get parameters prior to entering open hole. 2/11/2003 00:00 - 04:30 4.50 CASE N DPRB COMP RIH from shoe to 10,500. Ream to bottom from 10,500 to 11,151 with 100 RPM, 85 SPM @ 435 & 105 SPM @ 605. Hole packing off and tight at 11,151. Work back to 11,030 and clean hole. Up 205 Down 150 String 180 04:30 - 05:00 0.50 CASE N DPRB COMP Work pipe back to 11,060 and clean hole up. Pump 10 bbl. Hi-Vis sweep around hole opener and up hole. 05:00 - 09:30 4.50 CASE N DPRB COMP Spot 10 bbl. Hi-Vis sweep in pipe and wash down from 11,060 to 11,209. Very slow progress from 11,151 to 11,209 . Stacked 20k on ledge at 11,168 and worked several times to break through. RPM===80-1 00 GPM===208 WOB===3-20 Torque==7-13,OOO Loss rate was 300 BPH until breaking through obstruction @ 1.001 CASE 11,168, then increased to 515. 09:30 - 10:30 N DPRB COMP Pump 30 bbl. Hi-Vis sweep with 3% lubes while reaming up I and down from 11,209 to 11,115. Pump sweep as per Printed: 2/17/2003 228-50 PM ) BE'.æ~~t.O~~0Fli~f'5J Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date S-28 S-28 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 1/17/2003 Rig Release: 2/15/2003 Rig Number: Spud Date: 1/18/2003 End: 2/15/2003 2/11/2003 Frorn - To Hours Task Code NPT Phase 09:30 - 10:30 1.00 CASE N DPRB COMP 10:30 - 18:00 7.50 CASE N DPRB COMP 18:00 - 20:00 2.00 CASE N DPRB COMP 20:00 - 22:00 DPRB cOMP 2.00 CASE N 22:00 - 00:00 2.00 CASE N DPRB COMP 2/12/2003 3.50 CASE N DPRB COMP 00:00 - 03:30 03:30 - 12:00 8.50 CASE N DPRB COMP 12:00 - 12:30 0.50 CASE N DPRB COMP 12:30 - 14:00 1.50 CASE P COMP 14:00 - 15:30 1.50 CASE P cOMP 15:30 - 19:30 4.00 CASE P COMP 19:30 - 20:30 1.00 CASE P COMP 20:30 - 00:00 3.50 CASE P COMP 2/13/2003 00:00 - 01 :30 1.50 CASE P COMP 01 :30 - 05:00 3.50 CASE P COMP Description of Operations parameters above. Ream to bottom @ 180 FPH from 11,209 to 11,715. Pumping 10 bbl. Hi-Vis sweeps every 45 ft. Hole continues to take fluid at 450-480 BPH. Short trip back to 10,500. Wipe area from 11,130 to 11,190. Work pipe in several sections going back in hole. Did not ream, ran pipe in with no rotation/pumping. M/U topdrive and rotate and reciprocate while pumping 40 bbls. sweep around and up to faulted area. Spot 80 bbls. Hi-Vis pill with 3% lubes by pumping 30 bbls. outside pipe and leaving remaining 50 to fill open hole while pulling pipe. POH with 220K up. Saw 20 to 40K bumps pulling stab up through problem area between 11,130 to 11,190. Worked pipe through with no rotation or pumps. These areas have been dressed several times both reaming and working. Still see drag when stiff collars followed by stab pass. Continue POH to run liner. Hole kept full while POH. POH from 9,000 to BHA. Lay down HWDP, DC, and Hole opener. Clear floor of all vendors excess equipment. PJSM. P/U and R/U casing equipment. RIH to 9674 with 41/212.6# L-80 IBT liner on 4" HT 40 drillpipe. Keeping hole full to prevent inadvertant setting of hanger. Circulate liner volume at 4 BPM @ 220 PSI. 190K up and 148K down RIH with liner from 9,674 to 11,715. Began taking intermittent wt. from 10,900 to 11,165. Hit bridge at 11,420. Screw into topdrive and circulate by. Pump down plug to LlC and stage pumps up to 1,400 PSI and set liner hanger to put shoe at 11710'. Release from liner and set packer. Hole no longer taking fluid. POH and lay down Baker running tool. Inspect and lay down Baker tools. P/U Baker cementing stinger, upper and lower cups, HMCV shifting tool and 2 jts. of 27/8 tubing. RIH with cementing assembly on 4" HT 40 drillpipe. to top of 7" liner at 8385'. RIH with liner from 8395 to 9450 and circ. app. 20 bbls. to confirm string is clear. Space out into 4 1/2 liner with 2 singles and tag up on top of 4 1/2 liner with dog sub. PJSM. Make up cement lines and ready rig for cement/reversing operation. Test "Little Red' hardline to 4,000. Pressure test Halliburton lines to 4,000 and shear open HMCV with 1,500 PSI and pump away 2 bbls. Allow fluid level to drop app. 10 minutes while Halliburton primed up to pump cement. Perform cement job as follows: Pump 50 bbls. water spacer. 220 bbls. of 15.8 cement at 5.3 to 6.3 BPM 15 bbls. water 78 bbls. diesel Caught cement at 43 bbls. away. Built pressure from 415 to 1000 from 43 bbls. to 78 bbls. ,Bleed pressure from 510 to 400 I Printed 2/17/2003 2:2850 PM ) Operati.ons Summary..Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-28 S-28 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 1/17/2003 Rig Release: 2/15/2003 Rig Number: Spud Date: 1/18/2003 End: 2/15/2003 Date From .;;To Hours Task Code NPT Phase Description·of Operations 2/13/2003 01 :30 - 05:00 3.50 CASE P COMP P/U 10ft. and shift HMCV closed Test to 1,500 PSI for 10 minutes. Open bag and fill hole with 25 bbls. Bleed DP pressure to 750 and begin pumping down backside at 4 bpm. while holding 400 PSI on choke. Saw 15 bbls water and app. 3 bbls. cement back during reversing out 100 bbls. 05:00 - 05:30 0.50 CASE P COMP Flush choke and R/D cement equipment. Lay down all excess vendors equipment. Lay down 2 singles and move upper cups above liner top. 05:30 - 07:00 1.50 CASE P COMP Pump 30 bbl. sweep around at 11 BPM, 1560 PSI while POH from 9,512 to 9,450. The 4 1/2 liner top @ 9,502. 07:00 - 15:30 8.50 CASE P COMP POH 1X1. 15:30 - 16:30 1.00 CASE P COMP RIH with 33 stands of excess DP from derrick. 16:30 - 18:30 2.00 CASE P COMP Cut drilling line and service topdrive. Bring casing equipment to rig floor. 18:30 - 20:30 2.00 CASE P COMP POH 1 x1 with 4" drillpipe. 20:30 - 22:30 2.00 CASE P COMP Pull wear ring and dummy run tubing hanger. Change out to long bails. R/U chrome tubing running equipment. 22:30 - 23:00 0.50 CASE P COMP Test casing to 3,500 for 30 minutes. 23:00 - 00:00 1.00 RUNCOIVP COMP PJSM. Pick up tubing jewelry to 60 ft. Bakerlok all connections below packer. 2/14/2003 00:00 - 15:00 15.00 RUNCOIVP COMP RIH with 3 1/2" 13Cr-80, 9.2# production tubing. Torque up with computer tongs to 2,820 using "Jet Lube" pipe dope. 15:00 - 16:00 1.00 RUNCOIVP COMP Space out WLEG inside 4 1/2 liner and P/U tubing hanger. 16:00 - 19:30 3.50 RUNCOIVP COMP Spot corexit down backside @ 3 BPM @ 300 PSI. 19:30 - 20:00 0.50 RUNCOIVP COMP Land tubing hanger in bowl. RILDS and torqe same. Drop rod/ball assembly. (Will be left in well when rig moves off.) 20:00 - 22:30 2.50 RUNCOIVP COMP Pressure up on tubing with 24 strokes @ 3,500 PSI and set packer. Hold test for 30 minutes. Bleed tubing to 2,000 PSI. Pressure up on packer to 3,500 PSI. (Tubing pressure @ 2550) . Hold for 30 minutes. Bleed annulus pressure then tubing pressure to zero. Pressure up annulus to 3,500 to shear OCR valve in upper GLM. Circ. both ways at 3 BPM for 3 bbls. Bleed all pressures to zero. 22:30 - 23:30 1.00 RUNCOIVP COMP Set 2 way check and test from below to 1,000. 23:30 - 00:00 0.50 RUNCOIVP COMP Nipple down BOP's. 2/15/2003 00:00 - 04:30 4.50 WHSUB P COMP Nipple down BOP stack. N/U and test tree/adapter flange to 5,000 for 10 minutes. 04:30 - 05:30 1.00 WHSUB P COMP Pull 2 way check valve with DSM. 05:30 - 10:00 4.50 WHSUB P COMP PJSM. Pressure test lines to Little Red. Pump 160 bbls. 80 degree diesel down annulus. Open tubing to annulus and allow to U-tube into tubing. Well freeze protected to 2200 ft.. 10:00 - 11 :00 1.00 WHSUB P COMP Install BPV with DSM and pressure test from below to 1,000 PSI. 11 :00 - 12:00 1.00 RIGD P COMP Rig down and secure cellar and tree. Printed 2/17/2003 2:28:50 PM '} '> Well: Field: API: Permit: Date 8-28B Prudhoe Bay Unit 50-029-22095-02 203-002 Accept: Spud: Release: Rig: 01/18/03 01/24/03 02/15/03 Nabors 9E8 POST RIG WORK 02123/03 PULL B&R @ 9479' WLM. PULLED 1 1/2" DGLV WI RK LATCH FROM STA #1,2,3 & 4. PULLED RKP FROM STA # 5 @ 3023' WLM. 02124/03 ET LGLV'S IN STA #2, #3, #4, #5. PULLED VALVE FROM RHCM BODY. 02125/03 SET LGLV IN STA #1. PULLED 3.5" RHCM BODY. DRIFTED W 2.5" DUMMY GUN & SB. TAGGED @ 9748' WLM. NOTIFIED PAD OPERATOR. LEFT WELL SHUT IN. 03/08/03 PERFORM BOP TEST. BOP TEST FAILED, REBUILD BLIND SHEAR RAMS. RETEST BOP'S. TEST GOOD. RIH TO MEM GRICCL LOG AND 2.67" OD NOZZLE TO DRIFT. SET DOWN HIGH AT 9755' CTD, UNABLE TO WASH THRU. POOH TO PICK UP MOTOR AND MILL. RIH WITH WEATHERFORD 2 3/8" PDM W/2 3/8"X 3 3/4" UNDERREAMER. 03/09/03 RIH WITH WEATHERFORD 2 3/8" PDM WI 2 3/8"X 3 3/4" UNDERREAMER. UNDERREAMED 4 1/2" LINER FROM 9550' CTMD TO 11600' CTMD. SAW MOTOR WORK FROM 9757' TO +1- 9900' CTMD. OPEN CIRC SUB AND CIRCULATE BOTTOMS UP. LAY IN 35 BBLS FLOPRO FROM 11600' TO 9535'. POOH WI UNDERREAMER. RIH WITH MEM GR/CCL. LOG INTERVAL 10930' TO TD (TAGGED AT 11618'). MADE LOG PASS UP TO SAME. FLAG PIPE AT 10930'. POOH. TIED LOG INTO SLB VISION RESISTIVITY DATED 23-JAN- 03 TO 4-FEB-03 (-2.5' CORR). RIH WI 2.5" HSD 6SPF POWER JET 2506 TCP GUNS. AT FLAG, CORRECT TO TOP SHOT AT 10953'. RIH. PERFORATE 11125' TO 11300',11320' TO 11340', AND 11370' TO 11580'. POOH WI GUNS. 03/10/03 POOH WI PERF GUNS. ALL SHOTS FIRED. RIH WITH 2.67" JSN. LAY IN DIESEL FROM 2200' TO FP TUBING. NOTIFIED PAD OPERATOR AND PCC. RD. NOTIFY DSM THAT PLATFORM IS READY TO MOVE. JOB COMPLETE. SCRLUMBERGER DRILLING & MEASUREMENTS Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Prudhoe Bay Unit - WOA Well. . . . . . . . . . . . . . . . . . . . .: S-28b API number...............: 50-029-22095-02 Engineer. . . . . . . . . . . . . . . . .: E. Roux RIG: . . . . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions. . . . .: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: MEAN SEA LEVEL Depth reference..........: Driller's Pipe Tally GL above permanent.......: 26.70 ft KB above permanent.......: NjA - Top Drive DF above permanent.......: 63.66 ft ----- Vertical section origin---------------- La tit ude ( + N j S -) . . . . . . . . . : 0 . 00 f t Departure (+EjW-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+NjS-).........: N 70.35359433 Departure (+EjW-)........: W 149.03016889 Azimuth from rotary table to target: 271.80 degrees [(c)2003 Drilling & Measurements IDEAL ID6 lC_lO] 5-Feb-2003 09:54:57 Spud date.. ..... .........: Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 5 23-Jan-03 05-Feb-03 96 8553.25 ft 11715.00 ft ~/ ----- Geomagnetic data ---------------------- Magnetic model..... ......: BGGM version 2001 Magnetic date... .........: 31-Dec-2002 Magnetic field strength..: 1150.02 RCNT Magnetic dec (+EjW-).. ...: 25.97 degrees Magnetic dip.... .........: 80.81 degrees ----- MWD survey Reference Reference G..... . . . . . . . . . : Reference R..... . . . . . . . . . : Reference Dip............: Tolerance of G.. . . . . . . . . . : Tolerance of R...........: Tolerance of Dip.. .......: Criteria --------- 1002.68 mGal 1150.02 RCNT 80.82 degrees (+j-) 2.50 mGal (+j-) 6.00 RCNT (+j-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+EjW-).. ...: 25.82 degrees Grid convergence (+EjW-).: 0.00 degrees Total az corr (+EjW-). ...: 25.82 degrees (Total az corr = magnetic dec - grid conv) Sag applied (YjN)........: No degree: 0.00 --~ DRILLING & MEASUREMENTS SCHLUMBERGER Survey Report 5-Feb-2003 09:54:57 Page 2 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ ---~---- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 8553.25 27.73 240.33 0.00 7814.82 2045.20 -1768.89 -2101.80 2747.10 229.92 0.00 TIP 2 8560.00 27.77 240.38 6.75 7820.79..... 2047.88 -1770.44 -2104.53 2750.19 229.93 0.69 TOW -. 3 8576.00 28.77 235.44 16.00 7834.89 2054.17 -1774.47 -2110.94 2757.69 229.95 15.90 BOW 4 8599.96 28.87 233.84 23.96 7855.88 2063.37 -1781.16 -2120.36 2769.20 229.97 3.25 MWD Incl. Only 5 8658.83 28.10 229.83 58.87 7907.63 2084.89 -1798.49 -2142.43 2797.24 229.99 3.50 MWD Incl. Only 6 8685.80 28.15 227.97 26.97 7931.41 2094.20 -1806.84 -2152.01 2809.95 229.98 3.26 MWD IFR MSA 7 8751.41 26.55 221.26 65.61 7989.70 2114.69 -1828.23 -2173.18 2839.92 229.93 5.29 MWD IFR MSA ~' - 8 8845.82 24.32 226.22 94.41 8074.97 2141.71 -1857.55 -2201.14 2880.20 229.84 3.26 MWD IFR MSA - 9 8877.72 24.69 229.75 31.90 8103.99 2151.26 -1866.40 -2210.97 2893.42 229.83 4.73 MWD IFR MSA - 10 8909.78 24.13 234.97 32.06 8133.19 2161.48 -1874.49 -2221.45 2906.64 229.84 6.95 MWD IFR MSA 11 8940.92 24.95 237.54 31.14 8161.52 2172.00 -1881.67 -2232.20 2919.49 229.87 4.32 MWD IFR MSA 12 8970.46 25.62 239.88 29.54 8188.23 2182.57 -1888.22 -2242.98 2931.95 229.91 4.07 MWD IFR MSA - 13 9001.73 26.75 240.33 31.27 8216.29 2194.31 -1895.10 -2254.95 2945.54 229.96 3.67 MWD IFR MSA - 14 9032.21 28.36 240.09 30.48 8243.31 2206.32 -1902.10 -2267.18 2959.41 230.00 5.29 MWD IFR MSA - 15 9063.94 30.11 239.72 31.73 8271.00 2219.48 -1909.87 -2280.59 2974.68 230.06 5.54 MWD IFR MSA 16 9095.85 31.66 239.76 31.91 8298.38 2233.36 -1918.13 -2294.74 2990.82 230.11 4.86 MWD IFR MSA - 17 9126.22 32.75 240.82 30.37 8324.08 2247.16 -1926.15 -2308.80 3006.76 230.16 4.04 MWD IFR MSA - 18 9189.59 34.17 245.03 63.37 8376.95 2277.75 -1942.02 -2339.90 3040.82 230.31 4.29 MWD IFR MSA - 19 9220.55 34.76 247.68 30.96 8402.48 2293.57 -1949.04 -2355.95 3057.65 230.40 5.20 MWD IFR MSA - 20 9251.00 34.90 250.21 30.45 8427.48 2309.59 -1955.29 -2372.17 3074.14 230.50 4.77 MWD IFR MSA 21 9282.85 34.60 252.74 31.85 8453.65 2326.61 -1961.06 -2389.38 3091.10 230.62 4.62 MWD IFR MSA - ~- 22 9311.76 35.27 255.58 28.91 8477.35 2342.38 -1965.57 -2405.31 3106.28 230.74 6.08 MWD IFR MSA - 23 9345.06 36.73 259.30 33.30 8504.29 2361.34 -1969.81 -2424.41 3123.77 230.91 7.89 MWD IFR MSA - 24 9375.39 38.17 262.04 30.33 8528.37 2379.43 -1972.80 -2442.60 3139.78 231.07 7.26 