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Home My WebLink About201-107STATE OF ALASKA y~~~ S ALASK~L AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~EGEiVED MAR 4 7 2008 C)ii ~ Gas Cans. Commission 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoa+c zs.,os zoAAC za„o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1b. Well Class:h~iC ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban 02/12/2008 12. Permit to Drill Number 201-107 ~ 307-363 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 06/14/2001 13. API Number 50-029-22585-01-00- 4a. Location of Well (Governmental Section): Surface: 16 ' ' S 7. Date T.D. Reached 06/18/2001 14. Well Name and Number: PBU 18-32A 47 FNL, 41 FEL, EC. 24, T11N, R14E, UM Top of Productive Horizon: 1196' FNL, 4044' FWL, SEC. 19, T11 N, R14E, UM 8. KB (ft above MSL): 54' ' Ground (ft MSL): 16.2' 15. Field /Pool(s): ~ Prudhoe Bay Field / Prudhoe Bay Total Depth: 788' FNL, 427' FWL, SEC. 20, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 11535 8680 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 691737 y- 5960219 Zone- ASP4 10. Total Depth (MD+TVD) 11601 - 8681 - 16. Property Designation: ADL 028321- TPI: x- 695809 y_ 5960777 Zone- ASP4 Total Depth: x- 697134 y- 5961219 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit el ctronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD GR & Memory GR / CNL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP- BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 110' Surface 110' 30" 260 sx Arctic Set A rox. 10-3/4" 45.5# NT-80 Surface 3830' Surface 3707' 13-1 /2" 1283 sx PF 'E 212 sx Class 'G' 7-5/8" 29.7# USS-95 Surface 9223' Surface 8226' 9-7/8" 295 sx Class' ' 5-1/2" x 4-1/2" 17# / 12.6# L-80 8916' 9688' 7975' 8565' 6-3/4" 220 sx Class' ' s-,rz" x 33116" x 2-7/8" 9.3# / 6.2# / 6.,6# L-80 9272' 11600' 3845' 7963' 3-3/4" 82 sx Class 'G' 4-1/2" 12.6# 13Cr80 3996' 8902' 3845' 7963' Scab Lnr 774 sx Class'G' 23. Open to production or inject ion? ^ Yes ®No 24.' TueING RECOao If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER .SET MD 4-1/2", 12.6#, 13Cr80 4001' 3920' MD TVD MD TVD 25. ACID,:FRACTURE, CEMENT SQUEEZE, ETC. ~y~g ~~'~~~~ {{yy((~~Q ~~~E~GO~l~i~' ARR ~ ~ Ztl{,~~ DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 9240' Set Whipstock 26. r _ _ PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac uired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize Iithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC-2~0„n07e1., vlliVf i~3 ^91L~1'1 None Form 10-407 Revised 02/2007 ~J CONTINUED ON REVERSE SIDE z ~ ~ ~ ~ 1 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 9188' 8198' None Shublik 9230' 8232' Sadlerochit 9296' 8284' Zone 1 9922' 8653' Zone 1 A 10020' 8680' Formation at Total Depth (Name): 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~ /O~ ~j Signed Terrie Hubbl Title Drilling Technologist Date PBU 18-32A 201-107 307-363 Prepared ByNameMumber. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Greg Sarber, 564-4330 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only • 18-32B Well History Date Summary 1/16/2008 RIH with 2.75" JSN. No obvious bobbles were seen in wellbore. Tag at 9232' ctm. Well was supprting a full column of fluid while RIH to tag depth. Pickup to slickline tag area and wash tubing and lining with 1% XS KCI and wash down to hard bottom tag at 9232 using 320 bbls of 1 % xs KCI and 50 bbls of 2ppb Biozan. While chasing last sweep out of hole, triplex pump failed with final 2 Biozan sweeps still in tubing. Utilize LRS to freeze protect CT while POOH. Counter was -37' when tagged up. Makeup BHA #2 with 3.5" DJN. RIH and tag at 9220' ctmd. Job Continued. 1/16/2008 Assist CTU# 8 pump as directed- Pumped 44 bbls of 60/40 mth/wtr to freeze protect the coil and all surface lines, RDMO 1/17/2008 Confirm tag C~ 9220' ctmd. Jet down to 9230' ctmd. Wait for 50 bbls biozan. Circulate bottoms up. Tag ~ 9227' ctmd. Begin jetting with biozan. Jet down to 9250' ctmd. Repeated Hard Tag. POOH C~3 80%. pumping 1 % XS KCL w/0.6% safelube. Makeup Baker BHA with slickline GS running tool pinned for 5k shear down and 3.68" x 20' dummy whipstock. RIH past top of liner top packer to 4050'. PUH and pulled 10k over string weight then pulled free. RIH and tag at 8908' ctm. Set down 5k from string weight with no success. POOH. Job in progress. 1/18/2008 WELL SHUT IN ON ARRIVAL. T/I/O 0/0/0. RU ELINE FOR GR/CCL/JB RUN PRIOR TO WHIPSTOCK SET. TAG TD 9260'. RU WHIPSTOCK. 1/18/2008 RIH with dummy whipstock. Work through tight spot C~ 8911' (1500# - 3000# down weight). Tag C~3 9250' ctmd. PUH through tight spot at 8912' with 1 k overpull. RBIH with 500# set down. POOH with no further overpulls. Freeze protect well with 60140 methanol. Notify DSO of well status. RDMO. Job Complete. 1/19/2008 WELL SHUT IN ON ARRIVAL. T/I/O 0/0/0. RU ELINE FOR GR/CCL/JB RUN PRIOR TO WHIPSTOCK SET. TAG TD 9260'. 3.65" WHIPSTOCK STUCK IN XO AT 8903' -BOTTOM OF TOOL AT 8909', TOP 8875'. UNABLE TO WORK FREE- TOOL ELECTRONICALLY RELEASED. FISH LEFT IN HOLE: BOTTOM HALF OF ERS/WPMOT/WPTET/WPGRT/WPSA/BAKER 10 SETTING TOOU 3.65" BAKER WHIPSTOCK WITH 2 PIP TAGS 8.6 FT FROM TOP. TOTAL LENGTH 40', MAX OD 3.65", 580 LBS. JOB INCOMPLETE. 1/19/2008 WELL SI ON ARRIVAL. RIG SURFACE EQUIP & EXTRA RISER. PT SURFACE EQUIP. JOB IN PROGRESS. 1/20/2008 FISHED 38' E-LINE TOOLSTRING & WHIPSTOCK FROM 8855' SLM. RDMO. WELL LEFT SI, DSO NOTIFIED OF WELL STATUS. 1/21/2008 T/IA/OA =114PS1/0/0 Set 4 1/16" CIW "H" BPV {Pre- Rig for Nordic 1}Did set 4 1/16" CIW "H" BPV X96", no problems. 1/31/2008 T/I/0=10/0/0. Pulled 4 1/16 CIW "H" BPV. Set for Pre Rig -Repulled for coil. 1-2' ext ~ 96". No Problems. 2/1/2008 Thaw tree and surface lines. Conduct weekly BOPE test-good test - MU/RIH w/ 3.625" Jet Junk Basket, Icy/slushy from surface to 280'. Continue RIH pumping 1 % XSKCL w/ 0.6% Safelube making passes across all jewelry. No problems observed at top or bottom of scab liner. Run junk basket to 9125'.. Drv taq TD ~ 9228' CTM-up. Flag CT ~ 9208'. Make repeat pass to 8880'. Pump 10 bbl Geovis sweep just off TD, Chase out ~ 80%, making slow passes across jewelry and top/bottom of scab liner. FP wellbore from 500'. Continued. 2/2/2008 MU Baker jars, 2 7/8" motor, 3.78" string mill, 3.78" parabolic DSM. Mill from 275' into hole. Make slow passes across jewelry. Saw slight blips ~ nipples C~3 drillers 3900' & 3944'. Make 2 round trip repeat passes. Dry drift up/down OK. Continue milling to 9241', 16' past our flag. Make repeat pass to 8800 and back to 9241'. Pump 2 - 20 bbl Geovis sweeps. Chase out ~ 80%. Slight blips at 3944', 3900', 2999', 2019'. on trip OOH - FP well to 2500' - Biow coil down with N2 for pipe swap. Job Complete. RDMO. 2/10/2008 R/U SLICKLINE & RISERS FOR DRIFTS. CURRENTLY PERFORMING P/T ON LUBRICATOR. CONTINUED. Page 1 of 2 18-32B Well History Date Summary 2/11/2008 DRIFT W/ 3.65" BAKER WHIPSTOCK (19.6' OAL) TO BKR KB PKR @ 9238' SLM (1150# P/U WEIGHT ON BTM) NO ISSUES PUH. DRIFT W/ 3.875" G-RING TO SVN ~ 2000' SLM, NO ISSUES. ATTEMPT TO DRIFT W/ BAKER FLUTED DRIFT 3.65" BODY, 3.9" FINS, 23' OAL, UNABLE TO PASS 95' SLM. WELL S/I ON DEPARTURE, DSO NOTIFIED. 2/12/2008 WELL SHUT IN ON ARRIVAL INITIAL WHP: T/I/O = 0/0/0 RAN SCMT LOG TO OBTAIN PBTD, CONDITION AND TOP OF CEMENT IN IA. TAGGED TD AT 9260', FOUND TOP OF CEMENT IN IA AT 4008' DEPTH CORRECTED TO GEOLOGIST PDC LOG SCANNED INTO JOB PACKET. USED GR TO CORRELATE NEAR 9200'. SET TOP OF BAKER 3.63" WHIPSTOCK AT 9240' WITH AN ORIENTATION OF 0.5 DEGREES RIGHT OF HIGHSIDE LOOKIN D IGHT TO CONFIRM WHIPSTOCK SETTING. SONIC LOG INDICATES COLLARS AT 9215' AND 9255' IN 4.5" LINER. JOB COMPLETE. 2/12/2008 DRIFTED TO SSSV NIPPLE AT 2019'MD W/ 3.835" BAKER FLUTED SUB DRIFT.(OAL 13-1/2'). LEFT WELL SHUT IN PAD OP NOTIFIED. 2/14/2008 Set 4 1/16" CIW H BPV pre-rig for Nordic 1. Tagged ~ 100", well was on a vacuum, no problems. Page 2 of 2 TREE= 4-1/8" SM CAN WELLHEAD= FMG ACTUATOR = BAKER C KB. ELEV = 54.0' BF. ELE1/ KOP = _ _ 2607 Max Angle = 99 @ 10257' Datum MD = N/A Datum ND = 8800' SS ~ 10-3/4" CSG, 45.5#, L-80, ID = 9.953' ~ .. ~,e ~ NOTES: OPEN SLTD LNR BELOW PflS~ CTD SI{~fltl"~CIt WHIPSTOCK PKR~ 9704'. WELL EXCEEDS 70° ~ 9806' AND GOES HORIZONTAL ~ 10201'. GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 1 2 3 3900' 4-1i2" HES 9Cr X -Nipple, ID=3.813 3920' 7-518" X4-1/2" BAKER S PKR, 9Cr, 3J44' 4-1/2" f~ES 9Cr X-~lipp{e, 3.813" {d TOPOF 5-1/2" LNR 8921' 8976' 7-5/8" X 5-112" TNV LINER HGR PKR, ID = 4.880" 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892' 8923' " ' TOP OF 4-1/2" LNR 8923' XO, ID = 3.958 8923' S-1 /2" X 4-1/2 $g3$' Top of 3-1/2" Liner. TOC TOPOFCEM $940' i $949' 3-112" XN NIP, ID = 2.75" 7-5/8" LNR, 29.7#, S-95, .0459 bpf, ID = 6.875" 9223' 9240° Mechanical Whipstock 10204' 3-3116 x 2-718 X-over ~s as 3-3/16" X 2-7/8" cnfed & perfed 12375' - -- 9272' 4-1/2" BKR KB PKR, ID = 2.39" 9277' 3-3/4" BKR DEPLOYMENT SLV, ID = 3.00" 9318' 3-1 /2" X 3-3/16' XO, ID = 2.80' PERFORATION SUMMARY 9689' TOPOF BKR WHIPSTOCK REF LOG: Z-Den ON 09/25/95 ANGLE AT TOP PERF: 91 ~ 10500' Note: Refer to Production DB for historical perf data 9704" TOP OF BKR WHIPSTOCK PKR S¢E SPF INTERVAL Opn/Sqz DATE I I ID = 2 37" 9765' 3-3/16" X 2-7/8" XO 2" " 6 10500 - 11200 O 06/21 /01 06/21/01 I I , . I I 11232' HES CIBP, 05/26/02 2 6 11250 - 11530 O I I I I 4-1 /2" MILLOUT WINDOW I I PBTD 11535' 9687' - 9696' I I 4-1/2" LN R, 12.6 , L-80, .0152 bpf, ID= 3. 958" 11095° 2-7/8" LNR, 6.16>f, L-80, 11601° STL, .0058 bpf, ID = 2.37" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/03!95 OR{GINAL COMPLETION 02/27/08 BL Post FEB 2008 Sidetrack 06/26/01 CH/TP CTDSIDETRACK 04/04/02 JKB/KK PERF CORRECTIONS 05/26/02 DDW/tlh SET CIBP 06/15/03 CMOITLP KB ELEVATK)N CORRECTION 05/17/06 JGM./PJC WRP ~ 8865' PRUDHOE BAY UNff WELL: 18-32A PERMR No: 2011070 API No: 50-029-22585-00 SEC 24, T11 N, R14E, 3632' NSL 8~ 41' WEL BP Exploration (Alaska) 02/20/08 ~chlgmber~g~r NO. 4590 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth CC~~ 333 West 7th Ave, Suite 100 ~~~~~~ ~~U ~ ~ 2.00 Anchorage, AK 99501 Field: P:Bay,Milne Pt,Endicott,Borealis,Polaris,Lisburne Well Job # Loa Description Date BL Coler CD 18-32A 11968923 SCMT / - ~ 02/12/08 1 MPE-12 11978438 MEM INJ PROFILE iJZC' oDU~ - C}(o 02/08108 1 4-14/R-34 11996383 USIT ~ 02/12/08 1 V-07 40016096 OH MWD/LWD EDIT "3 - G j L(c 12/04/07 2 1 L1.14 11626482 RST ~ r- / / S'"9~/3 05/09/07 1 1 L2-18A 11657124 RST G 05/10/07 1 1 L2-33 11626484 RST j (p - j 'nj G ~ 05/11/07 1 1 G-31A 11962778 RST - vS ~/ ~~ 01/01/08 1 1 V-111 11978439 MEM GLS ~ ~ 02/10/08 1 W-216 12031441 CH EDIT PDC GR (USIT) g 01111/08 1 W-214 40016055 OH MWD/LWD EDIT V=, _ ( 11/15/07 2 1 Y-07A 11962576 USIT ~ 12/18/07 1 C-35B 11978432 _ MEM DDL _ / 01/02/08 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNI,I~G O E,COPY EACH TO: BP Ex /oration Alaska Inc. ~ ~ ~ ~ "~ p ( ) ~' €~..~, ~. ~' Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~ ,i..~+~ a , ._ ,.,L~.p Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Received by: I 1, ~J • /~ • STATE OF ALASKA ~ „p~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPE~TIONS JAN 2 5 ~(a~s 1. Operations Performed: a 8S 8 I eS Ot1S. '~ :,.: , ;~'~ ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-i[B~nded Well ^ Alter Casing ®Pull Tubing ' ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 201-107 ~ 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22585-01-00 _ 7. KB Elevation (ft): 54, ~ 9. Well Name and Number: PBU 18-32A 8. Property Designation: 10. Field /Pool(s): ADL 028321 ' Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11601 'feet true vertical 8681 ~ feet Plugs (measured) 11232 Effective depth: measured 11535 feet Junk (measured) None true vertical 8680 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3830' 10-314" 3830' 3707' 5210 2480 Intermediate 9223' 7-5/8" 9223' 8226' 8180 5120 Production Liner 772' 5-1/2" x 4-1 /2" 8916' - 9688' 7975' - 8565' 7740 6280 Liner 2328' 3-112" x 3-3/16" x 2-7/8" g272' - 11600' 8265' - 8681' 10160 10530 Scab Liner 4906' 4-1/2", 12.6#, 13Cr80 3996' - 8902' 3845' - 7963' 8430 7500 Perforation Depth MD (ft): 10500' - 11530' ~( , v~~ FED ~ ~ 200 ~, Perforation Depth TVD (ft): 8695' - 8680' 4-1/2", 12.6# 13Cr80 4001' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7-5/8" x 4-1/2" Baker'S' packer 3920' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut & Pull tubing, Run 4-1/2" Scab Liner, cement with 160 Bbls Class'G' (898 cu ft or 774 sx), Run new Chrome Completion. 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing. is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West,. 564-5471 307-349 Printed Name Sondra Stewm n Title Drilling Technologist .--- //~~ II ~~// Prepared By Name/Number: -U 1 ~ t Sig tune Phone 564-4330 Date V QSondra Stewman, 564-4750 i Form 10-404 Revised 04/2006 - a..~i~t Submit Original Only TREE = 4-1/8" 5M CNV WELLHEAD = FMC ACTUATOR = - -- BAKER C KB. ELEV = 54.0' BF. ELEV... KOP = 2607 Max Angle = 99 @ 1025T Datum MD = N/A -- Datum TVD = - . . 8800' SS ~ QTY NOTES: OPEN SLTD LNR BELOW WHIPSTOCK PKR @ 9704'. WELL IXCEEDS 70° @ R ; ~ !, ~ 9806' AND GOES HORIZONTAL @ 10201'. ~' ~' y 2007 RWO = 4-1/2" CHROM E TBG 8 SCAB LNR 24'19' -~ 4-1/2 "HES 9Cr X- NIP, ID = 3.813° GAS LIFT MANDRELS - MD TVD DEV TYPE VLV LATCH PORT DATE 4-1?2" TBG, 12.6#, 13CR80: ID = 3.958" ~~ 01 4-112" SCAB LNR, 12.6#: 13Cr-80 11 $902' f TOP OF 5-1/2" LNR 8921' 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" 8923' TOP OF4-1/2" LNR 8923' 7-5/8" LNR, 29.7#, S-95, .0459 bpf, ID = 6.875" 9223' PERFORATION SUMMARY REF LOG: Z-Den ON 09/25/95 ANGLE AT TOP PERF: 91 @ 10500' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2" 6 10500 - 11200 O 06/21 /01 2" 6 11250 - 11530 O 06/21 /01 4-1 /2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I--I 11095' 3996' I-i 5-112°` X 7-518" BKR LNR TOP PKR w,'HNGR, ]D = 4.850" $898' 5-1/2" X 4-1/2" XO, ID = 3.958"? $902` 5-1/2" mule shoe 8916' 7-5/8" X 5-1/2" TN11 LINER HGR PKR, ID = 4.880" 8923' 5-1/2" X 4-112" XO, ID = 3.958" 9272' 4-1/2" BKR KB PKR, ID = 2.39" 9277' 3-3/4" BKR DEPLOYMENT SLV, ID = 3.00" 9318' 3-1/2" X 3-3/16" XO, ID = 2.80" 9689' TOP OF BKR WHIPSTOCK 9704' TOP OF BKR WHIPSTOCK PKR 9765' 3-3/16" X 2-7/8" XO, ID = 2.37" 11232' HES CIBP, 05/26/02 4-1/2" MILLOUT WINDOW PBTD 11535 9687' - 9696' 2-7/8" LNR, 6.16#, L-80, 11601' STL, .0058 bpf, ID = 2.37" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/03/95 ORIGINAL COMPLETION 12/28/07 NOES RWO 06/26/01 CH/TP CTD SIDETRACK 01/01/08 /TLH CORRECTIONS 04/04/02 JKB/KK PERF CORRECTIONS 010/15 CJWPJC GLV GO (01/03/08) 05/26/02 DDW/tlh SET CIBP 06/15/03 CMO/TLP KB ELEVATION CORRECTION 05/17/06 JGM./PJC WRP@ 8865' PRUDHOE BAY UNff WELL: 18-32A PERMIT No: 2011070 API No: 50-029-22585-00 SEC 24, T11 N, R14E, 3632' NSL & 41' WEL BP Exploration (Alaska) Digital Well File ~ ~ Page 1 of 1 Well: 18-32 Well History Well Date Summary 18-32A 11/24/2007 T/IA/OA= SSV/760/400 Temp=Sl PPPOT-T (PASS) PPPOT-IC (PASS) (PRE RWO) PPPOT-T RU 2 HP bleed tools onto THA 1500 psi to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bleed void to 0 psi, RD test equipment. Cycle and torque LDS "ET style" all functioned no problems. PPPOT-IC RU 2 HP bleed tools onto IC test void 500 psi to 0 psi. Pressured to 3500 psi for 30 minute test, 3450/ 15 minutes, 3450/ 30 minutes. Bleed IC void to 0 psi, RD test equipment. Cycle and torque LDS " ETstyle" all functioned no problems. 18-32A 12/4/2007 "'WELL SHUT IN ON ARRIVAL*'* T/I/0=520/780/360. 3.65" POWERCUTTER RUN TO CUT 4 1/2" TUBING AT 8847 FT 3 FEET ABOVE THE TOP OF THE S-3 PACKER IN THE 4 1/2" PU OG CORRELATED T BING TALLY DATED 02-OCT-1995. WELL LEFT SHUT IN. T/I/0=550/740/350. ***JOB COMPLETED*** 18-32A 12/6/2007 T/I/O = 600/750/300 *** Circ Out*** (Pre RWO) Pumped a 5 bbl neat methanol spear followed by 300 bbls of 9.2# brine into the tubing taking returns up the IA through the jumper loop to the casasco valve down the flow line. Swap over to the IA and bull head 2 bbls of neat methanol followed by 252 bbls of 9.2 brine into the IA through the PC leak. Freeze protected T/IA with 91 bbls diesel U-tubed T/IA for 1 hr. Freeze protected Flowline with 5 bbls neat meth, 5 bbls diesel. Unable to bleed T/IA pressures to 0 psi. MIT-OA to 2000 psi postponed till later date due to space issues in cellar. Final WHPs 320/420/340 ( IA/OA casing valves open to gauges and tagged, swab shut needle valve open to gauge at time of departure) 18-32A 12/7/2007 T/I/O=SSV/120/360. Temp=Sl. WHP's. (Pre RWO). BPV in TBG for well work. IA & OA FL's C~ Surface. Flow line & wellhouse are removed. Swab platform is still on the wellhead but there are no hand rails. 18-32A 12/7/2007 Set 4" CIW BPV 18-32A 12/8/2007 T/I/0=0/320/340 MIT OA to 2000 psi (Pre RWO) MI, RU to OA. ****Continued on 12-09-07 WSR**** 18-32A 12/9/2007 ****Continued from 12-08-07 WSR**** MIT OA to 2000 si ***FAIL*** (Pre RWO) Pressured up OA to 1000 psi w/5 bbls crude. OAP stable at 1000 psi or 15 b s. onitor pressure. OA lost 480 psi in 75 min. Pumped 20 bbls 100* crude at 2 bbls min. OAP stable at 1100 psi while pumping. SD Monitor pressure. OA lost 560 psi in 75 min. Attempt to bleed OAP. FWP=0/320/360 ***Casing valves open to gages.*** 18-32A 12/9/2007 T/I/O = 0/320/360 Temp = SI. Monitor WHP's (CTD). IAP increased 200 psi, OAP unchanged since 12-7- 07. IA & OA FL C~3 surface. Bled OAP to slop trailer from 360 psi to 320 psi in 40 mins (all fluid no gas, bleed trailer @ max cap). Bled back 220 gallons fluid. OA pressure is not decreasing as expected, Bled IAP to slop trailer from 320 psi to 240 psi in 50 mins (all fluid no gas, bleed trailer @ max cap). Bled back 482 gallons fluid. Monitor for 1 Hr. IAP increased 30 psi. OAP increased 30 psi. FWHP's = 0/270/350. Note: Well support on location to pull BPV. 18-32A 12/9/2007 Pull 4" CIW BPV 18-32A 12/10/2007 T/I/O = 180/160/340 Temp = S/I -Load and Kill TBG, IA, and OA (RWO prep) -Loaded TBG w/5 bbls 10* meth followed by 200 bbls 80* 9.8# brine and 8 bbls 30* diesel for freeze protect. Loaded IA w/5 bbls 10* meth followed by 210 bbls 80* 9.8# brine and 13 bbls 30* diesel for freeze protect. Loaded OA w/5 bbls 10* meth followed by 127 bbls 80* 9.8# brine and 20 bbls 30* diesel for freeze protect. Bled back - 5 bbls on OA to bring pressure down from 450 psi to 300 psi. Monitiored for 1 hr pressure fell to 20 psi and down to 0 psi at departure. Tagged wing, IA and OA valve with amt pumped in each. Wing SI at departure, with all other casing valves open to gauges. FWHP's= 0/0/0 Print Date: 1/24/2008 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx Page 1 of 1 1/24/2008 • • BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: 18-32 Common Well Name: 18-32 Spud Date: 9/9/1995 Event Name: WORKOVER Start: 12/10/2007 End: 12/28/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/28/2007 Rig Name: NABORS 4ES Rig Number: Date 'From - To Hours ~I Task ' Code NPT 12/10/2007 121:00 - 00:00 3.00 RIGD N WAIT 12/11/2007 ~ 00:00 - 10:30 ~ 10.50 ~ RIGD ~ N ~ WAIT 10:30 - 13:00 2.50 RIGD N 13:00 - 00:00 11.00 MOB N 12/12/2007 00:00 - 09:00 9.00 MOB 09:00 - 13:30 13:30 - 23:00 23:00 - 00:00 12/13/2007 00:00 - 02:00 02:00 - 04:00 04:00 - 06:00 4.501 MOB 9.50 MOB 1.00 MOB 2.00 MOB P 2.00 MOB P 2.00 RIGU P 06:00 - 09:15 09:15 - 09:30 09:30 - 11:30 3.25 KILL P 0.25 KILL P 2.00 KILL P 11:30 - 12:00 0.50 KILL P 12:00 - 12:30 0.50 WHSUR P 12:30 - 13:00 0.50 WHSUR P 13:00 - 15:30 2.50 WHSUR P 15:30 - 19:30 4.00 BOPSU P 19:30 - 00:00 12/14/2007 00:00 - 01:00 01:00 - 02:30 4.501 BOPSUFIP 1.00 BOPSU~P 1.50 BOPSU P Phase Description of Operations PRE Wait on wind. Rig on stand by. Wind gusting to 43 MPH. Not safe to lower /lay over derrick. Wind is from the direction that would create a side loading effect, should the derrick be laid over PRE Wind still gusting to 37 mph. Wind is from the direction that would create a side loading effect, should the derrick be laid over. PRE PJSM. Rig down rig and rig components, scope down and lay over derrick. PRE Move rig and components from MPF pad to GPB DS #18. PRE Continue moving rig and components from MPF Pad to GPB DS #18. PRE Rig sub base sustained two damaged tires which required replacing. PRE Recommence moving to DS18-32. PRE Spot in rig & components over well. PRE Con't to spot Rig Sub, Pipe Shed & Pit modules. R/U equip. PRE Raise & Scope up derrick. Con't R/U equip DECOMP Spot in tiger tank & R/U lines. R/U lines to tree. Call DSM to pill BPV. Take on 9.8 ppg brine. ACCEPTED RIG rs. DECOMP P/T rig circulating lines to 3500-psi and return line to 120-psi with rig air to Tiger Tank. Steam out return line to Tiger Tank to heat up hammer unions and retighten same to provide 100% integrity of all connections. DECOMP PJSM -Reviewed well kill procedure with crew and assigned specific tasks to individuals and ensured all were clear in their job tasks. DECOMP Recorded T/I/O = 0/ONacuum. Opened well to Super Choke. Opened Super Choke to Micro-Motion flow meter and to Tiger Tank. Initialized circulation rate at 2.0-BPM Q 300-PSI. Increased circulation rate to 4.0-BPM C~3 500-PSI. Circulated surface to surface volume of 367-Bbls. + overdisplacement of 40-Bbls. Fluid in C~ 9.8-ppg =fluid out @ 9.8-ppg. Took all returns to Tiger Tank and hauled all returns for disposal at Pad 3. DECOMP Monitor well for 30-minutes. T/I/O = 0/0/0. DECOMP FMC wellhead technician d rod set TWC. DECOMP P/T TWC to 3500-PSI from above for 10 charted minutes. Bullhead into well to PIT TWC from below @ 4.0-BPM C~3 900-PSI. Charted test. DECOMP Blow down and rig down circulating lines. Nipple down Tree and adapter flange. Inspect tubing hanger top threads. Make up 4-1/2" IF x 4-1/2" NSCT into tubing hanger top threads to verify thread integrity. Thread make up of ccrossover is loose. Will use 4-1/2" double grapple spear to unland tubing hanger. DECOMP Clean up tubing spool flange and ring groove. Nipple up BOPE. Notified AOGCC of BOPE test. John Crisp waived state's right to witness testing. DECOMP PJSM.MU test jts & test all BPOE compoents & choke valve per AOGCC , LP 250 psi. HP 3500 psi., rams tested with 3 1/2" and 4 1 /2 " test jts. DECOMP Con't BOPE test & set back kelly. DECOMP PU lubricator & tested to 500 psi ,TWC pulled by DSM, L/D Printed: 1/14/2008 8:46:48 AM • • BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: 18-32 Common Well Name: 18-32 Spud Date: 9/9/1995 Event Name: WORKOVER Start: 12/10/2007 End: 12/28/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/28/2007 Rig Name: NABORS 4ES Rig Number: Date ~ From - To Hours I Task j Code ! NPT Phase Description of Operations 12/14/2007 01:00 - 02:30 1.50 BOPSUf~ P DECOMP 02:30 - 04:30 2.00 PULL P DECOMP 04:30 - 06:30 2.00 PULL P DECOMP 06:30 - 17:30 11.00 PULL P DECOMP 17:30 - 19:00 ~ 1.50 ~ PULL P ~ ~ DECOMP 19:00 - 20:30 1.50 PULL P DECOMP 20:30 - 21:00 0.50 PULL P DECOMP 21:00 - 22:00 1.00 PULL P DECOMP 22:00 - 00:00 2.00 PULL P DECOMP 12/15/2007 00:00 - 01:30 1.50 FISH P DECOMP 01:30 - 04:30 3.00 FISH N RREP DECOMP 04:30 - 09:30 5.00 FISH P DECOMP 09:30 - 12:15 ~ 2.75 ~ FISH ~ P ~ ~ DECOMP 12:15 - 14:00 I 1.751 FISH I P I I DECOMP 14:00 - 18:00 4.00 ~ FISH ~ P ~ ~ DECOMP 18:00 - 19:00 I 1.001 FISH I P I I DECOMP 19:00 - 00:00 I 5.001 FISH I P I I DECOMP 112/16/2007 100:00 - 07:00 I 7.001 FISH I P I I DECOMP lubricator PJSM with Baker, PU & MU spear, engage spear in hanger. BOLDS, P/U & pull free 150k and wt dropped off to 125k. Pull tbg hanger to floor w/ 120K and L/D spear & tbg hanger. CBU 4 bpm C~ 200 psi 24 bph losses. Lost 47-Bbls. during CBU for an average of 31-BPH losses. Rig down and blow down circulating lines. POH laying down 4-1/2" tubing 1x1 through pipe shed using double steel displacement for well control. Out of hole w/52 jts. and laid down HES Series 10 TRSV @ 11:00-hrs. Control line coming out of hole balled up and losing stainless steel bands. Had to pull control line with tugger while pulling tubing to get control line pulled. Recovered 17 of 32 stainless steel bands. Continue POH laying down 4-1/2" tubing. Beginning with joint #149, heavy scale deposition, sever corrosion and holes in tubing began to present themselves and continued on to joint #162. below joint #162, scale and corrosion disappeared. Jt. #182 layed down at 16:45-hrs. Losses to well averaging 3.3-BPH. PJSM con't POH la in down 4-1/2" tbg with sever corrosion pitting and scale. Recovered 209 jts4 1/2" tbg, 3 GL Assys, ! SSSV assy + 7.45" cut-off jt. Now have 2.19' tubing stub above packer. Clean rig floor, load pipe shed with 3-1/2" DP, R/U to P/U DP. Install short bowl protecter. PJSM with Baker, P/U and M/U BHA #2 . 6-3/4" Mill, 3 boot bskt, bumper & oil jars, 9 ea 4-3/4" and pump out sub. TL = 315.16'. P/U 3-1/2" DP from pipe shed &RIH Con't P/U 3-1/2" DP and RIH w/BHA #2 Make rig repairs to skate, hydraulics had bad swtch. Con't P/U 3-1/2" DP and RIH w/BHA #2. 180 jts. DP RIH 08:15-hrs. Stop RIH w/BHA at 7130'. Pipe sticking w/56K overpull while working pipe. Worked pipe and circulated hole ~ 4-5 BPM @ 1000-PSI. Mixed and pumped 30-Bbl. Flo-Vis sweep ~ 4-5 BPM C~3 1000-PSI. Recovered minimal amount of scale across shaker. Pipe was free after started circulating. Con't P/U 3-1/2" DP and RIH w/BHA #2. Tag up solid w/20K downweight on top of fill C~? 8710'._ Kelly up. establish milling parameters: PUW = 152K, SOW = 106K, 40-RPM, 4500-ft/Ibs. tork, 4-5 BPM C~ 1100-PSI. Mill soft fill down to top of tubing stub ~ 8841' DPM._ Pump Hi-Vis sweep to clean up hole prior to milling packer. Mill from 8841' to 8843' DPM PJSM w/ BAKER, Work pipe & pump 30 bbl HI-VIS sweep around, 5 blm Q 1090 psi at 8843' Recovered sand & scale. Mill on PKR ~ 8843' to 8845' PUW = 155 K, SOW = 104 k, FRW = 125 K, WOB = 5-12K, RPM = 60-75, T0=4500-7500 Wlb. 5 bpm ~ 1000 psi. Pump 30 bbl HI-VIS sweeps around Con't Mill on PKR F/ 8845' to 8846', PUW=155k,FRW=125k,SOW=104k,RPM=60-70, W0B=5-12k,T0=4500-7500 fUlb,5 BPMC~1000 psi,4 Printed: 1/14/2008 8:46:45 AM ~ • BP EXPLORATION Page 3 of 10 Operations Summary Report ', Legal Well Name: 18-32 , 'Common Well Name: 18-32 Spud Date: 9/9/1995 Event Name: WORKOVER Start: 12/10/2007 End: 12/28/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/28/2007 Rig Name: NABOBS 4ES Rig Number: Date From - To Hours Task !Code I! NPT i Phase Description of Operations 12/16/2007 00:00 - 07:00 7.00 FISH P DECOMP BPMC~700psi. Unable to gain any footage past 8846'. Losses = 0-Bbls. 07:00 - 08:00 1.00 FISH P DECOMP Set back and blow down kelly and lines. POH L/D 6 jt.s DP. During crew changeout a hydraulic leveling jack on the sub base was noted to be leaking. Decision to repair leak was made and in order to repair leak it is necessary to remove weight of drill string from sub base. Ordered out 7-5/8" Halco storm packer to hang off drill string and repair leak. Prior to hanging off drill string on storm packer, it was noted that a 2.0-Bbl. pit gain was occurring from the well flowing 9.6-ppg brine up the annulus. Weighed brine in pits and found that pit #2 has 9.7-ppg brine and pit #3 has 9.8-ppg brine. Conferred with RWO engineer and made decision to swap hole and pits to clean 9.8-ppg brine at opportune time. ' 08:00 - 08:30 0.50 FISH P DECOMP PUMU RIH w/7-5/8" Halco storm packer. Set packer at -15' below wellhead and hap off drill strip .Left packer landing joint with closed TIW valve attached to packer. 08:30 - 10:45 2.25 FISH N RREP DECOMP Repair rig sub base leveling jack. Further conference with RWO engineer led to decision to resume milling on packer to ensure that adequate work has been done to positively remove packer sealing element and lower packer slips. POH L/D 10:45 - 18:30 7.75 FISH P DECOMP RIH w/6 jts. from pipe shed. Kelly up. Establish milling parameters: PUW = 155K, SOW = 104K, ROT Wt. = 125K, Free TO. = 4000-ft/Ibs., 4.0-BPM ~ 600-PSI. Brine returns coming back C~3 9.4-ppg to 9.6-ppg with small amount of scale and metal cuttings. Con't to mill Packer from 8846' to 8847' 18:30 - 19:30 1.00 FISH P DECOMP PJSM Set back kelly, POH 6 jts. to 8637' work over pull 25-35k, 19:30 - 22:00 2.50 FISH P DECOMP Shut in well, for 60 min. observe pressures. DP= 50 psi. ANN.=70 psi. Return MW= 9.4- ppg. Bleed off pressure & circulate, 9.4 ppg. in, con't till 9.4- ppg. out ~ 3700 total stks, had to ship +/- 10 bbl. of 9.1-ppg brine to tiger tk. 3 bpm 370 psi. Discussed w/ town engineers & AOGCC (John Crisp ) of desire to obtain shut in pressure & slow pump rate. SPR 320 psi C~? 51 SPM. 22:00 - 00:00 2.00 FISH P DECOMP RIH to 8847' no fill ,Disp. well with 290 bbl. 9.8- ppg FLO-PRO and chase with 9.8- ppg brine, 4 bpm ~ 600 psi ,Displaced all 9.4- ppg brine to tiger tank. Work pipe to over lap tool jts for max. hole cleaning. 12/17/2007 00:00 - 01:00 1.00 FISH P DECOMP Con't Disp. with 9.8 ppg brine. 01:00 - 06:00 5.00 FISH P DECOMP Resume Milling at 8847' & mill to 8849'. PUW=145k SOW=110k FRW=125 W06= 10k RPM=60-75, FREETO=4000 ftlb 4 bpm@ 750 psi 3 bpmC~ 390 psi, Recovered base ball size metal cuttings. 06:00 - 08:00 2.00 FISH P DECOMP Con't milling operations. Final mill depth 8849.53' 4es RTKB. P/U wait & retag bottom, no fill. P/U Wt = 134K, S/O Wt = 115K, Rot Wt = 123K. 4.1 BPM @ 600 psi. 70-80 RPMs, Torq = 4K ft-Ibs, 5 -14K WOB. 08:00 - 09:00 1.00 FISH P DECOMP Blow down & set back kelly. P/U off slips & monitor well. Well started slight flow after 10 min. Est 1 1/2 BPH after 40 min. Call engineers & receive Ok to weiht up to 9.9+ w/ NaCI. 09:00 - 11:00 2.00 FISH P DECOMP Weight up pit # 2 to 9.9+ppg w/ NaCI. Printed: 1/14/2008 8:46:48 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-32 18-32 WORKOVER NABOBS ALASKA DRILLING I NABOBS 4ES Start: 12/10/2007 Rig Release: 12/28/2007 Rig Number: Page 4 of 10 Spud Date: 9/9/1995 End: 12/28/2007 Date From - To --~ -_ 12/17/2007 11:00 - 13:00 13:00 - 13:30 13:30 - 18:00 18:00 - 20:00 20:00 - 21:00 Hours Task Code I NPT 2.00 FISH P 0.50 FISH P 4.50 FISH P 2.00 FISH P 1.00 FISH P 21:00 - 22:30 1.50 FISH P 22:30 - 00:00 1.50 FISH P 12/18/2007 00:00 - 01:00 1.00 FISH P 01:00 - 04:00 3.00 FISH P 04:00 - 06:00 2.00 FISH P 06:00 - 06:30 I 0.501 FISH I P 06:30 - 07:30 I 1.001 FISH I P 07:30 - 09:00 ~ 1.50 ~ FISH P 09:00 - 10:00 I 1.001 FISH ~ P 10:00 - 13:00 ~ 3.00 ~ FISH ~ P 13:00 - 17:00 4.00 FISH P 17:00 - 18:00 1.00 FISH P 18:00 - 19:00 I 1.001 FISH I P Phase Description of Operations DECOMP Circulate & displace wellbore w/ 9.9+ppg brine. Pumped 4 BPM C~ 625 psi. Pump total of 386 bbls until had 9.9+ brine out. DECOMP S/D break off circulating head & monitor well. FL dropped -1' in 30 min. Well not flowing!! DECOMP POOH & stand back 3 1/2" DP., Pipe coming wet, shear pump out sub w/ 2000 psi. POOH. Pulling slowly to allow Flo-Pro to fall in DP. Monitor trip sheet closely & check for flow. DECOMP PJSM, Con't POH & stand back 3 1/2" DP. Monitor trip sheet & check for flow. DECOMP PJSM with Baker, B/O and L/D Mill assy, clean boot bskt., clean floor. Explained to W/O Engineer S. McLaughlin in town, on condition of Mill pulled out. BTM cutting face gone. Observed well 30 min. during BHA, No gains No loss (Recover 3-4gal or 50 Ibs mete) from boot bskt) DECOMP PJSM with Baker, M/U BHA #3 tbg. spear assy. DECOMP PJSM, Cut and slip drill-line DECOMP Con't to cut & slip drill-line DECOMP Con't RIH w/4" spear assy to 8817'. DECOMP P/U kelly & 23' DP pup. 8840' Circulate 9.9 ppg brine w/ FLO-PRO. No losses , No gains. 4 BPM C~ 925 psi. DECOMP RIH & taq fish C~ 8850' Work pipe & swallow 13' of spear Pressured up from 200 to 500 psi. P/U & insure good catch. Attempt to pull free. Jar 3 times w/ 75K over, then jar once i00K over. Fish moved. Jar 2nd time w/ 100K over & fish comin free. Work pipe up & down. Had 45 K over pull, dropped to 35K & then to string wt. P/U wt = 135K, S/O wt = 115K. DECOMP Work pipe up & down & circulate thru spear. 2 BPM pressure increased to 1800 psi & dropped to 1050 psi after working pipe. Drop bar & open Pump Out Sub w/ 2000 psi.. DECOMP Circulate bottoms up 5 BPM C~3 680 psi. Returns ~ bottoms up had small amount of gas & some metal shavings, scale & black (wtr)heavies across screens. Pump pressure had fallen to 600 psi C~ the end of circulation. Con't to circulate until cleaned up. No losses, No gains during circulation. S/D. Blow down & set back kelly. Pumped total of 350 bbls. DECOMP S/D monitor well. A few gas bubbles migrating up hole & hole is weeping. Con't to circulate a total of 110 bbls. DECOMP Displaced well to clean 9.9+ppg brine. Pumped Flo-Pro to tiger tank. Pumped 5 bpm Q 815 psi. Monitored well; fluid level falling slowly. DECOMP POH with BHA #3, standing back 3-1/2" Drill Pipe in Derrick. DECOMP POOH and stand back 4-3/4" Drill Collars in Derrick. Release spear for packers remains. UD Spear. DECOMP PJSM with Rig Crew on procedures for punching Tail Pipe Assembly and lay down same. Recover Packer rem^'nc z ^. joints, 1 "XN" Nipple, and WLEG. Total Length of recovery- 19:00 - 20:30 1.50 FISH P DECOMP Hold Safety Meeting with forth of four rig crews, Rig Toolpusher, BPX WSL and Field Supervisor. Cover Rig's recent incident record, how to get 4ES back on track, and BP's expectations for rig. Printed: 1/14/2008 8:46:48 AM • • BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: 18-32 Common Well Name: 18-32 Spud Date: 9/9/1995 Event Name: WORKOVER Start: 12/10/2007 End: 12/28/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/28/2007 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task ~ Code ~ NPT Phase Description of Operations 12/18/2007 20:30 - 21:00 0.50 FISH P DECOMP Pick up, break out, and lay down spear. 