MWD IFR MSA - 25 9406.49 40.03 261.77 31.10 8552.51 2398.75 -1975.56 -2462.02 3156.64 231.26 6.01 MWD IFR MSA 26 9467.89 44.02 265.33 61.40 8598.12 2439.42 -1980.13 -2502.85 3191.42 231.65 7.57 MWD IFR MSA - 27 9499.02 45.73 266.37 31.13 8620.18 2461.26 -1981.71 -2524.75 3209.60 231.87 5.98 MWD IFR MSA - 28 9530.01 47.73 267.43 30.99 8641.42 2483.74 -1982.93 -2547.28 3228.10 232.10 6.92 MWD IFR MSA - 29 9565.19 49.78 268.53 35.18 8664.61 2510.13 -1983.86 -2573.72 3249.57 232.37 6.28 MWD IFR MSA - 30 9592.56 51.45 269.28 27.37 8681.98 2531.26 -1984.26 -2594.87 3266.59 232.60 6.46 MWD IFR MSA DRILLING & MEASUREMENTS SCHLUMBERGER Survey Report 5-Feb-2003 09:54:57 Page 3 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/s- +E/w- displ Azim (degl tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 9623.61 53.78 270.73 31.05 8700.83 2555.92 -1984.25 -2619.53 3286.22 232.86 8.37 MWD IFR MSA - 32 9655.03 55.63 272.07 31.42 8718.98 2581.56 -1983.62 -2645.17 3306.31 233.13 6.84 MWD IFR MSA - 33 9725.38 60.01 275.44 70.35 8756.45 2641.04 -1979.68 -2704.55 3351.68 233.80 7.43 MWD Incl. Only 34 9756.09 62.86 276.81 30.71 8771.13 2667.93 -1976.80 -2731.37 3371.66 234.11 10.07 MWD IFR MSA 35 9786.77 64.19 277.51 30.68 8784.81 2695.27 -1973.38 -2758.61 3391.78 234.42 4.79 MWD IFR MSA 36 9817.74 65.56 279.59 30.97 8797.96 2723.11 -1969.21 -2786.34 3411.96 234.75 7.52 MWD IFR MSA - 37 9850.94 67.61 278.90 33.20 8811.15 2753.32 -1964.31 -2816.41 3433.76 235.11 6.46 MWD IFR MSA ~ - 38 9880.74 70.25 278.84 29.80 8821.86 2780.91 -1960.03 -2843.88 3453.89 235.43 8.86 MWD IFR MSA - 39 9910.66 72.86 278.23 29.92 8831.33 2809.10 -1955.82 -2871.95 3474.66 235.74 8.94 MWD IFR MSA - 40 9942.81 74.72 279.92 32.15 8840.30 2839.72 -1950.94 -2902.43 3497.18 236.09 7.68 MWD IFR MSA 41 9976.97 74.15 284.05 34.16 8849.47 2872.10 -1944.11 -2934.61 3520.16 236.48 11.77 MWD IFR MSA - 42 10005.57 73.51 284.19 28.60 8857.44 2898.94 -1937.41 -2961.25 3538.72 236.81 2.29 MWD IFR MSA - 43 10036.88 73.08 283.00 31.31 8866.44 2928.29 -1930.36 -2990.40 3559.32 237.16 3.89 MWD IFR MSA - 44 10063.76 72.94 284.43 26.88 8874.29 2953.44 -1924.27 -3015.37 3577.05 237.46 5.11 MWD IFR MSA 45 10094.51 71.60 284.06 30.75 8883.66 2982.04 -1917.06 -3043.76 3597.16 237.80 4.51 MWD IFR MSA 46 10126.05 72.86 280.20 31.54 8893.29 3011.58 -1910.76 -3073.12 3618.71 238.13 12.32 MWD IFR MSA - 47 10157.86 75.74 280.27 31.81 8901.89 3041.87 -1905.31 -3103.25 3641.48 238.45 9.06 MWD IFR MSA 48 10189.72 78.80 280.02 31.86 8908.91 3072.62 -1899.84 -3133.84 3664.74 238.77 9.64 MWD IFR MSA - 49 10220.43 81.66 280.14 30.71 8914.12 3102.56 -1894.55 -3163.63 3687.53 239.08 9.32 MWD IFR MSA - 50 10251.71 84.21 279.95 31.28 8917.97 3133.28 -1889.13 -3194.20 3711.02 239.40 8.17 MWD IFR MSA 51 10283.73 87.41 280.85 32.02 8920.31 3164.85 -1883.37 -3225.60 3735.18 239.72 10.38 MWD IFR MSA - 52 10315.08 89.71 281.15 31.35 8921.10 3195.79 -1877.39 -3256.36 3758.79 240.04 7.40 MWD IFR MSA ~ - 53 10348.14 92.66 280.88 33.06 8920.41 3228.41 -1871.07 -3288.80 3783.80 240.36 8.96 MWD IFR MSA - 54 10380.30 94.21 278.98 32.16 8918.49 3260.19 -1865.54 -3320.42 3808.60 240.67 7.62 MWD IFR MSA - 55 10410.19 93.83 275.74 29.89 8916.39 3289.86 -1861.72 -3349.99 3832.55 240.94 10.89 MWD IFR MSA 56 10441.47 92.42 273.90 31.28 8914.69 3321.05 -1859.09 -3381.11 3858.51 241.20 7.40 MWD IFR MSA - 57 10473.38 90.95 270.32 31.91 8913.75 3352.94 -1857.92 -3412.98 3885.91 241.44 12.12 MWD IFR MSA - 58 10504.06 90.60 263.83 30.68 8913.33 3383.49 -1859.49 -3443.60 3913.57 241.63 21.18 MWD IFR MSA - 59 10536.30 90.57 262.57 32.24 8913.00 3415.37 -1863.30 -3475.61 3943.57 241.80 3.91 MWD IFR MSA 60 10566.61 90.26 259.55 30.31 8912.78 3445.14 -1868.01 -3505.55 3972.20 241.95 10.02 MWD IFR MSA DRILLING & MEASUREMENTS SCHLUMBERGER Survey Report 5-Feb-2003 09:54:57 Page 4 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/s- +E/w- displ Azim (degl tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 10596.51 89.99 259.68 29.90 8912.72 3474.37 -1873.40 -3534.96 4000.69 242.08 1.00 MWD IFR MSA - 62 10627.21 90.09 257.45 30.70 8912.70 3504.25 -1879.49 -3565.05 4030.14 242.20 7.27 MWD IFR MSA - 63 10658.61 89.57 258.58 31.40 8912.79 3534.75 -1886.01 -3595.76 4060.36 242.32 3.96 MWD IFR MSA - 64 10689.04 87.10 259.82 30.43 8913.67 3564.43 -1891.71 -3625.64 4089.47 242.45 9.08 MWD IFR MSA - 65 10720.81 86.24 262.27 31.77 8915.52 3595.59 -1896.64 -3656.96 4119.54 242.59 8.16 MWD IFR MSA 66 10751.91 86.72 264.73 31.10 8917.43 3626.30 -1900.16 -3687.80 4148.55 242.74 8.04 MWD IFR MSA - 67 10783.13 86.80 267.75 31.22 8919.19 3657.32 -1902.20 -3718.90 4177.15 242.91 9.66 MWD IFR MSA ~ - 68 10813.90 86.04 267.26 30.77 8921.12 3687.94 -1903.54 -3749.58 4205.10 243.08 2.94 MWD IFR MSA - 69 10846.14 86.90 270.99 32.24 8923.10 3720.08 -1904.03 -3781.75 4234.02 243.28 11.85 MWD IFR MSA - 70 10877.31 87.03 269.69 31.17 8924.75 3751.20 -1903.84 -3812.88 4261.77 243.47 4.19 MWD IFR MSA 71 10907.39 87.62 272.38 30.08 8926.16 3781.24 -1903.30 -3842.92 4288.42 243.65 9.15 MWD IFR MSA 72 10940.17 88.75 269.01 32.78 8927.19 3813.99 -1902.90 -3875.67 4317.62 243.85 10.84 MWD IFR MSA - 73 10970.16 89.92 268.39 29.99 8927.54 3843.93 -1903.58 -3905.65 4344.85 244.02 4.42 MWD IFR MSA - 74 11001.97 90.23 267.58 31.81 8927.50 3875.67 -1904.70 -3937.44 4373.94 244.19 2.73 MWD IFR MSA - 75 11032.34 90.53 267.38 30.37 8927.30 3905.95 -1906.04 -3967.78 4401.85 244.34 1.21 MWD IFR MSA 76 11063.60 91.05 269.94 31.26 8926.87 3937.16 -1906.77 -3999.03 4430.35 244.51 8.39 MWD IFR MSA - 77 11094.14 91.05 269.47 30.54 8926.31 3967.68 -1906.93 -4029.56 4458.00 244.67 1.54 MWD IFR MSA - 78 11126.66 91.60 267.70 32.52 8925.56 4000.14 -1907.73 -4062.06 4487.74 244.84 5.70 MWD IFR MSA - 79 11155.11 91.94 268.18 28.45 8924.68 4028.51 -1908.76 -4090.48 4513.91 244.98 2.07 MWD IFR MSA - 80 11188.29 92.08 270.72 33.18 8923.51 4061.64 -1909.07 -4123.63 4544.11 245.16 7.66 MWD IFR MSA 81 11218.49 90.33 271.70 30.20 8922.88 4091.83 -1908.44 -4153.82 4571.25 245.32 6.64 MWD IFR MSA - 82 11248.89 89.78 268.40 30.40 8922.85 4122.21 -1908.41 -4184.21 4598.88 245.48 11.01 MWD IFR MSA - 83 11280.39 90.36 270.25 31.50 8922.81 4153.68 -1908.78 -4215.71 4627.71 245.64 6.15 MWD IFR MSA - 84 11312.20 90.77 268.21 31.81 8922.50 4185.45 -1909.21 -4247.51 4656.87 245.80 6.54 MWD IFR MSA - 85 11342.84 91.36 269.17 30.64 8921.93 4216.04 -1909.91 -4278.14 4685.11 245.94 3.68 MWD IFR MSA 86 11373.54 92.83 271.77 30.70 8920.81 4246.71 -1909.66 -4308.82 4713.03 246.10 9.72 MWD IFR MSA - 87 11404.92 93.11 269.35 31.38 8919.18 4278.04 -1909.35 -4340.15 4741.57 246.25 7.75 MWD IFR MSA - 88 11434.65 93.86 271.44 29.73 8917.37 4307.70 -1909.15 -4369.82 4768.67 246.40 7.46 MWD IFR MSA - 89 11466.09 94.07 268.94 31.44 8915.20 4339.05 -1909.04 -4401.18 4797.38 246.55 7.96 MWD IFR MSA - 90 11497.46 92.70 267.73 31.37 8913.35 4370.31 -1909.95 -4432.48 4826.47 246.69 5.82 MWD IFR MSA DRILLING & MEASUREMENTS SCHLUMBERGER Survey Report 5-Feb-2003 09:54:57 Page 5 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) ( deg ) (ft) (ft) (ft) ( ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 11527.92 89.23 267.10 30.46 8912.83 4400.67 -1911.33 -4462.90 4854.97 246.82 11.58 MWD IFR MSA 92 11559.46 86.97 265.31 31.54 8913.88 4432.04 -1913.41 -4494.35 4884.71 246.94 9.14 MWD IFR MSA - 93 11590.85 87.24 265.95 31.39 8915.46 4463.21 -1915.80 -4525.61 4914.41 247.06 2.21 MWD IFR MSA - 94 11622.24 87.34 266.26 31.39 8916.95 4494.41 -1917.93 -4556.90 4944.06 247.17 1.04 MWD IFR MSA - 95 11653.41 87.34 266.44 31.17 8918.39 4525.40 -1919.91 -4587.97 4973.48 247.29 0.58 MWD IFR MSA 96 11715.00 87.34 266.44 61.59 8921.25 4586.66 -1923.73 -4649.37 5031.64 247.52 0.00 Projected to TD -' [(c)2003 Drilling & Measurements IDEAL ID6 1C_10J bp 5-288 Sehlulberger Survey Report - Geodetic Report Date: 5-Feb-03 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: 8P Exploration Alaska Vertical Section Azimuth: 271.800° Field: Prudhoe 8ay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: 8-P AD / 8-28 TVD Reference Datum: K8 Well: 8-28 TVD Reference Elevation: 63.660 ft relative to M8L Borehole: 8-288 UWIIAPI#: 500292209502 Magnetic Declination: +25.801° Survey Name I Date: 8-288/ February 5, 2003 Total Field Strength: 57525.118 nT Tort I AHD I DOlI ERD ratio: 271.124° /5386.11 ft / 6.282/ 0.603 Magnetic Dip: 80.820° Grid Coordinate System: NAD27 Alaska 8tate Planes, Zone 4, U8 Feet Declination Date: February 11, 2003 -- Location LatlLong: N 70.35359433, W 149.0301688S Magnetic Declination Model: 8GGM 2002 Location Grid NIE YIX: N 5979855.270 ftU8, E 619432.000 ftUS North Reference: True North Grid Convergence Angle: +0.91338271° Total Corr Mag North -> True North: +25.801 ° Grid Scale Factor: 0.99991620 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) C/100ft) (ftUS) (ftUS) 10036.88 73.08 282.04 8866.30 2929.37 -1935.70 -2991.65 5977872.30 616471.84 N 70.34830456 W 149.05445250 10063.76 72.94 284.43 8874.16 2954.56 -1929.81 -3016.67 8.52 5977877.79 616446.73 N 70.34832061 W 149.05465563 10094.51 71.60 284.06 8883.52 2983.16 -1922.60 -3045.06 4.51 5977884.54 616418.24 N 70.34834027 W 149.05488608 10126.05 72.86 280.20 8893.15 3012.71 -1916.30 -3074.42 12.32 5977890.38 616388.78 N 70.34835746 W 149.05512441 10157.86 75.74 280.27 8901.76 3043.00 -1910.86 -3104.55 9.06 5977895.34 616358.57 N 70.34837229 W 149.05536902 10189.72 78.80 280.02 8908.78 3073.74 -1905.38 -3135.14 9.64 5977900.32 616327.90 N 70.34838721 W 149.05561732 10220.43 81.66 280.14 8913.99 3103.69 -1900.09 -3164.93 9.32 5977905.14 616298.03 N 70.34840164 W 149.05585918 10251.71 84.21 279.95 8917.84 3134.40 -1894.67 -3195.49 8.17 5977910.07 616267.39 N 70.34841640 W 149.05610730 10283.73 87.41 280.85 8920.18 3165.98 -1888.91 -3226.90 10.38 5977915.33 616235.90 N 70.34843211 W 149.05636225 10315.08 89.71 281.15 8920.96 3196.91 -1882.93 -3257.66 7.40 5977920.82 616205.04 N 70.34844841 W 149.05661197 -~/ 10348.14 92.66 280.88 8920.28 3229.53 -1876.61 -3290.10 8.96 5977926.61 616172.51 N 70.34846562 W 149.05687531 10380.30 94.21 278.98 8918.35 3261.31 -1871.08 -3321.72 7.62 5977931.64 616140.81 N 70.34848071 W 149.05713199 10410.19 93.83 275.74 8916.26 3290.98 -1867.26 -3351 .29 10.89 5977934.99 616111.19 N 70.34849110 W 149.05737201 10441.47 92.42 273.90 8914.55 3322.17 -1864.64 -3382.41 7.40 5977937.12 616080.03 N 70.34849823 W 149.05762463 10473.38 90.95 270.32 8913.61 3354.06 -1863.46 -3414.28 12.12 5977937.78 616048.15 N 70.34850140 W 149.05788332 10504.06 90.60 263.83 8913.20 3384.62 -1865.03 -3444.90 21.18 5977935.73 616017.56 N 70.34849709 W 149.05813186 10536.30 90.57 262.57 8912.87 3416.49 -1868.84 -3476.91 3.91 5977931 .40 615985.62 N 70.34848662 W 149.05839169 10566.61 90.26 259.55 8912.65 3446.27 -1873.55 -3506.85 10.02 5977926.22 615955.76 N 70.34847371 W 149.05863469 S-288 ASP Final Survey.xls Page 1 of 3 2/11/2003-12:17 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EJ-W DLS Northing Easting Latitude Longitude (ft) (0) (0) (ft) (ft) (ft) (ft) (°/1 o Oft) (ftUS) (ftUS) 10596.51 89.99 259.68 8912.58 3475.49 -1878.94 -3536.26 1.00 5977920.36 615926.45 N 70.34845895 W 149.05887339 10627.21 90.09 257.45 8912.56 3505.38 -1885.03 -3566.34 7.27 5977913.80 615896.46 N 70.34844229 W 149.05911760 10658.61 89.57 258.58 8912.66 3535.87 -1891.55 -3597.06 3.96 5977906.79 615865.86 N 70.34842443 W 149.05936690 10689.04 87.10 259.82 8913.54 3565.55 -1897.25 -3626.94 9.08 5977900.61 615836.08 N 70.34840882 W 149.05960938 10720.81 86.24 262.27 8915.39 3596.71 -1902.19 -3658.26 8.16 5977895.18 615804.84 N 70.34839530 W 149.05986364 10751.91 86.72 264.73 8917.30 3627.42 -1905.70 -3689.10 8.04 5977891.17 615774.06 N 70.34838566 W 149.06011396 10783.13 86.80 267.75 8919.06 3658.44 -1907.74 -3720.20 9.66 5977888.64 615743.00 N 70.34838003 W 149.06036639 10813.90 86.04 267.26 8920.98 3689.07 -1909.08 -3750.88 2.94 5977886.81 615712.35 N 70.34837634 W 149.06061543 10846.14 86.90 270.99 8922.97 3721.20 -1909.57 -3783.05 11.85 5977885.81 615680.19 N 70.34837495 W 149.06087654 10877.31 87.03 269.69 8924.62 3752.32 -1909.39 -3814.18 4.19 5977885.49 615649.07 N 70.34837541 W 149.06112919 ~ 10907.39 87.62 272.38 8926.02 3782.36 -1908.84 -3844.21 9.15 5977885.56 615619.03 N 70.34837685 W 149.06137303 10940.17 88.75 269.01 8927.06 3815.11 -1908.45 -3876.97 10.84 5977885.43 615586.27 N 70.34837789 W 149.06163892 10970.16 89.92 268.39 8927.41 3845.06 -1909.13 -3906.95 4.42 5977884.28 615556.31 N 70.34837599 W 149.06188227 11001.97 90.23 267.58 8927.37 3876.79 -1910.24 -3938.74 2.73 5977882.65 615524.55 N 70.34837289 W 149.06214030 11032.34 90.53 267.38 8927.17 3907.08 -1911.58 -3969.08 1.19 5977880.83 615494.23 N 70.34836920 W 149.06238657 11063.60 91.05 269.94 8926.74 3938.29 -1912.31 -4000.33 8.36 5977879.60 615463.01 N 70.34836716 W 149.06264019 11094.14 91.05 269.47 8926.18 3968.80 -1912.47 -4030.86 1.54 5977878.96 615432.48 N 70.34836668 W 149.06288805 11126.66 91.60 267.70 8925.42 4001.26 -1913.27 -4063.36 5.70 5977877.64 615400.00 N 70.34836444 W 149.06315185 11155.11 91.94 268.18 8924.54 4029.63 -1914.29 -4091.78 2.07 5977876.16 615371.60 N 70.34836161 W 149.06338252 11188.29 92.08 270.72 8923.38 4062.76 -1914.61 -4124.93 7.66 5977875.32 615338.46 N70.34836069 W 149.06365165 11218.49 90.33 271.70 8922.75 4092.95 -1913.97 -4155.12 6.64 5977875.47 615308.27 N 70.34836238 W 149.06389667 11248.89 89.78 268.40 8922.72 4123.33 -1913.95 -4185.51 11.01 5977875.02 615277.88 N 70.34836241 W 149.06414339 11280.39 90.36 270.25 8922.68 4154.80 -1914.32 -4217.01 6.15 5977874.14 615246.40 N 70.34836135 W 149.06439905 11312.20 90.77 268.21 8922.36 4186.58 -1914.75 -4248.81 6.54 5977873.21 615214.61 N 70.34836013 W 149.06465721 11342.84 91.36 269.17 8921.79 4217.16 -1915.45 -4279.44 3.68 5977872.02 615184.00 N 70.34835817 W 149.06490580 11373.54 92.83 271.77 8920.67 4247.83 -1915.19 -4310.12 9.72 5977871.78 615153.33 N 70.34835881 W 149.06515480 ~' 11404.92 93.11 269.35 8919.05 4279.16 -1914.89 -4341 .45 7.75 5977871.59 615122.00 N 70.34835960 W 149.06540914 11434.65 93.86 271.44 8917.24 4308.82 -1914.68 -4371.12 7.46 5977871.32 615092.33 N 70.34836011 W 149.06565000 11466.09 94.07 268.94 8915.06 4340.17 -1914.58 -4402.48 7.96 5977870.92 615060.97 N 70.34836034 W 149.06590457 11497.46 92.70 267.73 8913.21 4371.43 -1915.49 -4433.78 5.82 5977869.52 615029.69 N 70.34835780 W 149.06615864 11527.92 89.23 267.10 8912.70 4401.79 -1916.86 -4464.20 11.58 5977867.66 614999.30 N 70.34835400 W 149.06640556 11559.46 86.97 265.31 8913.74 4433.16 -1918.95 -4495.66 9.14 5977865.07 614967.89 N 70.34834825 W 149.06666083 11590.85 87.24 265.95 8915.33 4464.33 -1921.34 -4526.91 2.21 5977862.18 614936.68 N 70.34834168 W 149.06691455 11622.24 87.34 266.26 8916.81 4495.53 -1923.47 -4558.20 1.04 5977859.56 614905.43 N 70.34833581 W 149.06716847 11653.41 87.34 266.44 8918.26 4526.53 -1925.45 -4589.27 0.58 5977857.08 614874.40 N 70.34833034 W 149.06742068 S-288 ASP Final Survey.xls Page 2 of 3 2/11/2003-12:17 PM Station ID MD (ft) 11715.00 S-288 ASP Final Survey.xls Incl (0) 87.34 Azim (0) 266.44 TVD (ft) 8921.12 VSec (ft) 4587.78 N/-S (ft) -1929.27 Page 3 of 3 EI-W (ft) -4650.67 DLS (°/1 o Oft) 0.00 Geographic Coordinates Latitude Longitude Grid Coordinates Northing Easting (ftUS) (ftUS) 5977852.28 614813.07 N 70.34831980 W 149.06791910 ~ .