21:00 - 21:30 0.50 FISH P DECOMP Clear and clean rig floor. 21:30 - 23:00 1.50 CLEAN P DECOMP P/U and M/U BHA #4 (Liner Dress Off Milling Assembly) consisting of dress off mill with extension, x/o sub, 3 boot baskets, bit sub, bumper sub, jars, 3 stands 4-3/4" drill collars from derrick, 41 stands of 3-1/2" drill pipe, x/o, 7-5/8" casing scraper, bit sub, and pump out sub. Total length of BHA #4- 4155.59' 23:00 - 00:00 1.00 CLEAN P DECOMP RIH with BHA #4 on 3-1/2" drill pipe from derrick. 12/19/2007 00:00 - 03:00 3.00 CLEAN P DECOMP Continue RIH with dress off assembly on 3-1/2" drill pipe from derrick to 8888' and P/U kelly. 03:00 - 04:00 1.00 CLEAN P DECOMP Establish milling parameters of Up Wt- 135,000 lbs; Down Wt- 116,000 Ibs; Rot Wt- 125,000 Ibs at 36 RPM and 3000 ft-Ibs free torque; Pump Pressure- 670 psi at 4 bpm. RIH and tag to of liner at 8892'. S/O 3000 Ibs on liner top without rotation. Dress off liner at 36 RPM and 3500 ft-Ibs torque to 8898'. Make 3 passes dressing off liner top. Make 2 dry passes smoothly through liner top. Ran scraper to 4740'. 04:00 - 06:00 2.00 CLEAN P DECOMP Pump high vis sweep and clean out liner top at 4 bpm with 700 psi. 06:00 - 12:30 6.50 CLEAN P DECOMP Held crew change and performed pre-tour checks. POH and LD 130 jts 3-1/2" DP. Reciprocated 7-5/8" scraper at 4500' and 4000'. LD scraper. Stood back remainder of 3-1/2" DP while POH. 12:30 - 14:00 1.50 CLEAN P DECOMP Stood back collars. LD dress-off BHA #4. Cleared junk baskets. 14:00 - 15:00 1.00 CLEAN P DECOMP Cleared and cleaned rig floor. DSM crew arrived to spot and RU open-top tank for cementing. Strapped liner jewelry. 15:00 - 16:00 1.00 CASE P TIEB1 MU 7-5/8" HES Champ 4 packer. RIH with 4-3/4" drill collars from derrick. 16:00 - 18:00 2.00 CASE P TIEB1 RIH with HES Champ 4 packer on 3-1/2" drill pipe from derrick to 4500'. 18:00 - 18:30 0.50 CASE P TIEB1 Change out rig crews and service rig. 18:30 - 19:00 0.50 CASE P TIEB1 Break circulation at 2 BPM with 150 psi. 19:00 - 23:00 4.00 CASE P TIEB1 Establish parameters of Up Wt- 74,000 Ibs; Down Wt- 69,000 lbs. Set Champ 4 packer and S/O 20,000 psi on packer. R/U and attempt to pressure test 7-5/8" casing at 4500'. Pressure up to 3500 psi on casing. Pressure bled off at -300 psi per 5 minutes. Flow coming out top of drill string. Bleed off pressure and R/U to pump down drill pipe. Pump through Champ 4 packer to get LLR at 2 bpm with 700 ps and 3 bpm with 1120 ps. Release Champ 4 packer. Reciprocate drill string from 4475' to 4510' several times while pumping at 5 bpm with 560 psi. Reset Champ 4 packer at 4505'. S/O 30,000 Ibs on packer. Attempt to retest casing to 3500 psi. Pressure bled off at 150 psi per 5 minutes. Flow coming out top of drill string. Release packer and POOH to 4476'. Reset Champ 4 packer and S/O 30,000 Ibs on packer. Attempt to retest casing to 3500 psi. Pressure bled off at 150 psi per 5 minutes. Flow coming out top of drill string. Release packer and POOH to 4106' standing back 4 stand of drill pipe in derrick. Set Champ 4 packer and S/O 40,000 Ibs on packer. R/U and pressure test casing to 3500 psi. Hold test for 30 charted minutes, good test. Printed: 1/14/2008 8:46:48 AM r ~ ~ • • BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: 18-32 Common Well Name: 18-32 Spud Date: 9/9/1995 Event Name: WORKOVER Start: 12/10/2007 End: 12/28/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/28/2007 Rig Name: NABOBS 4ES Rig Number: Date From - To I Hours Task Code NPT Phase Description of Operations 12/19/2007 19:00 - 23:00 4.00 CASE P TIEB1 23:00 - 00:00 1.00 CASE P TIEB1 RIH with 4 stand of drill pipe from derrick to 4500' to retest casing and POOH on tally. Set Champ 4 packer and S/O 40,000 Ibs on packer. R/U and attempt to retest at 4500'. Pressure test casing to 3500 psi. Pressure bled off at 200 psi in 8 minutes. Bleed off pressure and R/U to POOH. 12/20/2007 00:00 - 02:30 2.50 CASE P TIEB1 POOH with HES Champ 4 packer. Lay down 16 joints of 3-1/2" drill pipe and stand back 4000' in derrick. 02:30 - 03:30 1.00 CASE P TIE61 POOH and UD (9) 4-3/4" drill collars. UD HES Champ 4 PKR. 03:30 - 08:00 4.50 CASE P TIEB1 M/U wear ring pulling tool and pull wear ring. Clear and clean rig floor. R/U 4-1/2" Liner running equipment and floor. 08:00 - 09:00 1.00 CASE P TIEB1 Held crew change and PJSM on liner running with all personnel. Performed pre-tour checks. 09:00 - 10:00 1.00 CASE P TIEB1 Continued RU for scab liner. RU and adjusted torque turn equipment. Removed thread protectors from tail pipe ass'y. Prepared thread for Bakerloc Compound. 10:00 - 11:00 1.00 CASE P TIEB1 MU and Bakerloc tail pipe assembly. 11:00 - 22:00 11.00 CASE P TIEB1 RIH with 123 joints of 4-1/2" 12.6#, IBTMod x NSCT. 13Cr80 scab liner assembly. Torque turned all NSCT connections to 4000 ft-Ibs. Installed centralizer each joint. Filled liner with 9.9+ ppg brine each 5 joints. Used "Jet Lube Seal Guard" pipe dope. Ran a total of 120 centralizers on liner. P/U Baker Flexlock Liner Hanger with Flexlock Liner Top PKR and RIH. Up Wt-64,000 Ibs; Down Wt- 59,000 Ibs. 22:00 - 23:00 1.00 CASE P TIE61 R/D Torque Turn Equipment and tools. R/U to RIH with 3-1/2" drill pipe from derrick. 23:00 - 00:00 1.00 CASE P TIE61 Continue RIH with 4-1/2" scab liner assembly on 3-1/2" drill pipe from derrick. 12/21/2007 00:00 - 03:00 3.00 CASE P TIEB1 Continue RIH with 4-1/2" scab liner assembly on 43 stands of 3-1/2" drill pipe from derrick to 8899'. 03:00 - 04:00 1.00 CASE P TIE61 Establish parameters of Up Wt- 114,000 Ibs; Down Wt- 98,000 lbs. RIH and No Go out at 8904'. Confirm space out. S/O 10,000 Ibs. P/U string weight plus 2' to 8902'. 04:00 - 06:00 2.00 CASE P TIEB1 R/U CMT head and circulating hoses. R/U Cementers. 06:00 - 07:00 1.00 CASE P TIE61 Continued to circulate at 5 bpm with 720 psi. Held PJSM with rig crew, vac truck drivers, and SWS cementers on scab liner procedure. 07:00 - 10:00 3.00 CEMT P TIEB1 Mixed and pumped total of 160 bbls CI G cement plus additives ~@ 15.8 ppg. Pumped 20 bbls CI G, 40 bbls CI G with 1/4 Ib/bbl CemNet, 100 bbls CI G. Initial pressure 815 psi, fell to 450 psi 5 bpm by end of cement. Released DP wiper plug from cement head and switched to displacement with 9.9+ ppg brine. Reduced rate to 3 bpm and saw pressure spike at 25.8 bbls displacement, when DP wiper plug latched and released liner wiper plug. Reduced rate to 2 bpm at 94 bbls displaced. Bumped plug at 99 bbls displacement with 2500 psi to set liner han er. Held pressure and SO 40k Ib. Increased pressure to 4000 psi to set liner top packer. Bled pressure and checked floats; had 1 bbl returned and floats held. Cleared SWS lines and RU to pump with rig. Rotated off liner top with 15 right-hand turns. Pressured up with rig to 1000 psi and PU 7'. Saw pressure bleed and pumped 15 bbls the long way. PU additional 15'+ and reverse circulated with rig 90 bbls at 4 bpm Printed: 1/14/2008 8:46:48 AM • • BP EXPLORATION Operations Summary Report Page 7 of 10 Legal Well Name: 18-32 Common Well Name: 18-32 Spud Date: 9/9/1995 Event Name: WORKOVER Start: 12/10/2007 End: 12/28/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/28/2007 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase I! Description of Operations 12/21/2007 07:00 - 10:00 3.00 CEMT P TIE61 10:00 - 11:00 1.00 CEMT P TIEB1 11:00 - 12:00 1.00 CEMT P TIE61 12:00 - 15:00 3.00 CEMT P TIE61 15:00-16:00 ~ 1.OO~CEMT ~P ~ ~TIEB1 16:00 - 18:30 2.50 WHSUR P TIEB1 18:30 - 19:30 1.00 WHSUR P TIEB1 19:30 - 21:00 1.50 BOPSU P TIEB1 21:00 - 00:00 3.00 BOPSU P TIEB1 12/22/2007 00:00 - 01:30 1.50 BOPSU P TIEB1 01:30 - 02:00 0.50 BOPSU P TIEB1 02:00 - 02:30 0.50 DRILL P TIEB1 02:30 - 04:30 2.00 DRILL P TIEB1 04:30 - 07:00 2.50 CASE P TIEB1 07:00 - 08:30 1.50 CASE P TIE61 08:30 - 10:30 2.00 CASE P TIE61 10:30 - 11:30 1.00 CASE P TIEB1 11:30 - 13:00 1.50 REMCM P TIE61 13:00 - 14:45 1.75 REMCM P 14:45 - 16:45 2.00 BOPSU P 16:45 - 18:00 1.25 REMCM P 18:00 - 23:30 5.50 REMCM P 23:30 - 00:00 12/23/2007 00:00 - 02:00 02:00 - 07:45 0.50 REMC 2.00 REMC 5.75 REMC TIEB1 TIE61 TIEB1 TIEB1 TIEB1 TIEB1 TIEB1 and 1200 psi. Had small amount of cement in returns to open-top tank. Blew down cementing lines, RD and LD cementing head. RD SW S cementing service and reviewed job report. Held PJSM. POH with liner running ass'y on 3-1/2" DP. Held crew change, serviced rig and performed pre-tour checks. Continued POH with 3-1/2" DP. Backed out liner hanger setting tool and LD same. Cleared and cleaned rig floor. Tested 4-1/2" scab liner cement to 3500 psi for 30 minutes. Upcoming BOPE test witness waived by C. Scheve, AOGCC at 15:30 hrs 12/21/2007. RU to pull 7-5/8" pack-off through BOPE stack. Installed new 7-5/8" pack-off and RU to test. Pressure tested 7-5/8" pack-off to 4100 psi. Held test for 30 minutes. Good test. RD FMC and test equipment. PU landing joint and install test plug. RU test joint and RU to test BOPE. Tested BOPE to 250 psi low pressure and 3500 psi high pressure. Tested VBR with 2-7/8" and 4-1/2" test joints. Each test was held for 5 minutes. AOGCC witness of test was waived by Chuck Scheve. Continued testing BOPE. Upper kelly valve failed. Will replace and re-test at opportune time prior to using kelly. Pulled and LD test plug. PUMU 7-5/8" scraper ass'y (BHA #5). RIH 42 stands + 2 singles. Scraper depth 3994', top of liner at 3996'. Encountered no resistance while RIH with scraper. Circulated bottoms up C~ 3994'. Pumped 4-1/2 bpm ~ 360 psi. POH with scraper BHA. Used single DP displacement while POH. Clear & clean rig floor and prepare to PUMU BHA #6. Clean up soot residue from boiler tubes in change room, boiler room and Koomey room. PUMU BHA #6 as follows: 3.80" MM mill, 2 x 3-1/2" boot baskets, 3-1/8" bit sub, XO, 3-1/8" oil jar, XO and 9 x 3-1/8" DC's. RIH w/2-7/8" PAC DP 1 x 1 from pipe shed. Released Baker fisherman C~? 1400-hrs. Upper kelly valve failed to test during last BOPE testing. PU kelly and replace upper kelly valve. Tested same to 250-PSI LO and 3500-PSI HI. Set kelly back and blowdown same. Resume RIH w/2-7/8" PAC DP 1 x 1 from pipe shed. Held crew change, performed pre-tour checks, and serviced rig. Continued RIH with 2-7/8" PAC DP. Tagged top of scab liner C~ 3999' DPM. Carefully entered liner top and continued in hole. Each joint rabbitted as it was PU off the pipe skate. PU total of 170 jts 2-7/8" PAC DP. RD 2-7/8" PAC handling equipment. RU to run 3-1/2" DP in stands from derrick. RIH with 3-1/2" DP in stands from derrick. Tagged cement inside liner ~ 8637' DPM. PU kelly, LD 5 jts 3-1/2" DP. Established milling parameters: Printed: 1/14/2008 8:46:48 AM • • BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: 1 8-32 Common W ell Name: 1 8-32 Spud Date: 9/9/1995 Event Nam e: WORKO VER Start : 12/10/2007 End: 12/28/2007 Contractor Name: N ABORS ALASK A DRI LLING I Rig Release: 12/28/2007 Rig Name: N ABORS 4ES Rig Number: Date . From - To Hours ~ Task - Code ~ NPT Phase i __ i Description of Operations - - - _ --__- - - 12/23/2007 02:00 - 07:45 . 5.75 _ REMCM P TIEB1 PU 100k Ib; SO 85k Ib; Rot 92k Ib; 3 bpm; 1600 psi; 100a; 2000 Ib-ft; 65 rpm. Washed to 8657' and encountered hard cement. Milled with 3k - 4k WOB. Milled cement to 8672' at 0500-hrs. Lost rig power at 0500-hrs. Ordered out sanding truck to sand pad around rig. Milled to landing collar ~ 0615-hrs. Circulate hole clean ~ 3-BPM ~ 2050-PSI. 07:45 - 09:00 1.25 CASE P TIEB1 Line up kill manifold, close pipe rams, close lower kelly valve and pressure test 4-1/2" liner and 7-5/8" casing from landing collar to surface @ 3500-PSI for 30 charted minutes. Good test. Blow down lines. 09:00 - 10:00 1.00 REMCM N WAIT TIE61 Circulate well, perform rig maintenance and housekeeping while waiting for release from "High Risk Work" holding pattern. 10:00 - 11:00 1.00 REMCM P TIE61 Blow down kelly. Secure well. Weekly safety meeting. 11:00 - 18:00 7.00 REMCM P TIEB1 Received release from "High Risk Work" holding pattern at 1000-hrs. from RWO Ops Superintendent. Established milling parameters: PUW = 100K; SOW = 85K; ROT WT. = 92K; 2.0-BPM ~ 1181-PSI; 2000 ft-Ibs ~ 69-RPM. Milling landing collar. 18:00 - 22:00 4.00 REMCM P TIEB1 Held crew change. Performed pre-tour checks and serviced rig. Continued milling landing collar with 60 rpm, 2-1/2 bpm, 1250 psi, 92a, 1800 Ib-ft. Increased WOB to 7k Ib and reduced pump rate to 1/2 bpm. Saw immediate increase in ROP. Torque began varying up to 3000 Ib-ft. Periodically PU off bottom and increased pump rate back to 2-1/2 bpm to clean wellbore. Milled through landing collar C~ 8807' DPM. 22:00 - 00:00 2.00 REMCM P TIEB1 Milled cement in shoe track with 60 rpm, 2-1/2 bpm, 1250 psi, 92a, 1800 Ib-ft, 7k Ib WOB. 12/24/2007 00:00 - 02:30 2.50 REMCM P TIEB1 Continued milling cement in shoe track with 65 rpm, 2-1/2 bpm, 1250 psi, 92a, 1800 Ib-ft, 7k Ib WOB. Milled float collar C«? 8846' DPM. Held spill drill in boiler room. Varied pump rate 1/2 bpm to 2-1/2 bpm. Continued milling through float collar to 8848'. Milled cement to ball seat C~3 8876' @ 0230-hrs. Offloaded 9.9 ppg brine to tiger tank. Filled rig pit with seawater. 02:30 - 09:00 6.50 REMCM P TIEB1 Milled to 8878'. Varying WOM from 4500# to 7000#, pump rate from 1-3 BPM and RPM from 55 to 80. 09:00 - 16:00 7.00 REMCM P TIEB1 Consulted with Baker packer, Baker Fishing and Jim Willingham about difficulty milling through ball seat. Conclusion was to continue 3-4 additional hrs. and then if no further penetration is made, we will POH and inspect mill for wear. Continued milling ~ 8878'. Varying WOM from 4500# to 7000#, pump rate from 1-3 BPM and RPM from 55 to 80. Unable to achieve any further penetration. Shut down milling operations. 16:00 - 16:30 0.50 REMCM P TIEB1 Set kelly back. Blow down lines. 16:30 - 18:00 1.50 REMCM P TIEB1 PJSM - POH w/drill string. Emphasized caution while tightening up lift nubbins for 2-7/8" PAC DP and also caution to be taken while standing back 2-7/8" PAC DP. Service rig and derrick inspection. 18:00 - 20:00 2.00 REMCM P TIE61 Held crew change. POH with 3-1/2" DP. Stood back 36 stands. 20:00 - 20:30 0.50 REMCM P TIE61 RD 3-1/2" DP handling equipment and RU 2-7/8" PAC handling equipment. Printed: 1/14/2008 8:46:48 AM • • BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: 18-32 Common W Event Nam Contractor Rig Name: Date ell Name: 1 e: Name: From - To ' 8-32 WORKO NABOBS NABOBS Hours II VER ALASK 4ES Task A DRI Code LLING NPT Start I Rig Rig Phase Spud Date: 9/9/1995 : 12/10/2007 End: 12/28/2007 Release: 12/28/2007 Number: Description of Operations 12/24/2007 20:30 - 00:00 3.50 REMCM P TIEB1 POH with 2-7/8" PAC DP. Stood back 56 stands + double. Stood back 3-1/8" DC. Broke out used 3.8" mill and cleared boot baskets. Recovered deformed aluminum junk from bottom of mill. Also recovered metal shavings and 1" x 1/2" metal chunks. 3 out of 5 jets on mill plugged solid. Photos on S-Drive. MU new 3.8" bladed mill. 12/25/2007 00:00 - 01:00 1.00 REMCM P TIE61 Held weekly rig safety meeting with all personnel. Reviewed progress rig is making in reducing incidents. Aired crew safety concerns and recommendations. 01:00 - 04:45 3.75 REMCM P TIE61 RIH with new 3.8" mill, boot baskets, jar and DC (BHA #7) on 2-7/8" PAC DP from derrick. Held kick while tripping drill. Entered 4-1/2" scab liner top with no resistance. 04:45 - 06:00 1.25 REMCM P TIE61 RD 2-7/8" PAC handling tools and RU 3-1/2" DP handling tools. Continued RIH with BHA #7 and 3-1/2" DP stands from derrick. 06:00 - 07:30 1.50 REMCM P TIEB1 Held crew change and performed pre-tour checks. Continued RIH with 3-1/2" DP from derrick. PU kelly. Established parameters: PU 107k Ib, SO 90k Ib, Rot 97k Ib, 120a, 2500 Ib-ft, 60 rpm, 3 bpm, 1790 psi. 07:30 - 11:30 4.00 REMCM P TIEB1 Tagged at 8882' DPM, 27' in on kelly. Milled to 8923', 36 stands + 36' on kelly. 11:30 - 12:30 1.00 REMCM P TIE61 CBU with 9.9+ppg brine at 8923'. Pumped 190 bbls, 3-1/2 bpm, 2500 psi. 12:30 - 13:00 0.50 REMCM P TIEB1 PU and set back kelly. 13:00 - 00:00 11.00 REMCM P TIEB1 Shut down for Christmas. 