--' 2/11/2003-12:17 PM SCRLUMBERGER Drilling & Measurements Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Prudhoe Bay Unit - WOA Well. . . . . . . . . . . . . . . . . . . . .: S-28b PB1 API number...............: 50-029-22095-70 Engineer.................: E. Roux RIG: . . . . . . . . . . . . . . . . . . . . .: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions. . . . .: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: MEAN SEA LEVEL Depth reference..........: Driller's Pipe Tally GL above permanent.......: 26.70 ft KB above permanent.......: N/A - Top Drive DF above permanent.......: 63.66 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- La tit ude ( + N / S -) . . . . . . . . . : N 70. 35359433 Departure (+E/W-)........: W 149.03016889 Azimuth from rotary table to target: 271.80 degrees [(c)2003 Drilling & Measurements IDEAL ID6_1C_10] 5-Feb-2003 13:58:32 Spud date. . . . . . . . . . . . . . . . : Last survey date.... .....: Total accepted surveys. . . : MD of first survey. ......: MD of last survey........: Page 1 of 3 23-Jan-03 05-Feb-03 58 8553.25 ft 10522.00 ft '-" ----- Geomagnetic data ---------------------- Magnetic model. .... ......: BGGM version 2000 Magnetic date... ... ......: 31-Dec-2002 Magnetic field strength..: 1150.02 RCNT Magnetic dec (+E/W-) .....: 25.97 degrees Magnetic dip.............: 80.81 degrees ----- MWD survey Reference Reference G..............: Reference H... ...........: Reference Dip............: Tolerance of G...........: Tolerance of R..... ......: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1150.02 RCNT 80.82 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.82 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.82 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)........: No degree: 0.00 Drilling & Measurements SCHLUMBERGER Survey Report 5-Feb-2003 13:58:32 Page 2 of 3 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 8553.25 27.73 240.33 0.00 7814.82 2045.20 -1768.89 -2101.80 2747.10 229.92 0.00 TIP 2 8560.00 27.77 240.38 6.75 7820.79 2047.88 -1770.44 -2104.53 2750.19 229.93 0.69 TOW 3 8576.00 28.77 235.44 16.00 7834.89 2054.17 -1774.47 -2110.94 2757.69 229.95 15.90 BOW 4 8599.96 28.87 233.84 23.96 7855.88 2063.37 -1781.16 -2120.36 2769.20 229.97 3.25 MWD Incl. Only 5 8658.83 28.10 229.83 58.87 7907.63 2084.89 -1798.49 -2142.43 2797.24 229.99 3.50 MWD Incl. Only 6 8685.80 28.15 227.97 26.97 7931.41 2094.20 -1806.84 -2152.01 2809.95 229.98 3.26 MWD IFR MSA 7 8751.41 26.55 221.26 65.61 7989.70 2114.69 -1828.23 -2173.18 2839.92 229.93 5.29 MWD IFR MSA .~ - 8 8845.82 24.32 226.22 94.41 8074.97 2141.71 -1857.55 -2201.14 2880.20 229.84 3.26 MWD IFR MSA - 9 8877.72 24.69 229.75 31.90 8103.99 2151.26 -1866.40 -2210.97 2893.42 229.83 4.73 MWD IFR MSA - 10 8909.78 24.13 234.97 32.06 8133.19 2161.48 -1874.49 -2221.45 2906.64 229.84 6.95 MWD IFR MSA 11 8940.92 24.95 237.54 31.14 8161.52 2172.00 -1881.67 -2232.20 2919.49 229.87 4.32 MWD IFR MSA - 12 8970.46 25.62 239.88 29.54 8188.23 2182.57 -1888.22 -2242.98 2931.95 229.91 4.07 MWD IFR MSA - 13 9001.73 26.75 240.33 31.27 8216.29 2194.31 -1895.10 -2254.95 2945.54 229.96 3.67 MWD IFR MSA - 14 9032.21 28.36 240.09 30.48 8243.31 2206.32 -1902.10 -2267.18 2959.41 230.00 5.29 MWD IFR MSA - 15 9063.94 30.11 239.72 31.73 8271.00 2219.48 -1909.87 -2280.59 2974.68 230.06 5.54 MWD IFR MSA 16 9095.85 31.66 239.76 31.91 8298.38 2233.36 -1918.13 -2294.74 2990.82 230.11 4.86 MWD IFR MSA - 17 9126.22 32.75 240.82 30.37 8324.08 2247.16 -1926.15 -2308.80 3006.76 230.16 4.04 MWD IFR MSA - 18 9189.59 34.17 245.03 63.37 8376.95 2277.75 -1942.02 -2339.90 3040.82 230.31 4.29 MWD IFR MSA 19 9220.55 34.76 247.68 30.96 8402.48 2293.57 -1949.04 -2355.95 3057.65 230.40 5.20 MWD IFR MSA - 20 9251.00 34.90 250.21 30.45 8427.48 2309.59 -1955.29 -2372.17 3074.14 230.50 4.77 MWD IFR MSA 21 9282.85 34.60 252.74 31.85 8453.65 2326.61 -1961.06 -2389.38 3091.10 230.62 4.62 MWD IFR MSA - .' 22 9311.76 35.27 255.58 28.91 8477.35 2342.38 -1965.57 -2405.31 3106.28 230.74 6.08 MWD IFR MSA -- - 23 9345.06 36.73 259.30 33.30 8504.29 2361.34 -1969.81 -2424.41 3123.77 230.91 7.89 MWD IFR MSA - 24 9375.39 38.17 262.04 30.33 8528.37 2379.43 -1972.80 -2442.60 3139.78 231.07 7.26 MWD IFR MSA - 25 9406.49 40.03 261.77 31.10 8552.51 2398.75 -1975.56 -2462.02 3156.64 231.26 6.01 MWD IFR MSA 26 9467.89 44.02 265.33 61.40 8598.12 2439.42 -1980.13 -2502.85 3191.42 231.65 7.57 MWD IFR MSA - 27 9499.02 45.73 266.37 31.13 8620.18 2461.26 -1981.71 -2524.75 3209.60 231.87 5.98 MWD IFR MSA - 28 9530.01 47.73 267.43 30.99 8641.42 2483.74 -1982.93 -2547.28 3228.10 232.10 6.92 MWD IFR MSA - 29 9565.19 49.78 268.53 35.18 8664.61 2510.13 -1983.86 -2573.72 3249.57 232.37 6.28 MWD IFR MSA - 30 9592.56 51.45 269.28 27.37 8681.98 2531.26 -1984.26 -2594.87 3266.59 232.60 6.46 MWD IFR MSA Drilling & Measurements SCHLUMBERGER Survey Report 5-Feb-2003 13:58:32 Page 3 of 3 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 9623.61 53.78 270.73 31.05 8700.83 2555.92 -1984.25 -2619.53 3286.22 232.86 8.37 MWD IFR MSA - 32 9655.03 55.63 272.07 31.42 8718.98 2581.56 -1983.62 -2645.17 3306.31 233.13 6.84 MWD IFR MSA - 33 9725.38 60.01 274.00 70.35 8756.44 2641.07 -1980.45 -2704.61 3352.17 233.79 6.64 MWD Incl. Only 34 9756.09 62.86 276.12 30.71 8771.13 2667.99 -1978.06 -2731.47 3372.48 234.09 11.08 MWD IFR MSA 35 9786.77 64.19 276.75 30.68 8784.80 2695.36 -1974.98 -2758.76 3392.83 234.40 4.71 MWD IFR MSA 36 9817.74 65.56 278.78 30.97 8797.95 2723.25 -1971.19 -2786.54 3413.27 234.72 7.40 MWD IFR MSA 37 9850.94 67.61 278.15 33.20 8811.15 2753.51 -1966.71 -2816.67 3435.34 235.08 6.42 MWD IFR MSA - - 38 9880.74 70.25 277.98 29.80 8821.86 2781.15 -1962.81 -2844.20 3455.73 235.39 8.88 MWD IFR MSA - 39 9910.66 72.86 277.45 29.92 8831.32 2809.37 -1959.00 -2872.32 3476.77 235.71 8.88 MWD IFR MSA - 40 9942.81 74.72 279.11 32.15 8840.30 2840.05 -1954.55 -2902.87 3499.56 236.05 7.62 MWD IFR MSA 41 9976.97 74.15 283.08 34.16 8849.47 2872.51 -1948.22 -2935.16 3522.88 236.43 11.32 MWD IFR MSA - 42 10005.57 73.50 283.21 28.60 8857.43 2899.45 -1941.98 -2961.90 3541.77 236.75 2.31 MWD IFR MSA - 43 10036.88 73.08 282.04 31.31 8866.44 2928.90 -1935.42 -2991.17 3562.71 237.10 3.82 MWD IFR MSA - 44 10067.54 73.00 282.28 30.66 8875.38 2957.75 -1929.24 -3019.83 3583.49 237.43 0.79 MWD IFR MSA - 45 10097.62 75.22 282.68 30.08 8883.62 2986.18 -1922.99 -3048.08 3603.98 237.75 7.49 MWD IFR MSA 46 10129.24 77.55 281.21 31.62 8891.06 3016.42 -1916.63 -3078.14 3626.08 238.09 8.64 MWD IFR MSA - 47 10160.32 80.30 283.22 31.08 8897.03 3046.42 -1910.18 -3107.95 3648.03 238.42 10.89 MWD IFR MSA - 48 10192.10 83.18 283.99 31.78 8901.60 3077.20 -1902.78 -3138.51 3670.26 238.77 9.37 MWD IFR MSA - 49 10221.40 85.46 283.43 29.30 8904.50 3105.72 -1895.87 -3166.84 3690.96 239.09 8.01 MWD IFR MSA - 50 10252.61 88.65 285.43 31.21 8906.10 3136.13 -1888.10 -3197.02 3712.93 239.43 12.06 MWD IFR MSA 51 10284.27 91.56 288.15 31.66 8906.04 3166.71 -1878.96 -3227.32 3734.45 239.79 12.58 MWD IFR MSA - 52 10315.54 91.46 294.66 31.27 8905.22 3196.14 -1867.56 -3256.41 3753.93 240.17 20.81 MWD IFR MSA .~ - 53 10347.29 90.64 297.14 31.75 8904.63 3225.12 -1853.69 -3284.96 3771.89 240.56 8.23 MWD IFR MSA - 54 10378.72 91.15 297.74 31.43 8904.14 3253.45 -1839.21 -3312.85 3789.15 240.96 2.51 MWD IFR MSA - 55 10409.87 90.64 295.26 31.15 8903.66 3281.74 -1825.32 -3340.72 3806.86 241.35 8.13 MWD IFR MSA 56 10439.76 90.40 292.95 29.89 8903.38 3309.39 -1813.11 -3368.00 3825.03 241.70 7.77 MWD IFR MSA - 57 10471.78 89.57 290.16 32.02 8903.39 3339.53 -1801.35 -3397.78 3845.75 242.07 9.09 MWD IFR MSA 58 10522.00 89.57 290.16 50.22 8903.77 3387.19 -1784.04 -3444.92 3879.47 242.62 0.00 Projected to TD [(c)2003 Drilling & Measurements IDEAL ID6 1C_10J bp S-28BPB1 Schlumbepger Survey Report - Geodetic Report Date: 5-Feb-03 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA (Drill Pads) Structure / Slot: S-PAD / S-28 Well: S-28 Borehole: S-28BPB1 UWIIAPI#: 500292209570 Survey Name / Date: S-28BPB 1 / February 5, 2003 Tort / AHD / DDI / ERD ratio: 192.594° / 4196.64 ft / 5.980 I 0.471 Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Location LatlLong: N 70.35359433, W 149.03016888 Location Grid NIE YIX: N 5979855.270 ftUS, E 619432.000 ftUS Grid Convergence Angle: +0.91338271 ° Grid Scale Factor: 0.99991620 Station ID MD Incl (ft) n 8552.05 27.73 8560.00 27.77 8576.00 28.77 8599.96 28.87 8658.83 28.10 8685.80 28.15 8751.41 26.55 8845.82 24.32 8877.72 24.69 8909.78 24.13 8940.92 24.95 8970.46 25.62 9001.73 26.75 9032.21 28.36 9063.94 30.11 9095.85 31.66 9126.22 32.75 9189.59 34.17 S-28BPB1 ASP Final Survey.xls Azim (0) 240.33 240.38 235.44 233.84 229.83 TVD (ft) 7813.63 7820.66 7834.75 7855.75 7907.49 Survey / DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 271.800° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: KB TVD Reference Elevation: 63.660 ft relative to MSL Magnetic Declination: +25.810° Total Field Strength: 57524.736 nT Magnetic Dip: 80.819° Declination Date: February 02, 2003 Magnetic Declination Model: BGGM 2002 North Reference: True North Total Corr Mag North -> True North: +25.810° Local Coordinates Referenced To: Well Head -' Grid Coordinates Geographic Coordinates VSec N/-5 EJ-W DLS Northing Easting Latitude Longitude (ft) (ft) (ft) (°/1 o Oft) (ftUS) (ftUS) 2045.20 -1768.89 -2101.80 5978053.26 617358.85 N 70.34876109 W 149.04722983 2048.35 -1770.72 -2105.01 0.58 5978051.37 617355.66 N 70.34875608 W 149.04725594 2054.64 -1774.75 -2111.42 15.90 5978047.25 617349.31 N 70.34874508 W 149.04730798 2063.84 -1781.43 -2120.84 3.25 5978040.41 617340.00 N 70.34872681 W 149.04738442 2085.36 -1798.76 -2142.91 3.50 5978022.74 617318.21 N 70.34867945 W 149.04756353 227.97 7931.28 2094.67 -1807.12 -2152.49 3.26 5978014.23 617308.77 N 70.34865661 W 149.04764127 221.26 7989.57 2115.16 -1828.51 -2173.67 5.29 5977992.50 617287.94 N 70.34859815 W 149.04781309 226.22 8074.83 2142.18 -1857.83 -2201.62 3.26 5977962.74 617260.46 N 70.34851803 W 149.04803996 229.75 8103.86 2151.73 -1866.68 -2211.45 4.73 5977953.74 617250.77 N 70.34849385 W 149.04811971~, 234.97 8133.06 2161.95 -1874.77 -2221.93 6.95 5977945.49 617240.43 N 70.34847174 W 149.04820474 237.54 8161.39 2172.47 -1881.95 -2232.68 4.32 5977938.14 617229.79 N 70.34845212 W 149.04829202 239.88 8188.10 2183.04 -1888.49 -2243.47 4.07 5977931 .42 617219.11 N 70.34843422 W 149.04837952 240.33 8216.16 2194.78 -1895.37 -2255.43 3.67 5977924.35 617207.26 N 70.34841543 W 149.04847661 240.09 8243.18 2206.79 -1902.38 -2267.66 5.29 5977917.15 617195.14 N 70.34839628 W 149.04857591 239.72 8270.87 2219.95 -1910.15 -2281 .07 5.54 5977909.17 617181.86 N 70.34837503 W 149.04868472 239.76 8298.25 2233.83 -1918.40 -2295.22 4.86 5977900.69 617167.85 N 70.34835247 W 149.04879953 240.82 8323.95 2247.63 -1926.42 -2309.28 4.04 5977892.45 617153.92 N 70.34833055 W 149.04891363 245.03 8376.82 2278.22 -1942.29 -2340.38 4.29 5977876.08 617123.08 N 70.34828717 W 149.04916606 Page 1 of 3 2/11/2003-12:17 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) (0) (") (ft) (ft) (ft) (ft) (o/100ft) (ftUS) (ftUS) 9220.55 34.76 247.68 8402.35 2294.04 -1949.32 -2356.43 5.20 5977868.81 617107.14 N 70.34826797 W 149.04929630 9251.00 34.90 250.21 8427.34 2310.06 -1955.56 -2372.66 4.77 5977862.30 617091.02 N 70.34825089 W 149.04942801 9282.85 34.60 252.74 8453.51 2327.08 -1961.33 -2389.86 4.62 5977856.26 617073.91 N 70.34823512 W 149.04956769 9311.76 35.27 255.58 8477.22 2342.85 -1965.85 -2405.79 6.08 5977851.50 617058.06 N 70.34822277 W 149.04969693 9345.06 36.73 259.30 8504.16 2361.81 -1970.09 -2424.89 7.89 5977846.95 617039.03 N 70.34821116 W 149.04985194 9375.39 38.17 262.04 8528.24 2379.90 -1973.07 -2443.08 7.26 5977843.68 617020.89 N 70.34820300 W 149.04999963 9406.49 40.03 261.77 8552.37 2399.22 -1975.83 -2462.50 6.01 5977840.61 617001.52 N 70.34819543 W 149.05015724 9467.89 44.02 265.33 8597.98 2439.89 -1980.40 -2503.33 7.57 5977835.39 616960.77 N 70.34818292 W 149.05048863 9499.02 45.73 266.37 8620.04 2461.73 -1981.99 -2525.23 5.98 5977833.45 616938.90 N 70.34817857 W 149.05066643 9530.01 47.73 267.43 8641.28 2484.21 -1983.20 -2547.76 6.92 5977831.88 616916.39 N 70.34817522 W 149.05084931 ~ 9565.19 49.78 268.53 8664.47 2510.61 -1984.13 -2574.20 6.28 5977830.53 616889.98 N 70.34817266 W 149.05106387 9592.56 51 .45 269.28 8681.84 2531. 