12/26/2007 00:00 - 03:00 3.00 REMCM P TIEB1 Held PJSM. PU kelly, RIH and tagged cement inside 4-1/2" .liner C~ 8923' DPM. Established parameters: PU 103k Ib, SO 88k Ib, Rot 97k Ib, 65 rpm, 100a, 2000 Ib-ft, 2-1/2 bpm, 1270 psi. PU single, milled with 2k - 4k WOB to 8938', encountering ratty cement and stringers. RIH free 4 jts to hard tag C~ 9042', or 37 stands + double 3-1/2" DP. 03:00 - 06:00 3.00 REMCM P TIE61 Continued PU singles, rotating and washing each joint, past 9110'. 06:00 - 06:30 0.50 REMCM P TIEB1 PJSM. Continue to wash /ream down to KB packer. Tag C~ 9256' DPM. Rotated for a few minutes, no progress, must be packer. Jt 119 & 28' of kelly. 06:30 - 07:00 0.50 REMCM P TIEB1 Service rig, check crown o matic, PVT system, OK. 07:00 - 09:30 2.50 REMCM P TIEB1 PJSM. Rig up tiger tank lines, pump 30 bbls Hi Vis sweep in 9.9 ppg brine & chase with seawater C~ 3 bpm / 2100 psi. Displaced well bore to seawater, pumped 215 bbls total to clean seawater returns. 09:30 - 15:00 5.50 REMCM P TIEB1 PJSM. Stand back kelly, POOH, LD 3 1/2" DP. 15:00 - 18:00 3.00 REMCM P TIEB1 Changed pipe handling equipment. POH and LD 2-7/8" PAC DP and BHA #7. 18:00 - 22:00 4.00 REMCM P TIEB1 Held crew change and performed pre-tour checks. Continued i LD 2-7/8" PAC DP and BHA #7. j 22:00 - 23:00 1.00 REMCM P TIEB1 LD 9 x 3-1/8" DC. Broke out and LD 3.8" mill and BHA #7. Blade tips worn or broken off mill. Mill jets clear. '~, 23:00 - 00:00 1.00 REMCM P TIEB1 Cleared boot baskets. Cleared and cleaned rig floor. Pulled ~, wear ring. 'I 12/27/2007 00:00 - 01:00 1.00 REMCM P TIEB1 RU, closed bllind rams and tested wellbore to 500 psi. Pressure dropped about 120 psi in 30 minutes. 01:00 - 03:30 2.50 REMCM P TIEB1 RU compensator, 4-1/2" han ing equipment, and stabbing Printed: 1/14/2008 8:46:48 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: 18-32 Common Well Name: 18-32 Event Name: WORKOVER Start: 12/10/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/28/2007 Rig Name: NABOBS 4ES Rig Number: Date 12/27/2007 From - To ' Hours Task Code NPT Phase 01:00 - 03:30 03:30 - 06:00 06:00 - 06:30 06:30 - 13:00 13:00 - 15:00 15:00 - 16:00 16:00 - 18:00 18:00 - 19:00 19:00 - 20:00 Page 10 of 10 Spud Date: 9/9/1995 End: 12/28/2007 Description of Operations 2.50 REMCM P TIE61 board. 2.50 REMCM N RREP TIEB1 Repaired stabbing board lift. 0.50 BUNCO P RUNCMP Service rig, check crown o matic, PVT system, OK. 6.50 BUNCO P RUNCMP PJSM. Make up jewelry below packer, baker locking all connections. RIH w/ 4 1/2" 13 cr 12.6# Vam Top completion, torque turning all connections to 4400 ft/Ibs. 92 jts total. Up wt 53k, Down Wt 50K. 2.00 BUNCO P RUNCMP PJSM. Bottom out 28.5' in jt #93. Space out w/ (1) 3.83' pup & bury same under Jt # 92. M/U hanger & landing joint. 1.00 BUNCO P RUNCMP PJSM. Rig down Torque turn equipment. 2.00 BUNCO RUNCMP PJSM. Rig up & reverse circulate 60 bbls heated seawater & chase w/ 160 bbls heated seawater w/ corrosion inhibitor. Pumped 3 bpm and 260 psi. RD circ lines. 1.00 BUNCO P RUNCMP Held crew change. Performed pre-tour checks. Landed tubing hanger and RILDS. Dropped ball /rod assembly. LD landing joint. 1.00 BUNCO P RUNCMP Pressured u on tubin to 3500 si to set acker. Held 3500 psi for 30 minutes to MIT tubing. Bled tubing pressure to 1500 osi. Pressured up IA to 3500 psi, and held pressure for 30 20:00 - 20:30 0.50 BUNCO P RUNCMP Bled tubing pressure to shear DCK valve. Confirmed circulation in both directions by pumping 46 spm at 1100 psi. 20:30 - 21:30 1.00 WHSUR P RUNCMP FMC set TWC with dry rod. Tested TWC to 1000 psi for 10 minutes, from above and below. 21:30 - 23:30 2.00 BOPSU P RUNCMP Blew down lines. RD choke line and kill line. RD flow nipple. ND BOPE. 23:30 - 00:00 0.50 WHSUR P RUNCMP NU tubing head adapter flange. 12/28/2007 00:00 - 00:30 0.50 WHSUR P RUNCMP Continued NU adapter flange. Tested flange to 5000 psi 30 minutes. Held fire drill. 00:30 - 02:30 2.00 WHSUR P RUNCMP NU tree and tested to 5000 psi. 02:30 - 03:30 1.00 WHSUR P RUNCMP RU lubricator and tested to 500 psi. Pulled and LD TWC. 03:30 - 04:30 1.00 WHSUR P RUNCMP Held PJSM. Moved in, spotted hot oil service and RU. Tested lines to 2500 psi. 04:30 - 07:00 2.50 WHSUR P RUNCMP Freeze protected well by pumping 85 bbls 120 deg diesel down IA, taking returns to pits. RU jumper line to tubing and allowed diesel to U-tube for 1 hour. 07:00 - 07:30 0.50 WHSUR P RUNCMP PJSM. Rig down lines on tree. 07:30 - 08:30 1.00 WHSUR P RUNCMP PJSM. Pick up lubricator, test to 500 psi, OK. Set BPV. 08:30 - 10:00 1.50 WHSUR P RUNCMP Test BPV from below C~3 1000 psi / 10 minutes, OK. Rig down all lines, secure well. Rig released @ 10:00 hrs, 12/28/2007. Printed: 1/14/2008 8:46:48 AM • • ,~ ~ a ~ ` ~ ~ ~, ~' SARA ~~ ~ ~ ~,~ / H PALIN, GOVERNOR CQ~S~j R A-frtzO ~ ~~ 333 W 7th AVENUE, SUITE 100 Gi>•sA~~ii l~o~~`~~•...uuu~~•11iii---777 0l` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Sarber CT Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 ~~~~,~~ ~~~ ~ ~ ZQt~? Anchorage, Alaska 99519-6612 ~ ~~ ~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-32A Sundry Number: 307-363 ,. ~ Q' ~'~ Dear Mr. Sarber: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this .LQ day of December, 2007 Encl. Sincerely, ,~j`~' d ~6®~~ ~ STATE OF ALASKA `.~/b-~/O ALASKA OIL AND GAS CONSERVATION COM SI( ~ ~ ~ ~~)~~ APPLICATION FOR SUNDRY APDD~~nn ~~~~ 20 AAC 25.280 r~t$~~~s; ~ ~~~~#r'r;t~."~l~if! ~.,~~ 1. Type of Request: ®Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 201-107 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22585-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 18-32A - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): _ ADL 028321 - 54'~ Prudhoe Bay Field / Prudhoe Bay Pool 12 PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11601 ~ 8681 ~ 11535 8680 8885'& 11232 None Casin Len th Size MD TVD Burst Colla se Structural Cond r 110' 20" 11 110' 1490 470 Surface 3830' 10-3/4" 3830' 3707' 5210 2480 Intermediate 9223' 7-5/8" 9223' 8226' 8180 5120 Production Liner 772' 5-1/2" x 4-1/2" 8916' - 9688' 7975' - 8565' 7740 6280 Liner 2328' 3-1/2" x 3-3/16" x 2-718" 9272' - 11600' 8265' - 8681' 10160 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10500' - 11530' 8695' - 8680' 4-112", 12.6# L-80 8908' Packers and SSSV Type: 7-5/8" x 4-1/2" Baker'S' packer Packers and SSSV MD (ft): 8850' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: January 15, 2008 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Greg Sarber, 564-4330 Printed Name reg Sarber Title CT Drilling Engineer Prepared By Name/Number: Signature 2_,j -p~. Phone 564-4330 Date Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance rr~~ Other: 3~~ V ~S ~ ~~ ~S~ Subsequent Form Required: ~® APPROVED BY A roved B : COMMISSIONER THE COMMISSION Date ~ d' ~ Form 10-403 Revised 06/2006 v ~ v QRIGIN~L Submit In Duplicate • To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Greg Sarber CTD Engineer Date: November 28, 2007 Re: DS 18-32A Sundry Approval by Sundry approval is requested to abandon perforations on well 18-32A. 18-32A is currently shut in for T x IA communication and a failed MIT-IA. (Suspected Cretaceous Leak) 18-32A was drilled as a June 2001 CTD sidetrack to the east of DS18. The well initially had a high GOR that was caused primarily by low oil rate paired with moderate gas. A Borax log run in March 2002 showed no channels and a production log showed little contribution from the toe perfs. A CIBP was set at 11,232' in May 2002 with no apparent impact to production. The well remained shut in for high GOR until a December 2005 static showed high pressure (4000 psi) and a water gradient in the wellbore. An ASRC test in April 2006 showed the well producing 1800 bwpd and 30 bopd. Lab analysis showed Barium and total chlorides consistent with Cretaceous water. A subsequent caliper indicated several holes in the tubing below 6300'. The tubing above 6300' is in fair condition. Finally, a CMIT TxIA in May 2006 failed with a LLR of 2 bpm at 1500psi. Several attempts were made to pull the WRP that secured the well and to get an SCMT of the liner to determine our cut and pull options. When slickline got on the well, they encountered approximately 50 ft. of cretaceous sand and scale on top of the plug. Upon further review, it was determined that the risk of pulling the plug and initiating further crossflow from the Cretaceous was too great and the SCMT was cancelled. The W RP was left in the hole and will be removed when the workover rig recovers the packer. The well remains SI. The well is scheduled for a workover to replace the existing 4-1/2" L-80 production tubing with 4-1 /2" 13Cr80 chrome tubing string, and to repair the suspected leak in the 9-5/8" casing. The workover will be performed by a different rig and is not the subject of this sundry application. Immediately following the work over a coil tubing sidetrack will then be made by performing a sidetrack from a whipstock set in the 4-1/2" liner. The sidetrack will be performed by the Nordic 1 CTD rig. The purpose of the sidetrack will be to access reserves left behind from the 18-32A and 18-34 wells. The cement job on the sidetrack liner is planned to come up to 8,940' MD in the parent well bore. All perforations in the parent well are intended to be abandoned by a bridge plug above the existing liner top and by the new sidetrack liner cement job. (See Schematic Attached). REASON FOR SUNDRY: In order to achieve adequate isolation for the 2-7/8" liner cement job on the sidetrack, it will be necessary to abandon all the perforations in the existing parent well bore. Pre-CT Rig Work: (Post workover) 1. Pull BPV. 2. slickline pull sheared DCR valve in upper GLM, and dummy off. 3. slickline pull ball and rod, RHC plug from nipple below packer, run whipstock drift to PBTD. 4. Bleed T, IA, OA to zero. 5. Set BPV 6. Bleed production flow lines and GL lines down to zero and blind flange 7. Remove wellhouse, level pad. Rig Sidetrack Operations: (Scheduled to begin on January 15, 2008 using Nordic rig 1) ~-~°~`~"~j~` ~'~ 1. MIRU Nordic Rig 1 f ~~~~~_ 2. NU 7-1/16" CT Drilling BOPE and test. ~a1~ 3. RU Coil. RIH with a 3.80" D-331 DSM on a mill and motor. Cleanout to top of liner at. 4. RIH with a Baker TT 4-1/2" monobore whipstock. Set top at 9,240'. I stoc o ~8,8 ~npvcL ~E~- ~ ~Cs.~~cc.~ `~/~o II~ 6. Mill 3.80" window at 9,240'. ` 7. Drill build/turn section with 3.75" x 4.125" bicenter bit, and land well. 8. Drill lateral section to 12,100'. 9. Run and cement a 2-7/8" x 3-3/16" L-80 liner string, abandoning perfs in parent wellbore. 10. Make a cleanout run with mill and motor and SWS GR-CNL logging tool. 11. Perforate well. 12. Circulate well to KWF brine. FP well to 2000' with diesel. 13. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 14. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run Live gas lift design. Greg Sarber CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble I TRFF = _, ra" Ana ryuu W~LHFAD= FMC ACTUATOR = BAKER C KB. El-EV = 54.0' BF. REV = KOP = 2607' Max Angle = 99 (4110257' Datum MD = NIA Datum ND= 8800'SS 10-314" CSG, 45.5#, L-80, D = 9.953" ~-~ 3$30' Minimum ID = 2.37" ~ 9765' 3-3116" X 2-7/8" LNR XD 412" TBG, 12.8#, L-80, .0152 bpf, ID = 3.958" ~-{ 8907' TOP OF 5-1/7' LNR }-{ 8921' 5-112" LNR, 17#, L-E0, .0232 bpf, ID = 4.892" ~ 8923' TOP OF 412" LNR 8923' • ,1 Q ~~ ~~ SAFETY NOTES. OPEN SLTD LNR BELOW V W FNPSTOCK PKR ~ 9704'. WELL EXCEEDS 70° ~ 9808' AND GOES HORIZONTAL ~ 10201'. 2217' 4tlr CAMCO TRCF SSSV, D =3.817' LOCKFJ] OUT (SET 04/16198) G11S l1FT MANDRELS ~I ST MD NO DEV TYFE VLV LATCH PORT DATE 389.9 3765 34 TMI'D)C DV BK 04!21/99 2 6765 8165 32 TMPDX DV BK 04121!99 3 8782 7861 32 TMPDX DV BK 0421199 8850' H7-518" X 41/2" BAKER S PKR, 10 = 3.875' I ' 88$5' H412" HES XN NIP, ID 1111LLED TO 3.80" BY CTD 8885' 41/r wRP (511 sros) 8908' 412" TUBING TAB WLEG ELMD TT NOT LOGGED g91g' ~-{7-518" X 5-12"'1JV LINER HGR PKR, ID = 4.880" 8923' ~-~ 5-12" X 41/2" XO, ID = 3.958" ~ 7-518" LNR. 29.7#, 5-95, .0459 tpf, ID = 6.875" ~--~ 9223' ~ PERFORATION SUMMARY Rf~ LOG: Z-Den ON 0925/95 ANGLEATTOPPERF: 91 ~ 10600' Note: Refer to Ftoductan OB for historical pert data SIZE SPF INTERVAL OpnlSgz DATE r s 1o6DD-11200 0 os21ro1 r 6 11250 - 11530 O 0621101 9272' H4-12" BKR KB FKR, ID = 2.35' 9277' 3-3i4" 8KR DEPLOYMENT SLV, ID = 3.00" 9318' 3-1/2" X 3-alts" XO, ID = 2.8tY' 9889' ~-{TDP OF BKR WHPSTOCK 9704' - I I 9785' I I I I 1 1 I 1 I I I I F~TD 11635' I I I I 2-718" LNR, 8.18#, L-80, STL, .0058 bpi, ID - 2.37" 4-12" LNR, 12.6#, L-80, .0152 bpf, D = 3.958" 11095' ^ATE REV BY COMMEMS DOTE REV BY COMMENTS 10103185 OWpNAL COMPLETK)N 06126101 CHITP CTDSIDEfRACK Odro4f02 JKBIKK PERF CORRECTIONS 0526102 ODWIt~ SET CIBP 06/15103 CMORLP KB FIEVATgN CORR~TION 05117106 JGM/PJC WRP®8665' TOP OF BKR WHIPSTOCK PKR 3-3/ts" x 2-7/8" XO, D = 2.37" 11232' HES CAP, 0526/02 4-12" MILLOUT WINDOW es67' 9s9s' PRUDHOE BAY UNIT W~L: 18-32A PERMIT No: "2011070 API No: 50-029-2258500 S~ 24, T11 N. R14E 3632' NSL & 41' WEI. BP Exploration (Alaska) -1f8" SM CNV • • 1 $ ~3 2 B SAFETY NOTES: OPEN SLTD LNR BELOW WHIPSTOCK PKR ~ 9704'. WELL EXCESS Proposed CTD Sidetrack ~o° ~ 9806' AND GOES HORIZONTAL ~ 10201'. • ALASFiA OIL A1~TD GAS COI~TSER~ATI011T CO1~II~IISSI01~ • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. Po Box 196612 ~~~~ NOV ~ ~ ~~~ Anchorage, Alaska 99519-661 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-32A_- Sundry Number: 307-349 l ~~ Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager) . As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ~ day of November, 2007 Encl. STATE' dF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RC~111E NOV 1 5 207 APPLICATION FOR SUNDRY APPROVA~i~ska Oil & Gas Cans. Carnrrlssion 20 AAC 25.280 Ant:horaae 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Putl Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 201-107 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22585-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 18-32A ' Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028321 54' - Prudhoe Bay Field / Prudhoe Bay Pool 12~ PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11601 8681- 11535 8680 11232 None Casin Len th ize MD TVD Burst Colla se Structural Cond r 110' 20" 110' 110' 14 0 470 Surface 3830' 10-3/4" 3830' 3707' 5210 2480 Intermediate 9223' 7-5/$" 9223' 8226' 8180 5120 Production Liner 772' 5-1 /2" x 4-1/2" 8916' - 9688' 7975' - 8565' 7740 6280 Liner 2328' 3-1/2" x 3-3/16" x 2-7/8" 9272' - 11600' 8265' - 8681' 10160 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10500' - 11530' 8695' - 8680' 4-1 /2", 12.6# L-80 8908' Packers and SSSV Type: 7-5/8" x 4-1/2" Baker'S' packer Packers and SSSV MD (ft): 8850' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: December 13, 2007 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Howard West, 564-5471 Printed Name vid Reem Title Engineering Team Leader Prepared By NamelNumber: Signature Phone 5645743 Date // /~. D Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: e Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~'~,BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~~~~` ~S c ~~~ .~ ~~ ~~~ rik? ~ 200i Subsequent Form Required: ~~ l~ APPROVED BY / ~ ~~~ d A roved B : SIONER THE COMMISSION Date ` Form 10-403 Revised 06/2006 Submit In Duplicate ~R~GlNAL • • by Scope of Work: Pull 4 1/2" L-80 completion, mill and retrieve Baker S-3 packer, run premium threaded 4 %2" scab liner to 4000' MD and cement, changeout 7 5/8" packoffs, run 4-%2" Chrome completion. MASP: 2445 psi Well Type: Producer Estimated Start Date: December 13, 2007 Pre-riq prep work: O 1 Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. E 3 Power Jet cut @ -8849', ~1' above the top of the S-3 packer in the 4'h" pup. (Ref: 10/02/1995 tubin summar F 4 Circulate/bullhead well with kill wei ht brine and ca with diesel. Bleed WHP's to 0 si. O 5 Set a BPV in the tubin han er. Proposed Procedure: 1. MIRU Doyon 16. ND tree. NU and test BOPE to 250 psi low, 3500 psi high. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4 1/2" tubing string. 3. Mill and retrieve Baker S-3 packer at 8859' MD. 4. Run and fully cement a 4 %" scab liner with Baker liner top packer set at 4000' MD. 5. Run new 4-1/2" Chrome tubing completion with packer at 3900' MD. 6. Displace the IA to packer fluid and set the packer. 7. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 8. Set BPV. ND BOPE. NU and test tree. RDMO. TREE _ 4-118" 5M CNV WELLHEAD = FMC ACTUATOR= BAKERC KB. ELEV = 54.0' BF. ELEV = KOP = 2607' Max Angle = 99 ~ 10257' Datum MD = WA Datum ND = 8800' SS ~ 10-3/4" CSG, 45.5#, L-80, fD = 9.953" ~ Minimum ID = 2.37" ~ 9765' 3/16" X 2-7/8" LNR XO ~ 4-1/2" TBG, 12.8#, L-80, .0152 bpf, ID = 3.958" ~ TOP OF 5-1/2" LNR ~ 8921' 5-1/2" LNR, 17#, L-80, .0232 bpf, ~= 4.892" 8923' TOP OF 4-1/2" LNR 8923' 7-5/8" LNR, 29.7#, S-95, .0459 bpf, ID = 6.875" 9223' PERFORATION SUMMARY REF LOG: Z-Den ON 09/25/95 ANGLEATTOPPERF: 91 ~ 10500' Note: Refer to Productron DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10500 - 11200 O 06/21/01 2" 6 11250 - 11530 O 06/21/01 ~ 4-1/2" LNR, 12.8#, L-80, .0152 bpf, ID = 3.958" ~ 2217' 4-1/2" CAMCO TRCF SSSV, ~ = 3.812" LOCKED OUT (SET 04116/96) GAS LF'i MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3899 3765 34 TMPDX DV BK 04/21/99 2 6765 6165 32 TMPDX DV BK 04/21/99 3 8782 7861 32 TMPDX DV BK 04/21!99 (7-5/8" X 4-1/2" BAKER S PKR, f0 = 3.875" ~ $$$5' -~4-1/2" HES XN N~, ID MILLED TO 3.80" BY CTD 8885' 4-1/2" WRP(5/19!06) 8908' - 4-1/2" TUBING TAL WLEG ELMD TT NOT LOGGED 17-5/8" X 5-1/2" TM/ LINER HGR PKR, ID = 4.880" I 5-112" X 4-1 /2" XO, ID = 3.958" 9272' -~4-1/2" BKR KB PKR, ID = 2.39" 9277' 3-3/4" BKR DEPLOYMENT SLV, ID = 3.00" ~ c1~31A~ 3-1/2" X 3-3/16" XO, D = 2.80" 9689' TOP OF BKR WH~STOCK 9704` TOP OF BKR WH~STOCK PKR 9765' 3-3/16" X 2-7/8" XO, ID = 2.37" 11232` HES CAP, 05/26/02 4-1/2" MILLOUT WWDOW PBTD 11535' 9x87' - 9898' >.-7/8" LNR, 6.16#, L-80, 11601' iTL, .0058 bpf, ~ = 2.37" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/03/95 OI~GINAL COMPLETION 06/26/01 CHITP CTD SIDETRACK 04/04/02 JKB/KK PERF CORRECTIONS 05/28/02 DDWttNt SET CAP 06/15/03 CMOlTLP KB ELEVATION CORRECTION 05/17/06 JGM./PJC WRP Q 8885' PRUDHOE BAY UNIT WELL: 18-32A PERMfT No: 1011070 API No: 50-029-22585-00 SEC 24, T11 N, R14E, 363Z' NSL & 41' WEL BP Exploration (Alaska) 18-32A TREE = 4-1/8" 5M CNV WELLHEAD= FMC ACTUATOR = BAKER C KB. ELEV = 54.0' BF. ELEV = KOP = 2607' Max Angle = 99 ~ 10257' Datum MD = WA Datum TV D = 8800' SS ~ 10-3/4" CSG, 45.5#, L-80, ~ = 9.953" ~ 4-1/2" WLEG -- 7-5/8" X 4-1/2" Baker LINER TOP PKR, I~ Top of Cement: -4000` MD Minimum ID = 2.37" ~ 9765' 3/16" X 2-7/8" LNR XO 4-1/2" TBG, 12.8#, 13Cr-80 --~ 4-1/2 " HES 9Cr X- N6y, O = 3.813" 7-5/8" X 4-1/2" BAKER S PKR,9Cr 4-1 /2 " HES 9Cr X- NP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3000 DV 4-112" TUBING TAB WLEG TOP OF 5-1/2" LNR 8921' 5-1/2" LNR, 17#, L-80, .0232 bpf, ~ = 4.892" 8923' TOP OF 4-1/2" LNR 8923' 7-5/8" LNR, 29.7#, S-95, .0459 bpf, ID = 6.875" 9223' PERFORATION SUMMARY REF LOG: Z-Den ON 09/25/95 ANGLEATTOPPERF: 91 ~ 10500' Note: Refer to Productan DB for historical pert data SIZE SPF INTERVAL OpNSgz DATE 2" 6 10500 - 11200 O 06/21/01 2" 6 11250 - 11530 O 06/21/01 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I 8916' 7-5/8" X 5-1/2" TM/ LINER HGR PKR, !D = 4.880" 8923' 5-1/2" X 4-1/2" XO, ID = 3.958" 9272' 4-1/2" BKR KB PKR, ID = 2.39" 9277' 3-3/4" BKR DEPLOYMENT SLV, ID = 3.00" 9318' 3-1 /2" X 3-3/16" XO, ID = 2.80" 9689' TOP OF BKR WHIPSTOCK 9704' TOP OF BKR WHIPSTOCK PKR 9765' 3-3/16" X 2-7/8" XO, ID = 2.37" 11232' HES CAP, 05/28/02 4-1/2" M~LOUT WINDOW PBTD 11535' 9sa7' - 9696' 2-7/s" LNR, s.1s#, L-ao, 11601' STL, .0058 bpf, ~ = 2.37" DATE REV 8Y COMMENTS DATE REV BY COMMENTS 10/03/95 ORIGINAL COMPLETION 06!26101 CHITP CTD SIDETRACK 04/04/02 JKB/KK PERF CORRECTIONS 05/26/02 DDW/tlh SET CIBP 06/15/03 CMO/TLP KB ELEVATION CORRECTION 05/17!06 JGM./PJC WRP (d1 8865' PRUDHOE BAY UNfr WELL: 18-32A Pl32NAfT No: 2011070 API No: 50-029-22585-00 SEC 24, T11 N, R14E, 3632' NSL & 41' WEL BP Exploration (Alaska) 18 -3 2A SAFETY NOTES: oPOV SLTD Ll~t l~OW W HIPSTOgC PKR ~ 9704. W B.I. D(t~ Proposed Completion 70° ~ ssos' Ate GOES HOIi1ZONTAL ~ 10201•. 4-1/2 " HES 9Cr X- N~, ID = 3.813" c¡ //t:d/ô6 STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS . f,fè 1. Operations Performed: Abandon 0 Alter CasingO Change Approved Program 0 Repair Well 0 Pull TubingD Operation ShutdownD Plu!1 PerforationsD Perforate New PoolO Perforate 0 Stimulate 0 WaiverO 2. Operator Name: 3. Address: 4. Current Well Class: Development 00 BP Exploration (Alaska),lnc. ExploratoryD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): StratigraphicO ServiceD 9. Well Name and Number: 18·32A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 54.00 8. Property Designation: ADL-028321 11. Present Well Condition Summary: Total Depth measured 11601 feet true vertical 8681.0 feet Effective Depth measured 11232 feet true vertical 8690.0 feet Casing Length Size CONDUCTOR 80 20" 91.5# H-40 SURFACE 3801 10·3/4" 45.5# NT·80 PRODUCTION 9200 7-5/8" 29.7# USS·95 LINER 6238 4-1/2" 12.6# L-80 LINER 46 3-1/2" 9.3# L-80 LINER 447 3-3/16" 6.2# L-80 LINER 1836 2-7/8" 6.16# L·80 OtherŒSecure Well Time ExtensionO Re-enter Suspended WellO 5. Permit to Drill Number: 201·1070 6. API Number 50-029-22585-01-00 Plugs (measured) Secure Well --. 4-1/2" WRP @ 8885' (05/19/2006) 2-7/8" CIBP @ 11232' (05/26/2002) @ 28 - 8908 @ 8850 @ 8916 @ 9272 @ 2217 RBDMS 8Ft SEP ~ 8 20D6 ! Junk (measured) 30.0 30.0 29.0 7975.0 8265.0 8301.0 8602.0 TVD - 110.0 - 3707.0 - 8230.0 - 8565.0 - 8301.0 - 8602.0 - 8681.0 MD - 110 - 3830 - 9228 - 9688 - 9318 - 9765 - 11601 30 29 28 8916 9272 9318 9765 Perforation depth: SCANNED SEP 2 0 2005 Measured depth: 10500-11200,11250-11530 True vertical depth: 8695-8691,8689-8680 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 Packers & SSSV (type & measured depth): 7-5/8" Baker S Packer 7·5/8" TIW liner HGR PKR 4-1/2" BKR KB PKR 4-1/2" Cameo TRCF SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Burst 1490 4230 8180 8430 10530 8520 10570 Collapse 470 2270 5130 7500 10160 7660 11160 Prior to well operation: Subsequent to operation: Oil-Bbl SI SI Representative Dailv Averaae Production or Iniection Data Gas-Mef Water-Bbl Casin!1 Pressure o 0 ~O o 0 --- Tubing Pressure 750 750 WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: IN/A 14. Attachments: 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ] GasD Copies of Logs and Surveys run _ Daily Report of Well Operations _ ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWayne R. Schnorr ~~ . ~ JI-k -".-~ Title Petroleum Engineer Signature Phone 564-5174 '/ Form 10-404 Revised 4/2004 . L.o' I n I \ I ~\ I V I '\I r\ L... DevelopmentŒ] ServiceD Date 9/11/06 . . 18-32A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/17/2006 SET 4 112" WRP PLUG @ 8865' MD. 750 PSI PSI WHEN SET, FLUID PACKED. ATTEMPT TO CMIT TO 3000 PSI. UNABLE TO GET TO TEST PRESURE, LLR OF 2 BPM @ 1500 PSI. ** TURNED WELL OVER TO DSO, LEFT SHUT IN** 05/17/2006 CMIT Tx IA to 3000 psi (UNABLE to Test) Established LLR of 2 bpm @ 1500 psi (Eval cretaceous leak) Unable to reach test pressure. Pumped 40 bbls crude at 2 bpm @ 1500 psi. When shut down pressure fell immediately to starting pressure. Final WHP's=920/920/360 05/16/2006 T/l/0=7501780/360 Assist Slickline CMIT Tx IA to 3000 psi. (Eval cretaceous leak) Pumped 40 bbls 180* crude and 5 bbls diesel for brush & flush. (Pre-plug set) 05/16/2006 RAN VARIOUS BROACHES AND CENTRALIZERS TO DRIFT FOR WRP. DRIFTED WI 3.72" SWAGE, 2' STEM, 3.745" SWAGE, TT LOC. LOC TT @ 8874' SLM,FLAG WIRE, SAW STA 3 @ 8748' SLM, GOOD FLAG. BEGIN TO RIH WI WRP PLUG. 05/15/2006 {set wrp plug} BROACHED WI 3.80" TO 7570' SLM. BROACHED WI 3.775" TO 7640' SLM. BROACHED WI 3.70" TO 8900' SLM. CALIPER TBG FROM 8900' MD TO SURFACE.{ good data} ATTEMPT TO DRIFT WI 3.70" CENT FOR WRP PLUG, UNABLE TO GET PAST 8701' SLM. 05/14/2006 T/IIO= 750/820/360 Assist Slickline (FIsh SIL toolstring) Pumped 80 bbls diesel and 110 bbls crude @ 180* during brush & flush. 05/14/2006 JAR UP ON FISH @ 9051' BLM. RECOVERED COMPLETE FISH. RIG DOWN BRAIDED (Fish WRP Slips I Parts or WRP Plug) MADE FULL GAUGE RUNS IN THE 7" & 4 1/2" X- OVER, MADE A 3" LIB RUN IN THE 41/2" TO THE 2 718" X-OVER. RECOVERED BOTTOM NOSE CONE OF WRP PLUG. 5 SLIPS AND SPRINGS STILL IN HOLE. FLUIDS PUMPED BBLS 2 PT Surface Equipment 85 Diesel 190 Crude 277 TOTAL Page 1 TREE = 4-118" 5M CIW WB..LHEAD = FMC ACTUATOR = BAKERC KB. B..EV = 54.0' BF. B..EV = KOP= tvlax Angle = Datum MO = DatumlVD= 2607' 99 @ 10257' N/A 8800' SS 10-3/4" CSG, 45.5#, L-80, ID = 9.953" I Minimum ID = 2.37" @ 9765' 3-3/16" X 2-7/8" LNR XO 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 890T I TOP OF 5-1/2" LNR I 8921' 15-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" H 8923' 1 TOP OF 4-1/2" LNR H 8923' 17-5/8" LNR, 29.7#, S-95, .0459 bpf, 10 = 6.875" I 9223' PERFORA TION SUMMARY REF LOG: Z-Den ON 09/25/95 ANGLEAT TOP PERF: 91 @ 10500' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10500 - 11200 0 06/21/01 2" 6 11250 - 11530 0 06/21/01 14-112" LNR, 12.6#, L-80, .0152 bpf. ID = 3.958" I 11095' DATE 10/03/95 06/26/01 04/04/02 OS/26/02 06/15/03 05/17/06 REV BY COMMENTS ORIGINAL COMPLETION CH/TP CrD SIDETRACK JKB/KK PERF CORRECTIONS DDW/tlh SET CIBP CMOITLP KB B..EV A TION CORRECTION JGM.lPJC WRP @ 8865' DATE 18-32A 5 NOTES: OPEN SLTD LNR BELOW WHIPSTOCK PKR @ 9704', WB-L EXCEEDS 70° @ 9806' AND GOES HORIZONTAl @ 10201'. . 2217' 4-1/2" CAMCO TRCF SSSV, ID= 3.812" LOCKED OUT (SET 04/16/96) GAS LIFT MANDR8...S ST MD lVD DEV TYPE VLV LATCH 1 3899 3765 34 TMPDX DV BK 2 6765 6165 32 TMPDX DV BK 3 8782 7861 32 TMPDX DV BK PORT DATE 04/21/99 04/21/99 04/21/99 8850' -7-5/8" X 4-1/2" BAKER S PKR, ID = 3.875" I -14-1/2" HES XN NIP, ID MILLED TO 3.80" BY CTD -j4-1/2" WRP(5/19/06) I -i4-1/2" TUBING TAIL WLEG I H ELMO TT NOT LOGGED I -17-5/8" X 5-1/2" TIW LINER HGR PKR, ID = 4.880" I 8923' -15-1/2" X 4-1/2" XO, ID = 3.958" I 9272' 9277' 9318' 9689' - 4-1/2" BKR KB PKR, ID = 2.39" I - 3-3/4" BKR DEPLOYMENT SLY, ID - 3.00" H3-1/2" X 3-3/16" XO, ID - 2.80" I - TOP OF BKR WHIPSTOCK I I PBTD H 11535' r / 2-7/8" LNR, 6.16#, L-80, -j 11601' STL. .0058 bpf, ID = 2.37" 4-1/2" MILLOUTWINDOW 9687' - 9696' REV BY PRUDHOE BA Y UNfT WB..L: 18-32A PERMfT No: r2011 070 API No: 50-029-22585-00 SEC 24, T11 N, R14E, 3632' NSL & 41' WB.. COMMENTS BP Exploration (Alaska) e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marlœr.doc Permit to Drill 2011070 MD 11601 ~ TVD DATA SUBMITTAL COMPLIANCE REPORT 718/2003 Well Name/No. PRUDHOE BAY UNIT 18-32A Operator BP EXPLORATION (ALASKA) INC 8681 --~ Completion Dat 6/22/2001 "~ Completion Statu 1-OIL Current Status 1-OIL APl No~ 50-029-22585-01-00 UIC N REQUIRED INFORMATION Mud Log No Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt i ED~.~--D- Ver~l~S Verification Log Log Run Name Scale Media No Interval Start Stop 9678 11601 (data taken from Logs Portion of Master Well Data Maint) OH I CH Open Dataset Received I~nber 4/4/2002 ~/0719 Comments ~~ ~utron c Me, mc~r~ NEU/GR.' ' 10220 Directional Survey Directional Survey 25 BS 1 25 BS 1 25 BS 1 1 2 BS I 2 1 FINAL FINAL FINAL FINAL 9188 9188 9188 9678 9234 9192 9710 9192 9192 11532 11532 11532 11601 11527 11523 11526 11523 11523 Case Case Case Open Case Case Case OH CH ch ch 5/14/2002 5/14/2002 5/14/2002 4/4/2002 '~10719 5/14~2002 5/14/2002 L41~99 8/3/2001 8/3/2001 ~I1~220 9/7/2001 9/7/2001 9192-11523 9192-11523 BL, Sepia 9192-11523, Digital Data Directional Survey Digital Data Directional Survey Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y / Chips Received? Analysis Daily History Received? Formation Tops Permit to Drill 2011070 MD 11601 Comments: ']'VD DATA SUBMITTAL COMPLIANCE REPORT 7~8~2003 Well Name/No. PRUDHOE BAY UNIT 18-32A Operator BP EXPLORATION (ALASKA) INC 8681 Completion Dat 6/22/2001 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22585-01-00 UIC N Compliance Reviewed By: 2/ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Clap GSO Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development _X Explorato~_._ Stratigraphic__ Service_ 4. Location of well at surface 1647' FNL, 41' FEL, Sec. 24, T11N, R14E, UM At top of productive interval 1195' FNL, 910' FEL, Sec. 19, TllN, R15E, UM At effective depth 891' FNL, 5193' FEL, Sec. 20, T11N, R15E, UM At total depth 788' FNL, 4852' FEL, Sec. 20, T11N, R15E, UM (asp's 691737, 5960220) (asp's 695809, 5960778) (asp's 696797, 5961107) (asp's 697134, 5961219) 12. Present well condition summary Total depth: measured true vertical Perforate _ Other_X ClBP Effective depth: measured true vertical 6. Datum elevation (DF or KB feet) RKB 54 feet 7. Unit or Property name Casing Length Conductor 110' Surface 3795' Intermediate 9188' Liner 772' Sidetrack Liner 2128' Prudhoe Bay Unit 8. Well number 18-32A 9. Permit number / approval number 201-107 10. APl number 50-029-22585-01 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 11601 feet Plugs(measured) CIBPset~ll~'~;~¢/~)(~ I~, I.,. ~,,, I.. IV~ I./ 8681 feet JUH 0 6 20O2 Size Cemented Measured Dep[bmh~,r~,.~r~ True Vertical Depth 20" 260 sx AS 145' 145' 10-3/4" 1283 sx PFE, 212~ sx 3830' 3707' Class 'G' 7-5/8" 295 sx Class 'G' 9223' 8226' 5-1/2" x 4-1/2" 220 sx Class 'G' 8916' - 9688' 7975' - 8565' 3-1/2" x 3-3/16" 17 bbls Class 'G' 9272' - 11600' 8265' - 8681' x 2-7/8" 11232 feet Junk (measured) 8690 feet Perforation depth: measured Open Perfs 10500' - 11200', Open Perfs Below CIBP 11250' - 11530' true vertical Open Perfs 8695' - 8691', Open Perfs Below CIBP 8689' - 8680' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, TBG @ 8850' MD; 4-1/2", 12.6#, L-80, Tubing Tail @ 8908'. Packers & SSSV (type & measured depth) 7-5/8" x 4-1/2" Baker S Packer @ 8850'. 7-5/8" x 5-1/2" TIW Liner HGR PKR @ 8916'. 4-1/2" BKR KB PKR @ 9272'. 4-1/2" Camco TRCF SSSV (Locked Out) @ 2217' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 05/05/2002 Subsequent to operation 06/01/2002 OiI-Bbl 778 989 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl 33051 0 40884 0 Casing Pressure Tubing Pressure 1376 906 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _ 16. Status of well classification as: Oil _X Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. D ,W~. ~R _~h~ .~~J~)~ Title: Technical Assistant e ayne .Sc norr Form 10-404 Rev 06/15/88 · Date June 06, 2002 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE'~'~~ 05/21/2002 05/25/2002 05/26/2002 05/21/02 05/25/02 18-32A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PACKERS/BRIDGE PLUGS/POGLMS: DRIFT/TAG PACKERS/BRIDGE PLUGS/POGLMS: CAST IRON BRIDGE PLUG; DRIFT/TAG PACKERS/BRIDGE PLUGS/POGLMS: CAST IRON BRIDGE PLUG; DRIFT/TAG EVENT SUMMARY DRIFT 2.25" CENT TO 9825' SLM (2-7/8 LINER TOP @ 9765' MD). <<<WELL LEFT SI.>>> MIRU CTU #5. KNOCK DOWN WHP W/10 BBL METH/WTR & 90 BBL 1%KCL. RIH W/2.25" NOZZLE FOR DRIFT. TAG PBTD @ 11535' (UP). POH. STANDBY DUE TO FIELD RESPONSE TO C-PAD. CONTINUE. MU BAKER 1 11/16" MHA, DS CCL, HALIBURTON 2 7/8" CIBP. KILL WELL W/10 BBL METH/WTR & 130 BBL 1% KCL. RIH. PARK @ 4921', PUMP TO CHECK CCL TOOL. NO PULSE OBSERVED. O5/26/O2 PARKED @ 4950', PUMPING. NO PULSES OBSERVED. LOG TO LOOK FOR PULSES. NONE OBSERVED. POH TO CHANGE OUT TS. INSTALL BACK UP CCL TOOL. TEST CCL IN LUBRICATOR, PUMPING TO TANK. GOT PULSES. RIH. CONFIRM TOOL OPERATIONAL AT 1300', OK. LOG FROM 10480'-9430'. NO SIGNAL. RIH TO TAG PBTD @ 11524'. DECISION TO POH. POH. LAY DOWN CIBP & CCL. PU 2.60" NOZZLE. RIH. TAG 3-3/16" X 2-7/8" XO. FLAG PIPE. POH. PICK UP HALLIBURTON CIBP. RIH. SET CIBP AT 11232'. TAG TO CONFIRM. POH. RD. NOTIFY DS THAT WELL IS READY TO POP. <<<JOB COMPLETE>>> Fluids Pumped BBLS 0 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 0 TEST) 72 METHANOL WATER 280 1% ECL WATER 160 1% SEAWATER 512 TOTAL Page I 5/1 O/2002 Schlumberger NO. 2069 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATrN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Endicott P.BAY Well Job # Log Description Date BL Sepia Color CD I2-4eB/S-13 J ~"7.-. 15 '7 PROD PROFILE/DEFT 04/22/02 1 1 D.S. 18-32A ~:~I-IOW 22199 MCNL 03/31/02 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 RECEIVED 2002 Schlumberger GeoQuest 3940 Arctic BIvd Anchorage, AK 99503 AFl'N: Sherrie Received b!~~l~ /_~~ · i 05/14/02 Schlumberger Alaska Data & Consulting Services 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 Al'tN: Beth NO. 2073 Company: State of Alaska Alaska Oil & Gas Cons Camm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD R-21 / ~ -/C~O PROD PROFILE 04/16/02 R-06A I c~'. ~7 INJECTION PROFILE 04/18/02 P-21B I c~'~'O~°c~ 'LEAK DETECTION LOG 05/02/02 I 1 W-37 l ~" OX:~q . !LEAK DETECTION LOG 04/02/02 1 1 NK-65 / C~ ~. O~ ~ 'LEAK DETECTION LOG 05/02/02 1 1 L1-31 J C~-O I .~ PRODUCTION PROFILE 04/09/02 1 1 N-21A 1 ~/~o -I 9 ~ PSP PROD PROFILE 04/27/02 1 1 D.S. 3-01 J ~7~-O '],~ PROD PROFILE/DEFT 04/16/02 1 1 D.S. 1-28 / ~3' O~ 5 PROD PROFILE/DEFT/GHOST 04/20/02 1 1 D.S. 18-32A nC)/" / (::) ""/ PROD PROFILE 03/21/02 1 1 K-14 ~ <~7- ~2)(~ PROD PROFILE 04/12/02 1 1 R-03A J ~ ~- I '1 J INJECTION PROFILE 04/18/02 1 1 P2-36 i c} 7-//~O PROD PROFILE/DEFT 04/05/02 1 1 D.S. 6-19 I ~- ilq PROD PROFILE 04/28/02 1 1 M-19A J ~-~-/~--~7 'LEAK DETECTION LOG 04111/02 1 1 R-24 ! ~-/~-~z~ PROD PROFILE 04/14/02 I 1 J-10 / ~) -.1~/(z2 PROD PROFILE 04/21/02 1 1 D.S. 1-32 1 ~-j~--/ PROD PROFILE 04~09/02 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) inc. Petrotectnical Data Center LR2-1 900 E. Benson Bivd. Anchorage, Alaska 99508 Date Delivered: RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATi'N: Sherrie Received~~ Transmittal Form BAKER HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference' BP Exploration, Inc. 18-32A Pmdhoe Bay Unit~o BP Exploration, Inc. H-07A Pmdhoe Bay Unit BP Exploration, Inc. !5,41BPB1 Pmdhoe Bay Unit 40 BP Exploration, Inc.: 4~41A PB2 P~dhOe Bay unit ~ B e Explorati on, Inc.: 05,12B: prudhoe: BaY unit: BP Exploration, Inc: 05L28A:: :PmdhoeBa~:unit~ol.~ Contains the following For Each Of The Above Wells: 1 - LAS Format disk .... :.., 1 '~.:,Measured~ De~th.:MWDi GR print': :.' · :: 114 'TvD'~ :~R.'~rint .i'~'. ::':" i .:' '.: Sent By: JosefBerg Received By: ~ Date: April 1, 2002 Date: RECEIVED PLEASE ACKNOWLEDGE RECEIPT BY SIGNIN~~~'~].~~': ....... OR FAXING YOUR COPY g~0ra!te ii::ii;ii~:i;;ii:'>; ................ ...... -- - .... · ..................... ......... .. ...',-2.2 ' ' ..' ' ..... .,i;'. .. . -':' :. . . · ' ]:.....:. .' .'...,, .... . ., . . ....... 'x;.: .... - ............ :,..?... .............. --..--..' FAX: (403) 537-3767 , ........ Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 ~ ............. 08/01/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-571'1 ATTN: Sherrie NO. 1345 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD D.S. 18-28 I c/5 - oTz-/ PSP-LDL 07122/01 I 1 B-3'0A 2.0 ~-- ) ~3 5 21329 ~ICNL 06125101 I I 1 E-35A ~Ol-~l? 21333 MCNL 07/03101 I t 1 K-10A -Zt31'- O~ 21331 MCNL 06/27101 I I 1 21328 MCNL 0612tl01 t I 1 D.S. t8-32A ~-oI Y-15A '?,~ I,-O~/ 21334 MCNL 07/05101 1 t 1 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: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A-I-tN: Sherrie RECEIVED AUG 0 3 ?.,001 Received by: Alaeka Oil & Gas Cons. Commisaon Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well OIL ]~1 GAS r-1 SUSPENDED r-! ABANDONED BI SERVICE BI 2. Name of Operator ~--..~..r..~,~-.,,~, 'l,r~l~ '7. Permit Number BP Exploration (Alaska), Inc. -~' 201-107 3. Address~ 8. APl Number P. O. Box 196612 Anchorage, AK 99519-6612 ; 50-029-22585-01 4. Location of well at surface~'"""-'----~ 9. Unit or Lease Name COMPLET~0~.,; 1647' FNL, 41' FEL, Sec. 24, T11 N, R14E, UM (asp's 691737, 5960220) I I Prudhoe Bay Unit At Top Producing Interval ! ~:','T~ i 10. Well Number ' .,~r~' ~_.~.~ ~ 18-32A 1195' FNL, 910' FEL, SEC 19, T11 N, R15E, UM (asp's 695809, 5960777)~ ;~:;~'C..i: At T ota Depth 'i ..... 11.F,e,d and Poo 788' FNL, 4852' FEL, SEC 20, T11 N, R15E, UM (asp's 697134, 5961219) "' ................... 4 Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 54 feetI ADL 28321 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions June 14, 2001 June 18, 2001 June 22, 2001I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11601' MD /8681' TVD 11535' MD /8680' TVD YES ~'1 No E]I 2217' feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD GR & Mem GR/CNL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE w-r. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 260 Sx AS 10-3/4" 45.5# NT-80 Surface 3830' 13-1/2" 1283 Sx PFE & 212 Sx Class G 7-5/8" 29.7# USS-95 Surface 9223' 9-7/8" 295 Sx Class G 4-1/2" 12.6# L-80 8916' 9688' 6-3/4" 220 Sx Class G 3-1/2" x 3-3/16" 9.3#/6.2#/ L-80 9272' 11600' 3-3/4" 17 bbls 15.8 ppg Class G x 2-7/8" 6.16# 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) (2" PJ carriers, 6 SPF, & Zone lA) 4-1/2" 12.6# L-80 8908' 8850' 10500' - 11200' MD; 8695' - 8691' TVD 8916' 11250' - 11530' MD; 8689' - 8680' TVD 9272' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See Sidetrack Summary for details) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 30, 2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 7/3/2001 10.0 Test Period >I 12610 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. -1552 psi 24-Hour Rate > 1541 19432 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. ,- .~o * This 10-407 is submitted as directed per the 10-401 form approved June 6, 2001 (Permit #201-107) t.-- Form 10-407 r'~bmit in duplicat_~ Rev. 7-1-80 CONTINUED ON REVERSE SIDE (.~ ~" ~ · ORIGINAL GEOLOGIC MARK ~ FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and MEAS. DEPTH TRUE VERT. DEPTH gravity, GOR, and time of each phase. Top of Sag River Sand 9188' 8198' Top of Shublik 9230' 8232' Top of Sadlerochit 9296' 8284' Top of Zone 1 9922' 8653' Top of Zone lA 10020' 8680' 31. LIST OF ATTACHMENTS Summary of 18-32A CT Sidetrack Drilling Operations + End of Well Survey + Updated Schematic. 32. I hereby certify that the tollowingLs true and correct to the best o! my knowledge. Signed ~ ~ ~D&---W Coiled Tubin,q En,qineer Date July 30, 2001 Prepared by Paul Rauf 564-5799. 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. RECEIVED Item 28: If no cores taken, indicate "none". Form 10-407 JUL 3 0' Z001 ORiGiNAL Alaska Oil & Gas Cons. Commission Anchorage 18-32A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING OPERATIONS SUMMARY Date Event Summary 6/12/2001: 6/13/2001: 6/14/2001: 6/15/2001: 6/16/2001: 6/17/2001: 6/18/2001: 6/19/2001: 6/20/2001: MIRU Nabors 3S. (Well to be drilled with Baker OXP system). Completed RU of Nabors 3S. Accepted rig @ 0830 hrs. Began PT of BOPE. Completed BOPE testing. RIH & tagged Whipstock Packer @ 9704'. Set Whipstick @ 9689' (top of Whipstock Tray). POOH w/setting tool. RIH w/Notch Mill & commenced window milling operations through the 4-1/2" Liner. Milled f/9687' & POOH. RIH w/Window Milling BHA. Milled window f/9688' to 9696' & into FM to 9706'. Dressed window interval & POOH. RIH & drilled to 9890'. Differentually stuck - freed by pumping Crude. Conditioned OH. Drilled to 10100' & POOH. RIH & drilled ahead to 10195'. Drilled to 10261' & POOH. RIH & drilled to 10422'. POOH. RIH & drilled to 10548'. Swapped out mud. Drilled ahead to 10969'. POOH. RIH & drilled to TD @ 11601'. Conditioned OH for liner & circulated in new mud. POOH. MU 3-1/2" x 3-3/16" x 2-7/8" liner. RIH & landed liner @ 11600'. TOL = 9272'. Pumped 17 bbls of 15.8 ppg Class G Cement to cement liner in place & to abandon the following perforations (well 18-32): 9520' - 9595' MD (Zone lA) Reference Log: Z-Den 9/25/1995. 9665' - 9704' MD (Zone lA) 6/21/2001: 6/22/2001: 6/29/2001: Contaminated cement w/Biozan & jetted contaminated cement from the wellbore. POOH w/ CT. RIH w/Memory CNL/GR tools & logged well f/9200' to 11528'. POOH w/logging tools. PT'd liner lap - failed. RIH w/Baker KB Packer & set it @ 9272'. PT'd liner lap to 2000 psi for 30 min - no leak off. POOH. RIH w/CT conveyed perforating guns & tagged PBTD @ 11535'. Shot 980' of initial perfs f/: 10500' - 11200' MD (Zone lA) 11250' - 11530' MD (Zone lA) Used 2" PJ carriers & all shots @ 6 SPF, random orientation, & overbalanced press. POOH w/guns. LD perf guns - ASF. FP'd well to 2000' w/Methanol Water. RDMOL. Rig released @ 1100 hrs. RIH & installed new GLV design. Placed well on initial production & obtained a representative well test. Sidetrack Summary Page I TREE = 4-1/8" 5M QVV WELL HEAD = FMC ACTUATOR-- BAKERC KB. REV = 53.45' BF. B_EV = KOP= 2607' Max Anille = 99 ~ 10257' Datum rvD = Datum ']'VD= 8800' SS 18-3 2A [ 10-3/4"CSG, 45.5#, L-80, ID: 9.953" [d 3830' 2217' SAFETY NOTES: OPEN SLT'D LIaR BELOW WHIPSTOCK PKR@ 9704'. WB_L EXCEEDS 70° @ 9806' AND GOES HORIZONTAL @ 10201'. 4-1/2" CA MOO TRCF SSSV, ID = 3.812" LOCKED OUT (SET 04/16/96) GAS LIFT MANDRR S Minimum ID = 2.37" @ 9765' [ 3-3/16"X 2-7/8" LNR XO 8850' Id 7-5/8" X 4-1/2" BAKER S PKR, ID = 3.875" [ 4-1/2"'1'BG, 12.6#, L-80,0.0152bpf, ID= 3.958" [d 8907' 8885' 8908' 4-1/2" I-ES XN NIP, ID MILLED TO 3.80" BY CTD [ Id 4-1/2" TUBING TAIL WLEG Id ELrvD 'FI' NOT LOGGED TOP OF 5-1/2" LNR 5-1/Z' LNR, 17#, L-80, 0.0232 bpf, ID= 4.892" Id TOP OF 4-1/2" LNR Id 7-5/8" LNR, 29.7#,S-95,0.0459 bpf, ID= 6.875" Id 8921' ~- 8923' I 8923' I 9223' ~ PERFORATION SUMMA RY REF LOG: Z-Den on 09/25/95 ANGLE AT TOP PERF: 91 @ 10500' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10500 - 11200 O 06/21/01 2" 6 11250 - 11530 O 06/21101 i · 4-1/2" LNR, 12.6#, L-80,0.0152bpf, ID= 3.958" Id 11095' I 8916' I-[ 7-5/8" x 5-1/2" TIW LINER HGR PKR, ID = 4.880" 8923' Id 5-1/2" X 4-1/2" XO, ID = 3.958" [ 9272' I--] 4-1/2"BKRKBPKR'ID=2'39"I 9277' Id 3-3/4" BKRDEFLOYMENTSLV, D =3.00" I 9318' I-I 9689' H 3-1f2" X3-3/16" XO, D =2.80" I TOP OF BKR WHIPSTOCK ] ] PBTD H 11535' 9704' I-I TOP OF BKR WHIPSTOCK PKR 9765' Id 3-3/16" X 2-7/8" XO, ID: 2.37" 1232' [~ HES CIBP, 05/26/02 4-1/2" MILLOU'F WINDOW 9687' - 9696' 11601' DATE FEV BY COMMENTS DATE REV BY COMMENTS 10/03/95 ORIGNA L COMPLETION 06/26/01 CH/TP CTD SIDETRACK 04/04/02 JKB/KK PERF CORRECTIONS 05/26/02 DDW/tlh SET ClBP PRUDHOE BAY UNIT WELL: 18-32A PERMIT No: 201-107 APl No: 50-029-22585-00 Sec. 24, T11N, R14E, 3632'NSL & 41'WFI BP Exploration (Alaska) TREE -- 4-1/8" 5M CPA/ WELLH~.A D = FMC ACTUATOR = BAKER C '~Bi"~ ~ ........................ 53.45' 'AOP':: 2607' '~;"~,~'~'i'~"~' .... 9'~~@' Datum MD = ' 'Datum TVD 8800' Ss 10-3/4" CSG, 45.5#, L-80, ID = 9.953" Id 3830' Minimum ID = 2.37" @ 9765' 3-3/16" X 2-7/8" LNR XO 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" Id 8907' I TOPOF 5-1/2" LNR Id 8921' 5-1/2"LNR, 17#,L-80,0.0232bpf, ID=4.892" Id 8923' 7-5/8" LNR, 29.7#, S-95, 0.0459 bpf, ID = 6.875" Id 9223' PERFORATION SUMMARY REF LOG: Z-Den on 09/25/95 ANGLE AT TOP PERF: 91 @ 10500' 2-7/8" SIDETRACK LNR TCP 2" 6 11250-11530 O 106/21/011 4-1/2" LNR, 12.6#, L-80, 0.0152 bpf, ID = 3.958" Id 11095' 18-32A 2217' SAFETY NOTES: OPEN SLT'D LNR BELOW WHIPSTOCK PKR @ 9704'. WELL EXCEEDS 70° @ 9806' AND GOES HORIZONTAL @ 10201'. 4-1/2" CAMCO TRCF SSSV, ID = 3.812" I I LOCKED OUT (SET 04/16/96) GAS LIFT MANDRELS 8850' 04/21/99 04/21/99 Id 7-5/8"X4-1/2" BAKERS PKR, ID= 3.875" I 8885' 8908' Id 4-1/2" HES XN NIP, ID MILLED TO 3.80" BY CTD I Id Id 4-1/2" TUBING TAIL WLEG I ELMD '1-r NOT LOGGED 8916' I-i 7-5/8"X5-1/2"TIVVLINERHGRPKR, ID=4.880" 8923' I~ 5-1/2"X4-1/2" XO, ID = 3.958" I 9272' I~ 4'1/2"BKRKBPKR'ID:2'39"I 9277' I~ 3-3/4" BKR DEPLOYMENT SLV, ID: 3.00" I 9318' I-i 9689' Id 3-1/2" X 3-3/16" XO, ID = 2.80" TOPOF BKRWHIPSTOCK I 9704' I~ TOP OF BKR WHIPSTOCK PKR I 9765' I --~ 3-3/16" X 2-7/8" XO, ID = 2.37" / 11600'I 4-1/2" MILLOUT WINDOW 9688' - 9696' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/03/95 ORIGINAL COMPLETION 06/26/01 CH/TP CTD SIDETRACK 01/08/01 SIS-Isl CONVERTED TO CANVAS 07/30/01 pcr 10-407 revisions 02/22/01 SIS-LG REVISION 05/31/01 RN/tlh CORRECTIONS 06/21/01 /TP ADD WHIPSTOCK ANCHOR PRUDHOE BAY UNIT WELL: 18-32A PERMIT No: 201-107 APl No: 50-029-22585-01 Sec. 24, T11N, R14E, 3632' NSL & 41' WEL BP Exploration (Alaska) ObP BP Amoco Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Field: Prudhoe Bay Site: PB DS 18 Well: 18-32 Wellpnth: 18-32A Date: 7/25/2001 Time: 16:27:28 Page: 1 Co-ordbiate(NE) Reference: Well: 18-32, True North Yertlml (T~rD) Refemuce: 59: 32 5/3111996 09:46 54.0 Section (VS) Reference: Well (0.00N,0.00E,45.00Azi) 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: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2001 Site: PB DS 18 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5959213.15 ft Latitude: 70 17 35.252 N 691583.44 ft Longitude: 148 26 55,555 W North Reference: True Grid Convergence: 1.46 deg Well: 18-32 Slot Name: 32 18-32 Well Position: +N/-S 1002.27 ft Northing: 5960219.60 ff Latitude: 70 17 45.110 N +E/-W 178.86 ft Easting: 691736.69 ft Longitude: 148 26 50.341 W Position Uncertainty: 0.00 ff Wellpath: 18-32A Drilled From: 18-32 500292258501 Tie-on Depth: 9687.00 ft Current Datum: 59: 32 5/31/1996 09:46 Height 54.00 ft Above System Datum: Mean Sea Level Magnetic Data: 6/13/2001 Declination: 26.79 deg Field Strength: 57505 nT Mag Dip Angle: 80.82 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg 0.00 0.00 0.00 45.00 Survey: MW D Start Date: 6/18/2001 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation , Survey 9687.00 57.60 62.75 8564.66 8510.66 353.08 3796.70 5960669.40 695522.92 0.00 2934.34 9716.00 59.40 53.00 8579.64 8525.64 366.22 3817.59 5960683.07 695543.47 29.32 2958.40 9746.00 63.50 55.40 8594.18 8540.18 381.62 3838.96 5960699.01 695564.44 15.37 2984.40 9776.00 66.50 61.00 8606.86 8552.86 395.93 3862.06 5960713.89 695587.17 19.65 3010.85 9806.00 70.30 64.80 8617.91 8563.91 408.62 3886.89 5960727.21 695611.66 17.29 3037.38 9636.00 73.10 66.00 8627.33 8573.33 420.47 3912.78 5960739.72 695637.25 10,08 3064.07 9866.00 72.90 71.90 8636.11 8582.11 430.77 3939.54 5960750.70 695663.73 18.82 3090.28 9896.00 72.80 75,60 8644.96 8590.96 438.79 3967.06 5960759.42 695691.03 11.79 3115.41 9926.00 73.20 79.20 8653.73 8599.73 445.05 3995.05 5960766.39 695718.86 11.55 3139.62 9956.00 73,50 83.10 8662.33 8608.33 449,47 4023.44 5960771.53 695747.13 12.49 3162.83 9986.00 74.00 86.30 8670.73 8616.73 452,13 4052.12 5960774.92 695775.72 10.38 3184.98 10016.00 75.00 88.70 8678.74 8624,74 453,39 4081.00 5960776.92 695804.56 8.40 3206.29 10046.00 75.70 92.80 8686.33 8632.33 453,01 4110.01 5960777.27 695833.57 13.43 3226.54 10078.00 76.40 95.40 8694.05 8640.05 450,78 4140.98 5960775.84 695864.59 8.18 3246.87 10107.00 79.10 99.00 8700.20 8646.20 447.23 4169.09 5960773.01 695892.78 15.29 3264.23 10140.00 86.90 104.40 8704.23 8650.23 440,58 4201.13 5960767.18 695924.97 28.67 3282.18 10174.00 86.00 115.10 8706.34 8652.34 429.13 4233.02 5960756.55 695957.14 31.52 3296.64 10201.00 91,90 121.60 8706.83 8652.83 416.33 4256.75 5960744.35 695981.19 32.50 3304.36 BP Amoco Baker Hughes INTEQ Survey Report Company: BP Amoco Date: 7/25/2001 Time: 16:27:28 Page: Fiekl: Prudhoe Bay Ce-er41aate(NE) Reference: Well: 18.32, True North Site: PB DS 18 Vertical (TVD) Reference: 59: 32 5/31/1996 09:46 54.0 Well: 18-32 Sceflen (~$) Reference: Well (0.00N,0.00E,45.00Azi) Wellpatk: 18-32A Smwey Calenlatlen Metko4: Minimum Curvature Db: Oracle Survey MD lid Azim TVD SSTVD N/S E/W MapN MnpE DLS VS 10227.00 93.50 118.50 8705.61 8651.61 403.32 4279.23 5960731.93 696003.99 13.41 3311.06 10257.00 99.10 111.80 8702.31 8648.31 390.65 4306.19 5960719.95 696031.26 29.00 3321.17 10287.00 96.90 108.80 8698.14 8644.14 380.35 4334.05 5960710.36 696059.37 12.32 3333.58 10317.00 94.00 105.60 8695.29 8641.29 371.52 4362.57 5960702.27 696088.11 14.36 3347.51 10347.00 91.70 102.50 8693.80 8639.80 364.25 4391.63 5960695.74 696117.35 12.86 3362.92 10377.00 91.20 98.20 8693.04 8639.04 358.86 4421.13 5960691.11 696146.97 14.43 3379.97 10407.00 88.10 97.70 8693.22 8639.22 354.72 4450.64 5960687.72 696176.77 10.47 3398.04 10437.00 87.60 100.40 8694.34 8640.34 350.00 4480.44 5960683.76 696206.48 9.15 3415.64 10467.00 89.10 97.20 8695.21 8641.21 345.41 4510.07 5960679.93 696236.22 11.78 3433.34 10500.00 91.30 96.40 8695.09 8641.09 341.51 4542.83 5960676.86 696269.07 7.09 3453.75 10530.00 90.80 92.80 8694.54 8640.54 339.10 4572.73 5960675.22 696299.01 12.11 3473.19 10560.00 89.40 87.10 8694.49 8640.49 339.13 4602.71 5960676.01 696328.99 19.56 3494.41 10590.00 88.90 82.70 8694.94 8640.94 341.79 4632.58 5960679.44 696358.78 14.76 3517.42 10620.00 88.90 79.70 8695.51 8641.51 346.38 4662.22 5960684.78 696388.29 10.00 3541.62 10650.00 90.10 76.00 8695.77 8641.77 352.69 4691.54 5960691.84 696417.44 12.97 3566.82 10682.00 92.10 72.10 8695.16 8641.16 361.48 4722.30 5960701.41 696447.96 13.69 3594.78 10711.00 93.10 67.40 8693.84 8639.64 371.51 4749.47 5960712.12 696474.86 16.55 3621.08 10740.00 91.50 62.70 8692.68 8638.68 383.73 4775.73 5960725.01 696500.80 17.11 3648.29 10770.00 90.10 58.90 8692.26 8638.26 398.36 4801.91 5960740.30 696526.60 13.50 3677.15 10800.00 89.10 54.80 8692.47 8638.47 414.76 4827.02 5960757.33 696551.28 14.07 3706.50 10830.00 89.10 50.00 8692.94 8638.94 433.06 4850.78 5960776.23 696574.57 16.00 3736.24 10860.00 88.90 45.90 8693.46 8639.46 453.14 4873.05 5960796.88 696596.31 13.68 3766.19 10892.00 88.80 40.80 8694.11 8640.11 476.40 4895.01 5960820.68 696617.67 15.94 3798.16 10921.00 89.60 37.10 8694.51 8640.51 498,95 4913.23 5960843.69 696635.31 13.05 3826.99 