73 -1984.53 -2595.35 6.46 5977829.79 616868.84 N 70.34817154 W 149.05123554 9623.61 53.78 270.73 8700.69 2556.39 -1984.53 -2620.02 8.37 5977829.40 616844.17 N 70.34817154 W 149.05143578 9655.03 55.63 272.07 8718.85 2582.03 -1983.90 -2645.65 6.84 5977829.62 616818.53 N 70.34817323 W 149.05164386 9725.38 60.01 274.00 8756.31 2641.54 -1980.72 -2705.09 6.64 5977831.85 616759.06 N 70.34818185 W 149.05212634 9756.09 62.86 276.12 8770.99 2668.46 -1978.34 -2731.95 11.08 5977833.81 616732.16 N 70.34818834 W 149.05234438 9786.77 64.19 276.75 8784.67 2695.83 -1975.26 -2759.24 4.71 5977836.45 616704.83 N 70.34819672 W 149.05256589 9817.74 65.56 278.78 8797.82 2723.72 -1971.47 -2787.02 7.40 5977839.80 616677.00 N 70.34820705 W 149.05279140 9850.94 67.61 278.15 8811.01 2753.98 -1966.98 -2817.15 6.42 5977843.80 616646.80 N 70.34821927 W 149.05303600 9880.74 70.25 277.98 8821.72 2781.62 -1963.08 ':2844.68 8.88 5977847.26 616619.21 N 70.34822989 W 149.05325948 9910.66 72.86 277.45 8831.19 2809.85 -1959.27 -2872.81 8.88 5977850.62 616591.04 N 70.34824027 W 149.05348777 9942.81 74.72 279.11 8840.16 2840.52 -1954.83 -2903.35 7.62 5977854.58 616560.42 N 70.34825239 W 149.05373574 9976.97 74.15 283.08 8849.33 2872.99 -1948.50 -2935.64 11.32 5977860.40 616528.05 N 70.34826965 W 149.05399782 10005.57 73.50 283.21 8857.30 2899.92 -1942.25 -2962.39 2.31 5977866.21 616501.20 N 70.34828668 W 149.05421496 10036.88 73.08 282.04 8866.30 2929.37 -1935.70 -2991.65 3.82 5977872.30 616471.84 N 70.34830456 W 149.05445250 10067.54 73.00 282.28 8875.25 2958.22 -1929.52 -3020.32 0.79 5977878.02 616443.08 N 70.34832140 W 149.05468523 ,--' 10097.62 75.22 282.68 8883.48 2986.65 -1923.27 -3048.56 7.49 5977883.82 616414.74 N 70.34833845 W 149.05491452 10129.24 77.55 281.21 8890.93 3016.89 -1916.91 -3078.62 8.64 5977889.70 616384.59 N 70.34835579 W 149.05515857 10160.32 80.30 283.22 8896.90 3046.89 -1910.45 -3108.43 10.89 5977895.68 616354.68 N 70.34837339 W 149.05540053 10192.10 83.18 283.99 8901.46 3077.67 -1903.06 -3138.99 9.37 5977902.59 616324.01 N 70.34839356 W 149.05564865 10221.40 85.46 283.43 8904.36 3106.20 -1896.15 -3167.32 8.01 5977909.04 616295.58 N 70.34841241 W 149.05587859 10252.61 88.65 285.43 8905.97 3136.61 -1888.38 -3197.50 12.06 5977916.33 616265.28 N 70.34843359 W 149.05612359 10284.27 91.56 288.15 8905.91 3167.18 -1879.24 -3227.80 12.58 5977924.98 616234.84 N 70.34845853 W 149.05636960 10315.54 91 .46 294.66 8905.08 3196.61 -1867.83 -3256.89 20.81 5977935.92 616205.58 N 70.34848965 W 149.05660575 10347.29 90.64 297.14 8904.50 3225.59 -1853.97 -3285.44 8.23 5977949.33 616176.81 N 70.34852749 W 149.05683758 S-28BPB1 ASP Final SUNey.xls Page 2 of 3 2/11/2003-12:17 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NI-S EI-W DLS Northing Easting Latitude Longitude (ft) n (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 10378.72 91.15 297.74 8904.01 3253.92 -1839.49 -3313.33 2.51 5977963.36 616148.69 N 70.34856702 W 149.05706402 10409.87 90.64 295.26 8903.52 3282.21 -1825.59 -3341 .20 8.13 5977976.81 616120.61 N 70.34860495 W 149.05729031 10439.76 90.40 292.95 8903.25 3309.86 -1813.38 -3368.48 7.77 5977988.58 616093.14 N 70.34863826 W 149.05751180 10471.78 89.57 290.16 8903.26 3340.00 -1801.62 -3398.26 9.09 5977999.86 616063.18 N 70.34867036 W 149.05775356 10522.00 89.57 290.16 8903.64 3387.66 -1784.31 -3445.40 0.00 5978016.42 616015.77 N 70.34871758 W 149.05813628 '~d '~ S-28BPB1 ASP Final Survey.xls Page 3 of 3 2/11/2003-12:17 PM ) ) Ó?03--ûêQ MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No S-28b . Date Dispatched: 11-Feb-03 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 r~ECEIVED FEB 1 8 2003 Alaska Oii & Gas Cons. Cornmisaion Anchorage Received Bd~ ~A Please sign and return to: / James H. Johnson BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery V1.1, Dec '97 ) ) õfð3-- t.:iJ~ MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No S-28B PB 1 Date Dispatched: 11-Feb-03 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 RECE\\'E[) FE8 1 8 2C03 .Alaska or, & Gas COOs. eommission AnCborage Received Bd~ c<fl21p, PI_ease sign and return to: James H. Johnson BP Exploration (Alaska) Inc. Petrotechnìcal Da1a Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery V1.1, Dec '97 ,) ) ¿; o3-~ Drilling & Measurements 3940 Arctic Boulevard Suite 300 Anchorage AK 99503 Tel (907) 273-1700 Fax (907) 561-8317 Schlumberger Date: Well Name: Company: API Number: AFE Number: Location: Field: Rig: 07-Feb-2003 S-28b BP Exploration (Alaska) Inc. 50-029-22095-02 PBD4P2044 S- Pad, Prudhoe Bay Prudhoe Bay Unit - WOA Nabors 9ES Drilling and Measurements Field Support: Operations Manager: Field Service Manager: Greg Nutter Nate Rose Gavin Rennick Drilling and Measurements Field Crew: Cell Manager(s): Cell Engineer(s): Etienne Roux Mark S1. Amour Rene Franco Brandon Barnes SERVICES PROVIDED Services Services Dates Depth Intervals PowerPulse - Gravity Toolface Directional Survey Service PowerPulse - Gamma Ray VISION* Pressure While Drilling VISION* Resistivity AIM* Inclination-at-Bit 22-Jan-03 to 24-Jan-03 24-Jan-03 to 04-Feb-03 24-Jan-03 to 28-Jan-03 24-Jan-03 to 28-Jan-03 29-Jan-03 to 04-Feb-03 29-Jan-03 to 04-Feb-03 8560 ft to 8590 ft 8600 ft to 11715 ft 8590 ft to 9725 ft 8590 ft to 9725 ft 9725 ft to 11715 ft 9725 ftto 11715 ft OPERATING STATISTICS Total MWD Pumping Time: 179.30 hr Total MWD Time Below Rotary: 320.00 hr Total MWD depth interval: 3125 ft Total MWD Runs: 4 Total L WD Pumping Time: Total L WD Time Below Rotary: Total L WD depth interval: Total LWD Runs: 106.44 hr 194.00 hr 1990 ft 2 JOB PERFORMANCE Directional Well S-28b was designed to be a two-string Ivishak Horizontal Sidetrack Producer. The tie-in point was therefore obtained from the final survey listing for the previously drilled well, S-28a. S-28b Tie-in Survey Measured Depth: 8553.25 ft ) True Vertical Depth: Inclination: Azimuth: 7814.82 ft 27.73 deg 240.33 deg The final MWD survey point was 10471.78 ft with an inclination of 89.57 degrees and an azimuth of 290.16 degrees. A survey was straight line projected ahead to TD using an inclination of 89.57 degrees and an azimuth 290.16 degrees. The final bottom hole location is: Measured Depth: True Vertical Depth: Displacement at Azimuth: 10522 ft 8903.77 ft 3879.47 ft at 242.62 degrees Whipstock Settin2 and Window Millin2 MWD Run 1 was the initial setting of the whipstock from which the S-28b sidetrack was to be performed as well as cutting the window in the 9-5/8in Casing. For this purpose, the 6.75in PowerPulse tool was used in conjunction with the Baker Whipstock / Milling assembly to provide Gravity Toolface Measurements (GTF) in order to align the whipstock properly. The whipstock was oriented to 69 degrees left of high side at 8587 ft. The window was then milled from 8560 - 8576 ft with an additional 14 ft of open hole drilled to 8590 ft. The middle of the whipstock, at 8568 ft MD, was used as the reference for all formation logging that followed. Formation Evaluation 9 7/8 in Intermediate Section The Intermediate Section was drilled from 8590 ft MD with data logged from 8568 ft MD. For this run, real-time gamma ray from PowerPulse was provided as well as VISION Pressure While Drilling data to help monitor BCD's during the drilling. Run 2 was terminated at 9330 ft and the BHA was POOH to change out the bit. The intermediate section was finally completed with run 3 at a depth of 9725 ft MD. For final log delivery, only Real-time Gamma Ray from PowerPulse was presented over the intermediate section. 6 1/8 in Production Hole The following measurements were presented in real-time: IMPulse Gamma Ray and IMPulse Resistivity (22", 34" Phase Measurements) and Inclination-at-bit (lAB). The Inclination-at-Bit measurement failed at the start of run 4 but the decision was made to continue on without the measurement. Due to losses experienced during run 4, the circulating sub had to be opened up in order to facilitate a more aggressive LCM treatment of the formation. The BHA was then POOH in order to change out the circulating sub. Once the tools were at surface, the IMPulse tool memory was downloaded and recorded mode logs generated. The data for run 4 had good resolution over the logged section and matched data acquired in real-time. The AIM motor was changed out and the lAB measurement was working again once Run 5 started drilling at a depth of 10 176 ft up to 11715 ft MD. During run 5 at a depth of 10522 ft, it was realised that previously corrected surveys from run 4 might have been inaccurate. Most of the surveys from Run 4 were re-taken and in the end it was decided to pull back to 10065 ft MD and perform an open-hole side-track to stay within the target zone. The well that was plugged back was then designated as S-28b PB 1. Run 5 experienced severe losses and eventually it was decided not to continue drilling - the well had reached TD at 11715 ft. After run 5, the IMPulse tool memory was downloaded and recorded mode logs generated. The data for run 5 had good resolution over the logged section and matched data acquired in real-time. 2 ) Transverse Shock Transverse shocks were monitored in the MWD/L WD tools, which were infrequent and low in severity. Down-hole collar RPM was monitored in real-time, showing no appreciable stick slip encountered while drilling this well. Lesson(s) Learned ECD measurements were provided in real-time and only in the 8.5 in. Intermediate section. These measurements provided valuable information regarding the condition of the hole. This helped to save a substantial amount of time spent in unnecessary wipe trips. Innovation(s) All of the tools were programmed and the recorded memory data retrieved from them while placed in the pipe shed instead of on the rig floor leading to a substantial reduction in rigtime required for the make up and break of the BRA respectively. Schlumberger Oilfield Services - Drilling & Measurements appreciates the opportunity to provide BP Exploration (Alaska) Inc. with MWD and L WD services. Sincerely, tff}> Etienne RO¿ Cell Manager Drilling & Measurements 3 ) ') a03-èD~ Drilling & Measurements 3940 Arctic Boulevard Suite 300 Anchorage AK 99503 Tel (907) 273-1700 Fax (907) 561-8317 Schlumberger Date: Well Name: Company: API Number: AFE Number: Location: Field: Rig: 07-Feb-2003 S-28b PB 1 BP Exploration (Alaska) Inc. 50-029-22095-70 PBD4P2044 S-Pad, Prudhoe Bay Prudhoe Bay Unit - WOA Nabors 9ES Drilling and Measurements Field Support: Operations Manager: Field Service Manager: Greg Nutter N ate Rose Gavin Rennick Drilling and Measurements Field Crew: Cell Manager(s): Cell Engineer( s): Etienne Roux Mark St. Amour Rene Franco Brandon Barnes SERVICES PROVIDED Services Services Dates Depth Intervals PowerPulse - Gravity Toolface Directional Survey Service PowerPulse - Gamma Ray VISION* Pressure While Drilling VISION* Resistivity AIM* Inc1ination-at-Bit 22-Jan-03 to 24-Jan-03 24-Jan-03 to 04-Feb-03 24-Jan-03 to 28-Jan-03 24-Jan-03 to 28-Jan-03 29-Jan-03 to 04-Feb-03 29-Jan-03 to 04-Feb-03 8560 ft to 8590 ft 8600 ft to 10522 ft 8590 ft to 9725 ft 8590 ft to 9725 ft 9725 ft to 10522 ft 9725 ft to 10522 ft OPERATING STATISTICS Total MWD Pumping Time: 179.30 hr Total MWD Time Below Rotary: 320.00 hr Total MWD depth interval: 1932 ft Total MWD Runs: 4 Total LWD Pumping Time: Total L WD Time Below Rotary: Total L WD depth interval: Total L WD Runs: 106.44 hr 194.00 hr 797 ft 2 JOB PERFORMANCE Directional Well S-28b was designed to be a two-string Ivishak Horizontal Sidetrack Producer. The tie-in point was therefore obtained from the final survey listing for the previously drilled well, S-28a. S-28b Tie-in Survey Measured Depth: 8553.25 ft ) ') True Vertical Depth: Inclination: Azimuth: 7814.82 ft 27.73 deg 240.33 deg The final MWD survey point was 10471.78 ft with an inclination of89.57 degrees and an azimuth of 290.16 degrees. A survey was straight line projected ahead to TD using an inclination of 89.57 degrees and an azimuth 290.16 degrees. The final bottom hole location is: Measured Depth: True Vertical Depth: Displacement at Azimuth: 10522 ft 8903.77 ft 3879.47 ft at 242.62 degrees Whipstock Settine and Window Milling MWD Run 1 was the initial setting of the whipstock from which the S-28b sidetrack was to be performed as well as cutting the window in the 9-5/8in Casing. For this purpose, the 6.75in PowerPulse tool was used in conjunction with the Baker Whipstock / Milling assembly to provide Gravity Toolface Measurements (GTF) in order to align the whipstock properly. The whipstock was oriented to 69 degrees left of high side at 8587 ft. The window was then milled from 8560 - 8576 ft with an additional 14 ft of open hole drilled to 8590 ft. The middle of the whipstock, at 8568 ft MD, was used as the reference for all fOffi1ation logging that followed. Formation Evaluation 9 7/8 in Intermediate Section The Intennediate Section was drilled from 8590 ft MD with data logged from 8568 ft MD. For this run, real-time gamma ray from PowerPulse was provided as well as VISION Pressure While Drilling data to help monitor ECD's during the drilling. Run 2 was terminated at 9330 ft and the BHA was POOH to change out the bit. The intennediate section was finally completed with run 3 at a depth of 9725 ft MD. For final log delivery, only Real-time Gamma Ray from PowerPulse was presented over the intermediate section. 61/8 in Production Hole The following measurements were presented in real-time: IMPulse Gamma Ray and IMPulse Resistivity (22", 34" Phase Measurements) and Inclination-at-bit (lAB). The Inclination-at-Bit measurement failed at the start of run 4 but the decision was made to continue on without the measurement. Due to losses experienced during run 4, the circulating sub had to be opened up in order to facilitate a more aggressive LCM treatment of the formation. The BHA was then POOH in order to change out the circulating sub. Once the tools were at surface, the IMPulse tool memory was downloaded and recorded mode logs generated. The data for run 4 had good resolution over the logged section and matched data acquired in real-time. The AIM motor was changed out and the lAB measurement was working again once Run 5 started drilling at a depth of 10176 ft up to 10522 ft MD when it was realised that previously corrected surveys from run 4 might have been inaccurate. Most of the surveys from Run 4 were re-taken after this realisation and in the end it was decided to pull back to 10065 ft MD and perfonn an open-hole side-track to stay within the target zone. The well that was plugged back was then designated as S-28b PB 1. After run 5, the IMPulse tool memory was downloaded and recorded mode logs generated. The data for run 5 had good resolution over the logged section. For S-28b PB 1, final field prints were only generated up to 10522 ft MD, the final depth reached before plugging back. 2 ') ) Transverse Shock Transverse shocks were monitored in the MWD/L WD tools, which were infrequent and low in severity. Down-hole collar RPM was monitored in real-time, showing no appreciable stick slip encountered while drilling this well. Lesson(s) Learned ECD measurements were provided in real-time and only in the 8.5 in. Intennediate section. These measurements provided valuable information regarding the condition of the hole. This helped to save a substantial amount of time spent in unnecessary wipe trips. Innovation(s) All of the tools were programmed and the recorded memory data retrieved from them while placed in the pipe shed instead of on the rig floor leading to a substantial reduction in rigtime required for the make up and break of the BHA respectively. Schlumberger Oilfield Services - Drilling & Measurements appreciates the opportunity to provide BP Exploration (Alaska) Inc. with MWD and L WD services. Sincerely, Cell Manager Drilling & Measurements 3 8-28B Permit ") ) Subject: S-28B Permit Date: Mon, 13 Jan 2003 17:32:06 -0600 From: "Tirpack, Robert B" <TirpacRB@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Hubble, Terrie L" <HubbleTL@BP.com> Winton, Over the weekend, Nabors 9-es TD'd the horizontal section at 8-109. They drilled close to 3500' in 3 days, half of the expected time. This has bumped the anticipated spud of 8-28B from 1/20/03 to as early as 1/16/03. Would it be possible to move the expected spud date of 8-28B from 1/20 to 1/16? Please call if there are any questions. Regards, Rob Tirpack GPB Rotary Drilling 564-4166 office 440-8633 cell @?®c-:>'c ciD u lru 'j L6 1('";.,'" ) } f !Æ~!Æ~:~!Æ ) l::J FRANK H. MURKOWSKI, GOVERNOR A.IA.SIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH 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, Alaska 99519-6612 Re: Prudhoe Bay Unit S-28B BP Exploration (Alaska), Inc. Permit No: 203-002 Surface Location: 1636' SNL, 1269' EWL, Sec. 35, T12N, R12E, UM Bottomhole Location: 3414' SNL, 4967' WEL, Sec',34, T12N, R12E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~- .-~./¿¡;¢-~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this /1~day of January, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section VJ61\- , ¡¡olø"3 Hole 8-1/2" 6-1/8" I' STATE OF ALASKA ALASKA G.._kND GAS CONSERVATION COMMI~-.. bN PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II 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 = 65.46' Prudhoe Bay Fie.ld I Prudhoe 6. Property Designation Bay Pool / ADL 028258 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number /' 8-288 9. Approximate spud date 01/20103 I Amount $200,000.00 14. Number of acres in property 15. Pr~osed depth (MD and TVD) 2560 13290' MD 18928' TVD o 17. Anticipated pressure {s9 20 AAC 25.035 (e) (2)} 95 Maximum surface 2518 psig, At total depth (TVD) 9005' 13418 psig Setting Depth TC;>D Botom LenQth MD TVD MD TVD 783' 8958' 8166' 9741' 8761' 3699' 9591' 8675' 13290' 8928' 11. Type Bond (See 20 AAC 25.025) 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 1636' SNL, ~ß~b S~~q, T12N, R12E, UM At top of prodú'f'tive IntelV~- 3604' SNL, 1747' WEL, Sec. 34, T12N, R12E, UM At total depth 3414' SNL, 4967' WEL, Sec. 34, T12N, R12E, UM 12. Distance to nearest property line 13. Distance to nearest well If ADL 028261, 1866' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 9108' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade Couclina 7" 26# L-80 BTC-M 4-1/2" 11.6# L-80 IBT-M Number 2S 100302630-277 Quantitv of Cement (include staae data) 225 cu ft Class 'G' 505 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 11 050 feet 8963 feet 1 0624 feet 8957 feet Length Plugs (measured) Junk (measured) Baker Open Hole Retainer, cemented in place, TOC at approximately 10624' (05/1996) Cemented MD TVD Size Structural Conductor Surface Intermediate Production Liner Liner 110' 20" x 30" 8 cu yds (Approx.) 110' 110' 2498' 13-3/8" 2022 cu ft AS III, 1066 cu ft AS II 2531' 2531' 9643' 9-5/8" 2068 cu ft Class 'G' 9672' 8797' 270' 7" 348 cu ft Class 'G' R ~~'b£~ E {]563' - 8803' 1234' 2-7/8" Uncemented Slotted Liner ' 6' 546' - 8957' Perforation depth: measured Slotted Section: 9649' - 9672' true vertical Slotted Section: 8777' - 8797' JAN 0 6 200j Alaska on & Gas Cons. Commission Anchorage 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report II 20 AAC 25.050 Requirements Contact Engineer NameINumber: Rob Tirpack, 564-4166 Prepared By NameINumber: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing i~ true and correct to the best of my ~nowl~~ge . " 7J\#') Signed Billlsaacson u.ll, k. \J..... '- Title Semor Dnlhng Engineer Date '1~... \P ""^5 , . <CQmmi$si,on .u$ØOnl~> ' Permit Number 203- 0 ð ..2.- Conditions of Approval: API Number Approval~Ç>;~ I' e, .:; See cover letter 50- 029-22095-02 I.! \. '-/ ! './ ¡ for other reauirements Samples Required 0 Yes B No Mud Log Required \ 0 Yes 12§ No Hydrogen Sulfide Measures iíI Yes 0 No Directional Survey Required ß 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: ~ ·~t '-g ~ P E- +c ~S 6'0 ,fÇ.i. ORIGINAL SIGNED BY-Commissioner- ML,Om by order of tne commission Date \ I~ , ... /Ì i. (1_ \ i I .>--\/..... ._;~) 'I !"'~'V ~/' S~b¡"it Iln Triplicate Approved BV Form 10-401 Rev. 12-01-85 I ) ,) I Well Name: 18-288 Drill and Complete Plan Summary 1 Type of Well (service I producer I injector): I Horizontal Sidetrack Producer // Surface Location: Estimated Target Location: Ivishak Zone 4 Bottom Hole Location: x = 619,432 Y = 5,979,855 1636' FNL, 1269' FWL Sec. 35, T12N, R12E Umiat X = 616,450 Y = 5,977,840 TVDss 8810' 3604' FNL, 1747' FEL Sec. 34, T12N, R12E Umiat X = 613,227 Y = 5,977,981 TVDss 8863' 34141 FNL, 4967' FEL Sec. 34, T12N, R12E Umiat 1 AFE Number: I PBD4P2044 1 I Estimated Start Date: 101/20/03 I MD: 113,290' I 1 TVD: 18,928' 1 I RiQ: I Nabors 9ES / I OperatinQ days to complete: 119.5 1 GL: 136.96' I I KB: 128.5' I I KBE: 165.46' I I Well DesiQn (conventional, slimhole, etc.): 1 Horizontal Sidetrack I Objective: 1 Zone 4A and 4B Formation Markers Formation Tops (wp06) Kingak JO Kingak JC Kingak JB Kingak JA Sag River Shublik Sadlerochit TO MD 8,955' 9,306' 9,464' 9,550' 9,741' 9,823' 10,066' 13,290' TVD 8,165' 8,465' 8,585' 8,645' 8,761' 8,803' 8,885' 8,928' TD Criteria: Based on 2700' MO of pay in Zone 4. TVDss 8,100' 8,400' 8,520' 8,580' 8,696' 8,738' 8,820' 8,863' Comments 7.3 ppg EMW 7.3 ppg EMW 7.3 ppg EMW 7.3 ppg EMW Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing 7.3 ppg EMW / 7.3 ppg EMW 7.3 ppg EMW 7.3 ppg EMW Casing/TubinQ Pro~ram Hole Size CsglTbg O.D. Wt/Ft Grade Conn Length Top 8tm / ./ MDITVD MDITVD 8-1/2" 7" 26# L-80 BTC-M 783' 8,958'1 8,166' 9,741'/8,761' 6-1/8" 4-1/2" 11.6# L-80 IBT-M 3,699' 9,591'/8,675' 13,290'/8928' Tubing 3-1/2" 9.2# 13Cr80 VAM ACE 9,463' GL 9,491 'I 8,606' S-288 Permit to Drill Page 1 I ) ) Directional KOP: 19,108' MD Maximum Hole Angle: -57.0° in 8-1/2" hole -95.0° in 6-1/8" horizontal section There are no close approach issues in the Intermediate hole section. The production interval passes BP's anticollision guidelines against S-28A when minor risk based. S-28A will be P&A'd during pre-rig operations. MWD with IFR/MSA from kick-off to TD Close Approach Well: Survey Program: Mud Program Section Milling Mud Properties: LSND I Whip Stock Window 9 5/8" I Densi~ý~pg) Viscosity PV YP tauo MBT PH API FI e·ß" 20 - 30 15 50 - 60 8.0- 9.0 <6 Intermediate Mud Properties: LSND 1 8-1/2" hole section I Denð!!pg) 10-Sec Gel PV YP tauo MBT PH API FI 10 - 20 15 20 - 27 8.0 - 9.0 <6 Production Mud Properties: Quickdril I 6-1/8" hole section I Density (pp~ LSRV PV YP LSYP MBT pH API FI 8.3-8.6 20,000+ 7 -11 20 - 25 4-8 <6 9.0 - 9.5 4-6 Logging Program 8-1/2" Intermediate: Sample Catchers - from JD to casing point. Drilling: MWD Dir/GR- Real time Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - over entire interval, samples described and discarded. Drilling: MWD Dir/GR/Res- Real time Open Hole: None Cased Hole: None Cement Proaram Casing Size í 7" 26#, L-80 Intermediate Liner Basis: Lead: None Tail: Based on 8º' shoe track, 633' of 7" X 8-1/2" open hole with 30% excess, 150' 7" X 9-5/8" Liner Lap, and 2æ' ·-5/8" excess. Tail TOC: ,95' D I Fluid Sequence & tnes: Pre Flush 10bbls CW100 Spacer 25bbls MudPU8H XL at 12.5ppg Lead None /1 / Tail 40 bbls, 225 ft3,¡(~~acks Class G @ 15.8 ppg,~·ft3/sack y (:...--" 8-288 Permit to Drill Page 2 ) ) Casing Size I 4.5" 11.6#, L-80 Production Liner Basis: Lead: None Tail: Based on 80' shoe track, 3550' of 4-1/2" X 6-1/8" open hole with 500/0 excess, 150' 4-1/2" X 7" Liner Lap'æn 0' of 7" excess. Tail TOC:, MD I Fluid Sequence & - limes: Pre Flush 10bbls CW1 00 Spacer 25bbls MudPUSH XL at 12.5ppg Lead None /ì // Tail 90 bbls, 505 ft3,~~acks Class G @ 15.8 PP9Q¿6"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. Diverter, 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 7-5/8" Casing/5-1/2" Liner Test Integrity Test - 6-1/8" hole Planned completion fluids 3326 psi (7.3 ppg @ 8761' TVD) 2450 psi (.10 psi/ft gas gradient to surface) Infinite with a 1 ?..5~ppg FIT Rams test tO/ð',~ºØ.lpsi/250 psi. Annular test"kr2,500 PSi/25V>Si 3500 psi surface pressure LOT after drilling 20' outside window 3418 psi (7.3 ppg @ 9005' TVD) 2518 psi (.10 psi/ft gas gradient to surface) Infinite with 9~6~3 FIT Rams test to .,¡; psi/250 psi. Annular test 2,500 psi/25~si 3500 psi surface 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 DS-04. Any metal cuttings will be sent to the North Slope Borough. . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. S-28B Permit to Drill Page 3 ) ) Sidetrack and Complete Procedure Summary Pre-RiQ Work: 1. Pressure test OA to 2500 psi (passed 11/23/02). 2. Pressure test Casing and Tubing pack-ofts to 5000 psi 3. Rig up slickline. Drift tubing and tag top of 2-7/8" liner. 4. Rig up coil. RIH to 9385' MD. 5. Bullhead and squeeze 50 bbls cement into sidetrack and existing perforations. 6. Pull up and contaminate cement to 9329' MD. 7. Pressure test cement plug and 9-5/8" casing to 3000 psi. 8. Rig up e-line. Chemical cut 4-1/2" tubing at 9226' MD. 9. Fluid pack tubing and OA. Freeze protect same. 10. Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover form. Ria Operations: / 1. MIRU Nges. 2. Pull BPV. Circulate out freeze protection and displace we~ seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull 4-1/2" tubing from above pre-rig cut. 5. Rig up e-line. Make GR/JB run to top of 4-1/2" tubing stub. /' 6. MU bridge plug on e-line with CCL. RIH and set at 9130' MD, set as needed to avoid cutting a casing collar. /' 7. Test wellbore to 3500 psi for 30 minutes. 8. RIH with 9-5/8" Baker bottom trip whipstock assembly. Orient whipstock and set on bridge plug. 9. Mill window in 9-5/8" casing at 9108' MD. Perform FIT. POOH 10. MU 8-1/2" drilling assembly with Dir/GR and RIH. 11. Kick oft and drill the 8-1/2" intermediate interval, building at 5°/100' to a 57° hold angl~> 12. Drill ahead to casing point at Top Sag River to an estimated depth of 9,741' MD. ."... _ 13. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing to 8958' ",- MD. POOH. 14. MU 6-1/8" BHA with Dir/GR/Res and RIH to the landing collar. 15. Pressure test wellbore to 3500 psi for 30 minutes. /' 16. Drill shoe track. Swap over mud and drill 20' of new formation. Perform FIT to 9.6 ppg EMW. 17. Drill the 6-1/8" production interval bujlding at 12°/100' to horizontal, targeting Z4 Ivishak. Drill ahead to an estimated TD of 13,290' MD ..;I"" ~ 18. Run a 4-1/2" solid liner throughout the 6-1/8" wellbore and back into the 7" intermediate liner to 9,491' MD. 19. Displace well to clean seawater. 20. RIH with DPC perf guns. Perf intervals to be determined from LWD logs. 21. POOH. LD DP and perf guns. 22. Run 3-1/2",9.2#, 13Cr-80 completion tying into the 4" liner top. /' 23. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 24. Set and test TWC. 25. ND BOPE. NU and test the tree to 5000 psi. 26. Freeze protect the well to -2200' and secure the well. 27. RDMO Post-RiQ Work: 1. Install well house 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. S-28B Permit to Drill Page 4 ) ) 5-288 Drilling Program Job 1: MIRU Hazards and Contingencies ~ No wells will require well house removal or shut-in for the rig move onto S-28B. The closest neighboring wells are on -35' well spacing. Care should be taken while moving onto the well. Spotters will be used at all times. / ~ S-Pad is not designated as an H2S site. However, Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest SHL Wells: Closest BHL Wells: 5-30 10ppm 5-17C 25 ppm 5-05 60ppm 5-28A 20 ppm The maximum level recorded of H2S on the pad was 160 ppm on 5-21 in 4/12/98. » 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 w.~,1IY""m','·,~;"",¡,·.w.....,.....m....~·"""'''''""IW''W","'')'',,,,·,.H¡.,.,.,.,.,.,·.W''~.....)¡.)¡.,~,¡.,w".,·'^""".,.,'J~m"H',.)¡.k.,.,.A....w...;,.....'mn.~,""'"';,.m..."·"'""'·m..,m..".,\wN.,.........mH.-AA-A-.-.-AA-.-.-,r.-.:,IAA'.,-¡m,r,;J.m;~m,rym}l.mß!,lK-m~ß;;'~I,ry~mm,W¡,lmm;¡,r,;';mmm;,!,IJ.~:)mm;m¡!.-m;¡mmJ',:mmm~wAA:¡;;..-mmmAr,;ß¡m;ÞÞAA.m¡.mmN'AI,rÞ:-~¡';'!~IAAI¡.;J¡"-.-.:¡m;.-m,:mmmm:¡,~r,;¡.mm¡'p),I,IJ:-~,-,:mJ,IAI)¡¡,Wm,IM;,~ Job 2: De-complete Well Hazards and Contingencies ~ S-28A will be P&A'd in pre-rig operations. The existing sidetrack and perforations will be cement squeezed. Planned TOC is 9,329' (100' below the tubing cut at 9226') ~ 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 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 S-288 Permit to Drill Page 5 ) ') Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies ~ The intermediate section will kick off in the Kingak '0' interval and TO at the top of Sag River. ~ié"¡S-28B will be at 570 inclination at a 2650 azimuth, maintain mud weight at minimum .3 pg to interval TO. Follow all shale drilling practices to minimize potential problems. ~ fe 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: In the worst-case scenario of 8.8 ppg pore pressure at the Sag River depth, a fracture gradient pf---f¿.O ppg at the 9-5/8" casing window, and 11.2 ppg mud in the hole, the kick tolerance i Ihfini . Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" ~-;¡"-,)),I,I,I,I,:,\:,~"tma,;,¡"JiAAWAlAI',IAI,I'-¡"-,I,l.\l,I.Im.-.l.-;'-.I.I,\~-m;'IA:¡.;m,-IfA4,1,-, :¡.,-m,:n-,I,-¡"-, .-m-I:.. ,)m-.,-¡"-.l.-¡"A-~~I,\I,I,-~"'-,~'-.-),\-M'-.,-A-.),~l,I,l).l,Im,l,!,I,-m,1,l,a~,I.I,I,\I,I,W.l.W',r,l,IAI,I.IAI,I,IA~¡,I,",I,I.A~'~\I,I,,'I;»mA¡¡'-'-,-I<-,I,-" .-mµA-A-,~-'-'-,I,'.l.r,l,I,~I,I.'AI.l.rAIAW!<I,I,:¡"I,\I,I,I,I,I,I,\'WAW,IJ,I,I,I,-m~:I.IAr,l,lAI,I,I,I,I,I,I.l.l,I,rAlmi,l,"'I,I,WAI,I,IAIAIA:AI.I.I,I,~.I,IAAJ,-!'-Ar.,;'-A-.l.-A-A-.l.J..I,I,Ar.;.;.A.,.H:.~~'"w~.".,.,.........,.,.....,.,~A-"-A-A-A-;J.I.;,I,IM.~"'.#>.w""",,,,,.,,.....,.,wm'~i<""'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 . L,LI. .11. .1. .1.11'_ _I. _L_' ..\ ...;-¡-- T--W \ ... .. .r-mll' _U_'UTIU _1_. 1'_ _mm_'.I:-T'Tum---... Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies ~ There are four potential fault crossings in Zone 4 while drilling the production section. The intercept information is listed below. Lost circulation is considered a moderate risk. Should the faults cause losses, follow the Lost Circulation Decision Tree. The faults near the end of the horizontal are newly mapped and have unknown characteristics. If lost circulation or drilling problems occur across these last two faults, the well will stopped short. All efforts should be made to drill past the first three faults. ./ Fault #1 - Shublik Fault #2 - Zone 4 Fault #3 - Zone 4 Fault #4 - Zone 4 Fault #5 - Zone 4 M D Intersect 9975' 10675' 11000' 12700' 13000' TVD Intersect 8800' 8895' 8900' 8915' 8890' Est Throw 20' -40' 20' -30' 1 0' -20' 1 0' -20' 30' -45' Throw Direction DIU UID DIU UID U/D Uncertainity Medium Medium Medium Medium Medium 8-288 Permit to Drill Page 6 ) ) ~ A large fault tips out 100' to the south midway through the wellpath. Past attempts to cross this fault have resulted in massive loss circulation. Stay in the northern portion of the driller's polygon. ~ A pump out sub will be run in the BHA to aid in placing LCM material. ~ KICK TOLERANCE: In the worst-case scenario of 8.6 ppg pore pressure in the Ivishak, a fracture grade..ie . ~...f)1 0.0 ppg at the 7" casing window, and 8.6 ppg mud in the hole, the kick tolerance is nfi~Jté. .;1-~_. » The S-28B (wêllpath passes BP's anticollision guidelines against S-28A when minor risk based. The S-28A well path will be P&A'd during pre-rig operations. Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP 1101111,1::':11:,.1. -mll:I,I,__I,IIIIIIII: .nl:II:I\1 .mn,II,:,!\:I:IIUmD-L:II;,ml:I!II,uwm:I:I~"ll\Iau,l:mrl,:1,IIIIIUlllmlr1IDI:,m:DII,IIUWDIIIUIII:llm_m:mrulnUIIII. :Tllm~ ):_aUlII:-lII!,\rlllmllc.::~,lc::m;mlm:I,:,I_r I ,-- -111--\-1- :I-:;I!;.I-~I;;;IUUa.....·· .11 :--III,'-:mm-:,III,I,I:lalmr,lIlIlm:UI,I.I:: Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies ~ Differential sticking is a concern. The 8.6ppg mud will be -600psi 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. Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Job 13: ND/NU/Release RiQ HazardsandConüngencres ~ No wells will require well house removal or shut-in for the rig move from S-28B. The closest neighboring wells are on -35' well spacing. Care should be taken while moving onto the well. Spotters will be used at all times. Reference RP .:. "Freeze Protecting an Inner Annulus" RP 8-288 Permit to Drill Page 7 ), ) S-288 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 S-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 11.3 ppg to ensure shale stability in the Kingak. · Kick tolerance is Infinite with a 12.0 ppg LOT. Production Hole Section: · Five faults are expected. Lost circulation risk is moderate. Use LCM Decision Tree in the event of losses. Consult Well Program for fault specifics. · 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. · S-288 passes close approach with S-28A in the horizontal interval when minor risk based. S-28A will be P&A'd during pre-rig operations. 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 S-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 8-288 Permit to Drill Page 8 5("5 \X )I x> x > 9459' l-t ELMD TT LOGGED 11/23/90 I X>'\... X > '" Perforation Interval- X > 9649'- 9672' ~ 19-5/8" CSG, 47#, L-80, ID = 8.681" l-i 9672' .. I... 19674' Top of Whipstock~ "'~.... ............ .... \11.1..- ............ ........ ~~. "......,....... I .............', ..",,!....m It~"'" ":::"""", ........ .... ........ 19682' Btm of Window 1 ........ TREE = 4" erN ·WB..LHEAD = FMC Ä'CruÃfOR";" ........... ....·...··.....ofïs· "" ."..,..............,..,....,............. KB. B..EV = 64.86' . ..,.....,..........." BF. ELEV = 36.96' ..."....".......................... ............."...................".....".....1 KOP = 3012' .. ............"...........""......,........................... Max Angle = 95 @ 11015' "5ãfun1'fíl1Õ;; .. -."'''..- ···1Ööf¡í ........ ..... ......",.. .". Datum TVD = 8800' SS ") S-28A (I) 113-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2531' ~ L Minimum 10 = 2.37" @ 9390' TOP OF 2-7/8" LNR TOPOF 2-7/8" LNR l-i 1 TOP OF 7" LNR l-i , ¡ : ~ ~ .. I 9390' 9409' t J 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" l-i 9459' I 19716' Toe ~ ÆRFORA TlON SUMMARY REF LOG: SÆRRY SUN MWD/RLL ON 10/31/90 ANGLE AT TOP ÆRF: 27 @ 9649' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9649-9672 0 05/01/96 ... x~ 10,100' MO 7", 26#, L-80, Butt 10,6024' MO 2-7/8" Slotted Liner, 6.16#, L-80 FL4S, 0.00579 bpf, 10=2.37" DATE 01/02191 05/02196 03/15/01 03/16/01 08/14/01 SIS-MH SIS-CS RNITP COMMENTS ORIGINA L COMPlE11ON SIDETRACK COMPlE11ON CONVERTED TO CANVAS FINAL CORRECTIONS COMMENTS DA TE REV BY REV BY SAFET"');rES: 3" FLOWLINE IN SKID PORTIONS OF THIS WELL'S .' WLlNE ARE 3" AND SUBJECT TO EROSION. THE GC SHOULD BE NOTIFIED OF ANY WELL OPERATION WHICH COULD INCREASE THE FLOW OR EROSION RATE. 2081' 1-i4-1/2" OTIS SSSV NIP,ID= 3.813" 1 --I ~ I~ GAS LIFT MANDRELS DEV TYPE VLV LATCH 12 OTIS RA 35 OTIS RA 27 OTIS RA 29 OTIS RA 28 OTIS RA PORT DATE 2589' ST MD 5 3093 4 5517 3 7545 2 9105 1 9329 TVD 3024 5118 6841 8230 8426 9358' 9359' 9379' 9390' 1-i4-1/2" PARKERSWS NIP, ID = 3.813" l-i BAKER E-22 ANCHOR SEAL ASSY. ID = 4.00" 1-i9-5/8" x 5-1/2" BKR SA-3 PKR, ID = 4.75" 1 l-i BKR RUNNING SUB WI GS PROFILE, ID = 3.75" 9423' 1- 4-1/2" PARKER SWS X NIP, ID = 3.813" (BEHIND CT LNR) 9443' 1- 4-1/2" PARKER SWS X NIP, ID = 3.813" (BEHIND CT LNR) 9455' 1- 4-1/2" TBG TAIL WILEG, ID = 3.958" (BEHIND CT LNR) I 10624' 1- BAKER OPEN HOLE RETAINER, NOT SET, eMf TO 11050' PRUDHOE BA Y UNIT WB..L: S-28A ÆRMIT No: 95-1730 API No: 50-029-22095-01 Sec. 35, T12N,T12E BP Exploration (Alaska) TREE = 4" CrN . WELLHEAD = FMe ÃcrüÄroþf; ................ ·.....oiì·s' kS:äE\i; 64.86' ,................... .... ......." BF. ELEV = 36.96' 'j(OP·;·· ... ...... ...... ···········3Ó12i' ivtî'xÄngïe;;;··..ss·(@ 11015" l)atumMO;;...·...····...·...······...·1Ó0^1"4' bätum Tv Ö = '. ·SSOÓi§§ ) S-28A ) e 2081' 1-i4-1/2" OTIS SSSV NIP, ID = 3.813" 1 113-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2531' ¡--..J -~ 2589' I~ ~ Minimum ID = 2.37" @ 9390' TOP OF 2-7/8" LNR ITOPOF 2-7/8" LNR l-i 9390' I TOP OF 7" LNR l-i 9409' --- ---JTubing Cut @ +/- 9226'1 ~TOC @ +/-9329'1 , ¡I, 9358' 9359' ~ 9379' 9390' 1-i4-1/2" PARKER SWS NIP, ID = 3.813" 1 l-i BAKER E-22 ANCHOR SEAL ASSY, ID = 4.00" l-i 9-5/8" x 5-1/2" BKR SA-3 PKR, ID = 4.75" 1 l-i BKR RUNNING SUB WI GS PROFILE, ID = 3.75" 1 :8: I if ~ J 9423' 1- 4-1/2" PARKER SWS X NIP, ID = 3.813" (BB-JIND CT LNR) 9443' 1- 4-1/2" PARKER SWS X NIP, ID = 3.813" (BB-JIND CT LNR) I X5" \X 'j X > X > 9459' 1-1 ELMD TT LOGGED 11/23/90 1 X>'\.. X:> '" Perforation Interval- . X :> 9649'- 9672' ~ I 10624' 1- BAKER OÆN HOLE RETAINER, NOT SET, eMT TO 11050' 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" l-i 9459' 1 9455' 1- 4-1/2" TBG TAIL W/LEG, ID = 3.958" (BEHIND CT LNR) 19-5/8" CSG, 47#, L-80, ID = 8.681" l-i 9672' ~ 10... 19674' Top of Whipstockr' ~ ...... ............... i i~Ii~i..c ............ ............ i.~."""""""""""""" 19716'TOC~ Hm..:~.. ....................::.................... .... .... ... .... .... .... ........ .... 19682' Btm of Window I .............. ... xa. 10,100' MO 7", 26#, L-80, Butt 10,6024' MO 2-7/8" Slotted Liner, 6.16#, L-80 FL4S, 0.00579 bpf, 10=2.37" Date 10-7-02 Rev By Comments RBT Final Pre-Rig PRUDHOE BAY UNIT WELL: S-28A PERMIT No: API No: Location: Sec. 35, T12N, R12E GPB Rotary Drilling 5-288 ) ) ~ ~ 'X' Nipple with 2.813" bore @ +/- 2200' MDI I. J ~ ~ ~ 9-5/8" X 7" Baker xxxx Liner Hanger w/ xx Running Tool, ZXP Liner Top Packer /' and TBR @ +/- 8958' 1 Top of Window @ 9108' MD 1 3-1/2", 9.2# 13CR80, VAM ACE Production Tubing I Btm of Window I @ 9,126' MD Top of BP @ 9130'1 17" X 3-1/2" Baker SABL-31 Packer @ +/- 9,491' MD - 7" X 4-1/2" Baker XX Liner Hanger w/ ZXP Liner Top Packer and TBR @ +/- 9591' MD 19-5/8",47#, L-80 -- /' ... ~ 14-1/2",11.6#, L-80 I 13,290' MD /8928' -"" Date 1 0-7-02 Rev By Comments RBT Proposed Completion PRUDHOE BAY UNIT WELL: S-28A PERMIT No: API No: 50-029-22095-01 Location: Sec. 35, T12N, R12E GPB Rotary Drilling AUGUST 17, 1990 Date ~,,~'-'-'"\.,', ..,.... ~ OF .4"\\ ,:'~ .41.... LA \, ", ~T'~.. .. ~J' . ~ ~.. *..1- . ~*~:4 H' ..;9 'i ~.... - . - r. .... At J ~. '- Ì!1. · · · '/0 .. "J ~... KEITH A. McNEIL · 'I ~.. No. LS7335 ... ' . ~J;.. · .§=" \\\~R(D·······:~~~ \" LA N D S ~ ......", ~"'""'~~ North Slope Production Engineering - 1 Reservoir Engineering Operations (MB9-2) - 1 North Slope - to Rig l8E for Posting - 1 Well Records (LR2-1) - 11 Well Files (MBI2-1) - 1 Graphic Services, Supv., Cartography (MB2-4) - 1 CIRCULATION: 2) The completed form should be returned to Drilling Dept for distribution. 1) The surveyor should fill in Items 2, 3, and 4. NOTES: *Measured by Drilling Foreman section 35, T 12 N, R 12 E, UPM X = 619432 Y = 5979855 ASP 4 LAT = 70021'12.94"N, LONG = 149°01'48.62" W 3) Local Benchmark Elevation Mon. S-4, 38.04 Ft. AMSL 4) Top Edge of Cellar 35.16 AT S.W. COR. Ft. AMSL 5) Kelly Bushing to Base Flange* 27.90 Ft. AMSL 6) Kelly Bushing to Ground Level* 29.70 Ft. AMSL 7) Base Flange Elevation 36.96 Ft. AMSL 8) Kelly Bushing Elevation 64.86 Ft. AMSL 1) WELL: S-28 FIELD: Prudhoe Bay unit 2) Well Head Location 1636' from North line 1269' from WEST line WELLHEAD LOCATION DATA B.P. EXPLORATION ) ) Plan: S-28B \\p06 (S-28/Plan S-28B) er""ted By: Ken Allen I""I MWD SURVEY PROGRAM Depth Fm Depth I 0 S""~FPIan 9126.00 1328954 Planned: S-28B "p06 VI Dale: Date: Checked: \\-'ELL DEI AILS NaIœ -N'·S -EJ-W Ncrthing Easting Ú!lituœ Loogitudo SIoI 149629 59798552 619432.00 70021'12.94ON 149'01'48.6œW 28 IARGETDETAILS Narœ NO ~N:-S -EJ-W Nonhmg Easting Sbap" S-28B ISad 8875.46 -1967.64 -3014.00 5977840.00 616450.00 PoiDt 5028B I50 8905.46 -1923.73 -4513.62 5977860-00 614950.00 Point 5-28B lew.1 8907.46 -187624 -3414.63 5971925.00 616048.00 Point 5-28B lew.3 8929.46 -1906.72 -394923 5977886.00 615514.00 Point S-28B Poly A 8940.46 -2051.45 -528532 5977720.0 I 614180.50 Polygon 5-28B I6b 9004.46 -1911.61 -5273.59 5977860.01 614190.00 Point SECTION DETAILS Target S-28B TSad ~ S-28B kwal S-28B kwa3 S-28B T5a S-28B T6b VSec 2779.15 3189.76 3206.24 3338.31 3388.89 3437.67 3588.70 3646.26 3797.94 3910.95 3985.10 4102.12 4320.45 4466.00 4530.99 4791.21 4867.91 5021.76 5408.60 5595.50 5780.35 6482.34 TFace 0.00 35.00 0.00 41.90 0.00 86.52 4.82 0.00 -99.03 -116.90 0.00 37.22 0.00 0.00 0.05 0.00 147.32 179.95 0.00 10.72 51.00 0.00 DLeg 0.00 5.00 ß;OO -12.00 0.00 12.00 10.00 0.00 10.00 6.00 0.00 6.00 0.00 0.00 6.00 0.00 6.00 6_00 0.00 5.00 4.00 0.00 +E/-W -2349.28 -2750.37 -2767.06 -2905.51 -2960.21 -3014.00 -3184.77 -3250.13 -3414.63 -3530.34 -3605.11 -3724.35 -3949.23 -4099.15 -4166.09 -4434.11 -4513.62 -4674.13 -5077. 70 -5273.59 -5471.3 I -6234.4 7 +N/-S -1897.49 -1988.28 -1989.81 -1985.86 -1978.45 -1967.64 -1919.44 -1900.09 -1876.24 -1882.54 -1890.73 -1899.22 -1906.72 -1911.72 -1913.95 -1922.87 -1923.73 -1921.84 -1917.07 -1911.61 -1892_24 -1775.43 TVD 8314.91 8760.46 8771.37 8838.76 8857.30 8875.46 8903.60 8903.62 8907.46 8915.92 8923.47 8929.46 8929.46 8929.46 8927.11 8908.25 8905.46 8919.05 8987.87 9004.46 8995.77 8928.23 Azi 244.32 264.75 264.75 277.71 277. 71 285.00 286.49 286.49 270.00 263.75 263.75 268.09 268.09 268.09 268.09 268.09 270.67 270.68 270.68 272.50 278.70 278.70 Inc 29.31 56.95 56.95 71.44 71.44 72.00 89.98 89.98 87.40 84.27 84.27 90.00 90.00 90.00 94.02 94.02 90.00 80.32 80.32 90.00 95.00 95.00 MD 9126.00 9739.63 9759.63 9914.34 9972.57 10030.40 10210.80 10278.96 10445.82 10562.08 10637.67 10757.45 10982.45 11132.45 11199.48 11468.32 11547.90 11709.19 12118.61 12315.52 12514.54 13289.54 See I 2 3 4 5 6 7 8 9 10 II 12 13 14 15 16 17 18 19 20 21 22 REFERENCE INFOR!\LUrON Co-ordinale (N'E) R~f~oc.e: Well C.ò'Dtre: 5-28. True North Vertical (TVD) Ref~r¿ocè: Plan 65_46' 65.46 SectiOD (V5) Refeconee: 510t - 28 (O.OON.O.OOE M<asured Depth Ref"",oœ: Plan 65.46' 65.46 Calculation Metbcd: Minimum Cun--aturè CASING DETAILS No. TVD MD Name Size 8761.46 '9741.46 7" 7.000 8928.23 13289.53 4 1/2" 4.500 FORMATION TOP DETAILS No. TVDPath MDPath Formation I 8165.46 8954.50 TJD 2 8465.46 9305.87 TJC 3 8585.46 9463.89 TJB 4 8645.46 9550.45 TJB 5 8761.46 9741.46 TSGR 6 8803.46 9823.56 TSHU 7 8885.46 10066.22 TSAD bp r--. V CakuLaIi.,)f1 M.:th.>å: Mmimwu CUr'\'alure EmIr Sph..-rn: ISCWSA ~al1 M<:lhl....t T rav C}'hD:iI..""r North Em}! SurfJ"~: Elliplio.::al ~ Casing Wamin~ M¡;d1od: Rulc..-s BJ!M.'Ö ~ '....~ ....;11-f' -' ,,' /' ,I ,I I ,I I I -I I ~ I. .1"#, < "r# ~ 8000- I I} t. -- End Dir : 9739.63' MD, 8760.46' TVD - -'FJC- '~ I~ j Start Dlr 12JIOO': 9759.63' MD, 877L37TVD -r EndDlr : 9914.34'MD,8838.76'TVD \ ¡ Start Dlr 12/100' : 9972.57' MD, 8857.3'TVD _ J~\ [ '-- ~ , Start Dlr 10/100': 10030.4' MD, 8875.46TVD L I I, End Dlr : 10210.8' MD. 8903.6' TVD _---l _~l_f!-- :-r-, 0 j StartDlfI0/IOO':10278.%'MD,8903.62TVD If" Start Drr 61100' : 10445.82' MD, 8907.46TVD - r - -t- ~hr>G~ ) r .i I I End Dlr : 10562.08' MD, 8915.92' TVD l I 1 . ! -l~TsF ~_L_ - & 0 ¡ S-28B kwaJ I I [\ , L I ~I &, , n ¡ ¡ f í t \ t - -- - I rÎ()~f~r.' [ I [ ¡I! ! ~ \1 I J I~ 1J '---1l , ~ : 4'ALr, 1[1 I: I 11111.1 r - i t- t ~T T: - I L_5-28Bkwa~:_' i I I /fOOO -l L _'_I _ J\- .J Sl~}saf ¡-.l I I f I! S-28(~-28.\~ i _l j [ l_:' - --! ~ ---J;taIilllr ¡¡IIM,I. 11)(i17 (i7' MI1, RQ14hVn I I l I _ l It- L I: \ 1---' I 1--.;--1 fnr nrr ·IIO'~'¡ 4<;' n, RQ?Q~(i' TVn I II I J I-L ". I [ !: I ii' [ Ii, I I I r 1 1 ! I L-;-'\j-b-~--t-t--t-i I II I I I tar.DIf6l100·dll 32.45'/vD,;89 9.~6tv.J k I.: i. I I I ; '. I S I S SfS'¡ I I. I II I I I:rd [If . I' 1?9.4!!' ~ID', w.-27¡1I T -[ Î - - -r j' f-- --, - ---t 1 I¡---I---t-t-- I i I I i 1-1 +_~.Il [, - _LLL-1-,__I--+-+--- I I 'I I· I 'i I i I! . I ¡ i I+I~I I! [ _1 CiJ LL_~~Q l 1-1-_1.: i i! I' ¡ I ¡ ! ! I .! I i I j.l 0- -+r '_n' .l 1['_ I l_~LJ LLU-.I I I ! [ I '! I , : I ! i : i ' ¡ i I I I ! ! _LI 1=--r - ~:=[.f=Ii~I- ! i I ¡ ¡ I :'; - - I I r ¡'I I j ~ I r I I I I I I I I I I I I I I I I I f I I 2800 3200 3600 4000 4400 4800 Vertical Section at 254.100 [400ft/in] 9126' MD. 8314.91TVD RKBE --- 4112" 892~.2~' TVD~ I I I 5128B \opQ6 i I [ I I I I I I I I i 1 ~ , [ I ! , I , I I I t I 6400 All TVD depths are ssTVD plus 65.46'for 13289.54' MD. J~ v¿-d(vv Total Depth 6000 Start Dir 6/100' I I I ¡Ii i I I 0 [ I ' I I I' I I I I I II I ¡I§; I ¡ I, ~c)XH hi)' , L~R T5~ Ii ii' I I' ¡ ~I I J) I T I I I 2000 ¡ 1 I [ ~Dir5flo-),:1218,61'WD,89hh"'" i I ! I 5tarUir~/~00': I2315·f2' \-fÖ,9()()L.46TVD I I I I! I E4d Bir : 1~5 4.~ \in, 8ù9~771' w9 , I , , I I i I I I I I! I I I I I I I I I I i I! i I !: 'I ! I i ¡: I I ¡ I I I I i I I I I I I I I 5200 5600 11468.32' MD, 8908.25TVD EndDir: 1l709.19'MD,8919.05'TVD &' 8400 c:: ;:: o o ~ ..c: i5.. ~ 8800 'f ~ ... ::> ¡:: 9200 Plan: 5-28B wp06 (5-2&'Plan 5-28B) Created By: Ken Allen Tool MWD SURVEY PROGRAM DepIb Fm DepIb To SUC\·ey¡Plan 9126.00 1328954 Planœd: 5-28B "p06 VI REFERENCE INFORMATION WeUCentœ:S-28. T"",Nonh Plan 65.46' 65.46 Slot - 28 (O.OON.O.ooE, Plan 65.46' 65.46 MiniImon CUJ'\'arure Co-t..-min.alo;: (N E) Ref~¿n:¿: Vertkal (lVD) Rekœoce: ~tion (VS) Refeœocç: M""sored Depth Ref"",...,,: Cakulation M¿tbcd bp o WELL DETAILS Name eN/-S eE/_W Northing E.1sting larírud< longitude Slot S-28 -1023.Q3 149629 5979855.27 619432.00 70"21'12.9-1ON 149'-ol'48.608W 28 TARGET DETAILS Name 1VD ~Ni-S ~EI-W Nonhing Eas'ÍDg Shap" S-28B TSad 8875.46 -1967-64 -3014.00 5977840.00 616450.00 Point S-28B T5a 8905.46 -1923.73 -4513.62 5977860.00 614950.00 Point ~S-28B ""-31 8907.46 -187624 -3414.63 5977925.00 616048.00 Point S-28B ""-33 8929.46 -1906.72 -3949.23 59778&6.00 615514.00 Point S-28B Poly A 8940.46 -205 1.45 -528532 5977720.0 I 61418050 Poly·gon S-28B T6b 9004.46 -1911.6! -5273.59 5977860.01 614190.00 Point SECTION DETAILS See MD Ine Azi TVD +N/-S +EI-W DLeg TFaee VSee Target 1 9126.00 29.31 244.32 8314.91 -1897.49 -2349.28 0.00 0.00 2779.15 2 9739.63 56.95 264.75 8760.46 -1988.28 -2750.37 5.00 35.00 3189.76 3 9759.63 56.95 264.75 8771.37 -1989.81 -2767.06 0.00 0.00 3206.24 4 9914.34 71.44 277.71 8838.76 -1985.86 -2905.51 12.00 41.90 3338.31 5 9972.57 71.44 277.71 8857.30 -1978.45 -2960.21 0.00 0.00 3388.89 6 10030.40 72.00 285.00 8875.46 -1967.64 -3014.00 12.00 86.52 3437.67 S-288 T~ 7 10210.80 89.98 286.49 8903.60 -1919.44 -3184.77 10.00 4.82 3588.70 ."-,,, 8 10278.96 89.98 286.49 8903.62 -1900.09 -3250.13 0.00 0.00 3646.26 9 10445.82 87.40 270.00 8907.46 -1876.24 -3414.63 10.00 -99.03 3797.94 S-288 kwal 10 10562.08 84.27 263.75 8915.92 -1882.54 -3530.34 6.00 -116.90 3910.95 11 10637.67 84.27 263.75 8923.4 7 -1890.73 -3605.11 0.00 0.00 3985.10 12 10757.45 90.00 268.09 8929.46 -1899.22 -3724.35 6.00 37.22 4102.12 13 10982.45 90.00 268.09 8929.46 -1906.72 -3949.23 0.00 0.00 4320.45 S-28B kwa3 14 11132.45 90.00 268.09 8929.46 -1911.72 -4099.15 0.00 0.00 4466.00 15 11199.48 94.02 268.09 8927.11 -1913.95 -4166.09 6.00 0.05 4530.99 16 11468.32 94.02 268.09 8908.25 -1922.87 -4434.11 0.00 0.00 4791.21 17 11547.90 90.00 270.67 8905.46 -1923.73 -4513.62 6.00 147.32 4867.91 S-288 T5a 18 11709.19 80.32 270.68 8919.05 -1921.84 -4674.13 6.00 179.95 5021.76 19 12118.61 80.32 270.68 8987.87 -1917.07 -5077.70 0.00 0.00 5408.60 20 12315.52 90.00 272.50 9004.46 -1911.61 -5273.59 5.00 10.72 5595.50 S-288 T6b 21 12514.54 95.00 278.70 8995.77 -1892.24 -5471.31 4.00 51.00 5780.35 22 13289.54 95.00 278.70 8928.23 -1775.43 -6234.4 7 0.00 0.00 6482.34 Start Dir 5/100' : 9126' MD, 8314.91'TVD Date: Date: Chec"ed: Re\iewed: CASING DETAILS No. TVD MD Name Size I 8761.46 9741.46 7" 7.000 2 8928.23 13289.53 4 1/2' 4.500 FORt\1A TION TOP DETAILS No. TVDPath MDPath Formation I 8165.46 8954.50 Till 2 8465.46 9305.87 TJC 3 8585.46 9463.89 TJB 4 8645.46 9550.45 TJB 5 8761.46 9741.46 TSGR 6 8803.46 9823.56 TSHU 7 8885.46 10066.22 TSAD CakulalltJCl ~klh.."-': MilllmWl1 CUlYJlun: F"\lr Srst~m: ISCWSA $.:all ~1.:tho.'lf.l: lra\' ('\·Iind:r NI-'f1h Error ~urfa..:~: Elllp(i..:al . C~ing W3mil~ M~"Iho.l: Rul~s IhSl.-d End Dir : 9739.63' MD, 8760.46' TVD Start Dir 12/100': 9759.63' MD, 8771.37'TVD End Dir : 9914.34' MD, 8838.76' TVD TVD Start Dir 12/100' : 9972.57' MD, 8857.3'TVD :'.' MD, 9004.46'TVD Start Dir 10/100': 10030.4' MD, 8875.46'TVD 12118.61' MD, 8987.87'TVD End Dir : 10210.8' MD, 8903.6' TVD \ Start Dir I Ofl 00' : 10278.96' MD, 8903.62'TVD Start Dir 6/100': 10445.82' MD, 8907.46'TVD J ¡ ¡ ¡ ¡-;- --- i I Iii I t-1lI\ ---1--LL I i 4--U:1 'ti f8lT~a _ ! i ¡ I I I I ¡ I "\:! I!-t----.. I I~' 'I 'i Ì\' \. ~I- I S-~oRRkw" I R\[! S-'~83k~1 I: i ! j I I! I I f- W I 7" t b-, ! ! I I \\. I I I I I I ---- r I v I ...~ I' 1 'l! '- i r l ¡ 'I i ¡ S-L~H lS¡d .J.... -';1~ , : i I \' S-~(S-28+) I I~ I ¡ I I ,I I, I ~-Î- 8 S-~81 ! , I' Nil' I ' i I I I '! ,~ i E 'd Dir: 0)6 .08' MD, 8916.5'2' n:D II I I: ' I I I ,¡ Start ~ir161 00' : 10ì37.6Lr M[U923."-7'1fVD I I : II, I I I I I 3nli I1>irl : 10~~~:t~dr 8n'J.46' '~v'¡D , I I I ' ill 8tt nir 61 Of' ·111132 ~, M-~ ' ::yp I I I I ! I I: I I ! Ene. f)ir I: III lJ9A8 N'DJ 8121.d: ~V..J II I I I I I I I I! I r -r i I " I I I I 1 . ¡ i, r I I J ¡3,?l, Di, 6~1O~ " 114Q8·k !vD, ~9)8¥~ryDI I I I I ¡ I r ¡ i ~ Enþq¡r: \qO""I9,'¥DI8?1~ I! i : I I ¡ I I i I ¡ I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I -3500 -3000 -2500 / - "/85~)Q I I I End Dir . 125 '-28B ",,06 . 14.54' MO, 8995 77' I ' ' , S" , ! I : _ '" Oi,41100'. 12315 5 I '"- - , ' ' , Iflll ~ï I _ ~~ j . . I Start Dir 51100': , ' ,¡ ¡ H ~ f +-=--=--=+- ,i j J ; 1-'-1 ~ I' ¡'llll-¡ ~~ ¡I_'i' III' I I ; I I! -i ,_. - 'I I' I :: I I i +: t i : ¡__I I j -i:r--r.Loi 'H'U", I -0' r I --I j-I I I '- , r I '1"00 ,_ i I Tò' 0,' I -,i ' . 1 ¡..,...i.--L ¡, ,: j ~ j~1 - t· ."'h_r! n ~19~~118J,28i2:-"" ~vb I ~ 2~8 PclyoA ,IL:-' -1- ~I If "I ,i ~ ~ _:----!-' tt ~----¡- I I I L -----L_L ¡ I I I I ' -2000 I -4500 -4000 W est( - )/East( +) [ 500ft/in] I -5000 All TVD depths are ssTVD plus 65. 46'for RKBE. I -5500 I, -6000 - 500- -2000 -6500 -I c: 4: o ~ +' :;: 1: o I o rfJ -250~ ) BP ) KW A Planning Report MAP Compal'!Y: Field: Site: Well: Wellpath: BP Amoco Prudhoè Bay PBS Pad $-28 Plan· $-28B Date: 11/15/2002 Time: 14:07:56 Page: Co-ordillate(NE) Reference: Well: $-28, Truè North Vertical (TVD) Reference: Plan 65.46'65.5 Section (VS) Reference: Well (0.OON,O.00E,254.1 OAzi) Survey Calculation Method: Minimum· Curvature Db: 'Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: PB S Pad TR-12-12 UNITED $TATES : North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5980854.54 ft 617919.92 ft Latitude: Longitude: North Reference: Grid Convergence: 70 21 23.002 N 149 2 32.343 W True 0.90 deg Well: $-28 Slot Name: 28 S-28 Well Position: +N/-S -1023.03 ft Northing: 5979855.27 ft Latitude: 70 21 12.940 N +E/-W 1496.29 ft Easting : 619432.00 ft Longitude: 149 1 48.608 W Position Uncertainty: 0.00 ft Wellpath: Plan S-28B Plan: $-28B wp06 Date Composed: Version: Tied-to: S-28A 9126.00 ft Mean Sea Level 25.95 deg 80.81 deg Direction deg 254.10 11/12/2002 11 From: Definitive Path +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: Plan 65.46' 9/10/2002 57519 nT Depth From (TVD) ft 0.00 Height 65.46 ft Principal: Yes Casing Points MD TVD Diameter Hole Size Name ft ft in in 9741.46 8761.46 7.000 8.500 7" 13289.53 8928.23 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 8954.50 8165.46 TJD 0.00 0.00 9305.87 8465.46 TJC 0.00 0.00 9463.89 8585.46 TJB 0.00 0.00 9550.45 8645.46 TJB 0.00 0.00 9741.46 8761.46 TSGR 0.00 0.00 9823.56 8803.46 TSHU 0.00 0.00 10066.22 8885.46 TSAD 0.00 0.00 Targets Map Map <-- Latitude --> <- Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg Min See Deg Min Sec Dip. Oil'. ft ft ft ft ft S-28B TSad 8875.46 -1967.64 -3014.00 5977840.00 616450.00 70 20 53.582 N 149 3 16.682 W S-288 T5a 8905.46 -1923.73 -4513.62 5977860.00 614950.00 70 20 54.007 N 149 4 0.504 W $-288 kwa1 8907.46 -1876.24 -3414.63 5977925.00 616048.00 70 20 54.479 N 149 3 28.390 W $-288 kwa3 8929.46 -1906.72 -3949.23 5977886.00 615514.00 70 20 54.177 N 149 3 44.012 W $-288 Poly A 8940.46 -2051.45 -5285.32 5977720.01 614180.50 70 20 52.745 N 149 4 23.052 W ) BP ) KW A Planning Report MAP Company: BP Amoco Date: 11/15/2002 Time: 14:07:56 Page: 2 Field: Prudhoe Say Co-ordinate(NE).Reference: Well: S,..28, True North Site: PB .s Pad Vertical (TVD)Reference: Plan 65.46' 65.5 Well: S,..28 Section (VS) Reference: Well (0.00N,O.00E,254.10Azi) Wellpath: Plan S-28B Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <--. .l.atitude -'.-> <.-' Longitude .---> Name Dêscription TVD +N/-S +E/-W Northing Eastlng Deg. Min ..... Sec DegMin ··Sec nip. Dir. ft ft ft ft ft -Polygon 1 8940.46 -2052.77 -4888.76 5977725.01 614576.99 70 20 52.735 N 149 4 11.464 W -Polygon 2 8940.46 -1967.02 -4119.23 5977823.01 615344.99 70 20 53.583 N 149 3 48.979 W -Polygon 3 8940.46 -1953.46 -3526.89 5977846.00 615936.99 70 20 53.719 N 149 3 31.670 W -Polygon 4 8940.46 -2107.50 -2648.16 5977706.00 616817.99 70 20 52.208 N 149 3 5.990 W -Polygon 5 8940.46 -1971.25 -2598.98 5977843.01 616864.99 70 20 53.548 N 149 3 4.554 W -Polygon 6 8940.46 -1776.90 -3497.07 5978023.00 615963.99 70 20 55.456 N 149 3 30.801 W -Polygon 7 8940.46 -1845.02 -3678.19 5977952.01 615784.00 70 20 54.785 N 149 3 36.092 W -Polygon 8 8940.46 -1862.03 -4054.54 5977929.00 615408.00 70 20 54.616 N 149 3 47.090 W -Polygon 9 8940.46 -1780.35 -4472.33 5978004.01 614988.99 70 20 55.417 N 149 3 59.300 W ·Polygon 10 8940.46 -1806.18 -5612.98 5977960.00 613848.99 70 20 55.155 N 149 4 32.632 W -Polygon 11 8940.46 -1710.55 -5964.53 5978050.01 613495.99 70 20 56.093 N 149 4 42.907 W -Polygon 12 8940.46 -1693.12 -6305.32 5978062.00 613155.00 70 20 56.262 N 149 4 52.867 W -Polygon 13 8940.46 -1873.04 -6312.19 5977882.01 613151.00 70 20 54.492 N 149 4 53.063 W -Polygon 14 8940.46 -1874.42 -5975.14 5977886.00 613488.00 70 20 54.481 N 149 4 43.214 W -Polygon 15 8940.46 -2047.23 -5424.78 5977722.00 614041.00 70 20 52.786 N 149 4 27.127 W 8-28B T6b 9004.46 -1911.61 -5273.59 5977860.01 614190.00 70 20 54.121 N 149 4 22.712 W Plan Section Information MD loel Azim TVD +N/-S +E/-W DLS ..QlIlId . Turn TFO Target ft deg deg ft ft ft deg/1 OOft . deg/10QftdE;jg/10Qft deg 9126.00 29.31 244.32 8314.91 -1897.49 -2349.28 0.00 0.00 0.00 0.00 9739.63 56.95 264.75 8760.46 -1988.28 -2750.37 5.00 4.51 3.33 35.00 9759.63 56.95 264.75 8771.37 -1989.81 -2767.06 0.00 0.00 0.00 0.00 9914.34 71 .44 277.71 8838.76 -1985.86 -2905.51 12.00 9.36 8.38 41.90 9972.57 71.44 277.71 8857.30 -1978.45 -2960.21 0.00 0.00 0.00 0.00 10030.40 72.00 285.00 8875.46 -1967.64 -3014.00 12.00 0.97 12.60 86.52 S-28B TSad 10210.80 89.98 286.49 8903.60 -1919.44 -3184.77 10.00 9.97 0.83 4.82 10278.96 89.98 286.49 8903.62 -1900.09 -3250.13 0.00 0.00 0.00 0.00 10445.82 87.40 270.00 8907.46 -1876.24 -3414.63 10.00 -1.55 -9.88 -99.03 S-28B kwa 1 10562.08 84.27 263.75 8915.92 -1882.54 -3530.34 6.00 -2.70 -5.38 -116.90 10637.67 84.27 263.75 8923.47 -1890.73 -3605.11 0.00 0.00 0.00 0.00 10757.45 90.00 268.09 8929.46 -1899.22 -3724.35 6.00 4.79 3.62 37.22 10982.45 90.00 268.09 8929.46 -1906.72 -3949.23 0,00 0.00 0.00 0.00 S-28B kwa3 11132.45 90.00 268.09 8929.46 -1911.72 -4099.15 0.00 0.00 0.00 0.00 11199.48 94.02 268.09 8927.11 -1913.95 -4166.09 6.00 6.00 0.01 0.05 11468.32 94.02 268.09 8908.25 -1922.87 -4434.11 0.00 0.00 0.00 0.00 11547.90 90.00 270.67 8905.46 -1923.73 -4513.62 6.00 -5.05 3.24 147.32 S-28B T5a 11709.19 80.32 270.68 8919.05 -1921.84 -4674.13 6.00 -6.00 0.00 179.95 12118.61 80.32 270.68 8987.87 -1917.07 -5077.70 0.00 0.00 0.00 0.00 12315.52 90.00 272.50 9004.46 -1911.61 -5273.59 5.00 4.91 0.93 10.72 S-28B T6b 12514.54 95.00 278.70 8995.77 -1892.24 -5471.31 4.00 2.51 3.12 51.00 13289.54 95.00 278.70 8928.23 -1775.43 -6234.4 7 0.00 0.00 0.00 0.00 Survey MD Inel Azim TVD Sys TVD MapN MapE VS DLS TFO Tool/Comment ft deg deg ft ft ft ft ft deg/10OO deg 8954.50 29.79 243.61 8165.46 8100.00 5977958.75 617188.50 2696.31 0.00 0.00 TJD 9126.00 29.31 244.32 8314.91 8249.45 5977920.73 617113.46 2779.15 0.34 144.31 MWD 9200.00 32.40 248.28 8378.43 8312.97 5977904.99 617078.95 2816.74 5.00 35.00 MWD 9300.00 36.74 252.66 8460.76 8395.30 5977885.30 617025.79 2873.33 5.00 31.60 MWD 9305.87 37.00 252.88 8465.46 8400.00 5977884.20 617022.44 2876.85 5.00 27.99 TJC 9400.00 41.22 256.21 8538.49 8473.03 5977867.56 616965.48 2936.19 5.00 27.81 MWD 9463.89 44.12 258.17 8585.46 8520.00 5977857.31 616923.42 2979.42 5.00 25.22 TJB 9500.00 45.78 259.19 8611.02 8545.56 5977851.90 616898.49 3004.85 5.00 23.78 MWD 9550.45 48.11 260.51 8645.46 8580.00 5977844.84 616862.32 3041.53 5.00 23.06 TJB 9600.00 50.41 261.72 8677.79 8612.33 5977838.46 616825.33 3078.79 5.00 22.16 MWD 9700.00 55.09 263.94 8738.31 8672.85 5977827.33 616746.55 3157.43 5.00 21.37 MWD ') BP ) KW A Planning Report MAP Company: BP Amoco nate: 11/15/2002 Time: 14:07:56 Page: 3 Field: Prudhoe· Bay Co..ordinate(NE) Reference: WeU:· S~28,. True North Site: PBSPad .vertical (TVD) Reference: Plan 65.46~ 65.5 Well: S-28 Section (VS) Reference: Well (0.00N,O.OOE,254. tOAzi) Wellpath: Plan S-28B 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/tOQft .. .. deg 9739.63 56.95 264.75 8760.46 8695.00 5977823.57 616713.91 3189.76 5.00 20.02 MWD 9741.46 56.95 264.75 8761.46 8696.00 5977823.41 616712.38 3191.27 0.00 180.00 TSGR 9759.63 56.95 264.75 8771.37 8705.91 5977821.77 616697.24 3206.24 0.00 180.00 MWD 9775.00 58.33 266.20 8779.59 8714.13 5977820.54 616684.32 3218.97 12.00 41.90 MWD 9800.00 60.61 268.46 8792.29 8726.83 5977819.20 616662.83 3239.92 12.00 41.13 MWD 9823.56 62.80 270.51 8803.46 8738.00 5977818.69 616642.09 3259.92 12.00 39.98 TSHU 9825.00 62.93 270.63 8804.12 8738.66 5977818.68 616640.81 3261. 15 12.00 39.01 MWD 9850.00 65.28 272.70 8815.03 8749.57 5977818.98 616618.33 3282.59 12.00 38.95 MWD 9875.00 67.65 274.70 8825.02 8759.56 5977820.10 616595.44 3304.18 12.00 38.04 MWD 9900.00 70.05 276.63 8834.04 8768.58 5977822.04 616572.21 3325.86 12.00 37.25 MWD 9914.34 71.44 277.71 8838.76 8773.30 5977823.52 616558.75 3338.31 12.00 36.55 MWD 9972.57 71.44 277.71 8857.30 8791.84 5977830.05 616503.95 3388.89 0.00 0.00 MWD 9975.00 71 .46 278.02 8858.07 8792.61 5977830.33 616501.66 3391.00 12.00 86.52 MWD 10000.00 71.67 281.18 8865.98 8800.52 5977833.91 616478.22 3412.41 12.00 86.42 MWD 10025.00 71.94 284.32 8873.79 8808.33 5977838.78 616454.98 3433.24 12.00 85.42 MWD I 10030.40 72.00 285.00 8875.46 8810.00 5977840.00 616450.00 3437.67 12.00 84.44 S-28B TSad 10050.00 73.95 285.17 8881.20 8815.74 5977844.59 616431.83 3453.73 10.00 4.82 MWD 10066.22 75.57 285.31 8885.46 8820.00 5977848.46 616416.67 3467.12 10.00 4.77 TSAD 10100.00 78.94 285.59 8892.91 8827.45 5977856.73 616384.78 3495.26 10.00 4.73 MWD 10150.00 83.92 286.00 8900.36 8834.90 5977869.43 616337.02 3537.32 10.00 4.67 MWD 10200.00 88.90 286.40 8903.49 8838.03 5977882.59 616288.90 3579.57 10.00 4.61 MWD 10210.80 89.98 286.49 8903.60 8838.14 5977885.48 616278.50 3588.70 10.00 4.58 MWD 10278.96 89.98 286.49 8903.62 8838.16 5977903.78 616212.85 3646.26 0.00 0.00 MWD 10300.00 89.65 284.41 8903.69 8838.23 5977909.06 616192.48 3664.22 10.00 260.97 MWD 10350.00 88.87 279.47 8904.33 8838.87 5977918.62 616143.43 3708.42 10.00 260.98 MWD 10400.00 88.10 274.53 8905.66 8840.20 5977923.92 616093.75 3754.45 10.00 261.05 MWD 10445.82 87.40 270.00 8907.46 8842.00 5977925.00 616048.00 3797.94 10.00 261.18 S-28B kwa1 10450.00 87.29 269.78 8907.65 8842.19 5977924.93 616043.82 3801.96 6.00 243.10 MWD 10500.00 85.93 267.09 8910.61 8845.15 5977922.77 615993.97 3850.31 6.00 243.11 MWD 10550.00 84.59 264.40 8914.74 8849.28 5977918.29 615944.35 3899.11 6.00 243.27 MWD 10562.08 84.27 263.75 8915.92 8850.46 5977916.86 615932.41 3910.95 6.00 243.49 MWD 10600.00 84.27 263.75 8919.70 8854.24 5977912.15 615894.98 3948.15 0.00 0.00 MWD 10637.67 84.27 263.75 8923.4 7 8858.01 5977907.48 615857.79 3985.10 0.00 0.00 MWD 10650.00 84.85 264.20 8924.64 8859.18 5977906.00 615845.61 3997.19 6.00 37.22 MWD 10700.00 87.25 266.01 8928.08 8862.62 5977900.95 615795.99 4046.15 6.00 37.17 MWD 10750.00 89.64 267.82 8929.44 8863.98 5977897.47 615746.14 4094.88 6.00 37.05 MWD 10757.45 90.00 268.09 8929.46 8864.00 5977897.09 615738.70 4102.12 6.00 37.00 MWD 10800.00 90.00 268.09 8929.46 8864.00 5977894.99 615696.21 4143.40 0.00 0.00 MWD 10900.00 90.00 268.09 8929.46 8864.00 5977890.07 615596.34 4240.44 0.00 0.00 MWD 10982.45 90.00 268.09 8929.46 8864.00 5977886.00 615514.00 4320.45 0.00 0.00 $-28B kwa3 11000.00 90.00 268.09 8929.46 8864.00 5977885.14 615496.47 4337.4 7 0.00 0.00 MWD 11100.00 90.00 268.09 8929.46 8864.00 5977880.21 615396.60 4434.51 0.00 0.00 MWD 11132.45 90.00 268.09 8929.46 8864.00 5977878.62 615364.19 4466.00 0.00 0.00 MWD 11150.00 91.05 268.09 8929.30 8863.84 5977877.75 615346.66 4483.03 6.00 0.05 MWD /- 11199.48 ( 94}>2 268.09 8927.11 8861.65 5977875.32 615297.30 4530.99 6.00 0.05 MWD 11300.00 ' 94.02 268.09 8920.06 8854.60 5977870.39 615197.16 4628.29 0.00 0.00 MWD 11400.00 94.02 268.09 8913.04 8847.58 5977865.48 615097.54 4725.08 0.00 0.00 MWD 11468.32 94.02 268.09 8908.25 8842.79 5977862.13 615029.48 4791.21 0.00 0.00 MWD 11500.00 92.42 269.12 8906.47 8841.01 5977860.86 614997.87 4821.83 6.00 147.32 MWD 11547.90 90.00 270.67 8905.46 8840.00 5977860.00 614950.00 4867.91 6.00 147.38 $-28B T5a 11550.00 89.87 270.67 8905.46 8840.00 5977860.00 614947.90 4869.92 6.00 179.95 MWD 11600.00 86.87 270.67 8906.88 8841 .42 5977859.78 614897.93 4917.82 6.00 179.95 MWD 11650.00 83.87 270.67 8910.91 8845.45 5977859.58 614848.10 4965.58 6.00 179.95 MWD ) BP ) KW A Planning Report MAP Company: BP Amoco Date: 11/15/2002 Time: 14:07:56 Page: 4 Field: Prudhoe Bay Co,..()rdinate(NE) Reference: Well: 8-28, True North Site: PB S Pad Vertical (TVD)Refercmce: Plan 65.46' 65.5 Well: S-28 Section (VS) Reference: Well·(0.OON,0.00E,254.10Azi) Wellpath: Plan 8-28B 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/tOOft .. deg 11700.00 80.87 270.68 8917.55 8852.09 5977859.37 614798.56 5013.08 6.00 179.95 MWD 11709.19 80.32 270.68 8919.05 8853.59 5977859.33 614789.49 5021.76 6.00 179.95 MWD 11800.00 80.32 270.68 8934.31 8868.85 5977858.97 614699.98 5107.57 0.00 0.00 MWD 11836.57 80.32 270.68 8940.46 8875.00 5977858.82 614663.93 5142.12 0.00 0.00 S-28B Poly A 11900.00 80.32 270.68 8951.12 8885.66 5977858.56 614601.41 5202.05 0.00 0.00 MWD 12000.00 80.32 270.68 8967.93 8902.4 7 5977858.15 614502.84 5296.53 0.00 0.00 MWD 12100.00 80.32 270.68 8984.74 8919.28 5977857.75 614404.28 5391.01 0.00 0.00 MWD 12118.61 80.32 270.68 8987.87 8922.41 5977857.67 614385.93 5408.60 0.00 0.00 MWD 12200.00 84.32 271.44 8998.74 8933.28 5977857.88 614305.30 5485.73 5.00 10.72 MWD 12300.00 89.24 272.36 9004.36 8938.90 5977859.60 614205.51 5580.77 5.00 10.62 MWD 12315.52 90.00 272.50 9004.46 8939.00 5977860.01 614190.00 5595.50 5.00 10.56 8-28B T6b 12400.00 92.13 275.13 9002.89 8937.43 5977864.28 614105.66 5675.01 4.00 51.00 MWD 12500.00 94.64 278.25 8996.99 8931.53 5977874.31 614006.37 5767.16 4.00 51.05 MWD 12514.54 95.00 278.70 8995.77 8930.31 5977876.22 613992.01 5780.35 4.00 51.23 MWD 12600.00 95.00 278.70 8988.32 8922.86 5977887.76 613907.66 5857.77 0.00 0.00 MWD 12700.00 95.00 278.70 8979.61 8914.15 5977901.26 613808.97 5948.35 0.00 0.00 MWD 12800.00 95.00 278.70 8970.89 8905.43 5977914.76 613710.28 6038.92 0.00 0.00 MWD 12900.00 95.00 278.70 8962.18 8896.72 5977928.26 613611.59 6129.50 0.00 0.00 MWD 13000.00 95.00 278.70 8953.46 8888.00 5977941.76 613512.90 6220.08 0.00 0.00 MWD 13100.00 95.00 278.70 8944.75 8879.29 5977955.26 613414.20 6310.66 0.00 0.00 MWD 13200.00 95~ 278.70 8936.03 8870.57 5977968.76 613315.51 6401.24 0.00 0.00 MWD 13289.54 t 278.70 8928.23 8862.77 5977980.84 613227.15 6482.34 0.00 0.00 MWD DATE CHECK NO. p054975 11/18/02 VENDOR DISCOUNT P054975 DATE DESCRIPTION GROSS INVOICE I CREDIT MEMO NET 11/18/02 INV# CK111402P PERMIT TO DRILL FEE ~. A8~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL .... PAY BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 . ANCHORAGE, AK99519-6612 TO THE ORDER OF ALASKAQ III & <GAS CO~S~¡O~ ....... 33 3·W 7'1'IjTA~rNuE. ANCHQRAGE, J\K. 99501 u- 0 5 ... ., ? 5 II- I: 0... ~ 20 j 8 ., 5 I: 0 ~ 2 ? 8 ., b u- ,.,. H -- ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(t), 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). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\j ody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon 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 AfJ)L WELL NAME /I'q ,5- L? A FIELD & POOL t:. '/6). c) ð INIT CLASS /),.-v J ... o. ï ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. . . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . (Service Well Only) 13. Well located wlin area & strata authorized by injection order #_ (Service Well Only) 14. All wells wlin ~ mile area of review identified. . . . . . . . .. ENGINEERING APPR DATE II±- Ii/h APPR DATE ~jGA- ¡IJO/()3 (Service Well Only) GEOLOGY - APPR DATE ø /AA; (EXPlorat6r;"only) Rev: 10/15/02 PROGRAM: Exp _ Dev X Redrll ~ Re-Enter _ Serv _ Wellbore seg _ GEOL AREA >1 'j' /J UNIT# /) ç'< 1""'\ ON/OFF SHORE Y.N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N ~N }{f .ltÁ A, .y N I Y N . -¥-N- 1\1/ It- ~. ~_ N ¡JCJCÐOY $ c¡ tf- ~ N H{¡;f 0"5 . N N/A- i~ MIL<? nl/IJ 1(. > p~ . -¥-N-l\Áj k- 1//, A. RESERVOIR ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . 16. Surface casing protects all known USDWs. . . . . . . . . . . 17. CMT vol adequate to circulate on conductor & surf csg. . . . . 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 19. CMT will cover all known productive horizons. . . . . . . .. . 20. Casing designs adequate for C, T, B & permafrost. . . . . . . 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved. .. 23. Adequate wellbore separation proposed.. . . . . . . . .. . . 24. If diverter required, does it meet regulations. .. . . . . . . . 25. Drilling fluid program schematic & equip list adequate. . . . . 26. BOPEs, do they meet regulation. . . .'. . . . . . . . . . . . 27. BOPE press rating appropriate; testto '35" 00 psig. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. . . . .. . . . . . 30. Is presenceofH2S gas probable.. . . . . . . . . . . . . . . . 31. Mechanical condition of wells within AOR verified. . . . . . . . 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . .. ...... 36. Contact namelphone for weekly progress reports. ...... GEOLOGY: RP~ PETROLEUM ENGINEERING: TEM SFD_ WGA 'v'/ G:\geology\permits\checklist.doc UIC ENGINEER JDH JBR MJW 0,..) ( COMMISSIONER: Commentsllnstructions: COT DTS oj T3(0 5 MLB Þ"//Ø/Ø~