10950.00 90.50 33.60 8694.49 8640.49 522.60 4930.01 5960867.76 696651.48 12.46 3855.57 10988.00 90.80 26.90 8694.06 8640.06 555.40 4949.14 5960901.04 696669.76 17.65 3892.30 11010.00 90.20 23.90 8693.86 8639.86 575.27 4958.57 5960921.14 696678.69 13.91 3913.02 11040.00 90.00 24.60 8693.81 8639.81 602.62 4970.90 5960948.80 696690.31 2.43 3941.07 11070.00 90.00 27.10 8693.81 8639.81 629.62 4983.98 5960976.12 696702,69 8.33 3969.41 11100.00 90.20 31.30 8693.76 8639.76 655.80 4998.61 5961002.68 696716.65 14.02 3998.27 11130.00 90.90 35.20 8693.47 8639.47 680.88 5015.05 5961028.15 696732.45 13.21 4027.64 11160.00 91.70 38.20 8692.79 8638.79 704.93 5032.97 5961052.64 696749.75 10.35 4057.31 11190.00 92.00 41.00 8691.82 8637.82 728.03 5052.09 5961076.22 696768.27 9.38 4087.16 11220.00 93.10 44.30 8690.49 8636.49 750.07 5072.39 5961098.77 696788.00 11.58 4117.10 11250.00 93.40 49.40 8688.78 8634.78 770.55 5094.23 5961119.80 696809.31 17.00 4147.03 11280.00 94.10 53,60 8686.82 8632.82 789.18 5117.65 5961139.02 696832.25 14.16 4176.76 11310.00 94.50 57.80 8684.57 8630.57 806.03 5142.36 5961156.50 696856.52 14.02 4206.15 11340.00 94.60 62.10 8682.19 8628.19 821.01 5168.24 5961172.13 696882.01 14.29 4235.04 11370.00 93.90 65.90 8679.97 8625.97 834.12 5195.13 5961185.92 696908.55 12.85 4263.32 11400.00 91.20 69.90 8678.63 8624.63 645.39 5222.89 5961197.90 696936.01 16.07 4290.92 11430.00 91.70 75.70 8677.87 8623.87 854.25 5251.52 5961207.49 696964.41 19.40 4317.44 11460.00 89.40 79.40 8677.58 8623.58 860.72 5280.81 5961214.70 696993.52 14.52 4342.72 11490.00 87.40 64.70 8678.42 8624.42 864.87 5310.50 5961219.60 697023.09 18.88 4366.64 11520.00 87.90 89.30 8679.65 8625.65 866.43 5340.42 5961221.93 697052.96 15.41 4388.91 11550.00 89.20 94.60 8680.41 8626.41 865.41 5370.38 5961221.68 697082.94 18.18 4409.37 11601.00 89.20 94.60 8681.12 8627.12 861.32 5421.22 5961218.68 697133.85 0.00 4442.43 REF/RENCE INFORMATION CC~ord]nale (N/E) Reference Well Centre 1832 Tree Nodh V~Cacai FFVD/Reference System Mean Sea Lewl Section S) Reference Slot- 32 MeastJredDeelhRefemnce 59 32 5/31/1996 09:46 5408 Calculation Method Minimum Curvature 8100 8150 t~250 ;~8550 8700 8750 3300 MOO 350(I 3000 3700 3800 3900 4000 4100 4200 4300 44£ 4500 4600 4700 ,~800 49[ 5000 §100 52(1( b300 b400 5SUG 560[ 2800 2850 2900 2950 3000 3050 3100 3150 3200 3250 3:30[) 3350 25400 3450 a[~oo 35bD 3600 38~ 3f00 3750 3800 3850 ouuu 3950 40Of~ ~50 4100 4150 4200 4250 438 4]~0 4480 q4~O 4b0O 455O 46OO 4650 4~00 7/25 2~1 4:29 PM ALASKA OIL AND GAS CONSERYA~ION COPlMISSION TONY KNOWLES, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark Johnson CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit 18-32A ' BP Exploration (Alaska) Inc Permit No: 201,107 Sur Loc: 3632' NSL, 41' WEL SEC. 24, TllN, R14E, UM Btmhole Loc. 4454' NSL, 459' EWL, SEC. 20, T1 IN, R15E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to re&ill the above referenced well. The permit to re&ill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit 18-32A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, C~nm~-a~y ylor~~tv~ Chair BY ORDER OF THE COMMISSION DATED this .~ day of June, 2001 jjc/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. T~,ANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK 1 CHECK WHAT APPLIES STANDARD LETTER "CLUE" DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR D]~POSAL (~) NO ANNULAR DISPOSAL ( ) YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS ( ) YES + SPACING EXCEPTION The permit is for a new wellbore segment of existing well , Permit No, APl No. __. Production should continue to be. reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(0, 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 permi0. Annular disposal has not been requested ~.. Annular Disposal of drilling wastes will not be approved... Annular Disposal of drilling wastes will not be approved... Please note that an disposal of fluids generated... Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance ~of a conservation order approving a spacing exception. (Company Name} will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates STATE OF ALASKA ALASKA ~' _AND GAS CONSERVATION COMMi~_ _,ION PERMIT TO DRILL 20 AAC 25.005 [] Ddll [] Reddll 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE - 54' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028321 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 2O AAC 25.025) 3632' NSL, 41' WEL, SEC. 24, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 3901' NSL, 3501' NWL, SEC. 19, T11N, R15E, UM 18-32A Number 2S100302630-277 At total depth 9. Approximate spud date 4454' NSL, 459' NWL, SEC. 20, T11N, R15E, UM 06/12/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028326, 4454' MDI No Close Approach 2560 11594' MD / 8643' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} o Kick Off Depth 9700' MD Maximum Hole Angle 91 Maximum surface 2470 psig, At total depth (TVD) 8800' / 3350 psig 18. Casing Program Specifications Setting Depth Size To 3 Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 3-3/16"x2-7/s"6.2#/6.16# L-80 ST-L 2274' 9320' 8303' 11594' 8643' 34 sx Class 'G' , ,, 19. To be completed for Redrill, Re-entry, and Deepen operations. ' Present well condition summary Total depth: measured 11095 feet Plugs (measured) true vertical 8709 feet Effective depth: measured 11095 feet Junk (measured) true vertical 8709 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 260 sx Arcticset (Approx.) 110' 110' Surface 3795' 10-3/4" 1283 sx PF 'E', 212 sx Class 'G' 3830' 3707' Intermediate 9189' 7-5/8" 295 sx Class 'G' 9223' 8226' Production Liner 2179' 4-1/2" 220 sx Class 'G' 8916' - 11095' 7975' - 8709' ,, ,,, 9 ~,,~,~,~,,t Perforation depth: measured 9520' - 9595', 9665' - 10151' ~,...,i,.~ii~,~ f'.} Slotted Liner: 10151'- 11093' true vertical 8459' - 8512', 8553' - 8709' .~...~as!(a 0itc~ .~ ~-.~,s {;gi~s. 60~'~issio~ Slotted Liner: 8709' - 8709' '20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Johnson, 564-5666 Prepared By Name/Number: Terrie Hubble, 564-4628 '21. I hereby certify that the foregoing is true.,a~d correct to the best of my knowledge __ Signed Mark Johnson ~ ~, L~Title CT Drilling Engineer Date · ~...,,~ Permit Number ........ I APl 'N~rt~er .............................. i ........ ~Ol:)~0val Date ...... I See cover I'ett~r' '" ' ? I I [ I_~/0 ~ l for other requirements Conditions of Approval: Samples Required [] Yes ~ No Mud Lb~Re~luired [] Yes ~ No Hydrogen Sulfide Measures [] Yes [] No Directional Survey Required ~[ Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ~1~3.5K psi for CTU Other: by order of Approved By Original Signed B~"~ ~, I i~ 1 [~, 1/I i Commissioner the commission Date Form 10-401 Rev. 12-~;~n¥0echsli .... SL plicate BP Coiled Tubing Drilling 18-32a Sidetrack Summary of Operations: Well 18-32 is scheduled for a through tubing sidetrack with the N3S coil drilling rig. The 18-32a sidetrack will kick off in Zone 2 from a window milled off a pre-set mechanical whipstock. 18-32a will target Zone lA reserves. Phase 1: 1. 2. 3. 4. Mill XN nipple, set whipstock. Planned for June 5, 2001. The IA will be liquid packed and an MIT performed. Mill XN nipple at 8885' to 3.8" ID - service coil. Run dummy whipstock drift to 9750' - slickline E-Line will set a mechanical whipstock/packer at approx. 9690' MD in the 4 1/2" liner. The packer will permanently shutoff all perforations and slotted liner below 9690' MD. Sundry already submitted. Phase 2: 5. Mill window, Drill and Complete sidetrack: Planned for June 12, 2001. Ddlling coil will be used to mill the window and drill the directional hole per attached plan. The sidetrack will be completed with a cemented liner. Mud Program: . Phase 1: Seawater . Phase 2: FIo-Pro (8.6 - 8.9 ppg) Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject . All Class I wastes will go to Pad 3 for disposal. Casing Program: · A combination 3 3/16" x 2 7/8" liner will be cemented from TD to approximately 370 fi window with a minimum of 13 bbls cement. 2 7/8" will be run from 11594' TD to ~9750' (~1844'). The liner will then crossover to 3 3/16" from 9750' to planned top of liner at 9320' (430') in the existing 4 %" liner. This running of 3 3/16" from TOL to ~60' out the window will allow for a slimhole sidetrack exit opportunity in the future. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2000 psi. · When running 3 3/16" liner, a 3 1/2" safety joint with TIW valve on top and XO to 3 3/16" liner on bottom will be ready on the rig floor if needed. Directional · See attached directional plan. Max. hole angle is 91 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray will be run over all of the open hole section. A Memory CNL will be run inside the liner. Hazards The last H2S reading on DS 18-32 was 5 ppm on 4/30/99. Lost circulation risk is Iow as no significant fault crossings are expected. Reservoir Pressure Res. press, is estimated to be 3350 psi at 8800ss (7.3 ppg EMW). Max. surface pressure with gas (0.10 psi/fi) to surface is 2470 psi. Baker S Pkr @ 8,850' 4.5" XN Nipple @ 8,885' 4.5" WLEG 8,908' Top TIW liner hanger/pkr 8,916' 7 5/8" 29.7# S-95 liner @ 9,223' Existing perfs to be abandoned by new CTD sidetrack liner. Top of Whipstock approx. 9690'. Whipstock packer will serve to abandon perfs and slotted liner below. , 18-32a Proposed Completion 10 3/4" @ 3830 1/2" 12.6# L-80 tubing --TRSSSV w/3.812" ID @ 2217' Gas Lift Mandrels: 3899' 6765' 8782' 3 3116" Top of 3 3116" liner approx. 9320' [:;ertorat~ons 2 718" TD at 594' XO 3 3116" x 2 7~8" 60' out of window at-9750' md Bonzai Cementing tools @ 10,151 4 112" shoe @ 11,095' BP Amoco WELLPATH DETAILS IObp Plan #103 18-32A 500292258501 Parent Wellpath: 1832 T~ on MD: 9700.00 Rig: Nabors 3e Ref. Dalum: 59: 32 ~3111995 09:46 54.00ft V. Sectio~ OriginOrigin Starting Angle +FU-S +F-/-W From TVD 4S.00' 0.~0 0.O0 0.00 REFERENCEINFORMA~ON Co-ordinate (N/E) Reference: Well Centre: 18-32, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Slot- 32 (0.00N,0.0OE) Measured Depth Reference: 59: 32 5/31/1996 09:46 54.00 1300 1200 1100 ~ 1000 HUGHES INTEQ LEGEND ...... 18-~2 (18-~2) Plan #103 18-32A ...... Plan #103 T Azimuths to True North I Plan: Plan #103 (18-32/Plan #103 18-32A) r Magnetic North: 26.79'I Created By:. James Ohlinger Date: 24/055,"2001 Magnetic Field Checked: Date: Strength: 57491nT Dip Angle: 80.81 Date: 24/055/2001 ~ ,:~ ~.., ,.~.~, .~,~,- ,. .... Model: BGGM2000I~.~...~.~.~,.~.~=~n,:~,/-~'~ ' Calculation Method: Minimum Curvature 8100 200'"i 6150 ,lOO': 8200 0 626o ,~ 8450 Tm-in Po~ion 8650: '"'"'"-'~'~-~'~ ~_~ ---: 87OO i 18-32A Polygon~ '] -'! P~'k #10~ 18-32A) 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4800 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 6100 West(-)/East(+) [t 00ft/in] 8750 2800 2850 2900 2950 3000 3050 3100 3150 3200 3250 3300 3350 3400 3450 3500 3550 3600 3650 3700 3750 3800 3850 3900 3950 4000 4050 4100 4150 4200 4250 4300 4350 4400 4450 4500 4550 4600 4650 4700 Vertical Section at 45.00' [50ft/ln] · Baker Hughes INTEQ %~ Baker Hughes INTEQ Planning Report Field: Pmdhoe Bay Co-ordinate(NE) Reference: W~I: 18-32, Trt~3 North Site: PB DS 18 Vertical (TVD) Reference: Sy~em: Me, an Sea Level ~'ell: 18-32 ~-ctien (V S) Reference: Well (0.00N,0.00E.45.00A~i) ':i::!!i.{:ii.:';;~ : .... Welll~th: Plan 0103 18 32A .~rvey Calculation .Mt~hod: Minimum Curvature Db: Sybase ·. ,:...~--- .-~ ...... .- =.-: ._-;.. · ,:,:...~.,_-~.. ......... . .' ........... ,-,,.. ........................ ..., ..... :,. ·. .. ....................... Field: Pmdhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 M~p Zene: Alaska, Zone 4 Goo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: BGGM2000 Site: PB DS 18 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5959213.15 ft Latitude: 70 17 35.252 N 691583.44 ft Longitude: 148 26 55.555 W North Reference: True Grid Convergence: 1.46 deg Well: 18-32 Slot Name: 32 18-32 Well Position: +N/-S 1002.27 ft Northing: 5960219.60 ft Latitude: 70 17 45.110 N +E/-W 178.86 ft Easting: 691736.69 ft Longitude: 148 26 50.341 W Position Uncertainty: 0.00 ft Wellpath: Plan #103 18-32A Drilled From: 18-32 500292258501 Tie-on Depth: 9700.00 ft Current Datum: 59: 32 5/3111996 09:46 Height 54.00 ft Above System Datum: Mean Sea Level Magnetic Data: 241055/2001 Declination: 26.79 dog Field Strength: 57491 nT Mag Dip Angle: 130.81 dee Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ff ff dog 0.00 0.00 0.00 45.00 Plan: Plan #103 Date Composed: 241055/2001 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets .Map Map ,:~ l,atitude ---> <-- IAmgitudc: ---> Name l~nlcriplion TVD +N/-S +EI-W Northing Easling Dee Min Sec I~g Min ~c 18-3~ T1 ~.00 296.63 4272.51 5960625.10 6959~.99 70 17 48.015 N 148 24 45.805 W 18-32A T2 8650.00 657.51 4831.92 5961000.12 696549.98 70 17 51.561 N 148 24 29.493 W 18-32AT3 8640.00 842.16 5436.85 5961200.13 697149.98 70 17 53.373 N 148 24 11.855 W 18-32A Polygon 0.00 221.65 4270.59 5960550.10 695999.99 70 17 47.278 N 148 24 45.862 W -Polygon 1 0.00 221.65 4270,59 5960550.10 695999.99 70 17 47.278 N 148 24 45,862 W -Polygon 2 0.00 217.19 4445.54 5960550.11 696174.99 70 17 47.233 N 148 24 40.763 W -Polygon 3 0.00 697.30 5233.08 5961050.12 696949.98 70 17 51.950 N 148 24 17.798 W -Polygon 4 0.00 690.29 5508.01 5961050.13 697224.98 70 17 51.879 N 148 24 9.784 W -Polygon 5 0.00 890.24 5513.11 5961250.13 697224.98 70 17 53.845 N 148 24 9.631 W -Polygon 6 0.00 901.07 5088.22 5961250.12 696799.98 70 17 53.955 N 148 24 22.017 W -Polygon 7 0.00 421.60 4275.69 5960750.11 695999,99 70 17 49.244 N 148 24 45.710 W Annotation MD T'VD ft ft 9621.00 8~,74.~1'i' ' Ti;'ir; F°sition 9700.00 8517.59 Kick off Point 9730.00 8533.07 1 9830.00 8573.71 2 10140.00 8652.43 3 10213.00 8659.01 4 10913.00 8651.55 5 11594.00 8643.34 TD ( Baker Hughes INTEQ :. ..:~.. ~ .... ~' Baker Hughes INTEQ Planning Report i!~'ield::!!i!ii!:!iPmdhoe. Bay!:.!!!;:!!:!':. :::i:;!!i!!:!::i!::!!i::ii:: ..: Co-ordinatL~NE) Reference: Well: 18-32. True Nodh V. rlieal (TVD) Reference: Sy~em: Mean Sea Level Well: 18-32 : ~, ~l~n (VS) Referent: W~l (0.00N,0.~E.45.~i) ~llpath: P~n 0103 18-3~ ~: Su~'~'Calculafion M~hod: Minimum Cu~atum Db: Sybase Plan ~ection Information ::::::::::::::::::::::::::::::::::::~J:::::::::::::::::::m:::::::" TV/) +N/-S d-Ed-W ' .DLS..: Build '" Tarn: ".. 'I'FO. Target" . . . ' : ':i',i'~',~':','~!~ii',i',i:,i~:ii',ii~i:,;',~,':',~:,':':',~01:,',:,:,':i ............. , .............. ~ .............. ~ .... ':d~:!~.:,~..uegt~o~ ....... ~ ....... " . .......................... 9621 26 54.04 68.03 8474.26 330.32 3746.94 0.00 0.00 0.00 0.00 9648.66 56.65 65.52 8489.84 339.21 3767.65 12.14 9.53 -9.16 320.93 9680.38 57.39 63.92 8507.11 350.58 3791.71 4.83 2.33 -5.04 298.43 9700.00 58.04 60.47 8517.59 358.31 3806.37 15.23 3.31 -17.58 281.64 9730.00 59.84 60.47 8533.07 370.98 3828.73 6.00 6.00 0.00 0.00 9830.00 72.16 67.77 8573.71 410.49 3910.82 14.00 12.32 7.30 30.00 10140.95 79.84 112.04 8652.59 408.98 4203.91 14.00 2.47 14.24 86.00 10213.50 90.00 112.04 8659.00 381.90 4270.81 14.00 14.00 0.00 0.00 10913.50 90.99 28.04 8651.54 599,97 4871.38 12.00 0.14 -12.00 -89.00 11594.00 90,14 109.70 8643.34 824.97 5453.72 12.00 -0.12 12.00 90.00 Survey MD Incl · Azim SSTVD N/S E/W MapN MapE DLS VS TFO Tool fl deg deg ft ft ft ft ft . deg/100ft ff deg 962126 54.04 68.03 8474.26 330.32 3746.94 5960645.37 695473.77 0.00 2883.06 0.00 MWD 9625.00 54.39 67.68 8476.45 331.46 3749.75 5960646.59 695476.55 12.14 2885.85 320.93 MWD 9648.66 56.65 65.52 8489.64 339,21 3767.65 5960654.79 695494.24 12.15 2903.99 321.14 MWD 9680.38 57.39 63.92 8507.11 350.58 3791.71 5960666.77 695518.00 4.83 2929.04 298.43 MWD 9700.00 58.04 60.47 8517.59 358.31 3806.37 5960674.87 695532.46 15.23 2944.87 281.64 MWD 9730.00 59.84 60,47 8533.07 370.98 3828.73 5960688.10 695554.49 6.00 2969.64 0.00 MWD 9750.00 62.27 62.05 8542.75 379.39 3844.08 5960696.90 695569.61 14.00 2986.44 30.00 MWD 9775.00 65.34 63.93 8553.78 389.57 3864.06 5960707.59 695589.33 14.00 3007.77 29.23 MWD 9800.00 68.43 65.72 8563.60 399.35 3884.87 5960717.89 695609.88 14.00 3029.40 28.40 MWD 9825.00 71.54 67.44 8572.15 408.68 3906.42 5960727.77 695631.19 14.00 3051.24 27.70 MWD 9830.00 72.16 67.77 8573.71 410.49 3910.82 5960729.69 695635.54 13.98 3055.63 27.13 MWD 9850.00 72.38 70.70 8579.80 417.24 3928.63 5960736.90 695653.17 14.00 3073.00 86.00 MWD 9875.00 72.71 74.35 8587.30 424.40 3951.37 5960744.63 695675.72 14.00 3094.14 85.11 MWD 9900.00 73.11 77.99 8594.65 430.11 3974.57 5960750.93 695698.77 14.00 3114.58 84.01 MWD 9925.00 73.57 81.61 8601.82 434.35 3998.14 5960755.77 695722.22 14.00 3134.24 82.94 MWD 9950.00 74.09 85.22 8608.79 437.10 4021.99 5960759.13 695745.99 14.00 3153.05 81.90 MWD 9975.00 74.67 88.80 8615.52 438.36 4046.03 5960761.00 695769.99 14.00 3170.94 80.90 MWD 10000.00 75.31 92.36 8622.00 438.11 4070.17 5960761.37 695794.12 14.00 3187.84 79.93 MWD 10025.00 76.01 95.90 8628.19 436.36 4094.32 5960760.24 695818.31 14.00 3203.68 79.01 MWD 10050.00 76.75 99.42 8634.08 433.12 4118.40 5960757.61 695842.46 14.00 3218.41 78.13 MWD 10075.00 77.55 102.92 8639.64 428.40 4142.31 5960753.50 695866.48 14.00 3231.98 77.31 MWD 10076.68 77.60 103.15 8640.00 428.03 4143.90 5960753.17 695868.09 14.00 3232.85 76.53 18-32A 10100.00 78.38 106.39 8644.85 422.22 4165.96 5960747.92 695890.28 14.00 3244.33 76.48 MVVD 10125.00 79.26 109.85 8649.70 414.59 418926 5960740.89 695913.77 14.00 3255.41 75.80 MVVD 10126.61 79.35 110.06 8650.00 414.05 4190.75 5960740.39 695915.27 14.10 3256.08 68.20 18-32A 10140.95 79.84 112.04 8652.59 408.98 4203.91 5960735.66 695928.56 14.00 3261.81 75.92 MWD 10150.00 81.11 112.04 8654.09 405.63 4212.18 5960732.52 695936.91 14.00 3265.29 0.00 MVVD 10175.00 84.61 112.04 8657.20 396.32 4235.17 5960723.81 695960.13 14.00 3274.96 0.00 MWD 10200.00 88.11 112.04 8658.78 386.96 4258.30 5960715.04 695983.48 14.00 3284.69 0.00 MWD 10213.50 90.00 112.04 8659.00 381.90 4270.81 5960710.30 695996.12 14.02 3289.96 0.00 MVVD 10225.00 90.02 110.68 8659.00 377.71 4281.52 5960706.39 696006.93 12.00 3294.58 271.00 MVVD 10250.00 90.08 107.66 8658.98 369.51 4305.13 5960698.79 696030.75 12.00 3305.47 271.00 MVVD 10275.00 90.13 104,66 8658.93 362.55 4329.14 5960692.44 696054.92 12.00 3317.53 271.00 MWD 10300.00 90.18 101.66 8658.86 356.86 4353.48 5960687.38 696079.40 12.00 3330.71 270.99 MWD 10325.00 90.23 98.66 8658.77 352.45 4378.09 5960683.60 696104.11 12.00 3344.99 270.98 MVVD 10350.00 90.28 95.66 8658.66 349.33 4402.89 5960681.11 696128.98 12.00 3360.33 270.97 MVVD 10375.00 90.33 92.66 8668.53 347.52 4427.82 5960679.93 696153.95 12.00 3376.67 270.96 MWD 10400.00 90.38 89.66 8658.37 347.01 4452.81 5960680.07 696178.94 12.00 3393,99 270.94 MVVD 10425.00 90.43 86.66 8658.20 347.81 4477.80 5960681.50 696203.90 12.00 3412.22 270.92 MWD 10450.00 90.48 83.66 8658.00 349.92 4502.70 5960684.25 696228.74 12.00 3431.32 270.90 MWD ( .... Baker Hughes INTEQ ( ...................... Baker Hughes INTEQ Planning Report tn~ Field: Pmdhoe Bay Ce-~rdinale(NE) Reference: Well: 18-32. '[rue, North :iii:i:,iii: Site: PB DS 18 Vertical (TVI)) Refercace: System: Mean Sea Level i:! ::: !::!' i:: !We~ti :: :: :: :: :.i:::: :::: :?t~.32;:: ::::::::::! :::::::::::::::::::::::::::::::::::::::::::::::::: ::i::ii::: ::ii::::i!;i::!! :': :.!iii:::: ;i::ii:: i i ii i i i i::! i:: :i::::ii ::S~.i~iii ::~S~ ~~"'2. ii:, !i:: ii:::: ::; i:: ~1:: (Oi{i~NiO. ilOE~4s:~O0~)i :: :: i :: i ::::: ii:: I:: I!: :: ii:.:': ' Welipath: Plan #103 18 32A ~rvey Calculation Mahod: Minimum Curvature Db: Sybase ...................................................................................................................... Survey 10475.00 90.52 80.66 8657.78 353.33 4527.47 5960688.28 696253.41 12.00 3451.24 270.88 MWD 10500.00 90.56 77.66 8657.54 358.03 4552.02 5960693.61 696277.83 12.00 3471.92 270.85 MWD 10525.00 90.61 74.66 8657.29 364.00 4576.29 5960700.20 696301.94 12.00 3493.31 270.83 MWD 10550.00 90.65 71.56 8657.01 371.24 4600.21 5960708.05 696325.67 12.00 3515.35 270.79 MWD 10575.00 90.69 68.56 8656.72 379.73 4623.72 5960717.13 696348.95 12.00 3537.97 270.76 MWD 10600.00 90.72 65.66 8655.42 389.43 4646.76 5960727.41 696371.73 12.00 3561.12 270.73 MWD 10625.00 90.76 62.66 8656.09 400.32 4669.26 5960738.87 696393.94 12.00 3584.73 270.69 MWD 10650.00 90.79 59.66 8655.75 412.37 4691.15 5960751.46 696415.52 12.00 3608.74 270.65 MWD 10675.00 90.82 56.66 8655.40 425.56 4712.39 5960765.20 696436.41 12.00 3633.08 270.61 MVVD 10700.00 90.85 53.66 8655.04 439.84 4732.90 5960780.00 696456.56 12.00 3657.68 270.57 MWD 10725.00 90.88 50.66 8654.66 455.17 4752.64 5960795.83 696475.90 12.00 3682.48 270.52 MWD 10750.00 90.90 47.66 8654.27 471.51 4771.55 5960812.65 696494.38 12.00 3707.40 270.48 MWD 10775.00 90.92 44.66 8653.87 488.82 4789.58 5960830.41 696511.96 12.00 3732.39 270.43 MWD 10800.00 90.94 41.66 8653.47 507.05 4606.68 5960849.07 696528.59 12.00 3757.37 270.38 MWD 10825.00 90.96 38.66 8653.05 526.15 4622.80 5960868.58 696544.22 12.00 3782.28 270.34 MWD 10850.00 90.97 35.56 8652.63 546.07 4837.90 5960888.87 696558.80 12.00 3807.04 270.29 MWD 10875.00 90,98 32.66 8652.20 566.75 4851.93 5960909.90 696572.30 12.00 3831.59 270.24 MWD 10900.00 90,99 29.66 8651.77 588.14 4864.86 5980931.61 696584.68 12.00 3855.86 270.18 MWD 10913.50 90.99 28.04 8651.54 599.97 4871.38 5960943.60 698590.90 12.01 3868.83 269.97 MWD 10925.00 90.99 29.42 8651.34 610.05 4876.91 5980953.82 696596.16 12.00 3879.87 90.00 MWD 10950.00 90.99 32.42 8650.91 631.49 4889.75 5960975.58 696608.46 12.00 3904.11 90.02 MWD 10975.00 90.98 35.42 8650,48 652.23 4903,70 5960996.67 698621.87 12,00 3928.64 90.08 MWD 11000.00 90.97 38.42 8650.05 672.22 4918.71 5961017.03 696636.37 12.00 3953.38 90.13 MWD 11025.00 90.96 41.42 8649.63 691.38 4934.75 5961036.60 696651.91 12.00 3978.28 90.18 MWD 11050.00 90.95 44.42 8649.21 709.69 4951.77 5961055.33 696568.46 12.00 4003.25 90.23 MWD 11075.00 90.93 47.42 8648.80 727.07 4969.73 5961073.17 696585.96 12.00 4028.25 90.28 MWD 11100.00 90.92 50.42 8648.40 743.49 4988.57 5961090.06 696704.38 12,00 4053.18 90.33 MWD 11125.00 90.89 53.42 8648.00 758.91 5008.24 5961105.97 698723.65 12.00 4077.99 90.38 MWD 11150.00 90.87 56.42 8647.62 773.27 5028.70 5981120.85 696743,73 12.00 4102.61 90.42 MWD 11175.00 90.85 59.42 8647.24 786.55 5049.88 5961134.66 696764.57 12.00 4126.97 90.47 MWD 11200.00 90.82 62.42 8646.88 798.69 5071.72 5981147.36 696786.09 12.00 4151.01 90.52 MWD 11225,00 90.79 65.42 8646.53 809.68 5094.17 5961158.92 698808.25 12.00 4174.65 90.56 MWD 11250.00 90.75 68.42 8646.20 819.48 5117.17 5961169.30 696830.99 12.00 4197.84 90.60 MWD 11275,00 90.72 71.42 8645.87 828.06 5140.64 5981178.47 698854.24 12.00 4220.51 90.64 MWD 11300,00 90.68 74.42 8645.57 835.40 5164.54 5961186.42 696877.94 12.00 4242.59 90.68 MWD 11325.00 90.64 77.42 8645,28 841.47 5188.78 5961193,11 698902.02 12.00 4264.03 90.72 MWD 11350.00 90.60 80.42 8645.01 846.28 5213.31 5961198,54 696926.41 12.00 4284.78 90.75 MWD 11375.00 90.56 83.42 8644.75 849.79 5238.06 5961202.68 696951.06 12.00 4304.76 90.78 MWD 11400,00 90.52 86.42 8644.52 852.00 5262.96 5961205.53 696975.90 12.00 4323.93 90.81 MWD 11425.00 90.47 89.42 8644.30 852.90 5287.94 5961207.07 697000.84 12.00 4342.23 90.84 MWD 11450.00 90.43 92.42 8644.10 852.50 5312.93 5961207.30 697025.84 12.00 4359.62 90.87 MWD 11475.00 90.38 95.42 8643.93 850.79 5337.87 5961206.23 697050.81 12.00 4376.04 90.89 MWD 11500.00 90.33 98.42 8643.77 847.78 5362.68 5961203.85 697075.69 12,00 4391.46 90.91 MWD 11525.00 90.28 101.42 8643.64 843.47 5387.31 5981200.17 697100.41 12.00 4405.82 90.93 MWD 11550.00 90.23 104.42 8643.52 837.88 5411.67 5961195.21 697124.91 12.00 4419.10 90.95 MWD 11575.00 90.18 107.42 8643.43 831.02 5435.71 5961188.97 697149.11 12.00 4431.25 90.96 MWD 11594.00 90.14 109.70 8643.34 824.97 5453.72 5981183.37 697167.27 11.09 4439.70 91.06 MWD 3S CTD BOP Detail ... CT Injector I '" '[1 i ~.~._ ,+i Head ' ~tu,,,,,g BOX (Pack-Off), 10,000 psi Working Pressure ~1 I --- 7"Riser Methanol Injection ~ , . I Otis 7" WLA Quick I'~ ' ' ' ~ I Connect "-"--- I ] 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic TOT Flanged Fire Resistant Kelly Hose to Dual Choke Manifold hCr 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic 2" Side Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure I BlindlShear I 2 3/8" or 3 1/2" CombiI Pipe/Slip . [ Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn check valve Valve on DS Hardline to Standpipe manifold 2 718" Combi Pipe/Slip 2 318" Combi Pipe/Slip MOJ 5D1~1 Single Manual Master Valve (optional depending on RU) XO Spool as necessary 2 flanged gate valves 7" AnnUlus 9 5/8" Annulus 18-32a permit to drill Subject: 18-32a permit to drill Date: Mon, 4 Jun 2001 19:37:55 -0500 From: "Johnson, Mark O" <JohnsoMO@BP.com> To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak.us> CC: "Hubble, Terrie L" <HubbleTL@BP.com> Tom, Would it be possible to review and approve the 18-32a sidetrack Permit to Drill by 6/7/017 It was submitted to you folks on 6/1/01, so I know this is a special request. Nabors 3S may need to move to this contingency well if the Kuparuk bridge is not passable due to high water level. Base plan is to cross the bridge from PBU to Milne point on ~6/7, but if we cannot we would need to move to 18-32a. Thx much, MOJ 564-5666 240-8034 11 of 11 6/5/01 9:01 AM VENDOR ALASKAOILA O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET )51401_ CKO51_4Ol'F 1OO. OO 1.OO. OO PYMT COMMENTS: Peen it to Deill Fee HANDLING INST: S/H - Tee~ie Hub~le X4628 IE AWACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ~1 I[1~1 I~-*1 ~ ~ 1 OO. OO 100- O0 BP EXPLORATION, (ALASKA)INC. RO. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 189912 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00189912 PAY To Th e ORDER O'~ ONE HUNDRED & ******************************************** US DOLLAR ALASKA OIL AND OAS C oNSER VAT I ON :.C'OMH':!I SS ION 333. WEST 7TH AVENUE SUITE 1..OO ,.'DATE.': - .AMOUNT NO3~ YALID 'AFTER 120 DAYS ANCHORAOE AK 995'01 ,, WELL PERMIT CHECKLIST FIELD & POOL INIT CI.~ASS ~JZJ /-c'/~// ADMINISTRATION COMPANY WELL NAME ENGINEERING 1. Permit fee 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 ...... 13. Can permit be approved before 15-day wait ............ 14. Conductor string provided ................... 15. Surface casing protects all known USDWs...' ........ 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ...... 25. BOPEs, do they meet regulation ........... 26. BOPE press rating appropriate; test to "~'>"-O 27. Choke manifold complies w/APl RP-53 (May 84) ..... . . . 28. Work will occur without operation shutdown ....... .... 29. Is presence of H2S gas probable ................. PROGRAM: exp dev ?<' redrll ~' serv GIEOL AREA _?~. C-'~ UNIT# N N N ann. disposal para req GEOLOGY 30. Permit can be issued w/o hydroger~ sulfide measures ..... Y N ~ 31. Data presented on potential overpressure zones ....... Y.N/'' ~ ~ 32. Seismic analysis of shallow gas zones ............. ~Y ~1 /'/"///~-'/ ' 33. Seabed condition survey (if off-shore) .... : ........ 34. Contact name/phone for weekly progress reports [exploratory o~y] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ..... ... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well' used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAc 25.252 or 20 AAC 25.412. wellbore seg ON/OFF SHORE YY N/N ~ Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: , Comments/Instructions: I§ I§ Z c:\msoffice\wordian\diana\checklist (rev. 11/01//00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this. · nature is accumulated at the end of the file under APPENDIXi No 'special'effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 02/03/26 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 02/03/19 171491 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: ldwg.las -Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame ~Well Information Block #MNEM.UNIT Data Type Information STRT.FT 9678.0000: Starting Depth STOP.FT 11601.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration, Inc. WELL. WELL: 18-32A FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 3632' SNL, 41' WEL CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 1.75" NaviGamma - Gamma Ray DATE. LOG DATE: 18-Jun-01 API . API NYUMBER: 500292258501 ~Parameter Information Block #MIqEM.UNIT Value Description SECT. 24 : Section TOWN.N llN : Township RANG. 14E : Range PDAT. MSL : Permanent Datum EPD .F 0 : Elevation Of Perm. Datum LMF . RKB : Log Measured from FAPD.F 54 : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 54 : Elevation of Kelly Bushing EDF .F N/A : Elevation of Derrick Floor EGL .F N/A : Elevation of Ground Level CASE.F N/A : Casing Depth OS1 . DIRECTIONAL : Other Services Line 1 ~Remarks (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Well 18-32A was drilled as a sidetrack on well 18-32. (5) The sidetrack began at 9687' MD (8511' SSTVD). (6) Well 18-32A was drilled to TD at 11601' MD (8627' SSTVD). (7) The interval from 11560' MD (8627' SSTVD) to 11601' MD (8627' SSTVD) was not logged due to sensor to bit offset. (8) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) supplied by BPX (SWS, 21-Jun-2001). (9) A Magnetic Declination correction of 26.79 degrees has been applied to the Directional Surveys. (10) Surface Logging System / Software: CTMWD / DRILLBYTE (11) Gamma Ray Detector Type: Scintillator MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet SENSOE OFFSETS: RUN GAMMA DIRECTIONAL 1 N/A N/A 2 N/A N/A 3 N/A N/A 4 N/A N/A 5 N/A N/A CURVE SHIFT DATA BASELINE 9681.02 9721.83 9742.94 9801.12 9821 52 9862 69 9890 98 9925 52 9948 13 9976 21 10024.1 10048.1 10311.2 10396.4 11481.9 EOZ END MEASURED, 9679.81, 9722.03, 9744.35, 9802 73, 9822 13, 9864 71, 9893 81, 9928 55, 9951 36, 9975 40, 10027.1, 10047.9, 10310.2, 10396.0, 11479.4, DISPLACEMENT -1.21191 0.202148 1.41406 1 61621 0 606445 2 02051 2 82812 3 03027 3 23242 -0.807617 3.03027 -0.202148 -1.00977 -0.404297 -1.61523 ! BASE CURVE: GROH,. OFFSET CURVE: GRAX Tape Subfile: 1 86 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP Exploration, Inc. WN 18-32A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 21-Jun-01. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP .................................................... GR GR GRAX10 0.0 ROP ROP ROPS10 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool 1 GR MWD 2 ROP MWD Code Samples Units 68 1 API 68 1 F/HR Size Length 4 4 4 4 ....... 8 Total Data Records: 46 Tape File Start Depth = 9678.000000 Tape File End Depth = 11601.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 55 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes FILE HEADER MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP Exploration, Inc. WN 18-32A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MI~EM CHAN DIMT CNAM ODEP GRAX GR3~X GRAX 0.0 ROPS ROPS ROPS 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: IF ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool 1 GRAX MWD 2 ROPS MWD Code Samples Units 68 1 API 68 1 F/HR Size Length 4 4 4 4 8 Total Data Records: 46 Tape File Start Depth = 9678.000000 Tape File End Depth = 11601.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 55 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 02/03/19 171491 01 **** REEL TRAILER MWD 02/03/26 BHI 01 Tape Subfile: 4 2 records... Minimum record length: Maximum record length: Tape Subfile 1 is type: LIS 132 bytes 132 bytes Tape Subfile 2 is type: LIS DEPTH 9678 9678 9700 9800 9900 10000 10100 10200 10300 10400 10500 10600 10700 10800 10900. 11000. 11100 11200 11300 11400 11500 11600 11601 0000 5O00 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 GR -999.2500 54.6300 25.7597 34.6660 39.7628 36.3117 51.9567 50 1372 45 3120 60 9712 56 1958 55 5697 71 3470 68 9566 58 7539 48 8797 52 5446 67.5509 62.8600 58.1210 47.8814 -999.2500 -999.2500 ROP -999.2500 -999 2500 15 8888 87 7066 112 0349 50 7701 143 2465 90 0072 96.2379 100.2885 117.4059 150 8997 81 5960 130 2450 146 4180 123 5047 137 9579 123 1668 138 4280 162 2666 189 5329 -999 2500 -999 2500 Tape File Start Depth = 9678.000000 Tape File End Depth = 11601.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH 9678 0000 9678 5000 9700 0000 9800 0000 9900 0000 10000 0000 10100 0000 10200 0000 10300 0000 10400 0000 10500 0000 10600 0O00 10700 0000 10800 0000 10900.0000 11000.0000 11100.0000 11200.0000 11300.0000 11400.0000 11500.0000 11600.0000 11601.0000 GRAX -999.2500 -999.2500 26.6960 44.2490 29 2340 42 2430 52 4160 49 7310 48 7320 60 9080 61 2980 55 9100 72 3080 66 0060 53 6850 52 6300 49 1170 63 4460 62.8600 57.5900 43.4160 -999.2500 -999.2500 ROPS -999 -999 59 87 112 55 110 93 93 97 119 147 51 131 146 124 138 123 136 167 227 148 139 .2500 .2500 .2870 .3810 .1320 .2440 .7710 .8140 .9260 .3390 .0820 6380 5020 6430 4180 3270 1410 9650 2810 5320 9280 2500 2500 Tape File Start Depth = 9678.000000 Tape File End Depth = 11601.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS